3A/450/3-78/012
EPA-450/3-78-012
»
March 1978
REGION VI LIBRARY
U, S. ENVIRONMENTAL PROMOTION
AGENCY
1445 ROSS AVENUE /
DALLAS, TEXAS 7520?
EVALUATION
OF HYROCARBON EMISSIONS
FROM PETROLEUM
LIQUID STORAGE
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Air and Waste Management
Office of Air Quality Planning and Standards
Research Triangle Park, North Carolina 27711
-------
EPA-450/3-78-012
1
I EVALUATION OF HYDROCARBON
J EMISSIONS FROM PETROLEUM
^ LIQUID STORAGE
C"\
V P.R. Peterson, P.S. Bakshi, A. Kokin, and L. Norton
'Q Pacific Environmental Services, Inc.
X 1930 14th Street
Santa Monica, California
Contract No. 68-02-2606
Work Assignment No. 1
\> EPA Project Officer: Richard K. Burr
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Air and Waste Management
Office of Air Quality Planning and Standards
Research Triangle Park, North Carolina 27711
March 1978
-------
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 - in limited quantities - from the
Library Services Office (MD-35) , U.S. 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.
This report was furnished to the Environmental Protection Agency by
Pacific Environmental Services, Inc. , 1930 14th Street, Santa Monica,
California, in fulfillment of Contract No. 68-02-2606. The contents of
this report are reproduced herein as received from Pacific Environmen-
tal Services , Inc . The opinions , findings, and conclusions expressed
are those of the author and not necessarily those of the Environmental
Protection Agency. Mention of company or product names is not to be
considered as an endorsement by the Environmental Protection Agency.
Publication No. EPA-450/3-78-012
11
-------
ABSTRACT
This study provides an estimate of 1976 nationwide hydrocarbon emissions
from storage of petroleum liquids in existing tanks with a capacity greater
than 150,000 liters. Numbers and types of existing tanks were determined to
estimate these emissions by geographical location, industry sector, and
volatility class of the stored products. Projections of emissions are made
for 1980 and 1985 assuming only newly constructed tanks meet the requirements
of the New Source Performance Standard (NSPS) for the storage of petroleum
liquids and then assuming existing fixed roof tanks storing products with
a volatility greater than 10.5 kPa are retrofitted with internal floating
covers. Other options such as the use of vapor recovery systems for fixed
roof tanks and double seals on external floating roof tanks were considered
beyond the scope of the study. A nationwide estimate of 1976 emissions by
petroleum liquid type stored is presented.
-------
TABLE OF CONTENTS
Section Page
1.0 SUMMARY 1-1
1.1 Emission Estimate Methodology 1-1
1.2 Emission Estimate Results 1-2
1.2.1 1976 Annual Hydrocarbon Emissions 1-2
1.2.2 1980 and 1985 Annual Hydrocarbon Emissions . 1-6
2.0 INTRODUCTION 2-1
2.1 Hydrocarbon Emission Estimates 2-1
2.2 Tank Cost Data - 2-2
3.0 EMISSION ESTIMATE METHODOLOGY 3-1
3.1 Tank Data Compilation 3-1
3.2 Tank Data Processing 3-3
3.2.1 Tank Data Tabulations 3-3
3.2.2 Emission Calculations 3-3
3.3 Emission Approximations 3-6
3.3.1 Refinery Emission Approximations 3-7
3.3.2 Pumping Station Emission Approximations. . . 3-7
3.3.3 Terminal Emission Approximations 3-3
3.4 1976 Emission Estimates 3-8
3.5 1980 and 1985 Emission Projections 3-9
3.5.1 Projected Number of Tanks 3-10
3.5.2 Projected Emissions 3-10
3.6 Applicability of Emission Equations 3-11
4.0 EMISSION ESTIMATE RESULTS 4-1
4.1 1976 Annual Hydrocarbon Emissions . 4-1
4.1.1 Estimated Numbers of Tanks 4-1
4.1.2 Current Emission Control Strategy 4-2
4.1.3 Alternative Emission Control Strategy. ... 4-2
4.2 1980 and 1985 Annual Hydrocarbon Emissions 4-3
4.2.1 Current Emission Control Strategy 4-3
4.2.2 Alternative Emission Control Strategy. ... 4-3
-------
TABLE OF CONTENTS (Continued)
Section Page
5.0 TANK COST DATA 5-1
5.1 New Tank Erection Costs 5-1
5.2 Internal Floating-Roof Installation Costs .... 5-2
6.0 CONCLUSIONS ' 6-1
7.0 REFERENCES : 7-1
APPENDIX A EMISSION ESTIMATE METHODOLOGY A-l
A-l Emission Calculations A-l
A.1.1 Emission Equations A-2
A.1.2 Emission Equation Input Parameters A-2
A.1.2.1 Meteorological Parameters A-3
A.1.2.2 Tank Design Parameters A-4
A.1.2.3 Petroleum Liquid Property
Parameters A-4
A-2 Emission Approximations A-ll
A.2.1' Refinery Tank Emission Approximations .... A-13
A.2.2 Pipeline Tank Approximations A-15
A.2.3 Terminal Tank Approximations A-15
A-3 Sample Calculation of Total Tank Emissions A-l7
A-4 1980 and 1985 Emission Projections A-18
A. 4.1 Projected Number of Tanks A-22
A.4.1.1 Projected Total Tank Storage
Capacity A-22
A.4.1.2 Projected Crude Oil Refining
Capacity A-24
A.4.1.3 Major Proposed Terminal Projects . . A-26
A.4.1.4 Tank Type Distribution A-29
A.4.2 Projected HC Emissions A-30
APPENDIX A REFERENCES A-31
-------
TABLE OF CONTENTS (Continued)
APPENDIX B TANK DATA FILE SUMMARY B-l
APPENDIX C EMISSION EQUATIONS C-l
APPENDIX D 1976 EMISSION ESTIMATES USING JANUARY AND
JULY METEOROLOGICAL CONDITIONS D-l
vn
-------
LIST OF ILLUSTRATIONS
Figure
3-1 Emission Estimate Methodology
3-2 Petroleum Administration for Defense (PAD) Districts
A-l Sample Emission Calculations Computer Printout . . .
3-2
3-4
A-20
LIST OF TABLES
Table
1-1
1-2
1-3
1-4
1-5
3-1
4-1
4-2
4-3
4-4
4-5
4-6
4-7
4-3
4-9
4-10
4-11
4-12
4-13
Summary of Tank Number Estimates for the Year 1976. . .
Summary of Annual HC Emission Estimates for the Year
1976
Comparison of Annual HC Emission Estimates for the
Year 1976
Comparison of Annual HC Emission Projections for the
Year 1980
Comparison of Annual HC Emission Projections for the
Year 1985
Tank Data Classification Cateaories
1976 Tank Number Estimates by Industry Sector
1976 Tank Number Estimates by Volatility Class
1976 Tank Number Estimates by Petroleum Liquid Type . .
1976 Annual HC Emission Estimates by Industry Sector. .
1976 Annual HC Emission Estimates by Volatility Class .
1975 Annual HC Emission Estimates by Petroleum Liquid
Type
1976 Annual HC Emission Estimates Assuming Alternative
Emission Control Strategy
1980 Tank Number Projections Assuming Current Emission
Control Strategy
1980 Annual HC Emission Projections Assuming Current
Emission Control Strateay
1985 Tank Number Projections Assuming Current Emission
Control Strategy
1985 Annual HC Emission Projections Assuming Current
Emission Control Strategy
1980 Annual HC Emission Projections Assuming
Alternative Emission Control Strategy
1985 Annual HC Emission Projections Assuming
Alternative Emission Control Strategy
1-4
1-5
1-7
1-8
1-9
3-5
4-5
4-6
4-7
4^
4-9
4-10
i-ll
4-12
4-13
4-14
4-15
4-16
4-17
-------
LIST OF TABLES (CONCLUDED)
Table Page
5-1 1977 Mew Tank Erection Costs 5-4
5-2 1977 Costs for Installation of Aluminum Pontoon
Type Internal Floating Roofs 5-7
A-l Tank Design Parameters A-5
A-2 Emission Equation Vapor Pressure Input Procedure. . A-7
A-3 Petroleum Liquid Property Assumptions A-8
A-4 Regional Crude Oil Vapor Pressure Assumptions . . . A-10
A-5 Relationships Used to Correct True Vapor Pressure
with Storage Temperature A-12
A-6 Tank Approximation Factors A-14
A-7 Tank Emission Approximation Factors A-l6
A-8 Summary of Data Used for Sample Calculation .... A-l9
A-9 Sample Calculation of Total Tank HC Emissions
for a State in PAD District 2 A-21
A-10 Announced Refinery Expansion and New Construction
Plans A-25
A-11 Distribution of Total 1985 Projected Refining
Capacity by State A-27
A-12 Domestic Refining Capacity by PAD District .... A-28
3-1 Tabulated Number of Tanks by Industry Section . . . B-3
B-2 Tabulated Number of Tanks by Volatility Class . . . B-4
B-3 Tabulated Number of Tanks by Petroleum Liquid
Type B-5
B-4 Tabulated Total External Floating-Roof
Tank Capacity B-6
B-5 Tabulated Total Internal Floating-Roof
Tank Capacity B-7
B-6 Tabulated Total Fixed-Roof Tank Capacity B-8
B-7 Tabulated Number of Floating-Roof Tanks
by Tank Capacity 3-9
8-8 Tabulated Number of Fixed-Roof Tanks
by Tank Capacity B-10
B-9 Tabulated Number of Tanks by Tank Construction . . B-ll
B-10 Tabulated Number of Floating-Roof Tanks by
Roof Type B-12
8-11 Tabulated Number of Floating-Roof Tanks by
Roof Seal Type 3-13
B-12 Tabulated Annual HC Emissions by Industry Area . . B-14
3-13 Tabulated Annual HC Emissions by Volatility Class . 3-17
B-14 Tabulated Annual HC Emissions by Petroleum
Liquid Type 3-20
0-1 1976 January HC Emission Estimates D-2
D-2 1976 July HC Emission Estimates 0-4
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1.0 SUMMARY
The purpose of this project was to evaluate hydrocarbon (HC)
emissions from petroleum storage tanks located in the United States.
The evaluation was limited to floating-roof and fixed-roof tanks
having capacities greater than 151,000 liters (40,000 gallons).
The project required estimating the current, nationwide, annual
emissions from the tanks and projecting the emission levels to
the years 1980 and 1985. Emphasis of the project was placed
on estimating the HC emissions from tanks located at refineries,
terminals, tank farms, and pipeline facilities. Tanks at oil
production facilities were not included. Emission estimates were
then developed for 1980 and 1985 assuming that all existing fixed-
roof tanks storing petroleum liquids with a true vapor pressure greater
than 10.5 kilopascals (kPa) (1.52 psia) were retrofitted with floating
roofs and that all new tanks for these petroleum liquids were external
floating-roof tanks. Application of alternative controls system such
as vapor recovery systems and double seals on external floating-roof
tanks was beyond the scope of this project.
l.T EMISSION ESTIMATE METHODOLOSV
The numbers of floating-roof and fixed-roof tanks, and sub-
sequently, the annual HC emissions from these tanks were estimated
by first compiling a tank data base. For individual tank locations,
information was collected about the tank design characteristics,
the properties of the petroleum liquid stored, and the tank opera-
tions. Primary data sources were state and local air pollution
regulatory agencies. Approximately 25,000 tank locations were
listed in the compiled tank data base.
Processing of the compiled tank data consisted of sorting
the data by various classifications schemes and calculation of the
annual HC emissions from each tank location. The emission
1-1
-------
calculations were performed using the emission equations described
in the U.S. Environmental Protection Agency document Compilation
of Air Pollution Emission Factors (AP-42). * Results for the
emission calculations were summed for direct input into the total
emission estimates. Also, the results were averaged to obtain
tank emission factors. These factors were used to approximate
tank HC emissions for refineries, terminals, and pipeline facilities
not listed in the compiled tank data base.
Summing the results for the emission calculations plus the
emission approximations for locations not listed in the data base
yielded the total estimates of annual HC emissions from floating-
roof and fixed-roof tanks for the year 1976. Projections of annual
HC emissions for the years 1980 and 1985 were made by linear
extrapolation of the 1976 estimated emission values. A ratio of
future to current domestic refining capacity was used to project
upward the 1976 values.
i.2 EMISSION ESTIMATE RESULTS
1.2.1 1976 ANNUAL HYDROCARBON EMISSIONS
For the year 1976, it was estimated there were 4C,GOO floating-
roof and fixed-roof tanks having capacities greater than 151,000
liters. Annual HC emissions from these tanks were estimated to
Q
total 3.3 ;< 10 kilograms per year (kg/yr). (One kilogram equals
2.2 pounds.) Approximately 17% of the emissions wera estimated
to be emitted from external and internal floating-roof tanks as
shown below by the volatility of the petroleum liquid stored in
the tank (expressed in kilopascals (kPa), 1.0 kPa equals 0.145 psia).
1-2
-------
Volatility of Petroleum
Liquid Stored
0
3
10
35
62
.0
.5
.5
.5
.7
(kPa
to
to
to
to
to
) (psia)
3.
10.
35.
62.
76.
5
5
5
7
5
0
0
1
5
9
.0
.51
.52
.0
.1
to
to
to
to
to
0
1
5
9
11
.51
.52
.0
.1
.1
TOTAL
Number of
Tanks
1,830
1,310
7,093
3,357
218
13,808
Annual HC
Emissions
(1,000 kg/yr)
2,002
5,020
64,178
61,464
9,400
142,064
The remaining 83% of the emissions were estimated to be emitted from
fixed-roof tanks as shown below:
Volatility of Petroleum
Liquid Stored
(kPa)
0
3
10
35
62
.0
.5
.5
.5
.7
to
to
to
to
to
3.
10.
35.
62.
76.
5
5
5
7
5
0
0
1
5
9
(psia)
.0
.51
.52
.0
.1
to
to
to
to
to
0
1
5
9
11
.51
.5
.0
.1
.1
<-
TOTAL
Number of
Tanks
15,416
3,388
5,340
1,396
49
26,089
Annual HC
Emissions
(1,000 kg/yr)
34,170
98,737
406,116
134,927
16,170
690,170
Tables 1-1 and 1-2 summarize, respectively, the estimated tank numbers
and annual HC emissions for the year 1976 by Petroleum Allocation for
Defense (PAD) Districts and by industry sectors.
Installing internal floating roofs is one method available to
control HC emissions from fixed-roof tanks. For the year 1976, annual
HC emissions from fixed-roof tanks were also estimated assuming the
retrofitting of internal floating roofs in the fixed-roof tanks stor-
ing petroleum liquids having a vapor pressure greater than 10.5 kPa
1-3
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(1.52 psia). These estimates showed total annual HC emissions
from fixed-roof tanks would be reduced by 77% to 1.6 x 10^ kg/yr.
A comparison of the 1976 emission estimates for both emission
control strategy assumptions is shown in Table 1-3.
1.2.2 1980 AND 1985 ANNUAL HYDROCARBON EMISSIONS
For the year 1980, it was projected there will be 16,900
floating-roof tanks and 29,000 fixed-roof tanks having capacities
greater than 151,000 liters. These projections assumed all new
tank construction would comply with the current New Source
r?i
Performance Standards (NSPS) for petroleum storage tanks.1- J All
new tanks projected to store petroleum liquids having a vapor
pressure greater than 10.5 kPa were counted as external floating-
roof tanks.
Total annual HC emissions from floating-roof and fixed-roof
3
tanks for the year 1980 were projected to be 8.3 x 10 kg/yr. A
second projection was made, assuming all new tank construction
would comply with the current NSPS and all existing fixed-roof tanks
would be retrofitted with internal floating roofs. Using -his
alternative control strategy assumption, projected annual 19oG
g
HC emissions were reduced to 3.5 x 10 kg/yr. Table 1-4 compares
tne 1980 emission projections by stored petroleum liquid volatility
class.
An analogous set of projections was ;nade for the year 1985.
The numbers of floating-roof tanks and fixed-roof tanks were pro-
jected to increase to, respectively, 19,700 tanks and 31,500 tanks
assuming current NSPS. Projected annual HC emissions totaled
q
9.3 x 10 kg/yr. Using the alternative emission control strategy,
the projected annual HC emissions decreased to ^.0 x 10^ kg/yr.
A comparison of the 1985 emission projections is shown in Table 1-5.
1-5
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2.0 INTRODUCTION
The purpose of this project was to evaluate hydrocarbon (HC)
emissions from petroleum storage tanks located in the United States.
The evaluation was limited to floating-roof and fixed-roof tanks
having capacities greater than 151,000 liters (40,000 gallons).
Estimates were made of nationwide, annual HC emissions from the
tanks. A complementary task involved compiling economic cost in-
formation about the installation of internal floating-roofs in
fixed-roof tanks.
2.1 HYDROCARBON EMISSION ESTIMATES
Hydrocarbon emission estimates were made for external and in-
ternal floating-roof tanks and fixed-roof tanks. The emphasis of
the project was placed on estimating the annual HC emissions from
tanks associated with refining, distributing, and marketing of
petroleum liquids (tanks located at refineries, at terminals, at
tank farms, and along pipelines). Tanks located at oil production
facilities were not included in the project. When information about
tanks located at petrochemical, power, or industrial plants was
readily available, the tanks were included in the emission estimates.
