ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
EPA 330/2-76-013
REPORT OH
State Implementation Plan
Air Pollution Inspection
°f
Douglas Oil Company
LOS ANGELES COUNTY, CALIFORNIA
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER
DENVER, COLORADO
AND
REGION IX. SAN FRANCISCO, CALIFORNIA
J""**
I \
FEBRUARY 1976
+*	

-------
ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
STATE IMPLEMENTATION PLAN
INSPECTION OF
DOUGLAS OIL COMPANY OF CALIFORNIA
14708 Downey Avenue
P.O. Box 198
Paramount, California 90723
213/531-2060
September 22, 1975
February 1976
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER - Denver, Colorado
and
REGION IX - San Francisco, California

-------
CONTENTS
INTRODUCTION 	 1
PROCESS DESCRIPTION 	 3
POTENTIAL AIR EMISSION SOURCES
AND RELATED CONTROL EQUIPMENT . 3
EMISSION DATA	13
SUMMARY OF PAST VIOLATIONS .... 16
INSPECTION SUMMARY 	 17
APPENDIX
A	NEIC REQUEST LETTER
B	LAAPCD RULES
C	STORAGE TANK LISTING
D	VAPOR RECOVERY SYSTEMS
E	SULFUR PLANT DETAILS
iii

-------
INTRODUCTION
Background
Douglas Oil Company of California (Douglas) operates a petroleum
refinery at this location with a rated capacity of from 6,360 to 7,160
O
m (40,000 to 45,000 bbl)/day. Average refinery capacity is 6,680
3
m (42,000 bbl)/day. The refinery processes heavy crude oils from
California (approximately 25% Wilmington and 25% Ventura), Arabia (20%),
and Bolivia or Indonesia (30%). This refinery also finishes napthas and
other condensates produced at a second Douglas refinery at Santa Maria,
California. Finished products from the Paramount, California refinery
include gasoline, JP-4 and JP-5 jet fuels, diesel fuel, low sulfur fuel
oil and various grades of asphalt.
The Douglas refinery employs 120 people and operates three 8-hour
shifts per day, 7 days a week, year around.
On September 22, 1975, a process inspection was conducted at this
facility by NEIC personnel. The inspection was preceded by a letter to
the Company [Appendix A] on September 8, 1975, announcing NEIC's inten-
tion to inspect the facility and requesting substantial amounts of
process and source information. Subsequent to the inspection, Douglas
personnel mailed NEIC the requested information.
»
During the inspection, an examination was made of the manufacturing
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.

-------
2
Company personnel were very cooperative during this inspection.
They supplied all EPA requested information during the inspection in-
terview or by subsequent letter.
Inspection Participants
Mr. H. E. McFarlin-Chief Engineer, Douglas
Mr. J. J. Lusardi-Senior Engineer, Douglas
Mr. R. M. Robinson, Coordinator Environmental Conservation,
Conoco Oil Company, Houston, Texas
Mr. Raak Veblen, State of California Air Resources Board (ARB)
Mr. Royce R. Haley, Los Angeles County Air Pollution Control
District (LAAPCD)
Mr. Lloyd Kostow, USEPA, Region IX
Dr. Wayne C. Smith, 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) [details in
Appendix B] are applicable to the State Implementation Plan for this
facility.


Rule
50.
Ringelmann Chart
Rule
51.
Nuisance
Rule
53.
Sulfur Compounds-Concentration
Rule
53.2
Sulfur Recovery Units
Rule
56.
Storage of Petroleum Products
Rule
59.
t
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
Rule
69.
Vacuum Producing devices or Systems
Rule
70.
Asphalt Air Blowing
Rule
71.
Carbon Monoxide
Rule
72.
Pumps and Compressors
Rule
73.
Safety Pressure Relief Valves

-------
3
PROCESS DESCRIPTION
The major processes at the Douglas refinery are crude desalting,
atmospheric distillation, vacuum distillation, catalytic reforming, dis-
tillate hydrotreating, gas/oil desulfurization, naptha desulfurization,
asphalt blowing, and sulfur recovery. A simplified process block flow
diagram for the facility is shown in Figure 1. Table 1 lists the unit
capacities for each of these processes.
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 re-
leases would result in loss of product. The process heaters attendant
to these units and the steam boilers constitute the main emission sources.
There are also 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 evapora-
tive losses from storage tanks and process wastewater drains. Potential
sources of emissions and their related control equipment are discussed
herein.
Process Heaters and Boilers
There are twenty-two process heaters and four steam boilers at this
refinery, ranging in size from 0.3 x 106 kg cal (1.3 x 106 Btu)/hr to
10.6 x 10^ kg cal (42 x 10^ Btu)/hr. A complete listing of these units
is presented in Table 2.
The majority of these units can utilize natural gas or refinery
fuel gas and/or fuel oil as fuel. The remainder are fueled with na-
tural gas or fuel gas only. The fuel oil is a low sulfur variety

-------
To Fuel Gas
	>
0)
3
P
CJ
o
to
rj
C
u E
•H p
a o
^ u
c.
cr o
O T3
E S
u u
< O
Naptha
Naptha
HDS *
4
Reformer
H2S to Sulfur Plant
	>-
4
Reformate
Kerosene
Dist.
HDS*
Distillate
Stripper
Naptha
Kerosene
Diesel
Residuum
HC + Inerts ,
To A/B
Incinerator**
Mixed Gas Oil
e
E
3
«—t
o
o
e
3 CJ
3 T3
(J 3
O V-
> CJ
Heavy Gas Oil
Diesel
Gas Oil
To Blending,
and
Gasoline,
JP-A,
JP-5,
Sales
To Sales
* HDS
** A/B
= Hydrodesulfurization
0 Asphalt Blowing
\ x
FIGURE 1
SIMPLIFIED PROCESS DIAGRAM
DOUGLAS OIL COMPANY OF CALIFORNIA
PARAMOUNT, CALIFORNIA
Vacuum Residuum
"V To Asphalt Plant

-------
5
Table 1
PROCESS UNITS AND RATED CAPACITIES
Douglas Oil Company of California - Paramount, California
Capacity
Process Unit
(m /SD)+
(bbl/SD)
No. 1 Crude Unit
No. 2 Crude Unit
Catalytic Reformer
Distillate Hydrodesulfurizing
Gas/Oil Hydrodesulfurizing
Naptha Hydrodesulfurizing
Asphalt Blowing
Claus Sulfur Plant
Unit No. 1
Unit No. 2
3,580
3,580
1,910
1,270
1,590
1,910
160
25 m tons/day
7 m tons/day
22,500
22,500
12,000
8,000
10,000
12,000
1,000
25 tons (1 )/day
7 tons (l)/day
2
t SD = Stream DAy; All units are m /SD or bbl/SD unless noted.

