APTD-1135
GUIDE FOR COMPILING
A COMPREHENSIVE
EMISSION INVENTORY
SECOND EDITION
U.S. ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF AIR AND WASTE MANAGEMENT
OF AIR QUALITY PLANNING AND STANDARDS
RESEARCH TRIANGLE PARK, NORTH CAROIINA 77711
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1 4 JUl 1976
APTD-1l35
GUIDE FOR COMPILING A COMPREHENSIVE
EMISSION INVENTORY
SECOND EDITION
MONITORING AND DATA ANALYSIS DIVISION
ENVIRONMENT AL PROTECTION AGENCY
OFFICE OF AIR AND WASTE MANAGEMENT
OFFICE OF AIR QUALITY PLANNING AND STANDARDS
RESEARCH TRIANGLE PARK, NORTH CAROLINA 27711
DECEMBER 1974 '
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This report is issued by the Environmental Protection Agency to report technical
data of interest to a limited number of readers. Copies are available free of charge
to Federal employees, current contractors and grantees, and nonprofit organizations -
as supplies permit - from the Air Pollution Technical Information Center, Environmental
Protection Agency, Research Triangle Park, North Carolina 27711; or, for a fee, from
the National Technical Information Service, 5285 Port Royal Road, Springfield,
Virginia 22161.
Publication No. APTD-1135
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ACKNOWLEDGMENTS
This manual was prepared to assist state and local air pollution control
agencies in compiling their emission inventories. Many persons assisted in its
preparation. The following individuals are especially acknowledged: D. H. Acker-
son, P. J. Bierbaum, J. Bosch, J. H. Cavender, M. J. Gedgaudas, J. R. Hammerle,
D. S. Kircher, A. A. MacQueen, C. O. Mann, D. V. Mason, J. B. Mersch,
J. H. Southerland, and E. F. Tison.
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CONTENTS
LIST OF FIGURES. .... .............
LIST OF TABLES. . . . . . . . . . . . . .
ABSTRACT. ............
1. INTRODUCTION . . . . . . . . . . .. ...
DESCRIPTION OF AIR POLLUTANT EMISSION INVENTORY. . . . . . . . .
USES OF EMISSION INVENTORY. . . . . . .. ...
PURPOSE OF THIS MANUAL. . . . . . . . . . . . .
2. UNIFORr~ SOURCE INVEiHORY . . . . .. ...
NEED FOR UNIFORM SOURCE INVENTORY . . .
COMPUTERIZED SYSTEM. . . . . . . . . . . . . . . . .
DATA FILES. . . . . . . . . . . . . . . . .
IDENTIFICATION FILES. . . . . . . . . . . .
. . .
. . .
. . .
Geographical Identification File. . . . . . . .
Use of UTM System. . . . . . . . . . . . . .
Air Quality Control Regions. . . . . ., .....
Population Data File. . .. ...........
AUTOMATIC DATA PROCESSING (ADP) SOFTWARE. . . . . . . . . . .
UPDATING DATA FILES. . . . . . . . . . . . . . . . .
REFERENCES. . . . . . . . . . . . . . . . . . . . .
3. EMISSION FACTORS.. ...............
EMISSION FACTORS DEFINED. . . . . . .. ......
USE OF EMISSION FACTORS. . . . . . . . . . . . . . . .
CONTROL EQUIPMENT. . . . . . . . . . . . . . . . . .
SOURCE CLASSIFICATION CODE. . . . . . . . . . .. ...
QUALITY RATINGS OF EMISSION FACTORS. . . . . . . . . . . . .
REFERENCE. . . . . . . . . . . . . . . . . . . .
4. POINT SOURCE CODING. . . . . . . . . . . . . . . . . .
DESCRIPTION OF POINT SOURCE CODING FORM. . . . .. ....
INSTRUCTIONS FOR COMPLETING POINT SOURCE CODING FORM. . . . . . .
IDENTI FICATION AND LOCATION OF POINT SOURCES. . . . . . .
STACK PARAMETERS. . . . . . . . . . . . . . . . . . .
CONTROL EQUIPMENT IDENTIFICATION CODE. . ... . . . . .
OPERATING INFORMATION AND EMISSION ESTIMATES. . . . . . . . . .
COMPLIANCE ANALYSIS. . . . . . .. """"
FUEL, PROCESS, OR SOLID-WASTE INFORMATION. . . . . . . . . . .
SUPPLEMENTARY INSTRUCTIONS. . . . . .. ........
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REFERENCES
5. AREA SOURCE CODING
IDENTIFICATION OF AREA SOURCE.
COUNTY INFORMATION.
EMISSION ESTIMATES.
FUEL DATA.
STATIONARY SOURCE FUEL CONSUMPTION
Major Fuels.
Minor Fuels.
Estimating Area Source Fuel Consumption
Apportioning Fuel Consumption.
Applying Fuel Consumption Apportionment Methods.
SOLID WASTE DISPOSAL.
MOTOR VEHICLE FUEL DATA.
Gasoline-Powered Motor Vehicles.
Diesel-Powered Motor Vehicles.
Off-Highway Fuel Use.
Railroads
Vessels.
Aircraft.
EVAPORATIVE LOSSES.
Gasoline-Handling Losses
Dry Cleaning Losses.
Surface-Coating and Miscellaneous Solvent-Use Operations
MISCELLANEOUS SOURCES.
REFERENCES
6. TRACE-MATERIAL AND HAZARDOUS-POLLUTANT SOURCE CODING
DESCRIPTION OF TRACE-MATERIAL AND HAZARDOUS-POLLUTANT FILE
INSTRUCTIONS FOR COMPLETING TRACE-MATERIALS CODING FORM
7. DATA PRESENTATION.
INTRODUCTION. .
APPORTIONING POPULATION DATA TO GRIDS
APPORTIONING TRANSPORTATION EMISSIONS TO GRIDS
Apportioning Vehicle Miles Traveled and Vehicle Emissions to Grids
Apportioning Railroad Track and Railroad Emissions to Grids.
Apportioning Vessel Emissions to Grids.
APPORTIONING OF LOSSES FROM GASOLINE MARKETING TO GRIDS
APPORTIONING OF SOLID WASTE DISPOSAL TO GRIDS.
APPORTIONING.OF RESIDENTIAL FUEL SOURCES TO GRIDS
APPORTIONING OF COMMERCIAL AND INSTITUTIONAL SOURCES TO GRIDS
APPORTIONING OF MISCELLANEOUS SOURCES TO GRIDS
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APPORTIONING OF POINT SOURCES TO GRIDS.
TOTALING GRIDDED EMISSIONS.
REFERENCES.
8. DISPERSION MODELING.
INTRODUCTION
USES OF DIFFUSION MODELS
EMISSION INVENTORY AND OTHER DATA NEEDED FOR MODELING.
REFERENCES.
9. QUESTIONNAIRES.
GENERAL INFORMATION.
10. EPA DATA SYSTEM FOR ATMOSPHERIC EMISSIONS.
CONCEPT OF NEDS
POINT AND AREA SOURCE INVENTORIES FOR NEDS
EMISSION FACTORS FOR NEDS .
DATA RETRIEVAL ACCESS FOR NEDS
Summaries.
Sorting.
Special Analysis.
UPDATING AND MAINTENANCE FOR NEDS
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APPENDIX A - COMPREHENSIVE EMISSION INVENTORY IDENTIFICATION CODES.
GEOGRAPHICAL IDENTIFICATION CODES.
State Identification Numbers.
Air Quality Control Region Identification Numbers.
SOURCE CLASSIFICATION CODES.
CONTROL EQUIPMENT IDENTIFICATION CODES.
IPP PROCESS IDENTIFICATION CODES.
TRACE ELEMENTS AND COMPOUNDS IDENTIFICATION CODES
APPENDIX B - COMPREHENSIVE E~ISSION INVENTORY CARD FORMATS
POINT SOURCE CARD FORMAT.
AREA SOURCE CARD FORMAT.
TRACE MATERIALS/HAZARDOUS POLLUTANTS SOURCE CARD FORMAT
SOURCE CLASSIFICATION CODE CARD FORMAT
GEOGRAPHICAL CARD FORMAT.
APPENDIX C - POINT SOURCE DEFINITION.
APPENDIX 0 - EXAMPLE QUESTIONNAIRES.
EXAMPLE COVER LETTER.
INSTRUCTIONS FOR COMPLETING QUESTIONNAIRE.
AIR POLLUTANT EMISSIONS SURVEY.
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--,
CRUDE OIL DRILLING, NATURAL GAS, AND LPG FACILITIES
CONCRETE BATCH PLANTS,
CONICAL BURNERS,
SAWMILLS
PEANUT PROCESSING
COTTON GINNING
ASPHALT BATCH PLANTS
GRAIN HANDLING
PETROLEUM REFINING,
TECHNICAL REPORT DATA SHEET .
LIST OF FIGURES
Figure
2-1 Emission Inventory System Concept.
2-2 UTM Grid Zones in the Contiguous United States,
4-1 Point Source Coding Form.
5-1 Area Source Coding Form
6-1 Trace Materials/Hazardous Pollutant Source Coding Form
7-1 Use of Pie Charts to Illustrate Relative Distribution of Pollutant
Emissions from Various Sources,
7-2 Grid Coordinate System Example
7-3 UTM Grid Overlay of Census Tract Map of One County
7-4 Grid Coordinate System for Example Study Area,
7-5 Population Densities for Example Study Area.
7-6 Point Source Locations for Example Study Area,
7-7 Particulate Emission Densities from All Sources in Example Study Area,
7-8 Sulfur Oxides Emission Densities from All Sources in Example Study Area.
7-9 Carbon Monoxide Emission Densities from All Sources in Example Study
Area
A-l Environmental Protection Agency Regions
A-2 Federal Air Quality Control Regions
LIST OF TABLES
Table
5-1 Nationwide Average Solid Waste Disposed of by Incineration and Open
Burning
. 5-2 Solvent-Use Estimates.
5-3 Forest Fire Estimates
7-1 Average Vehicle Counts by Land Use.
7-2 Average Vehicle Speeds by Route Class,
7-3 Average Fuel Consumption for a Five-Room Residence
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Table
7-4 Sunmary of Air Pollutant Emissions from All Sources in Example Study
Area
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ABSTRACT
Detailed procedures are given for obtaining and codifying information about
air pollutant emissions from stationary and mobile sources. The system has been
developed specifically for use by state and local air pollution control agencies.
Because of the large amount of information that must be collected, the data must
be handled by ADP means.
A uniform coding system fer the data is encouraged in order that the informa-
tion froffi one region may be compared with that from another. Detailed procedures
are given concerning the information to be gathered from each source, the methods
to be used to gather the information, the codes to be used to simplify the infor-
mation on standard coding forms, the geographical and population information
needed about the area of interest, the apportionment techniques and emission
factors needed, and the methods of displaying the data. The relation of state
and local emission inventory systems to the EPA NED system is also explained.
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GUIDE FOR COMPILING A COMPREHENSIVE
EMISSION INVENTORY
1.
INTRODUCTION
1.1
DESCRIPTION OF AIR POLLUTANT EMISSION INVENTORY
Pollution of the atmospheric environment has come about as an undesired by-
product of the technological advancement of modern society. It is imperative
that man use the technology that he has developed to engineer the prevention of
atmospheric emissions.
The initial step toward improving the air pollution situation is to define the
problem areas. A primary requirement is determination of the sources and components
of air pollution. Fundamentally, this requirement is provided for by the emission
inventory, which answers the pressing questions regarding sources, pollutant types
and quantities, and relative impact.
Identification of sources, pollutants. locations. and quantities of emissions.
coupled with local meteorological and air quality data and information regarding
air pollution effects. provides the basis for a plan of action for improvement of
air quality. The emission inventory is therefore a vital element in the abatement
of emissions and in subsequent improvements in air quality.
1.2 USES OF EMISSION INVENTORY
Because it defines the sources of air pollution relatively and quantitatively.
the emission inventory is one of the most important planning tools available to an air
pollution control agency. The inventory provides information concerning source emis-
sions and defines the location. magnitude. frequency. duration, and relative contribu-
tion of these emissions. It can be used to measure past successes and to point to
future requirements. An emission inventory can be used to design an air sampling
network. to predict ambient air quality, to design. evaluate. or modify a control
program. and. in conjunction with a permit or registration system. to provide up-to-
date information on major sources of pollution.
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The proper emission control strategy for a specific air pollution problem is
dependent upon an adequate assessment of the nature and extent of the pollution in
the region involved. This assessment includes a review of existing levels of
pollutants, the sources and their emissions, the techniques available for their
control, and the probable increase in source emissions resulting from urban and
economic growth. The emission inventory indicates the major contributors (motor
vehicle, industrial, etc.), and this information, in turn, directs the thrust of
control efforts. After the control strategies have been developed, they can be
tested with the aid of a diffusion simulation model or other systematic, quantita-
tive procedures to determine which strategies are capable of bringing about
acceptable air quality as defined by national or state ambient air quality
standards.
If the emission inventory is updated annually, a decrease in emissions should
be reflected over a period of years. This decrease would then be a measure of the
effectiveness and success of the control program and could be used to indicate
areas where program modification would be useful.
Likewise, in the design of an air sampling network, it is important to get
maximum return in usable data for the manpower and funds invested. Information
concerning the location of sources and quantities of emissions in a region may be
used to indicate where the highest pollutant concentrations probably exist. This
knowledge will assist the agency in locating elements of the sampling network.
Samplers are normally concentrated in areas of greatest emissions. In the event
that a single source is believed to be primarily responsible for degraded air
quality, the sampling network may be oriented in such a way that evidence of the
impact of the emissions from that particular source may be obtained.
The emission inventory may be used with sufficient supporting meteorological
data to predict ambient air quality for a given locality. From emission density
maps, areas with high pollutant releases can be located. A more sophisticated
method of predicting air quality is diffusion simulation modeling. Included among
the models in widespread u~e are the Air Quality Display Model (AQDM) and the
Implementation Planning Program (IPP). Although the AQDM and IPP are relatively
simple to use, the accuracy of results is very dependent upon the degree to which
the input data represent the physical situation within the area of interest.
1.3 PURPOSE OF THIS MANUAL
The specific purpose of this manual is to describe methods of obtaining
emission inventory data and of presenting the information. Automatic data
processing, charts, and maps are discussed as presentation techniques, and a step-
by-step description of data acquisition is provided. As more information becomes
available on emission inventory techniques and as specific methodology becomes
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more sophisticated, updated sections of this manual will be published as supplements
available from the Air Pollution Technical Information Center, EPA. Any suggestions
on specification of air pollutant emission inventory details should be directed to
the Chief, Technical Development Section, National Air Data Branch, Monitoring and
Data Analysis Division, Office of Air Quality Planning and Standards, U.S. Environ-
mental Protection Agency, Research Triangle Park, North Carolina 27711.
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2.
UNIFORM SOURCE INVENTORY
2.1 NEED FOR UNIFORM SOURCE INVENTORY
Much detailed information is needed about each source of pollutants in a
selected locale before an emission inventory can be computed for that area.
There are several ways in which the information about each source can be collected
and codified. If, however, the data from one area are to be compared with those
from another, it is necessary that all the information about all the sources con-
form to certain conventions.
Thus, common weight units, volume units, area units, grid coordinates, etc.,
must be used by all the data collectors. Another reason for standardizing data
recording is to facilitate automatic data processing (ADP), which win be necessary
because of the enormous amount of data that will be amassed from the large number
of sources nationwide.
2.2 COMPUTERIZED SYSTEM
The concept of the computerized system is shown in Figure 2-1; the data
storage and identification files are shown on the left side of the diagram, and
the ADP operations are indicated on the right. The system will store data for all
point and area (county) sources of emissions using the identification codes listed
in Appendix A, and the formats shown in Appendix B; these data will be updated
periodically.
2.3 DATA FilES
The following files are used for data storage:
Point source file - all source information on each point source, inclu9ing
Federal facilities.
2. Area source file - all source information on each area (county) source.
1.
3.
Hazardous pollutants source file - all source information on each emitter
of hazardous or potentially hazardous trace elements or compounds. (Emitters
meeting the requirement of a defined point source also are listed in the
point source file.)
Because all emission factor information is stored separately in the emission
factor file, changes can be made, at any time, in the emission factor file (con-
taining about 900 cards) without modification of the source files (containing many
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EMISSION INVENTORY DATA SYSTEM
POINT SOURCE FILE
EMISSION CALCULATION PROGRAMS
I INPUT /OUTPUT PROGRAMS
AREA SOURCE FILE
HAZARDOUS POLLUTANTS SOURCE FILE
AREAWIDE INVENTORY PROGRAMS
EMISSION FACTOR FILE
IPP MODELING CONVERSION PROGRAM
GEOGRAPHICAL ID FILE
AREA SOURCE GRIDDING PROGRAM
CONTROL EQUIPMENT ID FILE
TREND/PROJECTION ANALYSIS PROGRAMS
IPP PROCESS ID FILE
POPULATION DATA FILE
Figure 2-1. Emiss ion inventory system concept.
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thousands). The formats for storage in the source and emission factor files are
given in Appendix B, Sections 1. 2, and 3. and the Source Classification Codes
(SCC's) for emission factors and units are given in Appendix A. Section 2.
2.4 IDENTIFICATION FilES
Additional data required for identification are stored in the fOllowing files:
1. Geographical identification file - all Federal regional offices. state, AQCR
(Air Quality Control Region). and county names and identification numbers.
2. Control equipment identification file - all control equipment names and
identification numbers.
3.
IPP process identification file - all identification numbers as required in
the inventory to be used in IPP modeling programs.
The formats for files 1 and 2 are given in Appendix B. Sections 4 and 5, and
the actual identification numbers for files 1. 2. and 3 appear in Appendix A. Sec-
tions 1.3. and 4.
Both projection and trend analyses require the use of extensive population
data and associated information on housing. etc. If a state desires to use these
analyses. the necessary information will be stored in the OAP data file on
population.
2.4.1 Geograph ica I Identification File
For the emission inventory to be used properly. emissions must be reported
geographically. with point sources identified and located precisely. and area
sources apportioned to specific grids. For inventories in different localities to
be compatible. a uniform reporting system must be used.
For the purposes of emission inventories, as discussed in this manual. point
sources are defined1 as sources that emit at least 100 tons per year of an air
pollutant and that can be pinpointed to a definite geographic location or as sources
listed in Appendix C regardless of their annual emissions. An area source. on the
other hand. is one that emits less than 100 tons per year and is apportioned over a
geographic'area. (It should be noted that the value of 100 tons is the one chosen
by EPA; the states may. at their discretion. select smaller values that best suit
their own particular problems and needs.) These definitions apply to particulates.
SOx. CO. hydrocarbons. and NOx' Every emitter of hazardous pollutants or trace ele-
ments and compounds is considered a point source.
Various grid systems utilizing coordinate systems have been developed for
locating geographical points. The three most common systems are:
1. Latitude and longitude system.
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2.
3.
State plane system.
Universal Transverse Mercator (UTM) system.
A detailed description of these systems has been provided by the Department of the
Army2 and Deetz and Adams,3 who give excellent backgrounds for understanding the
development of coordinate systems. Because of various disadvantages of the first
two systems, the third, the Universal Transverse Mercator system, was developed by
the U. S. Army. In this system, instead of using the equator as the "axis of the
Mercator," the U. S. Army transversed (rotated) the axis 90 degrees and used a
meridian running north-south as the axis from which all measurements would be made.
In this manner, a meridian at any point on the globe may be selected so that an
approximately 2,000-mile-wide (15 degrees to each side of the meridian) area of
unskewed map covers any part of the world.
The Universal Transverse Mercator (UTM) system was designed by the U. S.
Army4 to provide for the projection of square grid zones with convenient measuring
units. The system also maximizes the distance measurable from one pair of
meridians and false origins with a reasonable amount of accuracy. The globe was
subdivided into 60 north-south zones, each 6 degrees wide with a central transverse
Mercator. Ten of these UTM zones cover the continental United States, as indicated
in Figure 2-2. The false origin for each zone in the Northern Hemisphere is
500,000 meters west of the point where its central meridian crosses the equator.
Using the UTM system, grid zones may be drawn for air pollution emission inven-
tories.
2.4.2
The advantages of this system are:
1.
UTM grids are continuous across the country and not hindered by political
subdivisions.
2.
3.
UTM grids are uniform throughout the country.
Grid lines are identifiable by "tick marks" on the USGS maps.
4.
5.
The system is used worldwide.
The system is becoming the base repository for a growing body of technical
information.
6.
Interstate AQCR's must have a common coordinate system.
Use of UTM System
USGS maps do not show UTM grid lines as they do latitude and longitude;
however, tick marks along the edges of the maps do indicate the grid locations.
Three basic map scales are available:
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ZONE 10
114'
ZONE 12
1~ .
ZONE 13
102.
ZONE 14
96.
90.
84-
78 0
72 -
ZONE 15
ZONE 16
ZONE 19
120'
\D
1~. W2° ~. ~o
Figure 2-2. UTM grid zones in the contiguous United States.
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1. 1 :250,000.
2. 1 :62,000.
3. 1:24,000.
For 1, the tick marks appear for every 10,000 meters; for 2 and 3, they appear for
every 1000 meters, with every fifth tick mark giving the meter value. Also for 2
and 3, the meter values for the tick marks nearest the southeast and northwest
corners of the map are given. .
The 1:24,000 scale is necessary to locate point sources adequately; maps with
these scales are readily available for many rural areas and for all metropolitan
areas. A straight edge must be used to connect tick marks on the top and bottom of
USGS maps when interpolating because the maps are drawn on the latitude-longitude
system and, therefore, the UTM grids may appear quite skewed. To facilitate the
reading of UTM grid coordinates and to avoid the need for visual interpolation, one
should obtain translucent metric grid templates that can be used to overlay the
grid zones.
The UTM zone number, which is indicated on each USGS map, must be cited to
locate the coordinates properly. Figure 2-2 indicates that zones 10 through 19
encompass the 48 contiguous states; zones 1 through 9, Alaska; zones 19 and 20,
Puerto Rico and the Virgin Islands; and zones 1 through 5, Hawaii. For a complete
description of these zones, refer to Reference 5.
2.4.3 Air Quality Control Regions
The Office of Air Programs, EPA, has issued a publication6 that clearly de-
fines the boundaries of the AQCR's and lists the counties and cities in each region.
Furthermore, an identification number has been assigned to each AQCR and county
for automatic data processing; these identification numbers, shown in Appendix A,
constitute the geographical identification file of the data system.
2.4.4 Population Data File
An emission inventory, the generation of which involves many steps, is for
the purpose of ascertaining the quantity of emissions for some selected pollutants
for a desired area such as county, city, or state. In this manual, particular
emphasis is placed on obtaining estimates at the county level.
Because it is impossible to test all pollutant sources individually,
particularly area sources, an estimating procedure must be used. In order to do
this, however, one must estimate the magnitude of variables or indicators that can
then be related to emissions. These indicators include such things as fuel consump-
tion, vehicle miles, gasoline sales, raw materials processed, and tons of refuse
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burned, which are then multiplied by appropriate emission factors to estimate
emissions.
Some emissions, however, can be related to the number of inhabitants in an
area. Perhaps the best example of this kind of emission is that occurring from
solid waste disposal. Studies? have shown that each person generates a daily
average of 10 pounds of solid waste. In this case, lacking more precise informa-
tion, an estimate of tons of refuse may be obtained by applying this figure to the
population of the area of interest.
The use of "population data," as this infonnation is called, has become an
inherent part of the emission inventory procedure. It is often difficult and
expensive to detennine fuel consumption and other indicators of pollution in
areas smaller than states or SMSA's (standard metropolitan statistical areas) because
data are normally only reported for large geographic areas (i .e., states). In such
cases, it is then necessary to apportion these totals to each county or city of
interest. The several ways of doing this, depending on the source category of emis-
sions, require the use of population ratios, number of household units in an area,
number of manufacturing employees, urban-rural population ratio, amount of construc-
tion, or number of retail and wholesale establishments. Without this information,
it would be very difficult to obtain estimates of emissions for smaller areas.
Population data may be obtained from a variety of sources. The Bureau of
Census publishes many documents containing such infonnation; the three most
valuable for inventory purposes are the Census of POPulation,8,g the Census of
Housing,lO and the Census of Manufacturing.ll As the name indicates, the census of
population contains official population counts for states, urban and rural resi-
dences, SMSA's, and counties. The census of housing contains detailed housing
.characteristics such as number of occupied dwelling units, number of rooms per
structure, equipment (heating, air conditioning), and fuels used for heating and
cooking. The census of manufacturing is comprised of 80 separate reports, and
summary figures are provided for 422 manufacturing industries on quantity and value
of goods shipped, cost of fuels and electric energy, employment, etc.
Apportionment on the basis of population data is primarily used in detennining
emissions from area sources. Procedures for identifying these emissions will be
discussed in detail in Chapter 5. The following, however, are simplified examples
of how population data can be used for this purpose if more detailed data are not
available as described in Chapter 5.
If residential or commercial coal consumption for a state is known and
apportionment to a specific county within the state is required, simply multiply
the amount of coal for the state by the ratio of the population of the county to
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that of the state. This method will permit an estimate of coal consumption to be
made for each county. This procedure is reasonable if the coal consumption is
primarily for residential use, as would probably be true of anthracite coal. The
procedure also assumes that the coal consumption is spread uniformly over the
state.
In estimating industrial fuel use, apportionment is made on the basis of the
number of manufacturing employees. To apportion commercial and institutional fuel
quantities, use either population figures alone or a combination of population and
number of retail and wholesale establishments, depending on the area under study
(see Chapter 5).
Census data are also used in estimating emissions from mobile sources. It
has been found that emissions vary according to the characteristics of driving:
stop-and-go city driving leads to greater emissions than open-road driving.12 It
thus becomes necessary to obtain estimates of the ratio of urban to rural driving
from the census of population. Sometimes it is necessary to use gasoline consump-
tion data to estimate these emissions, in which case apportionment by the population
file would be made.
2.5 AUTOMATIC DATA PROCESSING (ADP) SOFTWARE
Following the definition of storage and identification file formats, the ADP
programming necessary for data storage, maintenance, manipulation, and retrieval can
begin. Conceptually, some of these functions are shown in Figure 2-1 (right-hand
side). These programs, which constitute the ADP software necessary to utilize the
source and identification data, include:
l.
2.
Input/output programs.
Emission calculation programs - for use in applying emission factors to
source data to obtain emissions.
3. Areawide inventory programs - for outputting data in a form suitable for'
reporting point and area source emissions by source classification and
geographical areas.
4.
IPP modeling conversion
source files to be used
proper format for input
program - for selecting items of data from the
for modeling, and for outputting these items in the
to the IPP programs.
5. Area source gridding program - for apportioning the area source emissions
to grids in a form suitable for input to IPP modeling.
6. Trend/projection analysis programs - for utilizing available data to
ascertain trends or projections of emissions by sources and geographical
areas.
12
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The programs for these operations are currently being prepared by EPA.
2.6 UPDATING DATA FILES
Source files (point, area, and hazardous pOllutants) must be continuously
updated to keep the emission inventory current. Information for the update can
come from permit or registration activities as well as from inspection reports.
The emission factor file will also be updated continuously as new information from
source testing becomes available.
2.7 REFERENCES
1.
2.
Federal Register, Part II.
p. 15497.
August 14, 1971.
Grids and Grid References. Department of the Army.
Publication No. TMS-241-1. June 1967.
Washington, D. C.
3.
Deetz, C. H. and p. S. Adams.
of Commerce. Washington, D.C.
Elements of Map Projection. U.S. Department
Spec. Publication No, 68. 1945.
4.
Universal Transverse MercatQr Grid. U.S. Department of the Army.
D.C. Publication No. TM5-241-B. July 1958.
Washington,
5.
Universal Transverse Mercator Grid, Zone-to-Zone Transformation Tables. U.S.
Department of the Army. Washington, D.C. Publication No. TMS-241-2. June 1957.
Fe4eral Air Quality Control Regions. U.S. Environmental Protection Agency,
Office of Air Programs. Research Triangle Park, N.C. OAP Publication No.
AP-102. January 1972.
6.
7. National Survey of Community Solid Waste Practice.
PHS. Washington, D.C. 1968.
Interim report.
U.S. DHEW,
8.
1970 Census of Population, Number of Inhabjtants. PC (l)-A series. U.S.
Department of Commerce, Bureau of Census. W~shington, D.C. 1970.
1970 Census of Population, General Pppulation Characteristics. PC (l)-B
series. U.S. Department of Commerce, Bureau of Census. Washington, D.C.
1970.
9.
10.
1970 Census of Housing, Detailed Housing Characteristics. HC (l)-B series.
U.S. Department of Commerce, Bureau of Census. Washington, D.C. 1970.
1967 Census of Manufacturing, Final Industry Reports. MC 67 (2) series. U.S.
Department of Commerce, Bureau of Census. Washington, D.C. 1967.
11.
12.
Cernansky, N. P. and K. Goodman. Estimating Motor Vehicle Emissions on a
Regional Basis. Presented at the 63rd Annual Air Pollution Control Association
Meeting, June 14-18, 1970.
13
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3.
EMISSION FACTORS
3.1 EMISSION FACTORS DEFINED
In the assessment of community and national air pollution, there is a
critical need for accurate data on the quantity and characteristics of emissions
from the numerous sources that contribute to the problem. The large numbers of
these individual sources and their diversity make field measurements of all sources
of emissions impossible. The only practlcal approach is to make generalized
estimates of typical emissions for each of the source classifications when actual
field test data are not available.
The emission factor is a statistical average or a quantitative estimate of the
rate at which a pollutant is released to the atmosphere as a result of an activity
such as combustion or industrial production, divided by the level of that activity.
For example, assume that in the production of 260,000 tons of ammonia per year,
26,000 tons of carbon monoxide is emitted to the atmosphere. The emission factor
for the production of ammonia would therefore be 200 pounds (0.1 ton) of CO released
per ton of ammonia produced. The emission factor thus relates the quantity of pollu-
tants emitted to some indicator of activity such as production capacity, quantity of
fuel burned, or vehicle miles traveled.
Many techniques are available for use in determining emission factors. These
techniques include detailed source testing involving many measurements related to
a variety of process variables, single measurements not clearly defined as to
their relationship to process operating conditions, process material balances, and
engineering appraisals (estimates) of a given process.
The limitations and applicability of emission factors must be understood: in
general, emission factors are not precise indicators of emissions from a single
source, but are more valid when applied to a large number of sources and processes.
When such limitations are taken into account, emission factors can be extremely
useful in conducting source inventories as a part of community or nationwide air
pollution studies.
Emission factors may be found in a number of literature sources. The most
complete collection of factors has been pUblished by the Environmental Protection
Agency in AP-42, Compilation of Air Pollutant Emission Factors (revised 1973).1
15
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3.2 USE OF EMISSION FACTORS
Emission factors are used in conjunction with source information gained through
methods described elsewhere in this document. The information needed for area and
point sources will vary. When calculating area source emissions, a generalized
emission factor may be used with fuel data, vehicle miles, or other activity level
to estimate the emissions. For point sources it is very important that actual
data be available from questionnaires, on-site visits, telephone contacts, etc. in
sufficient detail to determine which factor to use, the production factors
involved, realistic estimates of control efficiencies, and any unique characteris-
tics that might affect the emissions. It is important that the information used
contain detail on minor operations, parallel or preparatory processes, and air
pollutants from sources other than the main production activity. Though the
emission factor procedure is simple in nature, utilization of factors cannot be
entirely mechanical. Engineering knowledge and judgment are often necessary to
arrive at realistic estimates. Emission factors are chosen from Compilation_~!.
Air Pollutant Emission F~~torsl and multiplied by the activity level information
available; correct units must be used. This product will be the estimated
emissions for the time frame in consideration (i.e., tons per day or tons per
year) .
3.3 CONTROL EQUIPMENT
When selecting an emission factor, care must be taken to determine whether
it is for emissions before or after control. Most factors are presented in
terms of uncontrolled or precontrolled quantities. A few source categories,
however, have factors that can be used to estimate the emissions on a controlled
or partially controlled basis because of the uniqueness of the process equipment
or sources of data available. In those cases where a factor that takes controls
into account is given, no further adjustment need be made to the emission estimate.
If the emission factor used gives an estimate of emissions before control; the
factor must be adjusted to reflect effects of control equipment employed. For
example, if a source has an activity level of 1000 tons production per year and the
uncontrolled factor is 1 pound of particulates per ton of product, the particulate
emissions before control would be 1000 pounds per year. If a baghouse having a 99
percent efficiency were attached to the process, then the "controlled" emissions
(i.e., emissions after effects of control) would be 10 pounds of particulates per
year. Thus both emission factors and control equipment effects must be considered VII..
when estimating emissions.
Efficiency of a particular control device or type of control device can vary
considerably, depending upon a number of source-related variables such as particle
16
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size, pressure drop, equipment deterioration, gas concentrations, and physical and
chemical characteristics of the pollutants. A control device for one pollutant may
also affect the removal of another pollutant. This might occur, for example, when
a wet scrubber, primarily for particulates, also removes some percentage of sulfur
oxides. The sulfur oxide remtal in th.iS case would be termed secondary control.
For these.reasons it is neces ry to define typical control efficiencies ~
pollutant for the devices use in terms of each specific process or operation.
These definitions are currently being developed by EPA.
3.4 SOURCE CLASSIFICATION CODE
For the purpose of data collection, the emission factors and control
equipment efficiencies have been identified by the individual process or activity
that might be defined as a point source. A series of point source classification
codes has been developed for those sources for which emission factors are
available. Four levels of identification are used. These four levels are
sufficient to define a general category, and subcategories within the general
category. The subcategories define classification as to fuels, industria'
processes, products. equipment types used, etc. The classification system is
quite flexible, and new or revised emission factors may be added easily.
3.5 QUALITY RATINGS OF EMISSION FACTORS
Emission factor accuracy and reliability are dependent upon many variables.
It is generally accepted that emission factors generated from on-site source-test
data are preferred and will give more realistic estimates than those developed
strictly from engineering analyses or material balances. Even the well-balanced
factors at best will have an inherent variability influenced by source-test
inaccuracies, material fluctuations, and age and condition of control devices.
In the past, the level of reliability of emission factors has been represented
by an alphabetic code: "A" through "E," where "A" indicates a rating of
"excellent." An attempt is currently underway to attach a number to this
reliability. This quality factor should be integrated into the emission factor
codes and should be available in such a fashion that by combining the individual
quality levels and the emissions in each source category, a reliability rating
for the overall emission inventory for an area may by realized. The quality
ratings are indicated in Compilation of Air Pollutant Emission Factors.1
3.6 REFERENCE
1.
Compilation of Air Pollutant Emission Factors. U. S. Environmental Protection
Agency, Office of Air Programs. OAP Publication No. AP-42. Research Triangle
Park, North Carolina. March 1973.
17
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4.
POINT SOURCE CODING
4.1 DESCRIPTION OF POINT SOURCE CODING FORM
The point source coding form shown in Figure 4-1 contains space for six sepa-
rate computer cards of data for each point source. At least one coding form should
be completed for each facility defined as a point source. As outlined in the
Federal Register, November 25, 1971,51 .1(K), a point source is:
(a) any stationary source causing emissions in excess of 100 tons (90.7 metric
tons) per year of any pollutant for which there is a national standard in a
region containing an area whose 1970 "urban place" population, as defined by the
U.S. Bureau of Census, was equal to or greater than 1 million, or (b) any sta-
tionary source causing emissions in excess of 25 tons (22.7 metric tons) per
year of any pollutant for which there is a national standard in a region con-
taining an area whose 1970 "urban place" population, as defined by the U.S.
Bureau of Census, was less than 1 million, or (c) without regard to amount of
emissions, stationary sources such as those listed in Appendix C to this part.
Also included in a definition of point sources are the sources included in a compre-
hensive permit or registration system already maintained by the agency.
Source data required on the coding form are needed for the following reasons:
1. To locate the source geographically and to index it with respect to
county, state, city, and AQCR.
2. To describe the process and operating conditions of the source along
with details on air pollution control equipment and emission charac-
teristics.
3. To automatically calculate emissions of particulates, SOx' hydrocarbons,
NOx' and CO by means of current emission factors.
