ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
EPA 330/2-76-007
REPORT ON
State Implementation Plan
Air Pollution Inspection
of
Golden Eagle Refining Company
LOS ANGELES COUNTY, CALIFORNIA
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER
DENVER, COLORADO
AND
REGION IX, SAN FRANCISCO, CALIFORNIA
£ \
FEBRUARY 1976 % phcj^
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ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
STATE IMPLEMENTATION PLAN
INSPECTION OF
GOLDEN EAGLE REFINING COMPANY, INC.
2100 S. Figueroa St.
Carson, California 90745
213/320-6860
October 16, 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 .... 5
Emissions Data 9
Summary of Violations 12
Future Expansion Plans 12
Inspection Summary 13
Appendix
A NEIC Request Letter
B LAAPCD Rules
C Storage Tank Listing
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INTRODUCTION
Background
The Golden Eagle Refining Company, Inc. operates a simple refinery
3
at this location with a rated capacity of 2,500 m (16,000 bbl) per
stream day (SD). Major products from this refinery include JP-4 and
JP-5 jet fuels, diesel fuel, and low sulfur fuel oil.
Golden Eagle employs about 35 people and operates three 8-hour
shifts, 7 days per week, year around.
On October 16, 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.
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 throughout this inspection.
They supplied all EPA requested information during the inspection interview
or by subsequent letter.
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2
Inspection Participants
Mr. Burl Freeman - Vice President for Refining, Golden Eagle
Refining Co., Inc.
Mr. C. W. Leggett - Consultant to Golden Eagle
Mr. John R. Powell, 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 61. Organic Liquid Loading
Rule 62. Sulfur Content of fuels
Rule 67. Fuel Burning Equipment
Rule 68.1 Fuel Burning Equipment - Combustion Contaminants
Rule 71. Carbon Monoxide
Rule 72. Pumps and Compressors
Rule 73. Safety Pressure Relief Valves
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3
PROCESS DESCRIPTION
The Golden Eagle facility is a simple refinery which processes
sweet (i.e., low sulfur) crudes received mostly from Alaska. The re-
finery also processes imported naptha. All crude and naptha are de-
livered to the refinery via pipeline. The main products from this
refinery include JP-4 and JP-5 jet fuels, diesel fuel, low sulfur fuel
oil, and refinery fuel gas which is consumed as fuel in the refinery.
Golden Eagle operates three atmospheric crude distillation towers
3
and a rerun unit with a total capacity of 2,500 m (16,000 bbl)/SD.
There are two desalter units which are currently not operated while
o
processing sweet crudes. Golden Eagle also operates a 720 m (4,500
bbl)/SD naptha rerun stabilizer unit.
Figure 1 is a simplified process flow diagram for this refinery.
Crude oil from storage is heated and introduced into an atmospheric
crude flash tower. Fuel gas and light napthas are flashed off in this
unit and separated in an accumulator. The fuel gas is used for refinery
fuel; the light naptha is further processed in the naptha stabilizer,
caustic treated, and then sent to storage.
The bottoms from the crude flash tower are reheated and introduced
into a fractionator tower. Here, they are separated into heavy naptha,
kerosene distillate, gas oils, and fuel oil. The heavy naptha is caustic
washed and mixed with light naptha to produce JP-4 jet fuel. The kero-
sene distillate is caustic washed and results in JP-5 jet fuel. The gas
oil and fuel oil are sent to storage.
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Fuel Gas to Processes
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FIGURE 1
SIMPLIFIED PROCESS DIAGRAM
GOLDEN EAGLE REFINING CO., INC., CARSON, CA
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5
The imported naptha is processed by introducing it as reflux to the
atmospheric flash towers.
POTENTIAL SOURCES OF AIR POLLUTION EMISSIONS AND RELATED CONTROL EQUIPMENT
The Golden Eagle refinery is a small non-complex refinery with
relatively few discrete potential sources of air pollution emissions.
The major unit processes 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 constitute the
main emission sources.