-------
TABLE 2
PROCESS HEATERS, BOILERS, AND INCINERATORS
Douglas Oil Company of California. - Paramount, California
Stack	Estimated
Rated Capacity Fuel Gas Fuel Oil Stack Cross Section	Stack	Stack
Heat Absorber/hr Usage per hr Usage per hr Height Area	Temp	Velocity
Unit No. Identification 106 kg cal 106Btu 103m3 103 ft3 liters gals m ft in^ ft? °C °F	m/sec ft/sec
H-l
Asphalt Oxidizing Plant Heater
1.3
5
0.24
8.5
210
55
22
72
0.46
4.9
416
780
4.0
13
H-2
Asphalt Oxidizing Plant Heater
1.3
5
0.24
8.5
210
55
22
72
0.46
4.9
416
780
4.0
13
H-l 01
Naptha Desulf. Charge Heater*
4.7
18.8
0.86
30.4
None
10
34
1.00
11
482
900
7.0
23
H-l 02
No.2 Crude Unit Vacuum Heater
5.2
20.5
0.80
28.4
695
183
20
67
0.52
5.6
416
780
5.5
18
H-301
Gas Oil Desulf. Rerun Tower Htr.
* 6.8
27
1.14
40.3
None
15
48
1.9
20
504
940
5.5
18
H-302
Gas Oil Desulf.Charge Heater+
3.8
15
0.63
22.4
None
15
50
0.4
4
482
900
7.3
24
H-303
Reformer Charge Heater*
7.1
28.3
1.30
45.8
None
16
51
2.2
24
343
650
4.0
13
H-304
Reformer Charge Heater*
7.1
28.3
1.30
45.8
None
16
51
2.2
24
324
615
4.0
13
H-305
Reformer No.l Intermed. Heater*
4.8
19.0
1.05
36.9
None
14
47
1.9
20
346
655
4.0
13
H-306
Reformer No.2 Intermed. Heater*
3.5
13.7
0.75
26.6
None
14
47
1.42
15.3
354
670
3.7
12
H-452
SCOT Unit Charge Heater
0.3
1.3
0.06
2.2
None
6
20
0.07
0.8
260
500
13
43
H-501/
H-502
Distillate Hydrotreater
Charge/Reboiler Heater
5.3
21
0.82
29
None
15
50
0.89
9.6
349
660
6.4
21
H-601
No.2 Crude Unit Charge Heater
9.6
37.9
1.49
52.6
1280
338
24
80
1.82
19.6
399
750
5.8
19
H-701
Asphalt Loading Heater
2.8
11
0.53
18.8
460
121
20
66
0.46
4.9
399
750
8.2
27
H-702
Asphalt Loading Heater
2.8
11
0.53
18.8
460
121
20
66
0.46
4.9
399
750
8.2
27
H-703
Asphalt 81 end. & Loading Heater
1.8
7
0.34
12
290
77
12
38
0.7
7
399
750
3.7
12
H-704
Asphalt Blend. & Loading Heater
2.8
11
0.53
18.8
460
121
12
40
0.7
7
399
750
5.8
19
H-705
Asphalt Blend. & Loading Heater
2.8
11
0.53
18.8
460
121
12
40
0.7
7
399
750
5.8
19
H-801
No.l Crude Unit,
Flash Tower Reboiler
5.0
20
0.90
31.7
775
204
18
60
1.0
11
416
780
6.4
21
H-802
No.l Crude Unit,
Fuel Tower Charge Heater
10.1
40.2
1.54
54.5
1330
350
29
96
2.21
23.8
416
780
5.2
17
H-805
No.l Crude Unit Vacuum Tower
Charge Heater
5.0
20
0.90
31.7
270
71
20
65
1.0
11
416
780
6.4
21
H-860
Depentarnzer Reboiler
3.0
12
0.54
19
465
122
14
45
0.55
5.9
399
750
7.0
23
No. 6
Steam Boiler
7.4
29.4
1.42
50.3
1230
323
8
25
0.81
8.7
316
600
1.2
4
No. 7
Steam Boiler
7.4
29.4
1.42
50.3
1230
323
8
25
0.81
8.7
316
600
1.2
4
No. 8
Steam Boiler
7.4
29.4
1.42
50.3
1230
323
8
25
0.81
8.7
316
600
1.2
4
No. 9
Steam Boiler
10.6
42
1.90
66.7
1630
429
8
25
0.81
8.7
260
500
1.2
4
+ Unit receives predominantly natural gae.

-------
7
produced at the refinery with sulfur content of <0.5% and a heating
value of 9300 kg cal/liter (140,000 Btu/gal). The refinery fuel gas
produced from the refinery operations has a heat content of 235 kg
3	3
cal/m (930 Btu/scf) and a sulfur content of approximately 0.2 gm/m
(10 grains/100 scf). Natural gas purchased from the Southern California
Gas Company has a heating value of 260 kg cal/m (1030 Btu/scf) and a
O
sulfur content of 0.2 gm/m (10 grains/100 scf). Natural gas accounts
for 30-50% of the gas burned at this facility.
The refinery fuel gas and natural gas piping at the refinery are
such that certain heaters and boilers receive predominately fuel gas
while others receive mostly natural gas. Table 2 indicates which units
receive natural gas or fuel gas.
Douglas is on an interruptible natural gas supply. During inter-
ruption periods, those units which can utilize fuel oil are operated in
this mode. During 1975, the natural gas interruption frequency was ap-
proximately 8% of the time.
Since the process heaters and steam boilers are operated on natural
gas, refinery fuel 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 be desulfurized to less than 1.1 gm/m (50
grains per 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
There are three stationary internal combustion engines at this

-------
8
refinery. Table 3 summarizes the available information on these units.
Only unit C-120, the hydrogen recycle compressor engine, is used daily.
The other two units are for emergency use only. None of the internal
combustion engines have emission control equipment.
TABLE 3
STATIONARY INTERNAL COMBUSTION ENGINES
Douglas Oil Company of California - Paramount3 Calif'omnia
Engine Designation
C-120
E-704
E-800
Function
H. P.
Fuel Type
Daily Fuel Consumed
Hydrogen Recycle
Compressor
880
Nat. Gas
(1050 Btu/cf)
207.1 x 103 ft3
Spare Fire Water
Pump
300
Nat. Gas
(1050 Btu/cf)
None-Normal!y
Emergency
Generator
180
Diesel
(32°API)
None-Normally
Storage Tanks
There are 105 storage tanks at this facility, ranging in size from
32 to 24,000 m3 (200 to 150,000 bbl), used to store a wide variety of
hydrocarbon materials. Since some of these compounds are volatile,
hydrocarbon vapors may escape from these tanks. Where such a potential
exists, the materials are stored in specially constructed tanks, such as
pressure vessels and floating roof tanks.
A summary of the storage tanks at this refinery, their configura-
tion, and the materials stored within is presented in Appendix C.
Blowdown Systems
All major process units have emergency relief valves which are con-
nected to a manifolded header system. If it becomes necessary to rapidly

-------
9
release quantities of liquids and gases from a unit, they are routed to
the manifold system and ultimately combusted in a flare unit.
The flare is a John Zink Company Model STF-S18 unit with a rated
capacity of 23,000 kg (50,000 lb)/hr of hydrocarbon. The flare is 30.5 m
(100 ft) high with a tip diameter of 0.5 m (1.5 ft). The flare incor-
porates pilot burners with an ignition flame front generator. It also
has a steam ring with steam jets.
Asphalt Air Blowing
Off-gases from the asphalt air blowing operations are treated in
four scrubber units, from which they are routed to a fume incinerator.
The incinerator is a Douglas designed unit and incorporates a Leahy
combination oil and gas burner. It is refinery fuel gas fired with low
sulfur fuel oil as standby fuel. The incinerator has an estimated heat
release of 5 x 10^ kg cal (2 x 10^ Btu)/hr. It is estimated that
approximately 1,900 kg (4200 lb)/hr of inerts and 41 kg (90 lb)/hr of
hydrocarbon vapors are fed to the incinerator from the asphalt air
blowing operations. In addition, the incinerator receives approximately
455 kg (1,000 lb)/hr of inerts and hydrocarbon vapors from the vacuum
jets attendant to the vacuum crude distillation units.
The incinerator exhaust stack is 16 m (51 ft) high and has a cross
2	2
sectional area of 1.2 m (12.6 ft ),. Estimated exhaust gas velocity is
3 m (10 ft)/sec and gas temperature is 650 °C (1,200 °F).
Vacuum Jets
The only vacuum jets at this refinery are attendant to vacuum crude
distillation units No. 1 and 2. Both jet systems ultimately discharge
to the asphalt blowing fume incinerator discussed above.

-------
10
Product Loading Racks
Gasoline, diesel fuel, low sulfur fuel oil and various asphalt pro-
ducts are loaded from loading racks into trucks and rail cars for ship-
ment to customers. Since hydrocarbon vapors may evolve from these
loading operations, the loading racks are equipped with vapor recovery
systems.
There are four separate, but similar, vapor recovery systems in the
asphalt loading area. The product fill pipes are equipped with vapor
collection hoods and vacuum piping. Vapors which escape from the truck
or tank car during filling are captured by the hoods and routed via the
vacuum piping to a manifold system and ultimately to the emission control
device.
The four emission control devices are Brink's glass fiber mat mist
eliminators manufactured by Monsanto Envirochem Systems, Inc. Typical
details for such a unit are presented in Appendix D. The manufacturer
claims that these devices will collect essentially 100% of all mist
particles larger than 3 microns and 99.5% of all other particles. No
claim is made as to the collection efficiency of gaseous hydrocarbon
emi ssions.
The gasoline truck loading rack is equipped with a Rheem Superior
vapor recovery system. The gasoline loading pipes are equipped with
tight fitting neoprene seals and vacuum piping. Vapors evolving from the
truck during a filling operation are captured by the vacuum piping and
routed to equipment which essentially saturates the vapors by counter-
current scrubbing with gasoline liquid and then condenses the saturated
vapors. Details of this system are presented in Appendix D. The manu-
facturer claims the system has a 92.9% recovery efficiency with a
capacity of 2.8 std m^ (100 scf)/min of gasoline vapors.

