COMPLIANCE AND EMISSION DATA SUMMARY
FOR PETROLEUM REFINERIES IN REGION VIII
EPA Contract No. 68-02-1378
Task Order No. 19
Pacific Environmental Services, inc.
1930 14th Street Santa Monica, California 90404
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SECTION 1. INTRODUCTION
This report summarizes compliance status and pollutant emission sta-
tistics for the twenty-eight refineries in Region VIII. Information presented
in this report was gathered in January, 1976, from Environmental Protection
'Agency (EPA) offices in Denver, Colorado, and from state air pollution control
agencies in Denver, Colorado; Salt Lake City, Utah; and Cheyenne, Wyoming.
The information represents the most recent data available from these agencies.
Pacific Environmental Services (PES) project engineers also obtained supple-
mentary data from technical publications such as the "Annual Refining Survey"
of The Oil and Gas Journal (April, 1975).
The remainder of this report summarizes the results of this phase of the
project and presents analyses of the relevant data items. Section 2 includes
a brief overview of each of the refineries and includes discussions of com-
pliance status and areas for additional investigation for each plant. In
Section 3, the project staff has identified major process sources for each of
the criteria pollutants (particulates, SO,-,, hydrocarbons, CO, and NO ) and
u A
presents a qualitative overview of the compliance status of these major sources
at each plant. Then in Section 4, available quantitative data have been sum-
marized for these major process sources. During the work of the project, cer-
tain problems were uncovered in existing state and local regulations. These
are discussed in Section 5. Finally, Section 6 deals with application of Federal
New Source Performance Standards to sources in the region.
Another objective of this project has been to discuss any areas of liti-
gation which apply to refinery sources. However no litigation areas ware
uncovered for the refineries in Region VIII.
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SECTION 2, PLANT SUMMARIES
2.0 This section presents a brief summary of compliance problems and areas
where further analysis is required for each of the refineries in the region.
For each plant, compliance status is summarized and any sources which are
not in compliance are discussed. When available, compliance status was
determined by process information supplied by the state agencies.
In some cases, information was unavailable or incomplete. In these cases,
project engineers uncovered areas which require further investigation.
These areas include: 1) Data were ambiguous or insufficient to allow deter-
mination of compliance status and/or pollutant emissions; 2) Some refineries
did not report data for units such as loading racks or catalytic cracker-
catalyst hoppers; 3) The collection efficiencies provided by the state for
many pieces of control equipment were inconsistent with values experienced
by the project engineers. Some values were overly optimistic while others
fell short of expected values. As a result, a series of source tests are
recommended to determine the actual results of the control equipment.
It should be pointed out that the report reflects the amount of information
available during the early months of 1976. In some cases, the analysis
has been updated as information became available, however it is possible
that PES was not advised of changes in plant status. This may become
apparent in refineries which have submitted compliance schedules for out
of compliance sources after the data gathering task was completed.
2.1 COLORADO
2.1.1 Continental Oil Company (CONOCO); Commerce City, Colorado; 30,000 BPD.
There are three sources which were determined to be out of compliance
with sulfur emission limitations. Process heaters H 1 and H 11 are
out of compliance due to the high sulfur content of the fuel. The
FCC unit is also out of compliance with sulfur regulations. There
were no known compliance schedules for the sources. A source test
is recommended for sulfur dioxide emissions of the FCC unit. The cata-
lyst handling operations on the FCCU should be inspected for opacity
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or fugitive emission problems.
Areas for further investigation include:
1) Where do the vacuum distillation jets exhaust to?
2) Where does the sour exhaust gas from the catalytic hydrotreater go?
3) What type of process is used in asphalt production? Is there any
asphalt oxidation? What are the operating hours and process weight
of the asphalt production? What type of control equipment is used,
and what is its efficiency?
4) Are there any loading racks, and what kind of control equipment
is used?
5) What type and quantity of petroleum storage is used, and what
type of vapor control equipment is used?
2.1.2 The Refinery Corporation; Commerce City, Colorado; 21,000 BPD.
The fluid catalytic cracking unit was found to be out of compliance
with particulate emission regulations, as well as sulfur dioxide
limitations. The waste gas furnace was also found to be out of
compliance with sulfur regulations. There were no known compliance
schedules for the sources.
The catalyst handling operations on the FCCU should be inspected for
opacity or fugitive particulate emission problems. A source test is
recommended to ensure accurate particulate and sulfur emission rates
for the FCCU. It may also be desirable to source test the waste gas
furnace for confirmation of actual sulfur dioxide emissions.
Possible areas for further investigation include:
1) Where does the exhaust of the vacuum jets go?
2) Is there any external collection equipment operating on the FCCU?
What type of collection equipment is it, and what is its efficiency?
3) Is there an oil-water separator? Is it covered or uncovered?
How much waste water does it process per year?
4) What type and quantity of petroleum storage is used? What type
of vapor control equipment is used?
5) Are there any loading racks, and what type of control equipment
is used?
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2.1.3 Gary Western Company (Gary Operating Company); Gilsonite, Colorado;
9,500 BPD.
The catalyst regenerator was found to be out of compliance with parti-
culate regulations. There was no known compliance schedule for this
source, A source test may be desirable to confirm the compliance
status of the catalyst regenerator. There are two sources where the
compliance status could not be determined. The emission estimates
in the state questionnaire summarized a source test, however,a. copy of the
test results was not available. The emission estimates indicated
that the group of three boilers (with a total of 439 x 106 BTU/hr
input) had a particulate emission rate of 2142 Ibs/hr, or 4.38 lbs/106
BTU. Since the boilers are fueled by a combination of oil and gas,
it was felt that the results of the source test were improperly
reported, or the source test was not valid. It is suggested that
a copy of the source test be reviewed, or a new source test be
conducted.
The compliance status of the"£oke vapor/liquid blowdown system"is also
unknown. There were insufficient data available to determine the dis-
posal equipment of the system and its compliance.
i
The processes used at this refinery are unique in the industry.
Although the information contained in the state questionnaire covered
most operating parameters, references were made to pieces of equipment
about which nothing was known. Where references existed, the equip-
ment was often only identified by plant coding numbers. Because of
the uniqueness of the processes used in this facility, it was not always
known what the exact function of the coded equipment was, or how it
was specifically associated with the process.
The information available from the data gathering is reflected in
this reportj but an inadequate understanding of the plant operations
makes it impossible to know what processes were not included in that
information. For this reason, it may be desirable to perform a com-
plete plant inspection and analysis of the facility.
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Possible areas for further investigation include;
1) Does the coker vapor/liquid blowdown system exhaust to a flare?
If yes, what is the minimum operating temperature of the flare,
and is it equipped for smokeless operation?
2) What type and quantity of petroleum products are stored at the
facility, and what type of control equipment is associated with
each tank?
3) Is there ari oil-water separator? Is it covered or uncovered?
How much waste water does it process per year?
4) Are there any loading racks? If so, what kind of control equip-
ment is used on them, if any?
5) Where does the sour exhaust gas from the catalytic hydrotreater go?
2.2 MONTANA
2.2.1 Exxon Company; Billings, Montana; 45,000 BPD.
The fluid coker is out of compliance with particulate emission regula-
tions. There is no known compliance schedule for the source. A source
test is recommended to confirm the emission estimates.
The combination fuel fired process heaters (which include a standby
boiler) are considered to be out of compliance with sulfur regulations
due to high sulfur content of the fuel oil. There is no known com-
pliance schedule for the sources.
Areas for further information include:
1) Are there any loading racks? If so> what control equipment is
used, if any?
2) Is there an oil-water separator in use at the facility? Is it covered
or uncovered? How much waste water does it process during the
year?
3) What type of process is used in asphalt production? Is there any
asphalt oxidation? What are the operating hours and the process
weight of the asphalt production? What type of control equipment
is used, and what is its efficiency?
2.2.2 Big West Oil Company; Kevin, Montana; 5,100 BPD.
This refinery was found to be in compliance. The facility is exempt
from petroleum storage regulations because its process capacity is
less than 7,000 BPD.
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Areas of further investigation include:
1) What process is used in asphalt production? Is there any asphalt
oxidation? What are the operating hours-and the process weight
of the asphalt production? Is there any control equipment used,
and what is its efficiency?
2.2.3 Farmers Union Central Exchange (CENEX); Laurel, Montana; 42,500 BPD.
The fluid catalytic cracking unit is out of compliance with particulate
regulations. A source test is recommended to confirm emission estimates.
There was no known compliance schedule for this source.
The combustion units in the refinery are listed as out of compliance,
not on a schedule even though the actual emissions are less than the
allowable emissions. These combustion units have been listed this way
because the emission data represents combination fuel firing. The low
sulfur content of the gas offsets the high sulfur content of the fuel
oil. If the combustion units are fired solely on fuel oil, then they
would be out of compliance. There were no known compliance schedules.
The plant was inspected by EPA personnel on August 7, 1975. Sources
which were found to be out of compliance with visible emission observa-
tions were the number three (#3) boiler with-an average opacity of sixty-
three percent; the new (1970) platformer charge heater with an average
opacity of seventy-seven percent; and the north stack of the crude
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heaters with an average opacity of sixty-eight percent. A Notice of
Violation was issued for the number three (#3) boiler, however it is
not known if similar action was taken for the other sources found to
be out of compliance with visible emission limitations.
The compliance status of the sulfur dioxide emissions of the sulfur
recovery plant are exempted from regulation. The regulations state that
waste gas incineration is exempt from sulfur regulations if the unit
manufactures sulfur from sulfur compounds.
Areas for further investigation include:
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1) Is there an oil-water separator at tha facility? Is it covered
or uncovered? How much waste water does it process per year?
2) Are there any loading racks at the facility? What type of con-
trol equipment is used, if any?
3) What type of process is used in the asphalt production? Is there
any oxidation? Is there any control equipment used, and if so,
what type is it and what is its efficiency? What are the operating
hours of the asphalt production, and how much material does it
process in an operating day?
4) What type of control equipment is used to minimize fugitive dust
losses during loading of the catalyst hoppers on the FCCU?
5) Does the sour exhaust gas from the catalytic, hydrotreater enter
the sulfur recovery plant?
6) What type of auxiliary fuel is used in the flares, and what is
its sulfur content? Are they equipped for smokeless operation?
2.2.4 Continental Oil Company (CONOCO); Billings, Montana; 52,500 BPD.
The FCCU was found to be out of compliance with particulate emission
limitations. A source test is recommended to confirm compliance status.
There was no known compliance schedule for this source. EPA personnel
inspected the plant on August 6, 1975 and performed a visible emission
observation of the stack on the FCCU regenerator. The average opacity
observed was fifty-four percent. It is not known if a Notice of Viola-
tion was issued.
Boiler numbers one and two, which share a common stack, are out of com-
pliance with the regulation concerning sulfur content in fuels.
The compliance status of the oil-water separator is unknown because it
is not known if the separator is uncovered or is controlled with a
covers floating roof, or vapor collection system.
Areas for further investigation include:
1) Does the oil-water separator have a cover, floating roof, or
vapor recovery system?
2) Is there any control equipment used to minimize the emission of
fugitive dust when the catalyst hoppers of the FCCU are filled?
3) Where does the sour waste gas from the catalytic hydrotreater go?
4) What type of process is used in asphalt production? What are the
operating hours and what is the quantity processed per day? Is
there any oxidation?
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5) What type of auxiliary fuel is used in the flare, and what is its
sulfur content?
2.2.5 Phillips Petroleum Company; Great Falls, Montana; 6,000 BPD.
This facility was found to be in compliance.
Possible areas for further investigation include:
1) Where do the sour waste gases from the catalytic hydrotreater go?
2) What type of process is used in the asphalt production unit? Is
there any oxidation? What are the operating hours and the amount
of material processed per day? Is there any control equipment, and
if so, what is its efficiency?
3) Does the facility have any loading racks? What is the gallon through-
put per day? Is there any control equipment? What is its efficiency?
