AP4221
SUPPLEMENT NO. 1
FOR
COMPILATION
OF AIR POLLUTANT
EMISSION FACTORS
SECOND EDITION
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Air and Water Programs
Office of Air Quality Planning and Standards
Research Triangle Park, North Carolina
July 1973
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INSTRUCTIONS
FOR INSERTING SUPPLEMENT NO. 1
INTO
COMPILATION OF AIR POLLUTANT EMISSION FACTORS
i
1. Replace undated page iii-iv with page iii-iv dated 7/73.
2. Replace undated page v-vi with page v-vi dated 7/73.
3. Replace undated page xiii-xiv with page xiii-xiv dated 7/73.
4. Replace undated page xv-xvi with page xv-xvi dated 7/73.
5. Replace page 4.3-1-4.3-2 dated 2/72 with pages 4.3-1 through 4.3-10 dated 7/73.
6. Replace page 4.4-1-4.4-2 dated 2/72 with pages 4.4-1 through 4.4-8.
7/73
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vX
V!)
PREFACE
This document reports data available on those atmospheric emissions for which sufficient information exists to
establish realistic emission factors. The information contained herein is based on Public Health Service
Publication 999-AP-42, Compilation of Air Pollutant Emission factors, by R. L. Duprey, and on a revised and
expanded version of Compilation of Air Pollutant Emission Factors that was published by the Environmental
Protection Agency in February 1972. The scope of this second edition has been broadened to reflect expanding
knowledge of emissions.
Chapters and sections of this document have been arranged in a format that permits easy and convenient
replacement of material as information reflecting more accurate and refined emission factors is published and
distributed. To speed dissemination of emission information, chapters or sections that contain new data will be
issued — separate from the parent report — whenever they are revised.
To facilitate the addition of future materials, the punched, loose-leaf format was selected. This approach
permits the document to be placed in a three-ring binder or to be secured by rings, rivets, or other fasteners;
future supplements or revisions can then be easily inserted. The lower left- or right-hand corner of each page of
the document bears a notation that indicates the date the information was issued.
Future supplements or revisions will be distributed in the same manner as this parent document. If your copy
was obtained by purchase or through special order, you may obtain the updated chapters or sections as they are
issued by completing and mailing the form below.
Comments and suggestions regarding this document should be directed to the attention of Director,
Monitoring and Data Analysis Division, Office of Air Quality Planning and Standards, Environmental Protection
Agency, Research Triangle Park, N.C. 27711.
Mailing Address
Air Pollution Technical Information Center
Environmental Protection Agency
Research Triangle Park, N.C. 27711
I would like to receive future supplements or revisions to AP-42 as they are issued. I do not receive EPA
documents through the regular mailing lists.
Name
Address
7/73 iii
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ACKNOWLEDGMENTS
Because this document is a product of the efforts of many individuals, it is impossible to acknowledge each
individual who has contributed. Special recognition is given, however, to Mr. Richard Gerstle and the staff of
Resources Research, Inc., who provided a large part of the efforts that went into this document. Their complete
effort is documented in their report for contract number CPA-22-69-119.
Environmental Protection Agency employees M. J. McGraw, A. J. Hoffman, J. H. Southerland, and R. L.
Duprey are also acknowledged for their efforts in the production of this work. Bylines identify the contributions
of individual authors who revised specific sections and chapters.
Issuance Release Date
Compilation of Emission Factors, Second Edition 4/73
Supplement No. 1 7/73
Section 4.3, Storage of Petroleum Products
Section 4.4, Marketing and Transportation of Petroleum Products
7/73 iv
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CONTENTS
Page
LIST OF FIGURES xiii
LIST OF TABLES ... % xiv
ABSTRACT xvii
INTRODUCTION 1
1. EXTERNAL COMBUSTION SOURCES 1.1-1
1.1 BITUMINOUS COAL COMBUSTION 1.1-1
1.1.1 General • 1.1-1
1.1.2 Emissions and Controls 1.1-1
1.1.2.1 Particulates 1.1-1
1.1.2.2 SulfurOxides 1.1-2
1.1.2.3 Nitrogen Oxides 1.1-2
1.1.2.4 Other Gases 1.1-2
References for Section 1.1 1.1-4
1.2 ANTHRACITE COAL COMBUSTION 1.2-1
1.2.1 General 1.2-1
1.2.2 Emissions and Controls 1.2-1
References for Section 1.2 1.2-3
1.3 FUEL OIL COMBUSTION 1.3-1
1.3.1 General 1.3-1
1.3.2 Emissions 1.3-1
References for Section 1.3 1.3-3
1.4 NATURAL GAS COMBUSTION 1.4-1
1.4.1 General 1.4-1
1.4.2 Emissions and Controls 1-4-1
References for Section 1.4 1.4-3
1.5 LIQUEFIED PETROLEUM GAS CONSUMPTION 1.5-1
1.5.1 General 1.5-1
1.5.2 Emissions 1.5-1
References for Section 1.5 1-5-1
1.6 WOOD WASTE COMBUSTION IN BOILERS 1.6-1
1.6.1 General 1.6-1
1.6.2 Firing Practices 1.6-1
1.6.3 Emissions 1.6-1
References for Section 1.6 1.6-2
2. SOLID WASTE DISPOSAL 2.1-1
2.1 REFUSE INCINERATION 2.1-2
2.1.1 Process Description 2.1-2
2.1.2 Definitions of Incinerator Categories 2.1-2
2.1.3 Emissions and Controls 2.1-5
References for Section 2.1 2.1-6
2.2 AUTOMOBILE BODY INCINERATION 2.2-1
2.2.1 Process Description 2.2-1
2.2.2 Emissions and Controls 2.2-1
References for Section 2.2 2.2-2
7/73 v
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CONTENTS-(Continued)
Page
2.3 CONICAL BURNERS 2.3-1
2.3.1 Process Description 2.3-1
2.3.2 Emissions and Controls 2.3-1
References for Section 2.3 2.3-3
2.4 OPEN BURNING 2.4-1
2.4.1 General 2.4-1
2.4.2 Emissions 2.4-1
References for Section 2.4 2.4-2
3. INTERNAL COMBUSTION ENGINE SOURCES 3.1.1-1
DEFINITIONS USED IN CHAPTER 3 3.1.1-1
3.1 HIGHWAY VEHICLES 3.1.1-3
3.1.1 Average Emission Factors for Highway Vehicles 3.1.1-5
3.1.2 Light-Duty, Gasoline-Powered Vehicles 3.1.2-1
3.1.3 Light-Duty, Diesel-Powered Vehicles 3.1.3-1
3.1.4 Heavy-Duty, Gasoline-Powered Vehicles 3.1.4-1
3.1.5 Heavy-Duty, Diesel-Powered Vehicles 3.1.5-1
3.1.6 Gaseous-Fueled Vehicles 3.1.6-1
3.1.7 Motorcycles 317-1
3.2 OFF-HIGHWAY, MOBILE SOURCES 3.2.1-1
3.2.1 Aircraft 3.2.1-1
3.2.2 Locomotives 3.2.2-1
3.2.3 Inboard-Powered Vessels 3.2.3-1
3.2.4 Outboard-Powered Vessels 3.2.4-1
3.2.5 Small, General Utility Engines 3.2.5-1
3.3 OFF-HIGHWAY, STATIONARY SOURCES 3.3.1-1
3.3.1 Stationary Gas Turbines 3.3.1-1