-------
11
Wastewater Treatment Farilit.ip<;
Douglas' wastewater discharges amount to approximately 720 m3
(190,000 gal)/day. Sources of process wastewater include; 1) water
which settles in storage tanks, 2) desalter water, 3) cooling tower
blowdown, 4) quench water from asphalt air blowing, 5) water col-
lected in the flare knockout drum, 6) water produced in sulfur re-
covery plant, 7) water collected in salt filter, and 8) water
collected in process vessels such as vacuum overhead accumulators, sep-
arator drums, and reflux drums.
Sulfides in the sour water streams are removed by steam stripping
and ultimately converted to sulfur at the sulfur plant. Sulfides re-
maining in the wastewater are converted to thiosulfate by adding hydro-
gen peroxide to the wastewater at the oil/water separator traps.
All wastewater passes through oil/water separators before being
discharged to the Los Angeles County Sanitation District sewer system.
Oil which is skimmed off at these units is returned to slop storage
tanks and is ultimately reprocessed. There are two oil/water separators
at this facility. The separator in the hydroprocessing area has a
floating cover to minimize hydrocarbon emissions. Currently, the other
separator is not covered, but plans have been made to do so during 1976.
Sulfur Plant
Sour gases from the naptha, distillate, and gas/oil hydrodesul-
furizing units are processed in di-isopropanolamine (DIPA) absorption
units where they are scrubbed with "lean" amine solution. The hydrogen
sulfide (H2S) is selectively absorbed in the solution and removed from
the gas stream. The cleansed gases are then introduced into the re-
finery fuel gas system.

-------
12
The ^S is stripped from the -"rich" amine solution and recovered as
a concentrated gas stream. The resulting "lean" solution is recycled to
the sour gas absorbers mentioned above. The concentrated H^S stream is
used as a feed stock to the sulfur recovery plant.
Sour water which resuTts from several refinery processes is another
source of ^S. The sour water is steam stripped in stripping towers and
the resulting is used as feed stock to the sulfur recovery plant.
Douglas recovers elemental sulfur with two 3-stage Claus sulfur
plants, the larger unit rated at 25 m tons (25 long tons)/day of ele-
mental sulfur and the smaller at 7 m tons (7 long tons)/day. Normal
refinery operations necessitate that only the larger Claus unit be on
stream, with the second unit held in reserve. A schematic diagram of a
typical Claus plant is presented in Appendix E.
In the Claus process, H2S is burned to form sulfur dioxide (S02).
The SO^ and H^S react in the presence of a bauxite catalyst to form
elemental sulfur and water vapor. Typical sulfur recovery efficiencies
for Claus plants are 85% for one catalytic stage, 94% for two stages,
and 97% for three stages.
The tail gases (i.e. exhaust emissions) from the Claus plants con-
tain H^S in excess of the concentrations allowable under LAAPCD Rule
53.2. In the past, it was commonplace in the industry to burn the tail
gases in an incinerator unit thus converting the H2S to S02- However,
the resulting S02 emissions were well in excess of the 500 ppmv allow-
able under the current requirements of Rule 53.2. To meet the new
requirements, Douglas has installed a Shell Claus off-gas treating
(SCOT) tail gas treatment system.
A diagram of the SCOT process is presented in Appendix E. In the
SCOT process, tail gases from the Claus plants are routed to a cobalt/
molybdenum catalyst reactor where all sulfur compounds and free sulfur

-------
13
are completely converted to in the presence of a reducing gas. From
the reactor section, the tail gases contain less than 100 ppmv of car-
bonyl sulfide (COS) and carbon disulfide (CS2) and less than 10 ppmv of
SO^. These tail gases are then cooled, and excess water is condensed
and sent to sour water stripping.
The cooled tail gases contain 20,000 to 40,000 ppmv of H2S. The
I^S is removed from the gas stream by scrubbing with di-isopropanolamine
(DIPA) solution in an absorption column. The f^S-rich DIPA solution is
regenerated by stripping the H2S in a conventional steam stripping
column. The concentrated stream is recycled as feed to the first
stage of the Claus units. The lean DIPA solution is recycled back to
the H^S absorption column.
Off-gases from the DIPA absorption column contain less than 300
ppmv H2S (vendor guarantee). These off-gases are burned in a SCOT
incinerator which has a single John Zink fuel gas burner rated at
6	6
1.3 x 10 kg cal (5 x 10 Btu)/hr heat release. The incinerator, using
natural gas as an auxiliary fuel, burns material at a rate of 810 kg
(1,777 lb)/hr and a tail gas flow rate of 3,680 std. m3 (130,000 scf)/hr.
The incinerator has a stack height of 18.3 m (60 ft) and a stack cross
2 2
sectional area of 0.37 m (4 ft ). The stack gas temperature is 870 °C
(1600 °F) and the gas velocity is 11 m (36 ft)/sec.
EMISSIONS DATA
Source Test Data
NEIC personnel requested that Douglas supply copies of all stack
tests conducted at the facility since 1972. The LAAPCD was requested
to do likewise. The only data obtained was from a stack test conducted
on the SCOT unit incinerator by KVB Engineering, Inc., under contract to
the State of California Air Resources Board. The test was conducted on
June 25, 1975.

-------
14
During the test period, the H2S gas feed rate to the Claus-SCOT
process was 12,200 std. m3 (430,000 scf) per day with a H2S content of
89.4%. Sulfur production rate was approximately 16 m tons (16 long
tons)/ day. The incinerator stack gas volume was 80 std. pi3 (2840
scf)/min. Stack gas contained 12% oxygen, 10.7% water vapor, 3 ppmv
sulfur trioxide (S03) and 104 ppmv sulfur dioxide (S02). Total sulfur
in the stack gas amounted to 17.7 kg (39 lbs)/day as elemental sulfur.
The Claus-SCOT complex was thus demonstrated to be 99.9% efficient
during the test.
Computed Emission Rates
Theoretical emission 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 Heaters. As can be seen from the listing of
process heaters and steam boilers in Table 2, a substantial number of
these units can be fired with both .fuel gas and fuel oil. Theoretical
emissions from these units are calculated using different factors for
each fuel type used. It can be seen that a range of emissions can exist
depending on the available fuel situation. Table 4 summarizes the
theoretical emissions for two possible situations: 1) all units in
operation and all units operating on refinery fuel gas or purchased
natural gas where applicable and 2) all units in operation and natural
gas is curtailed so that fuel oil is being used in those units which can
use fuel oil. For these calculations, the fuel usage figures for the

-------
Table 4
CALCULATED EMISSION RATES FROM VARIOUS UNIT OPERATIONS
Douglas Oil of California - Paramount, California Refinery
	^	CALCULATED EMISSIONS			
Particulates Sulfur Oxides (SO2) Carbon Monoxide (CO) Hydrocarbons Nitrogen Oxides (NOj) Aldehydes Ammonia
Emission Source	(kg/hr)(lb/hr) (kg/hr) (lb/hr)	(kg/hr) (lb/hr) (kg/hr)(lb/hr) (kg/hr) (lb/hr) (kg/hr)(1b/hr)(kg/hr)(lb/hr)
Process Heaters and
Steam Boilers
Condition 1+
7.4 16.4
1
2.3
Neg.
11.2
24.6
85.
.6 188
1.1 2.5
Neg.
Condition 2T+
32.8 72.1
122
269
Neg.
8.5
18.7
131
289
1.2 2.7
Neg.
Stationary Internal
Combustion Engines
Neg.
0.01
0.02
Neg.
4.7
10.3
3.
.5 7.8
O
O
iO
0.8 1.7
Blowdown Systems
with Flaring
Neg.

Neg.
Neg.
4.0
8.8

Neg.
Neg.
Neg.
Wastewater Treatment
Neg.

Neg.
Neg.
0.7
1.5

Neg.
Neg.
Neg.
Pipeline Valves & Flanges
Neg.

Neg.
Neg.
22
49

Neg.
Neg.
Neg.
Vessel Relief Valves
Neg.

Neg.
Neg.
8.8
19.3

Neg.
Neg.
Neg.
Pump Seals
Neg.

Neg.
Neg.
13.5
30

Neg.
Neg.
Neg.
Compressor Seals
Neg.

Neg.
Neg.
4.0
8.8

Neg.
Neg.
Neg.
Miscellaneous
Neg.

Neg.
Neg.
8.0
17.5

Neg.
Neg.
Neg.
Total s"1"1"1"
32.8 72.1
122
269
Neg.
74.2
163.9
135
297
1.6 3.6
r%.
CO
0
tAll unite operating at rated capacity and all units are fired with refinery fuel gas or natural gas.
ft All units operating at rated capacity, natural gas supply curtailed, and those units which can burn fuel oil are doing so.
All other units burning refinery fuel gas.
ttt Totals include only condition (2) for process heaters and boilers. Considered worst situation.
en

-------
16
units were those supplied by Douglas as rated unit capacities. Also,
all units at the refinery were considered to be operating and at rated
capacity, thereby yielding 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 85.6 to 131 kg (188
to 289 lb)/hr as NOg. If the refinery is on natural gas curtailment,
these units are also potential large sources of particulate matter,
32.8 kg (72.11b)/hr and sulfur oxides 122 kg (269 lb)/hr as SC^-
Other Sources. Table 4 summarizes the calculated theoretical emis-
sion 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 22 kg (49 lb)/hr.
SUMMARY OF VIOLATIONS
A review of the LAAPCD records indicates that a citation was
issued to Douglas on June 13, 1975 for visible emissions and nuisance
caused by emissions of excessive sulfur oxides from the incinerator unit
attendant to the sulfur plant. The disposition of this citation is not
known.
LAAPCD personnel also verbally informed NEIC personnel that a
second citation was issued to Douglas on August 18, 1975, again for a
nuisance violation. The details pertaining to this citation and its
final disposition are also unknown.