2.2.6 Westco Refining Company; Cut Bank, Montana; 4,700 BPD.
This refinery was found to be in compliance.
Possible areas for further investigation include:
1) Does the facility have any loading racks? If so, are they equipped
with any control equipment? What is its efficiency? How many
gallons throughput are there per day?
2) What kind of control equipment is there on the oil-water separator?
What is its efficiency?
3) Where does the sour waste gas from the catalytic hydrotreater go?
2.2.7 Tesoro Petroleum Company; Wolf Point, Montana; 2,700 BPD.
This refinery was found to be in compliance.
Possible areas for further investigation include:
1) Is there an oil-water separator? Does it have a cover, floating
roof or vapor recovery system? If so, what is its efficiency?
2) Is there a loading rack? Does it have any control equipment?
What is its efficiency?
2.3 NORTH DAKOTA
2.3.1 American Oil Company (AMOCO); Mandan, North Dakota; 53,000 BPD.
Even though the FCCU is equipped with secondary multiclones, it was
found to be out of compliance. A source test is recommended to confirm
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the compliance status. There was no known compliance schedule.
The crude furnace heater is out of compliance with sulfur regulations.
To establish actual sulfur emissions, a source test is recommended.
There was no known compliance schedule.
Possible areas for further investigation include:
1) Where does the blov;/-down system vent? Is there a vapor recovery
system? What is its efficiency?
2) Are there any loading racks? Are they equipped with any control
equipment? What is its efficiency?
3) Is there a catalytic hydrotreater at the refinery? If so, where
does the sour waste gas go?
4) The FCCU catalyst hoppers should be observed during loading to
ensure that steps are taken to minimize fugitive dust. Is there
any control equipment used during loading?
2.3.2 Northland Oil and Refining Company; Dickinson, North Dakota; 5,000 BPD.
This refinery was found to be in compliance.
Possible areas for further information include:
1) How many million gallons of water does the cooling tower process
per day?
2) How many barrels of waste water does the oil-water separator
process per day?
2.3.3 Westland Oil Company; Williston, North Dakota; 4,500 BPD.
This refinery was found to be in compliance.
Possible areas for further investigation include:
1) Is the flare equipped for smokeless operation?
2) What type and quantity of petroleum products are stored at the
facility? What type of storage is used, and what type of control
equipment is on each tank, if any?
3) Is the loading rack equipped with any control equipment? What is
its efficiency?
4) Where is the sour waste gas routed from the unifiner?
5) Where are the exhaust gases from the platformer routed?
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2.4 UTAH
2.4.1 American Oil Company (AMOCO); Salt Lake City, Utah; 39,000 BPD.
The FCCU was found to be out of compliance with particulate regulations.
A source test is recommended to confirm compliance status. A visible
emission violation was noted.from the FCCU CO boiler stack during a
2/27/75 EPA inspection. Possible areas for further investigation include:
1) Where does the blow-down system vent?
2) Is there a flare at the refinery? Is it equipped for smokeless
operation?
3) How much water does the oil-water separator process per day? Is
it uncovered or covered?
4) Where does the sour waste gas from the catalytic hydrotreater go?
5) Where do the waste gases from the catalytic reformer vent?
6) What process is used in the asphalt production? Is there any
oxidation? What are the operating hours? How many barrels are
processed per day? Is there any control equipment? What type of
unit is it, and what is its efficiency?
7) Are there any loading racks at the plant? Are they equipped with
any control equipment?
2.4.2 Phillips Petroleum Company, Woods Cross, Utah; 42,000 BPD.
The refinery was found to be in compliance.
Possible areas for further investigation include:
1) The catalyst hoppers for the TCC should be observed during loading
to observe fugitive dust emissions, and what steps are taken to
minimize the emissions.
2) Where do the exhaust gases from the vacuum jets vent?
3) Where does the sour waste gas from the catalytic hydrotreater go?
4) What type of process is used in the asphalt production? Is there
iany oxidation? What are the operating hours? How many barrels
are processed per day? Is there any control equipment? What
kind of control equipment is it, and what is its efficiency?
5) Is there an oil-water separator at the refinery? Is it covered
or uncovered? How much water does it process per year?
6) Are there any loading racks at the refinery? Is it equipped with
any control devices? What is its efficiency?
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2.4.3 Western Refining Company; Woods Cross, Utah; 10,000 BPD.
The existing units were found to be in compliance at this refinery,
but the compliance status of those sources subject to NSPS is unknown.
There are two (2) 10,000 BBL storage tanks which are being built or
have recently been finished. A source inspection is recommended to
ensure the tanks meet NSPS requirements. The refinery is also building,
or has recently finished, an Orthoflow catalytic cracking unit. The
compliance status of this unit is also unknown. A source test is
recommended for particulate and carbon monoxide levels to insure that
the emissions meet NSPS.
Possible areas for further investigation include:
1) Will there be a CO boiler on the FCC? What will it use as auxiliary
fuel? What is the sulfur content of the fuel?
2) What type of measures are taken to minimize fugitive dust emissions
from the loading of catalyst hoppers?
3) Where do the waste gases from the vacuum jets go?
4) Is there an oil-water separator at the facility? Is it covered
or uncovered? How many gallons of waste water are processed per
day?
5) Are there any cooling towers at the facility? How many gallons
of water do they process per day?
6) Are there any loading racks at the facility? Are they equipped
with any control equipment? What is its efficiency?
7) Has there been any progress in constructing a catalytic reformer?
Where will the waste gases go?
8) Will there be a catalytic hydrotreater installed for the cata-
lytic reformer? Where will the sour waste gases go?
9) Is there a flare at the refinery? Is it equipped for smokeless
operation?
2.4.4 Chevron Oil Company; Salt Lake City, Utah; 45,000 BPD.
This refinery was found to be in compliance.
Possible areas for further investigation include:
1) The CO boiler on the FCCU was to become operational in the second
quarter of 1975. Is the CO boiler now operational? What kind of
auxiliary fuel will be used in the boiler? How much sulfur is in
the fuel?
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2) The catalyst hoppers on the FCCU and the HCCU should be observed
during loading to ensure that steps are taken to minimize fugitive
dust.
3) Is there an oil-water separator at the plant? Is it covered or
uncovered? How much waste water does it process per day?
4) Where does the blow-down system vent?
5) Is there a flare? Is it equipped for smokeless operation?
6) Where do the gases from the vacuum distillation jets vent?
7) Is there a catalytic hydrotreater? Where does the sour waste
gas go?
8) Where does the waste gas from the catalytic reformer go?
9) The method of control of blow-down vapors from the delayed
coker should be investigated for potential hydrocarbon problems.
Where are these emissions vented?
10) The storage and handling procedures used for the product coke
should be examined for sources of fugitive particulate emissions.
2.4.5 Husky Oil Company; North Salt Lake City, Utah; 23,000 BPD.
This refinery was found to be in compliance.
Possible areas for further information include:
1) Where do the exhaust gases from the vacuum jets go?
2) Where do the sour waste gases from the catalytic hydrotreater go?
3) Where do the waste gases from the catalytic reformer go?
4) Is there an oil-water separator at the refinery? Is it covered
or uncovered? How much waste water does it process per day?
5) In July, 1975, mention was made of installing a CO boiler on the
Thermofor catalytic cracking unit. Is this boiler under construc-
tion, or has it been completed? Will the auxiliary fuel and its
sulfur content.be the same as projected?
6) Is there a flare at the refinery? Is it equipped for smokeless
operation?
7) Loading of the TCCU catalyst hoppers should be observed for
fugitive dust emissions and to ensure that steps are taken to
minimize those emissions.
2.4.6 Caribou Four Corners, Inc.; Woods Cross, Utah; 5,000 BPD.
This refinery was found to be in compliance:
Possible areas for further investigation include:
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1) Is there a catalytic hydrotreater at the refinery? Where does its
sour waste gas go?
2) Where does the waste gas from the catalytic reformer go?
3) Is there an oil-water separator at the refinery? Is it covered
or uncovered? How much waste water does it process per day?
4) Are there any cooling towers? How much water do they process
per day?
2.4.7 Plateau Incorporated; Roosevelt, Utah; 8,000 BPD.
The FCCU at Plateau, Inc. was scheduled to start operations in
November, 1974. It is not known if construction started on the unit
before the applicable NSPS dates. The compliance status of the unit
is unknown. A source test is recommended to determine the compliance
status.
Possible areas for further investigation include:
1) Is there a CO boiler on the FCCU? What is its auxiliary fuel,
and what is the sulfur content of the fuel?
2) What is the coke burn-off rate of the regenerator?
3) Is there external control equipment on the FCC? What is its
efficiency?
4) Is there an oil-water separator at the refinery? Is it covered
or uncovered? How much waste water does it process per day?
5) Are there any cooling towers? How much water do they process per
day?
6) Is there a flare at the refinery? Is it equipped for smokeless
operation?
7) Does the refinery have any loading racks? Are they equipped
with any control equipment?
8) What is the type and volume of petroleum storage? A tank list is
needed with products stored in each tank arid what kind of control
equipment is used for each tank. The vapor pressure of each
product is needed to determine emissions.
9) Is there a blow-down system at the refinery? Is it controlled
or uncontrolled? Where does it vent?
2.5 WYOMING
2.5.1 Tesoro Petroleum; Newcastle, Wyoming; 10,500 BPD.
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The Thermofor catalytic cracking unit was found to be out of compliance
with the particulate emission limitations from the process information
available from NEDS. A source test is recommended. There was no known
compliance schedule.
The compliance status is unknown for the fixed-roof gasoline storage
tanks. CDS indicated that the horizontal flare is not in compliance,
but was on a schedule. There was no other information available for
the flare, hence, the compliance status of its hydrocarbon emissions
is unknown.
Possible areas for further investigation include:
1) Is there any external control equipment on the TCCU? What is its
eff ici ericy?
2) The loading of the catalyst hoppers on the TCC should be observed
to ensure that steps are taken to minimize fugitive dust emissions.
3) Since CDS indicates the flare is on a compliance schedule, the
progress of the compliance schedule should be checked, or if the
project has been completed, a visual observation is needed to
ensure smokeless operation.
4) What type of auxiliary fuel does the flare use, and what is its
sulfur content?
5) Is there a blow-down system at the refinery? Where does it vent?
6) Is there an oil-water separator at the facility? Is it covered or
uncovered? How much water does it process per day?
7) Are there any product loading racks? Are they equipped with any
control equipment?
8) Are there any cooling towers at the plant? How much water do
they process per day?
2.5.2 Little America Oil Company, Evansville, Wyoming; 24,000 BPD.
CDS indicated the compliance status is unknown for particulate-
emissions from the TCCU. The process weight rate for the unit is
unknown and the allowable limits could not be established. Process
information should be secured in order to determine allowable emissions.
A source test may be desirable to confirm compliance status.
The compliance status of the flare is also unknown. Smokeless operation
is needed to conform to the state regulations. It is recommended that
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the flare be observed during operation to establish compliance status.
There was insufficient data available to determine the compliance
status of petroleum storage at the refinery. Type of material stored,
vapor pressure, type of tank, and throughput are needed to determine
compliance status.
Possible areas for further investigation include:
1) Where do the exhaust gases from the vacuum distillation jets go?
2) Where does the sour waste gas from the catalytic hydrotreater go?
3) Where do the waste gases from the catalytic reformer go?
4) Is there a blow-down system at the refinery? Is it controlled or
uncontrolled? Where does it vent?
5) Is there an oil-water separator at the refinery? Is it covered
or uncovered? How much water does it process per day?
6) Are there any cooling towers? How much water Jo they process per
day?
7) Are there any product loading racks at the refinery? Are they
equipped with any control equipment?
8) What type of process is used for asphalt production? Is there
any oxidation? What are its operating hours? Is there any con-
trol equipment? What is its efficiency?