4. To provide input data for mathematically modeling the local air quality;
the modeling, in turn, allows the enforcing agency to develop control
strategies on a rational basis after evaluating numerous combinations of
possible alternatives.
5. To ascertain the legal status of each
current pollution control regulations
pliance schedules, and variances).
point source in complying with
(i.e., allowable emissions, com-
19
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N
o
POINT SOURCE
Input Form
Date
Name 01 Person
Completing Form
SCC Fuel,Process, ~~
~earof c
Solid Waste Maximum Design Sullur .1, Ash Heat Content 0
Record I II III IV OllOratin Rate Rate Omtent " Content'. 106 BTU/see Comments ~ 0 u ed
..:
16 17 8 19 20 21 2223 24 25 627 2829 30 31 32 33 34 35 36 37 38 .39 40.41 4243 44 45 46 47 48 4950 51 52 53 54 556 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 273 74 75 76 7 8 9 80
: 1-1 A P 6
A P 6
I A P 6
I A P 6
~ A P 6
EPA I au RI 220
3/72
Figure 4-1.
Point source coding form.
-------
The layout of the six cards on the coding form is such that data least likely
to change are on the first cards, and data most likely to change are on the last
cards at the bottom of the coding form. This arrange~ent allows updating the point
source data at a later time without unnecessarily rewriting the entire coding form.
~oreover, the system is designed to facilitate the collection and recording of any
additional data on the point sources that may be required in the future. Such ex-
pansion as the need arises is necessary in compiling a comprehensive inventory.
4.2 INSTRUCTIONS FOR COMPLETING POINT SOURCE CODING FORM
Certain instructions that apply to the entire form include the following:
Zeros are treated either as numbers or to indicate fields that are
nonapplicablei blank spaces in a field indicate a lack of data.
This means that the system separates items that are either numerically
zero or not applicable from those that are unknown. If a field is
nonapplicable, then only one zero need be tabulated in the right-
justified columns of the field.
2. Only specified alphabetical or numerical characters are allowed to be
entered in the columns. No unusual marks are to be made "in the spaces.
No data field headings are to be changed and only data appropriate to the
field are to be entered. This rule prevents unnecessary keypunching errors
in processing the forms.
1.
3. Only the allowed coding values may be entered in columns that require
coding symbols. The coding lists may be expanded as needed from time to
time.
Instructions for filling out each card on the form are quite specific and
were designed to apply to the large majority of point sources. Neverthe-
less, it is recognized that assumptions must occasionally be made to
reflect the real, physical situation at an unusual point source. Care'
should be taken to make reasonable assumptions that most nearly correspond
to the true circumstances at the point source.
5. Any boiler should be considered a separate and individual point source and
coded on a separate coding form. For example, if two or more such boilers
at a facility discharge gases into one smokestack, then two (or more) coding
forms should be completed. However, there are instances when it is permis-
sible to combine boilers as a single point source:
4.
a. Where two or more similar small boilers (burning the same type fuel,
having the same operating hours, and having similar capacities) are dis-
21
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22
charged through a common stack,
on one coding form if the total
than 100 tons per year.
they may be combined as a sinq1e source
emission of anyone pollutant is less
b.
Where a number of very small similar boilers exists at a facility, each
emitting five tons per year or less of any pollutant and each discharg-
ing through separate similar stacks, they may be combined as a single
source on one coding form.
6.
When combining boilers as in (a) or (b), the boiler capacity shown in col-
umns 18 through 22, card 3,is the sum of capacities of the combined boilers.
The fuel use entered in columns 26 through 32, card 6, must be totals of
each fuel used in the combined boilers. Appropriate comments in columns
51 through 70, card 6, must show the number and typical boiler capacity of
the boilers which have been combined. Boilers having emissions controls
are not to be combined with boilers not having controls.
When several similar boilers emit through several stacks with the number of
stacks not equal to the number of boilers, retain the actual stack data and
apportion the boilers so total capacity and emissions are proportionally
distributed among stacks.
7.
If a plant or facility has several emitting sources (i.e., boilers, pro-
cesses, incineration) and the sum of emissions from all sources within the
facility qualifies it as a point source as defined in 4.1, then these emit-
ting sources are to be coded on coding forms.
Boiler, process, and solid waste source data for a facility should be
entered on separate coding forms. Combustion data other than boiler (desig-
nated C in space 71, card 6) are to be entered with process data on the same
coding form only when the combustion is an integral part of the process and
the exhaust gases are commingled in the process.
8.
9.
Solvent,
handling
reported
hydrocarbon, fuel, and other organic vapor losses
operations in a facility are emissions and are to
on one or more source coding forms.
from storage 'and
be appropriately
10.
The following identification parameters must be filled on every point source
form:
Parameter
Card Columns
State
County
AQCR
Plant
1 - 2
3 - 6
7 - 9
10 - 13
ID Number
-------
Parameter
Card Columns
Poi nt ID
SCC
14 - 15
18 - 25
Each of the above defined card columns must be filled out.
no blanks.
There may be
Detailed instructions are given below for completing each card in the coding
form. It should be noted that special coding lists are required when "numerical
code" or "alphabetical code" appears in the column headed "Symbol."
4.3 IDENTIFICATION AND LOCATION OF POINT SOURCES
Card 1 - General Facility Identification
Spaces Format Symbo ~ Des~~iptio~ Unit
1-2 XX Numerical Code State Coding Number :-
3-6 XXXX Numerical Code County Coding Number \.
7-9 XXX Numerical Code AQCR Number
10-13 XXX X Numerical Code Source Number Within the
County'
14-17 XXXX Numerical Code City Coding Number
18-19 XX Numerical Code UTM Zone Number
20-21 XX Numerical Code Year of Record
22-61 A-A Alphabetical and Name and Address of
Numerical Establishment
62-73 A-A Alphabetical Person to Contact about
Pollution Control
74 A Alphabetical Ownership of Facility
1. State Coding Number: Identification coding lists are tabulated in the
Geographical Identification Code, Appendix A, Section 1. These codings'
are compatible with the SAROAD air quality numbering system.
County codes to be used are listed in the SAROAD Station Coding Manual for
~~rome~ric Sampling Networks, Publication No. APTD-0907 of the Environ-
mental Protection Agency.'
3. AQCR Number: Numbers for the Air Quality Control Regions are specified in
the Geographical Identification Code, Appendix A, Section 1.
2.
4.
Source Number: This field identifies each point source in a county. The
numbering system is sequential, starting with the number one and continuing
until all facilities containing point sources that are located in a given
23
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24
county are assigned a number. It should be noted that each plant, facility,
or establishment containing one or more emission points (e.g., stacks) will
be assigned a unique identification number within the county.
5.
City Coding Number: It is advantageous to identify those point sources
that are within cities, towns, or urban areas. If the source is within
the geographical boundaries of any of the cities listed in the SAROAD Sta-
t.i~.!1- Codi ng Ma~u~J .for Aerometri c Sampl i ng Netwo!~~, 1 enter the four-di gi t
code number corresponding to that city. There are a few cities in the
United States that are not considered to be inside any county but,'rather, ,
are considered independent entities. In such cases, enter the city code
in both "city" and "county" coding columns. Do not enter a town or city
code if the facility is situated outside the boundary of the city of address.
6.
UTM Zone Number: The zone number must be known in order to locate the
point source via the UTM coordinate system; this number is found on all
USGS maps showing UTM coordinates. Although most states are within a
single UTM zone, a few states and counties are in two UTM zones. For this
reason a UTM zone number is required for each coding form.
7.
Year of Record: ,The last two digits of the calendar year that the data
on card 1 represent must be recorded here.
8.
Establishment Name and Address: 'This field will, in most cases, provide
a descriptive name for the facility and a usable mailing address. It is
important to leave blank spaces between words to ensure readable entries.
Common abbreviations, such as AM for American, CO for company, BROS for
brothers, and INC for incorporated, should be used as much as possible.
The address ~hould include a street number, city, and, preferably, a zip
code. The state name is unnecessary. Again, abbreviate when possible to
conserve space and to allow room for an intelligible and usable address;'
abbreviate the city's name if necessary. Record the physical location of
the source if possibl e, 'rather than the name and address of a distant
headquarters. If there is no official proper name for the source, then
record a descriptive name and usable address, such as CITY DUMP NR 3, ENGR
DEPT, CITY HALL.
9.
Person to Contact about Pollution Control: The last name of the person
responsible for pollution control activity at the source should be re-
corded in this field. If the responsible individual is not identifiable,
then record a descriptive and appropriate title such as PLANT MGR. Leave
blank spaces between names and initials.
-------
10.
Ownership of Facility:
this column:
The following code list should be used to complete
Sy~bo 1
P
Ownershi~
Private
L
S
Local government
F
State government
Federal Government
U
Utility (electric power plants, etc.)
11.
When there are multiple stacks or point sources at a facility, complete
spaces 14 through 74 on card 1 on only the firi1 point source coding form;
all other point source coding forms relating to additional points within
the plant have these spaces blank for card 1.
4.4 STACK PARAMETERS
Cards 2 through 6 on the coding form relate to separate emission points that
are located within the facility (identified on card 1). For example, a facility or
plant as previously defined could have more than one emission point within its
boundaries. One coding form must be completed for each of these locations within the
facility. For example. if there are two separate smokestacks within a power-plant
complex, then complete two coding forms and include: (1) the same facility identi-
fication number and data on card 1, and (2) different emission point identification
numbers (referring to the individual smokestacks) on cards 2 through 6 of each form.
Occasionally, a qualitative judgment must be made when the distinction between
emitting point sources within the facility is vague. Common ~ense should then dic-
tate whether the sources should be reported separately on the coding form or com-
bined into a single, apparent point source. For example, if a single drying kiln
has a multitude of vents to the atmosphere from the same process, then combining
these vents into a single one for reporting purposes would be acceptable. If the
same stack or control equipment is used for two different processes that operate
seasonally or consecutively during the year, then consider this particular facility
to have two separate emission points and complete two coding forms.
Card 2 - Stack Parameters
--.----..---- ----. -----
Spaces Format Symbol Description Unit
---~._- -----_.- '---."'-
14-15 XX Numerical Emission Point Identifi-
cation Number
25
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26
Card 2 (conti~~_~_L:_Stack Pa_~~ete!:~
Spa~~ Format _Slmbo 1 ~escri pti on Unit
16- 17 XX Numerical Year of Record
18-21 XXXX Numerical Code SIC Code
22-23 XX Numerical Code Process Code
24-27 XXX.X Numerical UTM Hori zonta 1 Coordinates km
28-32 XXXX.X Numerical UTM Vertical Coordinates km
33-36 XXXX Numerical Stack Height ft
37-39 XX.X Numerical Stack Equivalent Diameter ft
40-43 XXXX Numerical Stack Temperature of
44-50 XXXXXXX Numerical Stack Exhaust Flow Rate ft3/mi n
51-54 XXXX Numerical Plume Height ft
56-59 XXXX Numerical Points with Common Stack
1.
Emission Point Identification Number: - This is a sequential number -desig-
nated for each pollutant discharge point within the facility. One coding
form will be completed for every point source within the facility.
Year of Record: The last two digits of the year that the data on card 2
represent must be entered here. This field will be automatically up- -
dated whenever information on the card is added, changed, or deleted.
2.
3.
- -
SIC Code: This information is necessary to use the source data for model-
ing air qua,lity. Enter the appropriate Standard Industrial Classification
code (SIC code). 2 -, .
4.
Process Code: This field should be completed only when a process code for,
the activity has been listed in Appendix A, Section -4. The IPP proces,? code
for ~ombustjon is to identify the manner of coal firing in boilers (for
- -
codes other than 00). If ,coal is used part of the time or entirely, the,
code will be other than 00.
5.
UTM Horizontal and Vertical Coordinates: The UTM coordinate system is
another means of identifying the location of the point source. Coordinates,
are obtained from USGS maps or their equivalent with scales less than
1 :62,500. All spaces in these columns must be filled in with numbers and'
zeros if coordinates are available to an accuracy of 1 kilometer (0.1-
kilometer accuracy is desired); otherwise, leave the columns blank.
Stack Height: In the majority of cases, the exact location of the dis-
charge of pollutants will be well defined; there will be a stack or some
other enclosed, constrained, or physically-bounded area where pollutants
are emitted. In such instances, the stack height is the vertical distance
6.
-------
between the point of emission and ground level.
height must be made, that value will be rounded
entered on the form. There are, however, point
more of the following characteristics:
If an estimate of stack
to the nearest 10 feet and
sources that have one or
a.
No clear-cut or enclosed point of emission.
b.
No stack height (e.g., burning dumps).
A changing locus of emissions within the facility (i .e., leaking valves
at an oil refinery, dust from moving equipment in a quarry).
c.
In such cases, the stack height, temperature, and flow rate columns
coding form will be marked with zeros, and columns 51 through 54 on
will be completed.
on the
card 2
7.
Stack Diameter: The stack diameter is the inside diameter of a round gas
exit at the point of emission; for non-round exits, it is an equivalent
diameter calculated from the cross-sectional area at point of discharge.
Using a measured or estimated cross-sectional area, the equivalent diameter
(De) is calculated as follows:
De .. 1. 128 IA
where A is in square feet. For another common occurrence--the rectangular
stack exit--the stack diameter must be calculated from the total cross-
sectional area; it cannot be assumed to be one of the linear dimensions.
When combining several similar boilers which emit pollutants through sepa-
rate stacks, the following procedure will be used to determine the actual
stack parameters. Calculate Ki for each individual stack using the follow-
ing equation:
K. = (H.)(V.)(T .)/Q.
1 1 1 S1 1
where Hi
V.
1
Tsi
Q.
1
stack height (ft)
gas flow rate (ft3/min)
stack temperature (OF)
emission rate of any common
pollutant (T/yr).
= individual
= individual
= individual
= individual
Select the stack with the lowest Ki value, and enter this stack height,
diameter, temperature, and flow rate on the coding form in the appropriate
fields. Also include in the "Comments" section the total number of boilers
and the total number of stacks combined. If two or more sources are served
by a common stack, enter the actual diameter of the stack in spaces 37
through 39, card 2, on each point source coding form.
27
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8.
Stack Temperature: The temperature of the exhaust stream at the stack exit
should be reported in degrees Fahrenheit under normal operating conditions.
If measured temperatures are not available, an estimate to the nearest 50° F
should be made. If no fuel combustion is involved in the process, and if
the exhaust gas appears to be discharged at ambient air temperatures, then
record the stack gas temperature as 77° F unless a more valid assumption is
apparent. If plume height is entered for a source, enter 77 of for cases
without combustion and estimate the temperature for cases with combustion.
9.
Stack Exhaust Flow Rate: This number should be specified by recording the
design or maximum exhaust-gas volume unless actual measurements are avail-
able. Units are actual cubic feet per minute and represent the total
volume of exhaust gas released at the operating temperature of the stack
(assume gas pressure is the same as normal atmospheric pressure). When two
or more boilers discharge into a common stack and each boiler is coded on a
separate form, the exit-gas flow rate corresponding to each boiler is entered
on the coding form.
10.
Plume Height: This field is to be filled in if the previous spaces on
stack data (except temperature) all contain zeros. Conversely, if stack
height, diameter, temperature, and flow rate were reported, then this
field should contain a zero. The plume height is a gross estimate and is
used only when the source has one of the following characteristics:
a.
No clear-cut enclosed point of emission (e.g., gas leaks at an oil
refinery).
No stack height (e.g., burning dumps).
b.
c.
A mobile emission point within the facility (e.g., quarry).
Pollutants released into the atmosphere at ambient temperatures through
diffusion (e.g., gasoline storage tanks).
d.
Many point sources have no true stack release points (whereby the gases are
forcibly exhausted to the atmosphere from an enclosed area). In such cases columns
51 through 54 must be completed. If there is a physically definable height above
ground level where the pollutants are discharged, then enter this value (in feet) in
the spaces. Examples of this class are gasoline storage tanks and uncontrolled
grain-drying operations where the height of the tank or dryer would be considered
the plume height. On the other hand, some sources, such as some quarries, burning
dumps, and gas leaks at ground level at an oil refinery, have no discernible emission
height. In such cases enter zeros in this field. Processes that discharge emissions
at ambient temperatures mainly through ground-level leakage or diffusion should also
28
-------
be considered to have a zero plume height. In such cases the exhaust flow rate
entered in columns 44 through 50 will also be zero. Ground-level emissions which
are coded zero plume height should have an appropriate temperature entered in columns
40 through 43. Conical refuse burners must have stack data entered on the coding
form.
11.
Spaces 56 through 59 on card 2 are to be completed whenever the exit gases
from multiple point sources are discharged through a single stack. When
this situation occurs. all point sources discharging into the single common
stack must be numbered sequentially. Numbers in spaces 56 through 59
should be entered as if the following sentence were to be completed: "Emis-
sions from point sources (56 through 57) through (58 through 59) in this
facility are discharged through one single and common stack." All entries
must be numerical and the 1D number of the point source must be one of
those multiple sources discharging through the common stack. For example.
if a facility has 5 point sources and point sources 3. 4. and 5 discharge
into a single stack. then coding forms for points 3. 4. and 5 would have
identical entries in columns 56 through 59 on card 2 of all coding forms.
whereas zeros would be entered in spaces 56 through 59 on those coding
forms for point sources 1 and 2.
4.5 CONTROL EQUIPMENT IDENTifiCATION CODE
Card 3 contains data on the installed air pollution control equipment at the
point source and on the corresponding pollutant removal efficiency of that equipment.
Data correspond to the point source identified on card 2 of the coding form.'
1.
Year of Record: The last two digits of the calendar year that the data on
card 3 represent should be entered here.
Boiler Design Capacity: A boiler will be defined as consisting of a burner.
firebox. heat exchanger. and a means of creating and directing a flow of
gases through the unit. The boiler design capacity. which is defined as
the boiler input capacity before heat transfer. will be entered here.
Otherwise. enter a zero in the column to depict nonapplicability. Units
are in millions of Btu per hour based on the maximum capacity or design of
the boiler.
2.
3.
Pollutant Control Equipment: Primary and secondary control equipment for
each of the five common pollutants is reported in these columns:
a.
Primary Control Equipment: Any installed equipment or device that is
located at the point source and whose main purpose is reducing emissions
of a pOllutant must be reported as a primary control device for that pol-
29
-------
Card 3 - Control Equipment
Spaces Fonnat Symbol Description Units
16-17 XX Numeri ca 1 Year of Record
18-22 XXXXX Numerical Boiler Design Capacity 106 Btu/hr
23-25 XXX Numerical Primary Particulate
Code Control Equipment Code
26-28 XXX Numerical Secondary Particulate
Code Control Equipment Code
29-31 XXX Numeri ca 1 Primary SOx Control
Code Equipment Code
32-34 XXX Numerical Secondary SOx Control
Code Equipment Code
35-37 XXX Numerical Primary N°f Control
Code Equipment ode
38-40 XXX Numerical Secondary NO~ Control
Code Equi pment Co e
41-43 XXX Numerical Primary Hydrocarbon
Code Control Equipment Code
44-46 XXX Numerical Secondary Hydrocarbon
Code Control Equipment Code
47-49 XXX Numeri ca 1 Primary CO Control
Code Equipment Code
50-52 XXX Numercial Secondary CO Control
Code Equipment Code
53-55 XX.X Numerical Estimat~d Control %
Efficiency, Particulates
56-58 XX.X Numerical Estimated Control %
Efficiency, SOx
59-61 XX.X Numerical Estimated Control %
Efficiency, NOx
62-64 XX. X Numerical Estimated Control %
Efficiency, Hydrocarbon
65-67 XX.X Numerical Estimated Control %
Efficiency, CO
30
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lutant using only those coding values tabulated in Control Equipment
Identification Code, Appendix A, Section 3. In cases where the effi-
ciency range of the device is unknown or where none of the equipment
codes appear to be applicable, choose the device that most nearly
resembles the actual equipment and include a comment on card 6. Only
control devices that reduce the uncontrolled emissions normally asso-
ciated with the process should be reported. 00 not report equipment
that is a normal part of the source activity even though the quantity
of the pollutants emitted may be reduced. For example, the recovery
system for coke by-product gases of a coke oven should not be reported
as pollution control equipment for hydrocarbons. If there are no con-
trol devices actually installed at the source, enter a zero in each
column; if the status of the source is unknown, leave the columns blank.
b.
Secondary Control Equipment: Secondary control equipment shall mean
(1) any equipment following in series another piece of control equipment
designed to remove the same pollutant, or (2) a control device designed
for one pollutant that affects the removal of another pollutant. When
a piece of equipment incidentally removes pollutants other than those
for which it was normally intended, the code should be entered in the
secondary control field on the NEOS form under the pollutant which it
incidentally removes. When the above situation occurs, the control
device would be entered in the secondary control field with zeros in
the primary control field. If no secondary control devices are
installed, enter a zero in each column. Engineering judgment must be
used to ascertain whether a given control device significantly reduces
the emissions of more than one pollutant.
Estimated Control Efficiency: The overall collection efficiencies in
weight percent of all control equipment at the point source should be
entered for each of the five pollutants. Assume that the pOllutant load
entering the control equipment is the normal, uncontrolled quantity for
that specific process. If removal efficiency for a particular pollutant is
unknown, leave that space blank; if there is no effective removal, then
enter zeros in this field.
4.
4.6 OPERATING INFORMATION AND EMISSION ESTIMATES
Card 4 contains data on the operating schedule of the source as well as the
estimated annual emissions from that source. This information is required to deter-
mine the release of pollutants on a seasonal, monthly, or time-of-week basis. Such
data are valuable to an enforcement agency in properly selecting an effective air
pollution control strategy.
31
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Card 4 - Emission Estimates
------ -- ..-----
Spaces Format Symbol Des~ri ~~E~ Units
16-17 XX Numerical Year of Record
18-19 XX Numerical Percent of Annual %
Throughput (Dec., Jan.,
Feb.)
20-21 XX Numerical Percent of Annual %
Throughput (Mar.,
Apr., May)
22-23 XX Numerical Percent of Annual %
Throughput (June,
July, Aug.)
24-25 XX Numerical Percent of Annual %
Throughput (Sept.,
Oct., Nov.)
26-27 XX Numerical ,Normal Operating hr
Hours per Day
28 X Numerical Normal Operating da
Days per Week
29-30 XX Numerical Normal Operating wk
Weeks per Year
31-37 XXXXXXX Numerical Emissions Estimate - T/yr
Particulate
38-44 XXXXXXX Numerical Emissions Estimate - SOx T/yr
45-51 XXXXXXX Numerical Emissions Estimate - NO T/yr
x
52-58 XXXXXXX Numerical Emissions Estimate - T/yr
Hydrocarbons
59-65 XXXXXXX Numerical Emissions Estimate - CO T/yr
66 X Numerical Method of Estimating
Coding Particulate Emissions
67 X Numerical Method of Estimating
Coding SOx Emissions
68 X Numerical Method of Estimating
Coding NOx Emissions
69 X Numerical Method of Estimating
Coding Hydrocarbon Emissions
70 X Numerical Method of Estimating
Coding CO Emissions
71-73 XX.X Numerical Portion of Fuel Used %
for Space Heat
32
-------
1.
Year of Record: The last two digits of the calendar year that the data on
card 4 represent should be entered here.
Percent of Annual Throughput: The annual production, consumption, through-
put, or other valid number representing the operating of the source should
be proportionally divided into the four 3-month categories shown on the
coding form. The weighted portion of production occurring in each category
is reported as a percentage of the total annual throughput. For example,
if a boiler operates only during the months of December, January, and
February, then 99 percent would be entered in the appropriate columns.
2.
3. Normal Operating Time: The hours per day, days per week, and weeks per
year that the source operates under normal and usual conditions should be
entered here. It should be emphasized that this field refers to activity
of the point source, not of the entire facility. For example, aD industrial
boiler in a plant may be operating 7 days a week even though the plant may
be shut down on Saturdays and Sundays. In this case, the number 7 should be
entered in the appropriate space for days per week. If the source is opera-
ting at more than 25 percent of its normal rate, consider the source to be
fully operating during that time period. If production is less than 25 per-
cent of the normal rate, consider the source as not operating during that
time period.
4.
Emission Estimates: The annual, controlled emissions from the point source,
in tons per year, should be entered here. These calculations should include
the effect of pollutant removal by installed control equipment.
5. Method of Estimating Emissions: The following code list must be used to
specify the method used to ascertain the emissions reported in columns 66
through 70:
Code Description of Estimation Method
o Not applicable. Emissions are known to be zero.
1 Emissions based on source testing or other emission measurements.
2 Emissions based on material balance using engineering expertise and
knowledge of process.
3 Emissions computer-calculated using emission factors in accompanying. .
SCC listing. No emission estimates need be coded on NEDS form. '
- I
,
~
33
-------
4
5
6
7
Guess.
Emissions calculated using a special emission factor differing from
that in the see listing.
New construction. not yet operational. Zero emissions are estimated.
Facility c1osed. operations ceased. Zero emissions are estimated.
If the coder knows that a certain emission factor (including any from
AP-42 possibly differing from that given in the see listing) will yield
a better emission estimate for a specific source than that which re-
sults from applying the factor given in the accompanying see listing,
he should use the non-See factor to calculate an emission estimate,
enter this estimate into the appropriate pollutant field on card 4 of
the NEDS point source form, and enter the number 5 in the appropriate
estimation method field. If, on the other hand, the coder does not
know that any other emission factor is better than that given in the
see listing, he should leave the appropriate emission estimate field
blank on card 4 and enter the number 3 in the appropriate estimation
method field. When this is done, the computer will automatically cal-
culate emission estimates for the source using emission factors in the
see listing.
6.
Portion of Fuel Used for Space Heating: An estimate of the percent of to-
tal fuel used for space heating at the plant should be entered here. If no
fuel is used for space heating, enter zeros in this field.
4.7 COMPLIANCE ANALYSIS
Allowable emissions and compliance schedules for the source are recorded on
card 5. All entries are to reflect the current legal requirements of the source to
comply with the most stringent air pollution control regulations in effect.
1.
Year of Record: The last two digits of the calendar year that the data on
card 5 represent should be entered here.
2. Allowable Emissions: Entered here should be the maximum emissions of each
pollutant, in tons per year, that the source is legally allowed to discharge
into the atmosphere under the most stringent of the following conditions:
a. Existing local, state, or Federal regulation.
b.
Imminent legislation that will legally require the source to comply
to a certain discharge limitation within the year of record specified
in columns 16 and 17.
34
-------
c. Official agreements with air pollution control regulatory agencies
whereby the source must reduce emissions to a given quantity per year
within the year of record specified in columns 16 and 17.
Allowable emissions should be calculated in the same manner as intended by
the most stringent laws affecting the source. For example, if allowable
emissions are 5 pounds S02 per ton of daily production, then an average
annual production should be estimated and multiplied by the 5 pounds S02
factor to calculate the annual quantity of S02 allowed to be emitted to
the atmosphere. If allowable emissions are unknown, leave the spaces
b1 ank.
3.
Source-Compliance Status: Air pollution control enforcement agencies often
allow sources of air pollution an extended, but definite, period of time to
design and install air pollution control equipment. This act of leniency
is referred to as a "variance;" if the source succeeds in reducing its
emissions by the required date, then the law has been satisfied and the
source has met its pollution control obligation. One of the following
codes must be selected to record the present status of the source under
existing legal requirements.
Code
2
Description
Source is in compliance with the most stringent
air pollution control requirements.
Source is not in compliance with existing
legislation and ~ variance has been given.
(Complete columns 54 through 57 on card 5.)
Source is not in compliance with existing
legislation but a variance has been given.
(Complete columns 54 through 57 on card 5.)
Compliance status is unknown.
3
4
Card 5 - Compliance Analysis
Spaces
Format
Symbol
Description
Year of Record
Units
16-17
xx
Numerical
35
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Spaces
18-24
25-31
32-38
39-45
46-52
53
54-55
56-57
58-59
60-61
62-63
64
65-68
69-72
73-76
Format
xxxxxxx
xxxxxxx
xxxxxxx
xxxxxxx
xxxxxxx
xxxx
xxxx
Symbol
Numeri ca 1
Numerical
Numerical
Numerical
Numerical
x
Numerical
Coding
Description
Allowable Emissions -
Parti culate
Allowable Emissions -
SOx
Allowable Emissions -
NOx
Allowable Emissions -
Hydrocarbons
Allowable Emissions -
CO
Source Compliance Status
Year Source Must Be in
Compliance (complete only
if compliance status = 2,3)
Month Source Must Be in
Compliance (complete only
if compliance status = 2,3)
Year of Compliance Status
Update
Month of Compliance Status
Update
Day of Compliance Status
Update
Emergency Control Action
Program (ECAP) Status
Control Regulation No.1
Control Regulation No.2
Control Regulation No.3
Units
T/yr
T/yr
T/yr
T/yr
T/yr
Numerical
Code
Year and Month Source Must be in CO~lpliance: These columns should b,e com-
pleted only when code 2 or code 3 is entered in column 53. If codes 1 or
4.
36
xxxx
xx
Numerical
xx
Numerical
xx
Numerical
xx
Numerical
xx
Numerical
x
Numerical
Code
Numerical
Code
Numerical
Code
-------
4 are entered in column 53. then these spaces should be left blank.
5. Time of Compliance Update; The day. month. and year of the most recent
change in compliance status for the source should be entered in these
columns. Leave spaces blank if compliance status has been reported as un-
known. If the source is in compliance with existing air pollution control
legislation. then record the time that such legislation was enacted.
6.
Emergency Control Action Program (ECAP); Certain point sources are re-
quired to submit to government agencies an ECAP that specifies a detailed
plan for immediately reducing emissions whenever air pollution in an area
is considered an emergency condition. The following list shall be used to
denote whether or not an ECAP has been submitted to an appropriate govern-
ment agency. Leave blank if status is unknown.
Code
o
1
2
Description
ECAP is not required.
ECAP is required but has
ECAP has been submitted.
not been submitted.
7.
Control Regulations: Spaces 65 through 76 are used to identify air pollu-
tion control regulations that are in effect and apply to the source. This
information will augment the Comprehensive Data System (CDS). developed by
Division of Stationary Source Enforcement and will be included in the
Variable Data Subsystem (VDS) of NEDS.
4.8 FUEL, PROCESS, OR SOllD.WASTE INFORMATION
The operating characteristics of the source are defined on card 6. Because
there may be many functionally separate processes that discharge exhaust gases into
the same stack. a standard procedure was developed to report and retain such data.
The instructions that apply to this procedure are as follows: (1) Cards 2 through
5 on the coding form contain data pertinent to an individual point of emission within
the facility that can be geographically separated from other emission pointsi and
(2) There are five cards 6 on each coding form to record up to five separate pro-
cesses that may be contributing to the exhaust gases discharged from a particular
emission source. To report two or more units on one coding form where exhaust gases
37
-------
from two or more driers are discharged into a single stack, the units must have the
same SCC. One card 6 would be completed showing the SCC, the combined annual opera-
ting rate, the combined maximum design rate, and the number of combined units in
"Comments." If the combustion gases for the driers are discharged into the same
stack, additional cards 6 must be completed for each type of fuel. Similarly, if
one boiler uses coal, fuel oil, and natural gas as fuel, then three of the five cards
6 should be completed.
1.
Year of Record: The last two digits of the calendar year that the data on
card 6 represent should be entered here.
Source Classification Code (SCC): The SCC process description in the
Source Classification Code, Appendix A, Section 2, that most nearly des-
cribes the process should be entered by its eight-digit numerical code.
Note that multiple cards 6 are to be completed only if the SCC codes are not
identical. If the most appropriate SCC description appears to be signifi-
cantly different from the actual process, use SCC codes ending in 9999999,
99999, or 99 and include a brief, intelligible description of the process
and the rate units in the "Corrunents" section. Use only the "Comments" field
available on the card.
2.
Card 6 - Fuel, Process, and Solid-Waste Data'
Spaces Format Symbol Description Units
16-17 XX Numerical Year of Record
18-25 xxx XXX XX Numerical Source Classification
Code Code (SCC)
26-32 XXXXXXX Numerical Annual Charging Rate of (SCC)*/yr
Code Fuel Process or Solid
Waste
33-39 XXXX.XXX Numeri ca 1 Maximum Hourly Design (SCC)*/hr
Code Rate
40-42 X.XX Numerical Sulfur Content %
43-45 XX.X Numerical Ash Content %
38
-------
Spaces Format Symbol Description Units
46-50 XXXXX Numerical Heat Content, Mi 11 ions (SCe)*
Code of Btu
51-70 A-A Alphabetical Convnents
71 A Alphabetical Source Code
72 X Numerical Confidentiality of
Data
* Note:
Each of the code columns above that specify a numerical code symbol
requires reference to and use of the Source Classification Code
(seC), Appendix A, Section 2.
3. Annual Charging Rate of Fuel, Process, or Solid Waste: The units in which
the charging rates must be expressed are listed for each SCC in Appendix A,
Section 2. The average annual operating rates will be reported and entered
in the columns in those units given in Appendix A that correspond to the
appropriate sce of the process. Thus, for coal combustion, the process
rate is expressed in tons of coal burned per year, whereas, when oil is
burned, the units are thousands of gallons burned per year.
4. Maximum Hourly Design Rate: The maximum hourly design rate of the most
tmpcrtant process equipment, or the upper operating limit that generally
would not be exceeded in normal practice, should be entered here. Units are
expressed in those corresponding to the SCC for the process. The maxi~um
hourly design rate for boilers will be calculated by dividing the fuel heat
content into the boiler design capacity. (Note that design quantities are
expressed in hourly operating rates, and that a decimal point is positioned
in this field. Location of the decimal point is based on the relationship
of hourly capacity to annual process rate contained in the previous field.)
5. Sulfur and Ash Contents: Entries are to be made in these columns for all
combustion processes. If the process does not burn fuel, then enter zeros
in columns 42 and 45. Leave spaces blank if the process uses combustion
but the sulfur or ash contents of the fuel are unknown. Enter zeros to
denote nonapplicability for solid waste processes unless the waste has high'
or unusual sulfur content.
39
-------
40
6.
Heat Content: This field is to be completed only when the process involves
combustion. If the process does not involve combustion, enter a zero in
column 50 to denote nonapplicability. Enter zero for all. solid waste
processes. Units are millions of Btu per SCC. Thus, for natural gas
combustion the number entered ,would be as fo1.lows: (103 ~tu/cubic foot)
(106 cubic feet/SCC) / 106 = 1000.
Comments: The operating characteristics of most sources are defined by a
single SCC and associated data on one card 6; therefore, only the "Comments"
field (columns 51 through 70) of tne one card 6 is available for recording
comments. Comments may not be entered on a non-existent card 6, one which
has no Source Classification Code. Comments must relate to the correspond-
. .
ing SCC. When the SCC is general (e.g., ending in 99), a description of
the process and rate units must be reported. . Abbreviated comments m~st be
i~telligible. Useful notes pertaining to the source may be written. on the
back qf the. coding form.
7.
8.
Source Code:
6. is useful.
column:
A quick visual check of,the process category reported on card
.Use the following list and enter the appropriate code in this
Code
Description of Source
B
P
C
S
Boil er
Process'
Other combustion unit
Solid waste
9.
Confidentiality of Data: Process information occasionally is collected by
a government ..agency under a guarantee that the data wi.ll be treated in a
. confidential manner and will not be released to the public. This column
specifies whether or not any data on cards 2 through 6 are officially
considered confidential. Use the fo1.lowing list to select the appropri-
ate code number. Leave the space blank if confidentiality status is un-
known.
Code
Description
Some data on cards 2 through 6 are confioential.
-------
2
No information on the coding form is confiden-
ti a 1 .
4.9 SUPPLEMENTARY INSTRUCTIONS
1. The NEDS point source coding form may not be changed. Data other than those
described by field headings may not be entered in those fields. The columns
on the coding form which have no heading must be left blank.
2.
Rules for entering codes and data in the point source form:
a. The following parameters are defined as both numeric and alphabetic:
Parameter
Card Columns
Card 1
Establishment name
Contact - personal
Ca rd 5
Control
Control
Control
Ca rd 6
Comments
and address
22 - 61
62 - 73
Regulation 1
Regulation 2
Regulation 3
65 - 68
69 - 72
73 - 76
51 - 70
Any of the above defined card columns may be filled out or left blank.