However, compiling data about tanks located at these facilities re-
ceived secondary priority with respect to meeting the project ob-
jectives.
The specific objectives of the project were:
1. To estimate the number of existing floating-roof tanks
and fixed-roof tanks having capacities greater than
151,000 liters.
2. To estimate the current, annual HC emissions from the
existing floating-roof tanks and fixed-roof tanks.
2-1
-------
3. To estimate the annual HC emissions from the existing
fixed-roof tanks assuming an alternative emission control
strategy requiring all existing fixed-roof tanks storing
petroleum liquids having a true vapor pressure greater
than 10.5 kilopascals (kPa) (1.52 psia) be retrofitted
with internal floating-roofs.
*
4. To project annual HC emissions from floating-roof and
fixed-roof tanks for the years 1980 and 1985 assuming
current emission control strategy requiring all new r?-i
tank construction meet Mew Source Performance Standards.
5. To project annual HC emissions from floating-roof and
fixed-roof tanks for the years 1980 and 1985 assuming
an alternative emission control strategy requiring all
new tank construction meed (New Source Performance
Standards and all existing fixed-roof tanks storing pet-
roleum liquids having a vapor pressure greater than
10.5 kPa be retrofitted with internal floating roofs.
Use of alternative control systems such as vapor recovery systems and
double seals on external floating-roof tanks was beyond the scope of
this project.
The methodology used for the HC emission estimates is outlined in
Chapter 3. The annual HC emission estimates are presented in
Chapter 4.
2.2 TANK COST DATA
The purpose of this task was to compile economic cost information
on the installation of internal floating-roofs in fixed-roof tanks.
No evaluation of cost effectiveness was made. Chapter 5 presents the
cost data.
2-2
-------
3.0 EMISSION ESTIMATE METHODOLOGY
Estimation of the number of tanks in the United States and,
subsequently, the annual HC emissions from these tanks was per-
formed in five stages. Figure 3-1 outlines the estimation
procedures. The methodology used for each stage of the procedure
is summarized in Sections 3.1 through 3.5. A detailed description
of the calculations upon which the emission estimates were based
is presented in Appendix A. Section 3.6 discusses the applica-
bility of the equations used for the emission calculations.
3.1 TANK DATA COMPILATION
The first stage of the estimation procedure involved collect-
ing data for individual tank locations about the tank design
characteristics, the properties of the stored petroleum liquid,
and the tank operations. To determine the availability of exist-
ing tank data, inquiries were made to Federal agencies, air
pollution regulatory agencies, tank vendors, and tank owners.
State and local air pollution regulatory agencies proved to be
the best sources of individual tank data for meeting the study
objectives. Supplemental tank data was obtained from the U.S.
Environmental Protection Agency (EPA).
The minimum information required about a specific tank
Vocation for the tank to be included in the individual tank data
base was:
1. Type of tank
2. Capacity of tank
3. Type of petroleum liquid stored in tank
Additional information about the tank design, tank operations,
and stored petroleum liquid properties was compiled when available
3-1
-------
Compilation of tank data for individual tank
locations
Sorting of compiled tank data and calculation of
HC emissions for each tank location
Approximation of number of tanks and HC emissions
for tank facilities absent
data base
rrom individual tank
Summation of results for individual tank data base
plus tank approximations to obtain total estimates
for the year 1975
Projection of the 1976 tank number and HC emission
estimates to the years 1980 and 1985
Figure 3-1. Emission Estimate Methodology
3-2
-------
for a specific tank location. Approximately 25,000 tank locations
were listed in the compiled tank data base.
3.2 TANK DATA PROCESSING
Processing of the individual tank data comprised sorting the
data by various classification schemes and calculation of the
annual HC emissions from each tank location. To facilitate the
data processing, the data for individual tank locations were
sorted by state and coded for storage and retrieval from computer
data files. Computer programs were used to tabulate the data and
perform all emission calculations.
3.2.1 TANK DATA TABULATIONS
The individual tank data were sorted by geographic regions,
industry sector location, and the volatility of the stored petroleum
liquid. Petroleum Administration for Defense (PAD) Districts were
used to tabulate the data by geographic regions (see Figure 3-2).
The industry sectors selected to classify the data reflect the
project emphasis, on tanks located at petroleum refining, distribution
and storage facilities. These sectors are defined in Table 3-1.
Tabulations of the data by petroleum liquid volatility was accom-
plished using vapor pressure ranges provided by the EPA (refer to
Table 3-1). The distributions of the compiled individual tank
data by the classification schemes are summarized in Appendix S.
3.2.2 EMISSION CALCULATIONS
Annual HC emissions were calculated for each tank listed in
the 25,000 tank data base. The results were summed for direct
input into the total emission estimates and averaged to develop
tank emission factors. These factors were used to approximate
HC emissions at tank locations not listed in the tank data files.
3-3
-------
1/1
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3-4
-------
Table 3.1. TANK DATA CLASSIFICATION CATEGORIES
INDUSTRY SECTOR CATEGORIES
Industry Sector Definition
Refinery Refinery location including all tanks
used for petroleum Hauid storage,
processing, and distribution
Terminal Facilities independent of refineries
used primarily for receiving and
distributing petroleum liauids
Tank Farm Facilities independent of refineries
used primarily for storaae of
petroleum liquids
Pipeline Pipeline pumping stations
Other Petrochemical, power, and industrial
plants
PETROLEUM LIQUID VOLATILITY CATEGORIES
Volatility Class True Vapor Pressure Range
(kilopascals) (psia)
1 0 to 3.5 0 to 0.51
2 3.5 to 10.5 0.51 to 1.52
3 10.5 to 35.5 1.52 to 5.0
4 35.5 to 62.7 5.0 to 9.1
5 52.7 to 76.5 9.1 to 11.1
3-5
-------
The emission calculations were performed using the emission
equations described in the EPA document, Compilation of Air Pol-
lution Emission Factors (AP-42) (see Appendix C). Three types
of input parameters were required for the emission equations.
1. Meteorological parameters
2. Tank design parameters
3. Petroleum liquid property parameters
Annual average meteorological conditions were used to calcu-
late annual HC emissions. Also, emissions were calculated for
winter and summer conditions using, respectively, January and
July monthly average meteorological conditions. To account for
the variation of meteorological conditions throughout the United
States, the country was divided into 121 meteorological districts.
The district boundaries were selected so that the general meteor-
ology of each district was characterized by data recorded in the
district. The emission calculations were performed using the
meteorological data corresponding to the district in which a spe-
cific tank was located. -
Input for the tank design and petroleum liquid property para-
meters were obtained from the data compiled about each tank lo-
cation. If information for a particular parameter was missing,
a value for the parameter was assumed in order to allow the calcu-
lations to be completed. The assumptions used for the tank de-
sign parameters were based on tank design trends identified from
data listed in the tank data files. Properties tabulated in AP-42
were used when an assumed value for a petroleum liquid property
was required.
3.3 EMISSION APPROXIMATIONS
Tabulation of the calculated emissions for the individual
3-6
-------
tank data provided an estimate of the annual HC emissions for
many but not all refinery, terminal, tank farm, pipeline, and
other tank locations throughout the United States. Consequently,
a method was devised to approximate the number of tanks and tank
emissions for refinery and pipeline pumping station locations not
listed in the tank data files. Approximations of the total num-
ber of terminal tanks in each state were used to supplement the
individual tank calculation results. No approximations were made
for tank farm, petrochemical plant, power plant, or industrial
plant locations not listed in the tank data files.
3.3.1 REFINERY EMISSION APPROXIMATIONS
Refinery locations not listed in the tank data file were
identified using the annual Oil and Gas Journal refining sur-
vey. The number of tanks at these refinery locations were ap-
proximated on the basis of the rated crude oil refining capacity
(expressed as barrels per day). From the tabulated individual
tank data, tank factors were developed expressing the average
number of refiner/ floatinq-roof and fixed-roof tanks per 1000
bbl/day refining capacity. Multiplication of the refining cap-
acities times the tank factors yielded approximations of the num-
ber of tanks. Annual HC emissions from the tanks were aoproxi-
mated by multiplying the number of tanks by tank emission factors.
These factors expressed the average annual HC emissions from re-
finery tanks. Separate tank factors and tank emission factors
were used for each PAD District to reflect regional variations in
refinery operations.
3.3.2 PUMPING STATION EMISSION APPROXIMATIONS
The number of pipe! ine pumping stations located in each PAD
3-7
-------
District which were not listed in the tank data files was deter-
mined using pipline maps. Approximations of the number of tanks
at these stations were made using a factor of two tanks per pump-
ing station. Tanks located at crude oil pumping stations were
arbitrarily designated fixed-roof tanks, and tanks located at re-
fined product pumping stations were designated floating-roof
tanks. Emissions from the tanks were approximated using the tank
emission factors developed for refinery locations.
3.3.3 TERMINAL EMISSION APPROXIMATIONS
No surveys or maps were available that allowed identifica-
tion of the terminal locations not listed in the tank data files.
Therefore, the total numbers of tanks located at terminals in
each state were approximated based on the state peculations.
This was accomplished using tank factors expressing the average
number of terminal floatina-roof and fixed-roof tanks per 1000 popula-
tion. ' The difference between the approximated total number of terminal
tanks and the number of terminal tanks listed in the tank data
files indicated the number of additional tanks for which HC emis-
sion approximations were to be made. Annual H,C emissions wers
then approximated by multiplying the number of tanks by tank emis-
sion factors. These ^actors exorassed the average annual HC
emissions from terminal tanks. To reflect regional variations
in terminal operations, separate tank factors and tank emission
factors were developed for each PAD District.
3-4 1976 EMISSION ESTIMATES
A distribution of the total estimates of tank numbers and
annual HC emissions for the year 1976 were required by industry
sector, petroleum liquid volatility, and petroleum l-'auia type.
3-3
-------
Tabulations of tank numbers and annual HC emissions from the tank
data files were made for all three classification groups. How-
ever, approximations of tank numbers and annual HC emissions for
tank locations not listed in the tank data files were made only
by industry sector. To estimate total tank numbers and annual
HC emissions, the results of the data file tabulations and the
tank approximations were summed by industry sector. These total
values were subsequently redistributed by petroleum liquid vola-
tility and type assuming the same distribution ratios exhibited
by the tank data file tabulations shown in Appendix B.
Installing internal floating roofs is one method available
to control HC emissions from fixed-roof tanks. The annual HC emis-
sions for the year 1976 were also estimated assuming the retro-
fit of internal floating roofs in the fixed-roof tanks storing
petroleum liquids having a vapor pressure greater than 10.5 kPa
(1.52 psia). Annual HC emission calculations were repeated for
each fixed-roof tank listed in the tank data files. The emission
equations recommended in AP-42 for internal floating-roof tanks
were used. Estimates of total emissions were obtained by summing
the calculation results and ratioing the values upward by factors
of total estimated to tabulated numbers of tanks.
3.5 1980 AND 1985 EMISSION PROJECTIONS
Future petroleum storage tank HC emissions will depend on the
number of new tanks constructed in the United States as well as the
type of emission controls installed on new and existing tanks. Both
factors were considered for the 1980 and 1985 emission projections.
3-9
-------
3.5.1 PROJECTED NUMBER OF TANKS
Projections of the total numbers of tanks for the years 1980
and 1985 were made by linear extrapolation of the 1976 estimated
tank numbers. A ratio of future to current domestic refining capa-
city was used to project upward the 1976 values estimated by vola-
tility class and PAD District. The rational for using this ratio
is discussed in Appendix A. Projections of the 1980 refining capa-
city were made by totaling announced refinery expansion and new
construction plans. The 1985 refining capacity was projected using
an annual growth rate of 2.4%.
The projected tank numbers determined by linear extrapolation
of the 1976 values assume the current distribution of the tank num-
bers by tank type. However, the New Source Performance Standards
(NSPS) require all new tanks storing petroleum liquids having a
volatility greater than 10.5 kPa (1.52 psia) to be of floating-roof
12\
design or have a vapor recovery system. Consequently, the pro-
jected numbers of tanks for 1980 and 1985 were re-distributed by
tank type to comply with NSPS. This was accomplished by counting
all new tanks projected for volatility classes 3, 4, and 5 as extern-
al floating-roof tanks.
3.5.2 PROJECTED EMISSIONS
Projections of rank emissions for 1980 and 1985 were made by
linear extrapolation of the 1976 estimated KC emissions. A ratio
of future to current estimated numbers of tanks was used to projeez
upward the 1976 emission values listed by volatility class and PAD
District.
3-1C
-------
3.6 APPLICABILITY OF EMISSION EQUATIONS
Calculations of annual HC emissions from petroleum storage tanks
were performed using the equations described in AP-42. These equa-
tions were derived from empirical correlations developed by the Amer-
ican Petroleum Institute (API) for external floating-roof tanks,
internal floating-roof tanks, and fixed-roof tanks. The corre-
lations were originally developed to estimate liquid volume evapor-
ation losses from tanks storing gasoline and crude oil.
Although based on test data for gasoline and crude oil storage,
the fixed-roof tank equations may be used for all refined products
and intermediate refinery stocks. The floating-roof tank equa-
tions are applicable to external and internal floating-roof tanks
storing petroleum liquids in the true vapor pressure range of 13.8
Ml
kPa (2 psia) to 75.8 kPa (11 psia). There is no basis for apply-
ing the equations to floating-roof tanks storing fuel oils or other
low vapor pressure petroleum liquids. However, because no alterna-
tive relationships were available, the AP-42 equations were used to
estimate annual HC emissions from the floating-roof tanks placed in
volatility classes 1 and 2.
The API equations used to develop the AP-42 equations were
based on test data measured primarily during the late 1930's and
early 1940's. Field and experimental studies are currently being
conducted to re-examine the parameters affecting HC emissions from
petroleum storage tanks. Chicago Bridge and Iron Company
(C8I) constructed a pilot scale tank to investigate HC emis-
sions from external floating-roof tanks. Under sponsorship
of Standard Oil Company (Ohio) and the Western Oil and Gas Associa-
tion (WOGA), comprehensive studies have been conducted using the
test tank to study the performance of different external floating-
7 8l
roof seal types. " ' Field studies have also been sponsored by
3-11
-------
WOGA to measure HC emissions from floating-roof and fixed-roof
tanks located in California. '9jia- These studies compared the
measured emissions to quantities estimated using the AP-42 equa-
tions. Results from the various studies suggest that under certain
conditions the AP-42 equations significantly overestimate HC
emissions from floating-roof and fixed-roof tanks. However, inter-
pretation of these results with respect to revising the AP-42
equations was beyond the scope of this project.
The API has initiated a project to update its technical bulle-
tins on methods of estimating HC losses from external and internal
floating roof tanks, scheduled for completion in early 1979. "
A similar project is planned for fixed-roof tanks. Until the re-
vised API bulletins become available, the AP-42 equations remain
a conservative but the best available method for estimating HC
emission from petroleum storage tanks.
3-i 2
-------
4.0 EMISSION ESTIMATE RESULTS
Annual HC emissions from floating-roof tanks and fixed-roof
tanks were estimated for the years 1976 and then projected to
the years 1980 and 1985. All of the emission estimates presented
in this chapter were made using annual average meteorological con-
ditions. Emission estimates for the year 1976, using January and
July meteorological conditions, are shown in Appendix D.
4.1 1976 ANNUAL HYDROCARBON EMISSIONS
4.1.1 ESTIMATED NUMBER OF TANKS
For the year 1976, there were estimated to be 37,600 floating-
roof and fixed-roof tanks having capacities greater than 151,000
liters located at refinery, terminal, tank farm, and pipeline
facilities. An additional 2,300 tanks were counted at other
locations. The distribution of the estimated numbers of floating-
roof and fixed-roof tanks by industry sectors is shewn in Table
4-1.
The distribution of the estimated tank numbers by petroleum
liquid volatility and type are presented in Tables 4-2 and 4-3.
The tables show both floating-roof tanks and fixed-roof tanks
stored all types of petroleum liquids. However, floating-roof
tanks were used primarily for storage of high volatility petroleum
liquids. Approximately one-half of the rota! estimated number of
floating-roof tanks stored gasoline. The majority of fixed-roof
tanks were used for storage of petroleum liquids having vapor
pressures less then 10.5 kPa (volatility classes 1 and 2).
The overall ratio of the estimated fixed-roof tank numbers
to floating-roof tank numbers was about 2 to 1. However, one
should not assume that the total fixed-roof tank storage capacity
4-1
-------
was twice the storage capacity for floating-roof tanks. The
tank capacities listed in the tank data files were tabulated.
These results showed that total floating-roof tank capacity
was approximately equal to the total fixed-roof tank capacity
(refer to Appendix 8, Tables 8-4, 3-5, and B-6).
4.1.2 CURRENT EMISSION CONTROL STRATEGY
Annual HC emissions from floating-roof and fixed-roof tanks
located at refinery, terminal, tank farm, and pipeline facili-
3
ties were estimated to total 8.1 x 10 kilograms per year (kg/yr).
