ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
EPA 330/2-76-005
REPORT ON
State Implementation Plan
Air Pollution Inspection
of
Edgington Oil Company
LOS ANGELES COUNTY, CALIFORNIA
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER
DENVER, COLORADO
AND
REGION IX, SAN FRANCISCO, CALIFORNIA

I \
FEBRUARY 1976
Imj <
	j

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ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
STATE IMPLEMENTATION PLAN
INSPECTION OF
EDGINGTON OIL COMPANY
2400 E. Artesia Blvd.
Long Beach, California 90805
213/636-2524
October 15, 1975
February 1976
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER - Denver, Colorado
and
REGION IX - San Francisco, California

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CONTENTS
Introduction 	 1
Process Description 	 3
Potential Sources of Air
Pollution Emissions and
Related Control Equipment .... 3
Emissions Data	11
Summary of Violations 	13
Inspection Summary	15
Appendix
A	NEIC Request Letter
B	LAAPCD Rules
C	Storage Tank Listing
D	Source Tests Results

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INTRODUCTION
Background
Edgington Oil Company operates a simple petroleum refinery with a
rated capacity of 4,700 m (29,500 bbl)/day. The refinery processes 85-
90% indigenous California crudes with the remainder coming from Alaska
and Indonesia. It also finishes imported napthas from Venezuela and
reprocesses crankcase drainings. Finished products include gasoline,
jet fuels, diesel fuel, lube oil, stove oil, fuel oil and various grades
of asphalts.
Edgington employs about 155 people, and operates three 8-hour
shifts per day, 7 days per week, year around.
On October 15, 1975, a process inspection was conducted at this
facility by NEIC personnel. The inspection was preceded by a letter to
the Company on September 8, 1975 [Appendix A], announcing NEIC's in-
tention to inspect the facility and requesting substantial amounts of
process information. Subsequent to the inspection, Edgington personnel
mailed the requested information to NEIC.
During the inspection, an examination was made of the refining
equipment, potential air pollution sources, and air pollution control
equipment. The purpose of this inspection was to evaluate the degree of
compliance of this facility with the requirements of the Federally
approved State Implementation Plan as required by Section 110 of the
Clean Air Act, as amended.
Company personnel were very cooperative during this inspection.
They supplied all EPA requested information during the inspection
interview or by subsequent letter.

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2
Inspection Participants
Mr. David Davidson - President, Edgington
Mr. John W. Shrontz - Supervisor of Quality Control, Edgington
Mr. M. 0. Carrigan - Refinery Superintendent, Edgington
Mr. Robert S. Mueller - Refinery Engineer, Edgington
Mr. Charles R. Mason - Los Angeles County Air Pollution Control
District, (LAAPCD)
Mr. Paul de Percin - USEPA, NEIC
Mr. David L. Brooman - USEPA, NEIC
Applicable Regulations
The following rules contained in the Rules and Regulations of the
Los Angeles County Air Pollution Control District (LAAPCD) [detailed in
Appendix B] are applicable to this facility.
Rule 50.	Ringelmann Chart
Rule 51.	Nuisance
Rule 56.	Storage of Petroleum Products
Rule 59.	Effluent Oil/Water Separators
Rule 61.	Organic Liquid Loading
Rule 62.	Sulfur Content of Fuels
Rule 67.	Fuel Burning Equipment
Rule 68.1. Fuel Burning Equipment - Combustion Contaminants
Rule 69.	Vacuum Producing Devices or Systems
Rule 70.	Asphalt Blowing
Rule 71.	Carbon Monoxide
Rule 72.	Pumps and Compressors
Rule 73.	Safety Pressure Relief Valves

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3
PROCESS DESCRIPTION
Edgington operates a relatively small, simple refinery. All crude
oil and imported naptha are transported to the refinery by pipeline.
Crankcase drainings are delivered to the refinery by truck. Major
processes include crude desalting, atmospheric distillation, vacuum
distillation, and asphalt blowing. Simplified process flow diagrams for
the facility are shown in Figures 1 and 2. The following table sum-
marizes the various unit process capacities.
Process	Rated Capacities

(m3/d)
(bbl/day)
Crude Unit No. 1
1,600
10,000
Crude Unit No. 2
and Vacuum Unit
3,100
19,500
Crankcase Oil
Reprocessing
160
1,000
Asphalt Blowing
(6 stills)
1,300-2,200
8,000-14,000
t Unit operated approximately 50% of the time
POTENTIAL SOURCES OF AIR POLLUTION EMISSIONS AND RELATED CONTROL EQUIPMENT
The major unit processes at this refinery are closed systems.
Release of materials to the atmosphere is discouraged because such
releases would result in loss of product. The process heaters attendant
to these units and the steam boilers constitute the main emission
sources.

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Stove Oil
Diesel
Storage
v
Caustic
Vent Gas
Burned
in Heaters
and Boilers
Fuel Oil

to Storage
S-

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Vent Gases
Burned In
Heaters and Boilers
Vent Gas
Caustic
Wash
Lt. Naptha
cn
Hvy. Naptha
Stove Oil
Caustic
Wash
Vent Gas to
Vac. Jets
Heater H-201
Sour Stock
to btorage
Sour Stock

OO
CO
Heavy Vac. Gas Oil
Bottoms to
Storage
Soft Asphalt
to Storage
Hard Asphalt
Figure 2. Simplified Process Flow Diagram - Crude Unit No. 2
Edgington Oil Company - Long Beach, California

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6
There are also a large number of relatively small potential sources
of emissions related to the operation of the refinery. Such sources
include leaks from valve seals, pump seals, and pipe flanges, and
evaporative losses from storage tanks and process wastewater drains.
Potential sources of emissions and their related control equipment are
discussed below.
Process Heaters and Boilers
There are 13 process heaters and 5 steam boilers at	this refinery
ranging in size from 1.3 X 10^ kg cal (5 X 10^ Btu)/hour	to 15.2 X 10^
kg cal (60 X 10^ Btu)/hour. A complete listing of these	units is
presented in Table 1.
All of these units can be operated on either natural gas or low
sulfur fuel oil with the sole exception of Heater H-3, which is operated
on natural gas only. Natural gas is purchased from Southern California
3
Gas and has an approximate heating value of 9,340 kg cal/m (1,050
Btu/ft ) and a negligible sulfur content. Low sulfur fuel oil is also
purchased for use in these units. It has an approximate heating value
of 9,800 kg cal/1 (148,000 Btu/gal) and an average sulfur content of
0.47% by weight.
Edgington does not have a refinery fuel gas system per se. Vent
gases from the overhead accumulators on crude unit No. 1 and the receiver
on the crankcase oil processing unit are piped to, and burned in,
heaters H-l, H-2, H-3, and H-4 or in boilers No. 1, 2, 3 and 6. Like-
wise, vent gases from the overhead accumulators and vacuum jets on crude
unit No. 2 are piped to, and burned in, Heaters H-101, H-l02 and H-201
or the heaters and boilers listed for crude unit No. 1. All vent gases
are caustic scrubbed prior to burning to control sour gases. Edgington
does not monitor the quantity of vent gases burned in these units. They

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Table 1
LISTING OF BOILERS AND PROCESS HEATERS
Edgington Oil Company - Long Beachs Califormia
Stack	Stack	Height	Stack
Diameter Temperature Above Grade Rated Heat Input Gas Velocity
(m) (ft) (°C) (°F) (m) (ft) (106 kg (10^ Btu/ (m/sec)(ft/sec)
	cal/hr)	hrj	
Boiler #1 j