2.5.3 American Oil Company (AMOCO); Casper, Wyoming; 43,000 BPD.
The compliance status of the vacuum jets is unknown because there
was no information about control equipment.
The compliance status of the flare is also unknown. It should be
observed during operation to ensure that it does not smoke while
burning.
The 1973 NEDS data indicated the bauxite cooler was out of compliance,,
but on a schedule. This source should be checked to ensure the equip-
ment is operating properly and the source is in compliance. A source
test may be desirable to confirm compliance status.
Possible areas for further information include:
1) Where do the exhaust gases from the vacuum jets go?
2) The loading of the catalyst hoppers on the FCC should be observed
to confirm that steps are taken to minimize fugitive dust emissions.
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3) Where do the sour waste gases go from the hydrotreater?
4) Where do the waste gases from the catalytic reformer go?
5) What type of control equipment is used on the bauxite burner?
What is the process weight rate? How is the material transferred?
Have any steps been taken to minimize fugitive emissions?
6) Is there an oil-water separator at the refinery? Is it covered or
uncovered? How much water does it process per day?
7) Are there any product loading racks at the refinery? Are they
equipped with any control equipment?
8) Are there any cooling towers at the plant? How many gallons of
water do they process per day?
9) What type of process is used iri the asphalt production unit? Is
there any oxidation? What are the operating hours of the units?
What type of control equipment is used? What is its efficiency?
2.5.4 Pasco, Inc.; Sinclair, Wyoming; 48,600 BPD.
The fluid catalytic cracking unit was found to be out of compliance based
upon the 1974 data available from the state. There was no known
compliance schedule. A source test is recommended to confirm com-
pliance status.
CDS indicated the compliance status was unknown for gasoline storage.
Type of tank, vapor pressure, and throughput is needed to determine
emissions and compliance status.
The compliance status of the flares was also unknown. They should
be observed during operation to ensure that they are smokeless while
in operation.
The vacuum jets' compliance status was also unknown by CDS. Informa-
tion is needed as to where the exhaust gases are vented. Is there
any control equipment?
Possible areas for further investigation include:
1} Where do the sour waste gases from the catalytic hydrotreater vent?
Is there any control equipment?
2) Where do the waste gases from the catalytic reformer go?
3) Is there an oil-water separator? Is it covered or uncovered?
How much water does it process per day?
4) Are there any product loading racks at the refinery? Are they
equipped with any control equipment?
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5) What type of process is used in the asphalt production? Is there
any oxidation? What are the operating hours? Is there any con-
trol equipment? What is its efficiency?
6) The loading of the catalyst hoppers of the FCCU should be observed
to see that steps are taken to minimize fugitive particulate
emissions.
2.5.5 Texaco, Incorporated; Evansville, Wyoming; 21,000 BPD.
The fluid catalytic cracking unit was found to be out of compliance
with particulate emission limitations. The 1975 CDS data did not
show a compliance schedule for the source. A stack test is recom-
mended co confirm compliance status.
It was not known if the flare is equipped for smokeless operation,
hence the compliance status could not be determined. It is recom-
mended that the flare be observed while in operation to determine
if it produces smokeless exhaust.
The compliance status of the gasoline storage tanks could not be deter-
mined with the information available. The vapor pressure, size and
type of tank, and throughput are needed to determine emissions and
compliance status.
There wos insufficient information available to determine the com-
pliance status of the vacuum jets. It is not known where the gases
from the vacuum jets are vented.These data are needed to determine
compliance status.
Possible areas for further investigation include:
1) Where do the sour waste gases from the catalytic hydrotreater go?
2) Where do the waste gases from the catalytic reformer go?
3) What type of process is used in the asphalt production? Is there
any oxidation? What are the operating hours of the unit? How
much material is processed per day? Is there any control equip-
ment? What is its efficiency?
4) Is there an oil-water separator at the refinery? Is it covered
or uncovered? How much water does it process per day?
5) Are there any product loading racks? Are they equipped with any
control equipment?
455
-------
2.5.6 Sage Creek Refining; Cowley, Wyoming; 1,200 BPD.
The state agency was unable to supply any information about the plant.
The Oil and Gas Journal showed the facility.to have a catalytic
reformer. Although this was the only information available, it implies
that the facility is not a simple topping plant. It is recommended
that a full information survey be conducted by a Section 114 data
request or plant inspection.
2.5.7 Husky Oil Company; Cody, Wyoming; 11,000 BPD.
The compliance status of the flare is unknown because it is not known
if it is equipped for smokeless operation.
The emission factors used to determine emission estimates for the FCCU
were listed in the NEDS print-out and were developed by the National
Air Data Branch. It is riot known if these factors wore specially
developed for this unit, or why they were applied. It may be desira-
ble to investigate the reasoning for using the factors. Based upon
the special factors, the unit was found to be in compliance. AF-42
factors would also show the unit to be in compliance.
Possible areas for further investigation include:
1) Where do the sour waste gases from the catalytic hydrctreater go?
2) Where do the waste gases from the catalytic reformer vent?
3) Where is the exhaust gas from the vacuum jets routed?
4) Are there any product loading racks at the refinery? Are they
equipped with any control equipment?
5) The loading of the catalyst hoppers on the FCC should be observed
to see that steps are taken to minimize fugitive dust emissions.
2.5.8 Husky Oil Company; Cheyenne, Wyoming; 25,000 BPD.
The NEDS print-out stated that the compliance status of the oil-water
separator is not known.
The compliance status of the flare is unknown. The flare has to be
equipped for smokeless operation in order to be in compliance.
The fluid catalytic cracker was source tested March 1.8, 1975 and was
determined to be in compliance. A copy of the test summary was not
available.
456
-------
Possible areas for further investigation include:
1) Where do the exhaust gases from the vacuum jets go?
2) Where does the waste gas from the catalytic reformer vent?
3) Where does the sour waste gas from the catalytic hydrotreater vent?
4) What type of process is used for asphalt production? Is there any
oxidation? What are its operating hours? How much material is
processed per day? Is there any control equipment?
5) Are there any product loading racks at the refinery? Are they
equipped with any control equipment?
6) The loading of the catalyst hoppers on the FCC should be observed
to ensure that steps are taken to minimize fugitive particulate
emi ssi ons.
457
-------
SECTION 3. COMPLIANCE DATA SUMMARIES
3.0 In this section, a series of tables is presented which summarizes the
compliance status of each of the major polluting units in the region.
Each table deals with a separate pollutant, and contains data for the most
significant sources of that pollutant. For more complete data on in-
dividual sources and their compliance,, see Section 7.
3.1 PARTICULATE EMITTING UNITS
Various process units are responsible for particulate emissions in a
refinery. Only a few major units are considered here since their
contribution to air pollution is considered significant. Four major
operating units have been judged to be accountable for the majority of
the potential particulate emissions in a refinery. These units include
fluid cokers, fluid catalytic crackers (FCC's), Thermofor (moving bed)
catalytic crackers(TCC's), and combustion units.
The present status of each of these units is presented in Table 3-1 for
each of the refineries. The following sections outline a brief discussion
of the status of each of these units.
3.1.1 Fluid Cokers
There is one fluid coker in the region which is located at the
Exxon Company refinery in Billings, Montana. This unit was
found to be out of compliance, and not on a schedule.
3.1.2 Fluid Catalytic Cracking Units
Fifteen of the twenty-eight refineries in this region operate
a fluid catalytic cracking process. Seven of these units have
been found to be in compliance. The FCCU at Continental Oil
Company in Commerce City, Colorado is equipped with secondary
cyclones and was found to be in compliance. Exxon Company in
Billings, Montana was found to be in compliance by information
submitted to the state. There are two operational units at
Phillips Petroleum Co. in Great Falls, Montana. It was
assumed that one unit is on stand-by while the other is operating.
458
-------
05/22/76
TABLE 3-r "
PACIf-IC ENVIRONMENTAL SERVICES
PAGE
STATUS OF MAJOR PARTICULATE
EMITTING UNITS
" FLJID ""
CODERS
"" FCC.
UNITS
"TCC COMBUSTION " AQCR ""
UNITS UNITS STATUS
REMARKS'
"COMPANY NAME"
CITY
COLORADO
"CONTINENTAl"—01 "L"~ COMPANY COMMERCE'XI TY
THC'fJEFT NFiTV CGKPUR'fc 11 ON CCT!'iKFRrF~CT 1 V '
GARY WESTERN"COMPANY "GILSQNITE
"NA "
~R7T
"NA"
r
NA"
"^05"
~NA "~
~t«T
"'"NA"
I
~r
"CIT
rr
-Y-
"FCC has external cyclone control
-fCC-fia s-no-Gxternal-control
-Emission estimates from 3 boilers
are suspect. Have a catalyst regenerator
on Die reformer which is WIS.
mGJjTOa
-P=>
EXXON CO. BILLINGS NNS I
B IG WEST OIL CO. KEVIN NA NA
FARMERS UNION CENTRAL EX LAUREL NA NNS
CONTINENTAL OIL CO. _ BILLINGS NA _ NNS
PHILLIPS PETROLEUM CO. GREAT FALLS NA [
WESTCO_REFINING _ CUT_ BANK HA NA
TESORO PETROLEUM CO. WOLF POINT NA NA
COMPLIANCE CODES: NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
; NQS"'- NOT "IN COMPL I ANCEj" ON" A" SCHEDUL E
CU - COMPLIANCE STATUS UNKNOWN
I IN COMPLIANCE
NR - NO REGULATION
' —=—N CTI KP"P CTCA BTE '
NA
NA
FCC and fluid ccker have r.o external
control. _
NA
NA
HA
No external control on FCC.
No external control on FCC. Opacity
reading of 54% on 8/6/75. ~
No external control cn FCC.
NA
NA
N
Y
AQCR STATUS CODES:
N - NON-ATTAINNENT AQCR
"Y"-"ATTAINMENT "AQCR
? - ATTAINMENT STATUS
HOT DETERMINED
-------
TABLE 3-1
05/22/76 PACIFIC ENVIRONMENTAL SERVICES PAGE
STATUS Or MAJOR PARTICULATE EMITTING UNETS
~ "FLUiO FCC 7CC " "COMSUSnON "AQCR REMARKS
COKERS UNITS UNITS UNITS STATUS
COMPANY NAME " 'CITY
NORTH DAKOTA
,
AMERICAN OiL CO. iAMOCO)
KANDAN
NA
fins
NA
I
V
FCC has external niultlclone. Fluid
bed Incinerator is In compliance
NOkTHLANO OIL £. REFINING
OICKlNSGM
NA
NA
NA
1
1
WESTLANO OIL COMPANY
9
HILLISTON
NA
NA
NA
I
V
UTAH
AMERICAN OIL COMPANY CAM
SALT LAKE CITY
NA
NNS
NA
I
N
FCC has no external control
cn
° PHILLIPS PETROLEUM CO.
WOODS CROSS
NA
NA
I
I
N
TCC has no external control.
WESTERN REFINING COMPANY
HOODS CROSS
NA
cu
NA
I
N
FCC may be subject to NSPS.
CHEVRON OIL COMPANY
SALT LAKE CITY
NA
I
I
2
N
FCC has ESP control, lioudriflow (TCC)
HUSKY OIL COMPANY
NORTH SALT LAKE CITY
NA
NA
I
1
N
has no external control.
TCC has no external control*
CARIBOU FOUR CORNERS INC
WOODS CROSS
NA
NA
NA
I
N
Have hydrocracker - no part emission
PLATEAU INCORPORATED
ROOSEVELT
NA
CU
NA
I
Y
FCC may be subject to NSPS.
COMPLIANCE COOES!