There are a large number of relatively small potential sources of
emissions related to the operation of the refinery. Such sources in-
clude leaks from valve seals, pump seals, and pipe flanges, and evaporative
losses from storage tanks and process wastewater drains. Potential
major sources of emissions and their related control equipment are
discussed below.
Process Heaters and Boilers
There are nine process heaters and five steam boilers at this
refinery ranging in size from 0.8 X 10^ to 12.9 X 10^ kg cal (3 X 10^ to
51.4 X 10^ Btu)/hour. A complete listing of these units is presented in
Table 1.
All heater and boiler units at this refinery can be fired with
refinery fuel gas, natural gas, or low sulfur fuel oil. Natural gas is
purchased from the Southern California Gas Company on interruptible
service. Refinery fuel gas and fuel oil are produced in the refinery.
Golden Eagle can produce approximately two-thirds of the amount of gas
fuel required.
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Table 1
PROCESS HEATERS AND STEAM BOILERS
Golden Eagle Refining Company, Inc. -Carson, California
Unit
No.
Identification
Rated Capaclty/hr
(106kg cal)(1068tu) {10
Refinery
Fuel Gas.
Usaqe/hr
3 _3Yi,*3,
m',)( 10JSCF) (103m3) (10J
Natural . Fuel Oil.
hr Usaqe/hr Stack Height
SCF)(1iters)(gal) (m.) (ft)
Gas
Usage^
Stack
Velocity
Stack Diameter Stack Temp, (gas fired)
(cm) (ft) (°C) (°F){m/sec){ftAec)
H-l
No. 1 Crude Unit Heater
4.7
18.6
0.20
6.9
0.51
17.7
480
126
12.8
42
91
36
426
800
6.6
21.7
H-2
No. 2 Crude Unit Heater
6.5
25.7
0.27
9.6
0.70
24.5
660
174
20.7
68
122
48
371
700
4.8
15.6
H-3
No. 1 Crude Unit Heater
1.8
7
0.07
2.6
0.19
6.7
180
47
17.7
58
61
24
371
700
5.2
16.9
H-4
No. 1 Crude Unit Heater
1.5
6
0.05
2.2
0.16
5.7
160
41
17.7
58
61
24
371
700
4.4
14.5
H-5
No. 4 Rerun Unit Heater
3.5
14
0.15
5.2
0.38
13.3
360
95
17.7
58
76
30
371
700
6.6
21.6
H-6
Naptha Stabiluer Heater
3.5
14
0.15
5.2
0.38
13.3
360
95
17.7
58
76
30
371
700
6.6
21.6
H-7
Naptha Stabilizer Heater
0.8
3
0.03
1.1
0.08
2.9
80
20
16.8
55
61
24
371
700
2.2
7.2
H-8
No. 4 Rerun Unit Heater
5.0
20
0.21
7.5
0.54
19.0
510
135
21.9
72
107
42
371
700
4.8
15.8
H-9
No. 3 Crude Unit Heater
13.0
51.4
0.55
19.2
1.40
49.0
1320
348
25.0
82
168
66
371
700
5.0
16.5
—
B & W Steam Boiler
5.0
20
0.21
7.5
0.56
19.5
510
135
10.7
35
91
36
204
400
5.5
18.2
—
No. 1 Llewellyn Steam Boiler
1.8
7
0.07
2.6
0.19
6.7
180
47
24.4
80
109
43
204
400
1.3
4.4
—
No. 2 Llewellyn Steam Boiler
1.8
7
0.07
2.6
0.19
6.7
180
47
24.4
80
109
43
204
400
1.3
4.4
--
No. 3 Bigelow Steam Boiler
3.5
13.7
0.15
5.1
0.38
13.5
350
93
9.1
30
61
24
204
400
8.7
28.4
--
No. 4 Bigelow Steam Boiler
3.5
13.7
0.15
5.1
0.38
13.5
350
93
9.1
30
61
24
204
400
OD
-»4
28.4
t All Boilers and Heaters can be fired with refinery fuel gas, natural gas or low sulfur fuel oil. Data in columns indicate
fuel usage if fired by that fuel alone.
o~>
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7
None of the heaters or boilers at this refinery have been equipped
with emission control devices. None of these units have stack gas
opacity monitors or alarms.