3.3.2 Heavy-Duty, General Utility, Gaseous Fueled Engines 3.3.2-1
4. EVAPORATION LOSS SOURCES 4.1-1
4.1 DRY CLEANING 4.1-1
4.1.1 Genera] 4.1-1
4.1.2 Emissions and Controls 4.1-1
References for Section 4.1 4.1-2
4.2 SURFACE COATING 4.2-1
4.2.1 Process Description 4.2-1
4.2.2 Emissions and Controls 4.2-1
References for Section 4.2 4.2-2
4.3 STORAGE OF PETROLEUM PRODUCTS 4.3-1
4.3.1 Process Description 4.3-1
4.3.2 Emissions and Controls 4.3-2
References for Section 4.3 4 3-10
4.4 MARKETING AND TRANSPORTATION OF PETROLEUM PRODUCTS 4.4.1
4.4.1 Process Description 4.4-1
4.4.2 Emissions and Controls 4.4-1
References for Section 4.4 4.4-8
5. CHEMICAL PROCESS INDUSTRY 5 M
5.1 ADIPIC ACID , S.'i-l
5.1.1 Process Description 5.1-1
5.1.2 Emissions 51-1
References for Section 5.1 5 1_2
VI
7/73
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LIST OF FIGURES
Figure Page
3.1.1-1 Average Speed Correction Factors for All Model Years 3.1.1-7
3.3.2-1 Nitrogen Oxide Emissions from Stationary Internal Combustion Engines 3.3.2-2
4.3-1 Fixed Roof Storage Tank 4.3-1
4.3-2 Double-Deck Floating Roof Storage Tank (Nonmetallic Seal) 4.3-2
4.3-3 Variable Vapor Space Storage Tank (Wet-Seal Lifter Type) 4.3-3
4.3-4 Adjustment Factor for Small-Diameter Fixed Roof Tanks 4.3-5
4.4-1 Flowsheet of Petroleum Production, Refining, and Distribution Systems 4.4-3
4.4-2 Underground Storage Tank Vapor-Recovery System 4.4-5
5.9-1 Flow Diagram of Typical Nitric Acid Plant Using Pressure Process 5.9-2
5.17-1 Basic Flow Diagram of Con tact-Process Sulfuric Acid Plant Burning Elemental Sulfur 5.17-2
5.17-2 Basic Flow Diagram of Contact-Process Sulfuric Acid Plant Burning Spent Acid 5.17-3
5.17-3 Sulfuric Acid Plant Feedstock Sulfur Conversion Versus Volumetric and Mass SC>2 Emissions at
Various Inlet S02 Concentrations by Volume 5.17-6
5.18-1 Basic Flow Diagram of Modified Claus Process with Two Converter Stages Used in
Manufacturing Sulfur 5.18-2
6.9-1 Types of Orchard Heaters 6.9-2
6.9-2 Particulate Emissions from Orchard Heaters 6.9-3
7.1-1 Schematic Diagram of Primary Aluminum Production Process 7.1-3
7.5-1 Basic Flow Diagram of Iron and Steel Processes 7.5-2
8.1-1 Batch Hot-Mix Asphalt Plant 8.1-2
8.1-2 Continuous Hot-Mix Asphalt Plant 8.1-3
8.3-1 Basic Flow Diagram of Brick Manufacturing Process 8.3-2
8.6-1 Basic Flow Diagram of Portland Cement Manufacturing Process 8.6-4
8.11-1 Typical Flow Diagram of Tex tile-Type Glass Fiber Production Process 8.11-2
8.11-2 Typical Flow Diagram of Wool-Type Glass Fiber Production Process 8.11-2
9.1-1 Basic Flow Diagram of Petroleum Refinery 9.1-2
7/73
xui
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LIST OF TABLES
Table Page
1.1-1 Range of Collection Efficiencies for Common Types of Fly-Ash Control Equipment 1.1-2
1.1-2 Emission Factors for Bituminous Coal Combustion without Control Equipment 1.1.3
1.2-1 Emissions from Anthracite Coal Combustion without Control Equipment 1.2-2
1.3-1 Emission Factors for Fuel Oil Combustion 1.3-2
1.4-1 Emission Factors for Natural-Gas Combustion 1.4-2
1.5-1 Emission Factors for LPG Combustion 1.5-2
1.6-1 Emission Factors for Wood and Bark Combustion in Boilers with No Reinjection 1.6-2
2.1-1 Emission Factors for Refuse Incinerators without Controls 2.1-4
2.1-2 Collection Efficiencies for Various Types of Municipal Incineration Particulate Control Systems 2.1-5
2.2-1 Emission Factors for Auto Body Incineration 2.2-1
2.3-1 Emission Factors for Waste Incineration in Conical Burners without Controls 2.3-2
2.4-1 Emission Factors for Open Burning 2.4-1
3.1.1-1 Average Emission Factors for Highway Vehicles Based on Nationwide Statistics 3.1.1-6
3.1.2-1 Carbon Monoxide, Hydrocarbon, and Nitrogen Oxide Emission Factors for Light-Duty Vehicles
at Low and High Altitude 3.1.2-2
3.1.2-2 Carbon Monoxide, Hydrocarbon, and Nitrogen Oxide Emission Factors for Light-Duty
Vehicles, State of California Only 3.1.2-3
3.1.2-3 Light-Duty Vehicle Crankcase and Evaporative Hydrocarbon Emissions by Model Year for All
Areas Except California 3.1.24
3.1.2-4 Light-Duty Vehicle Crankcase and Evaporative Hydrocarbon Emissions by Model Year for
California 3.1.2-4
3.1.2-5 Carbon Monoxide, Exhaust Hydrocarbon, and Nitrogen Oxide Deterioration Factors for
Light-Duty, Gasoline-Powered Vehicles in All Areas Except California 3.1.2-6
3.1.2-6 Carbon Monoxide, Exhaust Hydrocarbon, and Nitrogen Oxide Deterioration Factors for
Light-Duty, Gasoline-Powered Vehicles in California 3.1.2-7
3.1.2-7 Sample Calculation of Weighted Light-Duty Vehicle Annual Travel 3.1.2-8
3.1.2-8 Particulate and Sulfur Oxide Emission Factors for Light-Duty, Gasoline-Powered Vehicles . .. 3.1.2-8
3.1.3-1 Emission Factors for Light-Duty, Diesel-Powered Vehicles 3.1.3-2
3.1.4-1 Heavy-Duty, Gasoline-Powered Vehicle Exhaust Emission Factors for Carbon Monoxide,
Hydrocarbons, and Nitrogen Oxides 3.1.4-3
3.1.4-2 Exhaust Emission Deterioration Factors for Heavy-Duty, Gasoline-Powered Vehicles (California
Only), 1975 and Later Models 3.1.4-4
3.1.4-3 Sample Calculation of Weighted Heavy-Duty Vehicle Annual Travel 3.1.4-5
3.1.4-4 Sulfur Oxide and Particulate Emission Factors for Heavy-Duty, Gasoline-Powered Vehicles . . . 3.1.4-5
3.1.5-1 Emission Factors for Heavy-Duty, Diesel-Powered Vehicles 3.1.5-2
3.1.6-1 Emission Factors by Model Year for Light-Duty Vehicles Using LPG, LPG/Dual Fuel, or
CNG/Dual Fuel 3.1.6-2
3.1.6-2 Emission Factors for Heavy-Duty Vehicles Using LPG or CNG/Dual Fuel 3.1.6-2
3.1.7-1 Emission Factors for Motorcycles 3.1.7-2
3.2.1-1 Aircraft Classification 3.2.1-2
3.2.1-2 Typical Time in Mode for Landing-Takeoff Cycle 3.2.1-3
3.2.1-3 Emission Factors per Aircraft Landing-Takeoff Cycle 3.2.1-4
3.2.1-4 Modal Emission Factors 3.2.1-6
3.2.2-1 Average Locomotive Emission Factors Based on Nationwide Statistics 3.2.2-1
3.2.2-2 Emission Factors by Locomotive Engine Category 3.2.2-2
7/73 xiv
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LIST OF TABLES-(Continued)
Table Page
3.2.3-1 Fuel Consumption Rates for Steamships and Motor Ships 3.2.3-1
3.2.3-2 Emission Factors for Inboard Vessels 3.2.3-2
3.2.4-1 Average Emission Factors for Outboard Motors 3.2.4-1
3.2.5-1 Emission Factors for Small, General-Utility Engines 3.2.5-1
3.3.1-1 Emission Factors for Gas Turbines Using Distillate Fuel Oil 3.3.1-1
3.3.1-2 Emission Factors for Gas Turbines Using Natural Gas 3.3.1-2
3.3.2-1 Emission Factors for Heavy-Duty, General-Utility, Stationary Engines Using Gaseous Fuels . . . 3.3.2-!