(One kilogram equals 2.2 pounds). Emission estimates for tanks
o
located at other facilities contributed an additional 0.2 x 10
kg/yr. The distribution of the estimated annual HC emissions by
industry sector, petroleum liquid volatility, and petroleum
liquid type are presented in Tables 4-4 through 4-6.
Approximately 17 percent of the total annual HC emissions
were estimated to be emitted from external and internal floating-
roof tanks. The remaining 33 percent of the total estimated
emissions were emitted from fixed-roof tanks. For both tank
types, the majority of the HC emissions were emitted from tanks
storing gasoline and crude ail.
4.1.3 ALTERNATIVE EMISSION CONTROL STRATEGY
Installing internal floating-roofs is one metnod available
to control HC emissions from fixed-roof tanks. For the year
1976, annual HC emissions were also estimated assuming the retro-
fit of internal floating roofs in the fixed-roof tanks storing
petroleum liquids having a vapor pressure greater than 10.5 kPa
(1.52 psia). Table 4-7 presents the annual HC emission astimatss
for this control strategy. Total annual HC emissions from
oating-roof tanks remained unchanged. However, the total fixed-
£1
I I
4-2
-------
roof tank emission estimates were reduced by 77 percent from
6.9 x 108 kg/yr to 1.6 x TO8 kg/yr.
4.2 1980 AND 1985 ANNUAL HYDROCARBON EMISSIONS
4.2.1 CURRENT EMISSION CONTROL STRATEGY
The New Source Performance Standards require all new tanks
storing petroleum liquids which have a volatility greater than
10.5 kPa to be of floating-roof design or have a vapor recovery
[21
system. J Projections of the numbers of tanks for the years
1980 and 1985 were made assuming all new tanks projected for
volatility classes 3, 4, and 5 would be of external floating-
roof design. For the year 1980, it was projected that there will
be 16,900 floating-roof tanks and 29,000 fixed-roof tanks. The
1985 numbers of floating-roof tanks and fixed-roof tanks were
projected to increase to, respectively, 19,700 tanks and 31,500
tanks. Tables 4-8 and 4-9 show the distribution of the tank
number projections by volatility classes.
Total annual HC emissions from floating-roof and fixed-roof
Q
tanks for the year 1980 were projected to be 3.8 x 10 kg/yr.
For the year 1985, the total emission projections increased to
9.3 x 10 kg/yr. The distributions of the 1930 and 1985 pro-
jected annual HC emissions by volatility classes are presented
in Tables 4-10 and 4-11.
4.2.2 ALTERNATIVE EMISSION CONTROL STRATEGY
Annual HC emissions were also projected for the years 1980
and 1985 assuming an alternative emission control strategy. For
this strategy, it was assumed all new tanks would comply with
the New Source Performance Standards and existing fixed-roof tanks
storing petroleum liquids in volatility classes 3,4, and 5 would be
retrofitted with internal floating roofs.
4-3
-------
The projected annual HC emissions for the years 1980 and
1985 are shown in Tables 4-12 and 4-13. Using the alternative emis-
sion control strategy assumption, projected total 1980 annual HC
g
emissions were reduced to 3.5 x 10 kg/yr. Similarly, the projected
Q
annual HC emissions for the year 1985 decreased to 4.0 x 10 kg/yr.
-------
Table 4-1. 1975 TANK NUMBER ESTIMATES BY INDUSTRY SECTOR
FLOATING
ROOF
A N K S
PAD
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Refinery
595
1,266
2,118
277-
1,226
5,482
Terminal
2,142
1,845
663
141
616
5,407
Tank Farm
122
93
202
11
151
579
Pipeline
368
868
532
94
170
2,032
Other
37
214
20
0
37
TOTAL
3,264
4,286
3,535
523
2,200
308 ! 13,308
External and internal floating-roof tanks
FIXED
ROOF
A N K S
P A D
DISTRICT
1
2
3
4
5
TOTAL
iNUUiiKf itLlUK
Refinery
1,610
3,354
4,560
525
2,476
12,525
Terminal
4,111
2,061
90S
144
849
3,073
Tank Farm
83
98
228
n
326
746
Pipeline
98
995
1,152
322
167
Other
311
1,064
269
n
356
2,734 ! 2,011
i
TOTAL
6,213
7,572
7,117
1 ,013
4,17/1
25,089
4-5
-------
Table 4-2. 1976 TANK NUMBER ESTIMATES BY VOLATILITY CLASS
FLOATING
ROOF
T A N K S£
PAD
DISTRICT
1
2
3
I
! 4
5
TOTAL
VOLATILITY CLASS
1
259
453
662
32
424
1,830
2
248
336
244
38
444
1,310
3
1,753
2,794
1,330
397
319
4
938
648
1,221
56
494
7,093 j 3,357
5
66
55
73
0
19
TOTAL
3,264
4,236
3,535
523
2,200
218 13,808
External and internal floating-roof tanks
FIXED
ROOF
TANKS
? A D
DISTRICT
1
2
3
4
t*
TOTAL
V U L
1
3,697
4,350
4,659
688
2,022
15,416
M 1 1
2
955
788
381
142
1,122
3,383
L 1 1
3
1,305
2,081
1,464
157
833
5,340
u u
4
237
332
606
26
195
1,396
M 0 J
f"
19
21
7
0
2
19
TOTAL
6,213
7,572
7,117
1,013
4,171
26,089
4-6
-------
Table 4-3. 1976 TANK NUMBER ESTIMATES BY PETROLEUM LIQUID TYPE
PETROLEUM LIQUID TYPE
Crude oil
Gasoline
Diesel fuel
Jet fuel , kerosene
Jet fuel , JP-4
Distillate Fuel oil
Residual fuel oil0
Naphtha
Alkylate
Medium vapor pressure stocks
Low vapor pressure stocks
Benzene
Other'
TOTAL
TANK TYPE
Floating
Roofa
2,212
7,119
248
265
515
882
160
d74
101
844
324
246
Fixed
Roof
2,223
3,755
1,213
1,031
822
5,327
1,543
453
68
2,175
5,439
82
418 1,958
13,808
26,089
External and internal floating-roof tanks
Fuel oil grades 1,2,3
Fuel oil grades 4, 5, 6
Petroleum liquid vapor pressure greater than 3.4 kPa (.5 psia'
Petroleum liquid vapor pressure less than 3.4 kPa (.5 psia)
Unidentified refined petroleum liquids
4-7
-------
TABLE 4-4. 1976 ANNUAL KC EMISSION ESTIMATES BY INDUSTRY SECTOR
Cunits: 1000 kg/yrl
FLOATING
ROOF
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Refinery
7,547
14,367
23,739
1,630
12,300
59,533
Terminal
19,340
17,261
9,959
684
5,204
52,448
Tank Farm
1,743
894
3,054
77
870
6,638
Pipeline
3,950
9,746
6,319
587
1,228
21 ,330
Other
174
1,120
232
Q
39
1,565
TOTAL
32,754
43,388
43,303
2,978
19,641
142,064
External and internal floating-roof tanks
FIXED
ROOF
A N K S
P A 0
DISTRICT
1
2
3
d
; 5
I
Refinery
43,180
125,336
131,496
6,907
49,313
N D U S T
Terminal
78,650
53,666
20,276
1,985
47,371
R Y S E
Tank Farm
17,305
3,713
5,028
20
4,435
: c T o R
Pipeline
1,079
25,206
37,549
3,777
12,090
Other
1 ;3S9
11 ,047
2,046
163
4,593
TOTAL
U2.S03
220,^63
196,395
12,352
117,352 !
- 0 T A L 357,732 1201,943
31,051
79,701 | 19,738 ; 530,170
4-3
-------
Table 4-5, 1976 ANNUAL HC EMISSION ESTIMATES BY VOLATILITY CLASS
(units: 1000 kg/yr)
FLOATING
ROOF
T A N K S<
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
121
247
1,124
36
474
2,002
2
756
1,658
1,087
151
1,368
5,020
3
15,992
26,361
13,189
2,180
6,456
64,178
4
13,966
13,499
24,061
611
9,327
61,464
5
1,919
1,623
3,842
0
2,016
i
TOTAL
32,754
43,388
43,303
2,978
19,641
9,400 | 142,064
External and internal floating-roof tanks
F I X
ROOF
TANKS
VOLATILITY
CLASS
PAD
DISTRICT
1
2
3
4
5
TOTAL
1
5,108
4,033
21 ,042
521
3,416
34,170
2
22,144
18,895
10,409
1,505
45,834
98,787
3
97,737
153,536
97,254
9,928
47,661
406,116
4
15,174
42,385
63,914
898
12,556
13^,927
5
2,44Q
1,569
3,776
0
3,385
16,170
TOTAL ;
142,503
220,468
196,395
12,352
117,852
590,170
4-9
-------
Table 4-6. 1976 ANNUAL HC EMISSION ESTIMATES
BY PETROLEUM LIQUID TYPE
(units: 1000 kg/yr)
PETROLEUM LIQUID TYPE
Crude oil
Gasoline
Diesel fuel
Jet fuel , kerosene
Jet ruel , JP-4
Distillate Fuel oilb
Residual fuel oilc
Naphtha
1 Alkylate
Medium vapor pressure stocks
Low vapor pressure stocks0
Benzene
Otherf
TOTAL
TANK TYPE
Floating
Roofa
23,719
97,389
471
470
2,059
2,073
187
4,936
1,237
A, 261
733
1,026
3,493
142,064
Fixed
Roof
171 ,520
335,322
3,374
5,188
18,438
1 7 ,381
4,377
15,359
2,533
53,369
7,647
1,220
43,392
590,170
External and internal floating-roof tanks
& Fuel oil grades 1,2,3
c Fuel oil grades 4, 5, 6
d Petroleum liquid vapor pressure greater than 3.4 kPa (.5 psia'
e Petroleum liquid vapor pressure less than 3.4 kPa (.5 psia)
' Unidentified refined petroleum liquids
4-10
-------
Table 4-7. 1976 ANNUAL HC EMISSION ESTIMATES ASSUMING
ALTERNATIVE EMISSION CONTROL STRATEGY
(units: 1000 kg/yr)
FLOATING
ROOF
T A N K Sc
PAD
DISTRICT
i
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
121
247
1,124
36
474
2,002
2
756
1,658
1,087
151
1,368
5,020
3
15,992
26,361
13,189
2,180
6,456
64,178
4
13,966
13,499
24,061
611
9,327
61,464
5
1,919
1,623
3,342
0
2,016
9,400
TOTAL
32,754
43,388
43,303
2,978
19,641
142,064
a External and internal floating-roof tanks
FIXED ROOF TANKS
PAD
DISTRICT
1
2
3
4
VOLATILITY CL
]
5,108
4,083
21,042
521
5 3,416
!
TOTAL
34,170
2
22,144
18,395
10,409
1,505
45,334
98,787
3
4,786
6,728
3,859
322
2,040
17,735
4
1 ,435
1,808
3,149
47
1,236
7,675
A S S
5
148
ISO
135
0
194
707
TOTAL
33,621
31,694
38,644
2,395
52,720
159., 074
4-11
-------
Table 4-8. 198Q TANK NUMBER PROJECTIONS ASSUMING
CURRENT EMISSION CONTROL STRATEGY
FLOATING
ROOF
TANKS5
PAD
DISTRICT
1
2
3
4
5
! TOTAL
i
VOLATILITY CLASS
1
368
456
745
32
463
2
352
339
274
38
435
2,064 | 1,488
i
|
3
3,037
2,830
1,677
397
964
8,9Q5
4
1,432
656
1,449
56
556
4,149.
5
102
55
89
0
21
267
1
TOTAL
5,291
4,336
4,234
523
2,489
16,373
3 External and
F I X
V 0 L
PAD i
DISTRICT
i
2
3
4
1
5,249
4,382
5,240
688
5 2,192
i T 0 T A L! 17,751
internal floating-roof tanks
ED ROOF TANK
A T I
2
1,356
794
423
142
1,216
3,936
L I T Y C L A <
3
1,305
2,081
1,464
157
333
4 5
237
332
606
26
195 i
5,340 1,396
S
; s
i
TOTAL
5
19 3,166
21 7,610
7 7,745
0 1,013
2 ; 4,423
49 28,972
4-12
-------
Table 4-9 1985 TANK NUMBER PROJECTIONS ASSUMING
CURRENT EMISSION CONTROL STRATEGY
F L 0 A T I
ROOF
T A N K Sc
P A D
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
406
531
787
37
533
2,294
2
389
394
290
44
558
1,675
3
3,488
3,630
1,856
492
1,233
10,699
4
1,604
816
1,565
70
669
4,724
5
114
69
94
0
24
TOTAL
6,001
5,440
4,592
643
3,017
301 j 19,693
External and internal floating-roof tanks
FIXED
ROOF
TANKS
PAD
DISTRICT
1
2
2
4.
5
TOTAL
VOL
1
5,792
5,096
5,538
807
2,518
19,751
A T I
2
1,496
923
453
166
1,397
4,435
L I T
0
M*
1,305
2,081
1,464
157
333
5,340
< C L
4
237
332
606
26
195
1,396
A S S
5
19
21
7
0
2
49
TOTAL
8,849
3,453
8,063
1,156
4,945
31,471
4-13
-------
Table 4-10 1980 ANNUAL KC EMISSION PROJECTIONS ASSUMING
CURRENT EMISSION CONTROL STRATEGY
(units: 1000 kg/yr)
FLOATING
ROOF
T A N <
PAD
DISTRICT
1
2
| 3
4
5
TOTAL
f
VOLATILITY CLASS
1
172
249
1,265
36
518
2,240
2
1,073
1,673
1,221
151
1,494
5,612
3
27,698
26,701
16,631
2,180.
7,599
80,80.9
4
21,326
13,666
28,561
611
10,503
74,567
5
2,965
1,623
4,384
Q
2,228
11,200
TOTAL
53,234
43,912
52,062
2,978
22,342
174,528
External and internal floating-roof tanks
FIXED
ROOF
TANKS
1
1
PAD
DIS-RICT
1
2
3
4
5
TOTAL
VOL
1
7,253
4,.. 113
23,672
521
3,703
39,262
A T I
2
31 ,444
19,039
11,690
1,505
49,634
113,362
L I T '
3
97,737
153,536
97,254
9,9.28
47,661
1406,116
I
< C L
4
15,174
42,385
63,914
898
1 O !"'"
1 2,530
134,927
ASS
5
2,440
1 ,569
3,776
0
3,385
16,170
TOTAL
154,0.48
220,6^2
200,306
12,352
121,9.89
709,337
A 1.1
4- 1 <+
-------
Table 4-11. 1985 ANNUAL HC EMISSION PROJECTIONS ASSUMING
CURRENT EMISSION CONTROL STRATEGY
(units: 1 ,000 kg/yr)
FLOATING
ROOF
T A N K S'
PAD
DISTRICT
1
2
3
4
5
VOLATILITY CLASS
1
190
290
1,337
42
596
TOTAL) 2,455
i '
2
1,185
1,944
1,293
175
1,720
6,317
3
31,824
34,249
18,399
2,701
9,717
96,890
4
23,882
16,999
30,847
764
12,629
85,121
5
3,314
2,036
4,630
0
2,547
12,527
TOTAL
60,395
55,518
56,506
3,682
27,209
203,310
a ,.
External and internal floating-roof tanks
FIXED
ROOF
TANKS
PAD
DISTRICT
^
2
3
4
5
TOTAL
VOL
1
8,005
4,784
25,019
611
4,253
42,672
A T I
2
34,700
22,132
12,376
1,759
57,064
128,031
L I T
3
97,737
153,536
97,254
9,928
47,661
^06 , 1 1 6
{ C L
4
15,174
42,385
63,914
898
12,556
134,927
A S S
5
2,4*0
1,569
3,776
0
8,385
16,170
1
TOTAL
158,056
224,406
202,339
13,196
129,919
727,916
4-15
-------
Table 4-12. 1980 ANNUAL HC EMISSION PROJECTIONS ASSUMING
ALTERNATIVE EMISSION CONTROL STRATEGY
(units: 1,000 kg/yr)
FLOATING
ROOF
A N K S{
PAD
DISTRICT
1
2
i 3
4
5
TOTAL
VOLATILITY CLASS
}
172
249
1,265
36
518
2,240
2
1,073
1,673
1,221
151
1,494
5,612
3
27,698
26,701
16,631
2,180
7,599
80,809
4
21,326
13,666
28,561
611
10,503
74,667
5
2,965
1,623
4,384
0
2,228
11,200
I
TOTAL
53,234
43,912
52,062
2,978
22,342
174,528
External and internal floating-rcof tanks
I X E D
ROOF
TANKS
! 1
j i
I PAD
VOLATILITY CLASS1
! DISTRICT 1
i 1
1
; 2
| 3
! 4
; s
| T 0 T A L
7,253
4,113
23,672
521
3,703
2
31,444
19,039
11,690
1,505
49,684
39,252 | 113,362
3
4,786
6,728
3,859
322
2,040
17,735
4
1 ,435
1,308
3,149
47
1,236
7,575
I
TOTAL
5
US
180
^5,065 i
31 ,868
185 1 42,555
Q
194
707
2,395
56 ,857
173, 7^1
4-16
-------
Table 4-13. 1985 ANNUAL HC EMISSION PROJECTIONS ASSUMING
ALTERNATIVE EMISSION CONTROL STRATEGY
(units: 1000 kg/yr)
FLOATING
ROOF
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
190
290
1,337
42
596
2,455
2
1,185
1,944
1,293
175
1,720
6,317
3
31 ,324
34,249
18,399
2,701
9,717
96,890
4
23,882
16,999
30,847
764
12,629
85,121
5
3,314
2,036
4,630
0
2,547
12,527
TOTAL
60,395
55,518
56,506
3,682
27,209
203,310
External and internal floating-roof tanks
FIXED
ROOF
TANKS
VOLATILITY
CLASS
PAD
DISTRICT
1
2
3
4
5
TOTAL
1
3,005
4,784
25,019
611
4,253
42,572
2
34,700
22,132
12,375
1,759
57,064
123,031
3
4,786
6,728
3,859
322
2,040
17,735
4
1,435
1,808
3,149
47
1 ,236
7,675
5
U8
180
185
0
194
707
TOTAL
49,074
35,632
44,588
2,739
64,787
196,320
4-17
-------
5.0 TANK COST DATA
Economic cost data was compiled about erection of new tanks
and installation of internal floating roofs in fixed-roof tanks.