Sulfur oxide emissions from these units are controlled by limiting
the amount of sulfur which can be contained in the fuels burned. Refinery
fuel gas and natural gas must contain less than 1.1 gm/m (50 grains/
100 ft ) of sulfur compounds. Fuel oil must contain less than 0.5%
sulfur by weight.
Golden Eagle processes sweet Alaskan crudes and does not require
sulfur removal processes to meet fuel sulfur content requirements. The
resulting refinery fuel gases contain approximately 0.02 gm/m (1 grain/
100 ft ) of sulfur. Fuel oils produced from these crudes contain approxi-
mately 0.25% sulfur by weight. Natural gas purchased from Southern
3 3
California Gas routinely contains 0.005 gm/m (0.2 grains/100 ft ).
Internal Combustion Engines
There is only one stationary internal combustion engine at this
refinery. It is a diesel unit used to drive a fire water pump and,
hence, is only activated during emergencies or during inspections.
There are no emission control devices on this engine.
Storage Tanks
There are forty-nine storage tanks at this facility ranging in size
3
from 7 to 12,700 m (43 to 80,000 bbl) and used to store a variety of
materials. Since some of these compounds are volatile, hydrocarbon
vapors may escape from these tanks. Where such a potential exists,
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8
the materials are stored in specially constructed tanks, such as pressure
vessels and floating roof tanks, or are stored in tanks which are hard
piped by manifolds to a vapor recovery and disposal system.
The vapor recovery/disposal system consists of a piping network
serving twenty-one hydrocarbon storage tanks, a conservation sphere, a
compressor, and a ground level flare. Vapors evolved from the storage
tanks are stored in the sphere which has a flexible neoprene membrane.
The sphere thus floats on the line with the diurnal variations in vapor
evolution maintaining a slight positive pressure on the system.
Should the membrane become fully extended and the sphere become
full, a switch activates the compressor. Vapors are then withdrawn from
the sphere and manifold system and exhausted to the ground level flare.
The flare unit is a ground level rectangular unit with an estimated
rated capacity of 12.6 x 10^ kg cal (50 X 10^ Btu)/hour. The unit is
estimated to be able to handle approximately 1.2 m. tons (1.3 tons)/hour
of hydrocarbon. The flare has a pilot light which is operated on
refinery fuel gas.
A summary of the storage tanks at this facility, their configuration
and the materials stored within is presented in Appendix C.
Blowdown Systems
The major process units have safety relief valves set at 2.5
2
kg/cm (35 psi) release pressure. These valves are connected to a
common manifold system which leads to a liquid knockout drum and ultimately
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9
to the ground level flare system discussed above. Should an emergency
arise, the process unit would vent through the header system to the
flare.
Product Loading Racks
Golden Eagle has two 4-arm loading racks which can be used to load
gasoline, JP-4 and JP-5 jet fuels, diesel fuel and crude oil. These
racks are under a valid LAAPCD permit to operate. The units are in-
active and there are no plans to operate them in the near future. All
products are currently shipped from the refinery by pipeline.
The loading racks are tied into the same vapor recovery system that
services the tank farm area.
Wastewater Treatment Facilities
Wastewater from these refining operations amounts to approximately
250 m /day (0.06 mgd) and results from boiler blowdown and process
drainage. All wastewater at the refinery passes through an oil/water
separator which is covered to prevent vapor losses. Skimmed oil from
the separator is sent to slop storage and eventually reprocessed. The
skimmed wastewater receives additional treatment with a 14% hypochlorite
solution to control sulfides before being discharged to the Los Angeles
County Sanitation District sewer system.
EMISSIONS DATA
Source Test Data
Both Golden Eagle and the LAAPCD were requested to supply copies of
all stack tests conducted at the facility since 1972. No source test
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10
data was received from either group so it is assumed that no tests have
been run during this period.