4.1-1 Hydrocarbon Emission Factors for Dry-Cleaning Operations 4.1-2
4.2-1 Gaseous Hydrocarbon Emission Factors for Surface-Coating Applications 4.2-1
4.3-1 Paint Factors for Fixed Roof Tanks 4.3-4
4.3-2 Evaporative Emission Factors for Storage Tanks 4.3-8
4.4-1 Organic Compound Evaporative Emission Factors' for Petroleum Transportation and Marketing
Sources 4.4-6
5.1-1 Emission Factors for an Adipic Acid Plant without Control Equipment 5.1-1
5.2-1 Emission Factors for Ammonia Manufacturing without Control Equipment 5.2-2
5.3-1 Emission Factors for Carbon Black Manufacturing 5.3-2
5.4-1 Emission Factors for Charcoal Manufacturing 5.4-1
5.5-1 Emission Factors for Chlor-Alkali Plants 5.5-2
5.6-1 Emission Factors for Explosives Manufacturing without Control Equipment 5.6-2
5.7-1 Emission Factors for Hydrochloric Acid Manufacturing 5.7-1
5.8-1 Emission Factors for Hydrofluoric Acid Manufacturing 5.8-1
5.9-1 Nitrogen Oxide Emissions from Nitric Acid Plants ' 5.9-3
5.10-1 Emission Factors for Paint and Varnish Manufacturing without Control Equipment 5.10-2
5.11-1 Emission Factors for Phosphoric Acid Production 5.11-2
5.12-1 Emission Factors for Phthalic Anhydride Plants 5.12-1
5.13-1 Emission Factors for Plastics Manufacturing without Controls 5.13-1
5.14-1 Emission Factors for Printing Ink Manufacturing 5.14-2
5.15-1 Particulate Emission Factors for Spray-Drying Detergents 5.15-1
5.16-1 Emission Factors for Soda-Ash Plants without Control 5.16-1
5.17-1 Emission Factors for Sulfuric Acid Plants 5.17-5
5.17-2 Acid Mist Emission Factors for Sulfuric Acid Plants without Controls 5.17-7
5.17-3 Collection Efficiency and Emissions Comparison of Typical Electrostatic Precipitator and Fiber
Mist Eliminator 5.17-8
5.18-1 Emission Factors for Modified Claus Sulfur Plants 5.18-2
5.19-1 Emission Factors for Synthetic Fibers Manufacturing 5.19-1
5.20-1 Emission Factors for Synthetic Rubber Plants: Butadiene-Acrylonitrile and Butadiene-Styrene . 5.20-1
5.21-1 Nitrogen Oxides Emission Factors for Terephthalic Acid Plants 5.21-1
6.1-1 Particulate Emission Factors for Alfalfa Dehydration 6.1-1
6.2-1 Emission Factors for Coffee Roasting Processes without Controls 6.2-1
6.3-1 Emission Factors for Cotton Ginning Operations without Controls 6.3-1
6.4-1 Particulate Emission Factors for Grain Handling and Processing 6.4-2
6.5-1 Emission Factors for Fermentation Processes 6.5-2
6.6-1 Emission Factors for Fish Meal Processing 6.6-1
6.7-1 Emission Factors for Meat Smoking 6.7-1
6.8-1 Emission Factors for Nitrate Fertilizer Manufacturing without Controls 6.8-2
6.9-1 Emission Factors for Orchard Heaters 6.9-4
6.10-1 Emission Factors for Production of Phosphate Fertilizers 6.10-1
6.11-1 Emission Factors for Starch Manufacturing 6.11-1
6.12-1 Emission Factors for Sugar Cane Processing 6.12-1
7.1-1 Raw Material and Energy Requirements for Aluminum Production 7.1-2
7.1-2 Representative Particle Size Distributions of Uncontrolled Effluents from Prebake and
Horizontal-Stud Soderberg Cells • 7.1-4
xv
7/73
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LIST OF TABLES-(Continued)
Table Page
7.1-3 Emission Factors for Primary Aluminum Production Processes 7.1-5
7.2-1 Emission Factors for Metallurgical Coke Manufacture without Controls 7.2.2
7.3-1 Emission Factors for Primary Copper Smelters without Controls 7.3-2
7.4-1 Emission Factors for Ferroalloy Production in Electric Smelting Furnaces 7.4-2
7.5-1 Emission Factors for Iron and Steel Mills 7.5-4
7.6-1 Emission Factors for Primary Lead Smelters 7.6-1
7.7-1 Emission Factors for Primary Zinc Smelting without Controls 7.7-1
7.8-1 Particulate Emission Factors for Secondary Aluminum Operations 7.8-1
7.9-1 Particulate Emission Factors for Brass and Bronze Melting Furnaces without Controls 7.9-2
7.10-1 Emission Factors for Gray Iron Foundries 7.10-1
7.11-1 Emission Factors for Secondary Lead Smelters 7.11-2
7.12-1 Emission Factors for Magnesium Smelting 7.12-1
7.13-1 Emission Factors for Steel Foundries 7.13-2
7.14-1 Particulate Emission Factors for Secondary Zinc Smelting 7.14-2
8.1-1 Particulate Emission Factors for Asphaltic Concrete Plants 8.1-4
8.2-1 Emission Factors for Asphalt Roofing Manufacturing without Controls 8.2-1
8.3-1 Emission Factors for Brick Manufacturing without Controls 8.3-3
8.4-1 Emission Factors for Calcium Carbide Plants 8.4-1
8.5-1 Particulate Emission Factors for Castable Refractories Manufacturing 8.5-1
8.6-1 Emission Factors for Cement Manufacturing without Controls 8.6-3
8.6-2 Size Distribution of Dust Emitted from Kiln Operations without Controls 8.6-4
8.7-1 Particulate Emission Factors for Ceramic Clay Manufacturing 8.7-1
8.8-1 Particulate Emission Factors for Sintering Operations 8.8-2
8.9-1 Particulate Emission Factors for Thermal Coal Dryers . 8.9-1
8.10-1 Particulate Emission Factors for Concrete Batching 8.10-1
8.11-1 Emission Factors for Fiber Glass Manufacturing without Controls 8.11-3
8.12-1 Emission Faclors for Frit Smelters without Controls 8.12-2
8.13-1 Emission Faclors for Glass Melting 8.13-1
8.14-1 Particulate Emission Factors for Gypsum Processing 8.14-1
8.15-1 Particulate Emission Factors for Lime Manufacturing without Controls 8.15-1
8.16-1 Emission Factors for Mineral Wool Processing without Controls 8.16-2
8.17-1 Particulate Emission Factors for Perlite Expansion Furnaces without Controls 8.17-1
8.18-1 Particulate Emission Factors for Phosphate Rock Processing without Controls 8.18-1
8.20-1 Particulate Emission Factors for Rock-Handling Processes 8.20-1
9.1-1 Emission Factors for Petroleum Refineries 9.1-3
10.1-1 Emission Factors for Sulfate Pulping 10.1-3
10.2-1 Particulate Emission Factors for Pulpboard Manufacturing 10.2-2
A-l Nationwide Emissions for 1970 A-2
A-2 Distribution by Particle Size of Average Collection Efficiencies for Various Particulate Control