Boiler #2 r (2 stacks)
1.2
4.0
260
500
21
70
2.1
8.5
1.7
5.7
Boiler #3 J










Boiler §6
1.8
6.0
260
500
23
75
2.1
8.5
0.5
1.8
Boiler B-301
0.9
3.0
204
400
6
20
15.1
60.0
13.5
44.4
H-101 Heater Unit £1
1.4
4.5
371
700
30
100
6.0
24.0
3.5
11.5
CC Heater
0.5
1.5
371
700
20
65
1.9
7.5
9.8
32.3
Heater H-2
0.5
1.5
371
700
9
30
2.0
7.9
10.4
34.0
Heater H-3+
0.5
1.5
371
700
9
30
1.3
5.0
6.5
21.5
Heater H-4
0.5
1.5
371
700
9
30
2.0
7.9
10.4
34.0
Heater H-101
1.4
4.5
371
700
24
80
7.6
30.0
4.4
14.4
Heater H-102
1.3
4.3
371
700
24
80
6.0
24.0
3.9
12.9
Heater H-201
1.2
4.0
371
700
24
80
3.8
15.0
3.9
12.9
West Hot Oil Heater
1.2
4.0
315
600
17
55
2.0
8.0
2.8
9.1
A. B. Heater South
0.8
2.5
315
_600
9
30
2.0
8.0
3.8
12.4
A. B. Heater West
0.6
2.0
315
600
11
35
2.0++
8t+
5.4
17.7
A. B. Heater East
0.6
2.0
315
600
11
35
1.3++
5++
3.4
11.1
W. E. Asphalt Heater
0.9
3.0
315
600
21
70
2.4
9.5
2.9
9.4
+ Unit fired by gas only
++ Estimated volumes

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8
O
estimate the heating value of these gases to be 26,700 kg cal/m (3,000
3
Btu/ft ) and the sulfur content to be negligible.
Edgington is on an interruptible natural gas supply. During
interruptions, units which can burn fuel oil are operated in this mode.
During 1975 the natural gas interruption frequency was about 3% of the
time.
Since the process heaters and steam boilers are operated on natural
gas or fuel oil, none of these units are equipped with emission control
devices. There are no stack gas opacity detectors and alarm systems on
these units either.
Sulfur oxide emissions from these units are controlled by limiting
the sulfur content of the fuels burned to comply with the LAAPCD Rule
62. Refinery fuel gas must contain less than 1.1 gm/m (50 grains/100
ft ) of sulfur compounds. Fuel oil must contain less than 0.5% by
weight sulfur. The fuels are tested routinely to insure compliance.
Internal Combustion Engines
Edgington has only one stationary internal combustion engine. It
is a 5,870 kg cal/min (550 hp) Cummings V-12 diesel powered unit which
consumes approximately 1,480 1 (390 gal) of fuel per day. The unit is
used to drive a fuel pipeline pump. There is no emission control equipment
on this engine.
Storage Tanks
There are 57 storage tanks at this facility ranging in size from 64
to 5,700 m"^ (400 to 36,000 bbl) and used to store a wide variety

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9
of hydrocarbon materials. All of the tanks are of the fixed roof type.
Due to the volatile nature of some of the compounds stored, the potential
exists for substantial emissions of hydrocarbon vapors from these tanks.
Where such a potential exists, the tanks have been equipped with con-
servation vents set at 5 cm (2 in) of water vacuum or pressure, or the
tanks have been hard-piped to a vapor control system. With this system,
vapors are collected from the tanks into a manifold and burned in boilers
No. 1, 2, 3 and 6.
A summary of the Edgington storage tanks, their configuration, and
the materials stored within is presented in Appendix C.
Blowdown Systems
Edgington has no flare systems. All major process units are equipped
o
with pressure relief valves set at 3.5 kg/cm (50 psia). The pressure
relief valves are in series with rupture discs and vent to the atmosphere.
Vacuum Jets
Exhaust gases from the vacuum jets attendant to the vacuum distillation
unit are scrubbed in a caustic scrubber and then burned in process
heater H-201.
Asphalt Blowing
There are 6 asphalt blowing stills. Two stills are in operation at
any time. Off-gases from the blowing operation are passed through water
seal pots and incinerated in Boilers No. 1, 2, 3 and 6.

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10
Product Loading Racks
There are 52 spigots from which various products can be loaded into
truck or rail car. Eight of the spigots used for truck loading of hot
asphalt are on a vapor collection system which routes fumes to a 28 m3
(1,000 ft )/minute Brink's filter. An additional 14 spigots at the
asphalt pit rack and a single spigot for truck loading of roofing asphalt
are tied to a vapor collection system which routes fumes to a 14 m3 (500
ft )/minute Brink's filter. Nine spigots at the rail car loading rack
for hot asphalt and five spigots at the west asphalt truck loading
facility are tied to a 14 m3 (500 ft3)/minute Brink's filter system.
The remaining spigots are as follows: gasoline, 2; jet fuel, 2;
gas oil, 2; diesel fuel, 1; stove oil, 1; asphalt emulsion, 3; medium
cure asphalt, 2; fuel oil, 1; and heavy lube, 1. With the exception of
the gasoline units, none of these spigots are on vapor control systems.
The two gasoline loading spigots are on vacuum systems with the collected
vapors being incinerated in boilers No. 1, 2, and 3.
Edgington has ordered vapor collection spigots for the two jet fuel
units. Delivery and installation are anticipated in early 1976. Collected
vapors will be incinerated in boilers No. 1, 2, and 3.
Wastewater Treatment
Edgington's wastewater discharges amount to approximately 930 m3
(245,000 gal)/day. Sources of the wastewater include cooling tower and
boiler blowdown, and process wastes.

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11
All wastewater passes through an oil/water separator which is
covered. The wastewater then passes through three holding ponds in
series and is ultimately discharged to the Los Angeles County Sanitation
District sewers.
Skimmed oil which is recovered from the separator unit or the ponds
is sent to slop storage and ultimately reprocessed in the crankcase oil
treating unit.
EMISSIONS DATA
Source Test Data
NEIC personnel requested that Edgington supply copies of all stack
tests conducted at the facility since 1972. The LAAPCD was requested to
do likewise. Edgington submitted no information. The LAAPCD submitted
the following information.
Test C-2043, conducted on September 20 and October 2, 1973, moni-
tored the sulfur content of the off-gases from the sour water stripping
unit and the distillation units. These gases are ultimately burned in
the process heaters or boilers. The tests were conducted to determine
compliance with Rule 62, Sulfur Content of Fuels. A copy of this source
test is presented in Appendix D.
The results of this test indicated that the off-gases from the sour
water stripper unit complied with Rule 62 since their heating value was
less than 2,670 kg cal/m^ (300 Btu/ft"^). The off-gases from the vacuum
jets at the vacuum distillation unit are passed through caustic scrubbers.
Hydrogen sulfide levels were below detectable limits for these gases and
hence, they also complied with Rule 62.

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12
The hydrogen sulfide in the off-gases from the two overhead collectors
on atmospheric distillation unit No. 2 was found to greatly exceed the
O
1.1 gm/m (50 grains/100 scf) allowable under Rule 62. The company was
required to install caustic scrubbers to desulfurize these gases before
they are incinerated in the process heaters and boilers. No source test
data was submitted by the LAAPCD which shows the hydrogen sulfide content
of these gases after installation of the scrubbers.
Test C-2203, conducted October 24, 1974, was made to determine the
adequacy of the boilers as asphalt fume incinerators. The test showed
that no detectable odors resulted from the boiler fireboxes and, hence,
the units were in compliance with Rule 70.
Computed Emission Rates
Theoretical emisson factors for typical emission sources found at
petroleum refineries are listed in Table 9.1-1 of the EPA publication
AP-42 Compilation of Air Pollutant Emission Factors> Second Edition
(second printing with Supplements 1-4). These emission factors were
used to compute the following emission rates. Emissions from hydro-
carbon storage tanks have not been calculated for this report; rather,
they will be included in a separate report being prepared by NEIC which
will summarize storage tank emissions from all refineries in Los Angeles
County.
Boilers and Process Beaters. As can be seen from the listing of
process heaters and steam boilers shown in Table 1, all but one of these
units can be fired with either natural gas or fuel oil. Theoretical
emissions from these units are calculated using different factors for

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13
each fuel type. Therefore, it can be seen that a range of emissions can
exist depending on the available fuel situation. Table 2 summarizes the
theoretical emissions for two possible situations: 1) all units in
operation and all units operating on natural gas and, 2) all units in
operation and natural gas curtailed so that fuel oil is being used in
those units which can use fuel oil. For these calculations, the heat
input figures for the units were those supplied by Edgington as rated
unit capacities. Also, all units at the refinery were considered to be
operating and at rated capacity, a situation which admittedly will yield
maximum emissions estimations.
The process heaters and boilers are major contributors of nitrogen
oxides. Depending on the fuel use pattern at the refinery, calculated
nitrogen oxides emissions for these units range from 25.3 to 54.5 kg
(55.6 to 119.8 lb)/hour as NOg. If the refinery is on natural gas
curtailment, these units are also potential sources of particulate
matter, 15.6 kg (34.3 lb)/hour and sulfur oxides 59 kg (129 lb)/hour as
so2.
Other Sources. Table 2 summarizes the calculated theoretical
emission rates from other sources within the refinery. In general, AP-
42 gives only hydrocarbon emission factors for these sources. The major
source appears to be leakage from pipeline valves and flanges which
amounts to 16 kg (34 1b)/hour.
SUMMARY OF VIOLATIONS
A review of the LAAPCD records indicates that four violation
notices have been issued to Edgington.