Computed Emission Rates
Theoretical emission factors for various 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 Heaters. As can be seen from the listing of
process heaters and steam boilers presented in Table 1, all of these
units can be fired with natural gas, refinery fuel gas, or low sulfur
fuel oil. The AP-42 emission factors vary, depending on whether gaseous
fuels or fuel oils are used to fire the units. Therefore, a range of
theoretical emissions can exist depending on the available fuel situation.
Under normal operating conditions, Golden Eagle would use 2/3 refinery
fuel gas and 1/3 natural gas for fuel. When natural gas is curtailed,
the 1/3 of the heat requirement normally supplied by natural gas would
be supplied by fuel oil. Table 2 summarizes the theoretical emissions
from all boilers and heaters under these two conditions. Heating values
3
for the various fuels used in these calculations are 23,800 kg cal/m
(2,680 Btu/ft^) for refinery fuel gas, 9,340 kg cal/m^ (1,050 Btu/ft^)
for natural gas, and 9,800 kg cal/1 (148,000 Btu/gal) for fuel oil.
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Table 2
CALCULATED EMISSION RATES FROM VARIOUS UNIT OPERATIONS
Golden Eagle Refining Company, Inc. - Carson, California
Calculated Emissions
Emission Sources Particulates Sulfur OxidesfSOg) Carbon Monoxide (CO) Hydrocarbons Nitrogen Oxides (NOj) Aldehydes Ammonia
(kg/hr)(1b/hr) (kg/hr) (lb/hr) (kg/hr) (lb/hr) {kg/hr)(1b/hr) (kg/hr) (lb/hr) (kg/hr)(1b/hr)(kg/hrJ(TB/hr)
Process Heaters and
Steam Boilers
V
1.1 2.5
Neg.
Neg.
1.7
3.8
13.1
28.8 '
0.2 0.4
Neg.
2tt
5.0 11.1
9.1
20
Neg.
1.6
3.4
21.5
47.2
**
o
CM
o
Neg.
Slowdown Systems
with flaring
Neg.
Neg.
Neg.
1.5
3.3
Neg.
Neg.
Neg.
Wastewater
Treatment
Neg.
Neg.
Neg.
0.2
0.5
Neg.
Neg.
Neg.
Pipeline Valves
and Flanges
Neg.
Neg.
Neg.
8.5
18.7
Neg.
Neg.
Neg.
Vessel Relief
Valves
Neg.
Neg.
Neg.
3.3
7.3
Neg.
Neg.
Neg.
Pump Seals
Neg.
Neg.
Neg.
5.2
11.3
Neg.
Neg.
Neg.
Compressor Seals
Neg.
Neg.
Neg.
1.5
3.3
Neg.
Neg.
Neg.
Miscellaneous
Neg.
Neg.
Neg.
3.0
6.7
Neg.
Neg.
Neg.
Totalt++
5.0 11.1
9.1
20
Neg.
24.8
54.5
21.5
47.2
0.2 0.4
Neg.
t All units operated at rated capacity and all units fired with refinery fuel gae or natural gas.
tt All units operated at rated capacity, natural gas supply curtailedt and 1/3 of Btu required supplied by oil. All other
Btu input refinery fuel gas.
ttt Total includes only situation 2 for process heaters and boilers. Considered worst situation.
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12
Nitrogen oxides are the main pollutant emitted from the process
heaters and steam boilers. Calculated emission rates for this pollutant
range from 13.1 to 21.5 kg (28.8 to 47.2 lb)/hr depending on the fuel
use pattern.
Other Sources. Table 2 also summarizes the calculated theoretical
emissions from other sources within the refinery. The largest of these
sources appears to be leakage from pipeline valves and flanges which
amounts to 8.5 kg (18.7 lb)/hr.
SUMMARY OF VIOLATIONS
A review of the LAAPCD records indicates that no recent citations
have been issued to Golden Eagle for violations of the Rules and Regulations.
FUTURE EXPANSION PLANS
3
Golden Eagle has completed a preliminary design for a 6,500 m
(41,000 bbl)/day major expansion and up-grading at this refinery. The
expansion, which is due to go on-line in 1979, will be designed to
process Alaskan North Slope crude oil. Approximately 75% of the product
from this expansion will be gasoline.