Equipment A-3
A-3 Thermal Equivalents for Various Fuels A-4
A-4 Weights of Selected Substances A-4
A-5 General Conversion Factors A-5
7/73 xvi
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4.3 STORAGE OF PETROLEUM PRODUCTS
Revised by William M. Vatavuk
and Richard K. Burr
Fundamentally, the petroleum industry consists of three operations (1) crude oil production, (2) petroleum
refining, and (3) transportation and marketing of finished products. Associated with these operations are
evaporative emissions of various organic compounds, either in pure form or as mixtures.
From an air pollution standpoint, the petroleum industry is defined in terms of two kinds of evaporative
losses: (1) storage and (2) marketing and transportation. (See Figure 4.4-1 for schematic of the industry and its
points of emission.)
4.3.1 Process Description1-5
Petroleum storage evaporation losses are associated with the containment of liquid organics in large vessels at
oil fields, refineries, and product distribution terminals.
Six basic tank designs, are used for petroleum storage vessels: (1) fixed-roof (cone roof), (2) floating roof
(single deck pontoon and double deck), (3) covered floating roof, (4) internal floating cover, (5) variable vapor
space, and (6) pressure (low and high).
The fixed roof tank (Figure 4.3-1) is the least expensive vessel for storing eentain hydrocarbons and other
organics. This tank generally consists of a steel, cylindrical container with a conical roof and is equipped with a
pressure/vacuum vent, designed to operate at slight deviations (0.021 Mg/m2 maximum) from atmospheric
pressure.
• PRESSURE-VACUUM
VENT
GAUGE HATCH.
MANHOLE
7/73
Figure 4.3-1. Fixed roof storage tank.
Evaporation Loss Sources
4.3-1
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A floating roof taink is a welded or riveted circular vessel with an external float-type pan or pontoon roof
(single- or double-deck) equipped with single or double mechanical seals (Figure 4.3-2).
WEATHER SHIELD
HATCHES
LIQUID LEVEL
DRAIN
VENT
ROOF SEAL
(NONWETALLIC
OR
METALLIC)
HINGED CENTER SUPPORT
Figure 4.3-2. Double-deck floating roof storage tank (nonmetallic seal).
The floating roof prevents the formation of a volume of organic vapor above the liquid surface, which would
otherwise be vented or displaced during filling and emptying. The seal, which is designed to close the annular
space between the roof and vessel wall, consists of a relatively thin-gauge shoe ring supported against the tank
shell around the roof.
The covered floating roof tank, simply a steel pan-type floating roof inside a fixed roof tank, is designed to
reduce product losses and maintenance costs. Another type, the internal floating cover tank, contains a floating
cover constructed of a material other than steel. Materials used include aluminum sheeting, glass-fiber-reinforced
polyester sheeting, and rigid plastic foam panels.
The lifter and flexible diaphragm variable vapor space tanks are also used to reduce vapor losses (Figure 4.3-3).
With the lifter tank, the roof is telescopic; i.e., it can move up or down as the vapor above the liquid surface
expands or contracts. Flexible diaphragm tanks serve the same function through the expansion and contraction of
a diaphragm.
Pressure tanks are especially designed for the storage of volatile orgamcs under low (17 to 30psia or 12 to 21
Mg/m2) or high (up to 265 psia or 186 Mg/m2) pressure and are constructed in many sizes and shapes, depending
on the operating range. The most popular are the noded hemi-spheroid and the noded spheroid for low pressure
and the spheroid for high pressure. Horizontal cylindrical forms are also commonly used for high pressure storage.
4.3.2 Emissions and Controls1'3 >57
There are six sources of emissions from petroleum in storage.
4.3-2 EMISSION FACTORS
7/73
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ROOF CENTER SUPPORT
FLEXIBLE DIAPHRAGM ROOF
GAUGE HATCH
ROOF SEAL
(LIQUID IN TROUGH)
Figure 4.3-3. Variable vapor storage tank (wet-seal lifter type).
Breathing losses are associated with fixed roof tanks and consist of vapor expelled from the tank because of
thermal expansion, barometric pressure changes, and added vaporization of the liquid.
Working losses consist of hydrocarbon vapor expelled from the vessel as a resun of emptying or filling
operations. Filling losses represent the amount of vapor (approximately equal to the volume of liquid input) that
is vented to the atmosphere through displacement. After liquid is removed, emptying losses occur, because air
drawn in during the operation results in growth of the vapor space. Both filling and emptying (together called
"working") losses are associated primarily with fixed roof and variable vapor space tanks. Filling losses are also
experienced from low pressure tankage, although to a lesser degree than from fixed roof tanks.
Primarily associated with floating roof tanks, standing storage losses result from the improper fit of the seal
and shoe to the tank shell.
Wetting losses with floating roof vessels occur when a wetted tank wall is exposed to the atmosphere. These
losses are negligible.
Finally, boiling loss is the vapor expelled when the temperature of the liquid in the tank reaches its boiling
point and begins to vaporize.
The quantity of evaporation loss from storage tanks depends on several variables:
(1) True vapor pressure of the liquid stored,
(2) Diurnal temperature changes in the tank vapor space,
7/73
Evaporation Loss Sources
4.3-3
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(3) Height of the vapor space (tank outage),
(4) Tank diameter,
(5) Schedule of tank fillings and emptyings,
(6) Mechanical condition of tank, and
(7) Type of paint applied to outer surface.