Embedded and leading blanks are allowed.
b. All parameters and card columns not covered in the above paragraph or
in section 4.2.10 are defined as numeric only. For each of these para-
meters all blanks or leading blanks are allowable; embedded blanks are
not. Each is right-justified. The following examples should clarify
these rules.
41
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42
Maximum design rate
33 34 35 36 37 38 39
All blanks Allowed
Leading blanks 0 Allowed
Leading blanks 2 4 0 1 Allowed
Embedded blanks 0 Not allowed
Embedded blanks 0 4 2 Not allowed
3. A source within a facility that has uncontrolled emissions of less than 1
ton per year of any pollutant, and that cannot be combined with like small
sources normally will not be reported on a coding form.
4.
Combining like process units: If a facility has a number of identical pro-
cess units each of which has a low level of emissions, the units should be
combined into one effective source reported on one coding form. If the
units have separate stacks, stack data for one typical stack should be
entered on the form and the number of stacks should be reported in comments.
Stack data coding:
a. Where two or more sources discharge into a common stack and each source
is coded on a separate coding form, enter the actual stack height,
diameter, and temperature on each coding form. Enter only the exhaust-
gas flow discharged by the single source (boiler or process) described
by the coding form.
5.
b.
Where two or more like sources that would have an identical SCC dis-
charge through separate but similar stacks are combined into one effec-
tive source, stack data (height, diameter, temperature, and flow) for
one typical stack is entered in the coding form. The number of combined
units is reported in the comments. Paragraph 4.4.7 describes a method
of selecting a typical stack by means of a formula.
6;
Boiler design capacity: These columns, 18 through 22, on card 3 are for
boilers exclusively. For other combustion units, enter a single zero in
column 22 to indicate not applicable.
-------
7.
It is very important to report the correct method of emissions estimation.
Emissions determined by stack tests are very valuable; therefore, the use
of code 1 to report stack" tests must be reliable.
Identical SCC's may not be entered on a source coding form.
8.
9. When a number of boilers or process units have been combined to make an
effective single source coded on one point source form, this must be re-
ported in comments by recording the number of combined units (e.g., 6
Blrs, 6 Stacks).
4.10 REFERENCES
1. SAROAD Station Coding Manual for Aerometric Sampling Networks. U.S. Environ-
mental Protection Agency, Office of Air Programs. OAP Publication No. APTD-0907.
Research Triangle Park, North Carolina. February 1972.
2. Standard Industrial Classification Manual. U.S. Bureau of the Budget, Office of
Statistical Standards. Washington, D.C. 1972.
43
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5.
AREA SOURCE CODING
5.1 IDENTIFICATION OF AREA SOURCE
This chapter presents techniques to be used both for estimating area source
quantities and for completing the area source coding form shown in Figure 5-1.
The chapter subsections devoted to each area source category include a brief des-
cription of the source category, discuss the data collection methods that are to be
used to obtain area source totals, and state how to fill out the area source coding
form and how to apportion the county totals to the proper source categories. Also,
general guidelines concerning the proper application of the methods are given.
An important point to remember is that an area source actually represents a
collection of many small sources. Each small source may emit only very small
quantities of air pollutants, but, because of the great number of small sources,
their collective impact may be very significant. The object of area source calcula-
tions is to obtain an accurate estimate of this collective contribution to total
emissions. Such an estimate can never be exact, however, because it would be
impossible to determine the emissions from every small source individually. For
instance, it would be impossible to monitor continuously every automobile in the
study area and determine the total emissions from automobile operation by adding
up the individual totals. Hence, the emissions from sources too small or too
difficult to be surveyed individually have to be reported collectively as "area
sources." In the area source format, each county or county equivalent (parish, .
census division, independent city, etc. for states where counties are not used) is
defined as the smallest region for which area sources are calculated. In areas where
detailed modeling of air quality data is desirable, the format will accommodate sub-
division of counties into UTM-based grid zones for processing. (County area source
totals can be apportioned to grid zones according to the procedures discussed in .
this chapter.)
5.2 COUNTY INFORMATION (COLUMNS 1 THROUGH 9 OF ALL CARDS; COLUMNS 10 AND 11 OF
CARD 1; AND COLUMNS 73 THROUGH 77 OF CARD 3)
Each area source is uniquely identified by a two-digit code identifying the
state, a four-digit code identifying the county, and a three-digit code identifying
the AQCR. The proper codes defined by the SAROAD systeml can be found from the Geo-
graphical Identification Code in Appendix A, Section 1 and in the SA ROAD Station
Coding Manual.l The year the data represent should be entered in spaces 10 and 11
of card 1. The county population and the population distribution code should be
45
-------
~
0'1
~
AREA SOURCE
Input Form
Date
_.,-
Cooiploti,. Fa
ElISSIOI ESTIlAT£S (JIll 118s)
cd
Anlll. Coal
101 Ions
2 26
VESSELS
Oiesel Oil Rnid. Oil
104 Gals. 104 Gal..
28 29 30 31 32 33 36
I
c
EPA IDURI 21'
1/72
Figure 5-1.
Area source coding form.
-------
entered in spaces 73 through 77 of card 3. The county population, to the nearest
thousand, must be determined from the 1970 Census of Population.2 This publication
also gives the urban-rural population breakdown. Using this information, the correct
population distribution code should be entered according to the designations below.
o
1
2
3
4
5
6
7
8
9
Population Breakdown
<10% urban
10 - 20% urban
20 - 30% urban
30 - 40% urban
40 - 50% urban
50 - 60% urban
60 - 70% urban
70 - 80% urban
80 - 90% urban
>90% urban
Population Distribution Code
5.3 EMISSION ESTIMATES (COLUMNS 12 THROUGH 35, CARD I)
The most recent emission estimates, in hundreds of tons per year, should be
entered. Such estimates should be obtained either from the state's implementation
plan emission inventory or from a more recent inventory, if available. Rounding off
emission totals to hundreds of tons does not sacrifice accuracy. Nearly every
county will have emissions of at least 100 tons of each of the five major pollutants.
A figure of 100 tons is also the smallest significant figure that can be reported
for emission totals. The units shown for each of the area source quantities on the
coding form are such that emissions can be reported down to the order of magnitude
of 1 ton. The precision of emission factors and the data to which these factors are
applied does not justify reporting countywide emissions of less than 100 tons.
5.4 FUEL DATA (COLUMNS 46 THROUGH 49, CARD I)
The percent sulfur and ash contents entered here are necessary for calculation
of sulfur oxide and particulate emissions from fuel combustion. The figures
entered should be weighted averages for the fuels consumed by area sources. For
instance, if the bituminous coal sulfur contents and fuel consumption totals are as
follows:
Residential: 1000 tons, 1.4 percent sulfur
Commercial-institutional: 500 tons, 1.6 percent sulfur
Industrial: 1500 tons, 2.0 percent sulfur
Then the weighted average sulfur content is calculated as follows:
1000 x 1.4 = 1400
500 x 1.6 = 800
1500 x 2.0 = 3000
3000
5200
47
-------
The average sulfur content = 5200 = 1.73 percent.
3000
Some areas have regulations limiting the sulfur content of fuels. If, for
instance, no bituminous coal with a sulfur content of more than 1.5 percent can be
burned, and if it is known that no significant amount of coal with a sulfur content
of less than 1.5 percent is burned, then the weighted average sulfur content for
bituminous coal can be assumed to be 1.5 percent. The figures entered on the form
must represent the fuel that is actually being used, however, and not the fuel that
is supposed to be used or that will be used at some time in the future. One set of
weighted-average fuel factors is assumed to be adequate for each fuel being used in
the county. The figures for each source category that may be found are also averaged
numbers. The main concern is to obtain one set of fuel factors that will permit
accurate countywide emission estimates to be calculated.
5.5 STATIONARY SOURCE FUEL CONSUMPTION (COLUMNS 50 THROUGH 77, CARD 1; AND
COLUMNS 10 THROUGH 77, CARD 2)
The quantity of fuel consumed by each source category must be ascertained. The
source categories are as follows:
Residential: This category includes all residential dwellings, from
single-family residences to multi-story apartment complexes.
2. Commercial-institutional: This category includes retail and wholesale
stores, schools, hospitals, government buildings, and other public
1.
bui ldings.
Industrial: This category includes all manufacturing industries with
emissions too small to qualify as point sources.
Collectively, the three categories above account for all the stationary fuel com-
bustion activities that are not usually reported as point sources. The breakdown
into source categories is necessary to show how each type of fuel combustion activity
contributes to the total air pollutant emissions. Such information is very useful
and often essential for the formulation of control strategies to achieve air quality
goals.
3.
The six major fuels and three generally less important fuels that may be con-
sumed by area sources are listed below.
5.5.1 Major Fuels
5.5.1.1 Anthracite Coa13 - Anthracite, or hard coal, is produced almost exclusively
in Pennsylvania and is available in significant quantities only in states that are
within easy shipping distance from Pennsylvania. Anthracite may be consumed by all
source categories, although most is used by residential sources.
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5.5.1.2 Bituminous Coa13 - Because production of bituminous coal is more widespread
than production of anthracite, the former is available in most areas of the country.
Also included as bituminous coal are the lower grades of sub-bituminous coal and
lignite. Bituminous coal is often favored for use by electric utilities, manufactur-
ing industries, and coke producers. Bituminous coal is used in some areas for resi-
dential and commercial-institutional heating.
5.5.1.3 Distillate Oi14 - Distillate oil includes fuel oil grades 1, 2, and 4. In
addition, diesel fuel and kerosene can be considered distillate-type oils. Nation-
wide, residential and commercial-institutional sources are the largest consumers of
distillate oil.
5.5.1.4 Residual Oi14 - Residual oil includes fuel oil grades 5 and 6.
areas residual oil is not used by residential sources, but significant
be consumed by industrial and commercial-institutional users.
5.5.1.5 Natural Gas5 -
other hydrocarbon gases
categories.
5.5.1.6 Wood - Wood may be used as heating fuel by residential sources (primarily
in rural areas where wood is readily available), by industrial sources, and by
commercial-institutional sources (usually in very small amounts). The chief
industrial users of wood as heating fuel are those wood-processing industries such
as sawmills, plywood mills, and furniture manufacturers that generate large amounts
of wood waste that can be consumed in boilers.
In most
amounts may
Natural gas, consisting principally of methane but containing
as well, is used in significant amounts by all source
5.5.2 Minor Fuels
5.5.2.1 Liquefied Petroleum Gas - Liquefied petroleum gas (LPG) consists of higher-
carbon-number hydrocarbons such as propane and butane.6 The contribution from LPG
combustion to total emissions is not significant in most areas. Where LPG use is
considerable, however, it should be recorded as "equivalent natural gas" according
to the procedure described later in this chapter. Should LPG use become more wide-
spread in the future, the format will be expanded by designating separate spaces or
adding new cards to accommodate LPG consumption. At present, it is not necessary
to report LPG use in many areas, however.
5.5.2.2 Coke - Coke is made by destructive distillation of coal to remove the
volatile components.3 Although primarily used by the iron and steel industry, some
coke may appear as an industrial area source fuel.
5.5.2.3 Process Gas - Process gas, or "sour gas" as it is sometimes termed, is
often used at petroleum and petro-chemical refining operations as well as at
natural gas production plants. Process gas, which is usually characterized by a
49
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high sulfur content and relatively low heat content, cannot be marketed commercially.
In addition, "coke gas," the gaseous product of destructive distillation of coal, has
some heating value and may be used industrially.
5.5.3 Estimating Area Source Fuel Consumption
Either of two methods can be used for estimating the quantity of fuel consumed
in an area.
5.5.3.1 Local Fuel Dealers Method - Most fuel retailers maintain sales records that
can be a valuable source of information for the determination of area source fuel
consumption. The information needed from fuel dealers concerns their annual sales
by county to each source category. The area source totals of residential and
commercial-institutional fuel consumption are then simply the fuel dealers' figures
minus any fuel consumed by point sources included in these source categories. Because
dealer sales to industrial users may not adequately represent the amount of fuel
consumed by industrial sources, the second method is primarily used for industrial
fuel determination. Any information gained from fuel dealers would be useful,
however.
It is important that all fuel dealers be contacted. The accuracy of the survey
results will be significantly reduced if some fuel dealers are overlooked. It may
be that not all fuel dealers will be able to furnish adequate information. In the
past, natural gas dealers have been best able to furnish the required data. Other
dealers either have been reluctant to release information, or simply have not had
the detailed breakdowns required. There is no assurance that fuel dealer sales
accurately represent fuel consumption, either. Sales of coal to industrial sources
or of wood to residential sources, for instance, may represent only a part of the
total fuel consumed, because much of the fuel consumed may not come from retail
dealers. The second method below should be used for those cases in which fuel
dealers cannot provide the detailed breakdowns of total fuel sales by county. It
should be emphasized, however, that information provided by dealers, although
perhaps incomplete, can provide insights into fuel use patterns that would not be
discovered by the second method.
5.5.3.2 Bureau of Mines Published Data Method - The Bureau of Mines of the U. S.
Department of the Interior publishes annual data on fuel sales and distribution.
The advantages to the use of this information are that the data are reported nation-
wide, are readily available because they are published, and are updated every year.
The drawback to the use of this material is that fuel data are reported by states
only, and often are not broken down into the desired source categories. County
totals must be estimated by apportioning state totals. This geographical
50
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apportioning step, which is not necessary for the fuel dealers method, decreases the
accuracy by which area source fuel totals can be determined. The geographical
apportioning techniques are discussed in the next section.
5.5.4 Apportioning Fuel Consumption
To complete the area source form. the county fuel consumption totals must be
assigned to the proper source categories. If fuel dealers furnish county totals by
source category, no problems are involved; but if only county sales totals can be
obtained from fuel dealers or if Bureau of Mines data must be used. then apportioning
techniques are required. Geographical apportioning techniques for use with Bureau
of Mines figures. and source category apportioning techniques for use with either
data collection method will be discussed.
5.5.4.1 Geographical Apportioning Techniques - Techniques for apportioning state
totals to counties are to be used for each source category. It should be noted that
these apportioning techniques are appropriate for use with area source fuel totals
only, and should not be used to apportion to counties the grand total amount of fuel
used in a state (which is the point source total plus the area source total). Fuel
used by point sources will be assigned to counties based on the grid coordinates of
the sources. It should be understood that when references are made in this chapter
to "state totals" or "county totals." these terms refer only to the total amount of
fuel consumed by area sources. Some of the coal data given by the Bureau of Mines
are reported for groups of states only.3 To separate the group total into individual
state totals. the group total should be distributed to states according to the same
method used to distribute a state total to counties.
5.5.4.1.1 Residential fuel use - State totals for residential fuel use can be
apportioned to counties by the number of dwelling units using each fuel per county.
Dwelling unit information is available from the 1970 Census of Housing7 and should
be applied according to the following formula:
County residential fuel total = State residential
fuel total County dwelling units
x State dwelling units
The county and state dwelling units above refer to the number of dwelling units using
each type of fuel for space heating. The Census of Housing reports the number of
dwelling units using each type 9f fuel in each county and in each state. The fuel
category "util i ty gas" refers to natural gas, and the category "bottled. tank. or
LP gas" is for LPG.
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5.5.4.1.2 Commercial and institutional fuel use - State
source category can best be apportioned to counties according
given in the 1970 Census of Population.2
County fuel total = State fuel total x County popula~ion
State populatlon
fuel totals for this
to population, as
5.5.4.1.3 Industrial fuel use - County industrial fuel totals
to the total number of manufacturing employees per county, as given
Census of Manufacturers, "Area Statistics."B
are proportional
in the 1967
County industrial fuel total = State industrial
County manufacturing emrloyees
fuel total x State manufacturing emp oyees
5.5.4.2 Source Category Apportioning Techniques - It is often necessary to
apportion state or county fuel totals to residential, commercial-institutional, and
industrial source categories. The prescribed methods for distributing each fuel
total to source categories are presented below.
5.5.4.2.1 Anthracite coal - State totals for major anthracite-consuming states
should be obtained from Minerals Yearbook3 or Distribution of Pennsylvania
Anthracite.9 Anthracite may be used by all three source categories. The stepwise
procedure for determining the use by each source category is presented below.
Step 1:
Determine the total area source consumption of anthracite by sub-
tracting the amount used by point sources from the state total given
by the Bureau of Mines.
Determine the residential consumption of anthracite (columns 50
through 53, card 1) according to the following method.10 The
residential anthracite consumption. is a product of four factors:
Step 2:
1. The number of dwelling units using coal as heating fuel.
2. The coal heating requirement factor.
3. The average annual heating degree-days.
4. The correction factor for the number of rooms per dwelling unit in
the study area.
The number of dwelling units heating with coal should be obtained from
the 1970 Census of Housing.7 The heating requirement factor for coal
is 0.0012 ton coal per dwelling unit per degree-day. The average
annual heating degree-days should be obtained from Local Climatological
Data.ll For a state, an average degree-day value compiled from all
the reporting stations in the state for the year of interest should be
used. For a county, the degree-day value given by the nearest re-
52
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Step 3:
.-
porting station should be used. For states in which there is not a
large variation in degree-days among different sections of the state,
it is acceptable to use one average degree-day total for the entire
state in order to compute the coal use in each county. The correction
factor is the average number of rooms per dwelling unit, as given in
the Census of Housing,? divided by 5--the national average for the
number of rooms per dwelling unit.
A sample calculation for State X would be as follows:
Number of dwelling units heating with coal = 10,000,
State average annual heating degree-days = 5,000,
State average rooms per dwelling unit = 4.5.
The residential use of anthracite coal is calculated:
State total
= (10,000 dwelling units)
(0.0012 ton coal/dwelling unit-degree-day) (5,000
degree-days) (4.5 rooms) = 54 000 tons coal/year.
5.0 rooms'
The commercial-institutional (columns 10 through 14, card 2) and the
industrial (columns 36 through 41, card 2) area source consumption of
anthracite can be determined as follows: Subtract the calculated
residential consumption figure from the anthracite area source total.
All of the remaining anthracite should be assigned to the commercial
and institutional category if no anthracite is consumed by industrial
point sources. Assign 60 percent of the remaining amount to
commercial and institutional sources and 40 percent to industrial
sources if anthracite is consumed by industrial point sources.3
5.5.4.2.2 Bituminous coal - State totals for bituminous coal should be obtained
from Minerals Yearbook3 or Coal-Bituminous and Lignite.12
Step 1:
The amount consumed by residential users (columns 54 through 58, card
l) must be determined. In some states anthracite coal is not
available.3. For these areas all of the residential coal consumption
should be considered bituminous coal, and the total consumption can be
calculated according to the same procedures given for anthracite coal.
For the states in which anthracite coal is available, estimates of the
number of dwelling units heating with anthracite and the number heating
with bituminous must be made. Local coal dealers may be able to state
what percent of their customers are sold anthracite, and what percent
53
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Step 2:
Step 3:
of their customers are sold bituminous. If not, all residential coal
may be assumed to be anthracite if a sufficient amount of anthracite is
available in the state. If the amount calculated for residential coal
use is less than the amount of anthracite coal shown for the state by
the Bureau of Mines, all residential coal use may be considered to be
anthracite. If the calculated amount for residential coal use is
greater than the Bureau of Mines total for that state, the difference
between the two figures should be considered as the amount of bitumi-
nous coal consumed by residential sources.
If the residential bituminous coal consumption is less than the Bureau
of Mines retail dealers bituminJJs coal figure for the state, assign
the difference to the commercial and institutioanl source category
(columns 15 through 19, card 2). If the residential bituminous coal
consumption is not less than the retail dealers figure, assume com-
mercial and institutional bituminous coal consumption to be negligible.
The state total for all industrial bituminous coal consumption is
assumed to be the Bureau of Mines figure for "all other. ,,3 The state
area source total is determined by subtracting the amount of bitumi-
nous coal consumed by industrial point sources from the state total for
all industrial bituminous coal consumption. Care should be taken to
ensure that coal used for industrial processes, such as for feed to
coke ovens, is not included in the state point source total. The
county area source totals should be entered in columns 42 through 47,
card 2.
5.5.4.2.3 Distillate oil - State totals for distillate oil consumption should
be determined from Mineral Indust.!'l__Surveys, "Sales of Fuel Oi 1 and Kerosene."4 ,
Step 1:
Step 2:
54
The amount consumed by residential sources (columns 59 through 63,
card 1) is estimated by using the number of dwelling units heating with
fuel oil and a heating requirement factor of 0.18 gallon oil per
dwelling unit per degree-day. The method has been described in detail
in the section on anthracite coal.
Commercial and institutional distillate oil consumption is the differ-
ence between residential consumption and the sum of the figures given
for "distillate-type heating oils," "kerosene used for heating," and
"distillate used by the military" from Tables 5, 6, and 12 of
Reference 4. Any distillate oil consumed by commercial and
institutional point sources should be subtracted before the area source
total is entered in columns 20 through 24, card 2.
-------
Step 3:
The state industrial area source use of distillate oil is the sum of
the figures given for "industrial" and "oil companies" in Tables 8
and 9 of Reference 4, minus the amount consumed by industrial point
sources. Enter the area source total in columns 52 through 56, card
2.
5.5.4.2.4 Residual oil - Use the same methods and reference as given for
distillate oil. Residential sources (columns 64 through 68, card 1) do not usually
consume residual oil. Local oil dealers should be contacted to determine what
percent of their residential customers, if any, were sold fuel oil grades 5 and 6.
The commercial and institutional area source consumption (columns 25 through 29,
card 2) can be determined from figures given in Tables 7 and 12 of Reference 4,
and industrial consumption can be determined from residual oil data in Tables 8 and
9 of the same publication. Remember to subtract residual oil consumption by the
point sources in each source category from the Bureau of Mines totals to obtain the
area source totals.
5.5.4.2.5 Natural gas - Distribution of natural gas by state is given in Table
6 of Reference 5. The proper source category totals are shown. The "commercia1-
institutional" category is the sum of "commercial" and "other users." Subtract
point source use of gas to obtain the area source totals. Enter residential con-
sumption in columns 69 through 73, card 1, commercial-institutional in columns
30 through 33, card 2, and industrial in columns 62 through 66, card 2.
5.5.4.2.6 LPG - In areas where large quantities of LPG are used, significant
air pollution emissions can result. LPG can be converted to "equivalent natural
gas" on the basis of resulting emissions. Assume that 1 gallon of LPG equals 100
cubic feet of "equivalent natural gas." LPG use by state is given in Table 2 of
Reference 6. The "residential and commercial" category of Table 2 can be separated
into residential and commercial-institutional by assuming that the ratio of
residential to commercial use of LPG is the same as the ratio of residential
to commercial use of natural gas, as given in Reference 5. The "equivalent natural
gas" should be added to the area source totals for residential, commercial-
institutional and industrial natural gas.
5.5.4.2.7 Wood - No published data are available for wood consumption by
source category. Residential use (columns 74 through 77, card l) can be estimated
by multiplying the number of dwelling units heating with wood by the heating
requirement factor of 0.0017 ton of wood per dwelling unit per degree-day. Wood
may also be used industrially (columns 67 through 69, card 2) by those wood-
processing operations that are not included as point sources. Wood use by these
sources should be estimated if all wood-processing operations have not been identi-
55
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fied as point sources. Space has also been provided (columns 34 and 35, card 2)
for commercial-institutional use of wood. No reporting techniques for consumption
of wood by users in this category are available, however. Thus, a figure for
commercial-institutional consumption of wood can be entered only if adequate local
data from fuel dealers or other reliable sources are available.
5.5.5 Applying Fuel Consumption Apportionment Methods
It should be evident from the discussion of the two methods for determination
of area source fuel consumption that neither method can be used exclusively to
produce an accurate, comprehensive source inventory. The two methods must be used
together, making best use of the advantages offered by each method to offset the
deficiencies in the inventory that would result from use of one method alone. This
section will deal with how to apply both methods to the best advantage, and the
assumptions to be made when difficulties are encountered in the use of each method.
A discussion is presented for each fuel.
5.5.5.1 Coal Data - In the past, Bureau of Mines data have been relied upon mainly
because coal dealers have not been able to furnish sufficiently detailed information.
The state totals given by the Bureau of Mines should be regarded as accurate. When
these totals are apportioned to counties, they may not be as accurate as the data
provided by local dealers. The chief value of data from coal dealers is usually as
a check on the Bureau of Mines figures and as an indicator of local use patterns
that would not be discovered by using Bureau of Mines data alone. For instance,
local dealers should be able to furnish the percent of their customers that burn
anthracite and the percent that burn bituminous. Their fuel sales figures may
reveal that all anthracite is consumed in only a few counties in the state, rather
than distributed among all the counties, as would be predicted by apportionment of
Bureau of Mines figures. If coal consumption totals obtained from dealers do not
agree with Bureau of Mines figures, it is best to assume that the total state con-
sumption given by the Bureau of Mines is correct. The distribution to source
categories, particularly residential and commercial-institutional, may be more
accurately provided by dealers, however. If the residential and commercial-institu-
tional area source totals provided by dealers are regarded as correct, the industrial
area source total can be adjusted, if necessary, so that the state total equals the
figure given by the Bureau'of Mines. If fuel dealer totals are given only for groups
of counties, individual county totals can be obtained by using the appropriate appor-
tioning technique. For residential and commercial-institutional sources, county to-
tals derived by this method should still be regarded as more accurate than the appor-
tioned Bureau of Mines data. A judgment must be made, however, as to whether the
data provided by dealers are truly accurate. If the dealer provides data that are
inaccurate or incomplete, use the Bureau of Mines data.
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5.5.5.2 Fuel Oil Data - Many of the remarks made for coal data also apply for fuel
oil. Distribution to source categories as provided by fuel dealers may be regarded
as more accurate than the apportioned Bureau of Mines data, but the state totals
reported by the Bureau of Mines should be regarded as correct. One of the chief
values of dealer contacts is in determining if residual oil is used residentially.
If fuel oil dealers can state what portion of their residential customers are sold
residual oil for heating, then a portion of the total fuel oil consumed by
residential sources, as predicted by the calculation based on number of housing
units, can be assigned to residual oil.
5.5.5.3 Natural Gas - Few problems should be encountered in determining natural gas
use by county. If gas dealers provide records of their sales to each source
category (by county), this information should be used. If the gas dealers do not
provide this information in sufficient detail, the Bureau of Mines figures should
be used.
5.5.5.4 Other Fuels - LPG use by county can be determined from local dealers and
Bureau of Mines data. The same criteria given for natural gas data also apply for
LPG. Wood use can best be determined by the calculation based on number of dwelling
units using wood as heating fuel, because much of the wood consumed may not be
delivered by dealers. Use of coke and process gas by area sources can be determined
only from available local information.
It should also be pointed out that the general approach to be taken is to mini-
mize duplication of work and the number of calculations necessary. Mention has been
made previously of the methods that should be used to determine area source totals.
Generally, it is most convenient to start with Bureau of Mines data and determine
statewide area source totals for each fuel by subtracting the amounts consumed by
point sources. Any apportioning to source categories that is necessary can then be
done, until statewide area source fuel consumption totals for each source category
are obtained. Next, local dealer information can be compared with the Bureau of
Mines data by apportioning the state area source totals to the counties for which
local dealer data are available. It can then be decided, according to the criteria
previously discussed, which are more accurate--the local dealer data or the Bureau
of Mines data. If fuel dealer data are used, required adjustments can be made in
the state area source totals so that the sum of the individual county fuel use
totals does not exceed the state totals determined from the Bureau of Mines data.
Finally, the adjusted statewide area source totals can be apportioned to the
remaining counties for which fuel dealer information was not available. It is
usually most convenient to combine all the factors used to compute area source fuel
totals into one constant factor. This factor can then be multiplied by the appro-
priate apportioning factor for each county, such as number of dwelling units. Use
of a computer can also aid in performing area source calculations.
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5.6 SOLID WASTE DISPOSAL (COLUMNS 10 THROUGH 42, CARD 3)
The area source solid waste category includes on-site refuse disposal
activities by residential, industrial, and commercial-institutional sources. On-site
incineration refers to disposal in a small incinerator. This includes backyard
burners, industrial incinerators, and incinerators at food and department stores,
hospitals, and schools. On-site open burning refers to unconfined burning of waste
such as leaves, landscape refuse, or other rubbish. For emission inventory purposes,
only solid waste that is burned is of interest. Unfortunately, very little
quantitative information about on-site solid waste disposal is available.
Two methods of collecting data are available:
1. Solid waste surveys: Some areas have conducted comprehensive surveys of
solid waste disposal practices. If such a survey is available, it should
be used to estimate solid waste quantities. Many such surveys cover only
collected waste, however, and are of limited value for determination of
on-site waste disposal quantities.
2. Per-capita generation rate: Average factors shown in Table 5-1 were derived
from the 1968 National Survey of Community Solid Waste Practic~~.13, 14
Table 5-1.
NATIONWIDE AVERAGE SOLID WASTE DISPOSED OF BY
INCINERATION AND OPEN BURNING
(lb/person-day)
Source category
._-----
Factor
1.6a
0.8a
0.65
Industrial on-site incineration
Industrial on-site open burning
Residential and commercial-institutional
on-site incineration
Residential and commercial-institutional
on-site open burning
0.5
a Unit refers to pounds per urban person per day.
No apportioning of state totals is necessary if solid waste quantities are
determined from a local surveyor a per-capita generation rate. The area source
quantities should be entered in columns 10 through 42, card 3 of the form. Method 1
should be used, if at all. possible, because method 2 does not take into account local
variations in solid waste disposal practices. The factors shown for method 2
represent national averages only. They may be very inaccurate predictors of solid
waste quantities in local areas. Note that, when method 2 must be used, the indus-
trial factors are based on urban population, and the residential-commercial-
58
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institutional factors are based on total population. The necessary population data
must be obtained from the 1970 Census of Popu1ation.2
The area source form also requires that the residential and commercia1-
institutional categories be reported separately. If better information from solid
waste surveys cannot be obtained, assume that 75 percent of the residentia1-
commercial-institutional total was generated by residential sources.14
In some areas, open burning and on-site incineration are regulated and may be
prohibited. If one or both of these practices is prohibited, the corresponding
generation factor(s) should not be applied. Under such circumstances assume that the
solid waste that would normally be allotted to on-site disposal is handled by some
other method, such as land-filling, thac would not result in air pollutant emissions.
For such cases, a value of zero should be entered, where appropriate, on the area
source form.
5.7 MOTOR VEHiClE FUel DATA
5.7.1 Gasoline-Powered Motor Vehicles
This area source category includes all highway use of gasoline by light-duty
vehicles (under 6,000 pounds gross vehicle weight) and heavy-duty vehicles (over
6,000 pounds gross vehicle weight). Light-duty vehicles include automobiles and
small trucks, while heavy-duty vehicles include larger trucks and buses. Three data
collection methods for estimating gasoline-powered vehicle miles of travel (VMT) are
given in order of decreasing accuracy.
1. Measured vehicle miles: Emissions from motor vehicles are best estimated
using measured VMT. Total VMT can be obtained from traffic surveys con-
ducted by state highway departments or local transportation agencies.
Normally the total VMT will include diesel VMT as well as gasoline VMT. If
actual vehicle-mile information is unavailable from these surveys, VMT can
be estimated from traffic counts or traffic flow maps. This is accomplished
by multiplying the traffic volume by the length of roadway. Since vehicle
emission rates vary appreciably with average speed, VMT data should be
obtained by roadway type. On the basis of average speed, roadway types
can be classified as: limited access (greater than 50 mph), rural roads
(45 mph), suburban roads (35 mph), and urban streets (25 mph or less).
Data are entered, by roadway speed, in columns 52 through 76 of NEDS area
source form, card 4.
2.
County gasoline sales data: Some state tax departments compute gasoline
sales by county. The county gasoline sales can be converted to VMT by
multiplying by 12.2 miles per gal10n.15
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3. Published gasoline sales totals by state: If neither of the above methods
can be used, state sales of gasoline for highway use may be obtained from
High~aY_Statistics.16 Statewide sales can then be apportioned to counties.
To complete the area source form by means of the first method above, total
vehicle miles of travel by roadway type are obtained by county and entered on the
area source form (columns 52 through 76, card 4). If it is not possible to determine
vehicle miles for each of the types of roads, the vehicle miles should be broken down
at least into the urban and rural components.
If the measured vehicle mile method is used, the light-dutyjheavy-duty fuel
consumption breakdown should be calculated. To estimate light-duty and heavy-duty
gasoline consumption, obtain the light- and heavy-duty mileage breakdown from trans-
portation study data. Subtract the heavy-duty diesel miles from the total heavy-
duty miles (see section 5.7.2). Light-duty vehicle gasoline consumption is calcu-
lated by dividing the light-duty miles by 13.6 miles per gallon. Heavy-duty vehicle
gasoline consumption is obtained by dividing the heavy-duty miles by 8.4 miles per
gallon.15 These values are entered in columns 43 through 54 of card 3.
If the second method is used to complete the area source form, total county
gasoline VMT, computed by assuming an average of 12.2 miles per gallon, is divided
into heavy-duty miles and light-duty miles. It is assumed that approximately 11
percent of the total miles in the county are heavy-duty vehicle travel. After
heavy-duty and light-duty VMT are determined, they are converted to gasoline con-
sumption by using 13.6 miles per gallon for light-duty vehicles and 8.4 miles per
gallon for heavy-duty vehicles.15 The urban-rural breakdown of vehicle miles by
county is estimated by the NEDS program using the population distribution code. The
population distribution code (column 77, card 3) shows the urban component of the
total county population. If this value is 2, for example, assume that 20 percent of
the VMT are urban and 80 percent are rural. If the population distribution code is
3, for example, assume 30 percent of the VMT are urban, etc. The light-duty and
heavy-duty gasoline consumption figures are entered in columns 43 through 54, card 3
of the area source form. The rural and urban VMT are entered in columns 58 through
63 and 70 through 76, respectively, on card 4.
In the third method, gasoline consumption must be apportioned to counties. The
best means for apportionment is to use county service station sales data from the
1968 Census of Business17 according to the following formula:
County gasoline sales =
County service station sales, $ x State gasoline sales, gal
State service station sales, $
60
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If adequate data from the 1968 Census of Business17 cannot be obtained., popula-
tion data from the 1970 Census of Population2 should be used to apportion state
gasoline sales to counties. Once this is completed, method 2 above is used to deter-
mine the values for the area source form.
The first is by far the most accurate of the three methods for the determina-
tion of gasoline motor vehicle emissions. Methods 2 and 3, based on gasoline sales,
are inferior to the vehicle-mile method--method l--because they assume that all
gasoline sold in the county is consumed on the roads in the county. The vehicle-
mile method measures actual vehicle travel. Another problem with the gasoline sales
method is that the urban-rural breakdown of VMT must be estimated. It should be
emphasized that only measured vehicle miles should be entered on the area source
form. Calculated vehicle miles, based on gasoline sales data, are to be used
only as described in the second method for determining light-duty/heavy-duty vehicles
breakdown. If no measured vehicle miles are available, columns 52 through 76 of card
4 must be left blank.
5.7.2
Diesel-Powered Motor Vehicles
This area source category includes heavy-duty trucks and buses using diesel
fuel. Again, three data collection methods can be used:
1.
Vehicle miles: The best method is to obtain measured vehicle miles
traveled by diesel-powered vehicles. If this information is not available,
diesel vehicle miles must be calculated from the county diesel fuel sales
determined by method 2 or 3 below. Diesel VMT is obtained by multiplying
the diesel fuel sales by 5.1 miles per gallon.16 If method 1 was previously
used for gasoline-powered vehicles, this method must also be used for diesel-
powered vehicles to account for diesel VMT included in the total VMT.
County diesel fuel sales: If vehicle miles cannot be obtained, gallons
of diesel fuel sold per county should be obtained from the appropriate
state agency or oil dealers' association.
2.
3.
Published statewide sales figures: If neither of the above methods can
be used, consider the figure for "on-highway use of special fuels" re-
ported in Highway Statistics16 to be the amount of diesel fuel sold
statewide. Apportion this total to counties using the same apportionment
method as for gasoline VMT.