New units included in the design are an atmospheric crude unit, a
vacuum crude unit, a unicracker, a power former unit, a hydrofiner unit,
a DGA treating system, a hydrogen plant, a new flare, and a sulfur
recovery plant with tail gas treatment. New storage tanks required for
this expansion include two 79,500 m (500,000 gal) crude tanks, two
31,800 m3 (200,000 gal) regular gas tanks, and two 15,900 m3 (100,000
gal) premium gas tanks. This entire expansion is subject to New Source
Review by the EPA. The new process heaters and the new storage tanks
are subject to the EPA New Source Performance Standards.
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i3
Golden Eagle has submitted an Environmental Impact Review Report on
this expansion to the City of Carson, the LAAPCD, the State of California
Air Resources Board (ARB), and the USEPA. The City of Carson is the
lead group for the review/approval process.
INSPECTION SUMMARY
At the time of this inspection, all major units were in operation.
All process units, storage vessels, potential pollution 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. The ground level flare also
appeared to be operating correctly.
General housekeeping at this facility appeared to be very good.
The main process areas were neat with no noticeable spills, leaks, etc.
All equipment is operating under a valid LAAPCD permit.
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APPENDIX A
NEIC Information Request Letter to
Golden Eagle Refining Company, Inc.
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tNVlRONMENTAL 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 v/ould
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,
"72t_ /°.
Thomas P. Gallagher
Director
Attachments
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Refinery Capacity in Barrels/Day
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:
Rated capacity in gals/hr or 10^ bbl/hr.
b. Heating value in BTU's/gal.
c. Pef cent sulfur and ash in oil by wt.
d. Specific gravity of oil.
e. Firing pattern (atomization, etc. for furnaces).
4. For gas fired units:
a. Rated capacity in 10"* SCF/hr.
b. Type of gas burned (list principal constituents in 7» 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).
Incinerators: (For each incinerator)
1, Rated capacity in 10^ BTU's/hr; include auxiliary burners
separately.
2. Auxiliary burner fuels:
oil - 10~ 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 efficiency(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).
!6. 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 - 10^ 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).
A. 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 (% 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 10^ 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.
4. 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).
-------
-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 we'ight.
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.
4. 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.
-------
APPENDIX B
Select LAAPCD Rules and Regulations
-------
APPENDIX B
County of Los Angeles
Air Pollution Control District
-------
IV
Prohibitions
-------
Rule 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.
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.
Rule 52., Particulate Matter - Concentration.
(Effective January 6, 1972 for any equipment not completed and put
Into service. Effective for all 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 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.
-------
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.
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
-------
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 equip-
ment this amendment shall be effective on July 1, 1972.
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 nqt apply to:
a. The burning of sulfur, hydrogen sulfide, acid sludge or other
sulfur*compounds 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.
-------
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.
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.
Rule 62.2 Sulfur Contents of Fuels.
Notwithstanding the provisions of Section (f) of Rule 62 or any pro-
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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
VA gallons of any photochemically reactive solvent, as defined in Rule 66(k),
or of any material containing more than V/i gallons of any such photochemi-
cally reactive solvent by any means which will permit the evaporation of
such solvent into the atmosphere.
.Rule 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
-------
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.
Rule 70. Asphalt Air Blowing.
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 at) other equipment
this rule shall be elfective on July 1, 1972.
Rule 71. Carbon Monoxide.
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
-------
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 is 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.
Rule 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.
-------
APPENDIX C
Storage Tank Listing
-------
TANK }
501
502
503
1001
1002
1003
100 u
1005
1006
1013
lOlfc
1015
1507
1508
STORAGE VESSELS
1 Of''3
GOLDEN EAGLE REFINING CO., INC.
TYPE OP STORAGE CAPACITY
TAjJX (THOUSANDS 07 BBLS)
AVERAGE
VAPOR TANK HAS PRESSURE
STORED PRESSURE TANK SUBMERGED TIGHT
MATERIAL psla DIAMETER FULL PIPE? VESSEL?