The American Petroleum Institute has developed empirical formulae, based on extensive testing, that correlate
breathing, working, and standing storage losses with the above parameters for fixed roof, floating roof, and
variable vapor space vessels.
Fixed roof breathing losses can be estimated from:
B =
2.74 WK
P \ 0.68 D1.73 R0.51 AT0.50
14.7-P
(1)
where: B = Breathing loss, lb/day-103 gal capacity
P = True vapor pressure at bulk liquid temperature, psia
D = Tank diameter, feet
H = Average vapor space height, including correction for roof volume, feet
AT = Average daily ambient temperature change, °F
Fg = Paint factor, determined from field tests (see Table 4.3-1)
C = Adjustment factor for tanks smaller than 20 feet in diameter (see Figure 4.3-4)
Vc = Capacity of tank, barrels
K = Factor dependent on liquid stored:
= 0.014 for crude oil
= 0.024 for gasoline
= 0.023 for naphtha jet fuel (JP-4)
= 0.020 for kerosene
= 0.019 for distillate oil
W = Density of liquid at storage conditions, Ib/gal
Table 4.3-1. PAINT FACTORS FOR FIXED ROOF TANKS3
Tank Color
Roof
White
Aluminum (specular)
White
Aluminum (specular)
White
Aluminum (diffuse)
White
Light gray
Medium gray
Shell
White
White
Aluminum (specular)
Aluminum (specular)
Aluminum (diffuse)
Aluminum (diffuse)
Gray
Light gray
Medium gray
Paint factor (Fp)
Paint condition
Good
1.00
1.04
1.16
1.20
1.30
1.39
1.30
1.33
1.46
Poor
1.15
1.18
1.24
1.29
1.38
1.46
1.38
1.44b
1.58b
Reference 2.
bEstimated from the ratios of the seven preceeding paint factors.
4.3-4
EMISSION FACTORS
7/73
-------
1.00
g 0.60
o
5 0.40 —
te
0 10 20 30
DIAMETER, feet
Figure 4.3-4. Adjustment factor for small-diameter fixed roof tanks.2
Breathing losses of petrochemicals from fixed roof tanks can be estimated from the respective gasoline loss
factor, calculated at their storage temperature:
BP = o.os i-^-1 y-p-] BG (2)
\ V*^ \ /
where: Bp, BQ, = Breathing losses of petrochemical (p) and gasoline (G), lb/day-103 gal
Mp = Molecular weight of petrochemical (p), Ib/mole
W = Liquid density of gasoline, Ib/gal
Pp, PQ = True vapor pressures of petrochemical (p) and gasoline (G) at their bulk storage temperature,
psia
This same correlation can also be used to estimate petrochemical working loss, standing storage loss, or any other
kind of loss from any storage tank.
A correlation for fixed roof tank working loss (combined emptying and filling) has also been developed:
180+ N
= lOOOWmP
/180 + N\
\ 6N I
where: Ff = Working loss, lb/103 gal throughput
7/73 Evaporation Loss Sources
(3)
4.3-5
-------
P = True vapor pressure at bulk liquid temperature, psia
N = Number of tank turnovers per year (ratio of annual throughput to tank capacity)
m = Factor dependent on liquid stored:
= 3x 10"4 for gasoline
= 2.25x 10-4 for crude oil
= 3.24 x 10-4 for naphtha jet fuel (JP-4)
= 2.95 x 10'4 for kerosene
= 2.76x 10"4 for distillate oil
Standing storage losses from floating roof tanks can be calculated from:
2.74 WKt 1.5 / p \ 0.7
— T^ ' 'V 1C IT If (4\
v w *^-Q-^-r*-t*-n \ J
Vc V14.7-P
where: S = Standing storage evaporation loss, lb/day-103 gal capacity
Kt = Factor dependent on tank construction:
= 0.045 for welded tank, pan/pontoon roof, single/double seal
= 0.11 for riveted tank, pontoon roof, double seal
= 0.13 for riveted tank, pontoon roof, single seal
= 0.13 for riveted tank, pan roof, double seal
= 0.14 for riveted tank, pan roof, single seal
D = Tank diameter, feet; for D ^ 150 feet (45.8 m) use "EK/150" instead of "D1-5"
Vw = Average wind velocity, mi/hr
Ks = Seal factor:
= 1.00 for tight-fitting, modern seals
= 1.33 for loose-fitting, older seals (typical of pre-1942 installation)
Kc = Factor dependent on liquid stored:
= 1.00 for gasoline
= 0.75 for crude oil
= 0.96 for naphtha jet fuel (JP-4)
= 0.83 for kerosene
4.3-6 EMISSION FACTORS 7/73
-------
= 0.79 for distillate oil
Kp = Paint factor for color of shell and roof:
= 1.00 for light gray or aluminum
= 0.90 for white
Finally, filling losses from variable vapor space systems can be estimated by:
1000 WmP
Fv = (Vt - 0.25VeN) (5)
where: m = Factor dependent on liquid stored (same as equation 3)
Fv = Filling loss, lb/103 gal throughput
Vj = Volume of liquid throughput, bbl/year
Ve = Volume of expansion capacity, barrels
N = Number of turnovers per year
W = Density of liquid at storage conditions, Ib/gal
Equations 1 through 5 can be used to calculate evaporative losses, provided the respective parameters are
known. For those cases where such quantities are unknown or for quick loss estimates, however, Table 4.3-2
provides typical emission factors. Refinement of emission estimates by using these loss correlations may be
desirable in areas where these sources contribute a substantial portion of the total evaporative emissions or are of
major consequence in affecting the air quality.
The control methods most commonly used with fixed roof tanks are vapor recovery systems, which collect
emissions from storage vessels and send them to gas recovery plants. The four recovery methods used are liquid
absorption, vapor compression, vapor condensation, and adsorption in activated charcoal or silica gel.
Overall control efficiencies of vapor recovery systems vary from 90 to 95 percent, depending on the method
used, the design of the unit, the organic compounds recovered, and the mechanical condition of the system.
In addition, water sprays, mechanical cooling, underground liquid storage, and optimum scheduling of tank
turnovers are among the techniques used to minimize evaporative losses by reducing tank heat input.