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Table 2
CALCULATED EMISSION RATES FROM VARIOUS UNIT OPERATIONS
EDGINGTON OIL COI-fPAlfY - LONG BEACH, CALIFORNIA
Calculated Emissions
Emission Source
Particulates
Sulfur Oxides
(so2)
Carbon Monoxide
(CO)
Hydrocarbons
Nitrogen Oxides
(no2)
Aldehydes
Ammonia

(kg/hr)(lb/hr)
(kg/hr)(lb/hr)
(kg/hr)(lb/hr)
(kg/hr)(lb/hr)
(kg/hr)(lb/hr)
(kg/hr)(lb/hr)
(kg/hr)(lb/hr)
Process Heaters
and Steam Boilers
Condition 1
Condition 2
2.2 4.8
15.6 34.3
Neg.
59 129
Neg.
Neg.
3.3
2.7
7.3
5.8
25.
54.
.3 55.6
.5 119.8
0.3 0.7
0.5 1.0
Neg.
Neg.
Wastewater Treatment
Neg.
Neg.
Neg.
0.9
1.9

Neg.
Neg.
Neg.
Pipeline Valves and
Flanges
Neg.
Neg.
Neg.
16
34

Neg.
Neg.
Neg.
Vessel Relief Valves
Neg.
Neg.
Neg.
6
14

Neg.
Neg.
Neg.
Pump Seals
Neg.
Neg.
Neg.
9
21

Neg.
Neg.
Neg.
Compressor Seals
Neg.
Neg.
Neg.
3
6

Neg.
Neg.
Neg.
Miscellaneous
Neg.
Neg.
Neg.
6
12

Neg.
Neg.
Neg.
T0TALS+t'
15.6 34.3
59 129
Neg.
43.6
94.7
54,
.5 119.8
0.5 1.1
Neg.
t Condition 1 is that all units	are operating at rated capacity and all are fired with natural gas.
tt Condition 2 is that all units	are operating at rated capacity, natural gas ie curtailed, and all units which can utilize fuel oil
are doing so.
ttt Totals include only Condition 2; considered worst situation.

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15
On August 30, 1963, a violation of Rule 62, Sulfur Content of
Fuels, was detected. Edgington was found guilty and paid a $52.50 fine.
On January 6, 1970, emissions ranging from 50-60% opacity were
detected emanating from the stack serving No. 1 steam boiler, a violation
of Rule 50. Edgington pleaded guilty and paid a $200 fine.
On February 20, 1973, emissions ranging from 80-90% opacity were
detected emanating from the stack of a crude oil heater, another violation
of Rule 50. The Company pleaded guilty and paid a fine of $65.00.
On October 14, 1973, emissions of 70% opacity were detected emanating
from an open hatch of a railroad tank car which was being loaded with
cutback asphalt without the vapor control system in use. Edgington
pleaded guilty and paid a fine of $65.00.
INSPECTION SUMMARY
At the time of this inspection, all major process units were in
operation with the exception of the crankcase oil rerun unit. All
process units, storage vessels, potential emission points, and pollution
control devices in use at the refinery were observed during the inspection.
No visible emissions were detected from any of the process heaters or
steam boilers.
Housekeeping at this facility was about average for a refinery
which produces asphalt. No major spill areas or leaks were noted throughout
the inspection.
The vent pipes on several asphalt storage tanks extend down the
side of the tanks into 210 1 (55 gal) drums. These drums are intended

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16
to be filled with water to form a seal against vapors which may escape
from the tanks through the conservation vents. It was noted that
several of these drums were empty, an apparent maintenance problem. No
fumes were noted escaping from these vent pipes, however.

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Appendix A
NEIC INFORMATION REQUEST LETTER
TO EDGINGTON OIL COMPANY

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ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
NATIONAL FIELD INVESTIGATIONS CENTER-DENVER
BUILDING 53. BOX 25227. DENVER FEDERAL CENTER
DENVER. COLORADO 80225
September 8, 1975
Dear
Pursuant to the authority contained in Section 114 of the Clean Air
Act, as amended, representatives of the EPA will conduct, within the
next year, inspections of the	operations to
ascertain compliance with the Federally approved California State
Implementation Plan.
Representatives from the Environmental Protection Agency will
observe the facility's process operations, inspect monitoring and
laboratory equipment and analytical methods, review source test data,
examine appropriate records, etc. A process and air pollution flow
diagram or a blueprint of the facility and production information should
be available for the EPA personnel at the start of the inspections.
Detailed information about air pollution sources will be discussed
during these inspections. Attached is a partial list of the information
that will be needed in order to complete these inspections. We would
appreciate it if you could inform the appropriate company personnel
about the forthcoming inspections so that the necessary information will
be readily available and the inspection can be expedited.
If you have any questions concerning these inspections, please feel
free to contact Arnold Den, Chief, Air Investigations Section, Region
IX, San Francisco, at 415/556-8752.
A representative of the EPA (Dr. Wayne Smith or Mr. David Brooman,
303/234-4658) will contact you within the next 30 days concerning this
visit.
Sincerely,
~7Z-^ f
Thomas P. Gallagher
Director
Attachments

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A. Refinery Capacity in Barrels/Day
B. Furnaces, Boilers and Process Heaters (for each furnace boiler
and heater)
1.	Rated capacity in 10^ BTU/hr heat input.
2.	Maximum capacity as per cent of rated capacity.
3.	For oil fired units:
a; Rated capacity in gals/hr or 10^ bbl/hr.
b.	Heating value in BTU's/gal.
c.	Per cent sulfur and ash in oil by wt.
d.	Specific gravity of oil.
e.	Firing pattern (atoraization, etc. for furnaces).
A. For gas fired units:
a.	Rated capacity in 10^ SCF/hr.
b.	Type of gas burned (list principal constituents in % by
weight).
C. Density lb/SCF.
d.	Heating value of gas in BTU's/SCF.
e.	Sulfur content of gas in % S by vol and grains/SCF.
5.	Type(s) of control equipment and collection efficiency(s)
(design and actual).
6.	Pressure drop (inches of water) across collection devices(s).
7.	Elevation above grade of stack outlets and other discharge
points.
8.	Identification of stacks equipped with recording monitors
for determining opacities of stack effluents.
9.	Existing stack test data. The full test reports describing
methods used, test data, calculations, test results and
process weights should be available.
10.	Inside diameters of each stack (ft).
11.	Temperature of effluent gas stream from each stack (°F).
12.	Exit velocity of each stack effluent (ft/sec).
C, Incinerators: (For each incinerator)
1,	Rated capacity in 10^ BTU's/hr; include auxiliary burners
separately.
2.	Auxiliary burner fuels:
oil - KH bbl/hr and specific gravity,
gas - 10 SCF/hr and density in lb/SCF.
other — (describe) - lbs/hr (Heating value of each fuel).

