ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
EPA 330/2-76-012
REPORT ON
State Implementation Plan
Air Pollution Inspection
of
Standard Oil Company
LOS ANGELES COUNTY, CALIFORNIA
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER
DENVER. COLORADO
AND
REGION IX, SAN FRANCISCO, CALIFORNIA
FEBRUARY 1976
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STANDARD OIL CO.
. EL SEGUNDO
SUMMARY AND CONCLUSIONS
Standard Oil Company operates a 36,600 m (230,000 bbl)/day in-
tegrated crude oil refinery in El Segundo, California. An air pollution
related inspection of these facilities was conducted by NEIC personnel
on November 17-18, 1975. Substantial amounts of process and air pollution
control equipment information were requested of, and received from the
Company. The Los Angeles Air Pollution Control District (LAAPCD) was
requested to supply information pertaining to stack testing conducted at
this facility and any violation notices issued to the Company.
The following conclusions were derived based on the inspection and
information obtained:
1. General housekeeping at the refinery appeared to be excellent.
2. All equipment at the refinery is operating unde.r a valid
LAAPCD permit.
3. Using EPA emission factors, the calculated emission rates from
the CO boiler ESP unit exceed the allowable rates under
LAAPCD Rule 54. Stack tests recently conducted
by the LAAPCD for Standard on this exhaust indicate
that the emissions comply with Rule 54. However, it
is not known whether these tests were conducted at
typical unit operating conditions.
4. Using EPA emission factors, the process heaters and boilers at
this facility appear to be significant sources of nitrogen
dioxide. There are no LAAPCD regulations which apply to these
units.
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RECOMMENDATIONS
1. Standard should be required to stack test the sulfur plant
tail gas treatment units at least once per year.
2. Standard should be required to stack test the existing ESP
unit at the mid-point of the turnarounds.
3. Reports of the above tests should be provided to the Enforce-
ment Division of the LAAPCD and to the Director, Enforcement
Division, USEPA, Region IX.
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ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF ENFORCEMENT
STATE IMPLEMENTATION PLAN
INSPECTION OF
STANDARD OIL COMPANY OF CALIFORNIA
EL SEGUNDO REFINERY
P.O. Box 97
El Segundo, California 90245
(213)322-3450
November 17-18, 1975
February 1976
NATIONAL ENFORCEMENT INVESTIGATIONS CENTER - Denver, Colorado
and
REGION IX - San Francisco, California
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CONTENTS
Page
INTRODUCTION 1
PROCESS DESCRIPTION 3
POTENTIAL AIR EMISSION SOURCES
AND RELATED CONTROL EQUIPMENT '3
EMISSIONS DATA 16
SUMMARY OF PAST VIOLATIONS 21
INSPECTION SUMMARY 21
APPENDIX
A NEIC REQUEST LETTER
B LAAPCD RULES
C PROCESS HEATER AND BOILER INFORMATION
D INTERNAL COMBUSTION ENGINES DATA
E STORAGE TANK LISTING
F FLARE DATA
G SOURCE TEST DATA, FCC UNIT
H SOURCE TEST DATA, SULFUR RECOVERY UNIT
I SOURCE TEST DATA, SULFURIC ACID PLANT
111
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INTRODUCTION
Background
Standard Oil Company of California, El Segundo, California, operates
an integrated petroleum refinery, at this location, with a rated capacity
o
of 36,500 m (230,000 bbl)/day of crude oil. Major products from this
refinery include jet fuels, diesel fuel, gasoline, fuel oil, petroleum
coke, liquid petroleum gas (LPG), asphalt and a variety of solvents
including benzene, toluene, and xylene (BTX).
The Standard Refinery, already the most complex in the Los Angeles
area, is constructing a new facility to produce low sulfur fuel oil.
o
This addition will raise the refinery capacity to 64,400 m (405,000
bbl)/day. The new complex is expected to start operation in mid-1976.
El Segundo Refinery employs about 1,250 people and the facility
operates three 8-hour shifts, 7 days per week, year around.
On November 17-18, 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 intention
to inspect the facility and requesting substantial amounts of process
and source information. Subsequent to the inspection, Standard personnel
transmitted the requested information by mail.
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.
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Company personnel were highly cooperative throughout this inspection.
They supplied all information EPA requested during the inspection inter-
view or by subsequent letter.
Inspection Participants
0. W. Daily - Senior Staff Specialist, Conservation
Standard Oil Company
L. R. Ray - Staff Specialist, Standard Oil Company
W. Carson - State of California Air Resources Board (ARB)
John R. Powell - Los Angeles Air Pollution Control District (LAAPCD)
Lloyd Kostow - USEPA, Region IX
Wayne C. Smith - 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 the State Implementation Plan for this
facility:
Rule SO. Ringelmann Chart
Rule 51. Nuisance
Rule 52. Particulate Matter - Concentration
Rule 53. Sulfur Compounds - Concentration
Rule S3.2 Sulfur Recovery Units
Rule 54. Solid Particulate Matter - Weight
Rule 56. Storage of Petroleum Products
Rule 59. Effluent Oil/Water Separators
Rule 61. Organic Liquid Loading
Rule 62. Sulfur Content of Fuels
Rule 67. Fuel Burning Equipment
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Pule 68. Fuel Burning Equipment - Combustion Contaminants
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 Valves
PROCESS DESCRIPTION
The Standard Refinery processes crude oil received from several
locations. Approximately 50% of the crude is received from domestic
sources (i.e., California) and the other 50% is imported. Crude oil is
delivered to the refinery by pipeline and tanker. Primary products
include LPG, gasoline, jet fuel, diesel fuel, fuel oil, petroleum coke,
ethylene, asphalt, and solvents, including benzene, toluene, and xylene
(BTX).
Major processes at this refinery include crude desalting, atmospheric
distillation, vacuum distillation, delayed coking, catalytic cracking,
hydrocracking, catalytic reforming, hydrotreating, isomerization,
alkylation, BTX production, hydrogenation, hydrogen production, asphalt
manufacturing, sulfur recovery, and sulfuric acid regeneration. 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,
as listed in The Oil and Gas Journal, April 7, 1975.
POTENTIAL SOURCES OF AIR POLLUTION EMISSIONS AND RELATED CONTROL EQUIPMENT
Although the Standard El Segundo Refinery is an extremely complex
facility, there are relatively few large discrete potential sources of
air pollutant emissions. With the exception of the fluid catalytic
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FIGURE 1
STANDARD OIL, "El Segundo Refinery
SIMPLIFIED FLOW DIAGRAM
Refinery Fuel Gas
Crude Oil
A tin.
Distillatloi
Unit
Straight Run Gasoline
Distillate
Vacuum
Distillation
Unit
Light Gas Oil
Heavy Gaa Oil
Residuum
Asphalt Unit
Reformers
Light Ends
Fractionation
Gasoline Base
Hydrotreater
Hydrocracker
Jet Fuel Stock,
HF p
Alkylation |
Fluid
Catalytic
Cracking
Unit
ISO & N
Butanes
Cat. Cast
Delayed Coker
"Jet Fuel S took
Hydrogenatlon Units
Fuel Gas
Gasoline
Jet Fuel
I.PC
To Gasoline
Blending
Catalytic Gasoline
Coke
Asphalt
"Fuel Ull
JDistillat.i
Distillate
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Table 1
PROCESS UNITS AND RATED CAPACITIES
STANDARD OIL COMPANY
EL SEGUNDO REFINERY
Process Unit
Crude Units
Vacuum Unit
Delayed Coker
Fluid Catalytic Cracking
Catalyst Reforming
Catalytic Hydrotreating
Alkylation
Aromatics/Isomerization
Asphalt
Capacity
(mW)
36,600
16,400
8,600
6,900
9,500
11,100
940
240
1,300
(bbl/SDf)
230,000
103,000
54,000
43,500
60,000
70,000
5,900
1,500
8,300
t Stream Day
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cracking (FCC) unit, the major unit processes at the refinery are closed
systems and release of materials to the atmosphere is discouraged
because such releases would results in loss of product. The process
heaters attendant to these units constitute the main emission sources.
There are also a myriad of relatively small potential sources of
emissions related to the operation of the refinery. Such sources
include leaks from valve seals, pump seals and pipe flanges, and evapora-
tive losses from storage tanks and process wastewater drains. Potential
sources of emissions and their related control equipment are discussed
below.
Process Heaters and Boilers
There are 82 process heaters and steam boilers ranging in size from
250 X 106 to 75 X 109 cal (1 X 106 to 300 X 106 Btu)/hour. A complete
listing of these units is presented in Appendix C. Two of the boilers
are used as spare equipment and 9 of the process heaters are currently
idle.
The majority of these units utilize refinery fuel gas as fuel. The
remainder can be fueled with either refinery gas or fuel oil. Except
for the carbon monoxide (CO) boiler at the FCC unit which will be dis-
cussed later, none of the process heaters or boilers are equipped with
emission control devices and none would be expected to have such equip-
ment.
Sulfur oxide emissions from these units are controlled by limiting
the sulfur content of the fuels burned. Refinery gas must be desulfur-
3 3
ized to less than 1.1 gm/m (50 grains/100 ft ) of sulfur compounds.
Fuel oil used in stationary fuel burning equipment is produced in the
refinery from low sulfur crude. The sulfur content of the fuel is less
than 0.5% by weight.
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Internal Combustion Engines
Eleven stationary internal combustion engines [Appendix D] are used
to drive compressors and use natural gas at a rate of 1,120 m (39.5 X
103 ft3)/hour. These units are all used in the vapor recovery and fuel
gas collection systems. None of the internal combustion engines have
emission control equipment and none would be expected.
Storage Tanks
3 3
The 523 storage tanks ranging in size from 14 m to 18,300 m (85
to 115,000 bbl), are used to store a wide variety of hydrocarbon materials.
Due to the volatile nature of some of these compounds, the potential
exists for substantial emissions of hydrocarbon vapors from these tanks.
Where this potential exists, the materials are stored in specially
constructed tanks, such as pressure vessels, and floating roof tanks, or
in tanks which are hard piped by manifold systems to vapor recovery
systems.
The vapor recovery system consists of a pipe network serving a
large number of hydrocarbon storage tanks, two truck loading facilities,
and several additional connections at the LPG loading racks. Vacuum is
maintained by a bank of compressors (discussed above) which discharge
into the refinery fuel gas system. Standard Oil is in the process of
changing all tanks to floating roof tanks so that the vapor recovery
system will not be needed.
A summary of the storage tanks at this facility, their configuration,
and the materials stored within is presented in Appendix E.
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8
Slowdown Systems
The majority of process units have emergency relief valves which
are connected to a manifolded header system. Should a situation arise
such that it is necessary to rapidly release quantities of liquids and
gases from a unit, they are routed to the manifold system and ultimately
combusted in a flare.
There are four flares at this refinery. One flare vents the fluid
catalytic cracker, one the delayed coker, one the isomax complex, and
one at the ammonia plant. All four flares are equipped with John Zink
Co. smokeless flare tips [Appendix F]. Most of the blowdown systems are
operated only on an as-needed basis, i.e., intermittently.
In addition to the flare blowdown system, there are two other
systems used for vapor and liquid collection.
The Rheniformer blowdown system (gasholder served by two recipro-
cating compressors) recovers both liquid and vapor hydrocarbons which
are returned to process. Hydrocarbon vapor is released to the atmosphere
less than 0.1% of the time.
The FCC unit blowdown system includes gas recovery facilities
•
(gasholder served by two reciprocating compressors) which return blow-
down vapors to the FCC process. This system recovers liquid and vapor
from various sources in the refinery. Liquids are returned to recovered
oil storage. Vapors are compressed and routed to FLS recovery, thence
to the refinery process gas system. If compressor capacity is exceeded
(estimated aggregate 2 hours/year) the gasholders blowdown tanks vent to
atmosphere.
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Vacuum Jets
Vacuum distillation columns at No. 1 crude unit and Nos. 1 and 2
vacuum distillation units are provided with 2-stage vacuum jets which
are operated by 150 psig steam. The condensate collected is injected
into the crude feed lines at No. 1 and No. 2 crude units while the non-
condensed gas is collected by the waste gas compressors and routed to
downstream treating facilities. The waste gas system recovery efficiency
is 100%.
Column C-1410 is provided with 2-stage vacuum jets which are
powered by 150 psig steam. All liquid and vapor is recovered to Crack-
ing Division blowdown system for recovery.
No barometric condensers are operated at the refinery.
Fluid Catalytic Cracking Unit
Spent catalyst from the FCC unit is continuosly removed from the
reactor portion and introduced through piping into the catalyst regenera-
tion portion. Here the petroleum coke, tars, and other residual deposits
which form on the catalyst surface are burned off the catalyst fines.
The recovered catalyst is then recycled to the reactor. Catalyst particles
which are entrained in the exhaust gases are partially captured by a
series of cyclone separators internal and external to the regenerator
unit. Particles captured by these cyclones are returned to the regenerator.
The regenerator unit exhaust gases contain considerable amounts of
carbon monoxide, particulate matter, aldehydes, sulfur oxides, ammonia,
and oxides of nitrogen. To minimize the emissions of particulates and
carbon monoxide (CO) and recover the fuel value of this material, the
regenerator exhaust gases are routed through an electrostatic precipitator
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10
(ESP) consisting of two parallel banks with four stages per bank, and
into the CO boiler where these gases are combusted. The ESP and CO
boiler were rebuilt in 1974.
The discharge stack at the CO boiler is equipped with a Lear
Seigler opacity monitor. This monitor has a recorder and alarm system
in the FCC unit control room.
The FCC unit and ESP are also served by a bypass discharge stack,
and if the CO boiler is not in operation the FCC could continue to
operate. If Standard chooses this bypass operation, except in an emergency,
they would be in violation of LAAPCD Rule 71 and would require a variance
to continue operating.
Product Loading Racks
LP gas, various grades of gasoline, solvents, jet fuel, diesel
fuel, and light and heavy distillates are all shipped from the refinery
by truck or rail car. Except for the diesel fuel and the light and
heavy distillates, all of these materials have vapor pressures greater
o
than 0.105 kg/cm (1.5 psia) at actual loading conditions. Hence, the
loading racks for these materials must be equipped with vapor recovery
systems.
The truck and rail loading racks for LP gas use an equalizing line
during loading. After the filling operation is completed, the loading
hoses are back-evacuated through the vapor recovery system.
The truck loading facilities, requiring controls per Rule 61, for
gasoline, solvent, and jet fuel loading are equipped with tight neoprene
seals for the truck hatches and vapor return lines to the main vapor
recovery system. The recovery system discharges into the refinery fuel
gas system.
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11
Vlastewater Treatment Facilities
The 22,600 m3 (5.8 X 106 gal)/day of wastewater is collected
through several covered, but venting to the atmosphere, API* oil-water
separators at various locations throughout the refinery. From the
separators, the water is treated in an air flotation unit and discharged
into the Pacific Ocean. Standard is currently building an activated
sludge unit to further treat these wastes.
There are no air pollution controls or monitors, other than the
covers, on the API separators. The LAAPCD has stated these separators
are in compliance with Rule 59.
Sulfur Plant
There are three 2-stage Claus units [Fig. 2] at the sulfur recovery
plant. Each is rated at 136 m. tons (150 tons)/SD of elemental sulfur.
Normal operations necessitate that only two units be on stream at any
time with the third unit being held in reserve.
Standard is currently constructing a fourth Claus unit to serve the
new low sulfur fuel oil facility. This unit should be on-stream by mid-
1976. The capacity of this new unit is 272 m. tons (300 tons)/day.
In the Claus process, hydrogen sulfide (hLS) is burned to form
sulfur dioxide (S02). The S02 and H2$ 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.
* American Petroleum Institute
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ACID GAS FROM
AHINE REGEN- ~
ERATOR AND SOUR
WATER STRIPPER
otr
So
SOUR WATER
SOUR WATER SURGE
TOTREATOENT
SECONDARY CONVERTER
STEAM
WASTE HEAT>
BURNER
PRIMARY CONVERTER.
^^ \
STEAM'
CONDENSERS-
f
I
r-
—i—I
h-
-l_
u.
BOILER FEED WATER
AIR BLOWER
STEAM.
Q
\ "rr^..
Figure 2
SULFUR TANK AND SUMP PUMP
Typical packaged claus plant (2 stage).
.TAIL GAS TO
INCINERATOR OR
TAIL GAS PROCESSINC
•UQUID'SULFUR pROlucT
IN3
-------
•INCINERATOR
FUEL
GAS
CLAUS
'TAIL-GAS
H.P. STEAM
B.F.
WATER-
WASTE HEAT
BOILER
QUENCH AND GAS
COOLING SECTION
RECYCLE
QUENCH WATER
SO; ABSORBER. EVAPORATOR .DISSOLVING1
.AND STEAM STRIPPING TANK
FUELAfR TO STACK
il
ACID WATER PURGE
TO NEUTRALIZATION
RECYCLE TO
CLAUS PLANT
Figure ,3 Flow diagram for the Wei I man-Lord S02 recovery process.