NNS - NOT IN COM PL IANCE i
NOS - NOT IN COMPLIANCE
C U 1 - COMPL I ANCE STATUS
"I " IN COMPLIANCE
NR - NO REGULATION
NOT ON A SCHEDULE
ON" A SCHEDULE
UNKNOWN
AQCR STATUS CODES:
N - NON-ATTAINMENT AQCR
Y - "ATTAINMENT AUCR
7 - ATTAINMENT STATUS
MOT "DETERMINED
NA
"R or-eut
-------
05/22/76
¦ TABLE 3-1
PACIFIC ENV1 RONHEJJTAt SERVICES
STATUS OF MAJOR PARTICULATE
EMITTING UNITS
PAGE
COMPANY NAME
WYOMING
C I t:
FLUID
CQKERS
FCC
UN ITS
TCC COMBUSTION AQCR
UNITS LIMITS STATUS
REMARKS
-P-
CD
TSSCKO PETROLEUM
" L' 1 T T L E " A ME R IC A_0 i CC'tT
AHER SCAN OIL {AMOCO)
PASCO INC
" T E X A CO
SAGE CP.EE-X REF INING""
HUSKY OIL
"HUSKY OTC
NEWCASTLE
VANS VILUt-
CASPER
"SINCLAIR '
"EvanSVIlTE"
COWLEY
CODY
"Cheyenne ~
NA
~NA"~
NA
NA
NA"
NA
NA
NA
NA
MA "
I
NNS
NN S
NA
I
I
NNS
cu
NA
NA
iiA ¦"
ii.A
iiA
rV. '
NKS -
" I ~
I
I
"I "
cu
I
- I
N
Y
y
V
Y"
Y
N
V
No externa] control on TCC. 3 oil
and gas fired combustion units are WIS
Wo external control on TCC.
FCC has external cyclones. Bauxite
cooler is N05.
FCC has ESP control.
FCC has ESP control
lio data for combustion units.
FCC has no external control. Have an
asphalt oxidizer - no solid part, emissions
FCC has no external control.
COMPLIANCE CODES: NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
"~ NOS - NOT IN COMPLIANCE; ON! A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
j~- IN'COMPLIANCE ~~
NR - NO REGULATION
NA - NOT" APPLICABLE
AQCa STATUS CODES;
N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
Assuming identical operating parameters, both units were calculated
to be in compliance.
Chevron Oil Company in Salt Lake City, Utah has an ESP fitted to
their FCC and were found in compliance. American Oil Company in
Casper, Wyoming has multiclones operating as secondary collection
equipment on their FCC, and were found to be in compliance. The
FCCU at Husky Oil Company in Cody, Wyoming was found to be in
compliance as well as the FCC at their facility in Cheyenne,
Wyoming.
The compliance status of the FCC at Plateau Incorporated in
Roosevelt. Utah is unknown due to insufficient information.
There is some doubt as to whether the unit is subject to New
Source Performance Standards because its start construction date
is unknown.
There are seven FCC units in the region which are out of compliance,
and not on a schedule. The FCC1s at the Refinery Corporation
located in Commerce City, Colorado; Farmers Union Central Exchange
in Laurel, Montana; and Continental Oil Company in Billings,
Montana are only equipped with internal cyclones. The FCC at
CONOCO's Billings refinery was subject to a VEO by EPA personnel
on August 6, 1975. The average opacity viewed was 54 percent.
The FCC at American Oil Company in Salt Lake City, Utah is also
out of compliance and does not have any secondary control
equipment.
Three sources have secondary control equipment ori the FCC's, but
were still found to be out of compliance and not on a schedule.
American Oil Company in Mandan, North Dakota is equipped with
multiclones. The FCC's at Pasco, Incorporated in Sinclair,
Wyoming, and Texaco, Incorporated, in Evansville, Wyoming are
both equipped with high efficiency electrostatic precipitators.
There is one FCCU in the region for which the compliance status
remains unknown,, This unit is at Pasco, Incorporated in
Roosevelt, Utah.
462
-------
3.1.3 Thermofor Catalytic Cracking Units
There are six TCC units in the region.. One was found to be not
in compliances not on a schedule; the compliance status of two is
unknown; and the other three units are in compliance.
The not in compliance, not on a schedule unit is located at
Tesoro Petroleum Company in Newcastle, Wyoming. There is no
secondary control equipment on the unit. CDS listed the unit
at Little American Oil Company in Evansvilles Wyoming as compliance
unknown. There was insufficient data to determine the compliance
status of the TCC at Western Refining Company's facility in Woods
Cross,. Utah.
The TCC units at Phillips Petroleum Company in Woods, Cross, Chevron
Oil Company in Salt Lake City, and Husky Oil Company in North Salt
Lake, Utah are in compliance.
3.1.4 Combustion Units
Boilers F-40001, 4002, and 4003 were source tested for compliance
at Gary Western Co. in Gilsonite, Colorado. A copy of the summary
of the test was not available, but it is doubtful that particulate
g
emissions from the boilers would be 4.38 lbs/10 BTU. For this
reason, the compliance status of the boilers was listed as unknown.
Particulate emission regulations iri Wyoming only apply to units
burning solid fuel. However, the regulations specifically define
solid fuels as including fuel oil. The only units which are out
of compliance with this regulation are three oil and gas fired
combustion units at the Tesoro refinery in Newcastle. The status
of the combustion units at Sage Creek in Cowley "is shown as
compliance status unknown simply because no fuel usage data were
available for the units.
SULFUR DIOXIDE EMITTING UNITS
Emission of sulfur dioxide from a petroleum refinery can be attributed to
several processes. Four prime units are responsible for potential sulfur
-------
dioxide emissions in a typical refinery. These operations include
combustion units, fluid catalytic cracking units (FCC), Thermafor
(moving bed) catalytic crackers (TCC), and sulfur recovery units (SRU).
The present status of these units is presented in Table 3-2 for each of
the refineries in Region VIII. The following sections briefly discuss
the status of each of these units. Other sulfur dioxide sources may include
flares which routinely vent process gas, and unprocessed gas streams
from foul v/ater strippers.
3.2.1 Combustion Units
The potential of sulfur dioxide emissions from combustion units in
a refinery can be sizeable, depending upon the fuels used and
their sulfur content. Major fuel burning units responsible for
SO^ emissions are boilers and process heaters, If any one of the
boilers and process heaters is found to be out of compliance, the
status code for "Combustion Equipment" reflects this unit.
All of the boilers and process heaters in Region Vl'II are gas and/or
oil fired. There are no EPA approved sulfur regulations in Utah
and Wyoming, hence these units have a status of NR.
Process heaters HI and Hi 1 are out of compliance with sulfur
limitations at the Continental Oil Company refinery in Commerce
City, Colorado. There is no known compliance schedule.
The waste gas furnace at the Refinery Corporation in Commerce City,
Colorado is also out of compliance with sulfur regulations. The
fuel being burned in this furnace is high in mercaptans and
sulfides. There is no known schedule.
The combination fuel process heaters and boilers at Exxon
Company's refinery in Billings, Montana are out of compliance
with SO2 limitations. There is no known compliance schedule.
At Farmers Union Central Exchange in Laurel, Montana the boilers
are equipped with multiple fuel firing capacity. If they were
fully fired on liquid fuel at capacity, the resultant SO2
464
-------
PAGE 1
COMPANY NAME
COLORADO
CITY
COMQUSTION FCC
UNITS UNiiTS
TCC SULFliR AQCR
L'Ni T5 RECOVERY STATUS
UNITS
REMARKS
CONTINENTAL OIL' COMPANY COMMERCE CITY
The"bef~ inerV-tcp,por'atfor COMMENCE LI ff~
GARY WESTERN COMPANY
GILSONITE
N S
TINS'"
. NNS
"NNS'
NA
NA
"NA"
NA
~"NA'
NA
SRU is not scheduled to operate until
1977, by data will be NNS
"One furnace + FCC emit>500 ppm SOg
MONTANA
E XXCN CO.
Tjl
01 B!G WEST OIL CO
BILLINGS
KEVIN
FARMERS UNION CENTRAL EX LAURcL
CONTINENTAL OIL CO. eiLLINGS
PMILL IPS PETROLEUM J|0_. p„REAT FALLS
KESTCO AEFINING CUT BANK
TESORO PETROLEUM CO. WOLF POINT
NNS
NNS
NNS
I
i
I
NR
NA
MR
NR
NR
n:a
NA
NA
NA
NA
MA
MA
NA
NA
NA
NA
CU
N A
NA
fJA
NA
Some combustion units burn high sulfur
fuel oil.
Exempt from fuel sulfur reg.
6 combustion units burn hiqh sulfur
fuel oil.
6 combustion units HUS with sulfur in fuel
regs.
Exanpt from fuel sulfur regs.
Exempt from fuel sulfur regs.
Exanspt from fuel sulfur regs.
COMPLIANCE CODES:
NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
I - IN COMPLIANCE
NR - NO REGULATION
"NA"— "NOT"APPLICABLE ~
AQCR STATUS CODES: N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
iNQT DETERMINED
-------
PAGE
COMPANY NAME
CITY "
COMBUSTION
' UNITS
FCC
UNITS
TCC
UNITS
SULFUR
RECOVERY
UNITS
AQCR
5TATUS
NORTH OAKOTA
. . _.
_ . .
- -
AMERICAN OIL CO. (AMOCO)
MANDAN "~
NNS
NR
NA
NA
f
NORTHLAND OIL 6 REFINING
OICKINSQN
I
N A
NA
N A
Y
WtSTLAND OIL COMPANY
HiLLlSTON
" 1
" MA
NA ' "
NA
Y
UTAH
-
--
-- -----
^ AMERICAN OIL COMPANY (AM
cr>
471 PHILLIPS PETROLEUM CO.
SALT LAKE CITY '
NR
NP.
NA
NA
Y
WOODS CROSS
MR
NA
NR
NA
V
WESTERN REFINING COMPANY
HOODS CROSS
MR
NR
NA
NA
Y
CHEVRON OIL COMPANY
SALT LAKE CITY
NR
NR
MR
NP.
Y
HUSKY OIL COMPANY
NORTH SALT LAKE
CITY NP.
MA
NR
NA
Y
CARIBOU FOUR CORNERS INC
WOODS CROSS
NR
NA
NA
NA
Y
PLATEAU INCORPORATED
ROOSEVELT
NR
NR
KA
NA
Y
REMARKS
1 heater Burning vacuum jet off-gas
COMPLIANCE COOES: NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NOT IN COMPLIANCES ON A SCHEDULE
CU - COM PL IANC E STATUS UNKNOWN
" " I - IN COMPLIANCE
NP. - NO REGULATION
NA NOT APPLICABLE
AqCp. STATUS CODES: N - NGN-ATT A iNME NT AQCR
Y - ATTAINMENT AQCR
7 - ATTAINMENT STATUS
NOT DETERMINED
-------
PAGE
STATUS OF MAJOR SULr'JP. DIOXIDE EMITTING UNITS
COMBUST ION
UNITS
FCC
UNITS
¦TCC
UNITS
"COMPANY NAME
CITY
HYOMINC-
"" TESCRO PETROLEUM
—Time AM£RTCX—Dm—CU~
AHERICAN Oi L (AMOCCJ
PASCO INC
"TEXACO '
SAGE CREEK REFINI KG
Cn HUSKY 0IL
^-J
HUSKY OIL"
NEWCASTLE '"
"FV5R"5VELUE '
CASPER
SINCLAIR
E VANSV11XE~
COWLEY
CODY
CHEYENNE
NR
"NP.~
NR
NR
NR
NA
NP.
NR
SULFUR AQCR
RECOVERY STATUS
UNI TS
REMARKS
NA
"NA"
NR
NR
" NR"
NA
NR
NR
" NR
""NR"
"" NA "
NA
"" NA'
NA
NA
NA
COHPL IANCE COOES: NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
5 JN COMPLIANCE ' ""
NR - NO REGULATION
NA - NOT APPLICABLE
NA
"NA""
NA
NA
NA "
NA
NA
NA
Y
— Y'
' V
Y
~ Y
Y
Y
Y
AQCR STATUS CODES: N - NOM-ATT A INMENT AQCR
y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
emissions would be above the allowable. All of the combination
fuel fired process heaters at the refinery, except the new plat-
former charge heater, would also be out of compliance with the
SO2 regulations when fired solely on fuel oil. For this reason,
they have also been listed as out of compliance. There are no
known compliance schedules.