No evaluation of cost effectiveness was made. The prices for
tanks and internal floating roofs were quoted by vendors for
tank capacities expressed in units of barrels. For convenience,
the new tank erection costs and internal floating roof install-
ation costs are presented in this chapter by tank capacity ex-
pressed in units of barrels (one barrel equals 159 liters).
5.1 NEW TANK ERECTION COSTS
Total costs for erecting a new floating-roof or fixed-roof
tank at a specific location include material costs for the tank
shell and fittings, costs for preparing the tank foundation, and
labor costs. Tank foundation costs vary depending on the soil
type at the tank site. Labor costs vary according to the prevail
ing labor rates for an area.
New tank erection costs were obtained for three basic tank
types.
1. Fixed-roof tanks
2. External floating-roof tanks
3. Covered floating-roof tanks
These tank types are briefly described in Appendix C.
Additional background information concerning petroleum storage
tanks is available in the EPA document Air Pollution Engineering
Manual (AP-40). ^1Zl
Table 5-1 presents new tank erection costs as quoted by two
major tank vendors ' and an oil company. These costs are
presented in units of dollars per barrel of tank capacity. The
5-1
-------
table shows the cost per barrel decreases as the tank capacity
incresses. Also, the erection costs quoted by the tank vendors
are significantly lower than the cost estimates used by the oil
company. For a 100,000 barrel capacity fixed-roof tank, the
tank vendor costs are 10 percent to 25 percent lower than the
cost estimates used by the oil company. Similarly, the vendor
costs for a 100,000 barrel capacity external floating-roof tank
are 4 percent to 23 percent below the oil company estimated costs.
5.2 INTERNAL FLOATING ROOF INSTALLATION COSTS
One of the most effective methods available to reduce HC
emissions from fixed-roof tanks is the installation of an inter-
nal floating-roof to cover the exposed liquid surface. There
are three basic types of internal floating-roofs:
1. Aluminum, pontoon type roofs
2. Steel, pan type roofs
3. Plastic, foam type rafts
Fixed-roof tanks with steel, pan type internal floating
roofs are termed, "covered floating-roof tanks". If the internal
floating roofs are made of a nonferrous material, the tank is
termed an "internal floating cover tank".
The internal floating roof type most commonly installed in
fixed-roof tanks today is the aluminum pontoon type. This type
of roof is preferred because of its strength, lignt weight, and
low cost. The use of steel pan type roofs has declined due to
the higher cost and problems with the roof sinking. Plastic foam
type rafts also are not widely used because of the possibility
of tne roof absorbing liquid or inducing static sparking.
Installation costs for installing aluminum, pontoon type,
internal floating roofs in fixed-roof tanks were obtained from
5-2
-------
two vendors. * ' These costs are presented in Table 5-2. The
table shows the roofs are available for all fixed-roof tank
capacities. Prior to installation of the internal floating roof,
the tank must be cleaned. The installation costs shown in
Table 5-2 do not include tank cleaning costs. These costs vary
depending on the condition of the tank and whether the work is
performed by a contractor or the tank owner.
5-3
-------
Table 5-1. 1977 NE1// TANK ERECTION COSTS
Tank Vendor A
Fixed-Roof Tanks
Capacity
(barrels)
5,000
10,000
15,000
20,000
30,000
40,000
50,000
60,000
30,000
100,000
120,000
150,000
200,000
Costs3
(S per
barrel)
7.80
5.60
5.20
4.80
4.10
3.30
3.65
3.50
3.30
3.15
3.05
2.95
2.90
External Floating
Roof Tanks
Capacity
(barrels)
20,000
25,000
30 ,000
35,000
45,000
55,000
67,500
80,000
95,000
100,000
110,000
120,000
130,000
150,000
170,000
220,000
270,000
Costs3
f.S per
barrel )
6.75
6.20
5.50
5.29
4.78
4.45
4.15
4.00
3.79
3.75
3.54
3.54
3.46
3.33
3.24
3.10
3.00
Covered Floating
Roof Tanks
Capacity
(barrels)
8,700
11,000
20,000
25,000
34,000
43,000
53,000
64,000
76,500
90,000
104,000
120,000
135,000
171,000
207,000
Costs3
'S per
barrel )
8.05
7.27
6.25
5.85
5.29
5.12
4.31
4.61
4.44
4.23
&.16
d.Qd
3.98
3.39
3.63
"Costs are ror Southern California and include cos'i
but do not include tank foundation costs.
tines
5-4
-------
Table 5-1. 1977 NEW TANK ERECTION COSTS (CONTINUED)
Tank Vendor B
Tank
Capacity
(barrels)
1,000
5,000
10,000
20,000
40,000
60,000
80,000
100,000
125,000
140,000
150,000
200,000
250,000
300,000
400,000
Tank Erection Costs3 ($ per barrel)
Fixed -roof
21.50
6.75
4.55
3.55
2.98
2.81
2.73
2.64
2.62
2.55
2.41
2.34
2.28
2.25
2.17
External Floating
Roof
b
10.75
6.75
5.15
4.00
3.50
3.22
3.00
2.90
2.84
2.80
2.64
2.62
2.56
2.42
Covered Floating
Roof
b
9.35
6.00
4.75
4.00
3.66
3.44
3.25
3.08
3.04
3.03
3.00
.2.98
2.94
2.33
"Costs are for Southern California but do not include costs for
fittings or the tank foundation.
Cost of fittings - Large tanks 1 to 4% of total cost;
small tanks - 5% of total cost.
K
Not available in this size.
0-3
-------
Table 5-1. 1977 NEW TANK ERECTION COSTS (CONCLUDED)
nil Comoanyc
Tank
Capacity
(barrels)
1,000
5,000
10,000
20,000
40,000
50,000
100,000
200,000
Tank Erection Costs (S per barrel)
Fixed-Roof
Tanks
13.00
8.85
7.00
5.50
--
3.50
3.25
External Floating
Roof Tanks
--
--
11.50
8.00
5.85
5.22
3.90
3.30
Covered Floating
Roof Tanks
--
--
9.50
7.00
5.50
--
4.25
3.79
Cost values used by a major oil company zo estimate new tank
erection cos's.
5-6
-------
Table 5-2. 1977 COSTS FOR INSTALLATION OF ALUMINUM
PONTOON TYPE INTERNAL FLOATING ROOFS
Vendor A
Tank Capacity
(barrels)
1,000
5,000
10,000
20,000
40,000
60,000
80,000
100,000
125,000
140,000
160,000
200,000
250,000
300,000
400,000
Tank Diameter
(feet)
18
34
42
60
84
102
120
121
136
142
154
172
193
212
244
Tank Height
(feet)
20
30
40
40
40
40
48
48
48
48
48
48
48
48
48
Cost Installed3
(S per barrel )
5.44
1.51
0.91
0.61
0.54
0.47
0.46
0.36
0.35
0.34
0.33
0.32
0.31
0.31
0.29
Costs are based on materials fabricated at the plant and include
the cost of installation with Boilermaker Craft Union oersonnel.
Costs do not include shipping charges, crew travel pay, or tank
cleaning costs.
5-7
-------
Table 5-2. 1977 COSTS FOR INSTALLATION OF ALUMINUM
PONTOON TYPE INTERNAL FLOATING ROOFS (CONCLUDED)
Vendor 3
Tank Capacity
(barrels)
4,000
9,000
14,000
20,000
27,500
35,000
55,000
70,000
30,000
Tank Diane tar
(feet)
30
40
50
60
70
SO
100
110
120
Tank Height
(feet)
30
40
40
40
40
40
40
40
40
Cost Installed3
(S per barrel)
1.35
0.71
0.53
0.52
0.52
0.45
0.42
0.39
0.37
Costs are for Southern California and do not include tank clean-
ina costs or sales rax.
5-8
-------
6.0 CONCLUSIONS
The primary goal of this project was to estimate existing
annual HC emissions from floating-roof and fixed-roof tanks having
capacities greater than 151,000 liters and located at refinery, term-
inal, tank farm , and pipeline facilities. To estirrate emissions,
individual tank data were compiled for approximately 25,000 tank lo-
cations throughout the United States. The emission calculations were
performed using equations described in the EPA document Compilation
of Air Pollutant Emission Factors. Results for the emission esti-
mates showed:
1. For the year 1976, total annual HC emissions from floating-roof
0
tanks were on the order of 1.4 x 10 kg/yr.
2. For the year 1976, total annual HC emissions from fixed-roof
a
tanks were on the order of 6.9 x 10 kg/yr.
3. Assuming the retrofit of internal flcatirg roofs ir the
existing fixed-roof tanks storing petroleum liquids which
have a vapor pressure greater than IG.ckPa, existing total
annual HC emissions from fixed-roof tanks would be on the
g
order of 1.6 x 10 kg/yr.
The American Petroleum Institute is sponsoring a project to de-
velop nev.' methods for estimating HC emissions frcr tanks. U-hen these
methods become available, a new set of calculations can be performed
using the individual tank data base to provide more accurate istirraces
of HC emissions from fixed-roof and floating-roof tanks.
6-1
-------
-------
7.0 REFERENCES
1. Masser, C.C., "Storage of Petroleum Liquids," Compilation of
Air Pollutant Emission Factors, Supplement No. 7, AP-42, U.S.
Environmental Protection Agency, Research Triangle Park,
North Carolina, April 1977.
2. "Standards of Performance For Mew Stationary Sources," Federal
Register, Vol. 39, No. 47, March 3, 1974.
3. Cantrell,A., "Annual Refining Survey," Oil and Gas Journal,
March 28, 1977.
4. API Bulletin 2517: Evaporation Loss From Floating-Roof Tanks,
American Petroleum Institute, Washington, D.C., February, 1962.
5. API Bulletin 2519: Use of Internal Floating Covers and Covered
Floating Roofs to Reduce Evaporation Loss, American Petroleum
Institute, Washington, D.C., May 1976.
5. API Bulletin 2518: Evaporation Loss From Fixed-Roof Tanks,
American Petroleum Institute, Washington, D.C., June 1962.
7. Chicago Bridge and Iron Company, Floating Roof Emission Test
Program, Report to Standard Oil Company Ohio, November 1976.
8. Chicago Bridge and Iron Company, Metallic Sealing Ring Emission
Test Program, Report to Western Oil and Gas Association, March
1977.
9. Engineering-Science, Inc., Hydrocarbon Emissions From FToating-
Roof Storage Tanks, Report to Western Oil and Gas Association,
January 1977.
10. Engineering-Science, Inc., Hydrocarbon Emissions From Fixed-
Roof Storage Tanks, Report to Western Oil and Gas Association,
July 1977.
11. Arnold, J.R., personal communication, American Petroleum
Institute Evaporation Loss Committee, July 1977.
12. Danielson, J.A., ed. . Air Pollution Engineering Manual, AP-40
U.S. Environmental Protection Agency, Research Triangle Park,
North Carolina, May 1973.
-------
13. Bankester, H., personal communication, Chicago Bridge and Iron
Company, Pasadena, California, May, 1977.
14. Lang, R., personal communication, GATX Tank Erection Corporation,
Los Angeles, California, May, 1977.
15. Baldwin, J., personal communication, Mobil Oil Corporation,
Los Angeles, California, June, 1977.
15. Murray, 3.3., personal communication, M.T. Vapor Float Company,
Anaheim, California, June, 1977.
17. Kern, R.C., personal communication, Ultra Flote Corporation,
Houston, Texas, September, 1977.
7-2
-------
APPENDIX A. EMISSION ESTIMATE METHODOLOGY
The estimation of the number of petroleum storage tanks
located in the United States and, subsequently, the annual hydro
carbon (HC) emissions from these tanks was performed in five
stages.
Stage 1 - Compilation of data about individual tanks
located throughout the United States.
Stage 2 - Tabulation of the individual tank data by
various classification schemes and calcula-
tion of annual HC emissions for each tank
location.
Stage 3 - Approximation of the numbers of tanks and HC
emissions for refinery, pipeline, and
terminal locations not included in the
individual tank data base.
Stage 4 - Summation of the results from Stage 2
and Stage 3 to obtain the 1976 HC"
emission estimates.
Stage 5 - Projection of the 1976 HC emission
estimates to the years 1980 and 1985.
T
he following sections describe in detail the calculations
upon which the emission estimates are based, the approximations
of tank emissions at locations not included in the individual
tank data base, and the projections of 1980 and 1985 tank emissions
A.I EMISSION CALCULATIONS
Annual HC emissions were calculated for each tank listed in
the 25,000 tank data base. All comoutations were Derformed usinq
A-1
-------
computer programs. The emission calculation results were summed
for direct input into the total emission estimates and averaged to
develop tank emissions factors. The emission factors, which will
be described in Section A.2, were used to approximate HC emissions
at tank locations not listed in the tank data files.
A.1.1 EMISSION EQUATIONS
The emission calculations were performed using the emission
equations described in Section 4.3 of Supplement No. 7 for Compila-
tion of Air Pollutant Emission Factors (AP-42). " Section 4.3 from
AP-42 is reproduced in Appendix C. External floating-roof tank HC
emissions were calculated using the "standing storage loss" and
"withdrawal loss" equations. The same equations were used with a
wind speed of 1.8 m/s (4 mi/hr) for calculating the HC emissions
from internal floating-roof tanks. Fixed-roof tank HC emissions
were calculated using the "breathing loss" and "working loss"
equations.
A.1.2 EMISSION EQUATION INPUT PARAMETERS
The emission equations required three types of input parameters;
1. Meteorological parameters
2. Tank design parameters
3. Petroleum liquid property parameters
Meteorological data was assigned to each tank location. Tank
design and petroleum liquid property parameters for each tank loca-
tion were obtained from the information listed in the tank data
files. If information about a specific parameter was absent from
A-2
-------
the tank data files a value for the parameter was assumed in order
to allow the calculations to be completed. Thus, annual HC emis-
sions were calculated for all tank locations listed in the tank
data files.
A.1.2.1 Meteorological Parameters
The emission equations required wind speed for the external
floating-roof tank equations and diurnal temperature variation for
the fixed-roof tank equations. Ambient temperature was used to
estimate bulk liquid storage temperature when it was not listed for
a specific tank location in the tank data files.
To account for variations of meteorological conditions that
occur throughout the United States, the country was divided into
meteorological districts. Meteorological data summaries were ob-
tained from the National Climatic Center, Asheville, North Carolina.
Each summary comprised a tabulation of meteorological data recorded
over a ten-year period at major meteorological stations. Using
these data, the country was divided into 121 meteorological dist-
ricts. The district boundaries were selected so that the data
recorded at the station characterized the general meteorology
throughout the district.
Each tank listed in the tank data files was assigned a code
number designating the meteorological district in which the tank
was located. The emission calculations for the tank location were
performed using the meteorological data corresponding to the code
number. Annual HC emissions were calculated for three different
sets of meteorological data:
1. Annual average data
2. Monthly average data for January
3. Monthly average data for July
A-3
-------
Annual HC emissions using the January and July meteorological
data assumed the monthly conditions occur throughout the year.
The reason for including these calculations was to allow the
relative comparison of the annual HC emissions based on annual
average meteorological conditions with HC emissions for winter
and summer meteorological conditions.
A.1.2.2 Tank Design Parameters
Tank design parameters were required for the floating-roof
tank and fixed-roof tank emission equations. When information
about a tank design parameter was absent from the tank data files,
a value for the parameter was assumed. The assumptions used for
the calculations are presented in Table A-l. These assumptions
were selected by reviewing the data listed in the tank data files
and selecting values that were representative of the majority of
the tanks.
A.1.2.3 Petroleum Liquid Property Parameters
Information about the petroleum liquid true vapor pressure,
density, and vapor molecular weight were required for the emis-
sion calculations. These properties can vary significantly
depending on the hydrocarbon composition of the petroleum liquids
as well as the temperature at which the liquids are stored.