CO
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14
The tail-gases from the Claus unit are then processed in a Wellman-
Lord unit [Fig. 3] for further sulfur removal.
In this unit, tail-gas from the Claus sulfur units is first in-
cinerated to convert all of the sulfur compounds originally present
(H2S, COS, CS2> etc.) to S02- The hot gases are cooled in a waste heat
boiler, then quenched and fed to the S02 absorber.
The absorber is fed a lean solution of sodium sulfite which absorbs
the S02 by reacting with it to form sodium bisulfite. The clean gases
pass to the stack, while the rich bisulfite solution is fed to an
evaporator/ crystallizer regeneration system. S02 and water vapor pass
overhead from the evaporator to a condenser. A knockout drum separates
condensed water for return to the absorbent dissolving tank and the
product steam of concentrated, saturated SCL is piped back to the Claus
plant feed or to other processing.
This refinery has three absorption units, one for each Claus unit,
and only one chemical regeneration plant. It is important to note that
each of the tail gas units is designed to handle the total off-gas flow
from all three Claus plants.
Once per shift, a sample of the absorber off-gas is taken and
analyzed by a gas chromatograph (GC).
Sulfuric Acid Regeneration Plant
The major potential emission point at the sulfuric acid plant [Fig.
4] is the exhaust stack. The Lurgi double absorption process is used as an
air pollution control measure. The double absorption process achieves a
99.7% conversion of S02 to SOj. The off-gases from the second absorber
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BOILER
FEED
WATER ,
SStifr
EXCHANGER
EXCHANGER
PURIFICATION
UNIT
*r xt*
X
DRYING
TOWER
COOLER
r—
V. "
CONVERTER
WITH
INTERCOOLERS
^r
^
/
\
/
1
/
\
•>)
1
1
1
I'
1
1
^
1
^ 1* — »
>
<
ABSO
TC
RPTIO
IWER
* OLEUM
I TOWER
i
I ^ TAIL
GAS
COOLER
ACID
PRODUCTS
©INCLUDES COMBUSTION UNIT WHEN USING SLUDGE, PYRITE OR H2 S.
(A) STEAM IS GENERATED ONLY WHEN BURNING SLUDGE OR H2S.
FIGURE 4
SULFURIC ACID PLANT FLOW DIAGRAM
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16
are contacted with a small amount of low pressure steam prior to being
discharged through a Brink mist eliminator.
All sulfuric acid regenerated is used within the refinery.
Other Sources
All off-gases from the sour water strippers and oxidizers are
burned In the process heaters.
Standard produces asphalt and has blow stills on site; however, no
asphalt air blowing is currently done.
No incinerators are in operation at this refinery.
EMISSIONS DATA
Source Test Data
NEIC personnel requested that Standard supply copies of all stack
tests conducted at the facility since 1972. The LAAPCD was requested to
do likewise. The data obtained is summarized below.
FCC Unit Emissions. Standard submitted a copy of the source test
(test C-2241) conducted on the CO boiler exhaust stack attendant to the
FCC unit electrostatic precipitator (ESP). This test was conducted on
February 25, 1975 by the LAAPCD [Appendix 6]. No details are given for
the operating conditions for the FCC unit and/or the CO boiler during
the test run. It also is not possible to determine from the data
whether the test was conducted at start-of-run conditions on the FCC
unit or near the turnaround time.
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17
According to the LAAPCD test results, the total emissions from the
stack of the ESP unit amounted to 4,400 dry m3/min. (155,300 dscfm) and
a particualte emission rate of 6.9 kg (15.5 lb)/hr. The other compounds
found were 249 ppmv S02» 54 kg (119 lb)/hr NOX and 0.013% vol CO. These
test results indicate that this unit was in compliance with the LAAPCD
rules.
From July 1972 to June 1973, Standard participated in a comprehensive
study of oxides of nitrogen (N0¥) emissions from stationary sources in
A
the South Coast Air Basin. The study was conducted by KVB Engineering,
Inc. under contract to the State of California Air Resources Board
(ARB). These data are coded, and determining which come from the
Standard processes is difficult.
Process Heaters and Boilers. Exhaust gases from four process
heaters and two process steam boilers were analyzed for NOX emissions
during the previously referenced KVB Engineering, Inc. study.
Sulfur Recovery Plant. The exhaust gases from each of the three
Wellman-Lord tail-gas unit, at the sulfur recovery plant, were source
tested (test C-1895) by the LAAPCD [Appendix H] on January 10-11, 1973.
The results of these tests are summarized below.
Emissions Plant 1 Plant 2 Plant 3
62 ppmv 38 ppmv 40 ppmv
!.3 kg (5.1 lb)/hr 0.9 kg (2.0 lb)/hr 0.8 kg (1.8 lb)/hr
9.7 DDtnv
so2
so2
NO 9.7 ppmv
n
H2S <0.10 ppmv <0.4 ppmv 1.5 ppmv
CO 0.05% v 0.2% v 0.07% v
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18
At the time of these tests the sulfur recovery units were in com-
pliance with the LAAPCD rules.
Sulfuric Acid Plant The exhaust gases from the sulfuric acid plant
were source tested (test C-1920) by the LAAPCD [Appendix I] on March 21
and April 3, 1973. The March 21 test was aborted due to an upset
condition at the sulfur plant. Only S02 and S03 were tested for, and
the emissions from the discharge stack contained 120 ppmv and 9.0 kg
(20.1 lb)/hr S02 and the SOg was lower than the detectable limit. At
the time of this test the sulfuric acid regeneration plant was operating
at 240 m. tons (265 tons)/day (88% capacity). There were no violations
of LAAPCD rules during this test.
Computed Emission Rates
Theoretical emission factors for various emission sources found at
petroleum refineries are listed in Table 1.1-1 on page 1.1-3 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 emission rates in Table 2. Emissions from hydro-
carbon storage tanks have not been calculated for this report. 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 shown in Appendix C, a substantial
number of these units can be fired with both fuel gas and fuel oil.
Also, several of the units are either out of service or are on standby.
Theoretical emissions from these units are calculated using different
factors for each fuel type used. It can be seen that a wide range of
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Table 2
CALCULATED EMISSION RATES FROM VARIOUS UNIT OPERATIONS
STANDARD OIL COMPANy - EL SEGUNDO, CALIFORNIA, REFINERY
Emission Source
Calculated Emissions
Particulates
(kg/hr)(lb/hr)
Process Heaters
and Boilers
!«
Fluid Catalytic
Cracking Unit
Compressor Internal
Combustion Engines
Slowdown Systems to
Vapor Recovery or
Flares
Wastewater Treatment
Pipeline Valves
and Flanges
Vessel Relief Valves
Pump Seals
Compressor Seals
TOTALSt+t
63 140
212 470
36 80
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
248 550
Sulfur Oxides Carbon Monoxide Hydrocarbons
(S02) (CO)
(kg/hr)(lb/hr) (kg/hr)(lb/hr)
7 15
756 1 ,680
400 890
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
1.156 2,570
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
(kg/hr)(lb/hr)
95
36
180
23
23
20
122
47
72
23
555
210
80
400
50
50
45
270
105
160
50
1,210
Nitrogen Oxides
(N02)
(kg/hr)(lb/hr)
734 1 .630
725 1,610
59 130
16 35
Neg.
Neg.
Neg.
Neg.
Neg.
Neg.
799 1 ,775
Aldehydes Ammonia
(kg/hr)(lb/hr) (kg/hr)(lb/hr)
9 20 Neg.
7 15 Neg.
16 35 45
244
Neg. Neg.
Neg. Neg.
Neg. Neg.
Neg. Neg.
Neg. Neg.
Neg. Neg.
24 54 49
100
8
108
t Mode 1. All units operated and all on fuel gas
tt Mode 2. All units in refinery operated and those units which can are burning fuel oil
ttt Totals include only situation (2) for boilers and process heaters. Considered worst possible operating mode.
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20
emissions can exist, depending on the available fuel situation. Table 2
summarizes the theoretical emissions for two possible situations: 1)
all units are in operation (100% capacity) and all units are fueled with
fuel gas; and 2) all units are in operation and fuel gas is curtailed
so that fuel oil is being used in those units which can use oil, i.e.,
all operating on oil. Realizing that a wide variety of unit/fuel com-
binations exist, for this analysis, situation (1) is considered the most
frequent operating mode, and situation (2) an operating mode which is
possible but used infrequently during fuel gas curtailment. For these
calculations, the heat content of refinery fuel gas was assumed to be
9,000 cal/m3 (1,100 Btu/ft3) and that of the fuel oil to be 9,860 cal/m3
(148,000 Btu/gal).
The process heaters and boilers are major contributors of nitrogen
oxides. Depending on the fuel use pattern at the refinery, calculated
nitrogen dioxide emissions for these units range from 725 to 734 kg
(1,610 to 1,630 lb)/hr as N02- If the refinery is on fuel gas curtail-
ment, these units are also potential large sources of particulate
matter, 210 kg (470 lb)/hr and sulfur oxides, 760 kg (1,680 lb)/hr as
so2.
Fluid Catalytic Cracking Unit. Table 2 summarizes the calculated
theoretical emissions from this unit. These theoretical emissions were
also calculated using AP-42 emission factors for FCC units with attendant
CO boilers and electrostatic precipitators. The calculated value for
particulate emissions using the average emission factor value listed in
AP-42 is 36 kg (80 lb)/hr. This value is in excess of the maximum
allowable emission rate under the LAAPCD Rule 54 which is 13.5 kg (30
lb)/hr. However, it should be emphasized that the AP-42 emission factor
is an average value for the industry and that the Standard precipitator
may be more efficient than the average unit. The LAAPCD test in February
1975 indicated a much lower emission rate, well within the limitations
of Rule 54.
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21
The calculated emission rates for other pollutants from the FCC
unit indicate that substantial amounts of sulfur dioxide, hydrocarbon,
and nitrogen dioxide are emitted from this unit. The calculated theoretical
values are 400 kg (890 lb)/hr, 180 kg (400 lb)/hr and 59 kg (130 lb)/hr,
respectively.
Other Sources. Table 2 summarizes the calculated theoretical
emission rates from other sources within the refinery. In general, AP-
42 gives only hydrocarbon emission factors for these sources. The major
source appears to be leakage from pipeline valves and flanges which
amounts to 122 kg (270 lb)/hr.
SUMMARY OF VIOLATIONS
A review of the LAAPCD records indicates there have been no citations
issued to Standard since late 1973.
INSPECTION SUMMARY
At the time of this inspection, all major process units were in
operation with the exception of the sulfuric acid plant, No. 1 crude
unit. Also, only one Claus unit was operating.
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 incinerators. The flare systems also appeared to
be operating correctly.
During the physical tour of the refinery, Mr. Daily indicated that
Standard had a variance for the elemental sulfur storage tank. He
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22
stated that at times there were visible emissions from these tanks.
Standard is currently attempting to find a solution to this problem. No
visible emissions were noted during this inspection.
The GC analysis of the sulfur recovery tail gas showed that the
unit was emitting 100 ppmv S0« at the time the sample was taken.
General housekeeping at the refinery is excellent. The main process
areas were neat with no noticeable spills, leaks, etc.
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APPENDIX A
NEIC INFORMATION REQUEST LETTER TO
STANDARD OIL
-------
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 operations, inspect monitoring and
laboratory equipment and analytical methods, review source test data,
•examine appropriate records, etc. A process and air pollution flow
diagram or a blueprint of the facility and production information should
be available for the EPA personnel at the start of the inspections.
Detailed information about air pollution sources will be discussed
during these inspections. Attached is a partial list of the information
that will be needed in order to complete these inspections. We would
appreciate it if you could inform the appropriate company personnel
about the forthcoming inspections so that the necessary information will
be readily available and the inspection can be expedited.
If you have any questions concerning these inspections, please feel
free to contact Arnold Den, Chief, Air Investigations Section, Region
IX, San Francisco, at 415/556-8752.
• A representative of the EPA (Dr. Wayne Smith or Mr. David Brooman,
303/234-4658) will contact you within the next 30 days concerning this
Visit.
Sincerely,
Thomas P. Gallagher
Director
Attachments
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A. Refinery Capacity in Barrels/Day
B. Furnaces, Boilers and Process Heaters (for each furnace boiler
and heater)
1. Rated capacity in 106 BTU/hr heat Input.
2, Maximum capacity as per cent of rated capacity.
3. For oil fired units:
a; Rated capacity in gals/hr or 10^ bbl/hr.
b. Heating value in BTU's/gal.
c. Per cent sulfur and ash in oil by wt.
d. Specific gravity of oil.
e. Firing pattern (atomization, etc. for furnaces).
4. For gas fired units:
*>
a. Rated capacity in 1Q SCF/hr.
b. Type of gas burned (list principal constituents in % by
weight).
c. Density Ib/SCF.
d. Heating value of gas in BTU's/SCF.
e. Sulfur content of gas in % S by vol and grains/SCF.
5. Type(s) of control equipment and collection efficiency(s)
(design and actual).
6. Pressure drop (inches of water) across collection devices(s)
7. Elevation above grade of stack outlets and other discharge
points.
8. Identification of stacks equipped with recording monitors
for determining opacities of stack effluents.
9. Existing stack test data. The full test reports describing
methods used, test data, calculations, test results and
process weights should be available.
10. Inside diameters of each stack (ft).
11. Temperature of effluent gas stream from each stack (°F).
12. Exit velocity of each stack effluent (ft/sec).
C. Incinerators: (For each incinerator)
1. Rated capacity in 106 BTU's/hr; include auxiliary burners
separately.
2. Auxiliary burner fuels:
oil - 10~ bbl/hr and specific gravity.
gas - 103 SCF/hr and density in Ib/SCF.
other - (describe) - Ibs/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 Ib/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.
D. Catalytic Cracking Units, Coker Units: (For each unit)
1. Rated capacity - 106 BTU/hr and indicate the type of unit such
as FCC, 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 103 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. Slowdown Systems:
1. Indicate type and efficiency of each air pollution control
device.
F. Flares: (For each flare)
1. Type
2. Height and diameter of stack (ft).
3. Velocity of stack effluent (ft/sec).
4. Temperature of gas effluent (°F).
5. Rated capacity 10^ BTU/hr and tons/hr (of flared material).
6. Amount of material flared and percent of time material being
flared.
7. Maximum capacity as per cent of rated capacity.
8. Type of flare ignition device at top of stack.
9. Sulfur content of flared input (% by wt).
10. Where material comes from that is burned in flare.
G. Storage Vessels: (For each vessel)
1. Indicate type of tank (fixed roof, floating roof, vapor recovery,
etc.)
2. Give storage capacity of each tank in 1(P gallons or barrels.
3. Indicate type of material stored in each tank (crude oil, gasoline,
finished petroleum product) and give annual average true vapor
pressure (TV?) and seasonal maximum for actual storage condition
of product stored in Ibs/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).
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-4-
3. Indicate type and efficiency of each air pollution control
device and any existing test data indicating actual emissions.
Data should include the full test reports describing methods
used, test data, calculations, test results and process weight.
I. Internal Combustion Engines: (Stationary)
1. Type of engine.
2. Amount of fuel burned per day.
3. Type of fuel.
J. Vacuum Jets and/or Barometric Condensers
1. Indicate type and efficiency of each air pollution control
device.
2. Indicate disposition of exhaust gases-(eg. To afterburners,
fireboxes, etc.).
K. Loading Rack Vapor Recovery:
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 participates, sulfur dioxide, carbon monoxide,
oxides of nitrogen, and hydrocarbons not covered by Items B-L.
Include:
1. Type of process and rated capacity.
2. Type of material processed.
3. Types of collection equipment and collection efficiency(s)
(design and actual).
4. Pressure drop (inches of water) across collection devices.
5. Existing stack test data applicable to current operating
conditions. The full test reports describing methods used,
test data, calculations, test results and process weights
should be submitted.
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APPENDIX B
SELECT LAAPCD RULES AND REGULATIONS
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APPENDIX B
County of Los Angeles
Air Pollution Control District
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IV
Prohibitions
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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
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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-
Cubie Feet Per Minute
Calculated as Dry Gas
at Standard Conditions
1000 or less
1200
1400
1600
1800
2000
2500
3000
3500
4000
5000
6000
7000
8000
10000
15000
Maximum Concentra-
tion of Paniculate Mat-
ter Allowed in Dis-
charged Gas-Grains Per
Cubic Foot of Dry Gas
at Standard Conditions
0.200
.187
.176
.167
.160
.153
.141
.131
.124
.118
.108
.101
.0949
.0902
.0828
.0709
Volume Discharged-
Cubic Feet Per Minute
Calculated as Dry Gas
at Standard Conditions
20000
30000
40000
50000
60000
70000
80000
100000
200000
400000
600000
800000
Maximum Concentra-
tion of Parliculdie Mat-
ter Allowed in DIS-
chared Gas-Grams Per
Cubic Foot of Dry Gas
at Standard Conditions
0.0635
.0544
.0487
.0447
.0417
.0393
.0374
.0343
.0263
.0202
.0173
.0155
1000000 .0142
1500000 .0122
2000000 .0109
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 (SC>2).