When the
only quantity
tion. Diesel
vehicle-mile method for completing the area source form is used, the
to be entered on the area source.form is highway diesel fuel consump-
VMT needs to be computed only to account for the diesel portion of the
61
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total VMT. The county diesel fuel consumption should be coded in columns 60 through
64 of card 3.
Obtaining measured diesel vehicle miles is by far the best method. Data may be
available that indicate the percent of the total VMT by diesels. As was indicated
in methods 2 and 3 for.gasoline-powered vehicles (Section 5.7.1), assume that diesel
fuel purchased in the county is consumed in the county. This is an even more gross
assumption with diesels, however, because most diesel traffic is through-traffic.
5.7.3 Off-Highway Fuel Use (Columns 55 through 59 and 65 through 67, Card 3)
Off-highway internal combustion machines use both gasoline and diesel fuel.
Off-highway gasoline-powered machines consist of farm tractors, lawnmowers, snow-
mobiles, etc. Off-highway diesel-powered machines include farm tractors, con-
struction equipment, emergency generator power units, compressor engines, etc.
All off-highway equipment is uncontrolled from an exhaust emission standpoint. Two
data collection methods can be considered:
1.
Fuel consumption factors:
a.
Gasoline fuel use: Farm tractor fuel consumption can be calculated by
applying an annual per-tractor fuel consumption rate (1,000 gallons/
tractor-year) to the number of tractors in use. The total consumption
for all other off-highway gasoline-powered equipment may be calculated
by applying a factor, based on population, of 13 gallons per person.
b.
Diesel fuel use: Farm tractor diesel fuel consumption is about 1,000
gallons per tractor annually. The total consumption for construction
equipment is approximately 5,000 gallons annually per non-building
construction employee. All other off-highway diesel fuel consumption
may be calculated by applying a factor of 7.4 gallons per capita
annua lly.
2.
Fuel totals by state: Total off-highway use of gasoline and diesel fuel by
state can be obtained from publications by the Bureau of Mines4 and the
Department of Transportation.16
If method 1 is used, off-highway gasoline consumption by county is calculated
by summing farm tracior gasoline consumption and all other gasoline consumption.
Total tractors (gasoline and diesel) by county are reported in the Census of
Agriculture.18
About 60 percent of all tractors are gasoline-powered. The total fuel use can
be calculated by multiplying the number of gasoline-powered tractors in the county
by 1,000 gallons per tractor-year. All other off-highway gasoline consumption is the
62
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\1\ .-..
product of 13 gallons per capita-year and the population of the county.2 Off-
highway gasoline consumption is entered in columns 55 through 59 of card 3 on the
area source form.
Using method 1, the total off-highway diesel fuel consumption by county is the
sum of farm tractor usage, construction equipment usage, and all other diesel-
powered equipment usage. Thirty-five percent of all tractors reported in the ~~nsus
~~!~Cultur~18 are diesel-powered. The total farm tractor population is made up .
of 60 percent gasoline tractors, 35 percent diesel tractors, and 5 percent LPG
tractors.
The diesel fuel usage by farm tractors is the product of the number of diesel
tractors in the county and 1,000 gallons per tractor-year. The number of non-
building construction employees is reported in County Business pattern~.19 Con-
struction equipment diesel fuel use is the product of the number of non-building
construction employees in the county and 5,000 gallons per employee-year. The
total for all off-highway diesel fuel use is entered in columns 65 through 67 of
card 3 on the area source form.
If method 2 is used, the state totals are apportioned to the county based on
the ratio of the county population to the state population.4 The resulting quantities
are entered on the area source form (gasoline in columns 55 through 59; diesel in
columns 65 through 67).
Method 1 is the recommended method. The published statewide non-highway fuel
totals for method 2 are determined from taxes refunded to individuals using taxed
fuels for off-highway purposes. Because all individuals using fuels off-highway do
not apply for tax refunds, the state totals are likely to be underestimated. It is
also difficult to apportion statewide off-highway fuel totals to counties in a
meaningful manner. Population apportionment, for instance, results in high farm
tractor fuel consumption in large urban areas. Method 1 will be expanded and improved
upon as more refined data on engine fuel consumption become available. State
snowmobile registrations, for example, will allow this source to be handled
separately and, therefore, more accurately.
r'
I
5.7.4 Railroads (Columns 68 through 72, Card 3)
This category, which is concerned with fuel consumption by railroad locomotives,
also includes the fuel used to heat railroad stations and workshops. The latter
fuel use will be much less than that of locomotives and is difficult to separate
from the total railroad fuel use. Hence, the railroad category is considered to be
the fuel consumption by locomotives, although it does include small amounts of fuel
used for space heating. The primary fuel consumed by railroads is distillate oil
63
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(diesel fuel), but smaller amounts of residual oil and coal are also used.
collection methods are available:
Two data
1.
Contact rail lines: Rail
their fuel use, but it is
formation by county.
Bureau of Mines data: Sales of fuel oil to the railroads for use in each
state are given in Table 10 of Mineral Industry Surveys.4
lines may be able to furnish state totals for
unlikely that they will be able to provide in-
2.
For completion of the
roads should be entered in
apportioned to counties as
area source form, the county fuel consumption by rail-
columns 68 through 72, card 3. State fuel totals can be
follows:
1.
By miles of track per county as determined from detailed state maps or
obtained from the rail lines.
By county population as given in the 1970 census_~_~~p-ulati9~.2
2.
If county fuel totals are obtained from rail lines, this information should be
used. In most cases it will be necessary to apportion a state total, however.
Rail line figures should be used in preference to Bureau of Mines state totals,
because some preliminary apportioning may be accomplished by doing so. Fuel use by
a rail line can be assigned to only that portion of the state in which the rail lines
operate.
Apportionment by miles of track per county is the preferred method; however,
track miles in railroad yards often cannot be determined if state maps must be used
to estimate track mileage. Because operations in rail yards are usually heavier
than on main-line track, emissions from yard operations may be quite significant.
If yard track mileage cannot be obtained from rail lines, the yard mileage can
be roughly accounted for by doubling the measured track mileage in counties where
it is known that there are significant yard operations. The population appor-
tioning technique should be used only when it is impossible to use track mile-
age. This technique assumes that most yard operations take place in large
cities, an assumption that mayor may not be true depending on the state being
considered.
Residual oil, which may be used by railroads, can be accounted for if Bureau
of Mines figures are used, by adding the state residual oil total for railroads
to the distillate oil total before apportioning to counties. Use of coal by rail-
roads, which can be considered negligible, does not need to be reported.
64
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.
----
5.7.5 Vessels (Columns 24 through 40, Card 4)
This source category includes ocean-going ships, river vessels, and small
pleasure craft used on lakes and rivers. A more detailed discussion of each type of
vessel and the methods used to obtain fuel consumption data are presented below.
Three data collection methods are available:
1.
Coal-powered vessels: There are still a few vessels, notably in the Great
Lakes region, that burn anthracite coal. No reliable method for estimation
of emissions on a local basis for these vessels is currently known, be-
cause only nationwide fuel totals are available.3 Thus information on
local fuel consumption can be obtained only from estimates made by port
authorities or ship operators.
2.
Gasoline-powered vessels: This category includes small craft operated by
inboard, outboard, or inboard-outboard motors on lakes and rivers. Gaso-
line consumption can be estimated by using a factor of 160 gallons of
gasoline per boat registration per year. This factor was derived from in-
formation on average annual operating hours, average horsepower per vessel,
and average fuel consumption per horsepower-hour of operation. The
estimate also approximately accounts for any non-motorized boats that may
be included in the state total of registrations and for boats with small
outboard motors that may not be registered.20 State boat registration should
be obtained from the appropriate state agency, such as the State Department
of Recreation or Fish and Game Department, etc.
Fuel oil (including diesel)-powered vessels: Fuel consumption by these
vessels, which are the major vessels subcategory of interest, includes the
fuel used by large cargo and passenger ships, oil tankers, tugboats, and
all other steamships and motorships that use fuel oil. Fuel consumption
totals can be obtained by:
3.
a.
Questionnaire surveys of shipping and tugboat companies and contact with
the local port authorities. This method would provide the most
accurate local data for fuel consumption rates of many of the vessels
in the area. Such a survey is not often comprehensive enough to in-
clude all vessels, however, because many vessels move in and out of the
port area during the year and would be difficult to contact.
Use of vessel movement data supplied by the U. S. Army Corps of
Engineers, 21 together with fuel consumption factors and Bureau of Mines
fuel consumption figures.4 This method is much easier to implement
than a questionnaire survey, and may be almost as accurate despite the
b.
65
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c.
generalizations that must be made to effect its use.
described in detail later in this chapter.
Use of Bureau of Mines figures only. State totals for fuel oil sold
to vessels are given in Table 11 of Reference 4. Not all the fuel sold
for vessel use is by any means consumed within the state boundaries,
however. Much of the fuel may be consumed far out at sea and not in a
port or waterway area. If it is assumed that 75 percent of the dis-
tillate oil figure given in Reference 4 and 25 percent of the residual
oil total are consumed in ports and waterways within the state, a
rough estimate of vessel fuel oil consumption can be obtained. This
method should not be used in conjunction with a detailed emission in-
ventory, however, and is useful mainly to obtain an order-of-magnitude
emission estimate from vessel operations.
This method is
Unique apportioning methods are used for each type of vessel when completing
the area source form:
66
1.
Coal-powered vessels: Because fuel consumption data on a local basis are
very limited for coal-powered vessels, county totals may have to be obtained
by apportioning state or regional totals. Anthracite coal use should be
assigned to counties with major ports, according to tonnage handled in the
ports. These data are available from Waterborne Commerce of the United
States,21 pub 1 i shed bv the U. S. Army Corps ~fEngineers for --;l~-;~~-:- and
from World Alman~~22 for major ports only. It may be that coal use is
available only as a total for a multistate area. In this case it is
necessary to assign fuel use to individual ports as a proportion of the
total tonnage handled by all major ports included in the multistate area.
2.
Gasoline-powered vessels: Gasoline use could be apportioned to counties
according to boat registrations per county, but this would not be an
accurate method because many boats are not used primarily in the county in
which they are registered. Instead, the total gasoline consumption
predicted by the state total of boat registrations should be apportioned to
counties on the basis of inland water surface area. County inland water
areas should be determined from the Bureau of the Census' Area Measurement
.-
Report~.23 .
Fuel oil-powered vessels: If fuel consumption totals are determined from a
questionnaire survey, the fuel oil consumption figures should simply be
assigned to the counties where the vessels are operated. If vessel movement
data obtained from Reference 21 must be used, extensive apportioning measures
3.
-------
are necessary. The apportioning method becomes somewhat involved because
both underway and dockside emissions should be considered.
Underway emissions include the emissions that occur when a vessel is moving
under its own power through a waterway and when it is maneuvering into its
dock space. The average fuel consumption rate during these periods for
steamships (predominantly residual oil users) is 44 gallons per nautical
mile, and for motorships (predominantly diesel fuel consumers) the average
fuel consumption rate is 19 gallons per nautical mile.
In-port, or dockside, emissions occur when a ship operates its engines or
boilers when in port to provide power for the ship's utilities. Average
fuel consumption rates are 1900 gallons per day of residual oil for steam-
. ships and 660 gallons per day for motorships. The local port authority
.should be able to supply a figure for the number of days, on the average,
that a ship remains in port. If not, an average figure of 3 days per
vessel should be used.
The complete description of the vessel-movement data method for fuel oil-
powered vessels is presented in stepwise form below:
Step 1:
Determine in-port fuel consumption.
1.
The number of vessels entering a port can be found in Section
2 of parts 1, 2, 3, and 4 of the Waterborne Commerce of the
United States.21 Each part cover~~~~ifi~ geographical area
of the United States. Section 2 lists vessel traffic on water-
ways for self-propelled vessels and non-self-propelled vessels
according to type and draft of vessel and direction of trip.
For the first step in the determination of inport emissions,
select the entries for ports in Section 2, and assume that
only self-propelled vessels with a draft greater than 18 feet
will be operating under their own power when in port. Determine
the number of vessels meeting these conditions that enter each
port, and m ltiply by 3 days per vessel or by a number recom-
mended by the port authority to calculate the number of vessel-
days' in each port.
Vessel-days in port must be distributed between those ships
that use residual oil and those that use distillate (diesel)
oil. This procedure is illustrated as follows for State X:
2.
a.
From Reference 4, Table 11,
residual fuel oils sold for
can be found for State X.
the amounts of distillate and
use by vessels in each state
67
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Distillate oil consumption = 232 x 103 bbl = 9,750 x 103 gal
Residual oil consumption = 1,000 x 103 bbl = 42,000 x 103 gal
b. Convert fuel consumption figures to vessel-days:
3
Distillate vessel-days = 9,750 x 10 gal = 14,800 vessel-days
660 gal/day
= 42,000 x 103 gal
Residual vessel-days 1,900 gal/day = 22,100 vessel-days
c.
Then total vessel-days = 14,800 + 22,100 = 35,900
Percent distillate vessel-days = ~::~~~ x 100% = 40%
d.
Then at each port in State X, assign 40
total vessel-days to motorships (diesel
60 percent to steamships (residual fuel
percent of the
fuel users) and
users) .
3.
Finally, in-port fuel consumption can be calculated by multiply-
ing the total distillate oil vessel-days by 660 gallons per
day, and the total residual oil vessel-days by 1900 gallons per
day.
Step 2:
Determine fuel consumption for vessels underway:
1.
Underway emissions will be calculated for diesel fuel use only.
In a typical harbor there are tugboats and small craft (draft
less than 18 feet) that use diesel fuel. Because most of these
do not operate their boilers or engines when in port, most
of the emissions occur when the ships are underway. Vessels
using residual oil also have underway emissions, which are
approximately accounted for when emissions for vessels using
diesel fuel are calculated by the technique described below.
Calculation of underway fuel consumption:
2.
a.
Subtract the sum for all ports of the in-port diesel fuel
consumption from the state total for distillate oil con-
sumption by vessel as given in Reference 4, Table 11.
Distribute the remaining fuel consumption figures to ports
and waterways according to tonnage handled, as given in
Secti on 1 of Water:t>.Q!~__~OI1ll!!~T~EU)f -.!h~_JJnited ~tates. 21
Underway fuel consumption totals are assigned to counties
using the description of the waterway given in Waterborne
Commerce of the United States. In cases where a waterway
borders more than one political jurisdiction, divide the
b.
68
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emissions equally between jurisdictions. In instances where
a waterway, such as a river, passes by a series of counties,
assign the emissions to counties according to shoreline
mileage along the waterway.
Essentially there is only one suitable method for determining fuel consumption
by coal- and gasoline-powered vessels. The method given for each of these types
of vessels at present cannot be supplemented by other techniques. If it is possible
to determine coal use by vessels according to the method given, the county totals
should be entered on the form in columns 24 through 27 of card 4. Likewise, the
gasoline consumption total determined by the methods given previously should be
entered in columns 37 through 40 of catd 4.
Two methods are given that can be used for a detailed survey of fuel oil use
by vessels. As mentioned previously, Bureau of Mines data alone are useful only for
a rough guess of vessel fuel oil use. Little can usually be gained by using both of
the methods for fuel oil consumption by vessels. Vessel-movement data serve as re-
placements for questionnaires or vice versa. A modified version of the vessel-
movement data method would be to contact port authorities for the vessel-movement
data. The Waterborne Commerce of th~ United States21 data are much more complete,
however, and should be used if at all possible. All four parts of ~ater~~ne C~mmerce
of the United States are not necessary for completion of a vessel fuel use inventory.
Only that part that covers the geographic area being considered need be used. The
choice of either of the first two methods depends on whether sufficiently complete
data could be obtained by a questionnaire survey to justify the time required to
institute the survey. If detailed data for individual types of vessels such as tug-
boats, tankers, and cargo ships are desired, questionnaires should be used. If only
a reliable estimate of the total fuel consumption by vessel is desired, vessel-
movement data are adequate. In any case, the total fuel oil consumption, both
residual and distillate oil, should be entered in columns 28 through 36 of card 4.
The figures entered on the form should thus be the sum of dockside and underway
fuel consumption totals. In the future, should emissions from vessels increase in
relative importance, the area source form may be expanded to allow space for both
underway and dockside fuel consumption.
5.7.6 Aircraft (Columns 10 through 23, Card 4)
All aircraft operations are considered area sources. The required data are
the number of landing-takeoff (LTO) cycles performed annually by military, civil
(general aviation), and commercial aircraft. Only two data collection methods are
a vail ab 1 e :
69
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1.
FAA published data: Three Federal Aviation Administration publications
can be used to determine LTO cycles performed in each county.
a. ~~-~!_~Ci.!fiC~~_~!~~ty:24 This publication gives the number of
operations performed by commercial, civil, and military aircraft at air-
ports with FAA-regulated control towers. These airports will include
all the major non-military airfields in the United States. An
"operation," as defined by the FAA, is either a takeoff or a landing;
thus to determine the number of LTO's, the number of "operations"
should be divided by two. Totals are given both for itinerant flights,
those that terminate at an airport different from the one at which they
originated, and for local flights, those that originate and terminate
at the same airport. To determine total LTO's for each aircraft category,
the sum of itinerant and local operations should be used.
b. MilJ_ta~:L~!!:_!~~f~ic!\~~!v.i_ty _~~por!:25 This publication gives the
number of operations by military and civil aircraft performed at military
airfields. Follow the same procedure as given for FAA Air Traffic
----- -.-.----
Activity24 to determine LTO's.
c. Census -~~S. Civil Aircraft:26 This publication can be used to
obtain rough estimates of the number of LTO's performed by civil air-
craft at airports that do not have FAA-regulated control towers. These
airports include the smaller public airports and privately owned air-
strips. The Census of U. S. Civil Aircraft26 gives the number of
active civil aircraft in each county. These data can be used to
estimate LTO's by assuming that the total number of eligible aircraft in
each county is approximately equal to the number of daily LTO cycles
performed by civil aircraft. This method should be used to estimate
LTO's only for airfields not included in FAA ~!r Traffic Activity.24
Local contacts: The airport owners or operators can be contacted to deter-
mine the number of LTO's performed by civil aircraft at airports that do
not have FAA-regulated control towers. Airport authorities can also furnish
the number of LTO's for any commercial aircraft that land at the airport.
2.
In completing the form, the number of LTO's
aircraft at each airport should be assigned
should be entered in columns 10 through 23.
for civil, commercial, and military
to the proper county, and the totals
card 4.
Emissions for each aircraft category will be calculated by using average
emission factors based on the mix of engine and aircraft types for each category of
the U. S. aircraft fleet. As the aircraft mix within each aircraft category changes
70
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with time, and as newer information becomes available
type of aircraft engine, the emission factors will be
changes.
LTG cycles at airports with FAA-regulated control towers and at military air-
fields can be easily determined from the FAA publications cited for method 1. LTG
cycles at small airports that do not have FAA-regulated control towers can most
accurately be determined by contacting airport officials. Data from the Census_of
U. S. Civil Aircraft26 should be used only when adequate information cannot be
determined by local contacts. In many areas the majority of civil aircraft operations
are perfprmed at airports that do not have FAA-regulated control towers; thus it is
definitely necessary to consider the aircraft operations at these smaller airports.
on the emission rates for each
adjusted to reflect these
5.8 EVAPORATIVE LOSSES (COLUMNS 41 THROUGH 51, CARD 4)
This source category covers evaporative losses of hydrocarbons and other organic
compounds at locations not considered as point sources. There are three main sub-
categories:
5.8.1 Gasoline-Handling Losses
Gasoline-handling losses include evaporative losses from gasoline marketing
operations, i.e., filling losses from loading underground storage tanks at service
stations, and spillage and filling losses from filling automobile gas tanks. Gaso-
line evaporative losses at refineries and bulk terminals should be considered as
point sources.
5.8.2
Dry Cleaning Losses
Clothing and other textiles may be cleaned by treatment with organic
The primary source of evaporation losses in the dry cleaning operation is
through which hot air is circulated to dry the clothes.
solvents.
the tumbler
5.8.3
Surface-Coating and Miscellaneous Solvent-Use Operations
Included in this category are organic solvent losses from surface-coating,
printing, metal-cleaning, and degreasing operations. Surface-coating operations
involve primarily the application of paint, varnish, lacquer, or paint primer for
decorative or protective purposes. The principal types of industries engaged in
surface-coating operations are automobile-assembly factories, aircraft companies,
contailler manufacturers, furniture manufacturers, appliance manufacturers, job
enamelers, automobile repainters, and plastic-products manufacturers. In many
industries, metal-fabricated products must be cleaned or degreased by washing with an
organic solvent before final surface finishing can be completed.
71
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Three data collection methods can be used:
1.
Gasoline-handling losses can be calculated if the gasoline sales total for
each county is known. If this total has not already been determined for
motor vehicle emission estimates (columns 43 through 59, card 3), it should
be calculated according to the methods given for on-highway motor vehicles
and for off-highway gasoline use.
2.
Evaporative losses for solvent-use operations can best be determined by a
questionnaire survey of all suspected solvent users. Information required
is the amount of solvent purchased per year in tons. If figures are
available only in gallons, the average density (pound per gallon) of the
solvents used should also be obtained and converted to tons.
3.
An alternate method, which is not as accurate as a survey but much easier to
employ, is to assume that solvent us~ is proportional to population. For
dry cleaning operations, use of either of two factors, 2 pounds of solvent
evaporated per person per year for moderate climates and 2.7 pounds per
person per year for colder climates, will provide reasonable estimates.
Emissions from surface-coating and degreasing operations are more difficult
to estimate, however. A figure of 30 pounds per person per year has been
proposed, but this estimate was derived from data obtained only in large
cities, where higher-than-average concentrations of industries involved in
surface-coating operations would be located, and represents the total amount
of solvent used by point and area sources. Thus, the graduated scale shown
in Table 5-2, based on county population obtained from the 1970 Census of
population,2 is recommended for estimation of other solvent-use evaporative
losses.
Table 5-2.
SOLVENT-USE ESTIMATES
--.- ---------. - -
- . -"- -- - - - - -- ...
----- ..----.-- .
----, .------.. -----..-."
--------- -----
---___.._0__- -..
- -- -". -_u
.______0- ..-.._-------- -----
County population
Solvent used, .
lb/capita-year
3
8
18
28
Less than 100,000
100,000 - 500,000
500,000 - 1,000,000
More than 1,000,000
--------- -
- - . -.-. - ._- ._--.--
. - ----.-.."------
In completing the form, the total county gasoline sales (the sum of both on-
highway and off-highway fuel consumption) should be entered in columns 47 through 51
of card 4. The total solvent use (the sum of the totals for dry cleaning, surface-
coating, and degreasing operations, and any miscellaneous solvent use) should be en-
tered in columns 41 through 46 of card 4. The amount of solvent purchased per year
is assumed to be the amount evaporated. If further information becomes available to
72
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indicate that this is not the case, any changes can be accounted for by adjusting
the solvent evaporation emission factor contained in the emission factor file. If
actual data concerning solvent use can be obtained, this information should be re-
corded on the area source form. Otherwise the per-capita solvent-use factor should
be employed. If an average density of the solvent used is not supplied, an estimate
of 6.7 pounds per gallon should be used to estimate the tons of solvent
27 28
purchased. '
5.9 MISCEllANEOUS SOURCES
Each of the source categories contained in this section can produce large
quantities of air pollutant emissions. The techniques for collection of the re-
quired data and estimation of emissions are normally not as refined as the methods
for other area sources, however. Each type of source included in this section is
discussed individually, and the best available means for making emission estimates
are presented. The miscellaneous sources are characterized by intermittent emissions,
rather than more or less continuous emissions that are characteristic of the other
source categories. This means that even though the total emissions contributed by
these sources may be relatively small, on particular days their contributions to the
total emissions can be quite significant.
1.
Forest fires (columns 32 through 41, card 5): Emissions from forest fires
can be very significant. Estimates of the quantity and type of growth
burned should be available from the U. S. Forest Service, state forestry
or agriculture departments, or local fire protection agencies. In addition,
the U. S. Forest Service annually publishes Wildfire Statistics ,29 which
gives the total acreage burned for each state; however, this document does
not provide data on acreage burned by counties. For this reason, it is
much better to consult with local officials for estimates of acreage burned.
If it is not possible to obtain sufficient information from local officials,
the state total from Wildfire Statistics should be apportioned to counties
according to forest acreage per county. If this information is not
available from the appropriate state or local agency, the total acreage
burned can be divided equally between counties with significant forest
acreage, as shown on state maps.
The determination of tons of growth burned per acre is equally important.
Local officials should be contacted for this information. If they cannot
provide an estimate, the factor from Table 5-3 that best describes the
growth burned should be selected.
73
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1-- ---
74
Table 5-3.
FOREST FIRE ESTIMATES
. >-- -- ---
---.. ------- -------------
Growth
Quanti ty
burned, tons/acre
Heavily forested
Thinly forested or brushy
40
20
--- --- - ---_..--
2.
Slash burning (columns 42 through 50, card 5): Waste from logging operations
is often burned under controlled conditions both to reduce the potential
fire hazard in forests and to remove brush that can serve as a host for
destructive insects. Because of the magnitude of this operation in certain
areas, if certain meteorological conditions exist when slash burning takes
place, a serious air pollution problem can result. Officials of the U. S.
Forest Service or state forestry department should be contacted to provide
estimates of the area burned and quantity of slash per acre. If an estimate
of the quanti.ty of slash burned per acre cannot be obtained from other
sources, use the factor of 75 tons per acre.
Also included under this source category are agricultural field-burning
operations such as stubble burning and burning of refuse from land clearing.
Because no published information is known to be available on this subject,
information must be determined through estimates made by state agriculture
departments or extension services. Estimates of acreage and tons per acre
burned should be obtained. For grass burning, if a local estimate is not
available, a factor of 2.5 tons per acre should be assumed. If
agricultural field burning is included with slash burning on the area
source form, the quantity-per-acre figure should represent a weighted
average for slash burning and agricultural field burning.
3.
Frost control (columns 51 through 57, card 5): In some areas orchard
heaters may be used on the coldest nights of the year. The county or state
department of agriculture will usually have a breakdown of the number and
types of orchard heaters that are in use. Data can also be obtained from
some of the citrus grove operators in the area. These sources should also
be able to furnish the number of nights the units were fired during the year
and the approximate length of time each night the units were burning. An
estimate should also be obtained of the number of units fired at anyone
time.
On the area source form should be entered the approximate number of units
that are fired on each night when frost control is required, and the number
of days out of the year when such operations take place. If individual
county totals are not available, state or area totals should be distributed
-------
4.
to counties according to the approximate acreage in each county subject to
orchard heating.
Structural fires (columns 58 through 61, card 5): Building fires can also
produce short-term emissions of air contaminants. The best procedure for
determining information for this source category is to contact local fire
departments, fire protection associations, or other agencies for an
estimate of the number of structural fires that occur in each county during
the year. In the absence of such information, it can be assumed that,
based on the nationwide figures given by the National Fire Protection
Association, an average of four fires per 1,000 population occur each
5.
year.
Coal refuse piles (columns 62 through 70, card 5): Burning coal refuse
piles exist in some areas. The coal refuse piles, which were produced as a
result of coal mining operations, were formed from coal refuse and rejected
material containing too high a percentage of impurities to be marketed.
Over the years, the coal refuse piles may have been ignited by spontaneous
combustion or through careless or intentional acts of humans. Bureau of
Mines Information Circular 851530 gives the location of all known burning
coal refuse piles in 1968. This publication also gives the size of each
bank in thousands of cubic yards and surface covered in acres. If possible,
local officials and owners of the coal piles should be contacted to determine
if there has been any change in status of the coal fires since 1968, and to
determine if any new fires have started. This updated information can be
used in conjunction with the data from the Bureau of Mines publication to
estimate the extent of coal refuse fires. The total size, in hundreds of
cubic yards, of all burning coal refuse piles in a county should be entered
in columns 62 through 67 of card 5, and the total number of burning fires in
the county should be entered in columns 68 through 70.
6.
Dust emissions (columns 10 through 31, card 5): Dust emissions can result
from a variety of operations. Many of the dust emissions are caused by man,
but a large portion can be the result of natural events. The principal
causes of dust emissions are discussed below.
a.
Vehicle travel on dirt roads (columns 10 through 16, card 5): The
information that should be obtained is an estimate of the number of
vehicle miles of travel on dirt roads. The state highway department
may have made such estimates; if not, it should at least be able to
furnish the total mileage of dirt roads in each county. This information
can be converted to vehicle miles by estimating the traffic on dirt
roads. County road departments can also be consulted to determine miles
75
-------
76
b.
of dirt roads in each
roads should be based
county officials.
Aircraft LTO's on dirt airstrips (columns 17 through 21, card 5): At
certain small airports, flight cycles may be performed on dirt air-
strips. At such locations an estimate of the number of annual LTO
cycles performed should be calculated, or obtained from the airport
operator. This entry is made to account for dust emissions only. The
emissions from the combustion of fuel by the aircraft themselves will be
accounted for by the aircraft LTO cycles entered in columns 10 through
23 of card 4.
county. The estimate of the traffic on dirt
on information that can be gained from state or
c.
Windblown dust and construction activities (columns 22 through 25, card
5): In some areas large dust emissions are generated as a result of
windblown soil. Officials of the appropriate state agency, such as
the state department of natural resources or department of agriculture,
may be able to furnish estimates of the number of acres in each county
that is subject to severe soil erosion. In addition, officials of the
local offices of the U. S. Soil Conservation Service should be able to
provide the same information. Because such estimates are usually vague,
reporting the total acreage to nearest 1,000 acres is sufficient.
Also, substantial areas may be subject to construction activities that
can produce dust emissions. Road construction and large building pro-
jects, such as urban redevelopment activities and large housing sub-
divisions, are the chief locations where significant dust emissions are
produced. An estimate of the area subject to such activities can be
based on information obtained from the state highway department and
local public works departments or similar agencies responsible for
regulation of building construction activities. The total area subject
to construction activities (to the nearest 1,000 acres) should be
included in the total for columns 22 through 26 of card 5.
d.
Rock handling and storage (columns 27 through 31, card 5): Usually all
rock quarries and other large rock-handling operations will be included
as point sources. The area source rock-handling operations would cover
any smaller-scale activities, such as small sand and gravel yards, stone
products manufacturers, and other mineral products industries that
would not be included as point sources. The tons processed by all these
small operations should be entered in columns 27 through 31 of card 5.
The totals should be determined by adding the totals given on question-
naires for sources that did not qualify as point sources.
-------
5.10
REFERENCES
1.
SAROAD Station Coding Manual for Aerometric Sampling Networks. U.S. Environ-
mental Protection Agency, Office of Air Programs. OAP Publication No. APTD-0907.
Research Triangle Park, North Carolina. February 1972.
1970 Census of Population, "Number of Inhabitants." PC-A series. U.S. Depart-
ment of Commerce, Bureau of Census. Washi ngton, D. C. 1970.
Minerals Yearbook. U.S. Department of the Interior, Bureau of Mines. Washington,
2.
3.
D.C.
1970.
4.
Mineral Industry Surveys, "Sales of Fuel Oil and Kerosene." U.S. Department of
the Interior, Bureau of Mines. Washington, D.C. 1970.
Mineral Industry Surveys, "Natural Gas Production and Consumption." U.S. Depart-
ment of the Interior, Bureau of Mines. Washington, D.C. 1970.
Mineral Industry Surveys, "Sales of LPG and Ethane." U.S. Department of the
Interior, Bureau of Mines. Washington, D.C. 1970.
1970 Census of Housing, "Detailed Housing Characteristics." HC-B series. U.S.
Department of Commerce, Bureau of the Census. Washington, D.C. 1970.
1967 Census of Manufacturers, "Area Statistics." MC(3) series. U.S. Department
of Commerce, Bureau of the Census. Washington, D.C. 1967.
Distribution of Pennsylvania Anthracite (reprint from Minerals Yearbook). U.S.
Department of the Interior, Bureau of Mines. Washington, D.C. 1970.
Ozolins, G. and R. Smith. A Rapid Survey Technique for Estimating Community Air
Pollution Emissions. U.S. Department of Health, Education and Welfare, PHS.
Division of Air Pollution. Publication No. 999-AP-29. Cincinnati, Ohio.
October 1966.
5.
6.
7.
8.
9.
10.
11.
Local Climatological Data, Annual Summary with Comparative Data.
ment of Conmerce, Environmental Sciences Service Administration.
U.S. Depart-
Washington,
D.C.
1970.
12.
Coal-Bituminous and Lignite (reprint from Minerals Yearbook). U.S. Department
of the Interior, Bureau of Mines. Washington, D.C. 1970.
1968 National Survey of Commmnity Solid Waste Practices. Interim report. U.S.
Department of Health, Education and Welfare, PHS. Cincinnati, Ohio. 1968.
1968 National Survey of Community Solid Waste Practices. Preliminary data analy-
sis. U.S. Department of Health, Education and Welfare, PHS. Cincinnati, Ohio.
1968.
13.
14.
15. Automobile Facts and Figures. Automobile Manufacturers Association. Detroit,
Michigan. 1971.
16. Highway Statistics. U.S. Department of Transportation, Federal Highway Adminis-
tration. Washington, D.C. 1970.
17. 1968 Census of Business, Retail Trade. U.S. Department of Commerce, Bureau of the
Census. BC-RA series. Washington, D.C. 1968.
77
-------
18. Census of Agriculture, County Data.
Census. Washington, D.C. 1969.
19. County Business Patterns. U.S.
Washington, D.C. 1970.
20. Statistical Abstract of the United States.
of the Census. Washington, D.C. 1971.
21. Waterborne Commerce of the United States.
U.S. Department of Commerce, Bureau of the
Department of Commerce, Bureau of the Census.
U.S. Department of Commerce, Bureau
U.S. Department of the Army, Corps of
Engineers. New Orleans, Louisiana. 1970.
22. World Almanac. New York, New York. 1972.
23. Area Measurement Reports. GE-20 series. U.S. Department of Commerce, Bureau of
the Census. Washington, D.C. 1970.
24. FAA Air Traffic Activity. U.S. Department of Transportation. Federal Aviation
Administration. Washington, D.C. 1970.
25. Military Air Traffic Activity Report. U.S. Department of Transportation,
Federal Aviation Administration. Washington, D.C. 1970.
26. Census of U.S. Civil Aircraft. U.S. Department of Transportation, Federal
Aviation Administration. Washington, D.C. 1970.
27. Air Pollution Engineering Manual. U.S. Department of Health, Education and
Welfare, PHS. Publication No. 999-AP-40. Cincinnati, Ohio. 1967.
28. Handbook of Chemistry and Physics. Chemical Rubber Company. Cleveland, Ohio.
1971.
29.
30.
Wildfire Statistics. U.S. Department of Agriculture, Forest Service, Division
of Cooperative Forest Fire Control. Washington, D.C. 1971.
Bureau of Mines Information Circular 8515, "Coal Refuse Fires - An Environmental
Hazard." U.S. Department of the Interior, Bureau of Mines. Washington, D.C.
1971.
78
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6.
TRACE-MATERIAL AND HAZARDOUS-POLLUTANT SOURCE CODING
6.1 DESCRIPTION OF TRACE-MATERIAL AND HAZARDOUS-POLLUTANT FILE
When substantial quantities of trace materials or hazardous pollutants are dis-
charged from a point source, the necessary information must be included in the point
source file. Normally, trace-material emission factors for processes will be
incorporated automatically in the Source Classification Code File for sources dis-
charging nominal amounts of trace materials. Many sources of concern emit only
trace materials, however, and must therefore be described in greater detail (e.g.,
beryllium manufacturers and users). Special source inventories are now being con-
ducted to identify prime emitters of asbestos, lead, mercury, and beryllium through-
out the nation. Additional point source coding forms must be completed for each of
these sources to supplement cards 1 through 6 on the original point source coding
form. The supplemental forms are variable data AOOl and A002 cards, which describe
those portions of a source's operation that relate solely to trace-material
emissions. (It must be emphasized that cards 1 through 6 of the point source coding
form are also to be completed for each emission source of trace materials.)