Identifying properties for different types of petroleum liquid
posed the greatest challenge to providing input values for the emis-
sion equations. For many tank locations listed in the tank data
files, no information was available about the petroleum liquid
properties. Consequently, assumptions were made for the property
values in order co complete the emission calculations. Selection
of the assumption values was complicated by the variation of the
A-4
-------
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of data available in the open literature about these properties.
A. 1.2.3.1 Storage Temperature
When petroleum liquid storage temperature was not listed
in the tank data files for a specific tank location, the tempera-
ture was assumed to equal the average ambient temperature for the
meteorological district in which the tank was located. A storage
temperature of 277 !< (40°F) was assumed if the average ambient
temperature was less than 277°K.
A.1.2.3.2 Vapor Pressure
The procedure used to input true vapor pressures (TVP) into
the emission equations is summarized in Table A-2. Reid vapor
pressures (RVP) were first converted to approximate TVP values
before being input into the emission equations. When no vapor
pressure information about the petroleum liquid stored at a
specific tank location was available, a TVP value was assumed.
The assumptions used for different refined petroleum liquids are
presented in Table A-3.
Crude oil vapor pressures vary over a wide range depending
on the crude oil source. When necessary to assume a crude oil
vapor pressure, RVP values for hypothetical crude oils were used.
The hypothetical crude oils represented composites of the major
crude oil types refined in different regions of the United States.
The relative quantities of the major crude oiTs refined in each
region were obtained from refinery crude oil slates used ror a
study about the petroleum refining industry comoleted by A. 0.
r? **
Little, Inc. (AOL). J Reid vapor pressures for the different
crude oils listed in each slate were obtained from oublished
A-6
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data. ' J A hypothetical crude oil RVP was calculated for each
refinery region by first weighting the crude oil RVP values on
the basis of the quantity of crude oil refined. These values
were then averaged to obtain the hypothetical crude oil RVP. The
ADL study did not include refineries located in the Rocky Mountain
states. The crude oil RVP used for tank locations in this region
was assumed to be that of crude oil produced from Wyoming oil
fields. The crude oil RVP assumptions are presented in Table A-4.
The conversion of RVP to TVP is normally accomplished using
the nomographs prepared by API. Because of the large volume of
individual tank data compiled for the study, converting each RVP
value manually proved to be a very time consuming task. Conse-
quently, the conversion procedure was adapted to allow the computer
program to perform the conversions. The program converted a given
RVP to an approximate TVP value by interpolating the TVP value
from a conversion table. The values tabulated in the table were
read from the API RVP-TVP conversion nomographs (see AP-42 Fig-
ures 4.3-8 and 4.3-9 in Appendix C).
The RVP values were converted to TVP values at a reference
petroleum liquid storage temperature of 289°'< (60°F). To account
for variations in TVP due to the storage of petroleum liquids at
temperatures other than 289°K, simplified relationships between
TVP and temperature were used. True vapor pressures for petro-
leum liquids having a TVP less than 6.9 kPa (1.0 psia) were not
adjusted for temperature variation. For these liquids the change
in TVP with temperature did not significantly alter the calculated
emission values. True vapor pressures for petroleum liquids, hav-
ing a TVP greater than 6.9 kPa were adjusted assuming TVP varied
linearly with storage temperature. Although the variation of TVP
with temperature is actually logarithmic, the assumed relation-
ship provided a reasonable approximation of TVP over the general
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A-10
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range of storage temperatures in floating-roof and fixed-roof
tanks (277°K (40°F) to 305°K (90°F)). The relationships used
for the emission calculations are presented in Table A-5. These
relationships were derived from the tabulated TVP values versus
temperature values listed in AP-42 Table 4.3-1 (see Appendix C).
Absence of data precluded developing similar relationships for
crude oils. Consequently, crude oil RVP values were converted
to RYP values assuming the storage temperature remained at
289°K.
A.1.2.3.3 Other Properti es
Petroleum liquid density and vapor molecular weight were
required for the emission equations. The values used for the
emission calculations were obtained from information listed
in the tank data files when available. However, for many
tank locations values for density and vapor molecular weight
had to be assumed. The assumptions were based on values listed
in AP-42 Table 4.3-1 (see Appendix C) and are presented in
Table A-3. Gas oil and commercial jet fuel, were assumed to have
properties similar to kerosene. Diesel fuel was assumed to have
properties similar to distillate fuel. Low vapor pressure
stocks (lubricating oils, slop oils, etc.) were assumed to have
properties similar to residual fuel. The density and vapor
molecular weight of crude oils vary depending on the crude oil
source. However, the absence of crude oil property data
required assuming for all crude oils a density of 350 kg/m
(7.1 Ib/gal) and a vapor molecular weight of 50 g/g-mole.
A.2 EMISSION APPROXIMATIONS
The results from the emission calculations were for many but
not all refinery, terminal, tank farm, pipeline, and other tank
A-ll
-------
Table A-5. RELATIONSHIPS USED TO CORRECT TRUE VAPOR PRESSURE WITH
STORAGE TEMPERATURE
GENERAL RELATIONSHIP4
TVP = TVP + S (T - T }
UPA IVKR + i UR IA;
TV?A ' TVP at actual storage temperature
TVPR - TVP at reference storage temperature
TA 3 Actual storage temperature
Tn = Reference storage temperature
S * Change in TVP per degree change in temperature
"S" FACTOR FOR DIFFERENT PETROLEUM LIQUIDSb
Petroleum Liquid "S" FACTOR
Gasoline
TVPA>41 . kPa
31 . kPa < TV?A<41 . kPa
31. kPa > TVPA
Naphtha
Alky!ate
Jet Fuel (JP-4)
Refinery Intermediate
Senzene
3 Valid for storage temperature range 2SC°:< to 310°:< (40°F to 90°F)
b Based on a reference temperature of 239°!< (50°F)
A-12
(pascals per "'<}
575
421
345
345
345
115
115
115
(psia per 3F)
.15
.11
.09
.09
.09
.03
.03
.03
-------
locations throughout the United States. The number of tanks and
HC emissions were approximated for refinery and pipeline pumping
station locations not included in the tank data files.
Approximations of the total numbers of tanks at terminals in
each state were used to supplement the tabulated numbers of termv
nal tanks and calculated emissions from the tank data files.
No approximations were made for tank farm, petrochemical,
power plant, or industrial plant locations not listed in the
tank data files.
A.2.1 REFINERY TANK EMISSION APPROXIMATIONS
Refinery tank locations not listed in the tank data files
were identified using the Oil and Gas Journal "Refinery
Survey."'- " The number of tanks at these locations were approx-
imated on the basis of the rated crude oil refining capacity
(expressed as barrels per calendar day (bbl/day). Factors were
calculated expressing the average numbers of floating-roof
and fixed-roof tanks per 1000 bbl/day rated capacity. These
factors were developed by averaging tank factors calculated
for specific refinery locations listed in the tank data files.
Separate tank factors were calculated for each PAD District
in order to reflect regional variations in refinery operations.
Multiplication of the rated refining capacity times the tank
factors yielded approximations of the number of tanks at a
refinery location. The refinery tank factors used for the
approximations are listed in Table A-6.
Annual HC emissions from the tanks were determined by
multiplying the numbers of tanks by factors expressing the
average annual HC emissions per tank. These factors were
developed by averaging tank HC emissions calculated for specific
refinery locations listed in the tank data files. Separate
A-13
-------
Table A-6. TANK APPROXIMATION FACTORS
PAD
DISTRICT
1
2
3
4
(-
TANK APPROXIMATION FACTORS
REFINERY
Tanks per 1 ,000 bbr
Crude Oil Refining Capacity
Fixed-
roof
.8
.8
.8
.3
.8
Floating-
roof
.4
.3
.3
.4
.4
TERMINAL
Tanks per 1 ,000
Population
Fixed-
roof
.06
.03
.04
.02
.03
Floating-
roof
.03
.03
.03
.02
.03
a.
,000 barrels = 159,000 liters
-------
tank emission factors were computed for each PAD District and the
three meteorological conditions. The refinery tank emission
factors are presented in Table A-7.
A.2.2 Pipeline Tank Approximations
No attempt was made to identify the specific pumping station
locations not listed in the tank data files. Instead, the total
number of pipeline pumping stations located in each state was
determined. This was accomplished by counting pumping station
locations on crude oil and refined product pipeline maps
published by the Oil and Gas Journal. The total number of
pumping stations was subtracted from the number of pumping
stations listed in the tank data files to determine the number
of additional station locations for which tank and HC emissions
must be made.
To approximate the number of tanks at these additional
pumping stations, a factor of two tanks per station
-------
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-------
approximated for each state. The assumption was made that the
number of terminal tanks in a state is related to demand for
petroleum products, and demand is related to population. Tank
factors were developed expressing the average number of floating-
roof and fixed-roof tanks per 1000 population. Factors were
calculated for the specific states for which the tank data
files were judged to provide a complete inventory of terminal
tanks in the state. Averaging of the calculated values
yielded terminal tank factors for each PAD District. These
factors are presented in Table A-6. Using the populations of
each state and the terminal tank factors, the total numbers of
terminal tanks in each state were approximated.
The difference between the approximated total number of
terminal tanks and the number of terminal tanks listed in
the tank data files indicated the number of additional tanks
for which HC emission approximations were to be made. Annual
HC emissions from these tanks were approximated by multiplying
the number of tanks by factors expressing the average annual HC
emissions per tank. Like the refinery tank emission factors,
these factors were developed by averaging the tank HC emissions
calculated for specific terminal locations listed in the tank
data files. Separate tank emission factors were computed for each
PAD District and the three meteorological conditions. The terminal
tank emission factors are presented in Table A-7.
A.3 SAMPLE CALCULATION OF TOTAL TANK EMISSIONS
A simplified sample calculation is presented for a state
located in PAD District 2 to illustrate the basic emission esti-
mate methodology. For the state selected for the example,
individual tank data was available for terminal and tank farm
locations in the state. No individual tank data was available
A-17
-------
for refinery or pipeline facilities. Table A-8 presents a
summary of the data used for the calculations.
The individual tank data was keypunched on computer cards.
The cards were used to create a computer data file. Using the
computer program developed for the project, emission calcula-
tions were performed for each tank location listed in the data
files. A sample page of the computer printout is shown in
Figure A-l. The printout tabulates the HC emissions from each
tank location for the three different sets of meteorological
data.
The HC emissions from tanks located at refinery and pipe-
line facilities in the state were approximated using the pro-
cedure outlined in Section A-2. The number of tanks at these
facilities were first approximated by using the tank factors
presented in Table A-6 and the general data presented in Table
A-8. From the approximated number of tanks, emissions were cal-
culated using the factors shown in Table A-?7,
The results of the computer calculations and the tank
approximation calculations are shown in Table A-9. Summation
of these results yielded the total estimates of annual HC emis-
sions from floating-roof and fixed-roof tanks in the state for
the year 1976.
A.4 1980 AND 1985 EMISSION PROJECTIONS
Future petroleum storage tank HC emissions will depend on
the number of new tanks constructed in the United States as well
as the type of emission controls installed on new and existing
tanks. 3oth factors were considered for the 1980 and 1985 emis-
sion projections.
A-18
-------
Table A-8. SUMMARY OF DATA USED FOR SAMPLE CALCULATION
GENERAL DATA
Location - PAD District 2
1970 state population - 4,418,000
1976 total refinery capacity in state - 45,400 bbl/day
Number of crude oil pipeline pumping stations - 12
Number of refined product pipeline pumping stations - 7
Meteorological condition - annual average
INDIVIDUAL TANK DATA
Individual tank data was compiled for 169 tanks at ter-
minal and tank farm locations in the state.
A-19
-------
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-------
STATE IN PAD DISTRICT 2
TERMINALS AND TANK FARMS
Individual tank aata was compiled for terminal and tank farm facilities located in the state. Annual HC emissions
from each tank location were calculated using a computer program. The summed results of the calculations assuming
annual average meteorological conditions were:
Tank Type
Floating-roof
Fixed-roof
Number of Tanks
98
71
REFINERIES
Total Annual HC Emissions
;'1Q3 kg/yr)
647,000
2,307,000
No individual tank data was compiled for refineries in the state. Total annual HC emissions were approximated usi
tne general data presented in Table A-8 and the appropriate factors from Tables A-6 and A-7.
FT gating-roof tanks
(45,400 bbl/day)(0.0003 tanks/bbl/day) = 14 tanks
( 14 tanks)(12,000 kg/yr/tank) = 168.000 kc/yr
Fixed-roof tanks
(45,400 bbl/day)(0.0008 tanks/bbl/day) = 37 tanks
( 37 tanks) (17,000 kg/yr/tank) = 629.OCQ kg/yr
PIPELINE PUMPING STATIONS
No individual tank data was compiled for pipeline pumping stations in tne stats. Total annual HC emissions were
approximated using the general data presented in Table A-8 and the procedure outline in Section A.2.2.
Floating-roof tanks
( 7 stations)(2 tanks/station) = 14 tanks
( 14 tanks)(12,000 kg/yr/tank) = 153,000 ko/yr
Fixed-roof tanks
(12 stations)(2 tanks/station) = 24 tanks
(24 tanks) (17,000 kg/yr/tank) = 408,000 kg/yr
TOTAL ANNUAL HC EMISSIONS
Float:na-roof tanks
647,000 kg/yr + 163,000 kg/yr - 163,300
-------
A.4.1 PROJECTED NUMBER OF TANKS
Projections of total numbers of tanks in 1980 and 1985 were
made by linear extrapolation of the 1976 estimated tank numbers.
A ratio of future to current total storage capacity was used to
project upward the 1976 estimated tank numbers by volatility
class and PAD District. The basic equations used for the
projections are shown below.
(1980 Capacity)
(1980 No. of Tanks) =
(1985 No. of Tanks) =
(1976 Capacity)
(1985 Capacity)
(1976 Capacity)
x (1976 Mo. of Tanks)
x (1976 No. of Tanks)
A.4.1.1 Projected Total Tank Storage Capacity
Total tank storage capacity in the United States is a
function of the demand for petroleum liquids. Prior to 1973,
petroleum demand projections could be based on historical trends.
However, uncertainties about the availability of crude oil
supplies as well as changes in national energy policies have
increased the complexity of petroleum demand forecasting.
Future petroleum demand has been the subject of recent
r/" 71
studies.°' However, these projections did not lend
themselves directly to estimating future tank storage capacity.
Elaborate projections of future petroleum demand are beyond
the scope of this study. Furthermore, since the tank projections
were based on the relative increase in future storage capacity
compared to current storage capacity, a simplified approach was
adopted to estimate total storage capacity.
A-22
-------
Total tank storage capacity was estimated assuming:
1. Demand for refined products in the United States
is satisfied by domestic refinery output.
2. Total tank storage capacity is a function of total
crude oil refined capacity (expressed in barrels
per day).
Based on these assumptions the following equation was devised.
'Total Tank"
Storage
.Capacity .
=
'Crude Oil
Refining Capacity
.(CORC)
"Product to"
Crude Oil
Ratio
L(PCOR) J
X
X
'Crude Oil
Storage Period
.(COSP)
"Crude Oil
Refining Capacity
.(CORC)
X
"Product"
Storage
Period
L(PSP) J
The crude oil and product storage periods represent the number of
days of storage capacity a refinery has to maintain operation
flexibility and to provide for seasonal demand variations. The
product to crude oil ratio represents the amount of refined
product producsd per barrel of crude oil.
To determine the ratio of 1980 to 1976 total tank storage
capacity, the following equation was used.
(1980 Capacity) {(1980 COSP)-[(1980 PCQR)x(1980 PSP^x (1980 CORC;
(1976 Capacity) |(1976 COSP)+[(1976 PCOR)x(1976 PSP)]lx(1976 CORC/
To further simplify the equation, the following assumptions were
made.
1. The crude oil and product storage periods are equal.
2. The crude oil storage period remains constant
through 1980.
3. The product to crude oil ratio remains constant
througn 1980.
A-23
-------
These assumptions allowed the projections to be made using
the equation shown below.
(1930 Capacity) = (1980 CORC)
(1976 Capacity) (1976 CORC)
Using an identical approach, the ratio of 1985 to 1976
total tank storage capacity was calculated by the following
equation.
(1985 Capacity) = (I9S5 CORC)
(1976 Capacity) (1976 CORC)
A. 4. 1.2 Projected Crude Oil Refining Capacity
Projections of 1980 and 1985 crude oil refining
capacities were made for each PAD District using the 1976
domestic refining capacity as the baseline. The Oil and Gas
re]
Journal "Annual Refinery Survey'"- J was the source for the
1976 baseline refining capacities.
The increase in total domestic refining capacity for
1980 was projected by totaling announced refinery expansion
and new construction plans. It was assumed all planned
refinery construction would be completed on schedule. Table
A-1C lists the refinery expansion and new construction plans
used for the calculations.
No specific refinery expansion or new construction
information was available for the oeriod 1980 to 1985. Conse-
quently, the increase in total domestic refining capacity for
1985 was determined by projecting tne total 1976 refining capacity
to 1935.