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 of 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.
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Rule 54. Solid Paniculate 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 paniculate 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
Per Hour-
Pounds Per Hour
250 or less
300
350
400
450
500
600
700
800
900
1000
1200
1400
1600
1800
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
7000
7500
8000
8500
9000
9500
10000
Maximum Discharge
Rate Allowed for Solid
Paniculate Matter
(Aggregate Discharged
From All Points of
Processl-Pounds
Per Hour
1.00
1.12
1.23
1.34
1.44
1.54
1.73
1.90
2.07
2.22
2.38
2.66
2.93
3.19
3.43
3.66
4.21
4.72
5.19
5.64
6.07
6.49
6.89
7.27
7.64
8.00
8.36
8.70
9.04
9.36
9.68
10.00
Process Weight
Per Hour-
Pounds Per Hour
12000
14000
16000
18000
20000
25000
30000
35000
40000
45000
50000
60000
70000
80000
90000
100000
120000
140000
160000
180000
200000
250000
300000
350000
400000
450000
5000QO
600000
700000
800000
900000
1000000 or
Maximum Discharge
Rate Allowed for Solid
Particular Matter
(Aggregate Discharged
From All Points of
Processl-Pounds
Per Hour
10.4
10.8
11.2
11.5
11.8
12.4
13.0
13.5
13.9
14.3
14.7
15.3
15.9
16.4
16.9
17.3
18.1
18.8
19.4
19.9
20.4
21.6
22.5
23.4
24.1
24.8
25.4
26.6
27.6
28.4
29.3
more 30.0
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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.
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Rule 56. Storage of Petroleum Products.
A person shall not place, store or hold in any stationary tank, reser-
voir or other container of more than 40,000 gallons capacity any gasoline
or any petroleum distillate having a vapor pressure of 1.5 pounds per square
inch absolute or greater under actual storage conditions, unless such tank,
reservoir or other container is a pressure tank maintaining working pressures
sufficient at all times to prevent hydrocarbon vapor or gas loss to the atmos-
phere, or is designed and equipped with one of the following vapor loss con-
trol devices, properly installed, in good working order and in operation:
a. A floating roof, consisting of a pontoon type or double-deck
type roof, resting on the surface of the liquid contents and equipped
with a closure seal, or seals, to close the space between the roof edge
and tank wall. The control equipment provided for in this paragraph
shall not be used if the gasoline or petroleum distillate has a vapor pres-
sure of 11.0 pounds per square inch absolute or greater under actual
Storage conditions. All tank gauging and sampling devices shall be gas-
tight except when gauging or sampling is taking place.
b. A vapor recovery system, consisting of a vapor gathering sys-
tem capable of collecting the hydrocarbon vapors and gases discharged
and a vapor disposal system capable of processing such hydrocarbon
vapors and gases so as to prevent their emission to the atmosphere and
with all tank gauging and sampling devices gas-tight except when gaug-
ing or sampling is taking place.
C. Other equipment of equal efficiency, provided such equip-
ment is submitted to and approved by the Air Pollution Control Offi-
cer.
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Rule 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 (CC^)
at standard conditions. Any carbon dioxide (CC^) produced by combustion
of any liquid or gaseous fuels shall be excluded from the calculation to 12
per cent of carbon dioxide (CO2).
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 (C02) at
standard conditions. Any carbon dioxide (C02) produced by combustion
of any liquid or gaseous fuels shall be excluded from the calculation to 12
per cent of carbon dioxide (C02).
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 percent
of carbon dioxide (C02> at standard conditions and shall not discharge
x
particles which are individually large enough to be visible while suspended
in the atmosphere. Any carbon dioxide (C02) produced by combustion of
any liquid or gaseous fuels shall be excluded from the calculation to 12 per
cent of carbon dioxide (C02).
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Rule 59. Effluent Oil Water Separators.
(Effective June 29, 1971 for any equipment not completed and put
into service. Effective for all equipment after July 1, 1972)
A person shall not use any compartment of any vessel or device operat-
ed for the recovery of oil from effluent water which recovers 200 gallons a
day or more of any petroleum products from any equipment which proc-
esses, refines, stores or handles hydrocarbons with a Reid vapor pressure
of 0.5 pound or greater, unless such compartment is equipped with one of
the following vapor loss control devices, except when gauging or sampling
is taking place:
a. A solid cover with all openings sealed and totally enclosing
the liquid contents of that compartment.
b. A floating pontoon or double-deck type cover, equipped
with closure seals to enclose any space between the cover's edye and
compartment wall.
c. A vapor recovery system, which reduces the emission of all
hydrocarbon vapors and gases into the atmosphere by at least 90 per
cent by weight.
d. Other equipment of an efficiency equal to or greater than
a, b, or c, if approved by the Air Pollution Control Officer.
This rule shall not apply to any oil-effluent water separator used ex-
clusively in conjunction with the production of crude oil, if the water
fraction of the oil-water effluent entering the separator contains less than
5 parts per. million hydrogen sulfide, organic sulfides, or a combination
thereof.
This amendment shall be effective at the date of its adoption for any
equipment not then completed and put into service. As to all other equip-
ment this amendment shall be effective on July 1,1972.
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Rule 60. Circumvention.
A person shall not build, erect, install, or use any article, machine,
equipment or other contrivance, the use of which, without resulting in a
reduction in the total release of air contaminants to the atmosphere, re-
duces or conceals an emission which would otherwise constitute a violation
of Division 20, Chapter 2 of the Health and Safety Code of the State of
California or of these Rules and Regulations. This Rule shall not apply to
cases in which the only violation involved is of Section 24243 of the Health
and Safety Code of the State of California, or of Rule 51 of these Rules and
Regulations.
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 fallowing:
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
0) 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.
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C. The use of solid fuels in any metallurgical process.
d. The use of fuels where the gaseous products of combustion
are used as raw materials for other processes.
e. The use of liquid or solid fuel to propel or test any vehicle,
aircraft, missile, locomotive, boat or ship.
f. The use of liquid fuel whenever the supply of gaseous fuel,
the burning of which is permitted by this rule, is not physically avail-
able to the user due to accident, act of God, act of war, act of the
public enemy, or failure of the supplier.
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-
-------
vision of said section as incorporated into Rule 62.1 or any provision of
Subsection (2) of Section b of Rule 62.1, a person shall not burn within the
Los Angeles Basin any liquid fuel or solid fuel having a sulfur content in ex-
cess of 0.5 per cent by weight.
It shall not be a violation of this rule to burn such fuel for a period of
not to exceed three calendar days (and in addition for that period of time
necessary for the Hearing Board to render a decision, provided that an ap-
plication for a variance is promptly filed) when other fuel which complies with
this Rule is not used due to accident, strike, sabotage, or act of God.
Rule 63. Gasoline Specifications.
a. A person shall not, after June 30, 1960, sell or supply for use
within the District as a fuel for motor vehicles as defined by the Vehicle
Code of the State of California, gasoline having a degree of unsaturation
greater than that indicated by a Bromine Number of 30 as determined by
ASTM Method D1159-57T modified by omission of the mercuric chloride
catalyst.
b. For the purpose of this rule, the term "gasoline" means any pe-
troleum distillate having a Reid vapor pressure of more than four pounds.
Rule 64. Reduction of Animal Matter.
»
A person shall not operate or use any article, machine, equipment or
other contrivance for the reduction of animal matter unless all gases, vapors
and gas-entrained effluents from such an article, machine, equipment or
other contrivance are:
a. Incinerated at temperatures of not less than 1200 degrees
Fahrenheit for a period of not less than 0.3 second, or
b. Processed in such a manner determined by the Air Pollution
-------
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 photochem realty reactive solvent, as defined in section (k), or
material containing such photochemicatly 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 materials
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
(iii) the volatile content is not photochemicaliy 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 luyhcr Hum
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 tuin
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 buiJdings.
Rule 66.2 .Disposal and Evaporation of Solvents
A person shall not during any one day dispose of a total of more than
114 gallons of any photochemically reactive solvent, as defined in Rule 66(k),
or of any material containing more than VA gallons of any such photochemi-
cally reactive solvent by any means which will permit the evaporation of
such solvent into the atmosphere.
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 (S02);
2. 140 pounds per hour of nitrogen oxides, calculated as nitrogen
dioxide (N02);
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 (N02) at 3 per cent oxygen, in ex-
cess of that shown in the following table:
NITROGEN OXIDES - PARTS PER MILLION PARTS OF FLUE GAS
FUEL
Gas
Liquid or Solid
EFFECTIVE DATE
DECEMBER 31. 1971
225
325
DECEMBER 31.1974
125
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 (C02) 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 m
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
PROCESS HEATER AND BOILER INFORMATION
-------
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APPENDIX D
INTERNAL COMBUSTION ENGINES DATA
-------
(I)
STATIONARY INTERNAL COMBUSTION ENGINES
EL SEGUNDO REFINERY
Engine
Designation
K-l
K-2
K-3
K-4
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K-204
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K-1035
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122
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82
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-------
APPENDIX E
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-------
APPENDIX F
FLARE DATA
-------
FLARES
EL SECUNDO REFINERY
(F)
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
FCCU
Type Zink, Elevated
Height, Ft. 167.5
Dia (At tip), Ft. 4
Effluent Velocity, fps 330
Effluent Temp, °F. Normal 80-100
Design 275
Rating, 106 Btu/Hr. (a)
Tons/Hr. 345
Amount Flared T/Yr. N
% of Time 0.1
Max. Capy, % of Rated 100
Type Ignition Continuous
Pilot
Sulfur Content of (b)
Flared Gas
Source of Flared Gas Principally FCCU
Occasional inter-
refinery
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150
4
163
230
(a)
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270
0.1
100
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4
163
225
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N.A.
100
Continuous
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(b), usually Nil
Isomax Complex
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100
1
106
100
(a)
7.5
N.A.
100
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Nil
NH3-H2S Plant
(a) BTU of flared gas will vary widely.
(b) Sulfur content: Variable depending on source of flared gas.
-------
APPENDIX G
SOURCE TEST DATA
FCC UNIT
-------
134 SOUTH SAN PDJRO STREET. LOS ANGELES. CALIF. 90013 - MADISON- 9-^471!/ COUNTY OF LOS ANGELES
5EST
CONDUCTED. AT
STANDARD OIL COMPANY OP CALIFORNIA
VEST EL SEGUHDO BOULEVARD
EL SEGUNDO, CALIFORNIA
ON
February 25, 1975
D
APR2975LRPX
\
REPORT
ON THE
HUSSIONS PROM A CARBON MONOXIDE BOILER AND
FROM A WET SCRUBBER SERVING A FLUID
CATALYST REGENERATING UNIT
Cl r ENC"»
"
GEf'E^L KWARER
fr.i CCP* . «:
A. J. Wilson
M. A. Ballas
Supv. A. ?. Engineer II
Sr. Air Pollution Engineer
TEAM NO. 4
SOURCE TESTING SECTION
REPORT i:0. C-22^1
Robert J. MacKnight
Director of Engineering
Howard BeVorkin
Supv. A. P. Engineer III
ISSUED /IPR 28 1975
-------
AIR POLLUTl/ CONTROL DISTRICT - COUNTY OP ^ ANGELES
C-22'H
^
2,25-75
INTRODUCTION
Upon the request of Mr. Willard F. Ganther, Sr. A. P. Engineer, of the Refinery
Unit, a source test was conducted to determine emissions from the stack of the
CO boiler and the stack of the wet separator at the Standard Oil Co. Refinery
located at J2^ West El Segundo Boulevard, El Segundo, California. Both units
are associated with the fluid catalyst regenerating unit.
The tests were conducted by Source Test Teaa No. *l, consisting of Andrew J.
Wilson, l-'iaurice A. Ballas, llichael Gudlow, and Jerry Kraim. llr. Ganther was
present during the tests and his recorded observations are appended to this
report. Test arrangements were made with Messrs. James Daily and 3U R. Ray,
Air Pollution Coordinators for Standard Oil Co.
TEST RESULTS AMD. DISCUSSION
The CO boiler participate emission appeared in compliance with Rule 5ft —
emitting only 15.5 pounds per hour of solid participates.
Dnission of particulates (both solid and total) at the wet separator stack
(also called the quench-drura stack) was 0.02 pound per hour. These and other
test. results are suoznarized on pages 3 to 7 inclusive.
The FCC unit was tested under the follovring conditions: (l) the unit •.•:2.E run
at or near its rated throughput, (2) no waste gases from other units \.-ere
incinerated in the firebox of the CO boiler, and (?) no fuel oil was fired
in the CO boiler.
The CO emissions from the wet separator stack v;ere greater than 1# during the
first test. It was discovered that Standard Oil personnel had inadvertently
left the catalyst dump valve partially open. A second test for CO with the
catalyst dump valve in the closed position showed no CO emissions.
•PROCESS DESCRIPTION
Petroleum products are continuously fed to a reactor and passed -through a
fluid catalyst bed which, under high temperature, and pressure, cracks or fragments
the petroleum products into new, smaller molecular weight compounds which are
continuously removed frora the reactor. The catalyst used in 'the cracking
process becomes coated with carbon and other impurities which destroy the
catalytic action and, therefore, the catalyst must be cleaned and reactivated
before it can be reused.
The catalyst is continuously recirculated from the reactor to a regenerator
and back to the reactor. The catalyst is regenerated by burning carbon and
oti'-r impurities from the surface of the catalyst by using air in n control] cd
co'noustiori process. Vented gases from the regenerator contain various air
CGntaraii/~nts such as catalyst dust, carbon monoxide, cyanides, a-saonia, sulfur
oxides ?-:id nitrocen oxides. To reduce emission of these air contaminants to
the atmosphere, the regenerator exhaust gases are passed through cyclones, an
-------
AIR POLLUTION CONTROL DISTRICT - COUNTY OP LOS ANGELES
C-22ln Page 2
2-25-75
electrical precipitator, and a waste heat boiler ("CO boiler") and then are
discharged to the ataosphere. The cyclones and the electrical precipitator
collect catalyst dust and other particulates from the exhaust gases. The
CO boiler oxidizes the carbon monoxide, ammonia, and other combustible
material.
The wet separator (quench drum) is the emission control device for the
vacuum eductor (or pneunatic conveyor) gases used in the catalyst fines
transfer system froa the precipitator. The system is also used for new
catalyst make up.
SAMPLING AND ANALYTICAL PROCEDURES
.All tests were made in accordance with the procedures in the Source Testing
Manual of the Air Pollution Control District. Diagrams of the sampling
trains used are shown on pages 14 and 15. The iapinger solution and probe
washings from the CO boiler water train were filtered through a tared Gooch
crucible. Both the Gooch collection and the filtered solution were dried at
105PC and weighed. The material collected on the Gooch filter plus the
material collected on the thimble constituted the "insolubles." The sulfuric
acid content of the dried, soluble impinger residue was determined by titration.
The weight of the sulfuric acid (as H2SOV2H20) was subtracted from the total
collected weight to determine the solid partieulates from the CO boiler.
The solid particulates from the wet scrubber stack were determinpd in the same
Banner with the exception that no attempt was made to differentiate between
solubles and insolubles.
Carbon monoxide emissions were estimated by use of MSA length-of-stain
indicator tubes and determined on integrated samples by TCA (Total Combustion
Analysis).
The velocity traverse was conducted on the CO boiler stack by traversing
half-way across the stack from two different ports 90° apart. From prior
•test results it could be assumed that the results of traversing by this
method would give essentially the same values as traversing all the way
across the stack by the standard procedure. The reason this was not done,
was that there was no suitable Pitot tube available.
Approved
-------
AIR POLLUTION/- ONTROL Dl STR ICT- - -COUNTY LOS ANGELES
/-
TEST NO- C-22»H
PAGE.
DATE.
NAME OF FIRM
SUMMARY: EMISSIONS TO ATMOSPHERE
Standard Oil Co. of California
LOCATION OF PLANT.
TYPE OF OPERATION .
West El Ssgundo Boulevard, El Segundo, California
Oil Refinery _•
UNIT Tf."gn_ CO Boiler
RULE NO.
MEASURED
EMISSIONS
ALLOWABLE
EMISSIONS
52 PARTICULATE
MATTER
53 SULFUR COMPOUNDS
AS S02
53.67 S-COMPS. AS S02
54 SOLID pARTICULATE
MATTER
58.68.1 COMBUSTION
CONTAMINANTS
67 COMBUST.CONTAMS.
NOX AS N02
68 NOX AS N02
71 CARBON MONOXIDE
GRAINS
PER SCF
PPM BY VOL.
LB. PER HR.
15-5 LB. PER MR.
GRAINS PER
SCF AT 12% C02
119
LB. PER MR.