The combination fuel fired boilers and process heaters at
Continental Oil in Billings, Montana are all out of compliance
if solely fired or liquid fuel. There are no known compliance
schedules. American Oil Company's facility at Mandon, North
Dakota is in compliance with sulfur regulations, except for
the crude furnace heater. There is no known compliance
schedule.
There are no EPA approved sulfur regulations for Utah and
Wyoming, hence the compliance status of the combustion units
in Table 3-2 show NR.
3.2.2 Fluid Catalytic Cracking Units
Another potential source of SOg emissions is the.FCC units. The
only state with sulfur regulations applicable to FCC units is
Colorado.
The FCC at the Continental Oil Company's refinery in Commerce City,
Colorado is out of compliance with allowable sulfur emission
limitations. There is no known compliance schedule. The FCC unit
at the Refinery Corporation in Commerce Citys Colorado is also out
of compliance.
3.2.3 Thermcifor Catalytic Cracking Units
None of the six TCCs in Region VIII are subject to sulfur oxide
limitations. The status of these sources is listed as no
regulation (RR).
3.2.4 Sulfur Recovery Units
Sulfur recovery units (SRU's) can be a major sulfur dioxide emitting
source if not properly controlled. Two refineries have existing
468
-------
SRU's wfiile another is installing one.
The SRU at Farmer's Union Central Exchange (CENEX) in Laurel, Montana
is exempted from state.sulfur regulations. The unit is equipped with
a tail gas oxidizer. There are no applicable regulations for the
SRU at the Chevron Oil Company refinery in Salt Lake City, Utah.
Continental Oil Company in Commerce .City, Colorado is building or
has recently finished an SRU, however, it is not scheduled to go on
stream until 1977. The information available on the unit
indicates that when it becomes operational, it will not be in
compliance.
3•3 hydrocarbon emitting units
Almost all processes in a refinery emit hydrocarbons. Of major concern for
this analysis are storage tanks, oil-water separators* vacuum jets, and
loading/unloading facilities. The status of each of these major sources
is presented in Table 3-3 for each refinery.
The following section is a brief summary of the overall status of
these four source categories. The contribution of blowdown systems
and miscellaneous sources as pipe/valve leakages and pump seals are
more dependent upon plant maintenance and housekeeping procedures, but
can also reach significant levels.
3.3.1 Storage Tanks
There are six basic tank designs available for petroleum storage:
fixed roof, floating roof, covered floating roof, internal
floating cover, variable vapor space, and pressure tanks. The
information available from state agencies indicated fixed roof,
floating roof, and pressure tanks were used in the region.
There was no inference of a refinery using a vapor recovery
system in conjunction with the storage of volatile organic
compounds in fixed roof tanks.
There was insufficient information to determine the compliance
status of storage tanks in Colorado. Gary Western Company in
469
-------
05/22/76
PAGE 1
COMPANY NAME
COLORADO
CITY
STORAGE OIL- VACUUM LOADING/ AQCR
TANKS HATER JETS UNLOADING STATUS
SEPARATORS FACILITIES
REMARKS
CONTINENTAL OIL COMPANY COMMERCE CITY
"THE "REF I NEft Y~CORPORATS'ON C0MMEP,CE~C"I7Y~
GARY WESTERN COMPANY " GSLGONITE
cu
"cir
cu
i
-CU —
'AR '
NR
¦fiR"
NA
CU
—CU
~jo
N
"iN
V"
No data re: petrol storage; loading/
unloading
No data re; petrol storage; oil-water
sep; loaciing/unloading racks
No data re: petrol storage; oil-water
sep.; loading/unloading racks
MONTANA
.p* EXXON CO.
° BIG WEST OIL CO,
BILLINGS
KEVIN
FARMERS UNION CENTRAL EX LAUREL
CONTINENTAL OIL CO, BILLINGS
PHZLLIPS PETRGLEUM_CO. _ GREAT FALLS;
WESTCG REFINING CUT SANK
TESORO PETROLEUM CO. WOLF POINT
CU
I
I
CU
I
I
I
CU.
I
CU
CU
i
I
I .
NR
HR
NR
MR
NR
NA
NA
MR
NR
NR
NR
fiR
;-:r
NR
iio data re: petrol storage; oi'-water
sep.; loading/unloading racks.
Exempt from HC regs. due to size of
refinery; no data re: loading/unloading
No data re: oil-water separator; "loading/
unloadinq racks.
Insufficient data re: petrol storage; oil
water sep.; leading/unloading racks.
Exempt from HC. regs. due to size of refiner}
Na data re: loading/unloading racks.
Exempt frcm HC regs. due to size of refinery
no data re: loading/unloading racks.
Exempt from HC regs. due to size of refiner}
no data re: loading/unloading racks.
COMPLIANCE CODES:
NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NO. IN COMPLIANCE? ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
I - IN COMPlIANCE . .
NR - NO REGULATION
"NA "^~NGT' APPLICABLE
AQCR STATUS CODES*
N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
05/22/76
TABL17 ')-3
PACIFIC ENVIRONMENTAL SERVICES
STATUS OF MAJOR HYDROCARBON EMITTING UNITS
PAGE 2
" COMPANY NAME
CITY.
STORAGE
T A tiK S
OIL-
WATER
SEPARATORS
VACUUM
JSTS
LOADING/
Ui'iL GAD i MG
FACILITIES
AQCi
STATi
NORTH DAKOTA
i
...
-
T AMERICAN OIL CO, (AMOCO)"
HAND AN
NR
" NR
' .NA
NR
V
NORTHLAND OIL £ REFINING
DICKINSON
&
NR '
~NA
T
Y
I"""" KESTLA^D OIL COMPANY
WILLISTCN
' K8
¦ — - - -
' MA
' "NR.
Y
UTAH
4s. AMERICAN OIL COMPANY I AM
~'. .PHILLIPS PETROLEUM CO.
SALT LAKE CITY
WOODS CROSS
NR
NR
NR.
NR.
NA
NR
NR
Y
Y
WESTERN REFINING COMPANY
WOODS CROSS
CU
NR
NA
NR
V
CHEVRON OIL COMPANY
SALT LAKE CITY
tin
1
IIR
NR
NR
Y
HUSKY OIL COMPANY
NORTH SALT LAKE CITY
NR
NR
. . NR - -
NR
V
CARIBCU"FOUR CORNERS INC
WOODS CROSS
NR
NR
i\'R
NR
Y
PLATEAU INCORPORATED
ROOSEVELT
NR
NR
MA
NR
Y
REMARKS
No data re: Leading/unloading racks.
Insufficient data re: oil-water separator.
Insufficient date re: Petrol storage, load'
loading racks.
Insufficient data re: Oil-water separator, loading/
unloading racks.
Insufficient data re: oil-water separator, loading/
unloadinq racks.
NSPS Storage, Federal inspection unknown, no data
re: loading/unloading racks, oil-water separator.
Ho data re: Oil-water separatoy, vacuum jets,
loading/unioadinq racks.
. No data re: oil-water separators,vacuum jets,
loading/unloading racks.
insufficient data re: cil-water separators, load-
ing racks.
Ho data re: Petrol storage, oil-water separator,
loading/unloading racks.
COMPLIANCE CODES:
NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NGS - NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
I - IN COMPLIANCE ""
NR - NO REGULATION
~NA"~~NOT 'APPLICABLE '
AQCR STATUS COOES:
N - NGN-MTA INMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
05/22/76
TA3LE 3-3
PACIFIC ENVIRONMENTAL . SERVICES.
STATUS OF MAJOR HYOROCAROON
EMITTING UNITS
PAGE
COMPANY NAME
WYOMING
CITY
STORAGE OIL- VACUUM
7 A iNK S HATER JETS
SEPARATORS
LOADING/ AQCR
UNLOADING STA1US
fAC IL STIES
REMARKS
TESORO PETROLEUM
'"LITTLE" AHEfUCA~OIL~ar
AMER ICAN OIL (AMOCO )
PASCO INC
TEXACO
SAGE CREEK REFINING
^ HUSKY OIL
ro
HUSKY "0 IL
NEWCASTLE
'EVANSViLTF
CASPER
SINCLAIR
"E VANS VI LITE"
COHLcY
CODY
"CHEYENNE ""
NR
NR
NR
NR
NR"
NR
NR
NR
NR
"MR"
MR
NR
NR
KR
NR
NR
NA
NR
NR"
NR
NR'
NA"
NR
NR
NR
MR
HR
NR-
KR
fiR*
KR
"nr"
Y
r
Y'
Y
Y
Y
r
COMPLIANCE CODES• NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULc
NOS - NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
i ~IN COMPLIANCE " "
HR - NO REGULATION
NA - NOT APPLICABLE
AOCR STATUS CODES:
N - NON-ATTAINMENT AQCR
V - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED ~ '
-------
in Gilsonite, Colorado listed information for two storage tanks
subject to NSPS, but did not list other storage facilities. The
compliance status of the tank's subject to NSPS is unknown because
there was no information regarding Federal inspection. There was
no information on petroleum storage at the other two refineries
fn Colorado (CONOCO and Refinery Corp.)
Big West Oil Company in Kevin, Phillips Petroleum Co. in Great Falls,
Westco Refining in Cut Bank and Texaco Petroleum Co. in Wolf Point,
Montana are exempt from hydrocarbon regulations due to the process
capacity of each. Fanners Union Central Exchange (CENEX) was found
to be in compliance with hydrocarbon storage regulations. There
was insufficient information to determine the compliance status of
petroleum storage tanks at CONOCO and Exxon refineries in Billings,
Montana.
There are no applicable regulations for the storage of petroleum
and petroleum products for existing refineries in North Dakota,
hence AMOCO in Mandan and Westland Oil in Williston are exempt.
Northland Oil and Refining in Dickinson is considered a new
refinery by state officials. They v/ere found to be in compliance
with petroleum storage regulations.
There are no EPA approved hydrocarbon limitations in Utah. Western
Refining Company in Woods Cross has tv/o 10,000 BBL storage tanks
which are subject to NSPS. It is not known if these tanks
have been inspected by Federal personnel, hence the compliance is
unknown.
In Wyoming, there are no regulations governing the emissions of
hydrocarbons from storage tanks. Three of the refineries have
equipped their storage tanks with floating roofs. These refineries
are American Oil in Casper, and the Husky Oil refineries in Cody
and Cheyenne. There weceinsufficient data available to determine
i'f the other refineries in the state have equipped their tanks with
floating roofs or other control equipment.
473
-------
3.3.2 Oil-Water Separators
There was often little or no data available to determine compliance
status and emissions of oil-water separators' in the region.
In Colorado, CONOCO at Commerce City was found to be in compliance
with their oil-water separators which were scheduled to be in
service on January 15, 1976. However, there was no information
available to confirm' the separators were in service on that date.
There were no data at all for the oil-water separator at the Refinery
Corporation in Commerce City, hence its compliance status is unknown.
Gary Western Company in Gilsonite did not supply any data on their
oil-water separator, so emissions could not be estimated. There
are no applicable regulations for this source at Gary Western.
Four of the refineries in Montana are exempt from hydrocarbon
regulations due to their small size. These refineries are listed
as in compliance. There were insufficient data to determine the
compliance status of the oil-water separators at Exxon and CONOCO
in Billings and Farmers Union Central Exchange in Laurel, Montana.
North Dakota, Utah, and Wyoming do not have any regulations
concerning hydrocarbon vapor losses from oil-water separators.