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-2-
3.	Maximum capacity as per cent of rated capacity for auxiliary
burners.
4.	Sulfur and ash content of fuel as % by weight for auxiliary
burners.
5.	Type of material incinerated.
6.	Rated capacity for material incinerated in lb/hr.
7.	Sulfur and ash content of material incinerated as % by weight.
8.	Heating value of material incinerated.
9.	The gas flow rate reported at dry standard conditions (DSCFH).
10.	Type(s) of control equipment and collection efficicncy(s)
(design and actual).
11.	Pressure drop (inches of water) across collection device(s).
12.	Elevation above grade of stack outlets and other discharge
points (ft).
13.	Identification of stacks equipped with recording monitors
for determining opacities of stack effluents.
14.	Existing stack test data. Data should include the full test
reports describing methods used, test data, calculations,
test results and process weights.
15.	Inside diameter of each stack (ft).
16.	Exit velocity of each stack effluent (ft/sec.).
17.	Temperature of effluent gas stream from each stack in °F.
D. Catalytic Cracking Units, Coker Units: (For each unit)
1.	Rated capacity - 106 BTU/hr and indicate the type of unit such
as PCC, Coker, etc.
2.	Maximum capacity as per cent of rated capacity.
3.	Type of feed-stock used and barrels of fresh feed used per yr.
•4. Sulfur content of feed-stock (% by weight).
5.	Types of control equipment and collection efficiency(s) (design
and actual).
6.	Pressure drop (inches of water) across collection devices(s).
7.	Elevation above grade of stack outlets and other discharge
points (ft).
8.	Identification of stacks equipped with recording monitors
for determining opacities of stack effluents.
9.	Existing stack test data. Data should include the full test
reports describing methods used, test data, calculations, test
results and process weights.
10.	Inside diameter of each stack (ft).
11.	Exit velocity of each stack effluent (ft/sec).
12.	Total flow through unit in 10^ bbl/hr and ton/hr.
13.	Temperature of effluent gas stream from each stack in °F.
14.	Indicate disposition of waste gas stream, i.e., burned in
afterburner, etc.

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-3-
15.	Average hours of operation per month and average monthly
catalyst makeup for the catalytic cracking units.
16.	Indicate date of installation or latest modification.
E.	Blowdown Systems:
1. Indicate type and efficiency of each air pollution control
device.
F.	Flares: (For each flare)
1.	Type
2.	Height and diameter of stack (ft).
3.	Velocity of stack effluent (ft/sec).
4.	Temperature of gas effluent (°F).
5.	Rated capacity 10^ BTU/hr and tons/hr (of flared material).
6.	Amount of material flared and percent of time material being
flared.
7.	Maximum capacity as per cent of rated capacity.
8.	Type of flare ignition device at top of stack.
9.	Sulfur content of flared input (Z by wt).
10. Where material comes from that is burned in flare.
G.	Storage Vessels: (For each vessel)
1.	Indicate type of tank (fixed roof, floating roof, vapor recovery,
etc.)
2.	Give storage capacity of each tank in 1(P gallons or barrels.
3.	Indicate type of material stored in each tank (crude oil, gasoline,
finished petroleum product) and give annual average true vapor
pressure (TVP) and seasonal maximum for actual storage condition
of product stored in lbs/sq. in. absolute.
A. State tank diameter (ft).
5.	Indicate if tank is equipped with submerged fill pipe.
6.	Indicate if the tank is a pressure tank capable of maintaining
working pressure sufficient at all times to prevent vapor or gas
loss to the atmosphere.
7.	State type of air pollution control equipment on each tank, i.e.,
conservation vent, vapor recovery system, etc.
8.	Indicate average and seasonal maximum temperature of each tank.
9.	Indicate date of installation or latest modifications.
10. Indicate if tank is used for multiple product storage.
H.	Wastewater Treatment Systems:
1.	Indicate gallons of waste water discharged daily.
2.	Indicate source of such drains (process discharged).

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-4-
3. Indicate type and efficiency of each air pollution control
device and any existing test data indicating actual emissions.
Data should include the full test reports describing methods
used, test data, calculations, test results and process weight.
I. Internal Combustion Engines: (Stationary)
1.	Type of engine.
2.	Amount of fuel burned per day.
3.	Type of fuel.
J. Vacuum Jets and/or Barometric Condensers
1.	Indicate type and efficiency of each air pollution control
device.
2.	Indicate disposition of exhaust gases (eg. To afterburners,
fireboxes, etc.).
K. Loading Rack Vapor Recovery:
3
1.	Actual product throughput in 10 gallons per day and year.
2.	Type of material loaded.
3.	Type of vapor recovery system and rated collection efficiency.
A. Existing test data. The full test reports describing methods
used, test data, calculations and test results should be
submitted.
L. Submit schematic diagrams showing stacks and their respective
process associations and control equipment.
M. List any other significant (25 tons/yr. potential uncontrolled
emission) sources of particulates, sulfur dioxide, carbon monoxide,
oxides of nitrogen, and hydrocarbons not covered by Items B-L.
Include:
1.	Type of process and rated capacity.
2.	Type of material processed.
3.	Types of collection equipment and collection efficiency(s)
(design and actual).
4.	Pressure drop (inches of water) across collection devices.
5.	Existing stack test data applicable to current operating
conditions. The full test reports describing methods used,
test data, calculations, test results and process weights
should be submitted.

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Appendix B
SELECT LAAPCD RULES

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APPENDIX B
County of Los Angeles
Air Pollution Control District

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IV
Prohibitions

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yjRule 50. Ringelmann Chart.
(Effective January 6, 1972 for any source not completed and put into
service. Effective for all sources on January 1, 1973.)
A person shall not discharge into the atmosphere from any single
source of emission whatsoever any air contaminant for a period or periods
aggregating more than three minutes in any one hour which is.
a.	As dark or darker in shade as that designated No. 1 on the Ringel-
mann Chart, as published by the United States Bureau of Mines, or
b.	Of such opacity as to obscure an observer's view to a degree
equal to or greater than does smoke described in subsection (a) of this
Rule.
This amendment shall be effective on the date of its adoption for any
source of emission not then completed and put into service. As to all other
sources of emission this amendment shall be effective on January 1, 1973.
\J Rule 51. Nuisance.
A person shall not discharge from any source whatsoever such quanti-
ties of air contaminants or other material which cause injury, detriment,
nuisance or annoyance to any considerable number of persons or to the
public or which endanger the comfort, repose, health or safety of any such
persons or the public or which cause or have a natural tendency to cause
injury or damage to business or property.
(Effective January 6, 1972 for any equipment not completed and put
into service. Effective for aEI equipment on January 1, 1973.)
A person shall not discharge into the atmosphere from any source par-
ticulate matter in excess of the concentration shown in the following table:
(See Rule 52 Table)
Where the volume discharged falls between figures listed in the table,
the exact concentration permitted to be discharged shall be determined by
linear interpolation.
The provisions of this rule shall not apply to emissions resulting from
the combustion of liquid or gaseous fuels in steam generators or gas turbines.
For the purposes of this rule "particulate matter" includes any material
which would become particulate matter if cooled to standard conditions.
This amendment shall be effective on the date of its adoption for any
Rule 52.. Particulate Matter - Concentration.

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^Rule 56. Storage of Petroleum Products.
A person shall not place, store or hold in any stationary tank, reser-
voir or other container of more than 40,000 gallons capacity any gasoline
or any petroleum distillate having a vapor pressure of 1.5 pounds per square
inch absolute or greater under actual storage conditions, unless such tank,
reservoir or other container is a pressure tank maintaining working pressures
sufficient at all times to prevent hydrocarbon vapor or gas loss to the atmos-
phere, or is designed and equipped with one of the following vapor loss con-
trol devices, properly installed, in good working order and in operation:
a.	A floating roof, consisting of a pontoon type or double-deck
type roof, resting on the surface of the liquid contents and equipped
with a closure seal, or seals, to close the space between the roof edge
and tank wall. The control equipment provided for in this paragraph
shall not be used if the gasoline or petroleum distillate has a vapor pres-
sure of 11.0 pounds per square inch absolute or greater under actual
storage conditions. All tank gauging and sampling devices shall be gas-
tight except when gauging or sampling is taking place.
b.	A vapor recovery system, consisting of a vapor gathering sys-
tem capable of collecting the hydrocarbon vapors and gases discharged
and a vapor disposal system capable of processing such hydrocarbon
vapors and gases so as to prevent their emission to the atmosphere and
with all tank gauging and sampling devices gas-tight except when gaug-
ing or sampling is taking place.
c.	Other equipment of equal efficiency, provided such equip-
ment is submitted to and approved by the Air Pollution Control Offi-
cer.