7/73 Evaporation Loss Sources 4.3-7
-------
Table 4.3-2. EVAPORATIVE EMISSION
EMISSION FACTOR
Product
Crude oil0
Gasoline0
Naphtha jet fuel
(JP-4)C
Kerosene0
Distillate fuelc
Acetone
Ammonium hydroxide
(28.8 % solution)
Benzene0
Isobutyl alcohol
Tertbutyl alcohol
Carbon tetrachloride
Cyclohexanec
Cyclopentanec
Ethyl acetate
Ethyl alcohol
Freon II
nHeptanec
nHexanec
Hydrogen cyanide
1 so octane0
lsopentanec
Isopropyl alcohol
Methyl alcohol
nPentanec
Toluene0
Vapor
pressure
ratio
0.543
1.53
0.2108
0.0263
0.0843
0.264
0.230
0.776
0.210
0.120
2.01
0.103
0.353
1.42
0.112
1.86
0.0933
0.272
1.26
0.0594
Mole
wt(M)
(Ib/mole)
64.5
56.8
63.3
72.7
72.7
58.1
35.1
78.1
74.1
74.1
153.8
84.2
70.1
88.1
46.1
137.4
100.2
86.2
27.0
114.2
72.2
60.1
32.0
72.2
92.1
Floating roof
Standing storage loss
"New tank" conditions
Ib/day-
103 gal
0.029
0.033
0.012
0.0052
0.0052
0.014
0.023
0.0074
0.00086
0.0029
0.018
0.0083
0.024
0.0081
0.0024
0.12
0.0045
0.013
0.017
0.0055
0.057
0.0024
0.0038
0.038
0.0024
kg/day-
103 liter
0.0034
0.0040
0.0014
0.00063
0.00063
0.0017
0.0028
0.00089
0.00010
0.00034
0.0021
0.0010
0.0028
0.00097
0.00029
0.014
0.00054
0.0016
0.0020
0.00066
0.0069
0.00029
0.00046
0.0046
0.00029
"Old tank" conditions
Ib/day-
103 gal
0.071
0.088
0.029
0.012
0.012
0.036
0.062
0.020
0.0023
0.0074
0.048
0.022
0.062
0.021
0.0064
0.32
0.012
0.036
0.043
0.015
0.15
0.0064
0.010
0.10
0.0062
kg/day-
103 liter
0.0086
0.011
0.0034
0.0015
0.0015
0.0043
0.0074
0.0023
0.00028
0.00089
0.0057
0.0027
0.0074
0.0025
0.00074
0.038
0.0014
0.0043
0.00051
0.0018
0.018
0.00077
0.0012
0.012
0.00074
References 2, 3, 6, and 7.
"Factors based on following conditions:
Storage temperature: 63°F(17.2 °C).
Daily ambient temperature change: 15°F (-9.5°C).
Wind velocity: 10 mi/hr (4.5 m/sec).
Crude oil
Gasoline
Naphtha jet
fuel (JP-4)
Kerosene
Distillate
oil
Reid vapor
pressure
psia
7.0
10.5
2.5
«0.5
«0.5
Mg/m2
4.9
7.4
1.75
<0.35
«0.35
True vapor
pressure
psia
4.6
5.8
1.2
<0.5
<0.5
Mg/m2
3.2
4.1
0.84
<0.35
«0.35
clndicates petroleum products whose evaporative emissions
only the elements hydrogen and carbon).
Typical fixed- and floating-roof tanks
Diameter: 90 ft (27.4 m) for crude, JP-4, kerosene, and
distillate; 110 ft (33.6 m) for gasoline and all
petrochemicals.
Height: 44 ft (13.4 m) for crude, JP-4, kerosene, and
distillate; 48 ft (14.6 m) for gasoline and all
petrochemicals.
Capacity. 50,000 bbl (7.95 x 10s liter) for crude, JP-4,
kerosene, and distillate; 67,000 bbl (10.65 x 10s
liter) for gasoline and all petrochemicals.
Outage: 50 percent of tank height.
Turnovers per year: 30 for crude oil; 13 for all others.
are exclusively hydrocarbons (i.e., compounds containing
4.3-8
EMISSION FACTORS
7/73
-------
FACTORS FOR STORAGE TANKS3- b
RATING: A
Fixed roof
Breathing loss
'New tank" conditions
Ib/day-
103 gal
0.15
0.22
0,069
0.036
0.036
0.093
0.16
0.050
0.0057
0.018
0.12
0.057
0.16
0.055
0.016
0.81
0.031
0.088
0.11
0.038
0.39
0.016
0.026
0.26
0.016
kg/day-
103 liter
0.018
0.026
0.0033
0.0043
0.0043
0.011
0.018
0.0057
0.00067
0.0021
0.014
0.0067
0.019
0.0062
0.0019
0.098
0.0036
0.010
0.013
0.0043
0.047
0.0019
0.0031
0.032
0.0019
"Old tank" conditions
Ib/day-
103 gal
0.17
0.25
0.079
0.041
0.041
0.10
0.18
0.057
0.0064
0.021
0.14
0.064
0.18
0.062
0.018
0.92
0.033
0.10
0.13
0.043
0.45
0.019
0.029
0.30
0.018
kg/day-
103 liter
0.020
0.031
0.0095
0.0048
0.0048
0.013
0.021
0.0069
0.0079
0.0026
0.016
0.0079
0.022
0.0074
0.0022
0.11
0.0040
0.012
0.015
0.0051
0.053
0.0022
0.0034
0.036
0.022
Working loss
lb/103 gal
throughput
7.3
9.0
2.4
1.0
1.0
3.7
6.3
2.0
0.23
0.74
4.8
2.3
6.4
2.2
0.65
32.4
1.2
3.6
4.5
1.5
15.7
0.66
1.0
10.6
0.64
kg/103 liter
throughput
0.88
1.1
0.29
0.12
0.12
0.45
0.76
0.24
0.028
0.90
0.58
0.28
0.77
0.27
0.079
3.9
0.15
0.43
0.54
0.18
1.9
0.080
0.13
1.3
0.077
Variable vapor
space
Working loss
lb/103 gal
throughput
Not used
10.2
2.3
1.0
1.0
4.2
7.1
2.3
0.26
0.83
5.4
2.6
7.2
2.5
0.73
36.7
1.4
4.0
5.1
1.7
17.8
0.74
1.2
12.0
0.73
kg/103 liter
throughput
Not used
1.2
0.28
0.12
0.12
0.51
0.86
0.27
0.031
0.099
0.63
0.31
0.87
0.30
0.089
4.4
0.16
0.49
0.61
0.21
2.1
0.090
0.14
1.4
0.087
Typical floating-roof tank
Paint factor (Kp): New tank-white paint, 0.90; Old
tank-white/aluminum paint, 0.95.
Seal factor (Ks): New tank-modern seals, 1.00; Old
tank-50 percent old seals, 1.14.
Tank factor (Kt): New tank-welded, 0.045; Old tank-
50 percent riveted, 0.088.
Typical fixed-roof tank
Paint factor (Fp)- New tank-white paint, 1.00; Old
tank-white/aluminum paint, 1.14.
Typical variable vapor space tank
Diameter: 50ft (15.3 m).
Height: 30ft (9.2m).
Capacity: 10,500 bbl (1.67 x 106 liter).
Turnovers per year' 6.
7/73
Evaporation Loss Sources
4.3-9
-------
REFERENCES FOR SECTION 4.3
1. Control of Atmospheric Emissions from Petroleum Storage Tanks. Petroleum Committee, Air Pollution
Control Association. J. Air Pol. Control Assoc. 27(5):260-268, May 1971.
2. Evaporation Loss from Fixed Roof Tanks. American Petroleum Institute, New York, N.Y. API Bulletin
Number 2518. June 1962.
3. Evaporation Loss from Floating Roof Tanks. American Petroleum Institute, New York, N.Y. API Bulletin
Number 2517. February 1962.
4. Evaporation Loss in the Petroleum Industry — Causes and Control. American Petroleum Institute, New York,
N.Y. API Bulletin Number 2513. February 1959.