3.3.3 -Vacnum Jets
The emissions from a vacuum distillation unit usually vent to one
of three places. The gases, after passing through a barometric
condenser, can be routed to a refinery fuel system, or be vented
to a flare. The gases can also be vented to the atmosphere.
This gas contains a large amount of hydrocarbons and sulfurous
compounds, and is a sizeable potential emission source.
There are seventeen refineries in Region VIII which employ vacuum
distillation. For the majority of these units, the manner of
control utilized on the jets is unknown. There are no refineries
in North Dakota using vacuum distillation.
474
-------
The refineries with vacuum jets of unknown controls are located
in states with no regulations governing their emissions,, Because
this can be a significant source of odor and hydrocarbons, these
refineries are listed and should be investigated. They are
CONOCO and the Refinery Corporation in Commerce City, Colorado;
Exxon Co, and CONOCO in Billings* Big West Oil Co., in Kevin,
Farmers Union Control Exchange (CENEX) in Laurel, and Phillips
Petroleum Co. in Great Falls, Montana; Phillips Petroleum
Co. and Caribou Four Corners, Inc. in Woods Cross.., Chevron Oil
Co., in Salt Lake City and Husky Oil Co. in North Salt Lake City,
Utah. There are no refineries in North Dakota utilizing vacuum
distillation.
In Wyoming, six of the eight refineries use vacuum distillation
as part' of their process. There was insufficient information
available to determine if these units are controlled. Although
there are no regulations governing hydrocarbon emissions in
Wyoming, refineries with vacuum jets are listed for further
investigations. These units are located at Little America Oil
and Texaco in Evansville, American Oil in Casper, Pasco, Inc. in
Sinclair, and the Husky Oil refineries in Cody and Cheyenne.
3,3.4 Load'ing/'Jnloedinq Fac.ilities
There was often insufficient data available from the state agencies
to determine emission estimates and compliance status. In many
instances, there was no mention of loading facilities, or their
operating hours9 throughput, or control equipment.
In Colorado, the compliance status of Continental Oil and the
Refinery Corporation, both in Commerce City, is unknown due to
lack of data. There are no applicable hydrocarbon regulations
for the loading/unloading facilities at Gary Western in Gilsonite.
The North Dakota regulations are written such that existing sources
are exempt from hydrocarbon regulations. State officials have
475
-------
determined that Northland Oil and Refining in Dickinson" can be
considered as a new source. The loading/unloading facilities
were found to be in compliance with their control equipment
although there were insufficient data to determine emissions.
In Montana, Utah, and Wyoming, there are no regulations which
would be applicable to loading/unloading facilities. These
sources are denoted with no regulation (NR) on the compliance
status summary in Table 3-3.
3-4 NITROGEN OXIDE EMITTING UNITS
The major source of nitrogen oxides in a refinery can be traced to combustion
units. Of the five states in Region VIII with refineries, Wyoming is the
only stats with limitations on the amount of nitrogen oxides which can
be emitted from a combustion unit. All refineries in Wyoming were found
to be in compliance with the nitrogen oxide regulations except Sage Creek
Refinery in Cowley. There wets no available data cn the refinery, so
it was impossible to determine the compliance status of the combustion
units. For a summary of the compliance status of each refinery, refer
to Table 3-4.
3•5 CARBON MONOXIDE EMITTING UNITS
There are four major units in a refinery which have a high potential
for carbon monoxide emissions. These units are the fluid coker, the fluid
catalytic cracking unit (FCC), the Thermofor (moving bed) catalytic
cracking unit (TCC), and combustion units.
Other than New Source Performance Standards, none of the states have regulations
limiting the emissions of carbon monoxide. The following is a brief
discussion of the compliance status listed in Table 3-5.
476
-------
PAGE
CQMSUSTION
UNITS
AQCR
STATUS
COMPANY NAME
CITY
COLORADO
REMARKS
CONTINENTAL OIL COMPANY
COMMERCE CITY
rOMHFRCfc CI ir
TiTm R £S7~CW PTJ"TOTTOfr
GARY WESTERN COMPANY GILSQMTE
NR
' "NR"
MR
MONTANA
•--J
EXXON CO.
6 IG WEST 01 L CC.
BILLINGS
KEVIN
FARMERS UNION CENTRAL EX LAUREL
CONTINENTAL OIL CO. BILLINGS
PHILLIPS PETROLEUM_CO» GREAT FALLS_
HESTCO -REFINING CUT BANK
TESORO PETROLEUM CO. WOLF POINT
NR
NR
NR
MR
NR
NR
NR
COMPLIANCE COOES: NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - MOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
"" ------- j -INCOMPLIANCE "
NR - NO REGULATION
NA -"~NOT~APPL ICAB CE
AQCR STATUS CODES J
N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
05/22/76
PAGE
COMPANY NAME
cm
NORTH DAKOTA
COMBUST ION
UNITS
AQCR
STATUS
REMARKS
AMERICAN OIL CO. (AKOCO) MANDAN
"NORTHLAND 0 IlT fi"REFIKING D'ICKiNSOK"
WESTLAND OIL COMPANY WILLISTON
NR
"NR~
NR
Y
Y
Y
UTAH
^ AMER ItAN OIL COMPANY I AH SALT LAKE CITY
-Sj ~ -
03 PHILLIPS PETROLEUM CO. WOODS CROSS
NR
NR_
WESTERN REFINING COMPANY WOODS CROSS NR
CHEVRON OIL COMPANY SALT.LAKE CITY NR
HUSKY OIL CC-iPANY NORTH SALT LAKE CITY NR
CARIBOU FOUR CORNERS INC WOOOS CROSS NR
PLATEAU INCORPCRATEO ROOSEVELT NR
Y
Y
Y
Y
Y
COMPLIANCE CODES:
,NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
I -IN COMPLIANCE
NR - NO REGULATION
NA "-""NOT-APPTICABCE
AQCR STATUS CODESs
N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
05/22/76
- ¦ ¦ TABLE 3-4
PACIFIC ENVIRONMENTAL SERVICES
STATUS DF MAJOR NITROGEN OXiCE EMITTING UNITS
PAGE
CCM3UST SON
UNITS
COMPANY NAME
CITY
WYOMING
A CCR
STATUS
remark:
TESORO PETROLEUM
TTfiTE AMERICA 0IL CO
AMERICAN OIL (AMOCO)
PASCO INC
T EKACO
SAGE CREEK REFINI WG"
-P»
-J HUSKY OIL
HUSKY "OIL
NEWCASTLE
TVaTSTTlTE
CASPER
S INCLAIR "
"E VANSVUCE
COWLEY
CODY
CHEYENNE
" i
—r~
i
" i
—j-
cu
I
I
Y
Y
Y
Y
Y"
Y
Y
Y
No data re; All aspects of production.
COMPLIANCE CODES:
NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
I - IN COMPL IANCE " '"
NR - NO REGULATION
NA - NOT APPLICABLE ¦ ¦ - -
AQCR STATUS CODES:
N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
.NOT DETERMINED '
-------
05/22/76
TABLE 3-5
PACIFIC ENVIRONMENTAL SERVICES
STATUS OF MAJOR CARBON MGN'QK IDE EMITTING UNITS
PACE
FLUID
COKERS
COMPANY NAME
CITY
COLORADO
CONTINENTAL OIL COMPANY COMMERCE CITY
"THE REF I M£R Y "C CP.PORATJON CCMf'.EP.Ce^CITV"
GARY WESTERN COMPANY " GtLSONITE
MONTANA
EXXON CO.
BIG HEST OIL CO.
BILLINGS
KEVIN
FARMERS UNION CENTRAL EX LAUREL
CONTINENTAL 01L CO. BILLINGS
_p HJi LA.P s_PJLIR0 LEliH _?2_* grem; fal_l_s
KESTCO REFINING CUT BANK
TESCRO PETROLEUM CO. WOLF POINT
N A
'NA~
NA
NR
(SiA
NA
NA
NA_
NA
NA
FCC
UN iTS
TCC C CfB L'ST ION AQCP.
UNITS UNI'S STATUS
REMARKS
NR
~NR~
NR
NA
NS
. NR
HP.
N A
NA
MA
' RA"
HA
NA
NA
NA
fin
»na
'NA
NR
NR
NR
NR
NR
NP-
NR
_ NR_
V P
FCC does not have CO boiler.
FCC does net'hava CC boiler.
Y
Y
Y
Y
Y
Fluid coker snc! FCC have CO boilers
FCC has CO boiler.
FCC does not. have CO boiler.
FCC does not have CQ toiler.
COMPLIANCE CODES:
NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS NOT IN COMPLIANCE; ON A SCHEDULE
CU - COMPLIANCE STATUS UNKNOWN
I - IN COMPLIANCE
NR - NO REGULATION
"NA'~~NOr~APPCICABLE
A3CR STATUS CODES:
N - NON-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
NOT DETERMINED
-------
I
05/22/76
TABLE 3-5
PACIFIC ENVIRCNMENTAL SERVICES
STATUS OF CAR80M MONOXIDE EMITTING UNITS
COMPANY NAME
NORTH DAKOTA
CITY
FLUID
CCKEKS
FCC
UNITS
7CC COKrtUSTION AQCR
UNITS U.^aTS STATUS
PAGE
REMARKS
AMERICAN OIL CO. IAMOCO)
"Ti'ORT HLA'urTO f L~~C~ R~tT fTOTKT
"WESTLANO OIL COMPANY
MANDAN
~BTCKTN5"GTT
HILLISTON
NA
"NA-
NA
NR
MA'
NA
Hfi
' m
m
NP.
" NR
NR "
Y FCC does not have CO boiler.
Y '
Y
UTAH
^ AMERICAN OIL COMPANY 1 AM SALT LAKE CITY
CO
-J PHILLIPS PETROLEUM CO. HOODS CROSS
NA
MA
WESTERN REFINING COMPANY WOODS CROSS NA
CHEVRON OIL COMPANY SALT LAKE CITY NA
HUSKY OIL COUP ANY NORTH SALT J.AKE CITY NA
CARIBOU' FOUR CORNERS INC HOODS CROSS NA
PLATEAU INCORPORATED ROOSEVELT NA
MR
NA
NR
MR
NA
NA
CU
NA
M O
NA
h?.
MR
NA
NR
NR
NR
NH
MR
r;p,
NR
Y FCC has CO boiler.
Y TCC dees not have CO boiler.
v
I
FCC docs not have CO boiler but haLidriflow (TCC)
Y does.
t
X. TCC does not have CO boiler.
x
* Unknown if FCC subject to N.SPS.
COMPLIANCE CODES S
NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NO'l IN COMPLIANCE; ON A SCHEDULE '
CU - COMPLIANCE STATUS UNKNOWN
I - IN COMPLIANCE '
NR - NO REGULATION
~ li A N 0 r - A P P LI C A B L E '
AQCR STATUS CODES: N - NQN-ATTAINMENT AQCR
Y - ATTAINMENT AQCR
? - ATTA[NScNT ST4 TUS
NOT DETERMINED
-------
PAGE 3
COMPANY NAME
WYOMING
CI TV
FLUID
COKcRS
rCC
u.-sii:
tCC CCMBUST ION
UNITS UNITS
A OCR
iTATUS
REMARKS
TESORO PETROLEUM •
L" 1 TTLE"AMERICANOI r~£TCT
t
AMER ICAN Oil (AMOCO}"
PASCO IMC
TEXACO '
SAGE CREEK REFINING ""
CD HUSKY OIL
ro
HUSKY" OIL
NEWCASTLE"
"EVANS VILTE-
CASPER
SINCLAIR
"t VANSVILLF"
COWLEY "
CGOY
~CHEYENNE
NA
"NA"~"
NA
f* A
"NA
NA
NA
NA ""
NA
""NA"
" HP.
Nr.
-;np. "
¦ NA
MR
~"MR"
NR
" NF.
NA"
MA
NA"
NA
HA
"NA"
NR'
"NR-"
NR
NP.