LB. PER MR.
PPM BY VDI .
AT 3% 02
. % BY VOL.
2000
GR A I N 5
PEW SCF
PPM CY VOL.
LB. PER MR.
30 1.0. PFR HR.
GHAINS PER
SCF AT 12% C02
Lu. PER MR.
I.EI. PER MR.
0.2
PPM BY VOL.
AT 3% 02
% (1Y VOL.
NOTES: ALL RESULTS ON DRY (OR EQUIVALENT) OASIS._UNLESS OTHERWISE NOTED
55D29 n-1
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AIR POLLUTION' ONTROL DISTRICT---COUNTY LOS ANGELES
TEST MO- C-22'H
PAGE.
2-2>-75
SUMMARY: EMISSIONS TO ATMOSPHERE
rXAML Ol r 1 K<
LOCATION OF
TYPE OF OPER
UNIT TESTED
RULE NO.
52
53"
53.67
54
56.68.
67
67
60
71
71.-
PI ANT 52'1 West E1 Segundo
,4TlftM Oil Refinery
Wet Separator
PART ICUL ATE* . 0
MATTER
SULFUR COMPOUNDS
*.s S02
S-CO'IPS AS SQ~
SOLID PART ICUL ATE "
MATTER
COMBUSTION _
CONTAMINANTS
COMBUST. CONTAMS.
NO.. AS NO,
NOX AS NOa
CARBON MONOXIDE*^
Carbon Monoxide (bi 0
Boulevard, El Segundo,
MEASURED
EMISSIONS
.OOjS GRAINS
PER SCF
PPM BY VOL.
LB. PER MR.
• 02 |_Bi PEP MR.
GRAINS PER
SCF »T 127. CO?
LB. PLR MR.
LO. PER HA.
PPM BY VOL.
AT 3% 02
.*.: ._ . • * BY un| -
.0 < by Vnl .
California
-
ALLOWABLE
EMISSIONS
0.? GRAINS
Ptn SCF
npu HV wni
Ln. PEW mi.
1.00 Lo. PER nn.
GRAINS PER
SCK AT 12% CO 2
LB. PER HH.
Lo. PTR HR.
PPM BY VOL .
AT 3% 02
°'2 % DY VOL.
n.? % by Vol.
NOTES: ALL KFSULTS ON DRY (OR EOUI VAI ENT) BASIS. UNLESS OTHERWISE NOTED
(a) Carbon monoxide concentration was 1.'i£ with the catalyst durrp valve
open.
(b) Ho CO could be detected with the catalyst dump valve closed (see
discussion under "Test Results"). 55D29 R-l
-------
AIR POLLUTION p^NTROL DISTRICT - COUNTY Of- LOS ANGELES
TEST NO._Cr?Mi -
SUMMARY OF DATA AND RESULTS TF 2-25-75
TEST SITE, EQUIPMENT, AND TEST CONDITIONS:
I. NAME OF FIRM Standard Oil Co. of California
2. BASIC FoiiiPMFMT Fluid Catalytic Cracking Unit
3. CONTROL EQUIPMENT Cyclones, Electrical Precipitator, CO Boiler, Wet Separator
4. EQUIPMENT TESTED CO Boiler^ Sfe.ck
5. PROCESS VE.GHT, LBS PER HOUR in excess of 1,000,000
Normal
6. TESTING CONDITION _
7. SAMPLING LOCATION: CO Boiler Stack
GAS FLOW AND ANALYSIS:
6. GAS TEMPERATURE,*F
9. GAS VELOCITY, FPS ___ 51 -3
IO. GAS FLOW RATE, SCFM (WET) _
GAS FLOW RATE. SCFM (DRY) _______ _ 155t3CX)
II. GAS ANALYSIS, VOL %, DRY BASIS:
CAK3ON DIOXIDE _ . _ ^?-
**
OXYGEN
0*0
CARBON MONOXIDE
Op 7
NITROGEN __ " *'
12. GAS ANALYSIS, VOL %, WET BASIS:
20.6
WATER VAPOR
CARBON DIOXIDE
OXYGEN
CARBON MONOXIDE
NITROGEN
AIR CONTAMINANTS MEASURED:
t3. MATERIAL COLLECTED Solid Particulates . SQx
H2S04-2HSO S02
14. TOTAL GAS VOLUME SAMPLED, SCF 3^.50 21.00 21.00
15. WEIGHT COLLECTED, GRAMS 0.026O* 0.021 0.392
16. MATERIAL CONCENTRATION:
GRAINS PER SCF (WET)
GRAINS PER SCF (DRY)
GRAINS PER SCF AT 12% COg
PARTS PER MILLION BY VOLUME
17. MATERIAL FLOW RATE, LBS PER HOUR _ 15»5 - ?P'5.
EFFICSENCY OF CONTROL EQUIPMENT:
18. MATERIAL IN, LBS PER HOUR
IS. MATERIAL OUT, LBS PER HOUR - 15-5 - 2Q.5
20. EFFICIENCY, %
21. Insoiubles, % 1"?.5
22. Carbon Monoxide, ppra by TCA _ 130
* Includes O.OOJ5 em insolublea.
60D489.R.
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AJR POLLUTION CONTROL DISTRICT - COUNTY 0&- LOS ANGELES
TEST NO._C=«!L! SUMMARY OF DATA AND RESULTS j^g 2-25-75
TEST SITE, EQUIPMENT, AND TEST CONDITIONS:
I. NAME OF FIRM Standard Oil Co. of California
2. BASIC rqinPuFuT Catalyst Pneumatic ConVeylng System
Vet Separator
•Vet Separator
3. CONTROL EQUIPMENT
4. EQUIPMENT TESTED .
5. PROCESS WEIGHT, LBS PER HOUR
6. TESTING CONDITION Catalyst. T>i!np Valvo On°n
100
1>vr-» Valv
7. SAMPLING LOCAT.ION: Vet Separator Stack
GAS FLOW AND ANALYSIS:
8. GAS TEMPERATUR
9. GAS VELOCITY, FPS
Wet Separator Stack
OXYGEN
NITROGEN
OXYGEN
CARBON
NITROGEN
AIR CONTAMINANTS MEASURED:
IIPF, "IT
. FPS
E, SCFM (WET
. SCFM (DRY)
, VOL %, DRY
n 10x1 fie .
MONOX IDE
H
, VOL %, »ET
APOD
p |nx lor
66
67.1
, 788
770
BASI Si
2.1
17.5
1.1
79.3
BASIS:
2.2
0.0
20.8
(None detected bv TCA)
79.2
"\^
unwonnr ^-^
M ^*>^
Particulatcs
14. TOTAL GAS VOLUME SAMPLED, SC
15. WEIGHT COLLECTED, GRAMS
16. MATERIAL CONCENTRATION:
GRAINS PFR SCF (WET! _
GRAINS PER SCF (DRY)
GRAINS PER SCF AT 12% CO
PARTS PER MILLION BY V
17. MATERIAL FLOW RATE, LBS PER
EFFICIENCY OF CONTROL EQUIPMENT:
18 MATERIAL IN, LBS PER HOUR
19. MATERIAL OUT, LBS PER HOUR
Solid Particulates
j) 46.8?
0.011
0.0036
2
(M ""r
un,,B 0.02
0.02
•
Total Particulates
*l6.87
0.011
0.0056
0.02
0.02
"
*
60D489.R
-------
AIM wmrnoN cm-no. DISTRICT - COUNTY or ins
Tc.it No. C-22-'r1
RESULTS OF ANA1.YSES
FOR
Nitrogen Oxides and Carbon Monoxide
Page
'Date 2-23-75
I
(JCWIWDNT:
TEST ST-VriON
' 'I
CDNCFjVnUTIONS. PPM DRY B-VSIS |
Sample 1;
2:
3:
h:
A. AMRAGC COXCN. , PP\I (DRV)
R. Conxeision factoi , ppii tograins/sc f
(o.onnmjue * Moicc. \\t.)
C. Avg. Concn. , grains/scf (dr>)
U x B)
D. Stack pas flow rate, scfm («ct)
F.. ttatcr \apor in gases, vol. %
f. Stack gas flo« rate, scfm (dry)
D( 1-0.0 1C)
C. Flo-* rate, pounds per hour
0.00357 \ C x F
II. Control Efficiency. Z
Npx
as
N02
CO Boiler
Stack
10?
102
105
I
0.0008't9
0.0891
195500
20.6
155300
11Q
CO
CO Boiler
Stack
150
•
130
•
CO
Catalyst
Dump Valve
Open
V/et Separator
Stack
10700
10300
11100
10900
CO
Catalyst
Dump Valve
Closed
Uet Separator
Stack
none
deLect-ed
0
•
jio IM
-------
AIR POLLUTION CONTROL DISTRICT •• COUNTY OF.'.OS ANGELES
TEST NO.C-2241 PAGE _
8
SAMPLING STATION _CO_Joiler_SUck_
HATF 2-25-75
SAMPLING TRAIN DATA AND CALCULATIONS (DRY BASIS)
TIME
1:10
+5
+10
+15
+20
<25
+30
-O5
+40
+45
+50
+55
+60
60 nan.
net
•
C.A, t.
READING
CU. FT.
VH
]
899.25
902.9
906.2
909.5
912.7
916.0
919.6
92?.1
926.5
q^o.o
c'33.4
9-55.7
I 9'io.09
I
40.B4
net.
L tt h
VAC.
IN. KG
PM
LO Train
4.0
4.0
4.0
4.0
4.6
4.6
4.6
4.5
A.6
4.4
4.4
4.4
4.3
avg.
IMPINOIR
TtMP .
°F
TI
56
56
56
56
54
54
54
55
54
56
54
53
55
avg.
VM
552.02
554.1
557.1
558.4
560.2
562.1
563.8
565.5
567.2
569.2
571.5
57^.5
575-19
23-17
net.
PM
NaOI-
4.8
4.9
0.9
2.2
2.0
1.7
2.0
2.0
3.0
2.4
2.2
1.9
2.4 '
avg,
TI
I Train
58
60
62
58
58
56
56
60
60
60
62
60
59
avg.
Thimble
Temp.
op
220
240
186
210
f'.O
"' >
K-J
202
210
.208
?00
189
"
Solid Particulates
Sulfur Oxides
MATLK1AL (.ULI.ll. 1 C.U . ;
H2
WEIGHT COLLfCIED. GSAMS:
Intaincers f insoluble) 0.0015
ImoiriKcrs (soluble) 0.1355 Thimble . _
Thinble 0.002 Imp infers
"iLess H?SOJ;-2H20) (-0.113)
o np6
A TOTAL WEIGHT G'ius w.ueu
D, VtPOff PfttSSURt Of AATER AT IMP. UMP.. J-N. Hri
F. TOTAL CAS VOLUME SAMPLED, EM-D'C) . scftonr) .
r. u.TCDiii rnvru 15.43 X A/F . GRA 1 MS/5C F ( 0(- T )
?JL«2H20 SOp o r- IT r- i
a) /,,\ METCR TE«p. = 60 ' IT.C. j
l"» fl Q *A
SftMI'Llllft POINTS '"'
0.021
A'TMOS. pfitssuRE. ,_ _
0.021 0.392 Pft, IN. HC -^ -
155300
25.7 ?';-6
0.436 ' O.'tfrt
35.10 ?!.-*>
34.50 ?-.oo
U> (b)
0.0116 O.'"'r>4 p !>Rfin
pjxn as 502
or.
-------
AIR POLLUTION CONTROL DISTRICT -• COUNTY OF .LOS ANGLLtb
TEST NO. C-22»H PAKF 9
SAMPLING
PERCEI
A. GAS P
B. VAPOR
C. GAS v
D. WATER
E. WATER
r. WATER
G. TOTA
H. TOTAI
•J. PER
DRY
K. GAS r
L. O-S.S T
GAS
L STATION CO Boiler Stack
DATr 2-25-75
WATER VARDR, DRY GAS FLOW RATE, AND GAS DENSITY CALCULATIONS
hIT WATER VAPOR IN GASES
PESSUBE AT METfR* Pi — P IN HG ABS
PRESSURE OF WATER AT IMP- TEMP., IN. HG
OKlur ur-rrprn, VM x VI. 9. STF
VAPOR METFRtP, C X P'/A, SCF
VAPOR COND.. VAPOR VOL.. 0.0464 X E. SCF
L WATER VAPOR IN GAS SAMPLE) D + F. SCF
CENT WATER VAPOR IN C*5 SAMrLtt i«« « w" —
GAS FLO* RATE
IDA RATE- SCFM 1ȣT)
DENSITY CORRECTION FACTOR
H20 Train
25.7
0.4-36
' 35.10
0.60
180
8.35
8. OK
20.6
195,500
155,300
COMPONENT
V/ATER
CARBON DIOXIDE
OXYGEN
NITROGEN & INERTS
TOTAt
UnimilAD WT 1 R UT
\OL. V>00
(DRY)
0.132
O.tfH
0.000
0.82?
1.000
or STACK CA
MOISTURE
CORRECTION -
(1-j/iOO)
0.79*1
0.79^
0.79^
0.791*
5
VOL.VIOO'
(WET) '
0.206
0.105
0.032
0.000
0.657
1.000
MOL. WT. =
18.0
44.0
32.0
28. 0
20.2
WEKKT
P£K MOLE OF
STACK GAS
3.7
n.6
1.0
0.0
1~.5
** 'jf*
N. DENSITY Of GAS DEFERRED TO AIR = M/28.95 -.
0. GAS DENSITY CORRECTION f*CTOR = Vl.OO/N=.
r.OD'.DO R-1
-------
AIR POLLU/ N CONTROL DISTRICT •- COUNTY
-------
TEST NO.
POLLUT;^ CONTROL DISTRICT •• COUNTY ot LOS ANGELES
PAGE it
SAMPLING STATION Wet Separator Stack
.DATE.
SAMPLING TRAIN DATA AND CALCULATIONS (CRY OASIS)
TIME
11:02
410
420
+JO
+40
+50
456
56 ipivi.
npt
(,!,•> Ml »l>
READING
CO. TT.
VK
VAC.
IN. HG
PM
trip i tiOt R
Teuc .
°r
T!
516.70
\ 526.2
536.^
5't6.9
557.**
568.0
57^.26
57.r;6
net
>l.6
5.1
5-Jt
5.4
5.^
5.3
5.2
avr.
52
56
57
57
55
56
56
aw.
•
,
MATERIAL COLLECTED
Particulates
WEIGHT COLLECTED, GRAMS:
Jjnpingors
0.010
Slninble 0.001
(XiSSS fl2SDV 2rIpOJ
(-O.OOO)
A. TOTAL WEI GMT.Ga IMS
0.011
B. STACK CAS FLOW RATE,
AT MEIER. PA—PM- '*•• Hw ASS. —
D. VAPOR PRESSURE Of V.ATER AT IMP. TEMP.. IN. HC
E. GAS VOLUME WETEHED, VM x C/29.9. SCF ., .
F. TOVAL CAS VOLUME SAMPLED, EIU-0/CI. SCf(ORV)
G. MATERIAL CONCN.. 15.13 xA/r. OHAINS/SCF(DBV]
METEH TEMP. =60° f (T.C.)
SAWK ING POINTS _?
SAMPIIKG NOZZLE t i
I . 0 . , MM _-** '
ATMOS. fRLSSURc.
O.'l52
o.oo'-;6
-------
AIR POLLUTION CONTROL DISTRICT -• COUNTY OF LOS ANGELES
TEST NO.
SAMPLING
PAGE.
12
Vet Separator Stack
DATE 2-25-75
WATER VAPOR, DRY GAS FLO// RATE, AND GAS DENSITY CALCULATIONS
PERCENT WATER VAPOR" IN GASES
A. GAS PRESSURE AT METER, PA _ PM . IN. HG ABS.
B.
c.
D.
C. WATER VAPOR CONDENSED. LIQUID VOL.. ML
VAPOR PRESSURE or WATER AT IMP- TCHP.. IN. He
GAS VOLUME METERED, VM X A'29.9. SCF
V/ATER VAPOR METERED, C X B/A, SCF
0.870
20
C.
H.
.J.
V/ATER VAPOR CONO. . VAPOR VOL.. 0.0464 X E. SCF .
TOTAL WATER VAPOR IN CAS SAMPLEt D + F. SCF
TOTAL CAS VOLUME SAMPLED, C + F. SCF
• 0.93
1.00
'18.67
.«« „ .-/^ 3-7 (contains droolet.
PER CENT WATER VAPOR IN GAS SAMPLE* 100 X G/H =
(actual saturation at 66°P = 2.2
DRY GAS FLOW RATE
K. GAS FLO:. RATE. SCFM UET>
788
GAS FLO* RftTL. Kll-J'100). SCFM (t>Rvl .