The variable data cards serve as storage for a large subsystem of data that
provides approximately 26,000 cards for recording data for each point source. The
first two cards in this subsystem, AOOl and A002, have been allocated to trace-
material and hazardous-pollutant data storage. A sample variable data cOding form is
shown in Figure 6-1.
6.2 INSTRUCTIONS FOR COMPLETING TRACE-MATERIALS CODING FORM
Procedures for completing cards 1 through 6 of the point source form have been
specified in Chapter 4, Point Source Coding. This section discusses additional
instructions for completing cards 1 through 6 if the source emits quantities of
trace materials or hazardous pollutants.
In most situations, the source will emit quantities of particulates, SO , NO ,
x x
hydrocarbons, and CO along with trace materials. In such cases, complete all six cards
on the original coding form in addition to cards AOOl and A002 for each point
source. If a trace material is the only pollutant discharged, however, then it may
be found that card 3 or card 5 of the point source form, or both cards, are not
applicable, in which case all columns on the card(s) should be left blank. Enter
zeros in spaces on card 4 relating to emission estimates of SO , NO , hydrocarbons,
x x
and CO if the source has negligible emissions of these compounds.
79
-------
(X)
o
TRACE IAATERIALS/HAZARDDUS POLLUTANT
INPUT FORIA
VARIABLE DATA INPUT FORM
WORKING COpy
DATE
SUTE
CIIUIm
IQCII
~ '?oaT il
cm
POLLUTNn
tOITROL
EQUIPIIEIIT
"'IU".~ SICO"'OAIIIY
COITRO
EfF.
,
.
ill
;5S!
lI!iI
g~~ ~c-
i!'coo
118 t;
~ ~ C08PLIAIICE
- : ALLOWABLE !t ~_LWlCI' 5TATU5
EST-TE EIISSIOtIS ~ SCllEOULE UPOATE EGULATIOI
ITOIIS PER YEARI ITOIIS PER YEAR' ~ 10 YR DAY I 10 YR
J6 11 !In 10 4142 Q 44 5" 41414. so !I SZ 53 5n551 51blS!liO 6\ 63 64 65 66 61 686910 1112
NAME OF PERSON
COMPLETING FORM
10
10
ID
;:: IfQ.
to..
\ 2 1 4 5 6 1 I , D II 12 11 14 15 6 11 11 It ZO 21 22 23 24 25 25 11 21 29
!l32!!!4
11415 161118 I! 10
A A 0 a 1
o 0 I
o I
A 0 0 I
o I
A
A
A
12145611' DII12111415611111'Z0212223242525112129
II 32 !! !4
]6 11 !In 10 4142 Q 44
464141
so !I SZ 53 54 55 51 51""<0110 61 62 63
6566616869101112
1 14 15 16 11 18 I! 10
A A 0 1
o 0 1
o I
A 0 0 I
o I
A
A
A
I 2 1 4 5 6 1 8 , 0 II IZ 11 14 15 6 11 18 I' ZO 21 22 23 24 25 25 11 21 29
31 32 !! !4 IS J6 !1 !I n 40 41 42 Q 44 5" 41 41 49 50 !I SZ 53 54 55 51 51blS!liO 61 62 63 64 65 66 61 68 69 10 1112
114151611181'10
A A 0 0 I
o 0 I
o 1
A 0 0 1
o I
A
A
A
1 2 1 4 56 1 II, 0 \ 11211 14 15 6 1111 "ZO 2122 24 25 251121 29 !l32!! !4 ]6 11 !In 404 I 42 Q 44 5 ,,' 41 41 49 50 !I SZ 53 54 55 51 51 1061 6263 6465 66 61 68 69 101112 114 15 161 118 I! 10
A A 0 0 I
o 0 1
1 A 0 I
A A 0 0 1
L...- A 0 I
. CARD CDLUIII71 lUST BE ALPHABET:C
Figure 6-1.
Trace materials/hazardous pollutant source coding form.
-------
Cards AOOl and A002 refer to trace-material emissions from the emission point
defined on card 2 of the point source coding form. Facility and emission point
identification numbers on cards AOOl and A002 must be identical to those on cards 2
through 6 on the original coding form. The format for the two cards AOOl and A002
is as follows:
Card AOOl - Emissions of Trace Materials or Hazardous Pollutants
------..------...- -.-.--..'---'-- - ...-.--.-- --..--__.___n---
Spaces
Format
Symbol
Description
Uni ts
1-13
(Same identification codes used on original point
source coding form)
14-15 XX Numerical Emission Point Identification
Number
16-17 . XX Numerical Year of Record
18-21 XXXX Numerical Code City Code
22-26 XXXXX Numerical Code Poll utant
27-29 XXX Numerical Code Primary Control Device
30-32 XXX Numerical Code Secondary Control Device
33-35 XX.X Numerical Collection Efficiency %
36-42 XXXX.XXX Numerical Emission Estimate T/yr
43 X Numerical Code Method of Estimating Emissions
44 X Numerical Code Emissions Included in
Emission Estimates Card 4
45 X Numerical Code Chemical Form of Emissions
46-52 XXXX.XXX Numerical Allowable Emissions T/yr
53 X Numerical Code Compliance Status
54-57 XXXX Numerical Code Compliance Schedule yr, mo
58-63 XXXXXX Numerical Code Compliance Status Update yr, mo, da
64-67 XXXX Numerical Code Regulation Code
73 X Numeri ca 1 Update
74-76 XXX Numeri ca 1 Sequence Number
77-80 AOOl Alphabetic and Card Identification Number
Numeric
81
-------
The detailed instructions that follow are to be used to complete card A001.
82
1.
Emission Point Identification Number: The point source identification
number must correspond to that on the original coding form.
2.
Year of Record: The last two digits of the calendar year that the data on
the card represent are entered here.
3.
City Code:
form.
The city code must be identical with that of the original coding
4.
Pollutant: This column specifies the contaminant to which all information
on each card AOOl refers. A five-digit code number is assigned to all
compounds known to exist in the ambi~nt atmosphere. The codes to be used
in these columns, listed in Appendix A, Section 6, are presently limited
to metallic pollutants and those declared to be hazardous pollutants.
This code presents a family-tree subcategorization of pollutants, an
arrangement that enables retrieval of data for a single pollutant or for
an entire class of pollutants. Furthermore, these codes are compatible with
the SAROAD system; thus, emissions can be correlated with ambient air
pollutant loadings of individual trace pollutants.
Primary and Secondary Control Device: Only those coding numbers specified
in the Control Equipment Identification Code (Appendix A, Section 3) should
be used. A code number should be entered for any installed pollution
control device that reduces the emission of the pollutant into the
atmosphere. Enter a zero in the columns when it is known that there is no
control device installed for reducing emissions of the pollutant. Leave
spaces blank when control status is unknown.
5.
6.
Collection Efficiency: The overall collection efficiency of the pollutant
for the entire process should be entered here. For example, assume that
the pollutant load entering the control equipment is the normal, uncontrolled
quantity for that process specified in card 6 of the point source coding
form. The quantity of pollutant actually discharged into the atmosphere
is the outlet loading. Estimate collection efficiency with these two values.
Enter a zero in the column if there is no effective removal efficiency;
leave the column blank if efficiency is unknown.
7.
Emission Estimate: The annual, controlled emissions of the pollutant in
tons per year should be entered here. Note that the positioning of the
decimal point allows emission quantities to be reported to the nearest 2
pounds of emission per year.
-------
8.
Method of Estimating Emissions:
specify the manner in which the
were determined.
The following codes should be used to
emissions reported in columns 36 through 42
Code
Description of Method
___H - . ---.-----
o
Not applicable (if emissions of the pollutant are
negligible)
Stack test results or other emission measurements
2
Material balance using engineering knowledge and
process expertise
3
Emissions calculated by means of emission factors
4
Guess
5
Emissions calculated using a special emission
factor that differs from the official EPA factor
9.
Emissions Included in Estimates on Card 4: Emissions of the trace material
specified in card AOOl may already have been included in card 4 of the
original coding form. For example, lead emissions might have been included
in estimates of particulate losses in columns 31 through 37 of card 4. This
column denotes whether or not the quantity of trace material discharged
from the source was included on card 4. Use the following codings or
leave blank if unknown.
Code
Descri.pti on
All emissions of trace material were included in
estimates reported on card 4.
2
About one-half of the trace-material emission was
probably reported on card 4.
3
None of the trace-material emission was reported in
the estimate reported on card 4.
10.
Chemical Form of Emissions: Trace materials can be emitted as particulates,
gases, or a combination of both. This column is used to estimate the
chemical state of the emissions. Use the following codes and leave blank if
unknown.
83
-------
11.
12.
13.
Spaces
1-21
22-72
73
74-76
77-80
Code
~~~.~Jp~j~!1
Emissions are primarily large settleable particulates
2
3
Emissions are primarily small suspended particulates
4
Emissions are primarily in the gaseous form
Emissions are probably a combination of particulates
and gases
Allowable Emissions and Compliance Status: The legal requirements placed
upon the source for reducing emissions of the trace material are specified
in columns 46 through 63. Follow the same procedure and use the same codes
as described for card 5 of the original coding form. Note that allowable
emissions can be reported to the nearest 2 pounds per year.
Regulation Code: The instructions and coding lists for making these
entries are found in Appendix A, Section 5.
Update, Sequence Number, and Card Identification Number:
as specified on the variable data form (Figure 6-1).
These entries are
Card A002 - Comments on Trace Materials or Hazardous Pollutants
-. --" ---
- .--..----. -- -W"'-".--.- ----
Format
Sy~~ol
Uni ts
De~.c!_i pti o.!!
(Same identification as card AOOl)
Comments,
alphabetic
or numeric
X Numerical Update
XXX Numeri ca 1 Sequence Number
A002 Alphabetic and Card Identification Number
Numeric
Because it is expected that there will be many unusual situations relating to
the emission of trace materials at a source, columns 22 through 72 in card A002 are
allowed for describing these factors. Information on this card will update
knowledge of trace material emissions. This knowledge, in turn, will be used to
improve the Emission Factor File and the Source Classification Code File.
84
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7.
DATA PRESENTATION
7.1 INTRODUCTION
The emission inventory system described in previous chapters has been especially
designed to facilitate grouping the point and area source data in multiple arrange-
ments. The three groupings listed below are basic "sorting" or indexing arrangements
for an emission inventory:
l.
2.
3.
Emissions
Emissions
Emissions
according to source category (i.e., by SCC or SIC
according to pollutant (e.g., mercury emissions).
within a specific geographical area.
code).
Any of these groupings can be used to display the emission data in a multitude
of ways suitable for a variety of uses. For example, emissions of hydrocarbons may
be automatically listed for a region, state, or county in order of relative contri-
butions from each point source.
Another combination of groupings could involve the tabulation of emissions of
all pollutants from pulp mills or chloroalkali plants in a region, state, or county.
As the coding forms described in Chapters 4 and 5 are expanded by users to collect
additional data for specialized uses, standard formats will be developed to summarize
the data. For example, if an annual operating permit is required for each point
source, then the agency may need a list revealing those permits about to expire.
Summaries and tabulations of emissions data may include:
1.
2.
Emission tabulation by source category, county, state, and region.
Stationary and mobile fuel balances within an area.
3.
4.
Solid waste balances.
Contribution of specific sources to emission totals.
5.
6.
Point source versus area source contribution.
Emission density maps for stationary and mobile source emissions arranged
by pollutant.
Installed pollution control equipment.
7.
8.
Indexes of process sources emitting specific pollutants.
Time fluctuations of emissions.
9.
85
-------
10.
Legal status of each source category to comply with air pollution control
requirements.
The inventory system described in this manual is primarily intended to accumu-
late data on pollutant emissions; however, the corresponding process data for each
source include extractable information on addresses, number of control devices, and
other plant factors. For example, names and addresses of all organizations emitting
asbestos (or any other pollutant) may be needed for a mailing list. In such a case
the following procedure would be used:
1.
2.
Select the appropriate SCC.
Instruct the computer to tabulate all sources with the given SCC inside the
study area.
3.
Instruct the system to print out columns 22 through 63 of card 1 of the
point source'coding form (names and addresses) for all sources.
The inventory system is designed to determine annual emissions of pollutants;
however, as the data base becomes more complete and emission factors become more
accurate, the need will arise to determine variance of emission rates with time.
This determination can easily be made by basing the automatic calculations of emissions
on production rate data (columns 18 through 30 of card 4 of the point source coding
form), thus allowing estimates of daily, weekly, and seasonal variations in emission
rates to be made.
Computer programs are now being written to retrieve the inventory data according
to the format described in Appendices 0 and E of the Federal Register dated August
14, 1971. This format summarizes county emissions by area/point sources and according
to specific groupings of source categories. When completed, such summaries will be
routinely produced by OAP, EPA for county, state, or regional areas. Moreover, as
requests for other summaries become more frequent, additional programs will be
developed by OAP.
It must be emphasized that the main advantages of a large, computerized data
base are:
1.
The availability
contained in the
power plants).
of relatively small quantities of detailed information
large data base (e.g., all data available on one or two
2.
The ability to obtain short summaries from the large data base.
The first advantage has been partially discussed in previous paragraphs and is
probably most valuable in those agency decisions that require detailed technical
86
-------
information; however, decisions on pollution control strategies are made on many
governmental levels, each of which requires data in varying degrees of detail.
Decisions at higher levels of management may require only a brief emission
summary from the control agency. Unfortunately, acquiring these numbers may be time-
consuming without computer access and a well-arranged data system. The inventory
system described in this manual has sufficient flexibility and capability to sub-
s tanti ally reduce manpower expenditures in answeri ng ques ti ons such as, "What are the
particulate emissions in this Congressional District and where do they come from?"
Such requests can often be easily interpreted by a pictorial presentation of emissions
data. For example, "pie" charts comparing the contributions of source categories to
total emissions might be more easily understood by the general public than numerical
tables.
Figure 7-1 demonstrates the use of the pie chart to display concisely a large
amount of information that would occupy several pages of tables in a report. Pie
charts are easily constructed and can simplify comparison of data on various emissions
and their sources. Because the charts compare emissions on a relative basis in per-
centages and fractions of total emissions, the total emissions should also be listed.
With the totals and percentages, calculations of quantities of emissions are easily
made. Furthermore, visual comparison of the relative quantities of emissions is
possible if the total area of each chart corresponds to the quantity of each pollutant.
A series of charts would then contain "pies" of different sizes according to the
varying quantities of emission.
Emission density maps offer one of the best methods of revealing (1) source
contributions by geographical area, and (2) concentrations of emitted pollutants by
geographical area. Because the inventory techniques described in this manual allow
emissions to be collected on a countywide basis, pollutant density maps can be con-
structed automatically with a computer plotter. Moreover, techniques for apportioning
the countywide data to smaller areas, thus showing more clearly the emission density
profile of each county, have been developed and are based on "gridding." The county
emissions apportioned to each grid are then used to construct an emission density
map for the county.
A map of the study area is divided into a grid pattern using the UTM coordinate
system as shown in Figure 7-2. This grid is used as the basic unit of area in
summarizing the emissions of each pollutant from all sources. The rest of this
chapter explains the procedure for apportioning county emission data to grids.
7.2 APPORTIONING POPULATION DATA TO GRIDS
Information on population
is available for 1970 from the
provide the most useful data:
and housing distribution in counties by census tracts
U. S. Bureau of the Census. The following documents
87
-------
NITROGEN OXIDES
HYDROCARBONS
TOTAL EMISSIONS
PARTICULATES 40473 TONS
SULFUR DIOXIDE 4064 TONS
CARBON MONOXIDE 161033 TONS
HYDROCARBONS 34589 TONS
NITROGEN OXIDES 63773 TONS
CARBON MONOXIDE
SULFUR DIOXIDE
PARTICULATES
Figure 7-1. Use of pie charts to illustrate relative distribution of pollutant emissions from various sources.
88
-------
430
\ -1'9900000
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540000
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-- ~
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440 ?OO I; '---. 5800
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I CATAWBA CO ) ISBURY '-..
~ ,;- ,,-.1--, "~- ,, '\ I:~" " "
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. LINCOLN CO
\ ), lAaARRUS CO /
I '~------ M!CKlENBURG CO[ \ /
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000) n!VIlAND CO ''. 5~ CONCORD
" GAIT CO \ /
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/ <) ( GA TONIA \ .1
II 0 \0 \1 (1 " ~ /
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0 " \11'~ U " .. 1 '), CHARLOTTE" "",/
I NORTH CAROLINA I ?
---- -"--,-., r--'/--"-- '\ r\ '(; / "i.,-_.'\....J"". fJ
-- /
SOUTH CAROLINA 1\ ( " " " " 38fOOO
if /
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Figure 7-2. Grid coordinate system example.
89
-------
General Characteristics for States, Cities, and Counties.l
Contains statistics on number of units at each address, number of rooms,
kitchen facilities, commercial establishment on property, and vacancy status
for all places surveyed; data are broken down by states, counties, SMSA's,
urbanized areas, and places with 1,000 inhabitants or more.
Detailed Characteristics for States, Cities, and Counties.2
Contains selected data on number of units at each address, number of rooms,
heating equipment, fuel heating, cooking and water heating, appliances,
automobiles, and data available for all or some of the following areas:
states, counties, SMSA's, urbanized areas, and places with 2,500 inhabitants
or more.
Census Tract Reports.3
Contains one report for each SMSA, showing data for most of the population
and housing subjects included in the 1970 census. Some tables are based on
100 percent tabulation, others on sample tabulation.
Number of Inhabitants.4
Contains final official population counts for states, counties (by
urban-rural residence), SMSA's, urbanized areas, minor civil divisions,
county divisions, all incorporated places, and unincorporated places with
1,000 inhabitants or more.
Before obtaining any of the above documents, it is suggested that the nearest
U. S. Department of Commerce field office listed below be contacted first to determine
what written information is currently available for the study area. If highly de-
tailed information is sought, the field office can offer assistance in obtaining the
information from computer tape, if available. A more complete breakdown of population
and housing data might be available from local planning agencies or the Chamber of
Commerce.
U. S. DEPARTMENT OF COMMERCE FIELD OFFICES
Albuquerque, N. Mex. 87101, U. S. Courthouse
Anchorage, Alaska 99501, 412 Hill Building
Atlanta, Ga. 30303, 75 Forsyth St., N. W.
Baltimore, Md. 21202, U. S. Customhouse
Birmingham, Ala. 35205, 907 Sough 20th St.
Boston, Mass. 02203, John F. Kennedy Fed. Bldg.
Buffalo, N. Y. 14203, 117 Ellicott St.
Charleston, S.
Charleston, W.
Cheyenne, Wyo.
C. 29403, 334 Meeting St.
Va. 25301,500 Quarrier St.
82001, 2120 Capitol Ave.
90
-------
Chicago, Ill. 60604, 219 South Dearborn St.
Cincinnati, Ohio 45202, 550 Main St.
Cleveland, Ohio 44114, 666 Euclid Ave.
Dallas, Tex. 75202, 1114 Commerce St.
Denver, Colo. 80202, Room 161, New Customhouse
Des Moines, Iowa 50309, 210 Walnut St.
Detroit, Mich. 48226, Federal Bldg.
Greensboro, N. C. 27402, Federal Bldg.
Hartford, Conn. 06103, 450 Main St.
Honolulu, Hawaii 96813, 1015 Bishop St.
Houston, Tex. 77002, 515 Rusk Ave.
Jacksonville, Fla. 32202, 400 West Bay St.
Kansas City, Moo. 64106, 601 East 12th St.
Los Angeles, Calif. 90024, 11000 Wilshire Blvd.
Memphis, Tenn. 38103, 147 Jefferson Ave.
Miami, Fla. 33130,25 West Flagler St.
Milwaukee, Wis. 53203, 238 West Wisconsin Ave.
Minneapolis, Minn. 55401, 110 South Forth St.
New Orleans, La. 70130, 610 South St.
New York, N. Y. 10007, 26 Federal Plaza, Foley Sq.
Philadelphia, Pa. 19107, 1015 Chestnut St.
Phoenix, Ariz. 85025, 230 North First Ave.
Pittsburgh, Pa. 15222, 1000 Liberty Ave.
Portland, Oreg. 97204, 520 S. W. Morrison St.
Reno, Nev. 89502, 300 Booth St.
Richmond, Va. 23240, 400 North 8th St.
St. Louis, Mo. 63103, 1520 Market St.
Salt Lake City, Utah 84111, 125 South State St.
San Francisco, Calif. 94102, 450 Golden Gate Ave.
San Juan, P. R. 00902, Post Office Bldg.
Savannah, Ga. 31402, 125-29 Bull St.
Seattle, Washington 98104, 909 First Ave.
Once the census tract map has been obtained, an overlay for the grid system, as
shown for one county in Figure 7-3 can be used. Data for the more densely populated
shaded portion would be given on a similar map showing only the tracts in the shaded
portion. Assuming that the population and housing are distributed uniformly over each
91
-------
7
31
32
36
42
43
!
63
Figure 7-3. UlM grid overlay of census tract map of one county.
92
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census tract, it is now possible to estimate the population density for each grid
zone. Populations for each grid zone are computed by estimating the fraction of a
census tract in a grid zone, multiplying this fraction by the total population of
the census tract, and summing the contributions of each census tract within the grid
zone. This procedure is now being computerized by GAP, EPA. The computer program
divides each fraction of a census tract into appropriate grids before multiplying the
fractions by the total population of the census tract. This procedure ensures that
all the population in the census tract is apportioned onto the grids. After
apportioning, the populations in all grids in the study area are checked to ensure
that the sum is identical to the total population of all census tracts in the study
area.
Figure 7-4 shows the grid system selected for a three-county example study area.
Using the procedure described above, the population density map of Figure 7-5 has been
constructed for this area by dividing the population of each grid zone by the area of
that grid zone. Data for housing and types of space heating are distributed in the
same way as those for population.
7.3 APPORTIONING TRANSPORTATION EMISSIONS TO GRIDS
To properly assess the impact of emissions of transportation sources, the
emissions must be apportioned onto the grids. Apportioning is done on the basis of
vehicle miles traveled in each grid for motor vehicles, miles of railroad track in
each grid for railroads, and ship traffic data for vessels. Aircraft, considered
as area sources, are applied to the grids at airport locations.
7.3.1 Apportioning Vehicle Miles Traveled and Vehicle Emissions to Grids
If possible, comprehensive traffic-count maps from local and state highway de-
partments and metropolitan planning agencies should be obtained. These maps should,
as least, show traffic counts (in units of vehicles per day) for all expressways,
major arterial roads of major cities, and downtown streets of major cities to
ensure that a substantial portion of the commuting traffic and through traffic can be
accurately proportioned. The grid zones are delineated on these maps in the same
manner as was done for census tract maps. The number of vehicle miles traveled on a
road in a grid zone is obtained by measuring the miles of road between two consecutive
traffic counts and multiplying this distance by the numerical average of the two
counts. When measuring the vehicle miles, special note should be taken of the number
of vehicle miles traveled per grid on roads where diesel-powered vehicles would most
likely travel: expressway, arterial, and downtown roads. These totals will be
required later in the methodology.
93
-------
i 'Wi -------,...,,);)
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i ,)1 2 :1 \..
i LAKE /,
I,., OKEECHOBEE .; (,\
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I 12 I J
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PALM BEACH COUNTY
2930°°0
23".
" 2920 UOO
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Figure 7-4. Grid coordinate system for example study area.5
65
5 0
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miles
20
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25
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5 10 15
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20 25 30
.~
ki lometers
94
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POPULA TlON,
persons/mi2
o 0 - 50
[ill] 50 - 100
fEJ 100 - 1,000
...~:::.
. 1,000 - 3,000
m 3,000 - 5,000
IIJ 5,000 - 12,000
Rgure 7-5.
,16
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COUNTY
12
18
2920000
25
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BROWARD COUNTY
27
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DADE CD'fIIIJ~::::::'~~f M'
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EVERGLADES 5 0 .10 15 20 25
NA TIONAL PARK I..... ' , , , I
miles
5 0 5 10 15 20 25 30
~ ' , , , L-.J
ki lorn.,.rs
5
Population densities for example study area.
95
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It is very unlikely that the traffic-count maps that are used to measure vehicle
miles will be of the same year as the intended emission inventory; these maps will,
therefore, require updating. This updating should reflect the total increase in
gasoline-powered and diesel-powered motor vehicle activity in the study area since
the traffic-count map was made. Diesel vehicle miles and gasoline vehicle miles
should be updated separately by means of the fuel consumption totals for each.
Before the traffic-count totals can be updated or the diesel-powered vehicle
miles proportioned, the number of diesel-powered vehicle miles included in the total
vehicle miles on the traffic-count maps must be determined. The diesel-powered vehi-
cle miles can be estimated by multiplying the percent of the total vehicle miles in
the study area that are deisel-powered by the vehicle miles of each grid that were
measured from roads having diesel traffic. The diesel percentages should also take
the year of the traffic survey into consideration. Remaining diesel-powered vehicle
miles should then be apportioned to grid zones on the basis of those diesel-powered
vehicle miles already distributed by the traffic-count maps.
The last step before calculating emissions is to distribute the gasoline-powered
vehicle miles that remain after the traffic-count maps have been used. These un-
distributed vehicle miles may be apportioned on the basis of population because
most remaining motor vehicle activity would occur in residential areas.
In many cases vehicle counts will be unavailable. In such a situation, the
grid zones must be laid out on a road map of the study area. The total miles of
road in each grid zone are calculated on the basis of the following street classes:
major, industrial, commercial, residential, and other; the average vehicle counts as
given in Table 7-1 can then be applied in determining the vehicle miles for the grid
zone.
Table 7-1. AVERAGE VEHICLE COUNTS BY LAND USE 6
(vehicles/day)
Street class
Density
Major
Industrial
Commercial
Residential
Other
17,000
14,000
10,000
1,000
1,000
After the vehicle miles have been established for each zone, it will be necessary
to estimate the emissions for the zones based on the vehicle miles. The following
factors must be taken into account in computing the emissions: sources of pollutants
96
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within the vehicle, degree of emissions control, and average speed for each type of
road in the zone.
Pollutants emanate from the exhaust system, engine crankcase blowby, carburetor,
and fuel tank in an uncontrolled gasoline-powered vehicle. The exhaust system
emissions consist of all the products of fuel combustion; the crankcase emissions
are hydrocarbons that escape from the engine cylinders. The emissions from the
carburetor and fuel tank are evaporative hydrocarbons. Before the proper emission
factors can be applied, an average speed for each type of road must be assumed. These
average speeds are often available from local traffic information; if not, the
average speeds shown in Table 7-2 can be used.
AVERAGE VEHICLE SPEEDS BY ROUTE CLASS 7
(mi/hr)
..==1------ Average speed
J ~~
45
expressway -- 50 and greater
For each grid an estimate should be made of total vehicle miles traveled by
diesel vehicles. An estimate of these miles can be made from local traffic data and
subtracted from the total vehicle miles for a given grid. If such data are not
available, 2 percent of the total vehicle miles for an area may be considered to be
traveled by diesel vehicles. When estimating diesel vehicle miles, one should be
careful not to estimate diesel miles in residential areas and on roads that are re-
stricted to automobiles, such as roads that specify "no through trucks."
Table 7-2.
Route class
Urban streets
Suburban roads
Rural roads
Limited-access
The following example illustrates how emissions from motor vehicles in one
grid zone are calculated.
Example 7-1.
Calculation of Motor Vehicle Emissions for a Grid Zone.
Given:
I.
By planimeter measurement, the grid
2 miles of residential roads
1 mile of arterial roads
1 mile of business roads
zone has:
II.
Vehicle counts for the roads in the grid zones are broken down in the
following ways:
Residential routes = 1,000 vehicles/day
Arterial routes = 10,000 vehicles/day
Business routes = 20,000 vehicles/day
97
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III. Because no data are available on the percentage of vehicles that are diesel,
it will be assumed that 2.5 percent of the vehicles on business routes are
diesel-powered, and that residential and arterial routes have no diesel
traffic.
IV. Emission factors8 are given in grams per vehicle mile for gasoline-powered
vehicles and in pounds per 1000 gallons of diesel fuel for diesel-powered
vehicles. It will be assumed that diesel-powered vehicles get 5.1 miles
per gallon of diesel fuel.
Calculations:
1. Vehicle Miles Traveled (VMT):
Residential VMT = (1,000 ve~icles) (2 miles) = 2,000 dVMT
ay ay
Arterial VMT = (10 000 vehicles) (1 mile) = 10 000 VMT
, day , day
Business VMT = (20 000 vehicles) (1 mile) = 20 000 ~MT
'day , aay
Gasoline VMT = (20 000 ~MT) (0 975) = 19 500 gasoline VMT
, aay' , day
Diesel VMT = (20 000 VMT) (0.025) = 500 diesel VMT
, day day
II. Gallons of diesel fuel:
(500 diesel VMT)
day
(miles )
5.1 gal diesel fuel
= 100 gal diesel fuel/day
III. Emissions:
A. S02
VMT 1 1 b 1 b
Residential = (2000 day) (0.18 gal/VMT) (454 gal) = 0.8 day
. VMT 1 1 b 1 b
Arterlal = (10,000 day) (0.18 gal/VMT) (454 gal) = 4.0 day
Business = (19,500 ~~~) (0.18 gal/VMT) (l5lbgal) = 7.7 d~~
Diesel = (100 gal diesel fuel) ( 451b ) = 4 5 ~
day 1000 gal diesel fuel' day
Total S02 = 17 ~
day
B. Particulate
Residential = (10,000 ~~~) (0.30 gal/VMT) (l5lbgal) = 1.3 d~~
. VMT 1 1 b 1 b
Arterlal = (10,000 day) (0.30 gal/VMT) (454 gal) = 6.6 day
98
-------
VMT 1 lb lb
Business = (19,500 day) (0.30 gal/VMT) (454 gal) = 12.9 day
. - (100 gal diesel fuel) ( 13 lb ) = 1 3 ~
Dlesel - day 1000 gal diesel fuel' day
Total Particulates = 22.1 d~~
C. NOx
VMT 1 lb lb
Residential = (2,000 day) (9 gal/VMT) (454 gal) = 40 day
VMT 1 lb lb
Arterial = (10,000 day) (9 gal/VMT) (454 gal) = 198 day
VMT 1 lb lb
Business = (19,500 day) (9 gal/VMT) (454 gal) = 387 day
Diesel = (100 gal ~:~sel fuel) (1000 ga13~~e~~1 fuel) = 37 d~~
Total NOx = 662 d~~
D. CO
Residential = (2000 ~~;) (95 gal/VMT) (l5lbgal) (1.2)* = 502 d~~
Arterial = (10,000 ~~;) (95 gal/VMT) (~5~bgal) (1.0)* = 2092 d~~
. VMT 1 lb lb
BUSlness = (19,500 day) (95 gal/VMT) (454 gal) (2.1)* = 8570 day
Diesel = (100 gal ~~~sel fuel) (1000 gal ~~~s~~ fuel) = 22 d~~
lb
Total CO = 11,186 day
E. HC
Residential
VMT) ( ) (1 lb ) ( )* - lb
Exhaust = (2000 day 12 gal/VMT 454 gal 1.15 - 61 day
VMT 1 lb lb
Crankcase = (2000 day) (0.9 gal/VMT) (454 gal) = 4 day
VMT 1 lb lb
Evaporative = (2000 day)(2.7 gal/VMT) (454 gal) = 12 day
Total Residential HC = 77 ~
day
Arterial
Exhaust = (10,000 ~~;) (12 gal/VMT) (l5lbgal) (1.0)* = 264 d~~
* Average vehicle speed adjustment factor. Adjustments of the emission factors for
CO and HC are necessary because the emissions of these pollutants vary considerably
with vehicle speed.8
99
-------
Crankcase = (10,000 ~~~) (0.9 gal/VMT) (151bgal) = 20 d~~
VMT 1 lb lb
Evaporative = (10,000 day) (2.7 gal/VMT) (454 gal) = 60 day
1b
Total Arterial HC = 344 day
Business
Exhaust = (19,500 ~~~) (12 gal/VMT) (151bgal) (1.75)* = 902 d~~
Crankcase = (19,500 ~:;) (0.9 gal/VMT) (151bgal) = 39 d~~
VMT 1 1 b 1 b
Evaporative = (19,500 day) (2.7 ga1/VMT) (454 gal) = 116 day
Total Business HC = 1 057 ~
, day
Diesel
(100 gal diesel
37 lb
fuel) (1000 gal diesel fuel)
Total HC = 1,482 dlb
ay
lb
= 3.7 day
Whenever a large number of grid zones are involved, the above procedure should
be computerized. Calculation of the vehicle miles by category in each grid remains
a manual operation. The estimation of vehicle emissions based on vehicle miles
traveled is very time-consuming. Data are often not available, and available data
are often out of date. The calculation of emissions of those pollutants that are
not affected by speed is not easy. Despite the above disadvantages, the method based
on vehicle miles is the best available at present.
7.3.2 Apportioning Railroad Track and Railroad Emissions to Grids
Railroad emissions in most areas do not contribute significantly to the total
emissions from mobile sources. The procedure outlined here is very general and
easily carried out. If more detailed information is desired for grids containing
extensive track facilities, such data can often be obtained locally by contacting the
stationmaster or other railroad officials. They may be able to provide such infor-
mation as the number of trains per day, number of switch engines in the yard, hourly
fuel consumption rates, and number of operating days per year. In most cases the
procedure outlined below is sufficient to distribute railroad emissions among the grids.
* Average vehicle speed adjustment factor. Adjustments of the emission factors for
CO and HC are necessary because the emissions of these pollutants vary considerably
with vehicle speed.8
100
-------
If possible, fuel consumption data should be obtained from individual railroad
companies that operate in the study area. In some cases, the consumption may be
broken down by stations within the study area. If this is not possible, information
on annual consumption of railroad diesel fuel by states is available from the Bureau
of Mi nes ? The state fuel total is di s trubuted into counti es, based on mi 1 es of
track per county. Using listed emission factors?' the emissions from railroad fuel
use may be estimated for each county.
In order to distribute the county emissions onto a grid system, the miles of
railroad tracks in each grid may be measured from USGS topographic or other
appropriate maps, and the pollutants may be apportioned according to the ratio of
track miles in a given grid to the summation of total track miles in the county. If
a grid contains segments of more than one county, the above procedure should be
followed for each county, and the combined emissions should be reported for the
grid. Yard operations must be distributed separately from information on fuel con-
sumption by switch engines.
7.3.3 Apportioning Vessel Emissions to Grids
Emissions from this source category are best estimated by obtaining from local
shipping and tugboat companies the quantity of fuel consumed by their vessels while
in the study area. Because many companies might not know how much fuel is being
burned, it might be advisable in those study areas with substantial vessel activity
to survey a representative number of vessels.
If such a survey is not feasible, and if local companies cannot estimate the
quantity of fuel being used, the total vessel operations in the area should be deter-
mined. These data are available from officials of shipping lines, harbor authorities,
and Waterborne Commerce of the United States.10
Air pollutant emissions resulting from vessel operations may be divided into two
groups--emissions that occur when the ship is under w~y and emissions that occur when
the ship is docked or in berth. Excluding the Great Lakes, vessel traffic, oil-
fired vessels account for most of the shipping in the United States. When fuel data
for ships are not available, rough estimates can be made from the total vessel
operations in the study area. For underway emissions it can be assumed that a ship
burns from 19 to 42 gallons of oil per mile (Chapter 5). At dockside, ships may burn
from 660 to 1900 gallons per day maintaining utilities aboard ship--lights, heat,
pumps, refrigeration, ventilation, etc. (Chapter 5). Furthermore, it can be assumed
that a ship remains at dockside from 2 to 3 days. The miles of ship channels in each
grid can be calculated from maps. The miles of docks can be apportioned to grids on
the basis of location from map information or at least by visual observation of the
dock area. Total dock area can be listed by percentages in grid zones, and miles of
101
-------
channels can be apportioned by percentages in each grid zone. Because the docking
area may be spread throughout the study zone, it may be desirable to establish an
average distance traveled by ships when under way in the study area. Then, assuming
that all entering ships also leave, the estimated underway mileage must be doubled
to account for underway emissions produced when entering and leaving port. This
doubled mileage figure is then multiplied by the number of ships entering the port
and by fuel consumption per mile to get the amount of oil burned per year by vessels
under way.