NR "
NR
NR "
"NR"'
Y
Y
y
Y
Y
Y
Y
y
COMPLIANCE CODES; NNS - NOT IN COMPLIANCE; NOT ON A SCHEDULE
NOS - NOT IN COMPLIANCE; ON A SCHEDULE
CD - COMPLIANCE STATUS UNKNOWN
¦""IN COMPLIANCE
'1 ~
NR - NO REGULATION
NA - NOT APPLICABLE
AQCR STATUS CODES!
N - NON-A TTA I N.".E NT AQCR
Y - ATTAINMENT AQCR
? - ATTAINMENT STATUS
""HOT"DETERMINED
-------
3.5.1 Fluid Coking Units
There are no regulations limiting the carbon monoxide emissions
of the only fluid coker in Region VIl'I which is located at the
Exxcn Company's refinery in Billings* Montana. AP-42 indicates
that CO emissions from a fluid coker are considered to be
negligible. This is in error. Exxon Company feels that the CO
emissions from the fluid coker are large enough to warrant
a CO boiler on the unit. With the CO boiler, carbon monoxide
emissions from this unit have been minimized.
3.5.2 Fluid Catalytic Cracking Units
Three of the fifteen FCC units in Region VIII are equipped
v/tth CO boilers. These units are located at facilities operated
By Exxon Company in Billings and Farmers Union Central Exchange
CCENEX) in Laurel, Montana» while the other is located at the
Americsn Oil refinery in Salt Lake City, Utah.
It is not known if the FCC at the Plateau* Inc. facility in
Roosevelt, Utah is equipped with a CO boiler. There is some
doubt as to whether the unit is subject to MSPS because the con-
struction date of the unit is unknown.
Although there are no regulations limiting CO emissions, the
FCC units which don't have CO control equipment are located at
Continental Oil and the Refinery Corporation in Commerce City,
Colorado; Continental Oil in Billings, and Phillips Petroleum
in Great Falls, Montana. The FCC at American Oil in Mandan,
North Dakota is not equipped with CO abatement equipment. In
Utah, both American Oil and Chevron Oil in Salt Lake City do
not have CO boilers on their FCC units.
Nona of the five FCC units in Wyoming are equipped with CO boilers.
These refineries are American Oil in Casper; Pasco, Inc. in
Sinclair; Texaco in Evansville, and the Husky Oil refineries
in Cody and Cheyenne.
483
-------
3.5.3 Thermofor Catalytic Cracking Units
Three of the five Thermofor (moving bed) catalytic cracking (TCC) units
are located in Utah, while the other two are in Wyoming. The three
TCC1s in Utah are located at Phillips Petroleum in
Woods Cross, Chevron Oil iri Salt Lake City, and
Husky Oil in North Salt Lake City. In Wyoming, there is a TCC
at Tosoro Petroleum in Newcastle and Little American Oil in
Evansville. Only the TCC at Chevron is equipped with a CO boiler.
3.5.4 Coinbust.ion Units
Since there are no regulations concerning CO emissions from com-
bustion other than NSPS, none of the combustion units have a
determinable compliance status. This is reflected in Table 3-5
with a listing of NR signifying no regulations.
484
-------
SECTION 4.
EMISSION DATA
ANALYSIS
4.0 The purpose of this section is to present a brief statistical analysis of
the major pollutant emissions from various refinery operations in this
region. The five major pollutants (particulates, SO , hydrocarbons, CO
A
and NO^) have been considered in this analysis. Based on the information
available and engineering evaluations cf various refinery units, emissions
of these pollutants are categorized as uncontrolled, present actual and
allowable. Each of these categories is explained briefly in the following
paragraphs.
© Uncontrolled emissions (shown as "UNC" in the tables) represent
the potential emission rate of a source as if it were not
equipped with external control devices.
G The present actual emission category (shown as "ACT" in the
tables) reflects data which were obtained by PES personnel
from EPA, state or local agency sources during January and
February of 1976. This data represents the most current
emission information at this point in time and does not
include the effects of any planned control devices or control
units which were in construction at the time of the visit.
G Allowable emissions (shown as "ALL" in the tables) are based
on the applicable Federal, state or local air pollution control
regulation for each source. In cases where more than one
regulation would apply, the allowable emission rate shown in
the tables represents the results obtained from application
of the most stringent rule.
4.1 PARTICULATE EMISSIONS
In Table 4-1, quantitative particulate emission rate estimates and data
are presented for each of the plants in the region. As described in
Section 3.1, four refinery processes are responsible for the majority
of the potential particulate emissions from a petroleum refinery. These
sources include fluid catalytic cracking units, combustion units, Thermo-
for catalytic cracking units and fluid cokers. Available data have been
summarized for each of these processes. Also included in the tables are
"Other Sources" of particulate emissions. Equipment such as
485
-------
asphalt oxidizing units and incinerators have been included in this category.
For each of the processes, missions have been categorized into these
groups as described in Section 4.0.
A review of Table 4.1 shows that data gaps exist for some of the
emission values. These gaps were in most cases caused by lack of
information or in the case of allowable emissions from combustion
units in Wyoming, lack of applicable regulation. In spite of these data
gaps, however, it can be seen from the table that the largest contributors
to current actual particulate emissions from the refineries in the region
are combustion units (69% of the total) and catalytic cracking regenerators
(23%). Significant emission reductions from cat crackers have been accom-
plished by the use of external cyclones5 multiclones and ESP1 s. However,
combustion units are essentially uncontrolled for particulate emissions.
Table 3-1 also indicates that fourteen of the refineries in the Region
are located in non-attainment AQCR's for total suspended particulate
matter.
4-2 SULFUR DIOXIDE EMISSIONS
Sulfur dioxide emissions have been compiled and presented in Table 4-2.
As with particulate emissions, key refinery processes have been noted for
their SO^ emission potential. They are: combustion units, FCC units,
TCC units and sulfur recovery units.
For the most part, uncontrolled emissions and actual emissions are equi-
valent since no data for emission control devices were presented for the
sources in this region. This is not to say that practices to reduce SO2
emissions are not practiced. Several refineries 'nydrodesulfurize
feedstocks and the use of a sulfur recovery plant significantly reduces
the SO2 emissions from combustion units and flares. Analysis of the
emissions of SO^ from sulfur recovery plants should take into account
the numerous data gaps caused by lack of information. Lack of regulations
and problems with interpreting existing regulations added to the data
gaps.
486
-------
Were one to analyze the emissions from a fluid coker based upon AP-42,
it would appear that there are no SO2 emissions. Experience with fluid
c.okers in other areas of the country, on the other hand, has shown these
units to be significant sources of SC^ The coker regenerator operates
in much the same manner as an FCC unit regenerator, causing similar
emissions. Operating data for the one fluid coker in the region were
not supplied, so emissions were not calculated.
The largest sources of actual SO2 in the region are combustion units
(63% of the total) and catalytic cracking units (23%). Table 3-2 also
indicates that none of the refineries in the region lie in AQCR's which
have been firmly established as non-attainment for sulfur dioxide.
4.3 HYDROCARBON EMISSIONS
The pollutant emitted from a refinery in the largest quantity is hydro-
carbon mster-ial. Many of these refineries lie in areas which have no
hydrocarbon regulations. A result of this is that because local officials
keep less than detailed information on non-regulation pollutants, data
we® not available on many of the sources listed in Table 4-3. For more
detailed information on the data necessary to determine actual
emissions and compliance of these sources, the reader is referred to
Section 3.3.
The largest potential sources of hydrocarbon emissions are storage tanks.
Refineries in areas subject to regulations utilize floating roof tanks
primarily, to reduce emissions. Other sources of hydrocarbon emissions
not shown in Table 4-3 are blowdown systems and miscellaneous equipment
such as pump and compressor seals.
Table 3-3 indicates that two of the refineries in the region are located in
non-attainment AQCR's for photochemical oxidants,
4.4 CARBON MONOXIDE EMISSIONS
Carbon monoxide emissions from a refinery, while being potentially as
significant as hydrocarbons, are more easily controlled in most plants.
Two of the refineries in the region lie in AQCR's which have definitely
been established as non-attainment.
487
-------
I
The primary sources of CO from refineries are catalytic cracking units,
fluid cofcers and asphalt oxidizers. Effective control of CO emissions
from a catalytic cracking unit can be accomplished by use of a waste
heat boiler or the "hot" regeneration process. The reader is referred
to Section 3-5 for a summary of which FCC units utilize such controls
and which do not.
4„5 NO EMISSIONS
X-
The major sources of NO emissions from a refinery are combustion units.
A
Other sources such as catalytic cracking regenerators also contribute to
the total NO emissions. No measures are taken to control these emissions
A
from the above mentioned sources and in most plants there are no applicable
NO regulations. None of the refineries in the region are located in
A
AQCR's which have definitely been established as non-attainment.
488
-------
06 /14/76
PACIFIC ENVIRONMENTAL SERVICES
TABLE 4-1
PARTICULATE EMISSIONS IN TONS PER YEAS
PAGE
COMPANY NAME
"CITY
REF.
CAP,
C 1000
¦ BPnr—unc *
FLUID
COKERS
A'Ci
~AL'L~
FLU 19
CATALYT EC
CRACKERS
"UNC ACT • " ALL"
THERr'AFfR
CATALYTIC
CRACKERS ¦
UNC ACT' ALL"
COMDUSTION
UNITS
OTHER
SOURCES
UNC"
"fiCT
~AL L UNC A CT ALC~
COLORADO
CONTINENTAL CIL COMPANY" {CONOC
COMMERCE CITY 30 NA
! THE REFINERY COPPOPATION
' ' CCMM FnC E CITY 21 NA
GARY WESTERN COMPANY
GIL SON I TE 995 NA
NA NA 508 127 143 NA
NA " NA - 319 " 319 134 NA
NA NA
NA
NA MA
NA
NA NA
NA " NA
131 131 420
61
61 175
8 39
NA NA 8741 3741 4Z7 2376 68 147
-f*
CD
to
STfTE TOTAlS
027 446
2B3
3933 8933 1024 238T
76 186
MONTANA
EXXCN CO.
BILLINGS
BIG WEST CIL CD.
KEVIN
45 ' • 639 639 407 -- 275"
5.123
NA
FARMERS UNION CENTRAL EXCHANGE
:75 376 NA-
NA NA NA NA
NA
NA
L AUREL
C3NTI*iGNT AL OIL CO.
RILL INC. S
42.5' NA
NA' NA 503 508 213 " NA
52.5
NA
NA NA 639 639
!22
PHILlIPS PETPCLEHM CO.
' GREAT FALLS 6
NA NA" NA 91" 91 '102 '
HESTCG REFINING
CUT BANK
TESTRC PETROLEUM CO.
" WOLr POINT -
4.7
NA
NA MA NA NA
NA
NA
NA
2 . T NA NA NA " NA NA NA NA
MA NA 135 135 C 75 0"
NA ' NA
NA-
NA
175
59 59 125:-
NA NA 232 232 1760
MA NA-
NA NA
8 8
• 01 '
0
"C 0
0 --
11
i I 444
NA — NA J. 2 12——"61
"0-
- 0-
STATE TOTALS 639 639 407 1515 1515 914 0 0
0 463 460 4769
0 0 0
-------
06/14/76
PACIFIC ENVIRONMENT A1-. SERVICES
PAGE 2
TA51E 4-1
REF.
CUP.
(1000
"B PD}"
COMPANY NAME
CI TY —
NORTH OAKDTA
AMEPICA'J OIL""CO". f JKCCO ) ' "
MANCAN 53
NORTHLAND OIL £ REFINING CO.
" DICXINSTN 5
""WES7LAND nil._COMPANY
WILLISTCN 4.5
STATE TOTALS
UTAH
AMERICAN PiL COMPANY fAMHCn)
SALT LAKF CITY 39"
PHILLIPS PETRTLEUM CD.