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Rule 59. Effluent Oil Water Separators.
{Effective June 29, 1971 for any equipment not completed and put
into service. Effective for all equipment after July 1, 1972)
A person shall not use any compartment of any vessel or device operat-
ed for the recovery of oil from effluent water which recovers 200 gallons a
day or more of any petroleum products from any equipment which proc-
esses, refines, stores or handles hydrocarbons with a Reid vapor pressure
of 0.5 pound or greater,unless such compartment is equipped with one of
the following vapor loss control devices, except when gauging or sampling
is taking place:
a.	A solid cover with all openings sealed and totally enclosing
the liquid contents of that compartment.
b.	A floating pontoon or double-deck type cover, equipped
with closure seals to enclose any space between the cover's edye and
compartment wall.
c.	A vapor recovery system, which reduces the emission of all
hydrocarbon vapors and gases into the atmosphere by at least 90 per
cent by weight.
d.	Other equipment of an efficiency equal to or greater than
a, b, or c, if approved by the Air Pollution Control Officer.
This rule shall not apply to any oil-effluent water separator used ex-
clusively in conjunction with the production of crude oil, if the water
fraction of the oil-water effluent entering the separator contains less than
5 parts per million hydrogen sulfide, organic sulfides, or a combination
thereof.
This amendment shall be effective at the date of its adoption for any
equipment not then completed and put into service. As to all other equip-
ment this amendment shall be effective on July 1, 1972.

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^ Rule 60. Circumvention.
A person shall not build, erect, install, or use any article, machine,
equipment or other contrivance, the use of which, without resulting in a
reduction in the total release of air contaminants to the atmosphere, re-
duces or conceals an emission which would otherwise constitute a violation
of Division 20, Chapter 2 of the Health and Safety Code of the State of
California or of these Rules and Regulations. This Rule shall not apply to
cases in which the only violation involved is of Section 24243 of the Health
and Safety Code of the State of California, or of Rule 51 of these Rules and
Regulations.
J Rule 61. Organic Liquid Loading.
(Effective June 29, 1971 for any equipment not completed and put
into service. Effective for all equipment after July 1, 1972)
A person shall not load organic liquids having a vapor pressure of 1.5
psia or greater under actual loading conditions into any tank truck, trailer,
or railroad tank car from any loading facility unless the loading facility is
equipped with a vapor collection and disposal system or its equivalent ap-
proved by the Air Pollution Control Officer.
Loading shall be accomplished in such a manner that all displaced
vapor and air will be vented only to the vapor collection system. Measures
shall be taken to prevent liquid drainage from the loading device when it is
not in use or to accomplish complete drainage before the loading device is
disconnected.
The vapor disposal portion of the vapor collection and disposal system
shall consist of one of the following:
a.	An absorber system or condensation system which processes
all vapors and recovers at least 90 per cent by weight of the organic
vapors and gases from the equipment being controlled.
b.	A vapor handling system which directs all vapors to a fuel gas
system.
c.	Other equipment of an efficiency equal to or greater than a
or b if approved by the Air Pollution Control Officer.
This rule shall apply only to the loading of organic liquids having a

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vapor pressure of 1.5 psia or greater under actual loading conditions at a
facility from which at least 20,000 gallons of such organic liquids are loaded
in any one day.
"Loading facility", for the purpose of this rule, shall mean any aggre-
gation or combination of organic liquid loading equipment which is both
(1) possessed by one person, and (2) located so that all the organic liquid
loading outlets for such aggregation or combination of loading equipment
can be encompassed within any circle of 300 feet in diameter.
This amendment shall be effective at the date of its adoption for any
equipment not then completed and put into service. As to all other eautp-
ment this amendment shall be effective on July 1, 1972.
yj Rule 62. Sulfur Contents of Fuels.
A person shall not burn within the Los Angeles Basin at any time be-
tween May 1 and September 30, both dates inclusive, during the calendar
year 1959, and each year thereafter between April 15 and November 15,
both inclusive, of the same calendar year, any gaseous fuel containing sulfur
compounds in excess of 50 grains per 100 cubic feet of gaseous fuel, calcu-
lated as hydrogen sulfide at standard conditions, or any liquid fuel or solid
fuel having a sulfur content in excess of 0.5 per cent by weight.
The provisions of this rule shall ncjt apply to-
a.	The burning of sulfur, hydrogen sulfide, acid sludge or other
sulfurcompounds in the manufacturing of sulfur or sulfur compounds.
b.	The incinerating of waste gases provided that the gross heat-
ing value of such gases is less than 300 British Thermal Units per cubic
foot at standard conditions and the fuel used to incinerate such waste
gases does not contain sulfur or sulfur compounds in excess of the a-
mount specified in this rule.

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c.	The use of solid fuels in any metallurgical process.
d.	The use of fuels where the gaseous products of combustion
are used as raw materials for other processes.
e.	The use of liquid or solid fuel to propel or test any vehicle,
aircraft, missile, locomotive, boat or ship.
f.	The use of liquid fuel whenever the supply of gaseous fuel,
the burning of which is permitted by this rule, is not physically avail-
able to the user due to accident, act of God, act of war, act of the
public enemy, or failure of the supplier.
y^Rule 62.1 Sulfur Contents of Fuels.
a.	A person shall not burn within the Los Angeles Basin at any
time between the days of November 16 of any year and April 14 of the
next succeeding calendar year, both dates inclusive, any fuel described in the
first paragraph of Rule 62 of these Rules and Regulations.
b.	The provisions of this Rule do not apply to:
1.	Any use of fuel described in Subsections a,b,c,d,e, and f of
said Rule 62 under the conditions and for the uses set forth
in said Subsections.
2.	The use of liquid fuel during a period for which the supplier
of gaseous fuel, the burning of which is not prohibited by
this Rule, interrupts the delivery of gaseous fuel to the user.
c.	Every holder of, and every applicant for a permit to operate fuel-
burning equipment under these Rules and Regulations shall notify the Air
Pollution Control Officer in the manner and form prescribed by him, of each
interruption in and resumption of delivery of gaseous fuel to his equipment.
\j Rule 62.2 Sulfur Contents of Fuels.
Notwithstanding the provisions of Section (f) of Rule 62 or any pro-

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vision of said section as incorporated into Rule 62.1 or any provision of
Subsection (2) of Section b of Rule 62.1, a person shall not burn within the
Los Angeles Basin any liquid fuel or solid fuel having a sulfur content in ex-
cess of 0.5 per cent by weight.
It shall not be a violation of this rule to burn such fuel for a period of
not to exceed three calendar days (and in addition for that period of time
necessary for the Hearing Board to render a decision, provided that an ap-
plication for a variance is promptly filed) when other fuel which complles with
this Rule is not used due to accident, strike, sabotage, or act of God.
^ Rule 63. Gasoline Specifications.
a.	A person shall not, after June 30, 1960, sell or supply for use
within the District as a fuel for motor vehicles as defined by the Vehicle
Code of the State of California, gasoline having a degree of unsaturation
greater than that indicated by a Bromine Number of 30 as determined by
ASTM Method D1159-57T modified by omission of the mercuric chloride
catalyst.
b.	For the purpose of this rule, the term "gasoline" means any pe-
troleum distillate having a Reid vapor pressure of more than four pounds.
Rule 64. Reduction of Animal Matter.
A person shall not operate or use any article, machine, equipment or
other contrivance for the reduction of animal matter unless all gases, vapors
and gas-entrained effluents from such an article, machine, equipment or
other contrivance are:
a.	Incinerated at temperatures of not less than 1200 degrees
Fahrenheit for a period of not less than 0.3 second, or
b.	Processed in such a manner determined by the Air Pollution

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^ Rule 66.1. Architectural Coatings.
a.	A person shall not sell or offer for sale for use in Los Angeles
County, in containers of one quart capacity or larger, any architectural
coating containing photochemically reactive solvent, as defined in Rule
66(k).
b.	A person shall not employ, apply, evaporate or dry in Los Angeles
County any architectural coating, purchased in containers of one quart
capacity or larger, containing photochemically reactive solvent, as defined
in Rule 66 (k).
c.	A person shall not thin or dilute any architectural coating with a
photochemically reactive solvent, as defined in Rule 66{k).
d.	For the purposes of this rule, an architectural coating is defined as
a coating used for residential or commercial buildings and their appurte-
nances; or industrial buildings.
^ Rule 66.2 .Disposal and Evaporation of Solvents
A person shall not during any one day dispose of a total of more than
IV2 gallons of any photochemically reactive solvent, as defined in Rule 66{k),
or of any material containing more than VA gallons of any such photochemi-
cally reactive solvent by any means which will permit the evaporation of
such solvent into the atmosphere.
\jj< ule 67. Fuel Burning Equipment.
A person shall not build, erect, install or expand any non-mobile fuel
burning equipment unit unless the discharge into the atmosphere of contam-
inants will not and does not exceed any one or more of the following
rates:
1. 200 pounds per hour of sulfur compounds, calculated as sulfur