The amount of oil burned at dockside is estimated by multiplying the average
number of days in port (3 days) by the number of ships entering the port per year and
by multiplying the result by the average fuel consumption per day while the ships
are in port (for example, 1600 gallons per day is an average for the combined total
of motorships and steamships). This computation gives the amount of oil burned in
port per year. By the use of emission factors, total emissions from vessels under
way and at dockside can be determined. These totals are then apportioned among
the grids on the basis of the percentages of dock area and channel mileage existing
in each grid zone.
Admittedly this method gives a rough estimate of emissions. It ignores tugboat
operations, emissions from vessels maneuvering at dockside, differences in ship size,
etc., but in many instances the emissions from vessels will be a negligible contri-
bution to the total emissions. If vessel movement is a significant activity in the
study area, better data will be available, and better estimates of emissions and their
distribution by grid zone can be made.
7.4 APPORTIONING OF LOSSES FROM GASOLINE MARKETING TO GRIDS
Hydrocarbon evaporative losses for the study area are calculated with emission
factors. Because many hours are required to locate all service stations and place
them onto grids, an acceptable practice is to apportion the estimated emissions from
service station operations on the basis of either population or vehicle miles. The
gallonage estimated for motor vehicle use should be the basis for determining evap-
orative losses.
7.5 APPORTIONING OF SOLID WASTE DISPOSAL TO GRIDS
Burning in dumps and in some incinerators is considered a point source emission
and is listed according to the UTM coordinates of the source. Emissions that must
be apportioned as area sources include on-site incineration and on-site open burning.
The grids in the county are rated on the basis of land-use, population density, and
industrial and commercial development. The rating system could be established by
estimating the percentage of each grid that is devoted to residential, commercial,
and industrial use. The percentages for each category are totaled for the county,
102
-------
and the ratio of the percentage in the grid to the county total is used to distribute
the emissions for each appropriate source category. Source information gathered
according to the methods of Chapter 5 gives the percentage of solid waste that is
industrial, commercial, or residential in origin. Once the quantities of solid
waste in each category have been allocated to grids, emission factors can be applied
to the solid waste disposal methods to determine quantities of pollutants released.
7.6 APPORTIONING OF RESIDENTIAL FUEl SOURCES TO GRIDS
Residential sources are considered to be area sources. If large apartment com-
plexes use oil or coal as a fuel, it will be necessary to survey and pinpoint these
complexes for more accurate pollutant ca"lculations. These large sources are then
easily located on the grid system as point sources; the area source classification
remains. After residential fuel consumption data are obtained, it is necessary to ob-
tain aid from local officials in apportioning these oil, coal, and gas data to the
correct areas. When this type of information is not available, it is necessary to
estimate the number of dwelling units in d given census tract that is using each type
of fuel, based on the same percentage as the county or SMSA. Further apportioning
will be necessary to reduce these data to a grid basis. References for obtaining
countywide data on space heating are given in Section 7.2.
Example 7-2.
to a Grid.
Estimation of a Census Tract's Contribution of Space Heating Units
Given:
(1970 Census Data)
I. Of 100,000 dwelling units (d. u.) in County A
10,000 d. u. use coal,
40,000 d. u. use oil,
35,000 d. u. use gas, and
15,000 d. u. use electricity.
Census tract 1 (CT-1) in County A has 5000 dwelling units.
II.
I I I.
It is estimated from a grid overlay of the County A census tract map that
20 percent (0.2) of CT-l is in grid 4.
Calculations:
1.
Electrical space heating is not considered an area source because the power-
generating facility will be a point source of emissions at the location of
the plant.
II.
Number of space heating units in CT-l that are in grid 4:
1 (lO,OOOd.u.usecoal) (5000d . )()
Coa: 100,000 d. u. in county' . u. ln CT-l 0.2
use coal
= 1 00 d. u.
103
-------
Oil:
( 40.000 d. u. use oil) (5.000 d. u. in CT-l) (0.2)
100.000 d. u. in county
use oil
=
400 d. u.
Gas:
( 35.000 d. u. ~~ec~~~ty) (5.000 d. u. in CT-l) (0.2)
100.000 d. u.
use gas
350 d. u.
In many instances it will be necessary to update census tract data before they
can be apportioned onto the grids. City and county planning commissions usually have
recent population and dwelling unit estimates by census tract. Below is a general
technique for updating residential fuel usage (including space. water. heating.
cooking. etc.) by census tract.
The following data must be available (either published or estimated):
1970 d. u. by census tract
1970 d. u. using coal for space heating by census tract
1970 d. u. using oil for space heating by census tract
1970 d. u. using gas for space heating by census tract
197X d. u. by census tract (estimated)
The percentage of units built since 1970 that use oil. gas, or electricity for
heating must be determined (usually from local gas companies). Very few homes
built since 1970 use coal as a heating fuel. Information is also needed on the per-
centage of homes that have converted fuel types since 1970. These conversions are
usually from coal to gas. oil. or electricity. This information is also usually
available from local utility companies. If there has been a decrease in the
number of dwelling units for a given census tract. then a corresponding decrease
should be made in the number of units using coal or oi1. This adjustment is under-
standable because most of the razed units are older buildings. which tend to burn
coal and oil.
It is assumed. unless known data indicate otherwise, that residential use of
coal is for space-heating purposes only. Some oil and large amounts of gas are used
for water heating and cooking. along with the normal usage for space heating.
From past experience. it has been found that 250 gallons of oil per year is
consumed per water heating and cooking unit. and. unless known otherwise. this oil
can be considered distillate oil. Using Census Bureau data on water heating and
cooking units. oil usage for this purpose can be determined and then distributed in
proportion to the number of dwelling units using oil for heating.
The natural gas usage for water heating and cooking for a county is the difference
between the quantity supplied by the natural gas companies and that calculated for
space heating using the dwelling unit data. The differential amount of gas is
104
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allocated to emission zones in proportion to the number of dwelling units using gas
for heating.
Anthracite and bituminous coal, distillate and residual oil, natural gas,
liquefied petroleum gas, and wood are used residentially. As previously shown in
Chapter 5, anthracite and bituminous coal used commercially and residentially can be
estimated for a given county.
Fuel requirements for space heating are a product of four factors--number of
dwelling units, fuel consumption per dwelling unit based on degree-days, number of.
degree-days, and a factor that corrects for the average number of rooms in a house.
Fuel consumption is based on the average of five rooms per dwelling. A correction
factor is necessary if the average dwelling in the county does not have five rooms.
Table 7-3 gives fuel consumption data for a five-room residence.
Table 7-3. AVERAGE FUEL CONSUMPTION
FOR A FIVE-ROOM RESIDENCE 11
~- . .. -- ..--------.--..----------
Fuel
Consumption
---
22.5 ft3/dwelling unit-degree-day
0.18 gallon/dwelling unit-degree-day
0.00012 ton/dwelling unit-degree-day
Natura 1 gas
Fue 1 oil
Coal
------ .-..-
The following example illustrates the procedures used to update and estimate
residential fuel consumption.
Example 7-3.
Updating and Estimating Residential Fuel Consumption by Grid.
Given:
1.
1970 county and census-tract data have been distributed onto grids. The
following data are available for one grid in the county:
1970 population
1970 dwelling units (d. u.)
1970 d. u. using coal
1970 d. u. using oil
1970 d. u. using gas
1970 d. u. using electricity
County A
300,000
100,000
10,000
40,000
35,000
15,000
Grid 4
10,000
4,000
500
1,300
1,800
400
105
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III.
III.
II.
Local planning commission population and housing estimates for County A in
1971 are as follows:
1971 population 315,000
1971 dwelling units 105,000
Five percent of County A dwelling units are in structures of 50 or more
units. Assume that this holds true for grid 4 and that residual fuel
oil is used in these structures for space heating.
Since 1970, according to the local gas company:
1.
2.
3.
1. Ten percent of the dwelling units using coal have switched to gas.
2. Five percent of the dwelling units using oil have switched to gas.
3. Eighty percent of the homes built since 1970 are heated with gas and 20
percent with electricity.
4. Total residential gas sales for 1971 are 9.1 x 109 ft3.
IV. Other:
In 1971, 20 percent of coal burned was anthracite and 80 percent was
bituminous.
2. 1971 degree-days (Oday) = 5.000 °day.
3. Average number of rooms per dwelling unit = 5.5 rooms.
4. Dwelling units in County A using oil for water heating =
1.
21,000 d. u.
Calculations:
I.
Update grid population from 1970 to 1971.
(~6~:~~~) (10,000 pop.) = 10,500 population in grid 4
II.
Update grid housing data from 1970 to 1971.
(10,500) ( )
10,000 4,000 d. u. = 4,200 d. u. in grid 4
Estimate 1971 coal usage for space heating in grid 4
A.
Dwelling units:
500 - (0.1) (500) = 450 d. u. using coal.
B.
Tons:
(450 d. u.) (0'00J~u:/~Ja;~a1) (5,000 °day) (555)* = 2970 tons
1. Anthracite coal burned = (2,970 tons) (0.2) = 594 tons
2. Bituminous coal burned = (2,970 tons - 594 tons) = 2376 tons
* This is the needed correction factor for the average number of rooms per dwelling
unit when using Table 7-3.
106
-------
IV. Estimate 1971 oil usage for space heating and water heating in grid 4.
A. Dwelling units:
40,000 - (0.05) (40,000) = 38,000 d. u. using oil in County A
1,300 - (0.05) (1,300) = 1,235 d. u. using oil in grid 4
B. Gallons:
(1,235 d. u.) (0.18 g~~~~~~d~~l) (5,000 °day) (555)* = 1,222,500 gallons fuel
oil used in grid 4.
1. Residual: All used in space heating of structures of 50 units or more.
(1,222,500 gallons fuel oil) (0.05) = 61,125 gallons residual fuel oil
used in grid 4
2. Distillate, space heating:
1,222,500 gallons fuel oil - 61,125 gallons residual = 1,161,375 gallons
distillate fuel oil used for space heating in grid 4
3. Distillate, water heating:
(1,235 d. u.) (20,000 d. u.) (250 gallons oil) = 162,500 gallons dis-
30,000 d. u. d. u.
tillate fuel oil used for water heating in grid 4.
V. Estimate 1971 gas usage for space heating and other purposes (water heating,
cooking, etc.).
A. Dwelling units:
The following formula is used in updating:
1970 + Converted + Converted + New d. u. = 1971 d. u.
gas users from coal from oil using gas using gas
County: 35,000 + 1,000 + 2,000 + 5,000 (0.80) = 42,000 d. u.
Grid: 1,800 + 50 + 75 + 200 (0.80) = 2,085 d. u.
B. Cubic feet of gas used:
1. Space heating: 3
County: (42,000 d.u.) (22.5 d.~~/Oday) (5,000 °day) (~)* =
5.2 x 109 ft3 gas use~ in County A for space heating
Grid: (2,085 d.u.) (22.5 d.~~/Oday) (5,000 °day) (555)* =
258 x 106 ft3 gas used in grid 4 for space heating
2. Total gas used in grid 4:
9 3
(~:~ ~ ~~9 ~~3) (258 x 106 ft3) = 451 x 106 ft3 gas used in grid 4, total
3. Gas used in grid 4 for other purposes:
451 x 106 ft3 - 258 x 106 ft3 = 193 x 106 ft3 gas used in grid 4 for
other purposes
* This is the needed correction factor for the average number of rooms per dwelling
unit when using Table 7-3.
107
-------
If the above fuel totals for space heating, water heating, cooking, etc. are
used, emissions from residential sources can be apportioned onto grids. If large
individual sources can be identified, their fuel usage should be subtracted from the
grid or census tract total to give the area source residential fuel.
7.7 APPORTIONING OF COMMERCIAL AND INSTITUTIONAL SOURCES TO GRIDS
Large commercial and institutional sources should be surveyed by questionnaire
or personal contact and classified as point sources. The fuel used by these sources
can be subtracted from the total estimates of commercial and institutional fuel for
the county. The remaining fuel for commercial and institutional sources can be
apportioned to the grid zones based on a rating system that is, appropriate for the
county under consideration. Apportioning can be established through knowledge of the
area, land-use maps, contacts with local officials, and USGS topographical maps.
7.8 APPORTIONING OF MISCEllANEOUS SOURCES TO GRIDS
The occurrences of construction and demolition, forest fires, brush burning,
agricultural burning, orchard heating operations, plowing and tilling, coal refuse
fires, and debris burning are usually known if such activities are significant in the
study area. These activities can be classified as point sources and apportioned onto
grids on this basis. Emission estimates may be difficult, however, in situations
where emission factors are unavailable. For example, although adequate emission
factors for dust emissions caused by plowing and till'ing are presently unavailable,
these operations may be a significant source of particulates during dry, windy periods.
Road dust is treated as an area source that can be distributed if data on vehicle
miles traveled on dirt roads are available. The quantity of dust created, which may
be great in some areas and of little concern in others, will vary from season to
season. The dust generated per mile traveled must be estimated or determined for
each area of interest.
Industrial solvent losses are considered point source emissions
tioned accordingly. Commercial dry cleaning solvent losses are also
as point source emissions.
and are appor-
best apportioned
7.9 APPORTIONING OF POINT SOURCES TO GRIDS
Point source emissions are apportioned onto the grid zones using the UTM coor-
dinates of the point source, as shown in Figure 7-6.
7.10 TOTALING GRIDDED EMISSIONS
For each grid the various point and area sources are now apportioned. For each
surveyed pollutant in the grids, totals are summarized for annual average emissions
and, generally, for summer and winter emissions also. This information can then be
108
-------
------______r" - 'II
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, 2950000
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.
.
8
.
.
.
PALM BEACH COUNTY
12
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.
. INDUSTRY
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o INCINERATOR
A AIRPORT
.. COMMERCIAL
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Figure 7-6. Point source locations for example study area. 5
13
2930000
I 2920000
o
;;:=
~
.....
(,J
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(,J
;:::
;;:=
'<:
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t
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5 0 5 10 15 20 25 30
It. ' , , , , , I
kilomefers
109
-------
presented as shown in Table 7-4. From this table emission density maps can be con-
structed for each pollutant as shown in Figures 7-7 through 7-9. In some cases, more
than one air pollution jurisdiction may exist in the study area (city, county), and
in such instances it is helpful to delineate the boundaries of the jurisdictions on
the various maps. For agency purposes, a map utilizing shaded plastic overlays is
desirable in comparing emission densities and geographic origin between pollutants.
A suggested master map form is the USGS topographical series, which has the UTM grid
ticks already established. This map is also extremely useful in comparing emission
densities with possible sources shown on the map.
7.11 . REFERENCES
1. Census of Population and Housing, General Characteristics for States, Cities,
and Counties. PHS series. U.S. Department of Commerce, Bureau of the Census.
Washington, D.C. 1970.
2. Census of Population and Housing, Detailed Characteristics for States, Cities,
and Counties. PHS series. u.S. Department of Commerce, Bureau of the Census.
Washington, D. C. 1970.
3. Census of Population and Housing, Census Tract Reports. PHS series. U.S.
Department of Commerce, Bureau of the Census. Washington, D.C. 1970.
4. Census of Population and Housing, Number of Inhabitants. PHS series. U.S.
Department of Commerce, Bureau of the Census. Washington, D.C. 1970.
5. McGraw, M. J. Miami-Fort Lauderdale-West Palm Beach Metropolitan Area Air Pol-
lutant Emission Inventory. u.S. Department of Health, Education and Welfare,
PHS, NAPCA. Durham, North Carolina. April 1970.
6. Automobile Facts and Figures. Automobile Manufacturers Association. Detroit,
Michigan. 1965. p. 49-50.
7. Automotive Air Pollution. Second Report of the Secretary of Health, Education
and Welfare to the United States Congress. U.S. Government Printing Office.
Washington, D.C. June 1965.
8. Compilation of Air Pollutant Emission Factors. U.S. Environmental Protection
Agency, Office of Air Programs. OAP Publication No. AP-42. Durham, North
Carolina. February 1972.
9. Shipments of Fuel Oil and Kerosene.
Mines. Washington, D.C. 1970.
10. Waterborne Commerce of the United States. U.S. Department of the Army, Corps of
Engineers. New Orleans, Louisiana. 1970.
11. Statewide Emissions Inventory for Oklahoma. U.S. Environmental Protection Agency,
Region VI. Final report for EPA Contract No. 68-02-0042. Dallas, Texas. Octo-
ber 15, 1971.
U.S. Department of the Interior, Bureau of
110
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Table 7-4.
SUMMARY OF AIR POLLUTANT EMISSIONS FROM ALL SOURCES IN THE EXAMPLE STUDY AREA5
(tons/day)
Land Area SOX PARTICULATES CO HYDROCARBONS NOx
Grid S W A 5 W A 5 W A 5 W A 5 W A
1 I 154.4 0.4 0.8 0.5 24.7 24.7 24.7 7.3 7.7 7.4 94.1 94.1 94.1 ! 0.3 0.4 0.3
2 I 154.4 3.7 6.1 4.3 0.4 0.6 0.4 0.8 1.6 1.1 233.2 233.2 233.2 1.5 2.6 1.8
I
3 I 154.4 0.2 0.3 0.2 0.5 0.8 0.6 27.0 52.8 35.6 191. 3 191. 3 191. 3 1.9 3.7 2.5
i
4 I 9.6 107.7 77.5 76.1 3.4 2.8 2.6 27.7 55.1 36.8 5.2 7.8 5.9 39.1 30.0 28.4
5 154.4 0.7 1.4 0.9 14.4 14.5 14.5 7.0 7.2 7.1 94.0 94.1 94.0 0.3 0.5 0.4
:
6 I 154.4 0.3 0.5 0.3 25.2 25.2 25.2 26.9 27.6 27.1 189.3 189.3 189.3 0.6 0.7 0.7
7 154.4 0.7 1.1 0.8 7.5 7.5 7.5 22.8 26.2 24.0 236.0 236.0 236.0 0.8 1.1 0.9
8 38.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 69.8 69.8 69.8 0.1 0.1 0.1
9 38.6 0.2 0.5 0.3 1.3 1.6 1.4 28.3 44.9 33.8 29.3 31. 7 30.1 2.3 3.8 2.7
10 I 9.6 0.3 1.0 0.5 0.3 0.7 0.4 35.1 69.7 46.7 5.0 8.2 6.1 1.2 3.0 1.7
11 9.6 0.5 1.4 0.7 0.4 0.9 0.6 46.3 91.9 61. 5 6.8 10.9 8.1 1.5 4.0 2.3
12 38;6 0.0 0.1 0.0 0.1 0.1 0.1 4.6 9.2 6.1 70.5 71.1 70.7 0.4 0.7 0.5
13 38.6 0.2 0.4 0.3 0.4 0.7 0.5 29.9 59.4 39.7 5.5 9.7 6.9 2.1 4.1 2.8
14 9.6 0.7 1.5 0.9 0.5 1.0 0.7 47.6 94.6 63.3 7.0 12.0 8.7 3.5 5.9 3.9
15 9.6 0.4 1.1 0.6 0.5 0.8 0.6 28.5 52.8 36.6 5.4 8.3 6.4 -1.6 3.6 2.2
16 i 154.4 0.0 0.0 0.0 1.0 1.0 1.0 6.5 6.5 6.5 256.8 256.8 256.8 0.1 0.1 0.1
I
I
17 I 154.4 0.3 0.6 0.4 13.5 13.5 13.5 26.1 26.1 26.1 259.1 259.1 259.1 0.6 0.6 0.6
18 154.4 0.0 0.0 0.0 3.1 3.1 3.1 19.5 19.5 19.5 258.3 258.3 258.3 0.4 0.4 0.4
19 I 154.4 0.2 0.4 0.3 0.6 0.9 0.7 29.5 57.5 38.9 146.7 146.7 146.7 2.2 4.1 2.8
20 ! 9.6 0.2 0.6 0.3 0.2 0.4 0.3 13.3 26.2 17.6 2.6 4.3 3.2 0.9 2.0 1.2
I
21 I 9.6 0.1 0.4 0.2 O.~ 0.3 0.2 9.1 17.9 12.0 2.0 3.1 2.4 0.6 1.5 0.9
22 I 9.6 0.6 0.7 0.7 0.2 0.3 0.2 10.3 20.4 13.7 2.1 3.4 2.6 0.7 1.3. 0.9
, - -
~
~
-------
-
d
m
PARTICULATE EMISSIONS,
ton I/mi 2.day
o
Bill
~
~
o
- 0.01
0.01 - 0.04
0.04 - 0.08
0.08 - 0.20
0.20 - 0.60
112
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5
h
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,
10
,
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5 0 5
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Figure 7-7. Pclrticulate emission densities'tom all sources in example study area. 5
1 /1
15 20
'-'
20 25 30
, , I
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SULFUR OXIDE EMISSIONS,
IO"s/mi2.day
o
EJ
G]
II
III
o
0.01 - 0.05
0.05 - 0.10
0.10 - 1.0
1.0 - 15.0
- 0.01
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17
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2920000
25
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39
EVERGLADES
NATIONAL PARK
5 0 10 15 20 7S
h ~ -- , , , I
miles
5 0 5 10 15 20 25 30
~ ' -- ' , , ' _---il
kilometers
Figure 7-8. Sulfur oxides emission densities ;~om all sources in example study area. 5
113
-------
H \ --------~ - \~
1 --------------- ~
7
12
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18
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CARBON MONOXIDE EMISSIONS.
ton sl m i 2.doy
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-
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o
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5
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10
,
15
,
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0.2 - 1.0
1.0 - 2.0
2.0 - 5.0
5.0 - 7.0
7.0 - 24.0
mires
5 0 5
~,
10 15
, ,
20 25 30
L....:I I
Figure 7-9. Carbon monoxide emission densities from all sources in example study area. 5
kilometers
114
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8.
DISPERSION MODELING
8.1
INTRODUCTION
Dispersion modeling is a mathematical method of calculating the expected dis-
tribution of air pollutants over an area based on emission, meteorological, and
topographical data for that area. To be able to "model" an area is one reason for
obtaining an emission inventory. Because of the mathematical complexity of modeling,
computers are often used to carry out the calculations. Although several methods
are available for these calculations, only two are regularly used--the Air Quality
Display Modell (AQDM), and the Air Quality Implementation Planning program2 (IPP).
The latter is the more extensive because it incorporates cost control models and
various control strategy options in addition to the dispersion modeling feature.
Operational computer programs are available for both methods.
8.2 USES OF DIFFUSION MODELS
The basic output of a diffusion model is a prediction of pollutant concentration
distribution. The distribution is usually displayed as a series of contours of con-
stant concentrations (isopleths) on a map of the region. When air quality measure-
ments are available, the model predictions at those sites are compared with the
measured values, and a calibration diagram is produced. The correlation (r) between
predicted and measured concentrations should be 0.7 or more. If r is less than 0.7,
or if the isopleths show a pronounced excess or deficiency of concentration for no
apparent reason, then errors in the source inventory are likely. Thus, a second use
of the diffusion model is as a check on the accuracy of the source inventory.
Once the model has been calibrated or has been verified as giving a reasonable
estimation of present or base-year conditions, it may be used to estimate the effect
of future emission changes on air quality. These changes may be due to proposed
emission regulations, expected new developments, or both. When data on fuel and
other costs are added to a sufficiently detailed emission inventory, the costs of
alternative control strategies (i.e., sets of emission limitations and fuel quality
regulations) as well as their effectiveness may be estimated.
Finally, a computerized model may yield a list of the contributions of each
point and area source to the concentrations at selected points. This source-
contribution file is valuable in designing effective and economical control
strategies.
115
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8.3 EMISSION INVENTORY AND OTHER DATA NEEDED FOR MODELING
The emission data needed for dispersion modeling are more detailed than those
that have normally been collected to date. Places for all emission data required are
provided in the format. The data requirements for both IPP and AQDM are:
A. Point Sources:
1 . Regi on .
2. SIC code.
3. Site number.
4. Process code (Appendix A, Section 4).
5. Descriptive name.
6. UTM coordinates (nearest 100 meters).
7. Political jurisdiction (e.g., county).
8. Owner (public, private).
9. Emission rate (tons per day for S02' particulates).
10. Operating time (hr/yr).
11. Shifts/day.
12. Control device identification (Appendix A, Section 3).
13. Control efficiency (percent for S02' particulates).
14. Boiler capacity (106 Btu/hr).
15. Fuel heat content (Btu/unit for coal, residual oil, distillate oil, gas).
16. Fuel burned (units/day for coal, residual oil, distillate oil, and gas).
17. Sulfur content (%).
18. Coal ash content (%).
19. Stack height (ft).
20. Stack-gas temperature (oF), exit-gas velocity (ft/sec), stack diameter
(feet), normalized plume rise (ft2/sec).
21. Maximum process rate (102 lb/hr).
22. Maximum exhaust gas velocity (102 actual ft3/min).
23. Use factor.
B. Area Sources:
1. UTM coordinates, southwest corner of grid (nearest 100 meters).
2. Emission density (tons per day-Rm2 of S02' particulates).
3. Average stack height (m).
A semi manual computerized method of gridding and apportioning area sources
is available and will considerably decrease the time requirements of this
operation.
C. Other data: Modeling requirements and meteorological and topographical data;
if a cost model is used, fuel and miscellaneous cost data. These data must
be obtained elsewhere.
116
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8.4 REFERENCES
1. Air Quality Display Model. TRW Systems Group. U.S. Environmental Protection
Agency, NAPCA. Washington, D.C. November,1970.
2. Air Quality Display Model, Implementation Planning Program. TRW Systems Group.
u.S. Environmental Protection Agency, NAPCA. Washington, D.C. November 1970.
117
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9. QUESTIONNAIRES
9.1 GENERAL INFORMATION
The questionnaire for point sources is the most widely used and expeditious
method of collecting emission inventory information. The use of the questionnaire
can produce problems, especially if the "questionnaire survey" is not properly con-
ducted. These problems may be grouped into two main categories: questionnaire design
and survey administration.
The proper design includes establishment of a suitable format for the question-
naire, selection of the appropriate questions, proper wording of questions, and
authorship of an appropriate cover letter. The basic rule is to design the question-
naire and the letter for the person who will be asked to complete it. When an
engineer is designing a questionnaire, he may overlook the fact that the person who
will complete the questionnaire may not have the benefit of a technical background
in air pollution. Also, the respondent may not have benefit of the engineer's
assistance when completing the forms.
The format of the questionnaire should be as simple and functional as possible.
Time will be saved if the format design is such that a keypunch operator can code the
information directly from the questionnaire onto the cards. The format should then
be in line with the example coding form formats of Chapters 4 and 5. If the inventory
is not computerized, the questionnaires might follow the format suggested by the
example questionnaires in Appendix D. Only information that can be used should be
solicited; the questions should be well spaced to ensure that they are easy to read,
yet placed on as few pages as possible because most people tend to avoid long
questionnaires. When writing the questions, use terminology with which the recipient
will be familiar. Each question should be self-explanatory or accompanied by clear
directions. All information that will be utilized should be asked for initially,
thus avoiding requests for additional data at a later time. The agency may wish
to coordinate the emission inventory with the establishment of a permit system
or a source registration system.
The questionnaire should be accompanied by a letter of transmittal. The example
in Appendix D shows the information that should be contained in this cover letter.
Before the questionnaire is due to be returned, a second letter may be sent out re-
minding the recipient of the need for the completed questionnaire. The second letter
is sent as a reminder only and should be worded so as not be be construed by the
119
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recipient as harassment on
has been returned, a short
turning the questionnaire.
The administrative portion of the questionnaire survey includes all operations
necessary to have the completed questionnaires distributed and processed by the
agency. The optimum procedure, which can be followed in the administrative portion,
will minimize the amount of time spent by technical staff. These procedures will
require secretarial, clerical, and keypunch help in the agency to be used whenever
possible.
the part of the agency. When the completed questionnaire
letter of appreciation should be sent to the party re-
120
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10.
EPA DATA SYSTEM FOR ATMOSPHERIC EMISSIONS
10.1 CONCEPT OF NEDS
The concept of the computerized emissions data system was previously given in
Figure 2-1; the data storage und identification files are shown on the left side of
the diagram and the ADP operations are indicated on the right. Recently the National
Source Inventory Section (NSIS) of OAP has begun to set up such a system for a nation-
wide emission inventory. The ADP and data bank are called the National Emissions
Data System (NEDS) and utilize the formats for data storage (Appendix B), the ADP
procedures, and the source inventory and emission factor methodology specified
earlier in this text.
NEDS is made up of the main system as described by cards 1 through 6 of the
point source form and cards 1 through 5 of the area source form, as well as a variable
data subsystem. The main system has been explained in Chapters 4 and 5, and
reference was made to part of the subsystem in Chapter 6. The format for the main
system is fixed; however, for the variable data subsystem, a format will be defined
for the usable columns 18 through 72 by the users as each card identification number
is assigned. The identification number is composed of an alphabetic letter in column
77 and right-justified numbers (from 001 to 999) in columns 78 through 80. The
result is that, for each point source, approximately 26,000 cards can be stored. Any
user desiring storage space for sources may request assignment of number of variable
data cards by merely submitting a proposed format (together with details for comple-
tion) to the National Source Inventory Section, which will check for conformity with
previously developed procedures. For example, cards AOOl through A999 will be used
by the National Source Inventory Section for data pertinent to their requirements--
such as AOOl and A002 for hazardous pollutants and trace elements.
All emission factor information is stored separately in the emission factor
file; this permits changes at any time in the emission factor files (about 900 cards)
without modification to the source files (about 300,000 cards). The formats for
storage in the source and emission factor files are given in Appendix B, Sections 1,
2, and 3; the SCC identification numbers are given in Appendix A, Section 2. After
the data files for NEDS are completed, this valuable tool for decision-making and
control strategies will likely become the major reference for EPA policy in which
emissions are considered.
121
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10.2 POINT AND AREA SOURCE INVENTORIES FOR NEDS
Point sources may be generally defined as sources that emit more than a specific
amount of pollutant and are iopntified individually, whereas area sources emit less
than the specific amount and are apportioned over some geographic area. This defini-
tion usually applies primarily to SO , NO , CO, hydrocarbons, and particulates.
x x
For the purpose of the NEDS inventories discussed in this chapter, point sources
of the above pollutants are defined in Appendix C. The current 100 ton/year minimum
level of emissions for point sources may be lowered to some lesser value after the
"lOa-ton inventory" for NEDS is complete.
The criterion for specifying as point sources those facilities that emit at
least 100 tons of a contaminant per year is based on the probable degradation by
such a facility of ground level air quality. If it is assumed that an installation
emits no more than 100 tons per year of a contaminant from a low stack, that it is
located in an area where the average wind speed is less than the average throughout
the country, that no wind direction occurs more often than 25 percent of the time at
the site, and that atmospheric stability conditions in the vicinity occur with normal
frequency, then the area most contaminated by the emissions would experience an annual
average concentration of 5 to 8 micrograms per cubic meter. This concentration is
about 10 percent of the secondary Federal annual air quality standard for sulfur
dioxide or particulate matter.
Therefore, for the purpose of NEDS, it is conservative to classify as point
sources only those facilities that emit at least 100 tons per year of the pollutants
listed above. When considering hazardous (or potentially hazardous) pollutants or
trace elements and compounds, point sources would be identified as every known
emitter. When considering an inventory of selected source categories or source
ownerships (Federal facilities, for example) every emitter would be listed. In many
parts of the United States, emissions from Federal facilities may contribute to the
total quantity of air pollutants in the area; therefore, source inventories of
"federally-owned facilities" are being incorporated into the NEDS system by NSIS, OAP.
In NEDS, area sources are all sources of emissions not included as point sources;
area source data are compiled on a countywide basis for both stationary and mobile
sources. It is anticipated that gridding and apportioning techniques currently under
development will facilitate conversion of the countywide totals to smaller areas for
dispersion modeling. The countywide totals for area sources will also be compatible
with the county identification numbers used on point sources, thereby permitting com-
pilation of a nationwide inventory that will be subdivided into states and counties.
122
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10.3 EMISSION FACTORS FOR NEDS
When fully operational, NEDS will automatically calculate emissions using the
most up-to-date emission factors and current population data. The emission factor
file will be periodically updated as new source test data become available; thus the
computerized system will always use the best emission factors possible.
It will also be possible to compare the estimated emissions as stored in the
data bank with the calculated emissions, and, by checking that the estimated emissions
were a result of source tests, to make some quality judgment of the calculated
emissions in general.
10.4 DATA RETRIEVAL ACCESS FOR NEDS
Any state or local agency that chooses to may request data from NEDS by telephone,
mail, or, in future, by terminal access of the computer at the Research Triangle
Park National Environmental Research Center.
Generally, three categories of data will be available: summaries, which will
be most commonly used; sorting, a useful tool to be developed after summary techniques
are finalized; and special analyses, techniques that will necessitate both terminal
and programming capability. Each category is discussed below.
10.4.1 Summaries
A number of programs are under development that will provide the following
summaries:
1.
Nationwide inventory - by county (3,300), AQCR (247), state and territories
(54), and the nation (1).
2. Area sources - by county (3,300), including tabulated data of cards 1
through 5 and calculated emissions of pollutants.
3.
Point sources - individually (40,000) by county, including tabulated data
of cards 1, 2, 3,4,5,6 and calculated emissions of pollutants, trace
elements and compounds.
10.4..1.1 Simple Summary Data Requests - Very brief data requests will be answered
from monthly summaries or from the summaries output on the last day of the year
(annual summaries). Annual summaries will be maintained for ADP and in computer
printout form, stored on microfiche in NSIS. Monthly summaries will only be main-
tained on computer tape for ADP. The methods of answering simple requests are as
follows:
123
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1.
Telephone requests to NSIS - Immediate answer will be given by telephone
or, if many numbers are required, photocopies of the annual summaries from
the microfiche will be mailed on the same day as the request, directed to
the Chief, Air Branch of the EPA Regional Office for the area from which
the request originated. The material will then be forwarded from the
Regional Office, and in this manner confidentiality of data will be the
responsibility of the Regional Office.
2.
Mail requests to NSIS - Photocopies of summaries will be mailed in the same
manner as for telephone requests.
3. Terminal requests to the computer - Immediate turnaround should be possible
from monthly summaries.
10.4.1.2 Comprehensive Summary Data Requests - More complicated requests will
probably require access of the computer by NSIS.
1.
from the data received by
computer, obtain printout
air branch chief for for-
2.
Telephone requests to NSIS - Five-day turnaround
NSIS is anticipated to enable NSIS to access the
from monthly summaries, and mail to the regional
warding.
Mail requests to NSIS - Such requests are handled in the same manner as
telephone requests.
3.
Terminal requests to the computer - Immediate turnaround should be possible
from monthly summaries.
10.4.2 Sorting
A number of programs will be developed that will enable sorting and ranking of
data. The methods for answering these requests will be the same as for comprehensive
requests of summary data, except that sorting and/or ranking operations will be in-
cluded.
10.4.3 Special Analysis
No programs will be developed for these operations; therefore, users must have
their own programming capability until this need can be met by increased resources
in NSIS.
10.5
124
UPDATING AND MAINTENANCE FOR NEDS
Three methods of updating the source files will be used:
1.
New and modified source semi-annual reports - These reports will be routed
to NSIS for use in revising source data.
-------
2.
Revisions - Any suggested revisions by local agencies, regional offices,
etc. should be submitted by letter, telephone, or through computer terminal.
The changes will be incorporated the last day of each month by NSIS.
NSIS "audit" procedures - Checks of the inventory will be made by selecting
source categories, pollutants, or geographical areas to be investigated
in depth by NSIS using available reports, data, etc. collected from a
multitude of references.
3.
The emission factors data file will be updated continuously as new information
on source testing becomes available.
125
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APPENDIX A
COMPREHENSIVE EMISSION INVENTORY IDENTIFICATION CODES
A.I
GEOGRAPHICAL IDENTIFICATION CODES
Environmental Protection Agency Regions are delineated and identified in
Figure A-l. State and Air Quality Control Region (AQCR) numbers are listed
following this figure. The states and the District of Columbia are listed
alphabetically, and identification numbers are assigned sequentially. AQCR's
are arranged alphabetically within each state according to the name specified in
the Federal Register. The AQCR's are then numbered sequentially, following
the same arrangement of states used for the state identification. Interstate
AQCR's are included within the lowest-numbered state. AQCR's have been
established for Puerto Rico, American Samoa, Guam, and the U.S. Virgin Islands.