5. Personal communication with personnel in Engineering Services Branch, Emission Standards and Engineering
Division, Office of Air Quality Planning and Standards, Environmental Protection Agency, Research Triangle
Park, N.C. November 1972.
5. Petrochemical Evaporation Loss from Storage Tanks. American Petroleum Institute, New York, N.Y. API
Bulletin Number 2523. November 1969.
7. Use of Variable Vapor Space Systems to Reduce Evaporation Loss. American Petroleum Institute, New York,
N.Y. API Bulletin Number 2520. September 1964.
4.3-10 EMISSION FACTORS 7/73
-------
4.4 MARKETING AND TRANSPORTATION OF PETROLEUM by William M. Vatavuk
PRODUCTS
4.4.1 Process Description1
As Figure 4.4-1 indicates, the marketing and transportation of petroleum products involves many distinct
operations, each of which can represent a source of evaporation loss.
For example, after gasoline is refined, it is transported first via pipeline, rail, ship, or barge to intermediate
storage and then to regional marketing terminals for temporary storage in large quantities. From here, the
product is pumped into tank trucks that deliver it directly to service stations or to larger distributors at "bulk
plants." From bulk plants, the product is delivered, again in trucks, to commercial accounts (e.g., trucking
companies). The final destination for the gasoline is normally a motor vehicle gas lank. A similar distribution path
may be developed for fuel oil and other petroleum products.
4.4.2 Emissions and Controls2"5
Losses from marketing and transportation fall into five categories, depending on the storage equipment or
mode of conveyance used:
1. Large storage tanks. Breathing, working, and standing storage losses;
2. Railroad tank cars and tank trucks: Loading and unloading losses;
3. Marine vessels: Loading, unloading, and transit losses;
4. Service stations: Loading and unloading losses from tank trucks and underground tanks; and
5. Motor vehicle tanks: Refueling losses.
(In addition, evaporative (and exhaust) emissions are also associated with motor vehicle operation. These topics
are discussed in Chapter 3.)
Losses from large storage tanks have been thoroughly discussed in section 4.3.
Unloading losses from tank cars and trucks consist of the amount of organic liquid that evaporates into the air
that is drawn in during a complete withdrawal of the contents of a tank compartment. These losses can be
estimated (within ± 10 percent) using the following expression derived from American Petroleum Institute
correlations:
69,600 YPW
(690-4M)T
where: U( = Unloading loss, lb/103 gal of liquid loaded
Y = Degree of saturation of organic in vapor space at time of unloading (estimated or measured)
T = Bulk absolute temperature of organic liquid, °R
7/73 Evaporation Loss Sources ,4.4-1
-------
P = True vapor pressure of liquid at temperature (T), psia
M = Molecular weight of liquid, Ib/lb-mole
W = Density of hydrocarbon liquid at temperature (T), lb/gal
The quantity of loading losses is directly dependent on the filling method used. "Splash" loading, which
usually results in extremely high emissions, occurs when the liquid is discharged into the upper part of a container
through a short filler spout. This free fall of the liquid encourages both evaporation and entrainment loss caused
by the formation and expulsion of liquid droplets. In "subsurface" or "submerged" loading, lower emissions are
achieved because the liquid is delivered directly to the bottom of the tank through a tightly connected pipe/spout
without splashing.
A submerged loading loss correlation (generally accurate within ± 25 percent) based on equation 1 has also
been developed:
/1.00-Y\ 69,600 PW
Lsub ^ 2 I (690-4M)T (2)
where: Lsub = Submerged loading loss, lb/103 gal of liquid loaded
Y = Saturation of the existent vapor in tank before loading.
This relationship assumes that the vapor formed during unloading (existent vapor) remains in the tank until
the next loading. Then the additional liquid that evaporates during loading becomes the loading loss. (A more
rapid method for calculating loading and unloading losses has been developed by the American Petroleum
Institute.6)
Variables affecting splash loading loss include the loading rtite, the degree of saturation of existent vapor, and
the elevation and angle of the loading spout. The following correlation was derived from the American Petroleum
Institute empirical formula:
"1
J
(1.023 x 106)W I" 14.7 - YP
LSP ~ ~(690^M)Tj_14.7 - (0.95)P *' "*
where: L = Splash loading loss, lb/103 gal
In equation (3), the vapor displaced from the tank is assumed to be 95 percent saturated—quite reasonable in
view of the high degree of saturation observed in vapors from splash-filling operations. The accuracy of this
expression is found to be ± 10 percent, 90 percent of the time.
Finally, transit (breathing) losses from tank cars and trucks during product shipment is assumed to be
negligible because the travel time is relatively short (2 days or less).
Emission correlations have also been developed for marine vessels.
For unloading losses:
Us = 0.07PW (4)
where: Us = Unloading loss, lb/103 gal of load
P = True vapor pressure of liquid at storage temperature, psia
W = Density of liquid at storage temperature, Ib/gal
4.4-2 EMISSION FACTORS 7/73
-------
en
E
03
(0
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(O
If
3 S
.a b
T3 'C
C Q)
CO >
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E w
3 W
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11
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7/73
Evaporation Loss Sources
4.4-3
-------
For loading:
Ls = 0.08PW (5)
where: Ls = Loading loss, lb/103 gal of load
Since vessel shipments are transported for longer periods, transit losses can be substantial. These losses can be
estimated by the following:
RS = 0.1PW (6)
where: Rs = Transit loss, lb/103 gal of load per week
For quick reference, selected petroleum product emission factors for transportation sources are provided in
Table 4.4-1.
A fourth major source of evaporative emissions is the loading and unloading of underground gasoline storage
tanks at service stations. As with the other categories, the quantity of the loading losses depends on several
variables such as the size and length of the fill pipe; the method of filling; the tank configuration; as well as the
gasoline temperature, vapor pressure, and composition. Depending on these parameters, and the control method
used, loading losses can vary from 0 to 11.5 lb/103 gal (1.4 kg/103 liter) of gasoline pumped into the tank (see
Table 4.4-1).
Unloading losses from underground tanks result from the inhalation of air and exhalation of a vapor-air
mixture during normal pumping operations. Variables affecting the losses are the type of service station
operation, the gasoline pumping rate and frequency, the ratio of liquid surface to vapor volume, the diffusion and
mixing of gasoline vapors and air, as well as the other parameters mentioned previously (Table 4.4-1).
The final loss category to be considered is the splash filling of motor vehicle gasoline tanks. These losses
consist of vapor displacement (94 percent of total loss) from the vehicle tank and liquid spillage (6 percent of
total) as the gasoline is pumped.
Scott Research Inc., under an EPA contract, did extensive laboratory and field testing that resulted in the
development of an empirical vapor displacement formula:s
LD = 2.22 exp (-0.02645 +0.01155TDF-0.01226Tv-l-0.00246TvPRVp) (7)
where: L£> = Vapor displacement loss, lb/103 gal
Tj3p = Average dispensed fuel temperature, °F
Ty = Average temperature of vehicle tank vapor displaced, °F
PRVP = ^eicl vaPor pressure of gasoline pumped, taken at storage temperature and composition, psia
exp = Base of natural logarithms = 2.71828
This expression provides good loss estimates (± 0.5 lb/103 gal or 0.06 kg/103 liter) within the experimental
temperature interval of 30° to 90°F (-1.1° to 32.2 °C).