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dioxide (SO2);
2.	140 pounds per hour of nitrogen oxides, calculated as nitrogen
dioxide (NO2);
3.	10 pounds per hour of combustion contaminants as defined in
Rule 2m and derived from the fuel.
For the purpose of this rule, a fuel burning equipment unit shall be
comprised of the minimum number of boilers, furnaces, jet engines or other
fuel burning equipment, the simultaneous operations of which are required
for the production of useful heat or power.
Fuel burning equipment serving primarily as air pollution control
equipment by using a combustion process to destroy air contaminants
shall be exempt from the provisions of this rule.
Nothing in this rule shall be construed as preventing the maintenance
or preventing the alteration or modification of an existing fuel burning
equipment unit which will reduce its mass rate of air contaminant emissions.
Rule 68. Fuel Burning Equipment -- Oxides of Nitrogen.
A person shall not discharge into the atmosphere from any non-
mobile fuel burning article, machine, equipment or other contrivance, having
a maximum heat input rate of more than 1775 million British Thermal
Units (BTU) per hour (gross), flue gas having a concentration of nitrogen
oxides, calculated as nitrogen dioxide (NO2) at 3 per cent oxygen, in ex-
cess of that shown in the following table-
NITROGEN OXIDES - PARTS PER MILLION PARTS OF FLUE GAS

EFFECTIVE DATE
FUEL
DECEMBER 31, 1971
DECEMBER 31,1974
Gas
225
125
Liquid or Solid
325
225

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Rule 68.1. Fuel Burning Equipment - Combustion Contaminants.
A person shall not discharge into the atmosphere combustion contami-
nants exceeding in concentration at the point of discharge, 0.3 grain per
cubic foot of gas calculated to 12 per cent of carbon dioxide (CO2) at
standard conditions.
Rule 69. Vacuum Producing Devices or Systems.
A person shall not discharge into the atmosphere more than 3 pounds
of organic materials in any one hour from any vacuum producing devices or
systems including hot wells and accumulators, unless said discharge has been
reduced by at least 90 per cent.
This rule shall be effective at the date of its adoption for any equip-
ment not then completed and put into service. As to all other equipment
this rule shall be effective on July 1, 1972.
A person shall not operate or use any article, machine, equipment or
Other contrivance for the air blowing of asphalt unless all gases, vapors and
gas-entrained effluents from such an article, machine, equipment or other
contrivance are
a.	Incinerated at temperatures of not less than 1400 degrees
Fahrenheit for a period of not less than 0 3 second, or
b.	Processed in such a manner determined by the Air Pollution
Control Officer to be equally, or more, effective for the purpose of air
pollution control than (a) above.
This rule shall be effective at the date of its adoption for any equip-
ment not then completed and put into service. As to all other equipment
this rule shall be effective on July 1, 1972.
A person shall not, after December 31, 1971, discharge into the atmos-
phere carbon monoxide (CO) in concentrations exceeding 0.2 per cent by
volume measured on a dry basis.
The provisions of this rule shall not apply to emissions from internal
Rule 70. Asphalt Air Blowing.
Rule 71. Carbon Monoxide.

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combustion engines
^ Rule 72. Pumps and Compressors.
A person shall not, after July 1, 1973, use any pump or compressor
handling organic materials having a Reid Vapor Pressure of 1 5 pounds or
greater unless such pump or compressor ts equipped with a mechanical seal
or other device of equal or greater efficiency approved by the Air Pollution
Control Officer
The provisions of this rule shall not apply to any pump or compressor
which has a driver of less than one (1) horsepower motor or equivalent
rated energy or to any pump or compressor operating at temperatures in
excess of 500° F.
^ jRule 73. Safety Pressure Relief Valves.
A person shall not, after July 1, 1973, use any safety pressure
relief valve on any equipment handling organic materials above 15 pounds
per square inch absolute pressure unless the safety pressure relief valve is
vented to a vapor recovery or disposal system, protected by a rupture disc,
or is maintained by an inspection system approved by the Air Pollution
Control Officer
The provisions of this rule shall not apply to any safety pressure relief
valve of one (1) inch pipe size or less.

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Appendix C
STORAGE TANK LISTING

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ANNUAL
AVG. TRUE
VAP.PRESS
TANK
CAPACITY



& MAX.

NUy.BER
103 B3L.
PRODUCT

VAP.PRESS.
36001
36.0
ASPHALT


0

36002
36.0
ASPHALT


0

36i00 3
36.0
ASPHALT


0

30003
30.0
CRUDE
*
1.0
AVG/1•2
MAX
30C04
30.0
CRUDE
•HP
1.0
AVG/1.2
MAX
30005
30.0
ASPHALT


0

30006
30 .0
CRUDE/FUEL OIL


0

30007
30.0
JET FUEL

1.0
AVG/1.5
MAX
30003
30.0
GASOIL


0

12001
12.0
ASPHALT


0

12002
12 .0
ASPHALT


0

12003
12 .0
ASPHALT


0

12005
12.0
DIESEL


0

12006
12 .0
GASOIL


0

12007
12 .0
NAPHTHA

1.0
AVG/1.5
MAX
12003
12.0
JET FUEL

1.0
AVG/1.5
MAX
12009
12 .0
JET FUEL/STOVE OIL
2 . 7
AVG/3.0
MAX
6303
6.3
RAW DRAIN OIL

0.1
AVG/0.2
MAX
6304
6.3
SLOP OIL

0.2
AVG/0.3
MAX
&305
6.3
HEAVY LUBE


0

6001
6.0
SLOP OIL

0.3
AVG/0.5
MAX
6002
6.0
DRAIN OIL

0.1
AVG/0.2
MAX
6006
6.0
ASPHALT


0

5002
5.0
GASOLINE

6.0
AVG/7.0
MAX
5003
5.0
ASPHALT


0

5004
5.0
GASOLINE

6.0
AVG/1.0
MAX
4001
4.0
FUEL OIL/HIGH FLASH
LUBE
0

4002
- .0
HIGH FLASH LU3E


0

300 1
3.0
HIGH FL=lSH LUBE


0

2201
2 . 2
DIESEL


?