These AQCR's follow those of the states.
127
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.REGIONAL OFFICE
HAWAII
Protection Agency Regions.
A 1 Environmental
Figure -.
-------
A.1.2 State Identification Numbers
State Number
Alabama 01
Alaska 02
Ari zona 03
Arkansas 04
California 05
Colorado 06
Connecticut 07
Delaware 08
District of Columbia 09
Flori da 10
Georgia 11
Hawaii 12
Idaho 13
Illinois 14
Indiana 15
Iowa 16
Kansas 17
Kentucky 18
Louisiana 19
Maine 20
Maryland 21
Massachusetts 22
Michigan 23
Minnesota 24
Mississippi 25
Mi ssouri 26
Montana 27
Nebraska 28
Nevada 29
New Hampshire 30
New Jersey 31
New Mexico 32
New York 33
North Carolina 34
North Dakota 35
129
-------
A.1.3
130
State Number
Ohio 36
Oklahoma 37
Oregon 38
Pennsylvania 39
Puerto Rico 40
Rhode Island 41
South Carolina 42
South Dakota 43
Tennessee 44
Texas 45
Utah 46
Vermont 47
Virginia 48
Washington 49
West Virginia 50
Wisconsin 51
Wyomi ng 52
American Samoa 53
Guam 54
Virgin Islands 55
Air Quality Control Region Identification Numbers
Region
Alabama
Alabama and Tombigbee Rivers
Columbus-Phenix City
East Alabama
Metropolitan Birmingham
Mobil e-Pensaco 1 a-Panama City-
Southern Mississippi (Fla., Miss.)
Southeast Alabama
Tennessee River Valley-Cumberland Mts. (Tenn.)
A 1 as ka
Cook Inlet
Number
2
3
4
5
6
7
8
-------
Regi on
Number
AlaskQ.
Northern Alaska
9
South Central Alaska
10
Southeastern Alaska
11
Arizona
Arizona-New Mexico Southern Border (N. Mex.)
Cl ark-r~ohave
Four Corners (Colo., N. Mex., Utah)
12
13
Phoenix-Tucson
14
15
Arkansas
Central Arkansas
16
17
Metropolitan Fort Smith
Metropolitan Memphis
18
Monroe-El Dorado (La.)
Northeast Arkansas
19
20
Northwest Arkansas
21
Shreveport-Texarkana-Tyler (La., Okla., Texas)
22
Ca 1 iforni a
Great Basin Valley
Metropolitan Los Angeles
23
24
North Central Coast
25
26
North Coast
Northeast Plateau
27
28
Sacramento Valley
San Diego
San Francisco Bay Area
29
30
San Joaquin Valley
South Central Coast
31
32
Southeast Desert
33
131
-------
Region
Number
Colorado
--
Comanche
34
Four Corners (Ariz., N. Mex., Utah)
14
35
Grand Mesa
Pawnee
36
37
Metropolitan Denver
San Isabel
38
San Luis
39
40
Yalllpa
Connecticut
Eastern Connecticut
41
42
lIartford-Ne\~ Haven-Springfield (r~ass.)
rJew Jersey-New York-Connecticut (N. J., fL Y.)
43
44
Northwestern Connecticut
Delaware
Metropolitan Philadelphia (rJ. J., Pa.)
45
Southern Delaware
46
District of Columbia
National Capital (Md.)
47
Florida
Central Florida
48
Jacksonville-Brunswick (Ga.)
49
Mobile-Pensacola-Panama City-
Southern Mississippi (Ala., Miss.)
Southeast Florida
5
50
Southwest Florida
51
52
West Central Florida
Georgia
Augusta-Aiken (S. C.)
Central Georgia
53
54
132
-------
Region
Number
Georgi a.
Chattanooya (Tenn.)
Columbus-Phenix City (Ala.)
Jacksonville-Urunswick (Fla.)
55
2
Metropolitan Atlanta
49
56
Northeast Georgia
Savannah-Beaufort (S. C.)
57
Southwest Georgia
58
59
Ha wa i i
Entire State
60
Idaho
Eastern Idaho
61
62
Eastern Washington-Northern Idaho (Wash.)
_.
Idaho
63
64
Metropolitan 80ise
III i no is
Burlington-Keokuk (Iowa)
East Central Illinois
65
66
Metropolitan Chicago (Ind.)
Metropolitan Dubuque (Iowa, Wise.)
67
68
Metropolitan Quad Cities (Iowa)
Metropolitan St. Louis (Mo.)
69
70
North Central Illinois
71
72
Paducah-Ca i ro (Ky.)
Rockford-Janesville-Beloit (Wise.)
73
74
Southeast Illinois
West Central Illinois
75
Indiana
East Central Indiana
76
133
-------
134
Region
Indiana
Number
Evansville-Owensboro-Henderson (Ky.)
Louisville (Ky.)
77
78
Metropolitan Chicago (Ill.)
Metropolitan Cincinnati (Ky., Ohio)
67
79
Metropolitan Indianapolis
Northeast Indiana
80
81
South Bend-Elkhart-Benton Harbor (Mich.)
Southern Indiana
82
83
~Jabash Valley
84
Iowa
Burlington-Keokuk (Ill.)
Metropolitan Dubuque (Ill., Wise.)
65
68
Metropolitan Omaha-Council Bluffs (Neb.)
Metropolitan Quad Cities (Ill.)
85
69
Metropolitan Sioux City (Neb., S. D.)
Metropolitan Sioux Falls (S. D.)
86
87
Northeast Iowa
88
89
North Central Iowa
Northwest Iowa
90
91
Southeast Iowa
South Central Iowa
92
93
Southwest Iowa
Kansas
Metropolitan Kansas City (Mo.)
94
95
Northeast Kansas
North Central Kansas
96
97
Northwest Kansas
Southeast Kansas
98
-------
Region
Kansas
South Central Kansas
Southwest Kansas
Kentuc ky
Appalachian
Bluegrass
Evansville-Owensboro-Henderson (Ind.)
Huntington-Ashland-Portsmouth-Ironton (Ohio. W. Va.)
Louisville (Ind.)
Metropolitan Cincinnati (Ind., Ohio)
North Central Kentucky
Paducah-Cairo (Ill.)
South Central Kentucky
Louisiana
Monroe-El Dorado (Ark.)
Shreveport-Texarkana-Tyler (Ark., Okla.. Texas)
Southern Louisiana-Southeast Texas (Texas)
r4a i ne
Androscoggin Valley (N. H.)
Aroostook
Down East
Metropolitan Portland
Northwest Maine
~laryland
Central Maryland
Cumberland-Keyser (W. Va.)
Eastern Shore
Metropolitan Baltimore
National Capital (D. C.)
Southern Maryland
Number
99
100
101
102
77
103
78
79
104
72
105
19
22
106
107
108
109
110
111
112
113
114
115
47
116
135
-------
136
Region
Number
Massachusetts
Berkshire
117
118
Centra 1 tlassachusetts
Hartford-New Haven-Springfield (Conn.)
42
119
Metropolitan Goston
Metropolitan Providence (R. I.)
Merrimack Valley-Southern New Hampshire (N. H.)
120
121
Michigan
Central Michigan
122
123
Metropolitan Detroit-Port Huron
Metropolitan Toledo (Ohio)
124
82
South Bend-Elkhart-Benton Harbor (Ind.)
South Central Michigan
125
126
Upper Michigan
Minnesota
Central Minnesota
127
128
Southeast Minnesota-La Crosse (Wise.)
Duluth-Superior (Wise.)
129
130
Metropolitan Fargo-Moorhead (N. D.)
Minneapolis-St. Paul
131
Northwest Minnesota
132
133
Southwest Minnesota
Mississippi
Metropolitan Memphis (Ark., Tenn.)
18
134
Mississippi Delta
Mobile-Pensacola-Panama City-
Southern Mississippi (Ala., Fla.)
5
135
Northeast Mississippi
-------
Region
Number
Missouri
Metropolitan Kansas City (Kans.)
Metropolitan St. Louis (Ill.)
94
70
Northern Missouri
137
138
Southeast ~lissouri
Southwest Missouri
139
Montana
13 ill i ng s
Great Fall s
140
141
Helena
142
143
Miles City
Missoula
144
liebraska
Lincoln-Beatrice-Fairbury
145
85
Metropolitan Omaha-Council Bluffs (Iowa)
r.letropol itan Sioux City (Iowa, S. D.)
Nebraska
86
146
(levada
Clark-Mohave (Ariz.)
13
147
Nevada
Northwest Nevada
148
New Hampshire
Androscoggin Valley (Maine)
Merrimack Valley-Southern New Hampshire (Mass.)
107
121
New Hampshire
149
New Jersey
Metropolitan Philadelphia (Dela., Pa.)
45
(iew Jersey
New Jersey-New York-Connecticut (N. Y., Conn.)
150
Northeast Pennsylvania-Upper Delaware Valley (Pa.)
43
151
137
-------
Region
Number
New Mexico
Albuquerque-Mid Rio Grande
Arizona-New Mexico Southern Border (Ariz.)
152
12
El Paso-Las Cruces-Alamogordo (Texas)
Four Corners (Ariz., Colo., Utah)
153
14
154
Northeastern Plains
Pecos-Permian Basin
155
156
Southwestern Mountains-Augustine Plains
Upper Rio Grande Valley
New York
157
Central New York
158
159
Champlain Valley (Vt.)
Genesse-Finger Lakes
160
Hudson Valley
161
43
New Jersey-Ne~1 York-Connecticut (iL J., Conn.)
Niagara Frontier
162
Southern Tier East
163
164
Southern Tier West
North Carolina
Eastern Mountain
165
166
Eastern Piedmont
Metropolitan Charlotte (S. C.)
167
168
Northern Coastal Plain
Northern Piedmont
136
169
Sandhi 11 s
Southern Coastal Plain
170
171
Western Mountain
North Dakota
Metropolitan Fargo-Moorhead (Minn.)
Horth Dakota
130
172
138
-------
L--
Regi on
Ohio
Dayton
Greater Metropolitan Cleveland
Huntington-Ashland-Portsmouth-Ironton (Ky., W. Va.)
Mansfield-Marion
Metropolitan Cincinnati (Ind., Ky.)
Metropolitan Columbus
Metropolitan Toledo (Mich.)
Northwest Ohio
Northwest Pennsylvania-Youngstown (Pa.)
Parkersburg-Marietta (W. Va.)
Sandusky
Steubenville-Weirton-Wheeling (W. Va.)
Wilmington-Chillicothe-Logan
Zanesville-Cambridge
Oklahoma
Central Oklahoma
Metropolitan Fort Smith (Ark.)
North Central Oklahoma
Northeastern Oklahoma
Northwestern Oklahoma
Shreveport-Texarkana-Tyler (Ark., La., Texas)
Southeastern Oklahoma
Southwestern Oklahoma
Oregon
Central Oregon
Eastern Oregon
Northwest Oregon
Portland (Wash.)
Southwest Oregon
Number
173
174
103
175
79
176
124
177
178
179
180
181
182
183
184
17
185
186
187
22
188
189
190
191
1 92
193
194
139
-------
Region
Pennsylvania
Central Pennsylvania
Metropolitan Philadelphia (Dela., N. J.)
ilortheast Pennsylvania-Upper Delaware Valley (N. J.)
Northwest Pennsylvania-Youngstown (Ohio)
South Central Pennsylvania
Southwest Pennsylvania
Rhode Island
Metropolitan Providence (Mass.)
South Carolina
Augusta-Aiken (Ga.)
Camden-Sumter
Charleston
Columbia
Florence
Greenville-Spartanburg
Greenwood
Georgetown
Metropolitan Charlotte (N. C.)
Savannah-Beaufort (Ga.)
South Dakota
Black Hills-Rapid City
Metropolitan Sioux City (Iowa, Neb.)
Metropolitan Sioux Falls (Iowa)
South Dakota
Tennessee
Chattanooga (Ga.)
Eastern Tennessee-Southwestern Virginia (Va.)
Metropolitan Memphis (Ark., Miss.)
140
Number
195
45
151
178
196
197
120
53
198
199
200
201
202
203
204
167
58
205
86
87
206
55
207
18
-------
Region
Number
Tennessee
Middle Tennessee
208
7
Tennessee River Valley-Cumberland Mountains (Ala.)
Western Tennessee
209
Texas
Abilene-Wichita Falls
210
211
Amarillo-Lubbock
Brownsville-Laredo
212
213
Austin-Waco
Corpus Christi-Victoria
El Paso-Las Cruces-Alamagordo (N. M.)
214
153
Metropolitan Dallas-Ft. Worth
Metropolitan Houston-Galveston
215
216
Midland-Odessa-San Angelo
Shreveport-Texarkana-Tyler (Ark., La., Okla.)
217
218
Metropolitan San Antonio
Southern Louisiana-Southeast Texas (La.)
22
106
Utah
Four Corners (Ariz., Colo., N. M.)
14
219
Utah
L-Jasatch Front
220
Vermont
Champlain Valley (N. Y.)
159
221
Vermont
Virginia
Central Virginia
Eastern Tennessee-Southwestern Virginia (Tenn.)
Hampton Roads
222
207
Ijational Capital (D. C., ~~d.)
223
47
141
-------
_Regi ~
Number
-.-
Virginia
----
Northeastern Virginia
224
225
State Capital
Valley of Virginia
226
~Iashington
Eastern Washington-Northern Idaho (Idaho)
62
Northern Washington
Olympia-Northwest Washington
227
228
Portland (Ore.)
193
Puget Sound
South Central Washington
229
230
West Virginia
Allegheny
Central West Virginia
Cumberland-Keyser (Md.)
231
232
Eastern Panhandle
113
233
Huntington-Ashlanu-Portsmouth-Ironton (Ky., Ohio)
103
Kanawha Valley
North Central West Virginia
234
Parkersburg-Marietta (Ohio)
235
179
Southern West Virginia
SteuLenville-Wierton-Wheeling (Ohio)
236
181
Wisconsin
Duluth-Superior (Minn.)
129
237
Lake Michigan
Metropolitan Dubuque (Ill., Iowa)
North Central Wisconsin
68
238
Rockford-Janesville-Beloit (Ill.)
73
239
Southeastern Wisconsin
142
-------
Region
Number
!.Jisconsin
----
Southeast r~innesota-La Crosse (r.1inn.)
128
240
Southern Wisconsin
l~yomi ng
Casper
241
J.1etropol itan Cheyenne
242
\~yoilli ng
243
Puerto Rico
PLlerto Rico
244
American Samoa
American Samoa
245
Guam
Guam
246
U. S. Virgin Islands
U. S. Virgin Islands
247
143
-------
~
~
r----------- ---
I
I
I
I
I
I
I
I
I
I
I
I
l.!
Figure A-2.
Federal Air Quality Control Regions.
60
244
245
246
247
-------
Note:
A.2
SOURCE ClASSIFICATION CODES
NATIONAL EMISSIONS DATA SYSTEM (NEDS)
SOURCE CLASSIFICATION CODE (SCC) REPORT
The National Emissions Data System (NUDS) Source Classification
Code (SCC) Report, commonly called the "NEDS SCC Listing," has
been removed from Appendix A.2 because it will now be issued
semiannually as an appendix to AP-42, Compilation of Air
Pollutant Emission Factors, and will include any new source
classification codes. The NEDS SCC Listing current with this
revision of APTD 1135 is dated July 1974.
145
-------
A.3 CONTROL EQUIPMENT IDENTIFICATION CODES
Identification Number
Control Device/Method
000
001
002
003
004
005
006
007
008
009
010
011
012
013
014
015
016
017
018
019
020
021
022
023
039
040
041
042
043
044
045
046
047
No Equipment
Wet Scrubber - High Efficiency
Wet Scrubber - Medium Efficiency
Wet Scrubber - Low Efficiency
Gravity Collector - High Efficiency
Gravity Collector - Medium Efficiency
Gravity Collector - Low Efficiency
Centrifugal Collector - High Efficiency
Centrifugal Collector - Medium Efficiency
Centrifugal Collector - Low Efficiency
Electrostatic Precipitator - High Efficiency
Electrostatic Precipitator - Medium Efficiency
Electrostatic Precipitator - Low Efficiency
Gas Scrubber (general, not classified)
Mist Eliminator - High Velocity
Mist Eliminator - Low Velocity
Fabric Filter - High Temperature
Fabric Filter - Medium Temperature
Fabric Filter - Low Temperature
Catalytic Afterburner
Catalytic Afterburner with Heat Exchanger
Direct Flame Afterburner
Direct Flame Afterburner with Heat Exchanger
Flaring
Catalytic Oxidation - Flue Gas Desulfurization
Alkalized Alumina
Dry Limestone Injection
Wet Limestone Injection
I
Sulfuric Acid Plant - Contact Process
Sulfuric Acid Plant - Double Contact Process
Sulfur Plant
Process Change
Vapor Recovery System (including condensers,
hooding, and other enclosures)
Activated Carbon Adsorption
Liquid Filtration System
Packed-Gas Absorption Column
Tray-Type Gas Absorption Column
048
049
050
051
146
-------
L
Identification Number:
052
053
Control Device/Method:
Spray Tower (Gaseous Control Only)
Venturi Scrubber (Gaseous Control Only)
For the particulate control devices (wet scrubbers, gravity collectors, centri-
fugal collectors, and electrostatic precipitators), the efficiency ranges correspond
to the following percentages:
High: 95 - 99 +
Medium: 80 - 95
Low: <80
A.4 IPP PROCESS IDENTIFICATION CODES
Process
Flour and other Grain Mill Products
Combustion
General
Wheat
Barley
Prepared Feeds for Animals and Fowls
Combustion
General
Alfalfa
Roasted Coffee
Combustion
Direct-Fired
Indirect-Fired
Stones and Cooler
Spray Cooler
Kraft Pu1 p Mill s
Combustion
Digester Blow System
Smelt Tank
Lime Kil n
Recovery Furnace
Code
2041
X*O
01
02
03
2042
XO
01
02
2095
XO
01
02
03
04
2621
XO
01
02
03
04
* For value of X, see following list for combustion code numbers.
147
-------
Process
Oxidation Tower
Code
2621
05
06
2819
XO
01
02
03
04
05
06
07
08
09
11
12
2816
XO
01
02
03
04
05
06
07
2851
XO
01
02
03
Kraft Pulp Mills
Multiple Effect Evaporator
Industrial Inorganic Chemicals
Combustion
Sulfur Recovery Incinerator
Sulfuric Acid
tJitric Acid
Amonium Nitrate
Hydrofluoricacid
Calcium Carbide - Coke Dryer
Calcium Carbide - Electric Furnace Hood
Calcium Carbide - Electric Furnace Vents
Calcium Carbide Stack
Calcium Carbide Calcination
Phosphori c Aci d
Inorganic Pigments
Combustion
Calcination
Digestion
Chloride Process
Chloride Coke or Ore Drying
Ore Grinding
Titanium Oxide Ore Drying
Varnish Reaction Kettles
Paints, Varnishes, Lacquers, Enamels, and Allied Products
Combustion
Varnish Cookers
Al kyd Resin
Cooking and Blowing
148 .
-------
Process
Paints, Varnishes, Lacquers, Enamels, and Allied Products
Polymerization
Fluid Cooker
Code
2851
04
2911
XO
01
02
03
04
05
06
07
08
2951
XO
01
02
03
04
3241
XO
01
02
03
3274
XO
01
02
3295
XO
01
Petroleum Refining
.Combustion
Fluid Catalytic Units
Moving Bed Catalytic Units
Sulfur Recovery
Acid Refining of Lube Oils
Microfines Unit
Calciner Kiln
Process Emission Source
Asphalt Batching
Combustion
Batching
Quarrying
Rock Dryi ng
Sheet Rock Cutting and Trimming
Cement Manufacturing
Combustion
Dry Process
Wet Process
Sand Dryer
Lime Production
Combustion
Rotary Kil n
Vertical Kiln
Minerals and Earths, Treated
Combustion
Crushing
149
-------
Process Code
---
Minerals and Earths. Treated 3295
Conveying, Screening, and Shaking 02
Storage Piles 03
Iron and Steel Mills 3312
Combustion XO
Blast Furnace 01
Basic Oxygen Furnace 02
Sintering 03
Coking Operations 04
Electric Arc Furnace 05
Open Hearth Furnace 06
Bessemer 07
Scarfing 08
Gray Iron Foundries 3321
Combustion XO
Cupola 01
Electric Induction 02
Reverberatory Furnace 03
Steel Foundries 3323
Combustion XO
Electric Arc 01
Electric Induction 02
Open Hearth 03
Primary Smelting and Refining of Lead 3332
Combustion XO
Sintering 01
Blast Furnace 02
Reverberatory Furnace 03
Refining of Lead 04
Lead Oxide t~anufacturing 05
150
-------
Process
Combustion
Code
3341
XO
01
02
03
04
05
06
07
08
09
3369
XO
01
02
03
04
05
06
07
08
4953
XO
01
02
03
04
05
06
Secondary Smelting an~ Refining of Non-Ferrous Metals
Combustion
Aluminum - Chlorination Station
Aluminum - Crucible Furnace
Aluminum - Reverberatory Furnace
Aluminum - Sweating Furnace
General Aluminum Operations
Brass and Bronze - Crucible Furnace
Brass and Uronze - Electric Furnace
Brass and Bronze - Reverberatory Furnace
Brass and Bronze - Rotary Furnace
Non-Ferrous Castings
Lead - Cupola
Lead Pot Furnace
Lead - Reverberatory and Sweating
Zinc - Galvanizing Kettles
Zinc - Calcine Kilns
Zinc - Pot Furnace
Zinc - Sweating Furnace
Zinc - Distillation Furnace
Refuse Systems
Combustion of fuel
Municipal Incinerator
Open Burning
On-site Multichamber Incinerator
On-site Single Multichamber Incinerator
Flue Fed Incinerator
Other
, 151
-------
COMBUSTION CODE NUMBERS
All not listed
Pulverized, general
00
10
Pulverized, dry bottom
Pulverized, wet bottom without flyash reinjection
Pulverized, wet bottom with flyash reinjection
20
30
40
Cyclone
Spreader stoker without flyash reinjection
50
60
Spreader stoker with flyash reinjection
70
All other stokers
Hand-fired
80
90
A.5 TRACE ELEMENTS AND COMPOUNDS IDENTIFICATION CODES
Po 11 utant Code
Total Element (Free and Combined) 121
Aluminum 12101
Antimony 12102
Arsenic 12103
Argon 12104
Asbestos 12552
Beryll i urn 12105
Bismuth 1 21 06
Barium 12107
Bo ro n 12108
Bromine 1 21 09
Cadmium 1 2110
Calcium 1 2111
Chromium 1211 2
Cobalt 12113
Copper 1 2114
Chlorine 1211 5
152
-------
Pollutant Code
Carbon 1 211 6
Cerium 1 211 7
Cesium 1 2118
Dysprosium 1 211 9
Erbium 12120
Europium 1 21 21
Fluorine 1 2122
Gadolinium 1 2123
Ga 11 i um 1 2124
Germanium 121 25
Iron 12126
Hafnium 121 27
Lead 121 28
Holmium 1 21 29
Hydrogen 12130
Indium 12131
Manganese 1 21 32
iridium 12133
Molybdenum 1 21 34
Krypton 12135
Ni eke 1 1 21 36
Helium 12137
Lithium 12138
Lutetium 12139
Magnesium 1 2140
Iodine 1 2141
Mercury 12142
Gold 1 2143
Neodymium 1 2144
Neon 1 2145
. 153
-------
154 .
Pollutant Code
Lanthanum 12146
Niobium 12147
Nitrogen 12148
Osmium 12149
Oxygen 12150
Palladium 12151
Phosphorus 121 52
Platinum 1 21 53
Selenium 1 21 54
Praseodymi.um 12155
Protectinium 121 56
Radium 121 57
Rhenium 1 21 58
Rhodium 121 59
Tin 121 60
Titanium 12161
Samarium 12162
Scandium 12163
Vanadium 12164
Sil icon 12165
Silver 12166
Zinc 12167
Strontium 1 2168
Sulfur 12169
Tantalum 12170
Tellurium 1 21 71
Terbium 12172
Thallium 12173
Thori urn 12174
-------
Pollutant Code
Thulium 1 21 75
Rubidium 12176
Ruthenium 12177
Tungsten 1 21 78
Uranium 12179
Potassium 12180
Xenon 12181
Ytterbium 12182
yttrium 1 21 83
Sodium 1 2184
Zirconium 12185
Group VII Compounds and Ions 122
Bromide ion 1 ?201
Fluoride ion 12202
Chloride ion 12203
Iodide ion 1 2204
Chlorate ion 12205
Perchlorate ion 12206
Bromate ion 12207
Sodium chloride 12210
Potassium chloride 12211
Calcium chloride 1221 2
Ammonium chloride 1 2213
Aluminum chloride 1 2214
Sodium bromide 12230
Potassium bromide 12231
Sodium iodide 12250
Potassium iodide 12251
Potassium fluoride 12270
,I 155
-------
Pollutant
Code
Sodium fluoride
1 2271
12275
Sodium fluorosilicate
Calcium f1uorosi1icate
12276
125
Group IV Compounds and Ions
Silicate ion
12550
12551
Silicon dioxide
Acids and Bases
126
12601
Total acidity 11+
Hydrogen ion concentration pH
12602
12603
Bicarbonate ion
Sulfuric acid
1 2604
1 2605
Nitric acid
Hydrochloric acid
Total al ka1 inity
12606
12650
Hydroxide ion concentration
12651
12652
Carbonate ion
Organo-Metal1ic Compounds and Ions
Miscellaneous
127
128
156
-------
APPENDIX B
COMPREHENSIVE EMISSION INVENTORY CARD FORMATS
8.1 POINT SOURCE CARD FORMAT
Plant Identification Data Card
Card Column Format Parameter
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 13 XXXX Plant ID Number*
14 - 17 XXXX City Code
18 - 19 XX UTM Zone
20 - 21 XX Year of Record**
22 - 36 A-nA Establishment Name
37 - 61 A-nA Establishment Address
62 - 73 A---A Contracts (Personal)
74 A Ownership***
78 X Action Code
79 P Point Source Code
80 Point Source Card Code
* This number is unique within county identification
** For each Point Source Card (1, 2, 3, 4, 5 or 6) the Year of Record
refers only to the data on that card
*** P = Private
L = Local
S = State government
F = Federal government
U = Util Hies
157
-------
158
General Identification and Stack Data Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 13 XXXX Plant ID Number
14 - 15 XX Point ID Number in Plant
16 - 17 XX Year of Record
18 - 21 XXX X SIC Code
22 - 23 XX Process Code (IPP)
24 - 27 XXXX.X UTM Horizontal Coordinate km
28 - 32 XXXX.X UTM Vertical Coordinate km
33 - 36 XXXX Stack Height ft
37 - 39 XX.X Stack Inside Equivalent ft
Diameter, At Top
40 - 43 XXXX Stack Gas Temperature of
44 - 50 XXXXXXX Stack Gas Flow Rate Actual ft3jmin
51 - 54 XXXX Plume Height (if no stack) ft
56 - 59 XXXX Points with Common Stack
78 X Action Code
79 P Point Source Code
80 2 Point Source Card Code
Control Equipment Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 13 XXXX Plant ID Number
14 - 15 XX Point ID Number in Plant
Hi - 17 XX Year of Record
-------
Card Column Format Parameter Units
18 - 22 XXXXX Total Boiler Design 106 Btu/hr
Capacity
23 - 25 XXX Primary Particulate Control
Equipment Code
26 - 28 XXX Secondary Particulate Control
Equipment Code
29 - 31 XXX Primary S02 Control Equipment
Code
32 - 34 XXX Secondary S02 Control Equipment
Code
35 - 37 XXX Primary NO Control Equipment
Code x
38 - 40 XXX Secondary NO Control Equipment
Code x
41 - 43 XXX Primary HC Control Equipment
Code
44 - 46 XXX Secondary HC Control Equipment
Code
47 - 49 XXX Primary CO Control Equipment
Code
50 - 52 XXX Secondary CO Control Equipment
Code
53 - 55 XX.X Estimated Control Efficiency- %
Particulates
56 - 58 XX.X Estimated Control Efficiency- %
S02
59 - 61 XX.X Estimated Control Effi ci ency- %
NO
x
62 - 64 XX.X Estimated Control Efficiency- %
HC
65 - 67 XX.X Estimated Control Efficiency- %
CO
78 X Action Code
79 P Point Source Code
80 3 Point Source Card Code
159
~- _. -'
-------
160
Emission Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 13 XXXX Plant ID Number
14 - 15 XX Point 10 Number in Plant
16 - 17 XX Year of Record
18 - 19 XX % of annual thruput
(Dec., Jan., Feb.) %
20 - 21 XX % of annual thruput
(Mar., Apr., May) %
22 - 23 XX % of annual thruput
(June, July, Aug.) %
24 - 25 XX % of annual thruput
(Sept., Oct., Nov.) %
26 - 27 XX Normal Operating hr/day hr
28 X Normal Operating da/wk da
29 - 30 XX Norma 1 Operating wk/yr wk
31 - 37 XXXXXXX Emissions Estimate - T/yr
Particulate
38 - 44 XXXXXXX Emissions Estimate - S02 T/yr
45 - 51 XXXXXXX Emissions Estimate - NOx T/yr
52 - 58 XXXXXXX Emissions Estimate - HC T/yr
59 - 65 XXXXXXX Emi ss ions Estimate - CO T/yr
66 X Method of estimating
Particulate Emissions*
67 X Method of estimating
5°2 Emissions*
68 X Method of estimating NOx
Emissions*
69 X Method of estimating HC
Emissions*
-------
Card Column Format Parameter Units
70 X Method of estimating CO
Emissions*
71 - 73 XX.X Portion of Fuel used for Space %
Heating
78 X Action Code
79 P Point Source Code
80 4 Point Source Card Code
* 1 - Stack Tests
2 - Material Balance
3 - Calculated using
4 - Guess
Emission Factors
Compliance Analysis Card
Card Column Format Parameter
1 - 2 ,XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 13 XXXX Plant 10 Number
14 - 15 xx Point 10 Number in Plant
16 - 17 XX Year of Record
18 - 24 XXXXXXX Allowable Emissions -
Particulate
25 - 31 XXXXXXX All owab 1 e Emissions - S02
32 - 38 XXXXXX Allowable Emissions - NO
x
39 - 45 XXXXXXX Allowable Emissions - HC
46 - 52 XXXXXXX Allowable Emissions - CO
53 X Source Compliance Status*
--.---
* 1 - In Compliance
2 - Non Compliance, variance not given (complete date items)
3 - Non Compliance, variance given (complete date items)
4 - Compliance status not known
Units
T/yr
T/yr
T/yr
T/yr
T/yr
161
-------
162
Card Column Format Parameter Units
54 - 55 XX Year Source must be in
compliance (complete only
if Compliance Status =
2, 3)
56 .. 57 XX Month Source must be in
compliance (complete only if
Compliance Status = 2, 3)
58 - 59 XX Year of Compliance Status
Update
60 - 61 XX Month of Compliance Status
Update
62 - 63 XX Day of Compliance Status
Update
78 X Action Code
79 P Point Source Code
80 5 Point Source Card Code
Operating Data Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 xxxx County Code
7 - 9 XXX AQCR Code
10 - 13 xxxx Plant ID Number
14 - 15 XX Point ID Number in Plant
16 - 17 XX Year of Record
18 - 25 xxxxxxxx SCC
26 - 32 xxxxxxx Fuel, Process, or Solid
Waste Operating Rate (SCC)*
33 - 39 xxxxxxx Maximum Design Rate (SCC)*
40 - 42 X.XX Sulfur Content %
43 - 45 XX.X Ash Content %
46 - 50 XXXXX Heat Content Btu/(SCC)*
* (SCC): Units defined by SCC category used.