A-24
-------
Table A-1C. ANNOUNCED REFINERY EXPANSION AND NEW CONSTRUCTION PLANS
fa 9l
Company And Location1 ' J
1 9
Steuart Petroleum Company
(Piney Point) Maryland
Mallard Exploration, Incorp-
orated (Atmor) Florida
Midland Corporation
(Cushing) Arkansas
Shell Oil Company
(Woodriver) Illinois
Tenneco (Chalmette) Louisiana
Gulf Oil (Luling) Texas
Exxon (Bay town) Texas
Energy Company of Alaska
(Fairbanks) Alaska
California Oil Purification
(Ventura) California
Standard Oil of California
(Perth Amboy) New Jersey
1 9
Crown Central Petroleum Corp-
oration (Baltimore) Maryland
Hampton Roads Energy Company
(Portsmouth) Virginia
Oddesa Refining, Incorporated
(Mobile) Alabama
Dow Chemical Company
(Freeport) Texas
Hudson Oil Refining (Bayport)
Texas
1 9
Pittston Company (Eastport)
Maine
Cascade Energy Resources
(Rainier) Oregon
Type
7 7
N
N
E
E
E
N
E
N
E
E
7 3
E
N
N
N
N
7 9
N
i
i
I
N
PAD
District
1
1
3
2
3
3
3
5
5
1
L
1
3
3
3
1
5
Refinery Process
Capacity
(Barrels Per Day)
100,000
7,000
16,000
30,000
30,000
30,000
250,000
25,000
|
i
15,000
i
t \
30,000
200,000
184,000
120,000 ;
200,000 ;
i
200,000 ;
250,000 \
200,000
E - Expansion at existing refinery
N - New refinery to be constructed
A-25
-------
Using an annual growth rate of 2.4 percent, the total
refining capacity for the United States in the year 1985 was pro-
jected to be 20 million barrels per day. The 2.4 percent factor
is a projected growth rate of future petroleum product demand in
the United States obtained from Reference 8. To distribute the
projected total 1985 refining capacity, the individual 1976 state
refining capacities were used as a baseline. First, the refinery
expansions and new construction listed in Table A-10 were added
to the 1976 state refining capacities for the appropriate states.
The 1976 state refining capacities for the states for which no
specific refinery expansion or construction data were available
were then increased by a constant factor to obtain the total pro-
jected capacity of 20 million barrels per day. The resulting dis-
tribution of the 1985 refining capacity by states is shown in
Table A-ll. Summation of these results by PAD District yield the
1985 refining capacities.
Table A-12 shows by PAD District the 1976 baseline refining
capacities and the 1980 and 1985 projected refining capacities.
A.4.1.3 Major Proposed Terminal Projects
Additional consideration was given to major seaport crude
oil terminal projects being planned. A terminal is expected
to be built on the West Coast to handle Alaskan oil. Oil
transported through this terminal will be used at refineries
in PAD District 5 as well as distributed to refineries in
PAD Districts 2 and 3. Alaskan oil fields have been estimated
to produce 1.7X10 barrels per day of oil by 1980 and 2.4X10
r "* i
barrels per day by 1985.L ' J To estimate the number of tanks
required to handle this oil, it was assumed all of the tanks would
be external floating-roof tanks with caoacities of 530,000 barrels.
A-25
-------
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A-27
-------
Table A-12. DOMESTIC REFINING CAPACITY BY PAD DISTRICT
PAD
District
REFINING CAPACITY (barrels/day)
Baseline
1976^
1
2
3
4
5
Total
j
1,836,320
4,125,171
6,737,358
567,436
2,854,285
16,170,570
Projected
1980
2,507,320
4,155,171
7,633,358
567,436
3,094,285
18,057,570
Projected
1985
2,377,049
4,832,040
8,067,598
664,669
3,553,474
i
i
i
19,99^,830
i
A-28
-------
Using a 7 day storage factor, it was calculated that 18 tanks would
be required in 1980 and 26 tanks in 1975. These tank numbers
were added to the 1980 and 1985 projected number of tanks for
PAD District 5. The only other announced major terminal project
is the Louisiana Off-Shore Oil Port (LOOP) located in PAD
District 3. However, storage at this terminal is to be under-
ground in salt domes.
A.4.1.4 Tank Type Distribution
The projected numbers of tanks determined by linear
extrapolation of the 1976 values assume the current distri-
bution of the tank numbers by tank type. However, the New Source
Performance Standards (NSPS) require all new tanks storing
petroleum liquids having a volatility greater than 10.5kPa
(1.52 psia) to be of floating-roof design or have a vapor
recovery system. * Consequently, the projected numbers of
tanks for 1980 and 1985 were re-distributed by tank type to
comply with NSPS. The projected total numbers of new tanks in
volatility classes 3, 4 and 5 were counted as external floating-
roof tanks.
A-29
-------
A.4.2 PROJECTED HC EMISSIONS
Projections of storage tank HC emissions for 1980 and 1985
were made by linear extrapolation of the 1976 estimated HC
emissions. A ratio of future to current numbers of tanks was
used to project upward the 1976 emission values by volatility
class and PAD District. The basic equations used for the
projections are shown below.
(1980 No. of Tanks)
1980 Emissions) =
(1985 Emissions)
(1976 No. of Tanks)
(1985 No. of Tanks)
(1976 No. of Tanks)
X (1976 Emissions)
X (1976 Emissions)
A-30
-------
REFERENCES
1. Nasser, C.C., "Storage of Petroleum Liquids," Compilation of
Air Pollutant Emission Factors, Supplement No. 7, AP-42, U.S.
Environmental Protection Agency, Research Triangle Park, North
Carolina, April 1977.
2. A.D. Little, Inc., The Impact of Lead Additive Regulations of
the Petroleum Refining Industry, EPA-450/3-76-016, U.S. Environ-
mental Protection Agency, Research Triangle Park, North
Carolina , May 1976.
3. "Guide to World Crudes," Oil and Gas Journal, March 29, 1976,
April 12, 1976, April 26, 1976.
4. Considine, D.M., ed. Energy Technology Handbook, McGraw-Hill
Incorporated, New York, 1977.
5. Cantrell,A., "Annual Refining Survey," Oil and Gas Journal,
March 28, 1977.
6. A Western Regional Energy Development Study: Economics, Final
Report, 2 Volumes, Contract No. EQ5AC007 and EQ5AC008, Stanford
Research Institute, Menlo Park, California, November, 1976.
7. Draft 1977 National Energy Outlook, Federal Energy Administra-
tion, Washington, D.C., January, 1977.
8. Reed, L.J., "Outlook for Refining Capacity," Hydrocarbon
Processing, June, 1977.
9. "Worldwide Construction," Oil and Gas Journal, April 26, 1976.
10. "Standards of Performance for New Stationary Sources," Federal
Register, Vol. 39, No. 47, March 3, 1974.
A-31
-------
APPENDIX S
TANK DATA FILE SUMMARY
Data for approximately 25,000 tank locations were listed in the
tank data files. Processing of the data comprised sorting the tank
data by various classification schemes and calculating the annual
HC emission for each tank location. The following series of tables
summarizes the distribution of tanks listed in the tank data files
and the results of the emission calculations.
Total Number of Tanks
Table 8-1 Tabulated Number of Tanks by Industry Sector
Table B-2 Tabulated Number of Tanks by Volatility Class
Table 3-3 Tabulated Number of Tanks by Petroleum Liquid Type
Total Tank Capacities
Table 8-4 Tabulated Total External Floating-Roof Tank Capacity
Table B-5 Tabulated Total Internal Floating-Roof Tank Capacity
Table 8-6 Tabulated Total Fixed-Roof Tank Capacity
Tank Design Characteristic^
Table 8-7 Tabulated Number of Floating-Roof Tanks by Tank Capacity
Table B-8 Tabulated Number of Fixed-Roof Tanks by Tank Capacity
Table B-9 Tabulated Number of Tanks by Tank Construction
Table 8-10 Tabulated Number of Floating-Roof Tanks by Roof Type
Table 8-11 Tabulated Number of Floating-Roof Tanks by Seal Type
B-l
-------
Annual HC Emissions
Table 8-12 Tabulated Annual HC Emissions by Industry Sector
Table B-13 Tabulated Annual HC Emissions by Volatility Class
Table 8-14- Tabulated Annual HC Emissions by Petroleum Liquid Type
3-2
-------
Table 8-1. TABULATED NUMBER OF TANKS BY INDUSTRY SECTOR
FLOATING ROOF
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Refinery
539
928
1,541
177
1,226
4,411
Terminal
851
718
314
41
553
2,477
Tank Farm
122
93
202
11
151
579
Pipeline
28
166
97
2
117
410
Other
37
214
20
0
37
308
TOTAL
1,577
2,119
2,174
231
2,084
8,185
External and internal floating-roof tanks
FIXED ROOF
TANKS
PAD
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Refinery
1,501
2,518
3,024
325
2,476
9,844
Terminal
1,440
1,107
463
44
786
3,840
Tank Farm
83
98
228
11
326
746
Pipeline
22
257
46
2
155
482
Other
311
1,064
269
n
356
2,011
TOTAL
3,357
5,044
4,030
393
4,099
16,923
8-3
-------
Table 8-2. TABULATED NUMBER OF TANKS BY VOLATILITY CLASS
FLOATING
ROOF
T A N ,< Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
125
223
407
14
402
1,171
2
120
166
150
17
421
874
3
847
1,382
818
175
775
3,997
* ! 5
453
321
751
25
468
2,018
32
27
48
0
18
125
TOTAL
1,577
2,119
2,174
231
2,084
8,185
a -
External and internal floating-roof tanks
I X E D ROOF
TANKS
0 A 0
DISTRICT
1
2
3
4
5
TOTAL
V 0 L /a
1
1,998
2,898
2,638
267
1,986
9,787
T I L
2
516
525
216
55
1,102
2,414
I T Y
^
705
1,386
329
61
818
3,799
C L A
4
128
221
343
10
191
893
S S
5
1Q
14
4
0
2
30
. T n ~ A i
7 7S7
-. 5 w> /
5,04^
4,030
393
4,099
16,923
3-4-
-------
Table B-3. TABULATED NUMBER OF TANKS BY PETROLEUM LIQUID TYPE
PETROLEUM LIQUID TYPE
Crude Oil
Gasoline
Diesel fuel
Jet fuel , kerosene
Jet fuel, JP-4
Distillate fuel oil3
Residual fuel oil
Naphtha
Alky! ate
Medium vapor pressure stocks0
Low vapor pressure stocks
Benzene
Other8
TOTAL
TANK TYPE
External
Floating
Roof
1,233
3,7S5
125
143
290
479
83
238
57
450
105
119
231
7,348
Internal
Floating
Roof
78
425
22
14
15
44
12
43
3
50
87
27
17
837
Fixed
ROO-P
1,442
2,436
787
669
533
3,455
1 ,001
294
44
1,411
3,528
53
1,270
16,923
Fuel oil grades 1,2,3
Fuel oil grades 4, 5, 6
cPetroleum liquid vapor pressure greater than 3.4 kPa (.5 psia)
Petroleum liquid vapor pressure less than 3.4 kPa (.5 psia)
£t
Unidentified refined petroleum liquids
3-5
-------
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Table B-9. TABULATED NUMBER OF TANKS BY TANK CONSTRUCTION
PAD District
1
2
3
4
5
TOTAL
Type of Tank Construction
Wei ded
377
354
184
39
952
1,906
Riveted
75
216
150
0
712
1,153
Not Identified
4,482
6,593
5,870
585
4,519
22,049
B-ll
-------
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o
c;
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21
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i
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ex
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o
y
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i
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z c
CD
c
C
-------
Table 8-11. TABULATED NUMBER OF FLOATING-ROOF TANKS BY ROOF
SEAL TYPE
PAD
DISTRICT
1
2
3
4
5
TOTAL
FLOATING ROOF
SEAL TYPE
Is
142
198
265
12
154
771
It
62
0
2
0
81
145
2s
5
0
1
0
2
8
2t
17
0
0
0
n
28
Not
identified
1,351
1,921
1,906
219
1,836
7,233
TOTAL
1,577
2,119
2,174
231
2,084
8,185
Is: Primary seal, mechanical type
It: Primary seal, resilient type
2s: Primary seal, mechanical type and secondary seal
2t: Primary seal, resilient type and secondary seal
8-13
-------
Table B-12. TABULATED ANNUAL HC EMISSIONS 3Y INDUSTRY AREA
Annual Average Meteorological Conditions
(units: 1 ,000 kg/yr)
FLOATING
R 0 0
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
INDUSTRY SECTOR
Refinery
6,937
10,377
16,928
994
12,300
TOTAL! 47,535
(
Terminal
7,616
7,028
4,572
48
4,804
24,068
Tank Farm
1,743
894
3,054
77
870
6,638
Pipeline
289
1,460
1,184
2
747
3,682
Other
174
1,120
232
0
39
TOTAL
16,759
20,879
25,970
1,121
18,760
1,565 83,489 i
External and internal floatina-roof tanks
FIXED
ROOF
T A N K S
a A D
DISTRICT
1
2
3
1
Refinery
41,794
112,413
88,866
4,546
5 49,313
TOTAL, 296,932
INDUSTRY SECTOR
Terminal
32,980
30,278
10,174
78
Tank Fam Pipeline
17,805
3,713
5,028
20
113
12,474
5,413
o
46,170 4,435 11,394
119,680
31,051 29,394
Other
1,889
11,047
2,046
163
4,593
19,733
T 0 T A L !
I
94,531
159,925 |
111,527 i
4,307 '
116,455
497,295
B-U
-------
Table B-12.
TABULATED ANNUAL HC EMISSIONS BY INDUSTRY AREA
(Continued)
January Meteorological Conditions
(units: 1,000 kg/yr)
FLOATING
ROOF
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Ref i nery
6,685
9,192
16,823
888
10,837
44,425
Terminal
6,201
6,563
4,343
36
3,717
20,860
Tank Farm
1,337
881
3,143
56
629
6,546
Pipeline
196
1,388
1,129
2
578
3,293
Other
173
871
222
0
37
1,303
TOTAL
15,092
18,895
25,660
982
15,798
76,427
External and internal floating-roof tanks
FIX. ED ROOF TANKS
INDUSTRY
SECTOR
PAD
DISTRICT
1
2
-1}
4
5
TOTAL
Refinery
31,519
81,066
35,283
3,761
45,362
246,991
Terminal
27,238
25,093
9,206
57
43,655
105,249
Tank Farm
12,108
3,112
4,464
14
4,034
23,732
Pipe! ine
112
10,052
4,783
0
11,105
26,052
Other
1,545
7,701
1 ,413
114
4,132
14,905
. f D T fl 1 <
i U 1 n 1_ |
72,522 i
127, 02* ;
105.U9 ;
3,946
108,283 '
416,929 ;
B-15
-------
Table 8-12.
TABULATED ANNUAL HC EMISSIONS BY INDUSTRY AREA
(Concluded)
July Meteorological Conditions
(units: 1,000 kg/yr)
FLOATING ROOF
T A N K Sc
PAD
DISTRICT
2
2
4
5
INDUSTRY SECTOR
Refinery
7,323
11,629
16,332
1,319
12,710
TOTAL 49,313
Terminal
8,635
7,890
4,569
76
5,790
26,960
Tank Farm
2,436
901
2,734
130
1,127
7,323
Pipeline
382
1,638
1,160
2
903
4,085
Other
172
1,507
235
0
39
1,953
TOTAL
18,953
23,565
25,030
1,527
20,569
89,644
i
External and internal floating-roof tanks
FIXED
ROOF
TANKS
; PAD
; DISTRICT
; i
2
! 3
fl
: 5
I TOTAL
Refinery
57,616
165,201
91,553
7,298
52,373
374,646
i. ,1 U U J
Terminal
42,683
40,086
11,005
126
51,389
145,289
1 K [ O
Tank Farm
25,066
4,738
5,507
34
5,302
40,747
i U 1 U rt
Pipe! ine
109
20,435
5,972
0
12,719
39,235
Other
2,367
16,961
2,714
292
4,369
27,203
T 0 T fl '
127,341
247,471
116,951
7,750
- ^ -7 t --^
i Ll , I 3/
527,170
3-15
-------
Table B-13. TABULATED ANNUAL HC EMISSIONS BY VOLATILITY CLASS
Annual Average Meteorological Conditions
(units: 1,000 kg/yr)
FLOATING -ROOF TANKS0
PAD
DISTRICT
1
2
3
4
5
TOTAL
L
VOLATILITY CLASS
1
65
119
673
14
45*1
1,325
2
1,087
799
653
57
1,307
3,903
3
8,053
12,684
7,910
819
6,166
35,632
4
6,523
6,496
14,430
231
8,908
36,588
5
1,031
781
2,304
0
1,925
6,0^1
TOTAL
16,759
20,379
25,970
1,121
18,760
83,489
External and internal floating-roof tanks
FIXED
ROOF
TANKS
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
2,970
3,157
11,951
197
3,296
21,571
2
14,656
14,604
5,911
567
45,323
81,061
3
64,685
118,659
55,228
3,720
47,130
289,422
4
10,042
32,759
36,293
339
12,415
5
. 1,613
1,212
2,1^4
0
8,291
91,848| 13,250
TOTAL
93,966
i
170,391
111,527
4,823
116,455
497,162
3-17
-------
Table 8-13.