GAS DENSITY CORRECTION FACTOR
JffiL
COMPONENT
WATER
GABOON DIOXIDE
OXYGEN
CARBON MONOXIDE
NITROGEN & INERTS
TOTAL
tfni r/>nl AD KrrtftlJT
\0i. V100
(DRY)
TX^
0.021
0.175
0.011
0.793
1. 000
OF STACK GA
MOISTURE
c CORRECTION ••
(l-j/100)
T^xd
0.978
0.978
0.978
0.978
s —
VOL. 1J 100
UET) *
O.OP2
0.020
0.171
0.011
0.776
1.00O
MOL. WT. =
18.O
At> .O
32.0
20.0
28.2
*£IC-HT
PER MOLE OF
STACK GAS
o.n
0.9
• 5.5
o.3
?.1.9
, po-n
N. DENSITY OF CAS REFERRED TO AIR = M/28.95 =.
o T.AS nrusiTy coRRfTiON FACTOR = V\7oo/H~.
-------
AIR POLLU^ %N CONTROL DISTRICT -• COUNTY Q '-OS ANGELES
TEST NO. C-22*H _ PAGE
SAMPLING STATION Wet Separator Stack
DATc 2-25-75
GAS VELOCITY DATA
TIME
ICF:!2!
Poirir
1
2
^5
4
avg.
VEL. HEAD
IN. H20
1.4
1.5
1.5
1.5
TEMP.
°F
66
bb
VELOCITY
FT/SEC
78,7
81.5
81.5
81.5
80.8
VEL. HEAD
IN H20
1.4
1.5
1.5
1.5
TEMP.
°F
66
bb
VELOCITY
FT/SEC
78,7
81.5
81.5
81, •}
80.8
-
VEL. HE«O
IN: H20
1.*
1.5
1.5
1.5
TEMP.
°F
66
,
bb
VELOCITY
FT/SEC
78. Y
81.5
81.5
81.5
80.8
A.
B.
c'.
D.
E.
F.
G.
H.
J.
K.
L.
M
INDICATED VELOCITY (TRAVERSE) FT'SEC—
INDICATED VELOCITY (REFERENCE PT.I FT/SEC
PlTOT CORRECTION FACTOR
Gi«t nruciTv CORRECTION FACTOR
GAS PRTSSURE IN STACK, IN. KG. AB5.
GAS PRESS. CORREC. FACTOR, ^29-9/F
CORRECTED VELOCITY, AxDxF.xG, FT/SFC
OR BxCxDxFxG, FT/SFC
AREA OF FLUE, so. FT.
AVERAGE FLUE TEMPFRATURF, °F.
FLOV; RATE, HxJx60. CFM ._
FLOW HATE.
-------
AIR POLLUTldK CONTROL DISTRICT -- COUNTY OF t--> ANGELES
TEST.NO.
PAGE
HATF 2-25-75
SAMPLING APPARATUS
For
particulates
G
100
100 „, dry
J. SAMPLING PROBE
2. IMPINGER (OUST CONCENTRATION SAMPLER)
3. ICE BATH CONTAINER
4. DRY F..Ttp Uhatman Thimble
5. THERMOMETER
6. MERCURY MANOMETER
7. SPRAGUE DRY GAS METER (ZEPHYR NO. IA)
8. VACUUM PUMP
9. HOSE CLAMP TO CONTROL GAS FLOW RATE
IMPINGER SOLUTION -Dft.inni7.Rc1 Water.
I6-5EO16
-------
Atn PCLUSr'ON CONTROL DISTRICT
TY f LOS ANGELES
TEST KO.
PAGE _ . 15—
2-25-75
SAMPLING
For
1. SAHPL ING PRODE_
2. DRY FiLten Lil.
3. IHPIHGER (OUST C
4. Ice BATH CONTM:
5. THEIIMOHETER
6. MEPCURY MAHOMET
7. SPRAGUE DRY GAS
0. VACUUM PUMP
9. HOSE CL^HP TO c.
lUPIHGER SOLUTI.
.c
•«N SAMPLER)
;y« no. JA)
"LOW RATE
t6.SS.Ot5
-------
AIR POLLUIJ/"' CONTROL DISTRICT - COUNTY OF >"S ANGELES
ENGINEERING DIVISION
OBSERVATIONS DURING SOURCE TEST NO.
NAUE Of DATE OF
STANDARD OIL COMPANY OT CALIFORNIA „„ February ?•%. 1Q7-S
"" c7fiT CO Boiler Stack; Quench Drum, Catalyst Handling System.."1""^ A-80700
HOURS or £]*•"• n«.M.
OBSERVATION :F
-------
AIR POLUiriN CONTROL DISTRICT - COUNTY 0& 'OS ANGELES
ENGINEERING DIVISION
OBSERVATIONS DURING SOURCE TEST NO.
FCC DATA
Reactor Feed Bate
Frcbh Feed, EPD 1*5 H
Recycle Feed, BPD 9.2 H
Regeneration Air Rate, CFM 100 M
Catalyst Circulation Rate, tons/min 6j
Flue Gas Tccp.(After Cottrell) °F 550
Regeneration Temperature °F
Dense Phase, Average 1185
Flue Gas Out 10JO
Coke Burnoff Rate, Ibs/hr. 38.8 M
Regeneration Pressure (Top) PSIG l'f,0
CO BOI1ER DATA
Combustion Air Rate, CTK 50 K
Inlet Regeneration Gas Tcnp., °F 527
Inlet Regeneration Gas Press., EgO 11.2
Steam Production Rate Ibs/hr. 250 H
Stean Torep. °F ?JO
Stcara Pressure PSIG 800
Firebox Teop. °F 1660
Fuel Gas Rate CFJI 200 M
% 02 in Flue Gas 1.2
Fuel Oil Rate B/hr. -0
Flue Gas Tenp. 770
VACUUtl UD'JCTOR, CATALYST TRANSFER SYSTEM
Steajn PresBure to Eductor 22 PSIG
Eductor Vacuusn 6 Inches of Water
nr.t _ «i
-------
APPENDIX H
SOURCE TEST DATA
SULFUR RECOVERY UNIT
-------
434 SOUTH SAN PEDRO STREET. LOS ANGELES. CALIF. 90013 - MAO ISDN 9-4711 /COUNTY OF LOS ANGELES
TESTS
CONDUCTED AT
STANDARD OIL COMPANY
OF CALIFORNIA
VEST EL SEGUNDO BOULEVARD
EL SEGUNDO, CALIFORNIA
ON
JANUARY 10 & 11, 1973
REPORT
ON THE
EMISSIONS TO THE ATMOSPHERE FROM THREE
CLAUS PROCESS SULFUR RECOVERY PLANTS
Iff
Janes T. Nance Supervising Air Pollution Engineer II
George Ames Sr. Air Pollution Engineer
SOURCE TESTING SECTION
REPORT NO. C"- 1895
Eric E. Lerrike Howard DeVorkin
Director of Engineering Supervising Air Pollution Engineer III
ISSUED: *B 2S ^
-------
Test No. C-1895 Page 1
January 10 & 11, 1973
INTRODUCTION
Upon request of Senior Air Pollution Engineer E. E. Larsson of the Refinery
Processing Unit of the Engineering Division, source tests were performed on
three CVus process sulfur plants. These plants are operated by the Stand-
ard Oil Company of California and are located at the El Segundo' refinery,
324 Vest El Segundo Boulevard, El Segundo, California. These tests were
performed jointly by personnel from both Standard Oil and the J^Lr Pollution
Control District. The District personnel were J. T. Nance, G. Ames, and
E. D. Halberg. Kr. Larsson wag present during the test, and the report of
bis observations is appended along with the sampling results obtained by
Standard Oil.
TEST RESULTS
This report presents the results of three separate tests made 4>n three dif-
ferent sulfur plants, one test per each plant. Over 80 separate determina-
tions were made during the tests and their summation will not be attempted
in this paragraph. The summary of results for Plants 1, 2, and 5 are shov.71
on pages ^ and 5, 9 and 10, 14 and 15, respectively.
The test results indicate that the incinerator and absorber column effectively
reduce the H^S content to nil and total sulfur compounds from approximately
1.6-1.8£ to J8-62 ppra as
DESCRIPTION OF PROCESS
The Standard Oil Corapany of California has constructed three two-stage Claus
process sulfur plants at the El Segundo refinery. The plants are alike,
have been constructed adjacent to each other, and are operated in parallel.
The plants receive hydrogen sulfide feed gas from other refinery process unite.
By the Claus process, the sulfur in the hydrogen sulfide feed gas is converted
to elemental sulfur. The tail gas from each unit is incinerated and passed
through a sodium sulfite absorption tower for removal of sulfur dioxide be-
fore venting to the atmosphere. A schematic drawing of a plant showing sam-
pling locations is shown on page 5*
SAMPLING AND ANALYTICAL PROCEDURES
Sampling and analysis of the absorber off-gases by the Air Pollution Control
District for S02, NOX, and hydrocarbons was performed according to the pro-
cedures of the Source-Testing Manual of the Air Pollution Control District.
Sampling for HgS was with an impinger train containing a 'ZnCOj solution.
The I^S -eacts with the ZnCO^ to forra ZnS. The solution is treated with a
strong acid and the liberated H2S is determined by iodometric titration.
-------
Tust No. C-1895
The sampling trains used for the collection of sulfur oxides and hydrogen
sulfidc are shown on page 22.
The Standard Oil Conpany in processing the acid feed gas samples determined
the 1US iodoractrically, the hydrocarbons by mass Spectrograph, and the 00%
gravinetrically after oxidation of the H2S by chrornate. The tail gas stream
was sampled with a 10# WaOH solution. Aliquots were titrated with Afil.'O^ to
determine l^S and precipitated to obtain BaSOjj io determine total sulfur.
The COS an.J. CS2 in the gas stream were determined by GC, using a flame
photometric detector, after the H2S and S02 had been scrubbed out of the
gas by the KaOH train solution.
Approved
-------
Teat No. C-1895
Page 5
1/10-11/73
Sulfur
Product
ClausProcess
Sulfur Plant
Incinerator to Chcm. Pit.
Absorber
Sample Locations
(1) Std. Oil
(2) Std. Oil
(3) APCD
Schematic Diagram o£ Sulfur Plant
and Tail-Gas Treating Unit Located
at Standard Oil Co. of California
El Segundo Refinery
-------
AIR POLLUTION CONTROL DlSTRICT>--COUNTY OF LOS ANGELES
TEST NO._ C-1895
PAGE.
1-10-73
SUMMARY: EMISSIONS TO ATMOSPHERE
Standard Oil Co.
NAME OF FIRM
LOCATION OF PI AMT 32*f West Fl So/nine!? Ro-jlpvard. Fl S«fmndof CalJjfornl;
TYPE OF npFBATinH Sulfur Recovery Plant ,
UNIT TESTED.
PI ar>t. 1—
a+.
MEASURED
EMISSIONS
ALLOWABLE
EMISSIO.M5
RULE 52
PARTICULATE
MATTER
RULE 5J.2-1 SULFUR COMPOUNDS
AS S02
53.2-3 " " "
53o COMBUSTION
CONTAMINANTS
RULE
RULE 54
DUST AND FUMES
C02
62
GRAINS
PER SCF
BY VOL.
5.07 IbsAr
•^ ' GRAINS PER
SCF AT 12%'COz
16.0
LOS. PERMR.
% BY VOL.
GR A I N S
PER SCF
500 pom BY VOL .
200
PER
SCF AT 12% C02
LOS. PERHR.
ALDEHYDES AS HCHO
PPM BY VOL.
HYDROCARBONS
AS HEXANE
NOX AS N02
Q.7
PPM BY VOLt
PPM BY VOL.
ORGANIC ACIDS
AS ACETIC ACID
Rule 53.2-2
Rule 71 CO
GAS FLOW RATE, SCFM.
GAS TEMPERATURE, °F.
8100
130
PPM BY VOL.
ppm hy vol. 10 pnra by vol.
g bv vol. 0.2 % by vol.
EFFICIENCY or CONTROL -ouiPMINT,%.
I6.SS029
-------
Test No. C-1895
Page 5
1-10-73
SULFUR PLANT NO. 1
SUMMARY OP CONCENTRATIONS OP CHEMICAL
CONSTITUENTS IN GAS STREAKS (l)
Gas Flow
Rate
H2S
C02
S02
COS (as S02)
CS2 (as S02)
5 vapor (calc.)
H20
NOX
H-C (as C)
CO
Acid Gas
Feed
Std. Oil
195,000 SCFH
67.5 %
31.8 %
Sulfur 'Plant
Tail Gas
Std. Oil
0.9355
15.0 %
0.53 %
0.02^ %
0.0455 %
0.0110 %
-&%
Fotal sulfur compounds as S02f ppm:
(D) + (E) + (F) = 27 + 13 + 22 = (K)
total sulfur compounds as S02f Ib/nr. :
(K) (10-6) (A) (10.i) -- fa
Absorber
Off Gas
Std. Oil APCD
(A) 8100 SCFM
nil (B) <0.10 ppm
16.0 % (C)
27 pprn (D) 27 ppm (2)
13 ppm (E)
22 ppm (F)
14.0* (G)
(H) 0.57 Ib/hr
(I) 0.90 Ib/hr
(J) 0.36 %
(dry)
(K) 62
GO 5.07
(l) All values are or. wet basis unless indicated.
(2) Includes any H2S present, which was negligible as shotm under (B) above,
-------
AIR POLLUTION CONTROL DISTRICT •• COUNTY OF LOS ANGELES
TE ST•NO. C-1895 PAGE _6
S'AMPLtNG STATiON Sulfur Unit >'o. ] DATE l-T.Q-73
SAMPLING TRAIN DATA AND CALCULATIONS
T J ME
11:50
+ 5
+1C
«15
+20
+25
. +30
+35
+40
+*5
4.50
+55
+60
GAS METER
READ ING
CU. FT.
VM
VAC.
IN. HG
PM
TEMP.
°F
TM
IMPINGCR
TEMP.
op
TI
WaOH Train
(for S02)
5'J.1*8
55.7
57-C
5B.4
59.9
6l.O
620
64.0
65.?
66.6
6H.i
69.4
70.r-7
16. OP
Net
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
AVR
rc 60° F
58
56
58
58
58
57
57
58
58
«tf
56
56
r»7
AVR
VM
PM
T
JM
ZnCO-j Train
(for H2S)
26.50
27.9
29. "5
30.6
32.1
33.2
3*. 5
36.0
37.3
38.7
40.1
*1.5
te.ffi
16. in
Net
1.0
1.0
1.0
1.0
1.0
1.0
1.0'
1.0
1.0
1.0
1.0
1.0
1 .0
Avt
I
[
TT
TC 60° 'p
sfi
S6
5l»
«A
S'4
53
S^
«;s
q<;
56
56
**;
cc.
«'- -
1
:-
i
1
•
\
\
MATERIAL COLLECTED
and HoS
WEIGHT COLLECTED, CRAMS:
SO-
H?S
-------
AIR POLLL JN CONTROL DISTRICT -- COUNTY
TEST NO.
LOS ANGELES
PAGE .7
SAMPLING STATION
Sxvlfur Unit No. 1
HATF 1-10-73
GAS VELOCITY DATA
TIME
10:25
10:33
POIHT
1
2
~*>
i\
5
6
7
R
9
10
IT
"*9
13
U
IS
16
AlTf
VEL. HEAD
IN. H20
. .15
.17
.1R
.18
.22
.24
.26
.?•>;
,r,
. L-r
.17
TR
OA
'.22
06
.97
.96
TEMP.
°F
131
130
VELOCITY
FT/SEC
27.3
29.0
?0 Q
29.9
33.0
•&.*,
?,s,9
33-8
96.-*
?Q.O
?q.o
•^m
^.n
•7^ 0
^ S
35- Q
32.0
VEL. HEAD
IN H20
.15
.17
iR
.20
.23
.?^
.26
.21
19
.16
.16
.IB
.??
.26
.?«
.24 •
TEMP.
°F
VELOC ITY
FT/SEC
27.3
2Q.O
?o o
31. 5
33.8
_-*S-9
^S.Q
32.2
?4Jj
9R.9
pR,p
?O.Q
T*.0
•^s.q
^7.^
^t.s
•=51 . 6
VEL .'HEAD
IK: |:H20
.16
.17
HP
.n.Q
."22
.9t
.(97
.23 .,
.1?f
."ifi
Nft
,'19
,?i
.9^
.?7
.?i
TEMP .
oF
VELOC i TY
FT/SEC
.28.2
?o.o
po o
30.7
33.0
.•Mi.s
^.6
33.8
?fi.^
9R.9
?0 O
•vi y
•^7 0
3S.2
•v>.fi
34.^
31.8
Static + .19" H20
A. INDICATED VELOCITY (TRAVERSE) FT/SEC.
31.6
B. INDICATED VELOCITY (REFERENCE FT.) FT/SEC.
C. FLUE FACTOR.A/B
1.00
I.D.