TYPE OP DATE
VAPOR EMISSION TANK INSTALLED
CONTROL DEVICE TEMPERATURE OR MODIFIED
Avg. Max.
Fixed
.5
Empty
11'-0"
Yes
No
Conservation Vent
1952
No
Fixed
•5
Empty
11'-0"
Yes
No
Conservation Vent
1952
No
Fixed
• 5
Fuel Oil
1.9
ll'-O"
Yes
No
Conservation Vent
150
180
1952
No
Fixed
1.0
Diesel
.25
21'-6"
Yes
No
Conservation Vent
70
80
19^5
Bo
Fixed
1.0
Diesel
.25
21'-6"
Yes
No
Conservation Vent
70
80
19^5
No
Fixed
Vapor
with
Recovery
1.0
Kerosene
.3
21'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
19^5
No
Fixed
Vapor
with
P.ecovery
1.0
Kerosene
.3
21'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
19^5
No
Fixed
Vapor
with
Recovery
lJo
Spent
Caustic
-0-
21*-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
19»*5
No
Fixed
Vapor
with
Recovery
1.0
Empty
21'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
19^5
No
Fixed
Vepor
with
recovery
1.0
Slop Oil
•5
21'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
19U5
No
Fi>ed
Vepor
with
recovery
1.0
Naphtha &
Kerosene
.5
21'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
19^5
No
Fi*ed
with
Vapor
recovery
1.0
Naphtha &
.5
21'-6"
Yes
Connected to
Kerosene
vapor recovery
Vapor recovery
70
80
19^5
No
Fixed
with
Vapor
recovery
1.5
Naphtha 1,
.7
26'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
1952
No
Fixed
Vapor
with
recovery
1.5
Naphtha 1.7
26'-6"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
1952
No
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TANK N
1509
1510
1511
1512
202k
2026
2027
5010
5011
5012
10005
10018
10019
20001
STORAGE VESSELS
GOLDEN EAGLE REFINING CO., ISC.
TYPE OF
TANK
AVERAGE
VAPOR
STORAGE CAPACITY STORED PRESSURE TANK
(THOUSANDS OF BBLS) MATERIAL psia DIAMETER
TANK HAS
SUBMERGED
FULL PIPE?
PRESSURE
TIGHT
VESSEL?
TYPE OF
VAPOR EMISSION
CONTROL DEVICE
TANK
TEMPERATURE
Avg. Max.
Fixed
vapor
vith
recovery
1.5
Diesel
.25
21'-6"
Yea
Connected to
vapor recovery
Vapor recovery
70
80
Fixed
vepor
with
recovery
1.5
Diesel
.25
21*-6"
Yea
Connected to
vapor recovery
Vapor recovery
70
80
Fixed
v6por
vi th
recovery
1.5
Diesel
.25
21*-6"
Yea
Connected to
vapor recovery
Vapor recovery
70
80
Fixed
vspor
with
recovery
1.5
Dieael
.25
21*-6" *
Yea
Connected to
vapor recovery
Vapor recovery
70
80
Fixed
2.0
Crude
1.1
30'-0"
Yes
No
Conservation Vent
70
80
Fixed
2.0
Crude
1.1
2k'-0"
Yes
No
Conservation Vent
70
80
Fixed
2.0
Crude
1.1
2l»'-0"
Yea
No
Conservation Vent
70
80
Fixed
5.0
Mater
37'-6"
Yea
No
None
70
80
Fixed
5.0
Fuel Oil
1.9
38'-6"
Yea
No
Conservation Vent
150
180
Fixed
5.0
Fuel Oil
1.9
37'-0"
Yea
No
Conservation Vent
150
180
Fixed
10.0
Water
5U'-6"
Yes
No
70
80
Fixed
Vepor
vith
recovery
10.0
Diesel
.25
55'-0"
Yea
Connected to
vapor recovery
Vepor recovery
70
,80
Fixed
Vapor
vith
recovery
10.0
Naphtha
1.7
55'-0"
Yea
Connected to
vapor recovery
Vapor recovery
70
80
Floating roof
20.0
Naphtha
1.7
60'-0"
YeB
Floating roof
Floating roof
70
80
Floating roof
20.0
Empty
60'-0"
Yea
Floating roof
Floating roof
70
80
Fixed
30.0
Fuel Oil
1.9
8V-0"
Yes
No
Conservation Vent
150
180
-------
TASK N
55001
55002
55003
550OU
55005
80010
80011
80012
80011»
80015
80016
80020
STORAGE VESSELS
GOLDEN EAGLE REFINING CO., INC.