TABULATED ANNUAL HC EMISSIONS BY VOLATILITY CLASS
(Continued)
January Meteorological Conditions
(units: 1,000 kg/yr)
FLOATING
ROOF
T A N K S'
PAD
DISTRICT
1
2
JM
4
5
TOTAL
VOLATILITY CLASS
1
63
125
670
3
424
1,291
2
356
501
656
54
1,034
2,501
3
6,586
10,910
7,770
702
4,933
30,901
4
7,031
6,532
14,250
218
7,420
35,451
5
1,056
326
2,3U
0
1,987
6,133
TOTAL
15,092
18,395
25,660
932
15,793
75,427
External and internal floating-roof tanks
I X E 0
ROOF
A N < S
PAD
DISTRICT
.
i
7
3
4
5
TOTAL
VULHIiLilT LLMii
1 | 2
3,270
2,003
11 5"3"1
1 1 , *J*S >
192
2,975
21 ,071
9,734
9,352
5,710
504
36,399
52,749
3
43,249
38,239
51,463
2,936
36,508
227,445
4
9,722
5
1,534
23,385 1,156
34,325
314
7,048
2,020
0
5,621
75,294 11,331
TOTAL
72,559
125,135
105,1 49
3,946
90,051
39", 390
3-18
-------
Table B-13.
TABULATED ANNUAL HC EMISSIONS BY VOLATILITY CLASS
(Concluded)
July Meteorological Conditions
(units: 1,000 kg/yr)
FLOATING
ROOF
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
60
113
628
9
448
1,258
2
443
558
622
58
1,391
3,172
3
10,322
16,174
7,667
1,220
6,611
41,994
4
7,234
5,971
13,911
240
10,348
37,704
5
394
676
2,202
0
1,771
5,543
TOTAL
18,953
23,592
25,030
1,527
20,569
89,671
External and internal floating-roof tanks
FIXED
ROOF
TANKS
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
3,402
3,250
12,100
231
3,169
22,152
2
19,871
21,152
6,070
697
48,400
96,190
3
92,648
177,004
58,532
6,469
53,328
387,981
4
10,276
42,816
37,999
353
13,493
104,937
5
1,644
1,203
2,250
0
3,767
13,864
TOTAL
127,341
245,425
116,951
7,750
127,157
525,124
B-19
-------
Table 3-14. TABULATED ANNUAL HC EMISSIONS 3Y PETROLEUM LIQUID TYPE
Annual Averace Meteoroloaical Conditions
(units: 1000 kg/yr)
TANK TYPE
i External
Internal
PETROLEUM LIQUID TYPE Floating Floating
Crude Oil
Gasol ine
Diesel fuel
Jet fuel , kerosene
Jet fuel, JP-4
j Distillate fuel oila
Residual fuel oil
Naohiha
Alkylata
Medium vaoor pressure stocks
Low vaoor cressure stocks
Benzene
Other6
TOTAL
Roof \ Roof
13,586
54,913
244
259
1,125
1,176
107
2,722
713
2,411
433
569
2,025
80,234
353
2,321
33
17
34
42
3
179
14
93
34
31
3,205
i
!
Fixed
Roo^
123,587
241,613
2,431
3,738
13,321
12,384
3,154
11,067
1,325
45,660
5,510
879
31,626
497,295
Fuel oi1 grades 1,2,3
Fuel oil grades 4, 5, 5
c?e*roleum liquid vapor pressure greater than 3.4 k?a (.5 psia)
Petroleum liquid vapor pressure less than 3.4 kPa (.5 psia)
eUnidentified refined petroleum liquids
3-20
-------
Table 8-14.
TABULATED ANNUAL HC EMISSIONS BY PETROLEUM LIQUID TYPE
(Continued)
January Meteorological Conditions
(units: 1000 kg/yr)
PETROLEUM LIQUID TYPE
Crude Oil
Gasoline
Diesel fuel
Jet fuel , kerosene
Jet fuel, JP-4
Distillate fuel oila
Residual fuel oil
Naphtha
Alky! ate
Medium vapor pressure stocks0
Low vapor pressure stocks
Benzene
Other8
TOTAL
TANK TYPE
External
Floating
Roof
13,668
49,529
237
254
999
1,162
102
2,599
684
2,281
415
561
1,138
73,629
Internal
Floating
Roof
353
2,024
33
17
84
42
3
155
14
13
1
32
27
2,798
Fixed
Roo^
122,420
161,120
2,392
3,726
11,182
12,712
3,087
8,271
M87
37,198
5,536
702
28,057
397,390
Fuel oil grades 1,2,3
Fuel oil grades 4, 5, 6
""Petroleum liquid vapor pressure greater than 3.4 kPa (.5 psia',
Petroleum liquid vapor pressure less than 3.4 kPa (.5 psia)
Unidentified refined petroleum liquids
B-21
-------
fable 3-14. TABULATED ANNUAL HC EMISSIONS BY PETROLEUM LIOUIO TYPE
(Concluded)
July Meteorological Conditions
(units: 1000 kg/yr)
PETROLEUM LIQUID TYPE
Crude Oil
Gasol ine
Diesel fuel
Jet fuel , kerosene
Jet fuel , JP-4
Distillate fuel oil3
h
Residual fuel oil
i
Naphtha
Alkylate
; Medium vapor pressure stocks0
Low vaoor pressure stocks
; Benzene
1 a
; Other"
TANK TYPE
External
Internal
Floating Floating
Roof I Roof
12,605
62,622
232
247
1,180
1,107
105
2,723
353
Fixed
Roo*
123,960
2,827 1333,603
33
17
35
42
3
204
703 13
2,409 151
420
537
1
36
976
35
TOTAL i 85,371 3,300
2,423
3,643
23,156
12,811
3,140
14,845
2,290
56,613
3,444
1,079
37,117
525,124
Fuel oil grades 1,2,3
Fuel oil grades 4; 5, 6
""Petroleum liquid vapor pressure greater than 3.4 kPa (.5 psia)
Petroleum liquid vaoor pressure less than 3.4 kPa (.5 psia)
sUnidentified refined petroleum liquids
3-22
-------
APPENDIX C
EMISSION EQUATIONS
The emission calculations were performed using the emission
equations described in Supplement No. 7 for Compilation of Air
Pollutant Emission Factor, AP-42, U.S. Environmental Protection
Agency, April 1977. The following pages are a reproduction of
Section 3.4, "Storage of Petroleum Liquids."
C-l
-------
4.3 STORAGE OF PETROLEUM LIQUIDS1 by Charles C. \tasser
Fundamentally, the petroleum industry consist* of three operations: (1) petroleum production and
transportation. (2) petroleum refining, and (3) transportation and marketing of finished petroleum
products. All three operations require some type of storage for petroleum liquids. Storage tanks for
both crude and finished products can be sources of evaporative emissions. Figure 4.3-1 presents a
schematic of the petroleum industry and its points of emissions from storage operations.
4.3.1 Process Description
Four basic tank designs are used for petroleum storage vessels: fixed roof, floating roof (open type
and covered type), variable vapor space, and pressure (low and high).
4.3.1.1 Fixed Roof Tanks2 The minimum accepted standard for storage of volatile liquids is the
fixed roof tank (Figure 4.3-2). It is usually the least expensive tank design to construct. Fixed roof tanks
basically consist of a cylindrical steel shell topped by a coned roof having a minimum slope of 3/4
inches in 12 inches. Fixed roof tanks are generally equipped with a pressure/vacuum vent designed to
contain minor vapor volume changes. For large fixed roof tanks, the recommended maximum operat-
ing pressure/vacuum is *0.03 psig/-0.03 psig (+2.1 g/cmV-2.1 g/cm:).
4.3.1.2 Floating Roof Tanks1 Floating root tanks reduce evaporative storage losses by minimizing va-
por spaces. The tank consists of a welded or riveted cylindrical steel wall, equipped with a deck or roof
which is free to float on the surface of the stored liquid. The roof then rises and falls according to the
depth of stored liquid. To ensure that the liquid surface is completely covered, the roof is equipped
with a sliding seal which fits against the tank walL Sliding seals are also provided at support columns
and at all other points where tank appurtenances pass through the floating roof.
Until recent yean, the most commonly used floating roof tank was the conventional open-type
tank. The open-type floating roof tank exposes the roof deck to the weather, provisions must be made
for rain water drainage, snow removal, and sliding seal dirt protection. Floating roof decks are of three
general types: pan. pontoon, and double deck. The pan-type roof consists of a flat metal plate with a
vertical rim and sufficient stiffening braces to maintain rigidity (Figure 4.3-3). The single metal plate
roof in contact with the liquid readily conducts solar heat, resulting in higher vaporization losses than
other floating roof decks. The roof is equipped with automatic vents for pressure and vacuum release.
The pontoon roof is a pan-type floating roof with pontoon sections added to the top of the deck around
the rim. The pontoons are arranged to provide floating stability under heavy loads of water and snow.
Evaporation iodsea due to solar heating are about the same as for pan-type roofs. Pressure/vacuum
vents are required on pontoon roof tanks. The double deck roof is similar to a pan-type floating roof,
but consists of a hollow double deck covering the entire surface of the roof (Figure 4.3-4). The double
deck adds rigidity, and the dead air space between the upper and lower deck provides significant insu-
lation rrom iolar heating. Pressure/vacuum vents are also required.
Th^ covered-type floating roof tank is essentially a fixed-roof tank with a floating roof deck insid*
the tank (Figure 4,3-5). The American Petroleum Institute has designated the term "covered floating"
roof to describe i fixed roof tank with an internal steel pan-type floating roof. Pne term "internal float-
ing cover" has been chosen by the API to describe internal coven constructed of materials other than
steel. Floating roofs and covers can be installed inside existing fixed roof tanks. The fixed roof protects
the floating mof from the weather, and no provision is necessary for rain or anow removal, or for seal
4/77 Evaporation Loss Sources 4.3-1
-------
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EMISSIOiN FACTORS
4/77
-------
MKMOUs
Figure 4.3-2. Fixed roof storage tank.
SIM. ixrruic
Figure 4.3-3. Pan-type floating roof storage tank {metallic seals)
StM.
Figure 4.3-4. Double deck floating roof storage tank (non-metallic seals).
4/77
Evaporation Loss Sources
4.3-3
-------
Figure 4.3-5. Covered floating roof storage tank.
protection. Antirotational guides must be provided to maintain roof alignment, and the space be-
tween the fixed and floating roofs mutt be vented to prevent the possible formation of a flammable
mixture.
4.3.1.3 Variable Vapor Space Tank*4 Variable vapor space tanks are equipped with expandable
vapor reservoirs to accommodate vapor volume fluctuations attributable to temperature and baro-
metric pressure changes. Although variable vapor space tanki are sometimes used independently, they
are normally connected to the vapor spaces of one or more fixed roof tanks. The two most common
types of variable vapor space tanks are lifter roof tanks and flexible diaphragm tanks.
Lifter roof tanks have a telescoping roof that fits loosely around the outside of the main tank wall.
The space between the roof and the wall is closed by either a wet seal, which consists of a trough filled
with liquid, or a dry seal, which employs a flexible coated fabric in place of the trough (Figure 4.3-6).
-OZZl-E
Figure 4.3-6. Lifter roof storage tank (wet seal).
Flexible diaphragm tanks utilize flexible membranes to provide the expandable volume. The> may
be separate gasholder type units, or integral units mounted atop fixed roof tanks (Fizure 4.3-").
4.3-4
EMISSION FACTORS
4/77
-------
Figurs 4.3-7. Flexible diaphragm tank (integral unit).
4.3. 1.4 Pressure Tanks3 Pressure tanks are designed to withstand relatively large pressure variations
without incurring a loss. They are generally used for storage of high volatility stocks, and they are
constructed in many sizes and shapes, depending on the operating range. The noded spheroid and
noded hemispheroid shapes are generally used as low-pressure tanks (1? to 30 psia or 12 to 21 mg/.m^,
while the horizontal cylinder and spheroid shapes are generally used as high-pressure tanks (up to 265
psia or 136 mg/m:).
4.3.2 Emissions and Controls
There are six sources of emissions from petroleum liquids in storage: fixed roof breathinz -losses.
fixed roof working losses, floating roof standing storage losses, floating roof withdrawal losses, vari-
able vapor space filling losses, and pressure tank losses. *
Fixed roof breathing losses consist of vapor expelled from a tank because of the thermal expansion
of existing vapors, vapor expansion caused by barometric pressure changes, and/or in increase in the
amount of vapor due to added vaporization in the absence of a liquid-level change.
Fixed roof working losses consist of vapor expelled from a tank as a result of filling and emptvmz
operations. Filling loss is the result of vapor displacement by the input of liquid. Emptying loss is the
expulsion of vapors subsequent to product withdrawal, and is attributable to vapor growth as the ne^»-
ly inhaled air is saturated with hydrocarbons.
Floating roof standing storage losses result from causes other than breathing or changes in liquid
level The largest potential source of this loss is attributable to an improper fit of the *eal and shoe to
the shell, which exposes some liquid surface to the atmosphere. A small amount of vapor mav escape
between the flexible membrane seal and the roof.
Floating roof withdrawal losses result from evaporation of stock which wets the tank wall as the
roof descend* during emptying operations. This loss is small in comparison to other types of losses.
4/
Evaporation Loss Sources
4.3-
-------
Variable vapor space filling losses result when vapor is displaced by the liquid input during filling
operations. Since the variable vapor space tank has an expandable vapor storage capacity, this loss is
not as large as the filling loss associated with fixed roof tanks. Loss of vapor occurs only when the vapor
storage capacity of the tank is exceeded.
Pressure tank losses occur when the pressure inside the tank exceeds the design pressure of the
tank, which results in relief vent opening. This happens only when the tank is filled improperly, or
when abnormal vapor expansion occurs. These are not regularly occurring events, and pressure tanks
are not a significant source of loss under normal operating conditions.
The total amount of evaporation loss from storage tanks depends upon the rate of loss and the per-
iod of time involved. Factors affecting the rate of loss include:
1. True vapor pressure of the liquid stored.
2. Temperature changes in the tank.
3. Height of the vapor space (tank outage).
4. Tank diameter.
5. Schedule of tank filling and emptying.
6, Mechanical condition of tank and seals.
7. Type of tank and type of paint applied to outer surface.
The American Petroleum Institute has developed empirical formulae, based on field testing, that cor-
relate evaporative losses with the above factors and other specific storage factors.
4.3.2.1 Fixed Roof TanksV Fixed roof breathing losses can be estimated from:
r p 10.63
Ln = ~> "M x tO"* M nl-73 u^-Sl AT^-SO p r v t-t\
1-3 i x. lu n hd7.P u n ai rpv-N: \l>
where: Lg = Fixed roof breathing loss (Ib/day).
M s Molecular weight of vapor in storage tank (Ib/lb mole), (see Table 4.3-1).
P = True vapor pressure at bulk liquid conditions (psia): see Figures 4.3-6, 4.3-9.
or Table 4.3-1.
D = Tank diameter (ft).
H = Average vapor space height, including roof volume correction (ft); see note I'D.
AT = Average ambient temperature change from day to night (°F).
Fp = Paint factor (dimensionless); see Table 4.3-2.
C = Adjustment factor for small diameter tanki (dimensionless); see Figure 4.3-10.
KC = Crude oil factor (dimensionless); see note (2).
Note: (1) The vapor space in a cone roof is equivalent in volume to a cylinder which has the
same base diameter as the cone and is one-third the height of the cone.
(2) Kc = (0.65) for crude oil, Kc = (1.0) for gasoline and all other liquids.
\PI reports that calculated breathing loss from Equation (1) may deviate in the order of : 10 percent
from actual breathing loss.
4.3-6 EMISSION FACTORS 1/77
-------
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Table 4.3-2. PAINT FACTORS FOR FIXED ROOF TANKS2
Tank color
Paint factors (Fp)
Paint condition
Roof
Shell
Good
Poor
White
Aluminum (specular)
White
Aluminum (specular)
White
Aluminum (diffuse)
White
Light gray
Medium gray
White
White
Aluminum (specular)
Aluminum (specular)
Aluminum (diffuse)
Aluminum (diffuse)
Gray
Light gray
Medium gray
1.00
1.04
1.16
1.20
1.30
1.39
1.30
1.33
1.40
! 1J5
1.18
1.24
1.29
1.38
1.46
1.38
1.44a
1.58a
Estimated from the ratios of the seven preceding paint factors.
1.00
.30
.30
O
O
a .20
<
10 20 30
TANK DIAMETER IN FSsT
Figure 4.3-10. Adjustment factor (C) for
small diameter ranks.
Fixed roof working losses can b« estimated from:
Lw = :.40x iO'-
4.3-10
EMISSION FACTORS
I-/77
-------
where: L^- = Fixed roof working loss (lb/103 gal throughput).
M = Molecular weight of vapor in storage tank (Ib/lb mole), see Table 4.3-1.
P = True vapor pressure at bulk liquid conditions (paia); see Fizures 4.3-3. 4.3-9,
or Table 4.3-1.
K^ = Turnover factor (dimensionless); see Figure 4.3-11.
Kc - Crude oil factor (dimensionless); see note.