-------
17
INSPECTION SUMMARY
At the time of this inspection, all major process units were in
operation, except the SCOT tail gas treatment unit at the sulfur plant
which had been taken out of service because of continuing malfunctions.
The Claus unit tail gas exhausts were being routed directly to the SCOT
incinerator unit, bypassing the SCOT tailgas treatment system. No
sulfur based odors were detected in this area.
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 process
heaters, steam boilers or incinerators. The flare system also appeared
to be operating correctly.
NEIC personnel climbed atop several tanks at this facility to in-
spect vents, floating roofs, etc. Moderate to strong asphalt odors were
noted near the vents of asphalt storage tanks. Asphalts are stored at
temperatures of from 120° to 205 °C (250-400 °F) which undoubtedly
contributes to the odors detected.
Truck loading of hot asphalt was observed at loading station No.
13. White fumes were observed escaping from the truck loading ports.
The vapor recovery system serving this loading station was only par-
tially effective. It appeared that insufficient vacuum was available at
the vapor collection hood.
In general, housekeeping at this facility was about average for the
industry. No major leaks or spill areas were noted throughout the
inspection.

-------
APPENDIX A
NEIC Information Request Letter to
Douglas Oil Company of California

-------
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 Allied Chemical Corp. operations to
ascertain compliance with the Federally approved California State
Implementation Plan.
Representatives from the Environmental Protection Agency will
Observe the facility's process oDerations, 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 concerninq this
visit.
Sincerely,
7?_ /°
Thomas P. Gallagher
Director
Attachments'

-------
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.
c.	Firing pattern (atomization, etc. for furnaces).
4.	For gas fired units:
a.	Rated capacity in lCp 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).
5. 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 - 1(P bbl/hr and specific gravity,
gas - 10"* SCF/hr and density in lb/SCF.
other - (describe) - lbs/hr (Heating value of each fuel).

-------
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).
16.	Exit velocity of each stack effluent (ft/sec.).
17.	Temperature of effluent gas stream from each stack in °F.
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.

-------
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.	Blowdovm 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 106 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 10J 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) .

-------
-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.
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
adoo

-------
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

-------
equipment not then completed and put into service. As to all other equip-
ment this amendment shall be effective on January 1, 1973.
Table For Rule 52
Volume Discharged-
Maximum Concentra-
Volume Discharged-
Maximum Concentra
Cubic Feet Per Minute
tion of Particulate Mat-
Cubic Feet Per Minute
tion of Particulate Mat
Calculated as Dry Gas
ter Allowed in Dis-
Calculated as Dry Gas
ter Allowed in Dis-
at Standard Conditions charged Gas-Grams Per
at Standard Conditions
chared Gas Grains Per

Cubic Foot of Dry Gas

Cubic Foot of Dry Gas

at Standard Conditions

at Standard Conditions
1000 or less
0.200
20000
0.0635
1200
.187
30000
.0544
1400
.176
40000
.0487
1600
.167
50000
.0447
1800
.160
60000
.0417
2000
.153
70000
.0393
2500
.141
80000
.0374
3000
.131
100000
.0343
3500
.124
200000
.0263
4000
.118
400000
.0202
5000
.108
600000
.0173
6000
.101
800000
.0155
7000
.0949
1000000
.0142
8000
.0902
1500000
.0122
10000
.0828
2000000
.0109
15000
.0709
2500000 or more .0100
Rule 53. Sulfur Compounds - Concentration.
A person shall not discharge into the atmosphere sulfur compounds,
which would exist as a liquid or gas at standard conditions, exceeding in
concentration at the point of discharge, 0.2 per cent by volume calculated
as sulfur dioxide (SO2).
Rule 53.1 Scavenger Plants.
Where a separate source of air pollution is a scavenger or recovery

-------
plant, recovering pollutants which would otherwise be emitted to the atmos-
phere, the Air Pollution Control Officer may grant a permit to operate
where the total emission cf pollutants is substantially less with the plant in
operation than when closed, even though the concentration exceeds that
permitted by Rule 53(a). The Air Pollution Control Officer shall report
immediately in writing to the Air Pollution Control Board the granting of
any such permit, together with the facts and reasons therefor.
Effective July 1, 1973, this Rule is repealed for sulfur recovery units.
Effective January 1, 1974, this Rule is repealed for sulfuric acid units.
Rule 53.2. Sulfur Recovery Units.
A person shall not, after June 30, 1973, discharge into the atmosphere
from any sulfur recovery unit producing elemental sulfur, effluent process
gas containing more than:
1.	500 parts per million by volume of sulfur compounds calculated
as sulfur dioxide.
2.	10 parts per million by volume of hydrogen sulfide.
3.	200 pounds per hour of sulfur compounds calculated as sulfur
dioxide.
Any sulfur recovery unit having an effluent process gas discharge con-
taining less than 10 pounds per hour of sulfur compounds calculated as sul-
fur dioxide may dilute to meet the provision of number (1) above.
Rule 53.3. Sulfuric Acid Units.
A person shall not, after December 31, 1973, discharge into the atmos-
phere from any sulfuric acid unit, effluent process gas containing more than:
1.	500 parts per million by volume of sulfur compounds calculated
as sulfur dioxide.
2.	200 pounds per hour of sulfur compounds calculated as sulfur
dioxide.

-------
Rule 54. Solid Particulate Matter - Weight.
(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
solid particulate matter, including lead and lead compounds, in excess of
the rate shown in the following table: (See Rule 54 Table)
TABLE FOR RULE 54
(Amended January 6. 1972)
Process Weight
Maximum Discharge
Process Weight
Maximum Discharge
Per Hour-
Rate Allowed for Solid
Per Hour-
Rate Allowed for Solid
Pounds Per Hour
Particulate Matter
Pounds Per Hour
Particulate Matter

(Aggregate Discharged

(Aggregate Discharged

From All Points of

From All Points of

Processl-Pounds

Processl-Pounds

Per Hour

Per Hour
250 or less
1.00
12000
10.4
300
1.12
14000
10.8
350
1.23
16000
11.2
400
1.34
18000
11.5
450
1.44
20000
11.8
500
1.54
25000
12.4
600
1.73
30000
13.0
700
1.90
35000
13.5
800
2.07
40000
13.9
900
2.22
45000
14.3
1000
2.38
50000
14.7
1200
2.66
60000
15.3
1400
2.93
70000
15.9
1600
3.19
80000
16.4
1800
3.43
90000
16.9
2000
3.66
100000
17.3
2500
4.21
120000
18.1
3000
4.72
140000
18.8
3500
5.19
160000
19.4
4000
5.64
180000
19.9
4500
6.07
200000
20.4
5000
6.49
250000
21.6
5500
6.89
300000
22.5
6000
7.27
350000
23.4
6500
7.64
400000
24.1
7000
8.00
450000
24.8
7500
8.36
500000
25.4
8000
8.70
600000
26.6
8500
9.04
700000
27.6
9000
9.36
800000
28.4
9500
9.68
900000
29.3
10000
10.00
1000000 or
more 30.0

-------
Where the process weight per hour falls between figures listed in the
table, the exact weight of permitted discharge shall be determined by linear
interpolation.
For the purposes of this rule "solid particulate matter" includes any
material which would become solid particulate matter if cooled to standard
conditions.
This amendment shall be effective on 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 January 1, 1973.
Rule 55. Exceptions.
The provisions of Rule 50 do not apply to:
a.	Smoke from fires set by or permitted by any public officer
if such fire is set or permission given in the performance of the official
duty of such officer, and such fire in the opinion of such officer is
necessary:
1.	For the purpose of the prevention of a fire hazard
which cannot be abated by any other means, or
2.	The instruction of public employees in the methods of
fighting fire.
b.	Smoke from fires set pursuant to permit on property used
for industrial purposes for the purpose of instruction of employees in
methods of fighting fire.
c.	Agricultural operations in the growing of crops, or raising of
fowls oranimals.
d.	The use of an orchard or citrus grove heater which does not
produce unconsumed solid carbonaceous matter at a rate in excess of
one(1) gram per minute.
e. The use of other equipment in agricultural operations in the
growing of crops, or raising of fowls or animals.