AVERAGE
VAPOR TANK HAS PRESSURE TYPE OF
TYPE OP STORAGE CAPACITY STORED PRESSURE
TAXK (THOUSANDS OF BBLS) MATERIAL psia
TANK
DIAMETER
SUBMERGED
FULL PIPE?
TIGHT
VESSEL?
VAPOR EMISSION
CONTROL DEVICE
TANK.
TEMPERATURE
Avg.
nax.
Fixed vith
vapor recovery
55.0
Crude
3.0
115'-0"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
Fixed with
vapor recovery
55.0
Crude
3.0
115*-0"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
Floating roof
55.0
Crude
3.0
100'-0"
Yes
Floating roof
Floating roof
70
80
Fixed
55.0
Fuel Oil
1.9
10O'-O"
Yes
No
Conservation Vent
150
180
Fixed
55.0
Fuel Oil
1.9
100'-0"
Yes
No
Conservation Vent
150
180
Fixed with
vepor recovery
80.0
JP-U
1.7
119'-0"
Yes
Connected to
vapor recovery
Vapor recovery
70
80
Fixed with
vapor recovery
80.0
JP-U
1.7
119'-0"
Yea
Connected to
vepor recovery
Vapor recovery
70
80
Fixed
80.0
Fuel Oil
1.9
119'-0"
Yes
No
Conservation Vent
150
180
Floeting roof
80.0
Naphtha
.9
120'-0"
Yes
Floating roof
Floating roof
70
80
Fixed with
v&por recovery
80.0
Fuel Oil
1.9
117'-0"
Yes
Connected to
vapor recovery
Vapor recovery
150
180
Fixed with
vapor recovery
80.0
Fuel Oil
1.9
117'-0"
Yes
Connected to
vepor recovery
Vapor recovery
150
180
Fixed
80.0
Fuel Oil
1.9
119'-0"
Yes
No
Conservation Vent
150
180
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GOLDEN EAGLE REFINING COMPANY, INC.
Carson, California
SUMMARY AND CONCLUSIONS
3
Golden Eagle Refining Company, Inc. operates a 2,500 m (16,000
bbl)/SD simple crude oil refinery. Sweet Alaskan crudes are processed,
as are purchased napthas. Atmospheric distillation and fractionation
and naptha stabilization are the only processes conducted at this facility.
The main products resulting from these operations include jet fuels,
diesel fuel, and low sulfur fuel oil.
On October 16, 1975, NEIC conducted an air pollution related in-
spection at this facility. Substantial amounts of process and air
pollution control equipment information were requested of, and received
from, Golden Eagle. 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 Golden
Eagle. Theoretical emission rates were calculated for various refinery
operations using approved USEPA emission factors.
The following conclusions were derived from the inspection and
information obtained:
1. No visible emissions were noted from any of the process heaters
or steam boilers. The ground level flare also appeared to be
operating correctly.
2. General housekeeping at the refinery appeared to be very good.
-------
3. All equipment at the refinery is operating under a valid
LAAPCD permit.
4. At the time of this inspection, there were no apparent
violations of any of the LAAPCD rules.
5. There is no source test data available on any of the potential
emission sources.
6. There have been no recent violation notices issued to Golden
Eagle by the LAAPCD.
RECOMMENDATION
The EPA Region IX should be aware of Golden Eagle's new expansion
plans. The proposed new process heaters and storage vessels are subject
to the New Source Performance Standards. The entire new facilities are
subject to New Source Review.
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