-------
Card Column Format
51 - 70 AuuA
71 A
78 X
79 P
80 6
Parameter
Comments
Units
Source**
Action Code
Point Source Code
Point Source Card Code
** B ;; Boil er
P = Industrial Process
S = Solid Waste Disposal
8.2 AREA SOURCE CARD FORMAT
Residential Fuel Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 11 XX Year of Record
2
12 - 16 XXXXX Emissions Estimate - 10 Tons
Particulate
17 - 21 XXXXX Emissions Estimate - S02 2
lOT ons
22 - 25 XXXX Emissions Estimate - NOx 102 Tons
26 - 30 XXXXX Emissions Estimate - HC 102 Tons
31 - 35 XXXXX Emissions Estimate - CO 102 Tons
36 - 37 X.X Sulfur Content - Anthracite %
38 - 39 X.X Sulfur Content - Bituminous %
40 - 41 X.X Sulfur Content - Distillate
Oil %
43 - 43 X.X Sulfur Content - Residual
Oil %
XX.X
44 - 46 XX.X Ash Content - Anthracite %
47 - 49 XX.X Ash Content - Bituminous %
50 - 53 Residential 1
XXX X Fuel - 10 Tons
Anthracite
163
-------
Card Column Forma t Parameter Units
54 - 58 XXXXX . Residential Fue 1 - 1
lOT ons
Bituminous
59 - 63 . XXXXX Residential Fuel - 4
10 ga 1
Di.still ate
64 - 68 XXXXX Residential Fuel - 104 gal
Res i den t i a 1
69 - 73 XXXXX Residential Fuel - 107ft3
Natural Gas
74 - 77 XXXX Residential Fuel - Wood 1
lOT ons
78 X Action Code
79 A Area Card Code
80 Area Card Code Number
Commercial, Institutional, and Industrial Fuel Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 14 XXXXX Commercial and Institutional 101 Tons
Fuel - Anthracite
15 - 19 XXXXX Commercial and Institutional 101 Tons
Fuel - Bituminous
20 - 24 XXXXX Commercial and Institutional 104 gal
Fuel - Distillate Oil
25 - 29 XXXXX Commercial and Institutional 104 gal
Fuel - Residual Oil
30 - 33 XXXX Commercial and Institutional 107 ft3
Fuel - Natural Gas
164
-------
Card Column Format Parameter Units
34 - 35 XX Commercial and Institutional 102 Tons
Fuel - Wood
36 - 41 XXXXXX Industrial Fuel - Anthracite 10 1 Tons
42 - 47 XXXXXX Industrial Fuel - Bitumi nous 101 Tons
48 - 51 XXXX Industrial Fuel - Coke 1
10 Tons
52 - 56 XXXXX Industrial Fuel - 0 i s t i 11 ate 104 gal
Oil
57 - 61 XXXXX Industrial Fuel - Residual 104 gal
Oil
62 - 66 XXXXX Industrial Fuel - Natural 107 ft3
Gas
2
67 - 69 XXX Industrial Fuel - Wood 10 Tons
70 - 73 XXXX Industrial Fuel - Process 107 ft3
Gas
78 X Action Code
79 A Area Card Code
80 2 Area Card Code Number
1'65 '
-------
Waste iJisposal and Mobile Fuel Card
Card Column Format Parameter Units
1 - 2 XX State Code
3 - 6 XXXX County Code
7 - 9 XXX AQCR Code
10 - 15 XXXXXX Residential On-Site 101 Tons
Incineration
16 - 20 XXXXY. Industrial On-Site 102 Tons
Incineration
21 - 24 XXXX Commercial and Institutional 102 Tons
On-Site Incineration
25 - 30 XXXXXX Residential Open Burning 102 Tons
31 - 36 XXXXXX Industrial Op~n Burning 102 Tons
37 - 42 XXXXXX Commercial and Institutional 102 Tons
Open Burning
43 - 49 XXXXXXX Gasoline Fuel - Li ght 103 gal
Vehicle
50 - 54 XXXXX Gasoline Fuel - Heavy 103 gal
Vehicle
55 - 59 XXXXX Gasoline Fuel - Off 103 gal
Highway
60 - 64 XXXXX Diesel Fuel - Heavy Vehicle 103 gal
65 - 67 XXX Diesel Fuel - Off Highway 104 gal
68 - 72 XXXXX Diesel Fuel - Ra i 1 104 gal
Locomotives
73 - 76 XXXX County Population 103 persons
77 X Density Code
78 X Action Code
79 A Area Card Code
80 3 Area Card Code Number
166
-------
Mobile Source Card
Card Column
1 - 2
3 - 6
7 - 9
10 - 13
14 - 18
19 - 23
24 - 27
28 - 31
32 - 36
37 - 40
41 - 46
47 - 51
52 - 57
58 - 63
64 - 69
70 - 76
78
79
80
Forma t
xx
XXXX
xxx
xxxx
xxxxx
xxx XX
xxxx
xxxx
xxxxx
xxxx
xxx XXX
xxxxx
xxxxxx
xxxxxx
xxxxxx
xxxxxxx
X
A
4
Parameter
State Code
County Code
AQCR Code
Military Aircraft
Civil Aircraft
Commercial (Air Carrier)
Aircraft
Units
2
LTO - 10 cycles
L TO - 101 cycles
LTO - 101 cycles
Vessel Fuel used in County;. 101 Tons
Anthracite
Vesse 1 Fuel used in County; . 104 gal
Diesel Oil
Vessel Fuel used in County;
Residual Oil
Vessel Fuel used in County;
Gasoline
Evaporation - Solvent
Purchased/year
Gasoline Marketed
Limited Access Roads,
Measured Vehicle Miles
Rural Roads, Measured
Vehicle Miles
Suburban Roads, Measured
Vehicle ~1iles
Urban Roads, Measured
Vehicle Miles
Action Code
Area Card Code
Area Card Code Number
104 ga 1
103 ga 1
Tons
5
10 gal
104 mi
104 mi
104 mi
104 mi
167
-------
Miscellaneous Source Card
Card Column
1 - 2
3 - 6
7 - 9
10 - 16
17 - 21
22 - 26
27 - 31
32 - 38
39 - 41
42 - 47
48 - 50
51 - 54
55 - 57
58 - 61
62 - 67
68 - 70
78
79
80
168
Format
xx
XXXX
xxx
XXXXXXX
XXXXX
XXXXX
xxx xx
XXXXXXX
XXX
xxx xxx
xxx
XXXX
XX.X
XXXX
XXXXXX
xxx
X
A
5
Parameter
State Code
County Code
AQCR Code
Vehicle Miles. Traveled,
Dirt Roads
LTO, Dirt Airstrips
Land Area Construction
Rock Handling and Storage
Forest Fires - Area Burned
Forest Fires - Quantityj
acre
Slash Burning (brush fires-
areas burned)
Slash Burning (brush fires-
quantity burned)
Frost Control, number of
orchard heaters
Units
103 mi
LTO cycles
3
10 acres
3
10 Tons
acres
Tjacre
acres
T j acre
2
10 heaters
Number of days heaters firedj dajyr
year
Structural Fires
Coal Refuse Burning -
Size of Bank
Number of Coal Refuse fires
burning
Action Code
Area Card Code
Area Card Code Number
firesjyr
102 yd3 jyr
fi resjyr
-------
.-
Comment Card
Card Column Format Parameter
1 - 2 XX State Code
3 - 6 XXX X County Code
7 - 9 XXX AQCR Code
10 - 77 A----A Comments
78 X Action Code
79 A Area Card Code
80 6 Area Card Code Number
8.3 TRACE MATERIALS/HAZARDOUS POLLUTANTS SOURCE CARD FORMAT
Spaces Format Symbol Description Units
1 - 19 (Same identification codes used on original coding form)
20 - 21 XX Numerical Year of Record
22 - 26 XXXXX Numeri ca 1 Pollutant
Code
27 - 29 XXX Numerical Primary Control Device
Code
30 - 32 XXX Numerical Secondary Control Device
Code
33 - 35 XX.X Numerical Collection Efficiency %
36 - 42 XXXXX.XX Numerical Emission Estimate T/yr
43 X Numerical Method of Estimating Emissions
Code
44 X Numerical Emissions included in Emission
Code Estimated on Card 4
45 X Numerical Chemical Form of Emissions
Code
46 - 52 XXXXX.XX Numerical Allowable Emissions T/yr
53 X Numerical Compliance Status
Code
54 - 57 XXXX r~umeri ca 1 Compliance Schedule yr/mo
Code
58 - 63 XXXXXX Numerical Compliance Status Update yr/mo/da
Code
169
-------
I
I
8.4 SOURCE ClASSIFICATION CODE CARD FORMAT
Source Classification Code Format
Card Column Format Parameter
SCC - Category I
2 - 3 II SCC - Category II
4 - 6 III SCC - Category III
7 - 8 IV SCC - Category IV
9 - 10 Blank
11 - 27 AnnA Category I Name
28 - 44 AnnA Ca tego ry II Name
45 - 61 An--A Category II I Name
62 - 78 AnnA Category IV Name
80 Card Number
170
Emission Factors Units Format
Card Column Format Parameter
X SCC - Category I
2 - 3 XX SCC - Category II
4 - 6 XXX SCC - Category III
7 - 8 XX SCC - Category IV
9 - 10 Blank
11 - 79 A--nA Source Units Name
80 2 Card Number
-------
*
Emission Factors Cards Format
Card Column
Fonl1at
Parahleter
2 - 3
4 - 6
x
XX
SCC - Category I
SCC - Category II
7 - 8
9 - 10
xxx
xx
SCC - Category III
SCC - Category IV
Blank
11 - 19
XXXXXXXXX**
Emission Factor for Particulates
20 - 21
22 - 23
xx
Confidence Level for Particulates
Blank
24 - 32
33 - 34
XXXXXXXXX**
Emission Factor for S02
Confidence Level for S02
Blank
xx
35 - 36
37 - 45
XXXXXXXXX**
Emission Factor for NO
x
Confidence Level for NO
x
46 - 47
48 - 49
xx
Blank
50 - 58
59 - 60
XXXXXXXXX**
Emission Factor for HC
xx
Confidence Level for HC
61 - 62
63 - 71
Blank
XXXXXXXXX**
Emission Factor for CO
72 - 73
xx
Confidence Level for CO
80
3. . .N
Card Number
* There may be more than one card having this format if the number of factor
classifications (pollutants) is greater than 5. In this case card number
and factor number would increase accordingly.
** One of these positions should be used for a decimal point where necessary.
171
-------
8.S GEOGRAPHICAL CARD FORMAT
STATE CARD
Card Column
1 - 2
53 - 73
80
EPA CARD
Card Column
1 - 2
1 0 - 34
80
AQCR CARD
Card Column
1 - 3
1 0 - 64
65
66
67
68
69
70
71
72
73
74
75
76
80
172
Format
XX
A----A
Format
XX
A----A
2
Format
XXX
A----A
x
X
X
X
X
X
X
X
X
X
X
X
3
Parameter
State 1D Number
State Name
File Number
Parameter
EPA Region 1D Number
EPA Region Name
Fil e Number
Parameter
AQCR 1D Number
AQCR Name
AQCR Particulate Classification
AQCR Particulate single point emission
significance
AQCR S02 Classification
AQCR S02 single point emission significance
AQCR NOx Classification
AQCR NO single point emission significance
x
AQCR HC Classification
AQCR HC single point emission significance
AQCR CO Classification
AQCR CO single point emission significance
AQCR Photo-chemical Classification
AQCR Photo-chemical single point emission
significance
Fil e Number
-------
courny CARD
Card Column Format Pdrameter
1 - 2 XX State 10 Number
3 - 6 XXX X County IO Number
7 - 8 XX EPA Region 10 Number
9 - 11 XXX AQCR IO Number
12 - 16 XXX XX County Area (mi2)
53 - 80 A----A County Name
173
-------
APPENDIX (
POINT SOURCE DEFINITION
A point source is defined as any emitting point or plant/facility whose summa-
tion of emitting points totals 100 tons or more per year of anyone of the five
primary pollutants: CO, S02' NOx' particulates, or hydrocarbons; or as any of the
pollutant sources listed below, regardless of quantity of emissions.
A.
Chemical Process Industries
1. Adipic acid
2. Ammonia
3. Ammonium nitrate
4. Carbon black
5.
6.
Charcoal
Chlorine
7. Detergent and soap
8. Explosives (TNT and nitrocellulose)
9. Hydrofluoric acid
10. Nitric acid
11. Paint and varnish manufacturing
12 Phosphoric acid
13. Phthalic anyhdride
14. Plastics manufacturing
15. Printing ink manufacturing
16. Sodium carbonate
17.
18.
Sulfuric acid
Synthetic fibers
19. Synthetic rubber
20. Terephthalic acid
175
-------
176
LL
C.
Food and Agricultural Industries
1.
2.
Alfalfa dehydrating
Ammonium nitrate
3.
4.
Coffee roasting
5.
Cotton ginning
Feed and grain
6.
7.
Fermentation processes
Fertilizers
8.
9.
Fish meal processing
Meat smoke houses
10.
Starch manufacturing
11.
Sugar cane processing
t1etallurgical Industries
1.
Primary metals industries
a.
Aluminum ore reduction
b.
Copper smelters
Ferroalloy production
c.
d.
Iron and steel mills
e.
Lead smelters
f.
Metallurgical coke manufacturing
g.
Zinc
2.
Secondary metals industries
a. Aluminum operations
b. Brass and bronze smelting
c. Ferroalloys
d. Gray iron foundries
e. Lead smelting
f. Magnesium smelting
g. Steel foundries
h. Zinc processes
-------
D.
E.
F.
G.
H.
Mineral Products Industries
l.
2.
Asphalt roofing
Asphaltic concrete batching
3.
4.
Bricks and related clay refractories
Calcium carbide
5.
6.
Castable refractories
Cement
7.
8.
Ceramic and clay processes
Clay and fly ash sintering
9.
10.
11.
Coal cleaning
Concrete batching
Fiberglass manufacturing
12.
13.
Frit manufacturing
Glass manufacturing
14.
15.
Gypsum manufacturing
Lime manufacturing
16.
17.
Mineral wool manufacturing
Paperboard manufacturing
Perlite manufacturing
18.
19.
Phosphate rock preparation
20.
Rock, gravel, and sand quarrying and processing
All Petroleum Refining and Petrochemical Operations
All Wood Processing Operations
Petroleum Storage (storage tanks and bulk terminals)
Miscellaneous
1. Fossil fuel steam electric powerplants
2. Municipal or equivalent incinerators
3. Open burning dumps
!. Hazardous Pollutant Sources
177
-------
D.I
APPENDIX D
EXAMPLE QUESTIONNAIRES
EXAMPLE COVER LETTER
Dear Sir:
The (agency or board) requests your
cooperation in providlng the information asked for on the
enclosed questionnaire concerning the operation of your
facilities. The data provided will be evaluated and trans-
lated into emissions of pollutants to the atmosphere and added
to the total emissions from all sources in the stud area.
This source information will enable the a enc or board
to develop air pollution control programs necessary for
compliance with re~uirements of the Federal Clean Air
Amendments of 1970.
This emission survey is being conducted under provisions of
wrric~~~ ~:c~~~~ ~~ni;:;; i~wfhe ~on}~~~~~~~~~~yf~~~v;~~~nS~~vey
(cite section of State Law) or Sec. 114 (c) of the Clean
Air Amendments of 1970 concerning the divulgence of methods or
processes entitled to protection as trade secrets.
The questionnaire is separated into four sections: fuel
combustion, refuse disposal, process losses, and stack data.
Each section should be completed regardless of the magnitude
or type of material handled, processed, or burned. In completing
the questionnaire, give a different number to represent each
source in Section I, II, and III and then give stack data opposite
the same number or numbers in Section IV. If you require
additional information or assistance, you may contact (name)
of this office, telephone
We would appreciate the return of the questionnaire by (date)
Your cooperation and expeditious completion of the inventory
forms are urgently requested.
D.2
A.
INSTRUCTIONS FOR COMPLETING QUESTIONNAIRE
General Instructions
1.
Please return questionnaire by
2. All information is to be based on data; if
this is not possible, specify the base year used.
3.
Complete all sections of the form that pertain to
your firm.
4. The small letters in each column refer to the foot-
notes at the bottom of the page. Please utilize these
in answering each section.
179
-------
5.
If emission rates are available from measurements or
computations, they should be included in the appropriate
columns, along with supporting data. If emission data
are unavailable, the emission column may be left blank.
In such case, emissions will be calculated by the staff
based upon data supplied. Calculations and factors
utilized in determining final emissions will be for-
warded to the originator of each questionnaire upon
request.
If there is more than one plant location, please
indicate totals for each location.
6.
7.
If additional questionnaires are needed they can be
obtained at the following location:
8.
If you have any questions, please contact
at Area Code
B.
Specific Instructions
Section I - Fuel Use
1. This section refers to the total amount of fuel
consumed on the premises. List the quantities of
fuel consumed as designated by footnotes. If
there is more than one plant location, list fuel
consumption for each location.
2. When estimating the percentage of fuel consumed
for process heat, include power generation in the
category.
Column E should be completed regardless of the
type or quantity of fuels consumed.
Section II - Refuse Disposal
3.
1.
This section refers to the total quantity of re-
fuse generated on the premises. Please estimate
the amount of refuse produced regardless of the
method of disposal (Column B).
If off-site disposal is used, please indicate
name of hauler and location of disposal site.
Section III - Process Emissions
2.
1. This section refers to the quantity of material
processed or used to produce the items manufactured
by your establishment and includes emissions from
liquid storage facilities.
Please indicate in Columns A, B, and C, the types
of processes, the types of materials used in these
processes, and the amounts of these materials
2.
1M
-------
3.
utilized on an annual basis; for example, the
amounts of limestone, sand, coal, and blast furnace
dust used to produce cement.
Any process descriptions, equipment types, flow
charts, etc. that will assist in calculating
process losses should be included.
In Column E, list total flow rate for stacks and
vapor losses for storage facilities.
Section IV - Stack Data
4.
1.
This section refers to any stacks which vent
emissions from any source listed in Sections I
through III above.
2.
Please list all stacks on the premises and identify
which sources are vented from the stack in the
column titled "Sources Vented."
3.
If test values are not available, please show
design, calculated, or estimated values and
indicate as such.
Additional Information
In addition to the information requested in Sections I and
III, please write the following information on the back
side of the questionnaire.
1.
Fuel Use
a.
Average fuel use in gallons or cubic feet
per hour
Maximum fuel use in gallons or cubic feet
per hour
b.
2.
Material Process Rate
a. Average material process rate in pounds, tons,
or gallons per hour
b. Maximum material process rate in pounds, tons,
or gallons per hour
181
-------
A.,.,.!n To:.
FOR OFFICE USE ONLY
1
CD
N
D.3
AIR POllUTANT EMISSIONS SURVEY
Recei.ed l3y:
R~"i~wed By:
Counly:
SIC Numbe,:
Coordit1oles:
Informorion is 10 be ,epresenloli.e of Calendar Year
Firm name:
Person to conlact regarding this
Moiling address:
Plonl odd,ess:
Nolure 01 business: (Products)
Employees 01 plont locolion:
report:
Tille:
Phone:
If seasonal, give range
Approximole land area 01 plonl 10Colion:
SECTION 1 - FUEl USE FOR GENERATION OF HEAT. STEAM. AND POWER
Normal opera ling schedule:
Seasonal ond....r peak ope,olion period: (Specily)
Es,imole of percen' of to'ol fuel ccnsumed to provide
Hours per day
Day s per week
Weeks pc, year
space heat:
A B C D E F G H I J K l
Size of Fuel dOlo /01 Air cleanin e"ui"lTIen' EstltT\Qle of c:cnfominon!s 1M)
Source unit(input)(B~ Type Installation Type Heat conlent (C;) Percent ash Efficiency IJI
No. ICI Dot. A n10unt Percent Type III Type IKI Quantity t loa)
106 B.u hr unit fvellFI year (FI B.v sulfur (G-H) (cool only) (G-H ~
pe, ..
-
.. -..
-- '---- - --. - -- .-.--- u -- -..-
SECTION II - REFUSE DISPOSAL
Refuse di sposed 01
Normal on.site combustion operating schedule:
5eo$onol ond/o, peak operolion period: (Specify)
Hours per day
Off si t. - Location of di sposo I site and/or nome of houl'er:
Day s per week W,...k s per year
On site
A B C D E F G H
Woste ,"olerial Method of dispo$ol Incinerator Type and efficiency. Estimate ot conlamlnon's 'MI
50\.1rc. Type IN) Amount per year tFI capacity. Auxiliary air cleaning Quontity
(See Code Page 2) '".1 uled 101 TypolK;
Na.IA) Ib,+.r equipment :I.JI per yeor IL.l
I
I
L-P'
PAGE I
USE ADDITIONAL S"EETS IF NECESSART
-------
SECTION III - PROCESS EMISSIONS
Normol operoting schedule:
Seasonal and/or peak operation period:
NOTE: For intermittent operations, indicote approximate
Hours per day
Day s per week
WeeN s per y cor
frequency and duration 50 thot estimates of yearly emissions may be obtained.
A B C D E F G H I
F\oc""es 0' Materials processed and/or Estimate 01 contaminants (M) 80sis 01 estimole (R)
5 oure e operations releosing Instollation used 01 operations Quantity 01 gas Type and effjciency
No!AI discharged ',om 0 ir c leoning (Pleose specify basis)
contaminonts '0 Dote
TypelQI Quantity per yeor IFI process 0' operation equi pme"' IloJ) Type (KI Quantity per yeoi l}
olmos phore (II' P)
bGiye a different no.'o ,opresen' eoch source and then give stack doto opposite the lame numb"r 0" Section IV.
Nome~late data ore suHiciont.
~Hond-firt'd; underf~cd. tr=v"ling-?rore or sprll!oder stoker; cyclone furnaco; pulyerized, wot or d,y bottom wirh or wirhour fly ash ,einiection; rorory or Qun..type oil b"r"e,; etc.
Fuel data are to br rr;:>ortcd on . a~ burned basis"
fCaL-e, bituminous ccai, anthroc:lc cool; No.1, 2. J, 5 or 6 fuel oil; natural gas; LR:i; ,efinery or coke oven gas; wood, .tc.
Pounds, tans, or 901l0"s ocr yeor.
~If un~na.....n, plecsf8 give nome and address of fuel supplier.
. Sulfur and ash cO:"!'enr lor f"och fuel ,hould be a weighted overage.
~ C).clone, scrubber, electrostatic preciptlator, baghou:;e, settling chamber, etc.
LPleose state if eHlciency is 0 rated or operating efficiency,
J Fly ash, sulfur oJr..~es, etc. (Include chemlcol description).
A:J",nd. or 'ons per y~Ot.
'"Ci„e Itock 'esf dot a If o„oiloble, 0' otherwise specify basis used.
nRIoIbb'sh, gorboge, mixed garboge and rubbi$h, wasre paper. wood chips or sawdu!;', etc.
o',..dlcote whe.h.r cU'l:iliory 'yel i:o used in incinerator, and pit byrning. and the amount.
PS"If",riC acid..chamber, olwminvm Imelting-crucible furnace, iron melting-cupola, cement manufacture-dry process, solvent cleaning, or oth.r (please specify).
qAcid prod",ced, ton,; metal charged or processed, tons; cemonr prodvc:ed, bbl.; solvent c:onsunled, 90110ns, etc. per yoor.
'Proc.., ",at.riol balance .tudie., field tes's by plont or by equipment manufactu'ers, or other basis.
'List aayrc.. Seclions I, I" III which utilize each .toci.;.
METHOD OF DISPOSAL CODE:
1, Ope,,-burnil"lg dump.
2. Sanitary landfili. (no bvrning)
3. Burned in boiler or Ivrnoce.
4. Incinerator, sing:i. chamber.
S. Incinerator, multiple chamber
6. Incinerator, rotary.
7. Conical metal burner.
S Other (Specify)
SECTION IV - STACK DATA
HEIGHT INSIDE EXIT GAS
SOURCES VENTED 151 (Feet) DIAMETER
(Fee.) Temperature of Velocity(FPS) Moi sture (%)
Dot.
Any suppl.mentol moterial O( dato considered pertinent (flow diograms, reports, summaries, telt results, maps) should be lubmitted with this form.
Nom. ond titl. 01 officiol submitting r.porta
(X)
W
PA GE 2
USE ADDITIONAL SHEETS .F NECESSARY
-------
D.4 CRUDE OIL DRILLING, NATURAL GAS, AND LPG FACILITIES
Return to:
DATA FOR YEAR
OFFICE USE ONLY
Rec I d by:
Revi ewed by:
County:
Coordinates: .
SIC No. :
I. General Information
A. Company Name
Plant Address City State
Mail ing Address City State
B. Person to contact about this form
Telephone
C. Operating Schedule:
Pos iti on
other than continuous operation, please specify
II. Process Information
A. Urilling Operations: Type of well (natural gas or crude)
Quantity pumped (bbl, gal, cu. ft. per yr.)
Oil
Water
Casing-head gasoline
Amount Flared
Sulfur content of crude
H2S Content
(bbl, gal per yr.)
B.
Sump Loss
Crude Handling and Storage
Amount transferred to storage
(bbl, gal per yr.)
Type storage tanks (floating or fixed-roof)
Height
(ft.) Diameter
(ft. )
I~o. of Tanks
Sump Loss (bbl/yr.)
C. Natural Gas Operations and LPG Plants
Cu. ft. processed/yr. (compressed, absorbed,
etc.) specify processes
Fuel burned/yr.: In boilers
Boiler Capacity (BTU/Hr)
Oia. (ft.) Exit Vel.
NOTE: Fill out separate questionnaires
In Gas Engi nes
Stack Height (ft.)
(ft/sec) Exit Temp.
for each location
of
184
-------
,-
D.S
CONCRETE BATCH PLANTS
Return to:
DATA FOR YEAR
OFFICE USE ONLY
Rec I d by:
Reviewed by:
County:
Coordinates:
SIC No.:
I. Genera 1
A. Company Name
Plant Address
City Zip Code
B. Person to Contact
Name
Position
Telephone No.
C. Average i~umber of Employees
D. Operating Schedule
Hrs/Day (if seasonal, qive ranqe)
Days/Year
II.
Process Information
A. Amount Produced During Year
(tons) or
(cubic vards)
B.
Control Equipment
Type
Efficiency
Installation Date
%
185
\.
t..
-------
D.6
CONICAL BURNERS
Return to:
IJATA FOR YEAR
OFFICE USE ONLY
Rec'd by:
Reviewed by:
County:
Coordinates:
SIC No.:
I. General
A. Name
Burner Location
City
B. Person to Contact
liame
Pos it ion
C. Operating Schedule
Zip Code
Telephone No.
Hrs/Day (if seasonal. give range)
Days/Year
II. Process Information
A. Burner Data
Base lJiameter
Height
B. Firing lJata
Percent Excess Air
Type Overfire
Method Charge
C. Waste Information
Top Diameter
Top Screen Size
Exit Gas Temp.
(Tanqential or Radial)
(Bulldozer. conveyor or other)
~
Municipal Refuse
Sawdust
Planer Shaving
Bark
Other (please specify)
Amount (Tons/Year)
III. Control Equipment
Type
Percent Efficiency-----Installation Date
186
-------
D.7
SAWMILLS
Heturn to:
DATA FOR YEAR
OFFICE USE ONLY
Rec I d by:
Reviewed by:
County:
Coordinates:
SIC No.:
1.
General
A. I~ame of Company
Pl ant Address
City State Zip
B. Person to Contact Position
C.
Telephone No.
Operating Schedule
I1rs/Day
Days/Year
II.
Process Information
A. Uust Producing Operations
1. Amount/Year (Tons) processed in each step:
Debarking
Cutting
Planing
Other
2. Is a burner used at this site? Yes /7 No n
If yes, give amount burned/year (Tons) , and:
a. Uate of Installation
b.
Base iJia. (ft.)
Burner Uata:
Top Dia. (ft.)
Height (ft.)
Top Screen Size
Capaci t,Y
c.
Firing Uata:
% Excess Air
Exit Gas Temp~oF
Type Overfire - tangential or radial
14ethod of Charge - Bu 11 dozer, conveyor, or other,
d.
Control Equipment:
Percent Efficiency
Type
Date of Installation
187
-------
D.8 PEANUT PROCESSING
00
00
Return to:
DATA FOR YEAR-----1
OFFICE USE ONLY
Rec'd by:
Reviewed by:
County:
Coordinates:
SIC No.:
I . General
A. Company Name
Plant Address
B. Person to Contact
C. Average Number of Employees
D. Operating Schedule
City
Position
Zip
Telephone No.----
Hrs/Day
Days/Year
II. Process Information
A. Use: Type
Control Equipment
Amount
Efficiency
%
B. 'Process
Amount Processed %
Type of Process (Tons) Control Equipment Control Installation Date
Roaster, direct-fired
Roaster, indirect-fired
Shell inq
Blanchinq
Other
-------
D.9 COTTON GINNING
Return to:
DATA FOR YEAR
OFFICE USE ONLY
Rec'd by:
Reviewed by:
County:
Coordinates:
SIC No.:
1.
General
A. Company r~ame
Plant Address
City
Zip Code
B.
Person to Contact
Name
Position
Telephone No.
C. Average Number of Employees
U. Operating Schedule
r10nths of Operation (Jan., Feb., etc.)
Hrs/Day
Days/Year
II. Process Information
A.
Bales of Cotton Ginned During Year
(500 lb. bales)
B. Gin Trash Disposal
Open Burning
(tons)
( tons)
Land Fill
Composted
(tons)
( tons)
(tons)
Hauled Off
Other
C. Control Equipment
Type
Efficiency
Installation Date
%
189
-------
1--..
!
D.10 ASPHALT BATCH PLANTS
Return to:
UATA FOR YEAR
OFFICE USE ONLY
Rec'd by:
Reviewed by:
County:
Coordinates:
SIC No.:
1.
General
A. Company Ijame
Plant Address
City
Zip Code
B.
Person to Contact
Name
Position
Telephone No.
C. Average Numuer of Employees
Hrs/Day (if seasonal, give ranqe)
Days/Year
II.
Process Information
A. Amount of Asphalt Produced Uuring Year
B. Control Equipment on Dryer
(Tons)
Equipment Type
% Efficiency
Installation Date
Precleaner
Cyclone
Scrubber
Centrifugal
Orifice Type
Baffle Spray Tower
Bag House
Other
C.
Fue 1 Use
Type
Amount
190
-------
D.n
GRAIN HANDLING
Return to:
DATA FOR YEAR
OFFICE USE ONLY
- Rec'd by:
Reviewed by:
County:
Coordinates:
SIC No.:
I.
General
A.
Company i~ame
Plant Address
City
Person to Contact
Zip Code
B.
C.
u.
Name
Position
Telephone No.
Average Number of Employees
Operating Schedule
Hrs/Day (if seasonal, give range)
iJays/Year
Process Information
A. Terminal Elevators
1. Shipping or Receiving
2. Transferring, Conveying, etc.
3. Screening and Cleaning
4. Urying
B. Country Elevators
1. Shipping or Receiving
2. Transferring, Conveying, etc.
3. Screening and Cleaning
C. Grain Processing
1. Alfalfa iJehydrating
2. Alfalfa Meal Milling
3. Corn r~ea 1
4. Soybean Processing
5. Malted Barley or
Wheat Cleaner
6. *Milo Cleaner or
Rice Dryer
7. *Barley Flour or
Ri ce Mi 11 i ng
8 . Wheat Mill i ng
0. *Feed Manufacturing
E. Control Equipment
1. Type of iJust Collector(s) (Specify
for each process with emissions)
2. iJesign Efficiency
3. Quantity Retained in collector{s}
*Specify which
II.
Tons/Year
separately
191
-------
\0
N
D.12
PETROLEUM REFINING
Return to:
OFFICE USE ONLY
Rec'd by:
Reviewed by:
County:
Coordinates:
SIC No:
DATA FOR YEAR
I. General Information
Fi rm Name
Person to Contact
Address of Plant
Mail ing Address
Amount of Crude Processed
Employees at Plant Site
Normal Operating Schedule
Type of Sulfur Recovery System
II: Fuel Use for Generation of Heat,
Title
Telephone
City
City
Barrels/Year. Plant Capacity
Land Area at Site
Hours/Day
. Amount Removed
Zip
Barrels/Day.
Days/Year.
. Method of Disposal---
Power, Steam
A B C D E F G H Stack Data
Source Size Unit Installation Type Amount Heat Percent Heigh1 Di a Exit Velo Exit
['lumber (incut)lO BTU/Hr Date Fuel Per Year Content Sulfur Ft. Ft. citv fps TmpoF
-------
III.
(a)
Process Information
Process or Operation Materials Processed and/or Control E uipment
Releasing Contaminants Used at Operation Instal.
Number To Atmosphere Type Quantity/Year Tvee Date Efficiencv
101 Catalytic Cracking Unit
Tvpe Fresh Feed Rarrels
102 Cool i ng Towers Cooling Water 106 Gal s
103 Vacuum Jets Vacuum Feed Barrels
104 Process Drains Waste Water Barrels
. . C6mpres!;br Int. Comb. 1000 Ft. 3
105 Engines Gas
106 Blowdown Systems Emissions Will be Estimated
from Plant Capacity
Storage Tank 10; Gal Total Capaci3Y
Number Fixed-Roof 10 Gal
107 Number Floating-Roof 1 0 Gal 1 03 Gal
IV.
(a)
Emission and Stack Information for above Processes
I -
Check Tvee Stack Data Emission Estimates ITons Year! 0 Atmosehere
V! Q) +-' u.. ::5 "O 0
Q) '+- V! > +-' - - .,....- 0 U ~ V! c.,.... I C I C
uOQ)Q) -"= Q) I-><: E '''''' ~ UV! '"", V! ::5 Q) 0 X 00 0 0 ~ V! I
~ U> U ~ +-'V! 0'> +-' . +-' +-'00. +-' a. +-,Q) 4-"0 .00 ~.o ~ ..o Q) .,.....,.... <1J
::5 . 00 to I~ c~ '"", V! .,.... u.. to u.. .,... r-- ~ .,.... E ~+-' ......,.... ~ C "O~ +-'c~ ..s:: V! +-' +-'
OO~.O +-' tOtO 0'> 0 Q)- .,....- XQ)- XQ) to to ::5X to 0 »to .,... QJ I'tS +-' to V! to
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TECHNICAL REPORT DATA
(Plcas(' read [us.uucliolls Oil lhe revers(' before comp/eling)
1. REPORT NO. ____l:~___- 3. RECIPIENT'S ACCESSION-NO.
AP'fD-1l35
4. TITLE AND SUBTITLE 5. REPORT DATE
GUIDE. FOR COMPILING A COMPREHENSIVE EMISSION INVENTORY, ~~ember 1974
SECOND EDITION 6. PERFORMING ORGANIZATION CODE
,
7. AUTHOR(S) 8. PERFORMING ORGANIZATION REPORT NO.
9. PERFORMINy OR~'ANIZATION NAME Af\jD AD}\RESS 10. PR('GRAM ELEMENT NO.
U.S. Env1ronmental Protect10n gency
Office of Air and Waste Management 11. CONTRACT/GRANT NO.
Office of Air Quality Planning and Standards
Research Triangle Park, North Carolina 27711
12. SPONSORING AGENCY NAME AND ADDRESS 13. TYPE OF REPORT AND PERIOD COVERED
Final
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
16. ABSTRACT
Detailed procedures are given for obtaining and codifying information about air
pollutant emissions from stationary and mobile sources. The system has been de-
veloped specifically for use by state and local air pollution control agencies.
Because of the large amount of information that must be collected, the data must be
handled by automatic data processing means.
A uniform coding system for the data is encouraged in order that the information from
one region may be compared with that from another. Detailed procedures are given
concerning the information to be gathered from each source, the methods to be used
to gather the information, the codes to be used to simplify the information on
standard coding fo~s, the geographical and population information needed about the
area of interest, the apportionment techniques and emission factors needed, and the
methods of displaying the data. The relation of state and local emission inventory
systems to the Environmental Protection Agency's National Emission Data System is
also explained.
17. KEY WORDS AND DOCUMENT ANALYSIS
a. DESCRIPTORS b.IDENTIFIERS/OPEN ENDED TERMS c. COSATI Field/Group
Air pollution
Emission inventories
Mobile sources (air pollution)
Stationary sources (air pollution)
18. DISTRIBUTION STATEMENT 19. SECURITY CLASS (This Report) 21. NO. OF PAGES
Unclassified 203
Release unlimited 20. SECURITY CLASS (This page) 22. PRICE
Unclassified
EPA Form 2220-1 (9-73)
194
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INSTRUCTIONS
1.
REPORT NUMBER
Insert the EPA report numher as it appears on the cover of the publication.
2.
LEAVE BLANK
RECIPIENTS ACCESSION NUMBER
Reserved for use by each report recipient.
3.
4.
TITLE AND SUBTITLE
Title should indicate clearly and brielly the subject coverage of the report, and be displayed prominently. Set suhtitle. if used, in smaller
type or olherwise subordinate i( 10 main lille. When a reporl is prepared in more (han one volume. repeal (he primary lirle, add volume
number and include subtitle for Ihe specific title.
5,
REPORT DATE
E'lCh report shall carry a date indicating at leasl month and year. Indicate the hasis on which it was selected (',K.. clale ofi",I'w', clale of
approvc1. clale of preparalion. ele.).
6.
PERFORMING ORGANIZATION CODE
Leave blank.
7.
AUTHORISI
Give name(s) in conventional order (John R. Doe. J. Roberl Doc, etc.), List author's affiliation if it differs from the performing organi-
zation.
8.
PERFORMING ORGANIZATION REPORT NUMBER
Inserl if performing organization wishes to assign this number.
9.
PERFORMING ORGANIZATION NAME AND ADDRESS
Give name, streel, cily, stale, and ZIP code. Lisl no more than (wo levels of an organizational hirean'hy,
10. PROGRAM ELEMENT NUMBER
Use the program clement number under which the report was prepared. Subordinate numbers may be included in parentheses.
11. CONTRACT/GRANT NUMBER
Inserl contract or grant number under which reporl Was prepared.
12. SPONSORING AGENCY NAME AND ADDRESS
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13. TYPE OF REPORT AND PERIOD COVERED
Indicale interim final, ele., and if applicable, dales covered.
14. SPONSORING AGENCY CODE
Leave blank.
15. SUPPLEMENTARY NOTES
Enler information nol included elsewhere bul useful, such as: Prepared in cooperation wilh, Translation of, Presented at conference of,
To be published in, Supersedes, Supplemenls, ele.
16. ABSTRACT
Include a brief (200 words or less) faclual summary of Ihe mosl significant information contained in Ihe report. If the report conlains a
significanl bibliography or literalure survey, mention it here.
17. KEY WORDS AND DOCUMENT ANALYSIS
(a) DESCRI PTORS - Select from the Thesaurus of Engineering and Scientific Terms Ihe proper aulhorized terms thai identify the major
coneepl of Ihe research and arc sufficiently specific and precise to be used as index enlries for calaloging.
(b) IDENTIFIERS AND OPEN-ENDED TERMS - Use idenlifiers for projeci names, code names, equipment designators, etc. Use open-
ended lerms writlen in descriplor form for Ihose subjee(s for which no descriptor exists.
(c) CaSAl'I FIELD GROUP - Field and group assignmenls are (0 be taken from the 1965 COSATI Suhject Category List. Since the ma-
jority of doeumenls are multidisciplinary in nature, the Primary Field/Group assignment(s) will be specific discipline, area of human
endeavor, or type of physical object. The applicalion(s) will be cross-referenced wilh secondary Field/Group assignments that will follow
the primary posling(s).
18. DISTRIBUTION STATEMENT
Denote releasabilily to the public or limitation for reasons other than security for example "Release Unlimited." Cite any availabilily to
the public, with address and price.
19. & 20. SECURITY CLASSIFICATION
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21. NUMBER OF PAGES
Inserl the total number of pages, including this one and unnumbered pages, but exclude distribution list, if any.
22. PRICE
Insert the price set by the National Technical Information Service or thl' Government I'rinting Office, if known.
EPA Form 2220.1 (9-73) (Reverse)
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