-------
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.
j
c.	Other equipment of equal efficiency, provided such equip-
ment is submitted to and approved by the Air Pollution Control Offi-
cer.

-------
Rule 58. Disposal of Solid and Liquid Wastes.
a.	A person shall not burn any combustible refuse in any incinerator
except in a multiple-chamber incinerator as described in Rule 2 (p), or in
equipment found by the Air Pollution Control Officer in advance of such
use to be equally effective for the purpose of air pollution control as an
approved multiple-chamber incinerator. Rule 58 (a) shall be effective in the
Los Angeles Basin on the date of its adoption, and in the Upper Santa Clara
River Valley Basin on January 1, 1972. In all other areas of Los Angeles
County, this Rule shall be effective on January 1, 1973.
b.	A person shall not discharge into the atmosphere from any incin-
erator or other equipment used to dispose of combustible refuse by burn-
ing, having design burning rates greater than 100 pounds per hour, except
as provided in subsection (d) of this rule, particulate matter in excess of 0.1
grain per cubic foot of gas calculated to 12 per cent of carbon dioxide (CO2)
at standard conditions. Any carbon dioxide (CO2) produced by combustion
of any liquid or gaseous fuels shall be excluded from the calculation to 12
per cent of carbon dioxide (CC^h
c.	A person shall not discharge into the atmosphere from any equip-
ment whatsoever, used to process combustible refuse, except as provided in
subsection (d) of this rule, particulate matter in excess of 0.1 grain per
cubic foot of gas calculated to 12 per cent of carbon dioxide (CO2) at
standard conditions. Any carbon dioxide (CO2) produced by combustion
of any liquid or gaseous fuels shall be excluded from the calculation to 12
per cent of carbon dioxide (CC>2h
d.	A person shall not discharge, into the atmosphere from any incin-
erator or other equipment used to dispose of combustible refuse by burn-
ing, having design burning rates of 100 pounds per hour or less, or for
which an application for permit is filed before Janaury 1, 1972, particulate
matter in excess of 0.3 grain per cubic foot of gas calculated to 12 per cent
of carbon dioxide (CO2) at standard conditions and shall not discharge
particles which are individually large enough to be visible while suspended
in the atmosphere. Any carbon dioxide (CO2) produced by combustion of
any liquid or gaseous fuels shall be excluded from the calculation to 12 per
cent of carbon dioxide (CO2).

-------
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 Re.d 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 edge 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.

-------
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-

-------
^ „tn Rule 62.1 or any provision of
vision of said section as '™=°jp°^	n sha„ not burn w.thm the
Subsection (2, o. Sect,on b o Ru	^ ^ ^ f ^ cQntcnt
Los Angeles Basin any liquid ,uel 0
not to exceed three	a decision, provided that an ap-
necessary for the Hear.ng oa	^ ^	wlth
plication for a variance ,s	or act of God.
this Rule is not used due to accident, strike,
Rule 63. Gasoline Specifications	$	for use
within the District as a fuel fo	unsaturat.on
coae o, the State of California ££ = ^ ^ ^ by
— tha; 7D£E — Z — 0- -—"
ASTM Method D11oy-b/l
catalYSt-	, this rule the term "gasoline" means any pe-
b. F„r the purpose »« *» '	of more than four pound,
troleum distillate having a Reid vapo p
Rule 64. Reduction of Animal Ma	^	equipment or
A PerS°n tLTredlctlon ^animal	«*<" M
r;=~ - ¦- -equ,pment
other COntar,Van|Cn8c.nerated at temperatures of not less than 1200 degrees
• a nf not less than 0.3 second, or
^^ITLch a manner determined „v the Air Pollution

-------
Control Officer to be equally, or more, effective for the purpose of air
pollution control than (a) above.
A person incinerating or processing gases, vapors or gas-entrained efflu-
ents pursuant to this rule shall provide, properly install and maintain in cali-
bration, in good working order and in operation devices, as specified in the
Authority to Construct or Permit to Operate or as specified by the Air Pol-
lution Control Officer, for indicating temperature, pressure or other operat-
ing conditions.
For the purpose of this rule, "reduction" is defined as any heated proc-
ess, including rendering, cooking, drying, dehydrating, digesting, evaporat-
ing and protein concentrating.
The provisions of this rule shall not apply to any article, machine,
equipment or other contrivance used exclusively for the processing of food
for human consumption.
Rule 65. Gasoline Loading Into Tanks.
A person shall not after January 1, 1965, load or permit the loading of
gasoline into any stationary tank with a capacity of 250 gallons or more
from any tank truck or trailer, except through a permanent submerged fill
pipe, unless such tank is equipped with a vapor loss control device as de-
scribed in Rule 56, or is a pressure tank as described in Rule 56.
The provisions of the first paragraph of this rule shall not apply to the
loading of gasoline into any tank having a capacity of less than 2,000 gallons
which was installed prior to the date of adoption of this rule nor to any
underground tank installed prior to the date of adoption of this rule where
the fill line between the fill connection and tank is offset.
Any person operating or using any gasoline tank with a capacity of
250 gallons or more installed prior to the date of adoption of this rule shall

-------
apply for a permit to operate such tank before January 1, 1965. The provi-
sions of Rule 40 shall not apply during the period between the date of adop-
tion of this rule and January 1. 1965, to any gasoline tank installed prior to
the date of adoption of this rule provided an application for permit to oper-
ate is filed before January 1, 1965.
A person shall not install any gasoline tank with a capacity of 250 gal-
lons or more unless such tank is equipped as described in the first paragraph
of this rule.
For the purpose of this rule, the term "gasoline" is defined as any pe-
troleum distillate having a Reid vapor pressure of 4 pounds or greater.
For the purpose of this rule, the term "submerged fill pipe" is defined
as any fill pipe the discharge opening of which is entirely submerged when
the liquid level is 6 inches above the bottom of the tank. Submerged fill
pipe" when applied to a tank which is loaded from the side is defined as any
fill pipe the discharge opening of which is entirely submerged when the liq-
uid level is 18 inches above the bottom of the tank.
The provisions of this rule do not apply to any stationary tank which is
used primarily for the fueling of implements of husbandry, as such vehicles
are defined in Division 16 (Section 36000, et seq.) of the Vehicle Code,
Rule 66. Organic Solvents.
a. -A person shall not discharge into the atmosphere more than 15
pounds of organic materials in any one day, nor more than 3 pounds in any
one hour, from any article, machine, equipment or other contrivance, in
which any organic solvent or any material containing organic solvent comes
into contact with flame or is baked, heat-cured or heat-polymerized, in the
presence of oxygen, unless said discharge has been reduced by at least 85 per
cent. Those portions of any series of articles, machines, equipment or other

-------
contrivances designed for processing a continuous web, strip or wire which
emit organic materials and using operations described in this section shall be
collectively subject to compliance with this section.
b. A person shall not discharge into the atmosphere more than 40
pounds of organic materials in any one day, nor more than 8 pounds in any
one hour, from any article, machine, equipment or other contrivance used
under conditions other than described in section (a), for employing or ap-
plying, any photochemically reactive solvent, as defined in section (k), or
material containing such photochemically reactive solvent, unless said dis-
charge has been reduced by at least 85 per cent. Emissions of organic ma-
terials into the atmosphere resulting from air or heated drying of products
for the first 12 hours after their removal from any article, machine, equip-
ment, or other contrivance described in this section shall be included in de-
termining compliance with this section. Emissions resulting from baking,
heat-curing, or heat-polymerizing as described in section (a) shall be exclud-
ed from determination of compliance with this section. Those portions of
any series of articles, machines, equipment or other contrivances designed
for processing a continuous web, strip or wire which emit organic materials
and using operations described in this section shall be collectively subject to
compliance with this section.
c. A person shall not, after August 31, 1974, discharge into the at-
mosphere more than 3,000 pounds of organic materials in any one day, nor
more than 450 pounds in any one hour, from any article, machine, equip-
ment or other contrivance in which any non-photochemically reactive organ-
ic solvent or any material containing such solvent is employed or applied,
unless said discharge has been reduced by at least 85 per cent. Emissions of
organic materials into the atmosphere resulting from air or heated drying of
products for the first 12 hours after their removal from any article, machine,