The quantity of spillage loss is a function of the type of service station, vehicle tank configuration, operator
technique, and operation discomfort indices. An overall average of 0.67 lb/103 gal (0.081 kg/103 liter) has been
estimated (Table 4.4-1).
Control methods for transportation and marketing sources are similar to those utilized with large storage tanks
and generally consist of one or more types of vapor recovery systems located at transfer terminals. Depending on
the system and the compounds recovered, the overall control efficiencies range from 90 to 95 percent.
4.4-4 EMISSION FACTORS 7/73
-------
For example, a technique used with some underground gasoline storage tanks consists of an arrangement by
which vapors are. recycled to the tank trucks during filling operations through the annular space of a specially
designed "interlock valve" and into a side arm that is connected to the return manifold in the dome cap of the
truck (see Figure 4.4-2). The control efficiency of this method ranges from 93 to 100 percent when compared
with uncontrolled, splash-fill loading (see Table 4.4-1).
VAPOR VENT LINE
MANIFOLD FOR RETURNING VAPORS
TRUCK STORAGE
COMPARTMENTS
/t 11 t\tt 11111111111
11111111111111 \ ..STSf
==; SUBMERGED FILL PIPE
UNDERGROUND
TANK
Figure 4.4-2. Underground storage tank vapor-recovery system"!.
7/73
Evaporation Loss Sources
4.4-5
-------
Table 4.4-1. ORGANIC COMPOUND EVAPORATIVE EMISSION FACTORS
FOR PETROLEUM TRANSPORTATION AND MARKETING SOURCES3
EMISSION FACTOR RATING: A
Emission source
Tank cars/trucks^
Splash loading
lb/103 gal transferred
kg/103 liter transferred
Submerged loading
lb/103 gal transferred
kg/103 liter transferred
Unloading
lb/103 gal transferred
kg/103 liter transferred
Marine vessels"
Loading
lb/103 gai transferred
kg/103 liter transferred
Unloading
lb/103 gal transferred
kg/103 liter transferred
Transit
lb/wk-103 gal load
kg/wk-103 liter load
Underground gasoline
storage tanksc
Splash loading
lb/103 gal transferred
kg/103 liter transferred
Uncontrolled submerged loading
lb/103 gal transferred
kg/103 liter transferred
Submerged loading with open
vapor return system
lb/103 gal transferred
kg/103 liter transferred
Submerged loading with closed
vapor return system
lb/103 gal transferred
kg/103 liter transferred
Product
Gasoline
12.4
1.5
4.1
0.49
2.1
0.25
2.9
0.35
2.5
0.30
3.6
0.43
11.5
1.4
7.3
0.38
0.80
0.097
Neg
Meg
Crude
oil
10.6
1.3
4.0
0.48
2.0
0.24
2.6
0.31
2.3
0.28
3.2
0.38
NUd
NU
NU
NU
NU
NU
NU
NU
Naphtha jet
fuel (JP-4)
1.8
0.22
0.91
0.11
0.45
0.054
0.60
0.072
0.52
0.062
0.74
0.089
NU
NU
NU
NU
NU
NU
NU
NU
Kerosene
0.88
0.11
0.45
0.054
0.23
0.028
0.27
0.032
0.24
0.029
0.34
0.041
NU
NU
NU
NU
NU
NU
NU
NU
Distillate
oil
0.93
0.11
0.48
0.058
0.24
0.029
0.29
0.035
0.25
0.030
0.36
0.043
NU
NU
NU
NU
NU
NU
NU
NU
4.4-6
EMISSION FACTORS
7/73
-------
Table 4.4-1 (continued). ORGANIC COMPOUND EVAPORATIVE EMISSION FACTORS
FOR PETROLEUM TRANSPORTATION AND MARKETING SOURCES
EMISSION FACTOR RATING: A
Emission source
Unloading
lb/103 gal transferred
kg/103 liter transferred
Filling motor vehicle
gasoline tanks6
Vapor displacement loss
lb/103 gal pumped
kg/103 liter pumped
Liquid spillage loss
lb/103 gal pumped
kg/103 liter pumped
Product
Gasoline
1.0
0.12
11.0
1.3
0.67
0.081
Crude
oil
NU
NU
NU
NU
NU
NU
Naphtha jet
fuel (JP-4)
NU
NU
NU
NU
NU
NU
Kerosene
NU
NU
NU
NU
NU
NU
Distillate
Oil
NU
NU
NU
NU
NU
NU
References 1, 3, and 5.
Data based on the following conditions:
Storage temperature' 63 °F (17.2°C)
Saturation of tank existent vapors in loading and unloading tank
trucks and c.---s: 20 percent
Molecular weight of vapor,
Ib/lb-mole
Reid vapor pressure
psia
Mg/m2
True vapor pressure
psia
Mg/m2
Liquid density
Ib/gal
kg/liter
Gasoline
56.8
10.5
7.4
5.8
4.1
6.2
0.74
Crude
oil
64.5
7.0
4.9
4.6
3.2
7.0
0.84
Naphtha jet
fuel (JP-4)
63.3
2.5
1.75
1.2
0.84
6.2
0.74
Kerosene
72.7
0.5
0.35
0.5
0.35
6.8
0.82
Distillate
oil
72.7
0.5
0.35
0.5
0.35
7.2
0.87
cFactors for underground gasoline storage tanks based on an organic compound vapor space concentration of 40 percent
by volume, which corresponds to a saturation of nearly 100 percent.
"Not used.
eMotor vehicle gasoline tank vapor displacement factor based on an average dispensed fuel temperature of 63 °F (17.2 °C),
an average displaced vapor temperature of 67 °F (194°C), and a Reid vapor pressure of 10.5 psia (7.4 Mg/m2).
7/73
Evaporation Loss Sources
4.4-7
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REFERENCES FOR SECTION 4.4
1. Nichols, Dr. Richard A. Control of Evaporation Losses in Gasoline Marketing Operation. (Presented at the
Technical Conference on New Technology in the Solution of Practical Problems in Air and Water Pollution
Control. Tokyo, Japan. December 1971).
2. Chass, R.L. et al. Emissions from Underground Gasoline Storage Tanks. J. Air Pol. Control Assoc. 13:524-
530, November 1963.
3. Evaporation Loss from Tank Cars, Tank Trucks, and Marine Vessels. American Petroleum Institute, New York,
N.Y. API Bulletin Number 2514. November 1959.
4. Petrochemical Evaporation Loss from Storage Tanks. American Petroleum Institute, New York, N.Y. API
Bulletin Number 2523. November 1969.
5. Smith, Malcolm. Investigation of Passenger Car Refueling Losses. Scott Research Laboratories, Inc. San
Bernadino, Calif. Prepared for Mobile Source Pollution Control Program, Office of Air and Water Programs,
EPA, Ann Arbor, Mich, under Contract Number CPA 22-69-68. September 1972.
6. American Petroleum Institute, New York, N.Y. API Bulletin Number 4080. July 1971.
4.4-8 EMISSION FACTORS 7/73
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