D. PlTOT CORRECTION FACTOR.
1.00
E. GAS DENSITY CORRECTION FACTOR.
1.02 (a)
F. GAS PRESSURE IN STACK, IN. HG. ABS..
G. GAS PRESS. CORREC. FACTOR, \/29.9/F _
3Q.15
.996 8
H. CORRECTED VELOCITY, AxDxExG, FT/SEC.
OR BxCxDxExG, FT/SEC.
J. AREA OF FLUE, so. FT.
32.4
4.67
K. AVERAGE FLUE TEMPERATURE, °F.
L. FLOW RATE, HxJx60, CFM
130
9080
M. FLOW RATE, (F/29.9)x520xL/(K-M60). SCFM-
8100
(a) Aocumsd value baood ypon cas composition info, in permit application.
-------
AIR POLLUTION CONTROL DISTRICT COUNTY,.or LOS ANGELES
TEST NO. C-1895
SAMPLING STATION
PAGE
8
Sulfur Unit No. 1
PATE 1-10-7T
WATER VAPOR AND GAS DENSITY CALCULATIONS
PERCENT WATER VAPOR IN GASES
A. GAS PRESSURE AT METER, IN. KG (ABSOLUTE)
NaOH
Train
29.35
B. VAPOR PRESSURE OF WATER AT IMPINGES TEMP., IN. HG
C. GAS VOLUME METERED, SCF
.'169
D. WATER VAPOR METERED, C X B/A, SCF
E. WfcTER VAPOR CONDENSED, VftPOfl VOLUME, SCF
F. TOTAL WATER VAPOR IN GAS SAMPLE, 0 + E, SCF
G. TOTAL CAS VOLUME SAMPLED, C + E,. SCF
H. PER CENT V/ATER VAPOR IN CAS SAMPLE, 100 X F/G
13.68
.25
2.27
2.S2
17.55
Train
29.15
1.81
2.05
17.55
12
GAS DENSITY CORRECTION FACTOR
COMPONENT
WATER
CARBON DIOXIDE
CARBON MONOXICE
OXYGEN
NITROGEN & INERTS
VOLUME PER CENT/100 >
DRY BASIS
DRY DASI5
DRY BASIS
DRY BASIS
MOISTURE CORRECTION
1 - H/100
1.0
: MOL. «nr, =
18.0
44 .0
28.0
32.0
28.2
WE 1 CHT
PEK I.'OLE OF
STACK GAS
J. MOLECULAR WEIGHT OF STACK GAS
K. DENSITY OF GAS REFERRED TO AIR = J/20.95 =.
L. GAS DENSITY CORRECTION FACTOR = VlToO/'K =.
GOD480
-------
AIR POLLUTION CONTROL DISTRICT-•-COUNFY Oh LUb ANbtLtb
TEST NO. C-1895
PAGE 9
DATE 1-11-73
NAME or FIRM
SUMMARY: EMISSIONS TO ATMOSPHERE
Standard Oil Co.
LOCATION OF p. A»T
TYPE OF
UNIT TESTED.
3^ West E1 Segundo Boulevard, El Scgundo, California
Sulfur Recovery Plant
Plant 2-Absorber Outlet
MEASURED
EMISSIONS
ALLOWABLE
EMISSIONS
RULE 52
PARTICIPATE
MATTER
RULE 53-2-1 SULFUR COMPOUNDS
AS S02
53.2-3 " " "
RULE 53s COMBUSTION
CONTAMINANTS
RULE 54
DUST AND FUMES
C02
. GRAINS
PER SCF
ppmaY VOL.
2.0U Ibs/hr
GRAINS PER
SCF AT 12% C02
LBS.PERHR.
16.0 % BY VOL.
GR AiN s
PER SCF
500 ppmnv VOL.
200 Ibs/hr
GRAINS PER
SCF AT 12% C02
LBS.PERHR.
ALDEHYDES AS HCHO
PPM BY VOL.
HYDROCARBONS
AS HEXANE
NOX AS
PPM BY VOL,
PPM BY VOL.
ORGANIC ACIDS
AS ACETIC ACID
Rule 53.2-2
Rule 71 CO
GAS FLOW RATE, SCFM.
GAS TEMPERATURE, F.
.110.
PPM BY VOL.
prni by vol. 10 pran by vol.
0.2 % by vol.
5300
0.2 % by vol.
EFFICIENCY OF CONTROL EOUIPMINT,%.
16-55029
-------
JfUijLAJ J JLWI1 UVK
Test No. C-1G95
SULPUR PLANT NO. 2
SUM-WHY OP COrfCEWRATIOMS OP CHEMICAL
CONSTITUENTS IN GAS STREAMS (l)
Page 10
1-11-73
Gas Flow
Rate
H2S
C02
S02
COS (as S02)
CS2 (as S02)
5 vapor (calc.)
H20
NOX
H-C (as C)
CO
Acid Gas
Feed
Std. Oil
129,000 SCFH
67O %
32.42
Sulfur Plant
Tail Gas
Std. Oil
0.91 %
1^.0 %
0.70 %
0.0260 %
0.0525 %
0.0100 %
32.0*
total sulfur compounds as SOp, ppra:
(D) + (E) + (F) = 33 + 1 ? * «=
Dotal sulfur compounds as S02, lb/hr.:
(K) (10-6) (A) (10.1)
Absorber
Off Gas
Std. Oil APCD
(A) 5>00 SCFM
nil (B) <0.4 ppra
16.0 % (c)
35 pp-n (D) 25 ppra (2)
1 ppm (E)
\ ppra (P)
10.0 ^ (G)
(H) 0.59 IbA-r
(1) O.'llJ IbAr
(J) 0.2 ^
(dry)
(K) 33
(L) 2.04
(l) All values are on wet basis unless noted.
(2) Includes any KgS present, which was negligible as shown under (B) above.
-------
TEST NO.
SAMPLING STATION
AIR POLLUTION CONTROL DISTRICT -• COUNTY OF LOS ANGELES
PACE 11
Acid Vs. ? DATE 1-1
SAMPLING TRAIN DATA AND CALCULATIONS
TIME
10:25
+ 5
+10
+15
+20
+25
. +30
+35
+'lO
+^5
•f50
+55
±Pin
GAS METER
READING
CU. FT.
VM
VAC.
IN. KG
PM
TEMP.
°F
TH
IMP INCEH
TEMP .
OF
TI
NaOH Train
39-02
'10.7
*2.3
43.9
45.5
'}?•!
A8.7
50. '»
51. B
511!.?
r>5.?
56.8
r^ hP
10 Jifi
TT°*
1.2
1.2
1.2
1.2
1.2
1.2
1.3
1.?
1.?
1.^
1.3
1 •*
'
1 ,9
Avr
To
60' P.
'
58
58
57
58
53
57
56
55
^
55
56
s6
^7
AVP
VM
W.12
'15.7
'J7.-5
Ii8.9
50. li
51.9
53-3
5*1.0
56. R
^.?
60.1
61.8
6^. si
19 19
Net
PM
ZnC03
1.2
1.-1
1.1
Ul
l.'f
l.'t
1.6
1.8
i.R
1.8
i.R
i.R
T (J
Av/r
T
M
TT
Train
To '-
60° P.-
.
•
*
. ^6
•*
5'!
55
56
55
C»l
ms
PI,
NT
t;Ji
rJi
55
/.»-
MATERIAL COLLECTED
WEIGHT COLLECTED, GRAMS:
SO.
0.055
A. TOTAL WEIGHT
B. STACK GAS FLOW RATE, SCFM
C. WATER VAPOR CONDENSED, LIQUID VOLUME, ML
D. WATER VAPOR CONDENSED, VAPOR VOLUME, 0.0464 x C, SCF,
E. GAS VOLUME METERED. '\7 . 4xVMX (PA-PM) /I 4604TH) . SCT
F. TOTAL GAS VOLUME s<
G. MATERIAL CONCENTRATION, 15.43 x A/F, GRAINS/SCF.
Material concentration, . ppm
H. MATFRIAL FLO* RATE, 0.00857 x D x G, LDS/HR
SAMKI ING POINT
SAMPLING NOZZLE
I.D.. MM
ATMO5. PRESSURE,
P., IN. HG
1.76
1.53
18.98
18. *6
20.7'i
J9.99
O.O-'Q
J.0002
25
JLJ
R.\ 60D-18-1
-------
AIR POLLU N CONTROL DISTH1CT •• COUNTY
TEST NO.
C-1895
SAMPLING STATION
ytgndard-Sulftir Unit Tio. 2
LOS ANGELES
PAGE
DATE
GAS VELOCITY DATA
TIME
W>
,
POIMT
1
2
•5
4
5
6
7
R
n
> •*-• •
10
11
TO
T».
IJi
1^
-Ifi
f.vf
VEL. HEAD
IN. H20
.M
.03
.03
.OR
.10
.10
.09
ofi
.o!i
-°7
.07
OS
\n
.19
.T*
,11
TEMP .
°F
no
VELOC ITY
FT/SEC
J5-5
1Q.6
IP. 6
10 fi
21.0
?1 °
20.8
TO, ft
v< R
1R /!
TR It
10 6
. .?! ..3 —
5t n
ps.n
9-^ 0
pn.?
VEL. HEAD
i« U20
.Ofi
,r>7
.0^
n?
.0^
in
.10
^
.tX
nfi
.07
-07
-..10
.i^>
.IP
-T"
TEMP .
°F
VELOC ITY
FT/SEC
l«S.r3
iR.'t
10^
38.':
IQ.rt
OT rj
21.9
T?.f»
17,0
10.^
iRJv
18. •>!
— 21.9
5't.n
?'!.0
?5.n
?n.i
VEL.:HEAO
IN. :H20
.05
.07
Aq
...49...
.no
10
.10
.nR
nh
.ofi
.hft
bs-
.00
.11
.1'.
.1?
TEMP .
°F
VELOCITY
FT/SEC
.37.0
IR.I.
10 A;
IfJ *C
9.T R
IT o
21 !§
IP. 8
l^.R
17.0
TO. 6
10 £ .
?n.8
2^.0
?=>.o
P'l.O
20.1
•
;
Static tt.02"H20 (pulsating)
A. INDICATED VELOCITY (TRAVERSE) FT/SEC-
B. INDICATED VELOCITY {R'EFCRENCL PT.J FT/SEC.
C. FLUE FACTOR, .
1.00
D. PlTOT CORRECTION FACTOR.
1.00
E. GAS DENSITY CORRECTION FACTOR.
1.O2 fa)
F. GAS PRESSURE IN STACK. IN. IIG. ADS..
G.
^50.
.99-5
H. CortiiecTEo VELOCITY, AxOxExG, FT/SEC.
OR OxCxOxExG. FT/SEC ,
J. AflLA OF FLUE, SO. FT.
20.1*
K. AVFRfcGE FLUE TEMPERATURE, °F.
L. TLOV.' RATE, HxJxGO. CFM
110
M. FLOW RATC, (F/P9.9)x520xL/(K+460). SCFM.
(a) Asr.iunecl value ba:>:c! upon cac composition i-ifo. in permit application.
R-» 60
-------
AIR POLLUTION CONTROL DISTRICT -- COUNTY OF LOS ANGCLES
TEST NO. C-1893
SAMPLING STATION
PAGE_li.
Sulfur Unit Ko. 2
OATF 1-10-7^
WATER VAPOR AND GAS DENSITY CALCULATIONS
PERCENT WATER VAPOR IN GASES
A. GAS PRESSURE AT METER, IK. HG (ABSOLUTE)
B. VAPOR PRESSURE OF WATER AT IMMNGER TEMP., IN.
C. GAS VOLUME METERED, SCF
D. V/ATER VAPOR METEREO, C X B/A, SCF
E. V/ATER VAPOR CONDENSED, VAPOR VOLUME, SCF
F. TOTAL WATER VAPOR IN GAS SAMPLE, D + E, SCF
•G. TOTAL GAS VOLUME SAMPLED, C + E, SCF
H. PER CENT WATER VAPOR IN GAS SAMPLE, 100 X F/G
KaOH
Train
18. Q8
3.76
2.07
20.7^
10.0
ZnCO
Train
28.7S
18.
l.fli
Q.I
GAS DENSITY CORRCCTION FACTOR
COMPONENT
WATER
CARBON DIOXIDE
CARDON MONOXIDE
OXYGEN
NITROGEN A INERTS
VOLUME PER CCWT/IOO >
CRY BASIS
DRY BASIS
DRY BASIS
DRY BASIS
MOISTURE CORRECT i OK ,
1 - H/100
1.0
C KML. WT. =
18.0
t4.0
28.0
32.0
28.2
WEIGHT
PER MOLE OF
STACK GA.S
J. MOLECULAR WEIGHT OF STACK GAS
K. DENSITY OF GAS REFERRED TO AIR = J/28.95 -.
L. GAS DENSITY CORRCCTION FACTOR = A/1 .00/K =.
600460
-------
AIR POLLUTION CONTROL Dl STK Id - - -CUUIM IY ut- LUS
TEST MO- C-1895
PAGE.
SUMMARY: EMISSIONS TO ATMOSPHERE
NAME OF FIRM
LOCATION OF PLANT.
TYPE OF OPERATION.
il Co.
West El SoKundo Boulevard, El Senundo. California
Sulfur Recovery Unit
UNIT TESTED.
Plant VAbRorhnr Outlet
MEASURED
EMISSIONS
ALLOWABLE
EMISSIONS
RULE 52
PARTICULATE
MATTER
RULE 5J.2-1 SULFUR COMPOUNDS
AS S02
53.2-3 "
RULE MB C
C
RULE 54 DUST AND FUMES
II II
COMBUSTION
CONTAMINANTS
GRAINS
SCF
-PP.T)
BY VOL.
1.81
GRAINS PER
SCF AT 12% C02
LBS.PERHR.
-00
GRAINS
PER SCF
VOL.
200
GRAINS PER
SCF AT 12% C02
LBS. PERHR.
C02
10.n % OY VOL.
ALDEHYDES AS HCHO
PPM BY VOL.
HYDROCARBONS
AS HEXANE
NOX AS
PPM BY VOL,
PPM BY VOL.
ORGANIC ACIDS
AS ACETIC ACID
Rule 53.2-2_H2S_
Rule 71 CO
PPM BY VOL.
ppm V>y
10 pp-n by vol.
0.057 £ hv vol.. 0.2 5? by vol.
GAS FLOW RATE, SCFM.
GAS TEMPERATURE, °F
EFFICIENCY OF CONTROL EQUIPMENT,?..
16-55029
-------
Test Ho. C-1895
15
1-11-73
SULFUR FIJOT NO. 3
SUMMARY OP CO?rCH3TRATIONS OK C1EUCAL
CONSTITUENTS IN GAS ST?£AI-'3 (l)
Gas Plow
Hate
H2S
C02
S02
COS (as S02)
CS2 (as S02)
S \'apor (calc.)
H20
NOX
H-C (as C)
CO
Acid Gas
Peed
Std. Oil
125,000 SCFH
62.1 %
37-'' %
Sulfur Plant
Tail Gas
Std. Oil
O.'JO %
18.0 %
1.30*
0.0026 %
0.0010 %
0.0133 %
42.0 Ji
Total sulfur cofiDOunds as SOp, ppm:
(D) + (E) + (F) = 3§ +<1 ? 2 = IK)
Total sulfur compounds as SO?, lbs/hr.
(K) (10-6) (A) (10.1)
Absorber
Off Gas
Std. Oil APCD
(A) 4500 SCFT'i
nil (B) 1.4 ppm
19-0 % (C)
38 pp-n (D) 28 ppm (2)
<1 ppra (E)
2 ppra (P)
12.0 JS (G)
(H) 0.^6 IbAf
(I) 0.21 IbAr
(J) 0.067 2
(dry)
(K) '!0
(L) l.Bl
(l) All values are on ucb basis unless noted.
(2) Includes any H2S present, ijhich \ias 1.4 ppm as shoun under (D) above.
-------
AIR POLLUTION CONTROL DISTRICT •- COUNTY OF LOS ANGELES
TEST NO.
C-08T;
SAMPLING STATION
Sulfur Unit Ho.
SAMPLING TRAIN DATA AND CALCULATIONS
PAGE 16
.DATE
1-11-71
TIME
1:50
+ 5
+10
+15
+?0
*25
«-30
+35
*'!0
J^
• irO •
4«^
. i/O .
GAS MLTER
READING
CU. FT.
VM
VAC.
IN. HC
PM
TEMP.
°F
TH
IMPINGE ii
TEMP .
OF
Ti
KaOH
6<^9
66.8
68.3
69-7
71.2
7?. 6
7!i.o
75- ''
76.8
7R.9
70. 1
Rl.l
ftO r4
17.17
Not
1.0
.9
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.0
i.n
_. T.I
i.O
Av.t
60° P.
Tc
68
66
66
65
64
65
6'i
6s
fiK
6r;
fiU
#i
fis
y\rrx
vt^
^M
TM
^T
2nCO_
60.60
6T. 9
63.3
6ii.6
66.1
67.5
6B.8
70.2
71. S
7^,n
7J[ V,
7^.7
77,10
l^.f-,0
Ik-t
1.0
1.2
1.2
1.2
1.2
1.2
1.?