-------
equipment, or other contrivance described in this section shall be included
in determining compliance with this section. Emissions resulting from bak-
ing, heat-curing, or heat-polymerizing as described in section (a) shall be ex-
cluded from determination of compliance with this section. Those portions
of any series of articles, machines, equipment or other contrivances designed
for processing a continuous web, strip or wire which emit organic materiols
and using operations described in this section shall be collectively subject
to compliance with this section.
d. Emissions of organic materials to the atmosphere from the clean-
up with photochemically reactive solvent, as defined in section (k), of any
article, machine, equipment or other contrivance described in sections (a),
(b) or (c), shall be included with the other emissions of organic materials
from that article, machine, equipment or other contrivance for determining
compliance with this rule.
f.	Emissions of organic materials into the atmosphere required to be
controlled by sections (a), (b) or (c), shall be reduced by:
1.	Incineration, provided that 90 per cent or more of the car-
bon in the organic material being incinerated is oxidized to
carbon dioxide, or
2.	Adsorption, or
3.	Processing in a manner determined by the Air Pollution Con-
trol Officer to be not less effective than (1) or (2) above.
g.	A person incinerating, adsorbing, or otherwise processing organic
materials pursuant to this rule shall provide, properly install and maintain in
calibration, in good working order and in operation, devices as specified in
the authority to construct or the permit to operate, or as specified by the
Air Pollution Control Officer, for indicating temperatures, pressures, rates
of flow or other operating conditions necessary to determine the degree and

-------
effectiveness of air pollution control.
h.	Any person using organic solvents or any materials containing or-
ganic solvents shall supply the Air Pollution Control Officer, upon request
and in the manner and form prescribed by him, written evidence of the
chemical composition, physical properties and amount consumed for each
organic solvent used.
i.	The provisions of this rule shall not apply to:
1.	The manufacture of organic solvents, or the transport or
storage of organic solvents or materials containing organic
solvents.
2.	The use of equipment for which other requirements are
specified by Rules 56, 59, 61 or 65 or which are exempt
from air pollution control requirements by said rules.
3.	The spraying or other employment of insecticides, pesticides
or herbicides.
4.	The employment, application, evaporation or drying of satu-
rated halogenated hydrocarbons or perchloroethylene.
5.	The use of any material, in any article, machine, equipment
or other contrivance described in sections (a), (b), (c) or (d),
if:
(i)	. the volatile content of such material consists only of
water and organic solvents, and
(ii)	the organic solvents comprise not more than 20 per
cent of said volatile content, and
(ni) the volatile content is not photochemically reactive as
defined in section (k).
j. For the purposes of this rule, organic solvents include diluents and
thinners and are defined as organic materials which are liquids at standard

-------
conditions and which are used as dissolvers, viscosity reducers or cleaning
agents, except that such materials which exhibit a boiling point higher tlun
220°F at 0.5 millimeter mercury absolute pressure or having an equivalent
vapor pressure shall not be considered to be solvents unless exposed to tem
peratures exceeding 220°F.
k. For the purposes of this rule, a photochemically reactive solvent is
any solvent with an aggregate of more than 20 per cent of its total volume
composed of the chemical compounds classified below or which exceeds any
of the following individual percentage composition limitations, referred to
the total volume of solvent:
1.	A combination of hydrocarbons, alcohols, aldehydes, esters,
ethers or ketones having an olefinic or cyclo-olefinic type of
unsaturation: 5 per cent;
2.	A combination of aromatic compounds with eight or more
carbon atoms to the molecule except ethylbenzene. 8 per
cent;
3.	A combination of ethylbenzene, ketones having branched
hydrocarbon structures, trichloroethylene or toluene: 20 per
cent.
Whenever any organic solvent or any constituent of an organic solvent
may be classified from its chemical structure into more than one of the
above groups of organic compounds, it shall be considered as a member
of the most reactive chemical group, that is, that group having the least
allowable per cent of the total volume of solvents.
I. For the purposes of this rule, organic materials are defined as
chemical compounds of carbon excluding carbon monoxide, carbon dioxide,
carbonic acid, metallic carbides, metallic carbonates and ammonium carbon-
ate.

-------
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
V/i gallons of any photochemically reactive solvent, as defined in Rule 66(k),
or of any material containing more than 11A 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

-------
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 all other equipment
this rule shall be effective 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

-------
Paee 1.
Douglas Oil Company of California
Paramount Refinery
Tank Li91	
TANK
TyTTtTTrTCATTONT
no:I. CAP.
ni-.bi
KOI.
rr.
CONTENTS

RT.ID VAPOR
AVC .
PPXS.
MAX.
. PSXA ROOF
TYPE
FILL
NOZZLE
AIR POLLUTION
CONTROL DEVICE
TEMPERATURE °F
AVG. S".'\S.V.«.
DATE INST.
on hod.
150,001
150
140
No. 2 Gas Oil

0.1
0.1
Fixed
Submerged
None

75
95
1974
150,002
150
140
Low Sulf. dist. Fuel
Oil
0.1
0.1
Fixed
M
None

120
150
1974
125,001
125
150
Crude Oil

5
6
Floating
Submerged
Floating
Roof
82
100
1961
125,002
125
150
Light Crude Oil

5
7
Floa ting
tr
Floating
Roof
76
100
1963
100,001
100
113
Paving Asph. AR1000

0.1
0.1
Fixed
Submerged
None

210
250
1974
100,002
100
113
Paving Asph. AR4000

0.1
0.1
Fixed
If
None

210
250
1974
80,001
80
118
Crude Oil

5
6
Fixed
Submerged
None

80
100
1937
80,002
80
117
Paving Asph. AR8000

0.1
0.1
Fixed
II
None

200
250
1957
80,003
80
118
Crude Oil

5
6
Floating
II
Floating
Roof
80
100
1975
50,001
50
89
Reg. Gasoline

10.5
13.5
Floating
Submerged
Floating
Roof
82
100
1966
50,002
50
86
Jet Fuel JP5

0.2
0.3
Floa ting
tl
Floating
Roof
82
100
1958
50,003
50
90
No. 2 Gas Oil

0.1
0.1
Fixed
It
None

75
100
1970
50,004
50
90
Heavy Naphtha

2.7
3.5
Floating
II
Tloatlng
Roof
72
100
1973
50,005
50
86
Low Sulf. Fuel Oil

0.1
0.1
F ixed
tl
None

170
200
1974
50,006
50
86
Low Sulf. Disc. Fuel
Oil
0.1
0.1
Fixed
tl
None

130
150
1974
50,007
50
86
No. 2 Gas Oil

0.1
0.1
Fixed
It
None

92
100
1974
50,003
50
86
No. 2 Gas Oil

0.1
0.1
Floating
II
Floating
Roof
88
100
1974
35,001
35
80
Flux

0.1
0.1
F ixed
Both
None

210
250
1962
25,001
25
60
Reformate

10.5
13.5
Floating
Submerged
Floa ting
Roof
92
100
1966
25,002
25
60
Reformate

10.5
13.5
Floa ting
It
Tloating
Roof
90
100
1975
25,003
25
60
Light Naphtha

10.5
13.5
Tloatlng
II
Floating
Roof
80
100
1975
25,004
25
60
Heavy Naphtha

2.7
3.5
Floating
II
Floa ting
Roof
85
100
1974
25,005
25
60
Unleaded Gasoline

10.5
13.5
Floa ting
II
Floa ting
Roof
80
100
19(i6
25,006
25
60
Prem. Gasoline

10.5
13.5
Floa ting
It
Floa ting
Roof
80
100
lor,r,
25,007
25
60
Dcsulf. Auto. Diesel

0.1
0.1
F ixed
II
None

95
125
1966
25,008
25
60
Kerosene Dist.

0.5
0.6
Floating
It
Floating
Roof
86
100
1970
25,009
25
60
Kerosene Dist.