Note: Kc s (0.84) for crude oil. KC » (1.0) for gasoline and all other liquids.
1.0
* 0.3
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300
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TUSNCVE3S »S
ANNUAL
TANK CAPACITY
Figure 4.3-11. Turnover factor (K^) for fixed roof ranks.
The fixed roof working loss (Lw,i is the sum of the loading and unloading loss. API reports that special
tank operating conditions may result in actual losses which are significantly greater or lower than the
e-mmate-s provided by Equation (2).
The API recommends the us< of these storage loss equations only for cases apor reco* erv 5\ s-
iera that collects emissions from the storage essels and converts them to liquid product. To recover va-
por, one or a combination of four methods may be used: vapor- liquid absorption. \ apor compression.
< ipor cooling.*nd vapor solid adsorption. Overall control efficiencies of vapor recov en. -\ stems * arv
Evaporation Loss Sources
4.3-11
-------
from 90 to 95 percent, depending on the method used, the design of the unit, the composition of vapors
recovered, and the mechanical condition of the system.
Emissions from fixed roof tanks can also be controlled by the addition of an internal floating cover
o covered floating roof to the existing fixed roof tank. API reports that this can result in an average
los* reduction of 90 percent of the total evaporation loss sustained from a fixed roof tank.8
Evaporative emissions can be minimized by reducing tank heat input with water sprays, mechani-
cal cooling, underground storage, tank insulation, and optimum scheduling of tank turnovers.
4.3.2.2 Floating Roof Tanks3'7 Floating roof standing storage losses can be estimated from:
9.21xlO-3Mr-rr£-J " D^ V^-7 Kt Ks Kp Kc (3)
where: L« = Floating roof standing storage loss (Ib/day).
M = Molecular weight of vapor in storage tank lib Ib mole): see Table 4.3-1.
P = True vapor pressure at bulk liquid conditions (psia): see Figures 4.3-8. 4.3-9.
or Table 4.3-1.
D = Tank diameter (ft); see note (1).
Vw = Average wind velocity (mi/hr); see note (2).
Kt = Tank type factor (dimensionless); see Table 4.3-3.
KS = Seal factor (dimensionleas); see Table 4.3-3.
K_ = Paint factor (dimensionless); see Table 4.3-3.
P
KC - Crude oil factor (dimensionless); see note 13).
Note: (1) For D > 150, use D/150 instead of D.1-5
(2) API correlation was derived for minimum wind velocity of 4 mph. If % ^
<, 4 mph, use Vw = 4mph.
(3) Kc = (0.34) for crude oil, Kc = (1.0) for all other liquids.
API reports that standing storage losses from gasoline and crude oil storage calculated from Equa-
tion (3) will not deviate from the actual losses by more than ±25 percent for tanks in good condition un-
df r normal operation. However, losses may exceed the calculated amount if the seals are in poor condi-
lion. Although the API recommends the use of these correlations only for petroleum liquids exhibit-
ing \apor pressures in the range of gasoline and crude oils, in the absence of better correlations, these
i-orreiations are also recommended with caution for use with heavier naphthas, kerosenes, and fuel
12 EMISSION FACTORS 4/77
-------
Table 4.3-3. TANK, TYPE, SEAL, AND PAINT FACTORS
FOR FLOATING ROOF TANKS2
Tank type
Welded tank with pan or pontoon
roof, single or double seal
Riveted 'ank with pontoon roof,
double seal
Riveted tank with pontoon roof,
Riveted tank with pan roof,
double seal
Riveted tank with pan roof,
single seal
Kt
0.045
0.11
n 1 *?
U* I w
0.13
0.14
Sea/ :>pe
Tight fining (typical of modern
metallic and non-metallic seats)
Loose fitting (typical of seals
built prior to 1942)
Paint color of snell ana roof
Light gray or aluminum
White
<
-------
where: Ly * Variable vapor space filling loss (lb/10J gal throughput).
M = Molecular weight of vapor in storage tank (Ib/lb mole); see Table 4.3-1.
P - True vapor pressure at bulk liquid conditions (psia); see Figures 4.3-3, 4.3-9, or Table
4.3-1.
V( = Volume of liquid pumped into system: throughput (bbl).
V, s Volume expansion capacity of system (bbl); see note (1).
N = Number of transfers into system (dimensionless); see note (2).
Note: (1) V is the volume expansion capacity of the variable vapor space achieved by roof-
lifting or diaphragm-flexing.
(2) N is the number of transfers into the system during the time period that corre-
sponds to a throughput of V,.
The accuracy of Equation (5) is not documented; however, API reports that special tank operating
conditions may result in actual losses which are significantly different from the estimates provided by
Equation (5). It should also be noted that, although not developed for use with heavier petroleum
liquids such as kerosenes and fuel oils. Equation (5) is recommended for use with heavier petroleum
liquids in the absence of better data.
Evaporative emission* from variable vapor space tanks are negligible and can be minimized by opti-
mum scheduling of tank turnovers and by reducing tank heat input. Vapor recovery systems can be
used with variable vapor space systems to collect and recover filling losses.
Vapor recovery systems capture hydrocarbon vapors displaced during filling operations and re-
cover the hydrocarbon vapors by the use of refrigeration, absorption, adsorption, and/or compres-
sion. C /ntrol efficiencies range from 90 to 98 percent, depending on the nature of the vapors and the
recovery equipment used.
4.3.2.4 Pressure Tanks - Pressure tanks incur vapor losses when excessive internal pressures result in
relief valve venting. In some pressure tanks vapor venting is a design characteristic, and the vented
vapors must be routed to a vapor recovery system. However, for most pressure tanks vapor venting is
not a normal occurrence, and the tanks can be considered closed systems. Fugitive losses are also as-
sociated with pressure tanks and their equipment, but with proper system maintenance they are in-
significant. Correlations do not exist for estimating vapor losses from pressure tanks.
4.3.3 Emission Factors
Equations (1) through (5) can be used to estimate evaporative losses, provided the respective para-
meters are known. For those cases where such parameters are unknown. Table4.3-4 provides emission
factors for the typical systems and conditions. It should be emphasized that these emission factors are
rough estimates at best for storage of liquids other than gasoline and crude oil, and for storage con-
ditions other than the ones they are based upon. In areas where storage sources contribute a substan-
tial portion of the total evaporative emissions or where they are major factors affecting the air quality,
it is advisable to obtain the necessary parameters and to calculate emission estimates using Equations
11) through (5).
4.3-14 EMISSION FACTORS . 4/77
-------
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Evaporation Loss Sources
4.3-15
-------
4.3.3.1 Sample Calculation Breathing losses from a fixed roof storage tank would be calculated as
follows, using Equation (1).
Design basis;
Tank capacity - 100,000 bbl.
Tank diameter 125 ft.
Tank height 46 ft.
Average diurnal temperature change 15°F.
Gasoline RVP - 9 paia.
Gasoline temperature 70°F.
Specular aluminum painted tank.
Roof slope is 0.1 ft/ft.
Fixed roof tank breathing loss equation:
LB - 2.21 x lO^M fJ-J0'68 Di-73 H°-51 AT0-50 Fp C Kc
where: M = Molecular weight of gasoline vapors (see Table 4.3-1)= 66.
P = True vapor of gasoline (see Figure 4.3-8) = 5.6 psia.
D = Tank diameter = 125 ft.
AT = average diurnal temperature change = 15°F.
F = paint factor (see Table 4.3-2) = 1.20.
C = tank diameter adjustment factor (see Figure 4.3-10) = 1.0.
KC = crude oil factor (see note for equation (1)) = 1.0.
H = average vapor space height. For a tank which is filled completely and emptied, the
average liquid level is I/ 2 the tank rim height, or 23 ft. The effective cone height is 1 3
of the cone height. The roof slope is 0.1 ft/ ft and the tank radius is 62.5 ft. Effective
cone height = (62.5 ft) (0.1 ft/ft) (1/3) = 2.08 ft.
H = average vapor space height = 23 ft * 2 ft = 25 ft.
Therefore:
LD = :.:i x lO-4(66)['. . f'6. J ' (125)1-73 C5)0-51 M5>°--"0 il :)ii OM: 0)
u L ' ~ ^-°J
Lg = 1063 Ib/day
4.3-16 EMISSION FACTORS t 77
-------
References for Section 4.3
1. Burkiin, CE. and R.L. Honerkamp. Revision of Evaporative Hydrocarbon Emission Factors.
U.S. Environmental Protection Agency, Research Triangle Park, North Carolina. Report No.
EP.A-450/ 3-76-039. August 15, 1976.
2. American Petroleum Inst., Evaporation Loss Committee. Evaporation Loss From Fixed-Roof
Tanks. Bull. 2518. Washington, D.C 1962.
3. American Petroleum Inst,, Evaporation Loss Committee. Evaporation Loss From Floating-Roof
Tanks. Bull. 2517. Washington. D.C 1962.
4. American Petroleum Inst., Evaporation Loss Committee. Use of Variable Vapor-Space Systems
To Reduce Evaporation Loss. Bull. 2520. N.Y., N.Y. 1964
5. American Petroleum Inst., Evaporation Loss Committee. Evaporation Loss From Low-Pressure
Tanks. Bull. 2516. Washington, D.C 1962.
6. American Petroleum Inst., Evaporation Loss Committee. Evaporation Loss In The Petroleum
Industry. Causes and Control. API Bull. 2513. Washington, D.C 1959.
7. American Petroleum Inst., Div. of Refining, Petrochemical Evaporation Loss From Storage
Tanks. API Bull. 2523. New York. 1969
8. American Petroleum Inst., Evaporation Loss Committee. Use of Internal Floating Covers For
Fixed-Roof Tanks To Reduce Evaporation Loss. Bull. 2519. Washington, D.C 1962.
9. Baraett, Henry C et al. Properties Of Aircraft Fuels. Lewis Flight Propulsion Lab., Cleveland.
Ohio. >'AC\-T>' 3276. August 1956.
4/77 Evaporation Loss Sources 4.3-17
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APPENDIX D
EMISSION ESTIMATES USING JANUARY AND JULY
METEOROLOGICAL CONDITIONS
Hydrocarbon emissions from floating-roof tanks and fixed-
roof tanks were estimated for the year 1976 using January and
July meteorological conditions. Tables D-l and D-2 present
average monthly HC emissions for January and July by industry
sectors and volatility classes.
D-l
-------
Table 0-1. 1976 JANUARY KC EMISSION ESTIMATES
(units: 1000 kg/month)
F L 0 A T I N
ROOF
T A N K S'
P A 0
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Refinery
613
1,075
1,959
116
903
4,667
i
Terminal
1,377
1,486
769
45
336
4,013
Tank Farm
153
73
262
5
52
545
Pipeline
356
759
529
39
79
1,762
Other
15
73
19
0
4
TOTAL
2,514
3,467
3,538
205
1,374
111 | 11,098
External and internal floating-roof tanks
FIXED
ROOF
TANKS
P A D
DISTRICT
1
2
3
4
5
TOTAL
I
Refinery
2,736
7,370
10,563
480
3,731
25,430
N D U S T
Terminal
4,940
4,079
1,509
155
3,732
14,415
R Y S E
Tank Farm
1,009
259
372
2
236
1,973
. C T 0 R
Pipe! ine
85
1,322
2,887
266
9^0
6,000
Other
129
642
113
10
337
1,226
TOTAL
3,399
14,572
15,449
913
9,126
49 059
0-2
-------
Table D-1. 1976 JANUARY HC EMISSION ESTIMATES (Concluded)
(units: 1000 kg/month)
FLOATING
ROOF
T A N K Sc
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
10
23
93
2
37
165
2
59
92
90
12
90
343
3
1,097
2,002
1,071
145
429
4,744
4
1,172
1,199
1,965
45
645
5,026
5
176
152
319
0
173
820
TOTAL
2,514
3,468
3,538
204
1,374
11,098
External and internal floating-roof tanks
FIXED
ROOF
TANKS
VOLATILITY
CLASS
PAD
DISTRICT
1
2
3
4
5
1
401
337
1,709
44
294
2
1,200
1 ,106
839
117
3,549
3
5,918
10,044
7,561
679
3,607
4
1 ,192
3,052
5,043
73
922
5
188
133
297
0
654
TOTAL
1
t
!
3,399
14,672
15,449
913
9,126
T 0
T A
Li
i
2
,785
6
,911
27,809
10
,282
1 ,272
I 4Q ">5Q
1 ,,. i..
D-3
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Table 0-2. 1976 JULY HC EMISSION ESTIMATES
(units: 1000 kg/month)
FLOATING
ROOF
A N K S
P A 0
DISTRICT
1
2
3
4
5
TOTAL
INDUSTRY SECTOR
Refinery
662
1,335
1,916
175
1,059
5,H7
Terminal
1,795
1,691
817
73
525
4,901
Tank Farm
203
74
228
11
94
510
Pipeline
344
897
532
62
115
1,950
Other
14
126
20
0
3
163
i
TOTAL-
I
3,018
4,123
3,513
321
1,796
12,771
External and internal floating-roof tanks
I X E 0
ROOF
TANKS
3 A D
DISTRICT
1
2
3
4
INDUSTRY SECTOR j
Refinery
Terminal
4,929 7,786
15,736
11,349
859
5,885
1,307
177
| T 0 T A L
Tank Farm Pipeline; Other |
2,089
395
467
3
98
3,491
3,171
400
197 j ;5,Q99
1,413 1 25,970
226 | 17,020
24 1 ,463
5 4,406 ! 4,387 142 1,076 i 4Q6 10,717
TOTAL 37,329 20,042 j 3,396 3,236 2,266 1 71,259
0-4
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Table D-2. 1976 JULY HC EMISSION ESTIMATES (Concluded)
(units: 1000 kg/month)
FLOATING
ROOF
T A N K S*
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
10
20
88
2
39
159
2
70
115
37
12
121
405
3
1,644
2,827
1,076
257
577
6,381
4
1,152
1,043
1,953
50
904
5,102
5
142
118
309
0
155
724
j
TOTAL
3,018
4,123
3,513
321
1,796
12,771
External and internal floating-roof tanks
FIXED
ROOF
TANKS
PAD
DISTRICT
1
2
3
4
5
TOTAL
VOLATILITY CLASS
1
402
358
1,761
43
267
2,831
2
2,347
2,332
883
132
4,079
9,773
3
10,942
19,778
8,519
1,221
4,495
44,955
4
1,214
4,371
5,530
67
^ T 0 T A L !
5
194
131
327
0
1,137 739
12,319 1 ,391
I
15,099
26,970
17,020
1 ,463
10,717
71,259
0-5
-------
-------
TECHNICAL REPORT DATA
I Please read Inanicnom an the reverse before completing*
NO.
EPA-450/3-78-012
2.
3. HECIP'SNTS ACCSSSICN-NO.
4. TITL£ AND SUBTITLE
Evaluation of Hydrocarbon Emissions From Petroleum
Liquid Storage
5. REPORT DATE
March. 1978
6. PERFORMING ORGANIZATION CODE
7 AUTHORIS)
8. PERFORMING ORGANIZATION R£aORT NO
P.R. Peterson, P.S. Bakshi, A. Kokin, L. Norton
9 PERFORMING ORGANIZATION NAME AND ADDRESS
Pacific Environmental Services, Inc.
1930 14th Street
Santa Monica, CA 90404
10. PROGRAM CLEMENT NO.
11. CONTRACT/GRANT NO.
68-02-2606
Work Assignment
12. SPONSORING AGENCY NAME AND ADDRESS
U.S. Environmental Protection Agency
Research Triangle Park
North Carolina, 27711
13. TYPE OF REPORT AND PERIOD COVERED
14. SPONSORING AGENCY CODE
IS. SUPPLEMENTARY NOTES
OAOPS-RTP project officer for this report is
919/541-5371
Richard K. Burr, Mail Drop 13,
16. ABSTRACT
This study provides an estimate of 1976 nationwide hydrocarbon emissions
from storage of petroleum liquids in existing tanks with a capacity greater
than 150,000 liters. Numbers and types of existing tanks were determined to
estimate these emissions by geographical location, industry sector, and
volatility class of the stored products. Projections of emissions are made
for 1980 and 1985 assuming only newly constructed tanks meet the requirements
of the New Source Performance Standard (NSPS) for the storage of petroleum
liquids and then assuming existing fixed roof tanks storing products with
a volatility greater than 10.5 kPa are retrofitted with internal floating
covers. Other options such as the use of vapor recovery systems for fixed
roof tanks and double seals on external floating roof tanks were considered
beyond the scope of the study. A nationwide estimate of
petroleum liauid type stored is presented.
1976 emissions by
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.IDENTIFIERS/OPEN ENDED TERMS
c. COSATi Field/Group
Storage Tanks
NSPS for the Storage of Petroleum Liquids
Hydrocarbon Emissions
Storage of Petroleum Liquids
Fixed Roof Tank
External Floating Roof
Tanks
Internal Floating Roof
Tanks
13 315TRI8UT'QN STATSM6N1
Unlimi ted
19. SECURITY CLASS . This Report)
Unclassified
I 21 NO OP
20. SECURITY CLASS iTHis page:
Unclassified
122. PRICE
£PA Form 2220-) (9-V3)
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