1.2
I.'*
1 ."
1.1
1 .7
l.P
Avr
60° P.
Tc
64
53
56
53
56
56
•#
So
r,fi
c,/;
r,r.
r.l,
^.7
/.vfr
•
MATERIAL COLLECTED
SO,, and
WEIGHT COLLECTED, GRAMS:
-fifi.
o.ntu
o.rvn
A. TOTAL WEIGHT
SAMPLING POINT ^
SAMPLING NOZZLE ,• __
I.D., I.IM 0.35
ATMOS.. PRESSURE,,
B. STACK GAS FLOW RATE, sent
C. WATER VAPOR CONDENSED, LIQUID
ML
S02
'15
D. WATER VAPOR COHDENSEO, VAPOR VOLUME, 0.0464 x c, SCF
F.. GAS VOLUME METERED, "IV . -SxVMX (P A-PM> / ( 4604TM) . SCF
F. TOTAL CAS VOLUME SAMPLED, D + E, SCF
2.09
3.76
16.80
18.90
17.
G. MATERIAL CONCENTIMTION, 15.43 x A/F, GHAIKS/SCF.
Material concentration, -ppm
II. MATERIAL tLOW RATE, 0.00057 x B x G, LDS/MR
?8
i '-ft
R. 1
-------
TEST NO. C-1805
SAMPLING STATION .
AIR POLLLT ,N CONTROL DISTRICT •• COUNTY LOS ANGELES
PAGE 17
Standard-Sulfur Acid No.'__? DATE 1-11-73
GAS VELOCITY DATA
TIME
12:55
-
POINT
1
?.
•*,
'k '
5
6
7
8
9
10
11
12
13
lli
IS
16
AVK
VEL . HEAD
IN. H20
.04 '
.06
.Ofi
.06
.07
.08
.07
.06
.03
.OS
^n^ ._.
.06
.07
,no
.no
-.OR
TEMP.
°F
120
VELOCITY
FT/SEC
13.9
37.1
17. 1
17.3.
18.5
2Q.7
18.5
^ 7-^-1-
l?.l '
1ST
- 15-7
17.'1
38. *
.21.0, .
?1.0
19-7 •
17,?
VEL. HEAD
IN H20
.0^;
.. .06
0^
.06
.07
.08
.07
-Tns
.nfi
.OR
O1^
'n^
.07
no
.nfl
.OR
TEMP.
°F
130
VELOCITY
FT/SEC
13.9 •
17.1 .
.,17.3. ,.
17.1
18. R
10.7
18.5.
15 7
n.o
I* 7
15 ^
I7 l
_iai__
_?T n
10.7
10.7
. .1.7 Jt ...
VEL. HEAD
IN: 'H20
.M
.hfi
.b<5
.1)6.
-.hfi
-nfi
-07
n£
,nli
n«
U$
•r -J
n<
.07
nR
-OR
• n7
TEMP.
°F
120
VELOCITV
FT/SEC
n.9
17.1
n7 1
IV. 1
17.1
TO. 7
18.^
17 T
TH 0
">7, T
1-7 I
1 ITT
18.S
10 7
r IP.? .
18.^
_ 17. e;
Static5r.02"H 0 (fluctuates)
17.5
B.
C.
D.
E.
F.
G.
H.
J.
K.
L.
M.
INDICATED VELOCITY (REFERENCE PT.) FT/SEC
FIIIF rirrnp.A/R
PlTOT CORRECTION FACTOR.
GAS DENSITY CORRECTION FACTOR
GAS PBFSSHRF, 1^ STACK, 1". n
120
4960
4500
291,, I.D.
ft- 1 60048
(a) Acsiunert value based upon G^S composition info, in permit application.
-------
AIR POLLT 'ON CONTROL DISTRICT -• COUNTY/ r LOS ANGELES
TEST NO. C-1893
SAMPLING STATION
PAGE.
18
Sulfur Unit No.
DATE 1-11-7?
WATER VAPOR AND GAS DENSITY CALCULATIONS
PERCENT WATER VAPOR IN GASES
A. GAS PRESSURE AT METER, IN. HC (ABSOLUTE)
. NaOH
Train
29^25
B. VAPOR PRESSURE OF WATER AT IMPINGER TEMP., IN. HG
.622
G.. TOTAL CAS VOLUME SAMPLED, C + E, SCF
H. PER CEKT WATER VAPOR JN GAS SAMPLE*.100 X F/G
16.80
18.89
n.o
ZnCO
Train
2Q.OS
.469
P WATFR VAPOR MFTFRFP, C X R/A, ^CF
E'. WATFR VAPOR CONOFNSFP,. VAPOR vm HMF, SCF _..,
F. TOTAL WATER VAPOR IN GAS SAMPLE, D + E, SCF
.36
2.09
' j».*i
.26
1.76 -
2.0?
17.8Q
11.-
GAS DENSITY CORRECTION FACTOR
COMPONENT
WATER
CARBON DIOXIDE
CARBON MONOXIDE
OXYGEN
NITROGEN ft INERTS
VOLUME PER CENT/100 >
PRY BASIS
DRY BASIS
DRY BASIS
DRY BASIS
MOISTURE CORRECTION
1 -H/100
1.0
•
: MOL. WT. :
18.0
44.0
28.0
32.0
28.2
V/E 1 GHT
: PER MOLE OF
STACK GAS
1
;
J. MOLECULAR WEIGHT OF STACK GAS
K. DENSITY OF GAS REFERRED TO AIR = J/28.95 =.
L. GAS DENSITY CORRECTION FACTOR = \f\ .00/K =.
. 600^00
-------
AIR >'OLLUTI COJ1THOL DISTRICT - COUNTY OF
Test No. C-1G93
RESULTS OF AK'vLYS-vS
FOH
ORGANIC
AIICLLES
Page 19
Date 1-10-73
1-11-73
TEST STATION:
COHCSNTRATims, PM JJHY BASIS
Sample 1:
2:
3:
li:
IV. AVERAGE CO:;CM., PFM (DRY)
D. Water vapor in gases, vol. %
C. Stack gas flow ratp, scfkn
D. Conversion factor
E. AVERAGE CO! CM., PR! (ViET),
A(l - 0.013)
F. AVG. Cffi.'CN., GRADiS/SCF (lilT),
D x E
G. now Rvre, rourins KR HOUR,
0.00057 x C x F
H. CO.iTHOI, L'FFICJUOCr, J{
onfi.unc
cofipoiiins
AS
CARBON
S UWIT 1
ABSORBER
OUTLET
40
' 93
53
64
11.7
8100
0.000222
57
0.013
0.90
ORGANIC
COMPOUNDS
AS
CARBON
s mrrp S
ABSORUCR
OUTT.ET
61
5^
29
1)8
9.1
5200
0.000222
M
0.0097
0.'('!
•
ORGANIC
COi-TOUJiDS
AS
• CARBON
S IPJTT ?
ABS03ti3FP,
OU7TET
37
24
24
28
11.3
'iyso
0.000222
25
0.0035
0.21
600646
-------
AIR FOLLUTIp" CONTROL DISTRICT - COUNTY OF }"" ANGELES
Tcit Mo. C-1895
RESULTS OF AKILYS-S
fOH
NITROGHJ OXIDES
Page ?o
flato 1-10-73
1-11-73
TEST SI'VTira:
CO'-JCENTR VFT'iMS, Pftt D;«Y mSIS
Swnple 1:
2:
3:
Ii:
4. AVliRAGE COyCM., PPM (nRY)
13. Water vapor an E^SCS, vol. %
C. Stack cas flo" ral«, pcfm
D. Conversion factor
E. AVERAGE CQ!C\'., PPM (\ET),
A(l - 0.01B)
F. AVG. CO\'CH., GRM>:S/SCF (LIT)
D x E
G. FLOU R.'iT'o, !X)IJ!PS KTH HOiJR,
0.00057 x C X F
I!. COM1:*!, L'lTJCli^CY, ^
NTTKOOEW
OXIDSS
AS
NITROGEN
DIOXID3
S 1JJJIT 1
ABSORBSR
OUTLET
11
9
12
11
11.7
8100
0.0008*19
9.7
0.0082
0.57
NITROGEN
OXIECS
AS
in-rnooa-i
DIOXIDE
S UHIT ?
ABSOT3ER
oim.'jrr
19
13
17
16
9.1
5'.}00
o.ooo3'i9
15
0.013
0.59
NITKOCV!
OXIDL5
AS
MITRaV.il
DIOXIHS
S UN'TT "=5
ADSORBER
OUTI.ET
15
21
13
16
n.3
'1500
Cvoooaii?
11
0.032
0.^6
.6on6lj6
-------
APPENDIX I
SOURCE TEST RESULTS
SULFURIC ACID PLANT
-------
/-
/-
V
.134 SOUTH SAN PEORO STREET. LOS ANGELES. CALIF. 90013 - ,\WDISON V-47H / COUNTY OF LOS ANGELES
„ M /• s _
TESTS
CONDUCTED AT
STANDARD OIL CO., V.O.I.
VEST EL SEGUKDO EOULE\'ABD
EL SEGUNDO, CALIFORNIA
ON
MARCH 21 & APRIL 3, 1973
REPORT
ON THE
EMISSIONS TO THE ATMOSPHERE OP SULFURIC ACID,
SULFUR THIOXIDE & SULFTJH DIOXIDE FROl-i A SULFURIC ACID PLANT
Jasss 'J. Nance Supervising Air Pollution Engineer II
George Ames Senior Air Pollution Engineer
SOORCE TESTING SECTION
REPORT NO. C - 1920
Eric E. Lealte Howard DsVorkin
Director of Engineering Supervising Air Pollution Engineer III
ISSUED:-.,, . ,
*•••»« •. i •.«.'.«)
-------
AIR POLLUTION COM'l'KUl. Liiimuoi - VAAHIJ.A \JL
Test No. C-1920
INTRODUCTION
Upon request of the Refinery Unit of the Engineering Division, a source test
was performed on a sulfuric acid plant to determine the emissions to the ataios-
phere of sulfuric acid, sulfur trioxide and dioxide, and oxides of nitrogen.
Ohis plant is located at the Standard Oil Refinery complex, J24 West El Segundo
Boulevard, El Segundo, California. Mr. Robert Ray, APC Coordinator of Standard
Oil, assisted in making the test arrangements. Source Testing personnel Messrs.
J.T. Nance, E.D, Halberg and G. Ames performed the sampling operations. Senior
Air Pollution Engineer K. Lawrence, who initiated the request, was present dur-
ing the test. He obtained data, on equipment operation, which is included in
his observations attached to this report.
TEST RESULTS AND DISCUSSION
Ofce now rate of gases to the atmosphere was l6,'JOO scfm, containing 120 pom of
SOo by volume. Mass emission rate of sulfur compounds was 20.1 Ibs/nr. No sul-
furic acid was found in the samples and any SOj, if present, was below the de-
tectable limits.
On March 21, 1973, a traverse was made with the intention of testing shortly
thereafter; but, due to an upset condition, the test had to be postponed. On
the morning of April ^, one leg of the traverse was rerun. It was repeated in
tiie afternoon prior to the testing period, c.» Source-Testing personnel were id-
formed that a alight upward change in the feed rate had taken place. This did
not seem to affect the flow rate of the gases at the sampling point, according
to the traverse measurements.
The data used on the summary (emission to atmosphere) sheet are from the sam-
pling train with the larger total gas volume sampled, vhich would be expected
to give more reliable results. The values for S02 of 107 and 120 ppm from the
two trains agree quite well within experimental error and values for SO^ and in
both cases were below the detectable limits.
SAMPLING AND ANALYTICAL PROCEDURES
Gases were withdrawn from the stack and passed through duplicate sampling trains,
differing only in the equipment being used for absorption of SO-j. Train 1 used
one SO-z absorber and filter tube, as shown on page 86 of Public Health Service
Publication No. 999-AP-l?, whil* Train 2 used two Smith-Greenberg irapingers. A
complete description of both trains is on page 12 of this report.
Sulfuric acid was removed by the Whatman thimble preceding the iinpingers (ab-
sorber) which contained 8o# isopropyl alcohol for absorbing SO^. She 1PA im-
pin^ers were followed by impin/sers containing NaOH to collect SOg.
-------
Teal; No. C-1920 Page 2
Analysis for SO-, and S02 was done by the analytical laboratory by the barium
chloride gravimetric procedure. Sulfuric acid was determined by & standard acid-
base titration.
Samples for oxides for nitrogen were taken with two-liter evacuated flasks con-
taining a sulfuric acid-hydrogen peroxide absorbing solution and analyzed by the
phenoldisulfonic acid procedure.
A Ifylai* bag was filled with the gases which were then transferred to two-liter
evacuated flasks for a TCA analysis for CO, C02 and CH^. A sample from the bag
was also analyzed with, a conventional Orsat apparatus.
The flow rate of the gases at the sampling station was determined by a standard
pitot tube traverse.
Approved
-------
Test No. C-1920
.
> . -73
*-;-.-3
SCHEMATIC DIAGRAM SHOWING SAMPLING
LOCATION AT STANDARD OIL CO. SULFURIC ACID PLANT
To
Atmosphere
iampling Station
Walkway-Bridge
IPinaT. Absorber with
Mist Eliminator Section
Stack
-------
AIR POLLUT I 0V CONTROL D I STR I CT---COUNTYx-^F LOS ANGELES
TEST NQ. C-1920
PAGE.
DATEjh2=IL
NAME OF
SUMMARY: EMISSIONS TO ATMOSPHERE
Standard Oil Co. of California, V.O.I.
LOCATION OF »- *MT 32-* Vest El Seguado Boulevard
TYPE OF OPERATION,
Manufacture of sulfuric acid
UNIT TESTED.
Sulfur acid plant
RULE NO.
MEASURED
EMISSIONS
ALLOWABLE
EMISSIONS
5Z
53
53
54
58.68.'!
67
67
68
71
PARTICIPATE
MATTER
SULFUR COMPOUNDS
AS SO;
S-COMPS. AS S02
SOLID PARTICULATE
MATTER
COMBUSTION
CONTAMINANTS
COMBUST. CONTAMS.
NOX AS N02
NOX AS NOz
CARBON MONOXIDE
120
GRAINS
PER SCF
PPM BY VOL.
20.1 LB. PER MR.
LB. PER HR.
CHAINS PER
_
SCF AT 12%
LB. PER HR.
LB. PER HR.
PPM BY VOL.
AT 3% 02
• % BY VOL.
GR A t Ns
PER SCF
FPK BY VOL
200 Lo. PER HR.
Ln. PER "HR.
GRAINS PER
SCF AT 12% C02
LO. PER HR.
LB. PER HR.
NOTES* ALL RESULTS ON DRY (OR EQUIVALENT) BASIS. UNLESS OTHERWISE NOTED
PPM BY VOL.
AT i% 02
% BY VOL.
55D29 fl-1
-------
AIR POLLUTION CONTROL DISTRICT - COUNTY OF LOS ANGELES
TEST N0.C-1920 ........... ~>- „.,-. ...^ „,-,•»,,, -rr- PAGE _5_
SUMMARY OF DATA AND RESULTS
TEST SITE, EQUIPMENT, AND TEST CONDITIONS:
J. NAME OF FIRM Standard Oil Co. of California, W.O.I.
Sulfuric acid nlant
2. BASIC EQUIPMENT
3, CONTROL EOUIPMENT
4, EQUIPMENT TESTED
Brink's mist eliminator
Sulfuric acid olant
5. PROCESS WEIGHT, LBS PER HOUR
6. TESTING CONDITION
See engineers observation report
7. SAMPLING LOCAT.ION:
Duct to Stack
GAS FLOW AND ANALYSIS:
8, GAS TEMPERATURE,
9. GAS VELOCITY,
0. CAS FLOW RATE
160
F, $f!Fu ( WET)
. SCFM (DRY}r
;, VOL %t DRY BASt S:
16400
5.8
7.9
ununv IDF •
N
0.0 (nor.e detected by TCA)
86.3
CARBON
OXYGEN
CARBON
NITROGEN
12. GAS ANALYSIS. VOL %. WET BASIS:
WATER VAPOR
CAREON DIOXIDE
OXYGEN
CARGON MONOXIDE
NITROGEN
AIR CONTAMINANTS MEASURED:
13-. MATERIAL COLLECTED
SO^ & SOp
HgSOJj
Train I
SO-,
' HpSOk
Train 2
SO,
14. TOTAL GAS
15. .*T.JGHT COLLECTED, GRAMS _
16. MATERIAL CONCENTRATION:
GRAINS PER SCF
-------
AIR POLLUTION CONTROL DISTRICT •- COUNTY OF. LOS ANGEL,
TEST NO. C-1920
SAUPL I NG STAT I ON Duct to Stack
PAGE
HATP
SAMPLING TRAIN DATA AND CALCULATIONS (DRY BASIS)
TIME
13:30
+ S
10
15
20
25
30
' 35
40
45
_5o
55
60
fin ni"
pr>+
GAS ML rm
READ ING
CU. FT.