0.5
0.6
Floa ting
II
Floa ting
Roof
80
100
1970
JLL/pw
10-20-75

-------
DATE
03
1974
1974
1963
1963
1963
1961
1961
1974
1974
1958
1953
1958
1958
1966
1961
1961
1974
1950
1950
1953
1975
1960
1963
Douglas Oil Company of California
Paramount Refinery
Tank List
NfTf

RE ID VAPOR
PRCS.
.PSIA ROOF
FILL
AIR POLLUTION
TEMPERATl'RE
DTAM. FT.
CONTENTS
AVC .
tiAK.
TYPE
NOZZLE
CONTROL DEVICE
MG.
SE/\S
60
Paving Asph. AR4000
0.1
0.1
Floating
Submerged
Floating Roof
375
400
60
Paving Asph. AR1000
0.1
0.1
Fixed
II
None
350
400
60
Jet Fuel JP4
2.5
3.0
Floating
ft
Floating Roof
78
100
60
Heavy Naphtha
2.7
3.5
Floating
tl
Floating Roof
78
100
60
No. 2 Gas Oil
0.1
0.1
Fixed
It
None
115
150
48
No. 1 Gas Oil
0.1
0.1
Fixed
Submerged
None
98
125
48
No. 1 Gas Oil
0.1
0.1
Fixed
tt
None
98
125
48
No. 3 Gas Oil
0.1
0.1
Fixed
Submerged
None
185
225
60
No. 3 Gas Oil
0.1
0.1
Fixed
II
None
185
225
45
Paving Asph. AR2000
0.1
0.1
Fixed
fl
None
375
400
60
Desulf. Naphtha
2.7
3.5
Fixed
tt
None *
72
100
60
Kerosene Dist.
0.5
0.6
Fixed
tt
None
88
100
54
Kerosene Dlst.
0.5
0.6
Fixed
tt
None
88
100
39
Kerosene Dist.
0.5
0.6
Floating
It
Floating Roof
90
100
32
Vacuum Tops
0.1
0.1
Fixed
Submerged
None
92
100
32
Kerosene Dist.
0.5
0.6
Fixed
tt
None
85
100
36
Paving Asph. AR8000
0.1
0.1
Fixed
Subtne rged
None
375
400
35
Paving Asph. AR1000
0.1
0.1
Fixed
Overhead
None
250
300
35
Flux
0.1
0.1
Fixed
ii
None
225
250
36
Tlux
0.1
0.1
Fixed
Submerged
None
350
375
35
Flux
0.1
0.1
Fixed
II
None
250
275
35
Tlux
0.1
0.1
Fixed
II
None
300
325
30
Paving Asph. AR1000
0.1
0.1
Tixcd
II
None
280
300
30
Paving Asph. AR4000
0.1
0.1
Fixed
II
None
280
300
40
Slop
5
6
Fixed
Submerged
None
180
225
for Installation

-------
OR I'1
1956
1956
1974
1974
1949
1949
1949
1949
1957
1957
1950
1950
1974
1974
1951
195/
1957
1957
1957
1957
1957
1957
1962
1962
1962
19 60
1900
1960
CouglC9 Oil Company of California
Paramount Refinery
Tank List 	
NCW. RE ID VAPOR PRES. .PSIA ROOF FILL	AIR POLLUTION TEMPERATURE °F
niAM. FT. 	CONTENTS		AVG. MAX.	TYPE NOZZLE CONTROL DEVICE AVC. SE'»S.VAX.
30
Slop
5
6
Fixed
Both
None
160
200
30
Slop
5
6
Fixed
ii
None
160
200
30
Slop
5
6
Fixed
II
None
150
200
30
Slop
5
6
Fixed
It
None
150
200
24
riux
0.1
0.1
Fixed
Overhead
None
325
350
24
riux
0.1
0.1
Fixed
tl
None
350
400
24
riux
0.1
0.1
Fixed
II
None
350
400
24
Flux
0.1
0.1
Fixed
II
None
95
150
30
Saturant -
0.1
0.1
Fixed
Submerged
None
400
450
30
Saturant -
0.1
0.1
Fixed
If
None
400
450
21.5
Saturant
0.1
0.1
Fixed
Submerged
None
300
425
21.5
High Molt Asph.
0.1
0.1
Fixed
ii
None
300
425
21.5
SC Asphalt
0.1
0.1
Fixed
tt
None
180
225
21.5
SC Asphalt
0.1
0.1
Fixed
tt
None
180
225
21.5
Asph. Cutback Spec.
0.1
0.1
Fixed
Overhead
None
80
120
18
Specialty Apsh.
0.1
0.1
Fixed
Submerged
None
250
375
21.5
Asph. Emulsion
0.1
0.1
Fixed
II
None
100
150
21.5
Asph. Emulsion
0.1
0.1
Fixed
tl
None
100
150
21.5
Paving Asph. AR4000
0.1
0.1
Fixed
ri
None
250
275
21.5
Asph. Emulsion
0.1
0.1
Fixed
tt
None
100
150
21.5
Asph. Emulsion
0.1
0.1
T lxed
tt
None
100
150
21.5
Asph. Emulsion
0.1
0.1
Fixed
ii
None
100
150
21.5
Asph, Emulsion
0.1
0.1
Fixed
ii
None
100
150
21.5
Asph. Emulsion
0.1
0.1
Fixed
ii
None
100
150
21.5
Asph. Emulsion Base
0.1
0.1
Fixed
ii
None
100
150
24
Rosin


Fixed
Submerged
None
70
90
16
Wax Emulsion Base Stock
0.1
0.1
Tixed
tl
Hone
150
200
15
Wax
0.1
0.1
Fixed
If
None
300
375

-------
no;i. cap.
nrbi
xat.
PtAM. FT.
CONTENTS
Douglas Oil Company of California
Paranount Refinery
Tank List
REID VAPOR PRKS..PSIA ROOF
AVG . >'AX.	TYPE
751
.75
9
Pesulf. Naphtha
2.7
3.5
752
.75
9
Posulf. Naphtha
2.7
3.5
507
.5
15
Specialty Asph.
0.1
0.1
508
.5
15
Asph. Cutback Spec.
0.1
0.1
509
.5
15
Out of Service
	
	
510
.5
15
Out of Service
	
	
511
.5
15
Asph. Emulsion
0.1
0.1
512
.5
15
Asph. Emulsion
0.1
0.1
513
.5
15
Asph. Emulsion
0.1
0.1
514
.5
15
Paving Asph. AR1000
0.1
0.1
515
.5
15
Wax Emulsion Base Stock
0.1
0.1
516
.5
13
Purch. Solvents
2.5
3.5
201
.2
10
Asph. Emulsion
0.1
0.1
202
.2
10
Water Make-up
	
	
203
.2
10
Water Make-up
	
	
204
.2
10
Out of Service
	

205
.2
10
Out of Service
	
	
205
.2
10
Out of Service
	
	
207
.2
10
Out of Service
	
	
208
.2
10
Out of Service
	
	
209
.2
10
Asph. Emulsion
0.1
0.1
210
.2
10
Asph. Emulsion
0.1
0.1
211
.2
10
Asph. Cutback Spec.
0.1
0.1
212
.2
8
Asph. Cutback Spec.
0.1
0.1
213
.2
8
Asph. Mastics
0.1
0.1
Horiz.Pres.
Horiz.Pres.
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
Fixed
FILL	AIR POLLUTION
NOZZLE	CONTROL DEVICE
Submerged	Pressure Vessel
"	Pressure Vessel
Submerged	None
Overhead	None
Submerged	None
"	None
"	None
"	None
"	None
"	None
"	None
"	None
Submerged	None
"	None
"	None
"	None
"	None
"	None
"	None
"	None
"	None
V	None
"	None
"	None
"	None
TE?!PERATl'RE OF
AVG. SrAS.*
-------
APPENDIX D
Vapor Recovery Syst
-------
Wow!: n
Env/iroJ
nChsm
BRINK SYSTEMS
St. Louis, Missouri
P.;,.:'
Do0\\. LO.
Vaa? Ks
J.\.
W-Tl-V
~-l

w-»cr»f*io»*
BRINK MI-5T EUM\N\TO
^.v'5~Virc5L-
po.'-to^o
—;nc-
\
\v \
1 >¦/ \
X
^^o
V.D.I.-.-

V
;r^-.
*— -t i
-Jr-T. :[
\
X
^'\(X
=5D-
O'JT
0\'H> 6'..OVj
\\ w
t~>o0
pi.AM V\E.VJ
3