TABLE NO. 2
TANKS
TANK
DIAMETER
(FEET)
7 3 ' - 0 "
7 3 ' - 0 "
7 3 ' - 0 "
70'-0"
70'-0"
67'-0"
67 '-0"
67'-0 "
6 71-0"
4 2 1 - 6"
42 ' -6"
42 '-6"
42 '-6"
42 '-6"
42'-6 "
42 '-6"
42'-6"
33'-6"
33'-6"
38'-0"
32 '-0"
32 ' -0"
32 ' -0"
38'-0"
38 ' -0 11
39'-6"
31'-0"
31'-0"
26 ' -6"
26 ' -0"
TANK
POLLUTION	TEMP. MULTIPLE
CONTROL AVG./MAX¦ PRODUCT DATE INSTALLED OR MODIFIED
2" H20	390/420
2" H2O	390/420
2" HpO	390/420
0 * 100/110
0 # 100/110
2" H20	390/420
VAP/REC 110/120-120/140
VAP/REC	AMB
VAP/REC	110/120
2" W20	390/420
2" H20	390/420
2" H20	390/420
0	110/120
0	105/115
VAP/REC	MB
VAP/REC	AM3
VAP/REC	AM3
2" H20	140/150
0	175/200
VAP/REC	150/180
2" H20	175/200
2" H20	110/130
2" H20	390/
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TABLE NO. 2 (con't.)
TANKS
TANK
NUMBER
CAPACITY
103 BBL.
PRODUCT
ANNUAL
AVG. TRUE
VAP.PRESS.
& MAX.
VAP.PRESS.
TANK
DIAMETER
(FEET)
POLLUTION
CONTROL
TANK
TEMP.
AVG./MAX.
MULTIPLE
PRODUCT
DATE INSTALLED OH MODIFIED
2202	2.2	STOVE OIL
22 03	2.2	CUT BACK ASPHALT
2 2 04	2.2	CUT BACK ASPHALT
2001	6.3	ASPHALT
2002	6.3	ASPHALT
1801	1-8	ASPHALT
1302	1.8	ASPHALT
1506	1.1	HEAVY GASOIL
1507	1.5	CUT BACK ASPHALT
150 8	1.5	CUT BACK ASPHALT
1509	1.5	WELL WATER
1510	1.5	EFFLUENT WATER
1511	1.5	CC TOPS
1513	1.5	SPENT CAUSTIC
1101	1.1	ROOFING ASPhALT
1102	1.1	ROOFING ASPHALT
1103	1-1	ROOFING ASPHALT
1104	1.1	ROOFING ASPHALT
1105	1-1	ROOFING ASPHALT
1106	1.1	ASPHALT
1107	1.1	ASPHALT
1108	1.1	HEAVY LUBE
1001	1.0	FUEL OIL
4 51	.4	CUT BACK ASPHALT
4 52	.4	CUT BACK ASPHALT
453	.4	CUT BACK ASPHALT
4 54	.4	CUT BACK ASPHALT
0	26 '-0"	0
0	30*-0"	2" H20
0	30'-0"	2" H20
0	33'-6"	2" H20
0	33'-6"	2" H20
0	2 7 ' - 0"	2" HpO
0	2 7 ' -0"	2" H20
0	201-0"	2" H20
0	21'-6"	2" H20
0	21'-6"	2" H20
0	18 ' - 0 "	0
0	18 ' - 0 "	0
1,0 AVG/1.3 MAX 18'-0"	9
0	18'-0"	0
0	151-6"	2" H20
0	15'-6"	2" H20
0	19'-0"	2" H20
0	19'-0"	2" H20
0	19 '-0"	2" H20
0	19'-0"	2" H20
0	191-0"	2" H20
0	19'-0"	2" H20
0	21"-6"	0
0	10'-0"	2" H20
0	lO'-O"	2" H20
0	10'-0"	2" H20
0	10'-0"	2" 1120
70/100
NO
1948
225/310
NO
1948
225/310
NO
1943
380/450
NO
1968
380/450
NO
1968
300/375
NO
2948
300/375
NO
1948
150/200
NO
1952
225/300
NO
1966
225/300
NO
1966
AMB
NO
1942
130/175
NO
1942
70/100
NO
1942
100/130
NO
1942
350/470
NO
1948
350/470
NO
1948
450/500
NO
1959
450/500
NO
1959
420/460
NO
1950
420/460
NO
1960
390/420
NO
1959
120/135
NO
1959
170/180
NO
1942
225/275
NO
1967
225/275
NO
1967
225/275
NO
1967
225/275
NO
1967

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Appendix D
SOURCE TESTS RESULTS

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ABES POE.B.UTBOW CONTROL DBSTKBCT
434 SOUTH SAN PEDRO Stt^CT. LO$ A,^W.CS. CALIF. 90013 - MAD I SON 9-4711 / COUNTY OF LOS ANGCLES

TESTS
CONDUCTED AT
EDGING TON OIL COITAL
2*100 EAST ARTE5IA BOULL\/ARD
LONG BEACH, CALIFORNIA 90805
ON
-e^TsrasR-se-AKB October 2, 1973
REPORT
ON THE
COMPOSITION OF OFF-GASES FROM THE SOUR
WATER STRIPPING UNIT AND DISTILLATION UNITS AT A
PETROLEUi; REFINERY (CRUDE UNIT NO. 2)
BY
Andrew J. Wilson	Supervising Air Pollution Engineer II
Maurice A. Balias	Senior Air Pollution Encincer
TEAJ1 HO. b
SOURCE TESTING SECTION
REPORT NO. C-20^3
Eric E. Lemke	Howard DeVorkin
Director of Engineering	Supervising Air Pollution Engineer III
ISSUED:
NOV 3 0 1973

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AIR POLLUTION CONTROL DISTRICT
- COUNTY Of LOS ANGKLES
Test No. 0-2043	Page 1
Sept.—20 nnil
Oct. 2, l)Jipi
Keese of the Source Testing Section, Mr. Matt liisiak of the Refinery Unit
was present on both test days and his recorded observations are appended to
this report. Test arrangements were made through Mr. Jim Carngan, Superin-
tendent of Edgmgton Oil Company.
The standards employed for the test evaluation v/ere compliance with tv,o
provisions of ]?ule 62; nanely, (l) determination whether the off-gar.es had a
heating value of 300 BTll/SCK or greater, and (2) determination of r.-e sulfur
compounds in the off-gases, calculated as hydrogen sulfide, whetne-r in excess
of 50 grams/ICO SCF.
PROCESS /-HP EQUIP!'-a iT DESCRIPTION
Crude oil is heated in the primary tower of the Atrospheiic Crude Oil Distil-
lation Unit. The gases fron the top of this tower arc condensed 11 an overhenn
(O.H.) condenser. The knock-out pot for this condenser is designated Accu"iu-
lator No. D-102. This accumulator has an auxiliary ratural gas supply unich
was closed during the respective source test. The off-gases from tms pot were
sampled; the station designation is D-102. The condensate from this pot is
6cparated into fractions by settling — the water is sent to the sour water
stripper, the hydrocarbons returned to the tower.
The bottoms from the prinary tower are heated and pumped to the secondary
crude tower. The off-gases from this tower are processed an a smilar manner
to that described above for the primary tower. The auxiliary natural gas
eupply was also off during the test. This accumulator is designated D-103^

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AIR POLLUTION CONTROL DISTRICT -
COUNTY OF LOS ANGELES
Test No. C-20bj>	Page 2
—20 ¦¦ i t n e*
Oct. 2, 19Tj
The "bottoms from the secondary tower are heated and pumped to the vacuum
distillation tower of tne Vacuum Crude Oil Distillation Unit. The cases
from the top of this tower are reroved by a vacuum ejector-condenser system.
The off gases from this system are vented to a caustic scrubber, desipna+'cd
0-1)02. The off-gases from tne scrubber were sampled (station D-'i02). Tne
knock-out pot from the condenser (D-201) has a vent pipe for off-cases;
however, it was closed during the test (and has always been closed according
to the plant operator).
All of the sour water from the various processes of Crude Unit Ho. 2 are
pumped to the sour water stripper. The gases from the top of the stripper
are cooled m an overheaa condenser. The condensate is collected in a
knockout drum, designated D-302, with the liquid draining into an accumulator,
designated D-301. Since the off gases from the knockout drum and the
accumulator had separate piping whicn did not join, individual samples were
taken of each streara (station D-302 and station D-301).
The off-gases from the above five stations are vented to boilers where they
are incinerated without further processing.
SAIIPLJNG PROCEDURES AND ANALYSIS
Hydrogen Sulfide
Hydrogen sulfude was collected by neans of an impinger train as shown on
page 20 consisting of: two impingers in series containing 100 ml eacn of a
zinc carbonate slurry (prepared in accordance with American Petroleun Institute
Method 715-57) followed by a dry inpinger, an impingcr containing 100 nil
of standard iodine solution to absorb any HjS that was not collected by tne 2r.-
CO^ ifiipingers (and also to act as an indicator to signal wnen tne Zn CC-j m.pmgers
vere saturated), and finally by a dry inpinger with a thermometer.
The trains were purged with ambient air after the sampling was completed.
The hydrogen sulfide m the ZnCOj impingers v/as determined by iodine titration
and added to the amount of found m the iodine impingcr as determined
by back titration.
The total sample volume is the sum of the water condensed in the impingers,
the volume of H^S absorbed, the volume of NHj, if any (as determined by
another train), plus the measured volume of gases through the meter.