VM
VAC.
IN . HG
PM
MP I NCCR
TEMP.
°F
Tj
Train I
4.77
5.0
5.2
5.5
5.6
5.8
6.1
6.4
6.6
\ 6.8
7.1
7.3
7.61
1
? Pk
no-H
4.8
4.8
4.8
5.0
5-3
5.9
5.9
5.9
5-9
5-9
5-9
5.9
-------
rui_l_U i
TEST
C-1920
PAGE _7_
SAMPLING STATION
Duct to Stack
, DATE,
SAMPLING TRAIN DATA AND CALCULATIONS (DRY BASIS)
TIME
13:30
+5
10
15
20
25
30
35 •
40
45
50
55
60
£O TTvin
Y-.o-h
GAS ML ILK
READING
CU. FT.
VM
VAC.
IN. HG
PM
IMPINGER
TEMP.
°F
TI
Train 2
44.46
45.6
47.2
48.6
50.1
51. 3
53-1
54.3
55.7
57.3
58.9
60.3
61.65
17.10
, nnt, „,
1.7
1.7
1.7
1.7
1.7
1.7
1.7
1.7
1.7
1.8
1.7
1.7
1-7
avc
62
60
62
60
60
60
60
60
60
58
58
56
fin
av£
Temp
Thimble
°P.
TTH
74
77
77
77
78
78
77
76
76
75
74
74
7*
av£
1!
MATERIAL mi i mm
t SQ-n & SO? (by impingera)
WEIGHT COLLECTED, GRAMS:
Thimble
ND
. IPA portion of igrpinger train_
<0.0005
MaOH portion of
>r T.Tvri-n
0.149
A. TOTAL WEIGHT.GRAMS
C0.0005 O.l49
6. STACK GAS FLOW RATE, SCFM(DRY).
AT METER. P.~-PU. IN
D. VAPOR PRESSURE OF WATER AT IMP. TEMP.. IN. HG
E. GAS VOLUME METEREO, \'M X C/29.9. SCF
F.
GAS VOLUME
G. MATERIAL CO-NCN. . l5.43xA/F. GRAiNs/scF(Df
-------
AIR POLLUTION CONTROL DISTRICT •- COUNIY OF LOS ANGELES
TEST NO. E-
PAGE 8
SAMPLING STATION
Duct to Stack
DATE *-V73
WATER VAPOR, DRY GAS FLOW RATE. AND GAS DENSITY CALCULATIONS
PERCENT WATER VAPOR IN GASES
A. GAS 'PRESSURE AT METER* PA _ PM. IN. He ABS.
B. VAPOR PRESSURE OF WATER AT IMP. TEMP.. IN. HG
C. GAS VOLUME METERED, VM X A/29.9. SCF
t. WATER VAPOR METERED, C x B/A, SCF
E. WATER VAPOR CONDENSED. LIQUID VOL.. ML
F. WATER VAPOR CONO.. VAPOR VOL.. 0.0464 x E. SCF .
G. TOTAL WATER VAPOR IN GAS SAMPLE, D + F. SCF
H, TOTAL GAS VOLUME SAMPLED, C + F. SCF
J.. PER CENJ WATER VAPOR IN GAS SAMPLE* 100 X G/H
DRY GAS FLOW RATE
K. GAS FLOA RATC. SCFM (WET)
L. GAS FLOW RATE. K(UJ/100). SCFM (DRY) .
GAS DENSITY CORRECTION FACTOR
COMPONENT
WATCH
i
C»REON DIOXIDE
OXYGEN
CARBON MONOXIDE
NITROGEN ft INERTS
TOTAL
MOLECULAR WEIGHT
VOL. VIOO
(DRY)
>at Analysis
0.99'
60043
-------
AIR POLLITJO: CONTTOL DISTRICT - COUNTY OF
Test No. C-1920
RESULTS OF ANALYSES
FOR
& C02 (a)
ANGELES
Page!.
Date 1
OOMPONE.NT:
TEST STATION
CONCENTRATIONS. PPM DRY BASIS
Sample 1:
2:
3:
U:
A. AVEFUGE CONCN. , PPM (DRY)
B. Conversion factor, ppm to grains/sc F
(0.00001846 x Molec. Wt.)
C. Avg. Concn. , grains/scf (dry)
(A x B)
D. Stack gas flow rate, scfm (wet)
E. \\ater \apor in gases, vol. %
F. Stack gas flo* rate, scfm (dry)
DC1-0.01C)
G. Flow rate, pounds per hour
0.00857 x C x F
H. Control Efficiency, %
NO*
as N02
(by PUS)
JH
28
32
28
30
0.0008^9
0.0255
—
16^00
3.6
C02
(by TCA)
59000
59500
609CO
59800
0.000812
48.56
~
16*500
6800
•
(a) No CO or methane detected by TCA analysis.
60D616 n-1
-------
AIR POLL, ON CONTROL DISTRICT •• COUNTY
TEST NO. C-1920
SAMPLING STATION
. -ho S
• LOS ANGELES
PAGE 10
DATE fr-J
GAS VELOCITY DATA
TIME
10:12
12;JO
12:38
POINT
1
2 "
"*
it
5
6
7
8
9
10
Avg 1-10
1
?
3
4
5
6
V
8 '
o
10
Avg 1-10
VEL. HEAD
IN. H20
.10
.12
.11
.r*
.n
.34
.14
.15
.16
.IP
.OS
.11
.13.
.I*}
. ,12
.it
.17
-17
.IS
.-n
TEMP.
°F
160
1
VELOCITY
FT/SEC
22.8
25.0
p"3; o
?6.f)
26.0
— 27 "
27.0
27.9
•9R.Q -
. ?5..D ...
26.0
16.?
OT; 0
«"»/T r»
£U,.u
O^ O
...?fi.n
...07 o
P^.O
._ 2« 0
pFt.o
5Rwn
25.7
VEL, HEAD
IN: H20
.12
.11
',1?
.1?
' .1^
.U
.15
tfi
.T,<;
i?
.06
-\1
— -
.11
1 o
,1^-
u"1 S
.17
-^1^
.T7
T,
TEMP .
°F
160
i
VELOCIT>
FT/SEC
25.0
-_ 2^,9
?R.n
2S.Q
26.0
27,0
27.9
?R Q
?3.o
?n -0
26.4
17-7
O"=i O
— *-^-y—
2^ 0
9c n
0^.0
O'7 O
- *• i . y
T9.8
00 g^
?O P
P6 O
2" n
10:12 Static - .02" H?0
Static - .02" E20
25.9
B.
C.
0.
E.
F.
G.
H.
J.
K.
L.
INDICATED VELOCITY (REFERENCE PT.) FT/SEC
FLUF FACTOR, A/R
P'.TOT CORRECTION FACTOR
GAS DENSITY CORRECTION FACTOR
RAI PRF«;«;IIBF IN ^rtrtc , IN, HR. an<;_
GAS PRESS. CORREC. FACTOR, \/?9.9/F ,
CORPFCTFD VF10CITY, AyHxTx^, FT/qFC
on BxCxPxFxR, FT/SFC ?y.O
ARFA OF FLUE, SO. FT.,.,
AVPflARF Fl IIP TFMP FBiTIIBC , Of.
FLOW RATE, HX.JXKO, TFM 19700 1
• 1.
1.
•
•50.
0.
25.6
12.
160
9^00
00
00
990
1
997
6
/20
\
M. FLOW XATE, (F/29.9)x520xL/(K+460) , sr.FM l6600 16^00
R- I 60C
-------
AIR POLL ON CONTROL DISTRICT -- COUNTY
•TEST NO.
C-1920
LOS ANGELES
PAGE JLI_
SAMPLING STATION
Duct to Stack
DATE 3-21-73
GAS VELOCITY DATA
TIME
10:07
10 1 20
POINT
1
2
3
4
5
6
7
fi
•9
10
11
1?
13
1*
15
16
17
18
19
20
IVK n -20
AVR 1-10
VEL, HEAD
IN. H20
.07
ip
.IS
.It
.IS
.17
.18
.?o
-19
.16
.11 .'_
IS
lis1
.Ifi
.17
..Ifi-
.18
.18
-17
.14
TEMP .
°f
160
VELOCITY
FT/SEC
19.2 .
?S.O
27.9
97,0
27. Q
P0.fi
•vi. 6
•v>.4
•an k
?R a
9-VQ
^7. Q
?7.P
ofi o
PQ.R
9H a
•*).£
^0.6
?QrR
27.0
pR.-^
?8.o
VEL. HEAD
IN H20
.08
.T=! .
, .I1*
1=;
.IS
.16
.?n
.?!
aft
,, .15 .
,no
.1"
.1* ,
.. , O-5 —
.15 .
,17
.17
.17
iR
.W
TEMP.
°F
160
VELOC ITY
FT/SEC.
P0.il
?6,n
27.0 ,
27 9
?7.9
9ft. Q
??.ll
??•!
•w £
27 9
,. ?l .7
?7.r>
?7.n
27.9
?7TP
2Q.R
?9.fi
po.R :
^n.^
,,27.9
?R.l
PR. 9
VEL. HEAD
IN: H20
.np
.,12
'.It
15
' .TS
,lfi
rpn
^10
.19
.16
4no
.ia
.if;
1*
-IS
.16
.17
-17
.1R
.1^
TEMP .
°F
160
VELOC i TY
FT/SEC
..?1.7
?",n
27.0
?7 9
97. Q
pfi.p,...
•X9 J{
^1.^
... 3.1..^.
28 o
-.?l.7.._
27.0
27.0
93.0
27.9
- ?StP.
po.R
po.8
- ?0.6.
^%rf <\
£/ .-?
9fi.T
?8.'5
Static - .04" H20
A. INDICATED VELOCITY (TRAVERSE) FT/SEC
(1-10)
B. INDICATED VELOCITY (REFERENCE PTS)
C. FLUE FACTOR.A/B
28.2
28.2
i.oo
D. PiTOT CORRECTION FACTOR
E. GAS DENSITY CORRECTION FACTOR.
1.00
F. GAS PRESSURE IN STACK, IN. HG. ABS.
G. GAS PRESS. CORREC.
H. CORRECTED VELOCITY,
OR BxCxOxExG, FT/SEC
J. AREA OF FLUE, so. FT._
30.1
.997
28.1
12.6
K. AVERAGE FLUE TEMPERATURE,
L. FLOW RATE, HxJxSO,
M. FLOW RATE, (F/29.
160
21200
, SCFM-
17900
R-\ 60C
-------
AIR POLLUTION CONTROL DISTRICT •• COUNC. OF LOS ANGELES
TEST NO.
C-1920
PAGE
12
DATE _U-
SAMPLING APPARATUS
tor S02 and
_10Q- ML 100.-. ML drj!L-
(a) (b)
t. SAMPLING PROBE
2. DRY f n TEE Whatman Thimble _
3. IMPINGER (DUST CONCENTRATION SAMPLER)
'4. ICE BATH CONTAINER
5. THERMOMETER
6. MERCURY MANOMETER
7. SPRAGUE DRY GAS METER (ZEPHYR NO. 1A)
8. VACUUM PUMP
9. HOSE CLAMP TO CONTROL GAS FLOW RATE
IMPINGER «="' nrinu
filter
isopropyl aleoholt ^0 ml
ppetlvelv. fb> Two S
in ml -rea-
rnnt^im'ng
NaOH. Train 2 (a) two impingers witix
isopropyl alcohol, (b) Two icipingers
containing *j% HaOH.
16-55-Oie
-------
AIR PCV 'JTION CONTROL DISTRICT - COUNP" IF LOS ANGELES
ENGINEERING DIVISION
OBSERVATIONS DURING SOURCE TEST NO. c-a920
Stream data follows:
Spent Acid Densities 755 Acid 13.95 Ibs/eallon
85# Acid 14.8? Ibs/gallon
Average l'J.4 Ibs/eallon
Product Acid 15-0 Ibs/eallon
1 gallon/bin (feed) 8.77 tons/day, product acid
HgS
1000 SCFH @ 32°F. 6530 Ibs/day, product acid
Stack observations appear on page 3« During a period of 3^- hours (11:00 am
to 2:30 pm) no visible eaission v/as noted. This can be attributed to the
effectiveness of a "Brink, Mist Elininator" mounted inside the final absrober,
C-560.
SOo concentration in stack sas is measured once daily by Standard Oil operators.
The 5 A!-! reading was l6o ppra. The estimated design loss at rated throughput
is 86 Ibs/hr.
Maxwell La^.Tonce, Sr. A. P. Engineer
-------
AIR POLLUTION CONTROL DISTRICT - COUNTY OF LOS ANGELES
ENGINEERING DIVISION
OBSERVATIONS'OURING SOURCE TEST NO
N7,1.^ Standard Oil Co-roany of California rfsr ^-3-73
EOU^T Sulfurie Acid H;covery plant »PPL"H1No.:
,£"»«.»«. H":-:^ffi-«kl"-2s32- «™ JMZ «» *> to ^ T.?H
.uce & T i TI re nr
Kcsnrs. Bob Ray and Carl Pederson _
PERSONS CONTACTED
Maxwell Lawrence. Senior Air Pollution Engineer
REPORT BY
03SERVATJONS MADE AND DATA RECORDED DURING TEST:
This test was made to evaluate the operation of a sulfuric acid, recovery
plant. Design recovery is 300 tons of acid (992 H2SOjt) per day.
At the tine of this, test^ the plant was processing spent acid
from 75 to 85,? sulfuric acid) and sour gas (HgS). Based or. feed rates,
throughput in estimated to bs 8S<5 of capacity; that is, 265 tons of acid per
day.
Feed and product flows, taken froTi strip-charts, are listed
Time 11:15 12:15 1:00 1:'}0 2:10 2:25
Spen^Acid, (GPH) 19-0 19-0 18.7 19.0 l8.6 18.9
H2S (SCFH) 28.8 H 30.^ 30.8 M 30.8 K 30.8 M 30.8 K
Fuel Gas (SCFI{) 9.6 M 10.8 M 10.8 M 10.8 H 9-8 M 9-8 M
Recycle Acid (#)
Product (GPM) - - 25.6 27.2 26.8 26.8
Feed equivalent of product, tons/day;
Tiae 11:15 12:15 1:00 1:^0 2:1O 2:25
Spent Acid 167 l6? l^t 163 163 166
H2S 9^ 99 101 101 101 101
TOTALS 26l 266 265 26'1 26«f 267
50C2I7 R1.C1.6 P*M'
-------
A IK HULLUIIU." l-Ull I rtui. u i :> in ik, i •
434 SOUTH SAN PEDI STREET. Los ANGELES. CAL
90013 MADISON 9-47JI
ENGINEERING DIVISIONS-FIELD REPORT
*AU£ Of 1-PLlC'NT
STAiraARD on, CCMPANY OP CALiPOSJiA, w. OPS., n:c. Jt-3-73
tOUIPMENT LOCATION UoOftC*!) *"
•2'! Vest El Eesundo Boulevard, El Sofrundo, California ^-0^573
""""iv^Vs" HiSOii Kcoovary Plant ios"«?««is SOz. H-.SO-.
oIltJ^T^N Crcui"' Level 100-200 Ft, Ko. & So. "«£•!« 1^0 Ft. "ip-h Stack
.fOHIl pair
,i«o _ ,_, 1 HOURS or FKo-iT.grj P ™ TO o.^O D m
OBSERVATIONS OF VISIBLE AIR CONTAMINANTS
TIME
FROM
11:00
12:00
32:15
12:20
12:?.5
3.2:10
12:^=5
12:'iO
12:^5
12:50
!2i55
1:00
1:10
1:30*
1:^0
1:50
2:00
2:10
•co ton
"8" WEJN3
"*" MCtl.i
- H(«»s
. MC1HJ
TO
11:15
12:15
12-9ft
12-25
12:7O'
12: 15
12:-0
10. Ue^
12:50
12:55
1:00
1:10
1:?0
1:''0
1:50
2:00
2:10
?'.">r>
CO DC:
B\.K<
W1ITC
IflTERVAL
HIN.
UTE£
15
15
S
5
5
5
c
c;
5
5
10
in
in
10
10
10
11
1jQ
*
SEC-
ONDS
r. Of ACI Tf
OR
RlNCEL-
M^IIN Fi'O
0
»
1
COLOr)
*(SIE
CODE ,
eCLO«l
V
•
Heat emission cmlv vaa nctpd.
•
•
•
-
•
1 TOTAL Tl- •" 0^ DlSu--rtC£ OF AIR C- OS C.^EA7f«!
best started
»
P*«E ^ 0
.^./ti\*.tlhl/ff)£fl.'fa.'&
Maxwell Lflvrrcnco, Sr. A. ?. £:. -ir-eci'
r__2_p»cEs i£.' iiios TiJ-SS-S
------- |