^ o.* i: '.o..
. .' 'eC^VlET		
. i *SH,f?TOS 	>
'0.
"i I
Ji !
Vc-.^
PDI ^
V^'c.'.r.o
bni-vc c-uf/e.j i"
1' I CP
• »jC
j
il v Qa s>
IM-
1 ••' V*
	M uolc r
! |
"fT
I 3	'
.1
T!Ofio I! |
feu
i_. .A
>•
	fl v
—->L i0-' ~
Out
- i/a -. --
V«" £ P '"O"
1 v 1' '- E - 'n'j
C/ r Tic3cv; r
w/ri AT l''iS c'3
• 3! fe ^/fi
^ Gdup.CG,
r i CO^OT'.^T
\ Ovsar'-O.'/
\ Da mm .
-A-" 1
-y	
. v-iriv v ¦
' i	\ "
|\ \-.i cc.-jp r. r
1 C'-LAI-l Ck'T
f Tawu'
-------
rhi:i:m CJJ1L RIPI* v \t'CR Ri;covrRy svsTryi
The installation of a piL-ntoJ RHCh.M SUPFPJOR \ APOR Ri.CP\ LM
SYSTEM at jour gasoline loading teirmnl will:
1.	Recover gasoline va^jis nnd corvert thani back into c.asoi.tu'*,
a salable product nonwal!} lost into t! c air.
2.	Substantially reduce air pollution.
3.	Increase safety factor of installation by reducing fire haxaitl.
4.	Greatlv reduce loading time inasmuch as one loadei can load
several compartments simultaneously usinj the automatic s.iut
off devices incorporated in the \ apor recovery lonc.ing ai.1^
and meters.
5.	Impi'o\e operating conditions for pjrsonr.fi, since vapor? pre
elimir/ited.
b. itrprove cnviiuinne.iL Iul ilic co..t.iiui'ntj.
process riPTro^:
The operation of the RIIl.'EM SL'l'IiRiOl V.iPOR M.COVL'RY f>Y.VfEM
can bo fc-llnvcd by ieferi.n:\ to Dm*, .-.i:; No. D-TO-JilO-lOOJ..
When oasohr.es aie loaded into tarl.	rail cars, or bariv\apoib
will cvo]vi duo to c vjpia:.o:i to as i-.'ch as thi;^ poi t :"t hu'.iv-
carbo:i. Th'S percei.ti-c: is c^ponden" on tiic- type of fuc!, U*i *;vi ituro,
and the vapor prebP'.ic of the- fuel. T/.cse \ apori arc collcctcJ wi bpet.al
loading arms imd cor'h'Cteci to the process unit.
In the mtorort of .s ifet\ , your unit is protected h\ ? ' SUPERIOR' m'mc
flaiii:-; arre.-tor n>ourt?u near liio srt¦.¦ .*ir>r. "I'll--" v itjjosp of ti,1. ratL'K-ioi
is to intuit* a uniform composition c>f h.1 drocai :;t-'' ill air v.hich is bu05 l.ip-
tially b!k»vO the combj&tiblc l'Pius. lo," mxt-rcs of -nsohrc. At ro pc»"il
In the* s\r,icm is th-- composition an c .rlosivc ni^t. re. I'oi t! ir> ic*:",on
all vaj>ors aro conducted !liiso..^li llu ,>atui\i'.or a\d ll'^i'-o to I1 * xa^o;
holder.
-------
At the instant that loadipi; starts a iela\ is cnei^i ed uhich auUvnat'calh
starts P-l and P-2 i imps which Circulate .qnsohne tr.rough the s.n. i.ilor.
The other parts of tue pl.n t ma\ r.ol be in operation as thej aie actuated
independently b\ the qaantih of \apors n the vapor holdei.
The \apor holder is a necessary part of the equipment 111 tl;at it senes to
allow stcacU operation 01 the entire 1.11:t. Coivotcasor, pu\i;>-, anci coa-
trols are al! coi";"tiblc arcl o; orate l.iost efhcieialy in stcaclj opt'iatiop^,
whereas the loading operation is interniitept.
The vapor holder is provided vith :• diaphragm. The incoming, vapors arc
contained brneath ti e diaphragm. Wren this dianlua^n is ra-sed to a p:e-
deteir.vn^d level an eLctric sv itch is actuated v iuch energi/.cs tlu starter
of the P-l and P-2 pi'jr.ps and compressor in sequence.
The cor.ipiessor is a tv.o sta~e operat»on with inter-coolmg bei»s, effect?;'
by the gasoh'ie circulated in the syslc-.n. Afiei-coolins is effecUjd bj an
aerial section of finrubo.
To?	rl !"i"i*v\'210 PS!G: i^ intl'Olll'CCu V. "il tlie
boiiov."> of the absorber column, ard the gasoline from the 1'-?. pur.-.p is
introduced at the to.) of tr.e sine column. The absorber cohiM'n is a
counter current Ik;•aid-?,as absorption process utilizing an wor. to. or
packing of la'alox saddle. The licjaid c^soline fib;oibs the uas">lM,c vapors
pnd t!;e ii.iris:n~ Pir is r"ij>charj;i 1 fror1 the lop oi" t'in tower tin o'.^j h a h.ic!
press are ccntrol \>il,'e fid exhaust lr^Jiler^ this air will cch ii stai'n
tion is desired to raecl the ii.divid m] situation in.ohc' for cip.irri'.'M oi>ora-
tion.	p
\\C \ b,"1 Ki;v> to submit a proli vIriai;, piojc-.1! for your spvcific ltcjai.
\ llho.it obligation.
-------
' 1 " < ' "
r . t	 		
1.1"''-..
| j
jliAV) 10 • • * fc»'A
• - >\ 1 f(\n, i )..e |
•n - . J uw 1 » zi 1
(- - - . ^ ..
li.f»v d | 0*;4 MM* .
| • t'»f ••
j •. v ...'_ ~r>". i
: i r: i
; — , ; i w i !
• 1 » ° I v**i*
! 1 i »—£^1 : .
1 1 |_u 1/ .
4* •/» j 4.4rf f,ti jCI.il' ffJIIVj
1 I \\W"K
1 •"• ' T ~"!
.1 mW I i . "W Ll»- y.^.'
1 <»/> »%>«¦* «*»<»,«. - *4 | {



H2j±vi
prry «;
-------
APPENDIX E
Sulfur Plant Details
-------
SECONDARY CONVERTER
STEAM
STEAM'
'tAIL GAS TO
INCINERATOR OR
TAIL GAS PROCESSINC
£
CONDENSERS'
WASTE HEAT-
BURNER
I—
I—
—\	1
ACID GAS FROM	
AYIXE REGEN- -
ERATOR AND SOUR
WATER STRIPPER


_ I
I—
O
LIQUID SULFUR PRODUCT
SOUR WATER
BOILER FEED WATER
AIR BLOWER
STEAM
SOUR WATER SURGE
TO TREATMENT
SULFUR TANK AND SU.V.P PUMP
Typical packaged claus plant (2 stage).
-------
sb
DOUGLAS OIL COMPANY OF CALIFORNIA
SUMMARY AND CONCLUSIONS
Douglas Oil Company of California (Douglas) operates a 6,680 m3
(42,000 bbl)/day petroleum refinery at Paramount, California. An air
pollution related inspection was conducted at Douglas by NEIC personnel
on September 22, 1975. Substantial amounts of process and air pollution
control equipment information were requested of, and received from,
Douglas. The Los Angeles County Air Pollution Control District (LAAPCD)
was requested to supply information pertaining to stack testing con-
ducted at this facility and any violation notices issued to Douglas.
The following conclusions were derived from the inspection and in-
formation obtained:
1.	Douglas has had considerable operating problems with the Claus
sulfur recovery units and the SCOT tail gas treatment unit. At
least one LAAPCD violation notice has been issued to Douglas be-
cause of visible emissions and nuisance conditions related to these
operations.
The SCOT tail gas unit was not operatinq durina this inspection
due to equipment malfunctions.
2.	The vapor collection system attendant to several asphalt load-
ing racks was not operating correctly during this inspection.
Asphalt fumes were noted escaping from one truck loading operation.
The problem appeared to be related to insufficient vacuum on the va-
por collection piping.
3.	One of the two effluent oil/water separator units at the fa-
cility does not have a covered forebay as required by LAAPCD Rule 59.
Douglas is aware of the problem and has scheduled the installation
of such a cover for early 1976.
-------
4.	Based on calculations using approved EPA emission factors,
the process heaters and boilers at this facility appear to be sig-
nificant sources of nitrogen dioxide emissions. There are no
LAAPCD regulations which apply to these units.
5.	General housekeeping at the refinery appeared to be about
average for the industry.
RECOMMENDATIONS
1.	Douglas should be required to modify the Claus and SCOT units
to ensure reliable operation.
2.	Douglas should be required to stack test the SCOT tail gas
treatment system at least once per year.
3.	Douglas should be required to improve the vapor collection system
attendant to the asphalt truck loading racks. Clogging of the vacuum
piping by build-up of condensed asphalt fumes should be investigated
as a possible source of the problems.
4.	Douglas should install a cover on the one effluent oil/water
separator which is not currently covered.
5.	Reports confirming the above modifications and stack tests
should be submitted to the Enforcement Division, LAAPCD and to the
Director, Enforcement Division, USEPA, Region IX.
-------
COOLING TOWER	ABSORBER	REGENERATOR
PACKED OR TRAY	OFF GAS TO	OFF GAS TO
FIRST STAGE
OF CLAUS UNIT
REACTOR
REDUCING
GAS —
LEAN AMINE
FROM ^	
REGENERATOR
FIXED BED
REDUCING
CATALYST
hIR 0
WATER
AMINE
REGENERATOR
TRAY TOWER
ABSORBER
LINE HEATER
L.P. .STEAM
CLAUS PLANT TAIL GAS
PRIOR TO
INCINERATOR
FUEL GAS
AIR"
"TAT AMINE
TO REGENERATOR
-SOUR WATER
CONDENSATE TO
EXISTING SOUR
HATER STRIPPER
Flow diagram for the Shell Claus off-qas treating process.
-------