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AIR POLLUTION COHTfiOL DISTRICT - COUNTY CF LOS AHGELKS
Test No. C-20^3	Page 3
£ept.-PQ-and
Oct. 2, 1973
Moisture
Total moisture in the sample is the sum of the water condensed in the lmpingers
plus the water vapor that passed through the meter, assuming saturation at
the last impmger temperature.
Ammonia
Ammonia was determined by use of an acid inpmger train as shown on page 21.
The ammonia is absorbed in the HC1 lmpingers and determined by use of
Nessler Neagent.
The IlaOH impinger which follows the HC1 inpingers was used to absorb acid
gases in order to protect source testing personnel and equipment.
The total sample volume is the sum of the v/ater condensed m the impingcrs,
the volume of lTtlj absoroed, the volume of acid gases absoroed (as detcrruned
by Orsat and calculated as shoun on page 9)> and the volume of gases measured
by the meter.
Acid Gases
The samples were collected in Tedlar bags and analyzed for acid gases (CO^,
I^S) with an Orsat analyzer.
Orpanics
The gas samples were drawn through a "Ilallcosorb" tube and coDlecled m
evacuated tv/o-liter flasks. The "Jiallcosorb" absorbs all acid gases. The
flack samples were analyzed for crganics by TCA (Total Combustion 'nalyxtr)
which reported the carbon content as equivalent % CO2 on a dry, acid gas-free
basic.
Heating Value
The gross heating value was determined by calculating the volume of I^S, NH^,
and organics, expressed as CO2, contained per standard cubic foot of each
aample; multiplying each component by its gross heating value (H2S by 6^7 3TU/
SCF, KIIj by ^1 BTU/SCF, and organics expressed as COj by 900 BTU/SCF), and
totaling these results. Calculations are shovn on page 11.
TEST CRITIQUE
Heating Value
Due to lack of sufficient laboratory personnel, the organics were run by TCA

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AIR POLLUTION CONTROL DISTRICT -
COUNTY OF LOS ANGKLES
Test No. 0-20^3	PaGc
rScpt-i—20-ai i d -
Oct. 2, 1973
instead of G.C. (Gas Chrom^t o graphy), consequently results for total
organics are expressed as equivalent C02 only. In calculating heating value,
it was necessary to assume an average BTU per SCF of carbon as equivalent
(X>2. The value used \-as 900 BTU/SCF. This assumes that ino^t of the organics
were from the lighter end of the paraffin series. Actual values for various
hydrocarbons are presented in the table below:
Compound
BTU/SCF -7" No.
of carbon atoms
= BTU/equiv.
Methane
1013
1
1013
Ethane
1792
2
896
Propane
2590
3
863
Butanes (Avg)
3367
h
8 k2
Pentanes (Avg)
'tOO')
5
801
Hexanes (Avg)
V?28
6
788
Station D-*t02
The H2S concentration at point D-'i02 i-as considered to be ml as no H2S
v/as found in tne Zn CO3 lmpingers for this station. Folloumc the "n CO^
impingers was an impinger containing 100 nl of standard I2 solution (tee
diagram on page 21). The reduction of loaine was equivalent to 0.1274 I^S
as determined by the back-ticration. However, since no H2S was found m
the leading Zn CO3 inpinger.s, and no elemental sulfur was found in the I2
eolution, it v/as assumed tnat the reduction 01 I2 m this case v/as caused
by the evolution of iodine oy too rapid a rate of sampling,or reduction by
material other than {^S in the sample.
General
It vas assumed, at conditions existing at the campling points involved,
that both H2S and NH3 were in the gasous uncombined state.
The samples were not collected simultaneously since different amounts
of time were required to complete the sampling at each station, and only one
train could be run at a time at each station.
TEST RESULTS
The test results are summarized on page 6 . It should be noted that emissions
from points D-102 and D-103 fail to comply with limitations of Ru] e 62 with
respect to sulfur content and heating value of the gasei. being discharged to
thcboilern.

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AIR POLLUTION CONTROL DISTRICT - COUNTY OP LOS ANGELES
Test No. C-20^3
Pace 5
Sept. 20 and
Oct 2, 1973
TEST EVALUATION
A email amount of the iodine absorbing/indicator solution may have been
volatized. Since the loss in iodine (determined by backtitralior.) is
assumed to be caused by the l^S reducing the 1° to I", and the subsequent
production of elemental sulfur, the values reported for the I^S emission
may be slightly hich.
Fortunately, for stations D-301 and D-302, vhcre the possible errors could
be as high as 2% and 10% respectively, the heating values v/ere belou
300 BTU/SCF and Rule 62 did not apply.
For station D-102 and D-103 the possible errors are less than 3^« The
H2S content at these stations is so high that an authority to conctr'ict
probably would not have been issued if this data v/ere known before thit. test.
APPROVED
ev;: 11-29-73

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AIR POLLUTION CONTROL DISTRICT - COUNTY OF LOS ANGELES
Test No. C-2043	Page 6
•^gcot ¦ QO end »
Oct* 2, 1973
SUMMARY OF DATA AND RESULTS
Sampling point and location % H2O % HgS % H2S Grains	%	% Acid Gases Organics as Gross Heating
(Wet (Wet (Dry H2S Per	(Wet (Dry Basis) % CO2 on dry Value BTU/SCF
Basis) Basis) Basis) 100 SCF	Basis) (3y Orsat) acid free- (Wet Basis)
(Wet Basis)	basis
Off-gases from O.H.
Accumulator D-102,
Atmospheric Unit	23-9 7-18 9-^3	^530	NR	22.0	208	1157 (a)
Off-gases froc O.H.
Accu-ulator D-103
Atcospneric Unit	16.7 5-61 6-73	3520	NR	16.8	112	735 (a)
Vacuus Sjectors-Crude
Vaccuuci Dist. Unit
Scrubber Outlet, D-*t02	2.8	ND	ND	ND	NR	NR	NR	KR
Vessel D-301, Sour
Water Accumulator	2.5 O-IO^ 0.106	65	ND	6.4	32.3	266
Ve >1 D-302, O.H.
Knowic-Out Pot	91.0 2.U 26.7	1500	2-3	7^-0	3^.3	33
NOTS: (a) Rule 62 limits HjS concentrations to 50 grains/100 SCF v/hen gross heating value exceeds 300 BTU/SCF
ND = None Detected
NR = Not Requested

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ra
EDGINGTON OIL COMPANY
Long Beach, California
SUMMARY AND CONCLUSIONS
3
Edgington Oil Company operates a 4,700 m (29,500 bbl)/day, simple
petroleum refinery at Long Beach, California. An air pollution related
inspection was conducted at this facility by NEIC personnel on October
15, 1975. Substantial amounts of process and air pollution control
equipment information was requested of, and received from, Edgington.
The Los Angeles County Air Pollution Control District (LAAPCD) was
requested to supply information pertaining to stack testing conducted at
this facility and any violation notices issued to Edgington.
The following conclusions were derived based on the inspection and
information obtained:
1.	No visible emissions (which exceeded the 20% opacity limita-
tions of LAAPCD Rule 50) were noted from any process units.
2.	General housekeeping appeared about average for a refinery
which produces asphalt.
3.	Based on calculations using approved EPA emission factors, the
process heaters and steam boilers at this facility appear to
be significant sources of nitrogen dioxide. There are no
LAAPCD regulations which apply to these units.
4.	The results of the LAAPCD source test C-2203 indicate that the
use of boilers No. 1, 2, 3, and 6 as fume incinerators for the
asphalt-blowing off-gases complies with the LAAPCD Rule 70.

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5.	There is no current source test data available from the LAAPCD
on the off-gases from the caustic scrubbers installed post-
1973 to treat the off-gases from the overhead accumulator of
atmospheric distillation unit No. 2. It is not known there-
fore whether these off-gases comply with LAAPCD Rule 62,
Sulfur Content of Fuels.
6.	Edgington currently operates a jet fuel loading rack without a
vapor recovery system. The vapor recovery equipment for this
rack has been ordered and installation is anticipated in early
1976.
RECOMMENDATIONS
1.	Edgington should notify the Director, Enforcement Division,
Region IX and the Enforcement Division of the LAAPCD when
installation of the vapor recovery spigots for the existing
jet fuel loading rack is completed.
2.	Edgington should improve their maintenance schedule to insure
that the water seal drums on the asphalt storage tanks are
kept filled with water.
3.	Edgington should conduct source tests on the off-gases from
the caustic scrubbers on atmospheric distillation unit No. 2's
overhead accumulator. The results of these tests should be
forwarded to the Enforcement Division, LAAPCD and the Director,
Enforcement Division, Region IX, USEPA.

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