HOODS CROSS 24.0
WESTERN REFINING COMPANY
" WCODS CROSS " "" " " MO"
CHEVPON OIL COMPANY
SALT LAKE CITY
HUSKY OIL COMPANY
45
CARIBCU FOUR CORNERS INC
WOOOS CROSS 5
PLATEAU INCORPORATED
ROOSEVELT " " B
PAR T!
CULAT
c EMI
Ss ¦ On*S
!N TOMS PER YEAR
FLUID
,
FLU i 0
THEP f'.AFTR
COMBUSTION
OTHER
COKFRS
CATALYTIC
CATALYT IZ
U.\ ITS
SOURCES
CRACKERS
CRACKERS
"" UMC
"ACT"
""AtL
~uriC"
ACT
ALL
'T UMC
ACT
"ALL
' UNC
" ACT " "
ALL
" UNC "
ACT-
ALL
NA
NA
NA
NO
468
236
NA
NA
NA
271
271
3442
0
3
0
NA
NA
' " NA
NA
' NA"
NA
NA
MA
N A
16
16
" 79
0
0
0
NA
NA
NA
NA
NA
NA
NA
NA
NA
2
2
243
0
0
0
0
0
0
0
46 3
236
0
0
0
291
291
3770
0
3
0
1
'NA-
NA-
"' ' 'NA —"
232
232 "
22T
" NA
' NA " "
N A" —
Z14"
214
1256""
u
0"
i
~0
(
NA
NA
NA
NA
NA
NA
205
205
205
NO
ND
C45
0
0
° i
""•NA'
" NA-
NA
~"N3 ~
NQ
— NB~
NA '
MA
~ NA "
35
—14T
0
0
—0—
NA
NA
NA
204 1
203
214
100
100
219
161
16 I
1410
0
0
0
— "NA—
NA-
NA
- " NA-
NA
" -"NA""""
35
35
-170"-
-—1-18-
118
' -700-
0-
0
0-—
NA
NA
NA
NA
NA
NA
NA
fvA
" NA
4
4
46
0
0
0
—"Mfl--
NA ~
NA
"219
ND"'~
... .
NA-
NA
"NA "
.. -3C -
30 '
96
- 0
0"
¦ - —- — — Q" —
-------
06/14/76
PACIFIC ENVIRONMENTAL SERVICES
P AGE
3
TABLE 4-1
PARTICULATE
ENISSIGNS IN TONS PER YEAR
REF.
CAP.
( 1 000
FLUID
CDKERS
FLUin
CATALYTIC
CRACKERS
THERVAFPR
CATALYTIC
CRACKERS
COMBUST ION
UNI TS
OTHER
SOURCES
COMPANY NAME
CITY
BPD) UNC
ACT "ALL UNC ACT ALL" ~ UNC
ACT ALL'
UNC ACT ALT UNC ACT ALL
WYOMING
TESCRC PETROLEUM """ - . . -
NEWCASTLE 10.5 NA NA NA NA NA NA 25 1 251 135 149 149 NO 0 0 0
LITTLE AMERICA CIL CO
EVANSVILLE 24.0 NA ' NA MA NA NA MA 97 97 NO " " 123 " 123 NfJ 0 0 0
AMFPTCAN CIL' (AMOCO) "
CtSPEP 43.0 NA NA NA 153300 153 303 NA NA NA 79 79 NO 38 35 10
PASCC INC
SINCLAIR 48.6 NA ~ NA NA 24034 248 230 NA NA NA 154 154 NO 0 0 0
EVANSVILLE 21.0 NA NA NA ND 256 190 NA NA NA 180 180 NO 0 0 0
SATE CPEEK REFINING
COkLEY. 1.2 NA NA NA ' NA NA " NA NA NA NA NA NA NA 0 0' 0
COPY 11.0 NA NA NA 32 32 157 NA NA NA 23 23 ND 0 0 0
HUSKY OIL
CHEYENNE 25 NA NA NA 398 NO 200 NA NA NA 43 43 NO 0 0 0
"STATE TOTALS"
0
0 " 0 176565 691 1082" 349 "349 " 135" " 755 755 T5 38 33 10
"REGICN TOTALS* 639 639 407 183400 3558 2958 690 690 731 11013 11013 14067 2925 123 196
-------
06/18/76
PACIFIC ENVIRONMENTAL SEPVICES
TADLF 4-Z
SULFUR D iOX IDE EMISSIONS IN TOf-iS PER YEAR
PAGP
CQ«P\NY NAME
C i T Y
REF.
TAP.
( 1000
f) P0!" "
CTMBUS T ION
I INI TS
UNC
iLX
FLUFO
• r.ATALVTIC
CRACKERS
~UMC" '""ACT ALL
THF R'^iAFDP
CATALYT if
CRACKERS
'JNC ACT ALL
SULPIJP
RECOVERY
UNI TS
" tjVjC ACT ' ALL
OVHF R
SOURCES
IJNC "" ACT'"'
ALL
color son
CONI" I NcNTIL" nTi. C'J^PAMY (C0N0C
CQ1M F RC E CITY 30 2062
2362 2356 B 76
876
446 N A
NA
NA
NO 1519
52
43
43
1 49
THF PrFINcPY CORPORATION
CPI^ERCE CITY 21
517 517
L322 646
"GARY We STF- R N COMPANY
-P» GILSPNITr
LO
ro
995 I229 1229 2281 NA
646
NA
105 ' NA
NA NA
NA
NA.
^A NA
MA M &
NA
NA
NA NA
2 7 108
STATE TOTALS
3B09 3609 5960 1522 1522
MONTANA
5 5?.
0 1519
52
71
71
2 56
FXX1N en.
Bin f'ir,s"
"BIG WfST OIL CO.
KFVIN
45 3657 3b 5 7 1769 3293 3298 NO NA
5.123 139 139 NO NA
NA
N A NA
NA
NA
NA' " NA NA ¦ NA " 2225 2225
N A NA
NA
NA
FAOMFRS UNION CENTRAL EXCHANGE
L All' - L '""42.5 "75 2"
7 52
6i& 1033" 1033" " NCI NA
NA
NA
731 731
NO
"CONTTNrNTAL OIL CO.
BIU.PIGS 52.5 935 ?S5
963 1261 1261 NO NA
NA
^ A
NA
NA
NA
PHILLIPS PFTROLEU^ CO.
GR-AT falls 6 2"JOS 2503
"Nn"
' 1 B7 187"
NO
"WESTfn RFFINTNG
CUT RANK
4.7
339 339 - NO NA
NA
NA "NA
NA NA
NA
MA NA
\:a
NA
NA
NA
NA
fJ.A
" 0
635
tesodo p^trolfum ro.
""HOLroonr 2:7"
NO"
-
-------
06/18/76
COMPANY NA*:
C I T V
PACIFIC. F.NV I Rf'NKFMT fit SFRVICES
_ TABIF 4-2
SIM. FUR DIOXIDE FMI3SI0NS IN TONS PEP YEAR
R CF.
CAP.
( 1 000
4 PD ) '
CTM8U3 TTON
UNITS
"UNC AfT~ ALL"
FLUID
CATAIYTIC
CRACKERS
ilNC. ACT ' All.
THE R M 3 F 0 R
r. AT AL YT ic
CRACKERS
UNC ACT ALL
S JLFIJR
re:ovfry
UNI rs
UNC ACT ALL
P AGP
other
SOURCE S
UNC
ACT ALL
NORTH DAKOTA
"A H f s 1 C AN 01 L 0 V" ( 1 ^ICC 0 ) ¦ _ "
KA'i'Jf.'l , 53 4 813 43 13 12347
1800 1800
NORTHLINn n 1L f. RF F I NI NO. CO.
DICKINSON' 5 33
33 4 11
N A
'w^stland nI l company"
WILLISTQN
-
OJ
4.5 ND
0
B48 N \
NA
NA
NO
NA
N A
MA NA NA NA NA KA
NA NA
NA NA NA NA
NA NA N! A NA NA NA
ST A T c TOTA1 S
4847 4347 13606 1800 1000
UTAH
l«PP|r4M nIl COMPANY (AMOCO)
"SALT L AKr CITY""" 39 3784 '"'3784 NO' 1865 " 1665 " , ND NA NA NA NA NA NA
PHILLIPS Pc TR3L C(JM CO.
HOO^S C°"1SS 24.0 3613 3S13 ND NA NA NA 473 473 ND NA NA NA
HcSTcdr| OCFJNING COMPANY
- HO 1ns""CRTS 5 10 " ' 12" ND ND ND ND' NA NA MA NA ' NA NA
CHrVPON Oil COMPANY
SALT LAKF CITY 45 4313 49 13 MO 1081 1081
HUSKY OIL COMPANY
""NPTTH SUT LAKE "T~ 23 845 545'"' NO"" ^ A NA
CAPinQi) nun CODMFRS INC
WOODS C.RiSS 5 NO ND ND NA NA
PLATPAIJ J'JC^PPOR ATTP)
— ROIS^VPLT 8 ~" "43 " " 43 ~ "'NO 451 451
STATE TOTALS 13..",. 0 3308 3 390
ND 21 21 ND ND 19? ND 0 0 0
NA 78 78 vn NA NA NA 0 0 0
NA NA NA NA NA NA NA 0 0 0
NO NA , NA NA NA MA NA 0 0 0
9
0 573 573 0 0 193 0 0 0 0
-------
06/18/76
PACIFIC ENVIRONMENTAL SERVICES
T A f) L E 4-2
SULFUR DTOX-nF PMI S5S ONS !N TD'i5 PER YEAR
company namc
'city""
"FF.
cap.
(1000
"rpdj inc
7 ION
UNI TS
ALL
WYO-UNG
ELU10
CATALYTIC
CRACKERS
UNC ' ACT ALL
THE R"iAc HR
CAT Al. YT iC
CRACKERS
li'?(C AC T AL L
SJLTUR
RECOVERY
JNI TS
U'4C ACT ALL
PAGE
UMC
OTHER
SOURCES
ACT
ALL
TP'SORi" PETROLEUM
NEWCASTLE
10.5 24 7
247
L ITTLc am=rTCA oil CO
FVVJSVILLE 24.0 796 796
ND N A
ND ha
NA
NA
AMr^flN 0 ! L I AHO^O)
S^S°ER
-i^>
pasc rnc
Si NCI MR
Tc xicn
EVVJ^VILLE
sag^ tj=fk repining
COVL FY
HU^
-------
PACIFIC ENVIRONMENTAL SERVICES
N
PAGE . I
HYDROCARBON
TABLE 4-3
EM-SSiONS IN TONS PcR YEAR
_CO^PANY NAME
CITY -
REF.
CAP.
I 1000
" BPD)" l)NC~~
STORAGE
TANKS
ACT ALL
GiL/WATER
SEPARATORS
' U.MC ACT " ' ALL'
FLUID
CATALYFiC
CRACKERS
UfJC ACT ALL
LOADING/
UNLOAD ¦ NG
FACILITIES
U.MC ACT " ALL"
OTHER
SOURCES
UNC act
ALL
COLORAOO
"CONTINENTAL OIL" COMPANY < CONOC
COMMERCE CITY 30 NA
THE REFINERY CORPORATION
CO'-WERCE CITY 21 NA
"GARY WESTERN COMPANY '
GILSONITE
UD
cn
MONTANA
995
STATE TOTALS
NA
"NA
NA
451
ND
13
13
NA """ NA
ND NA
NA
NA
4 51
ND
NA
464 '*64 ND
NA
754 754
H A
NA
NA NA
NA ' 289 289 ND NA
r:A
NA
NA
NA NA
52 52
44
90 94
166 190
EXXON CO.
' BILLINGS"
6IG WEST OIL CO.
KEVIN
45
NA"
LAUREL 42.5
CONTINENTAL OIL CO.
BILLINGS
PHILLIPS PETROLEUM CO.
""GREAT FALLS 6
WESTCO REF JNiNG
CUT BANK
TESORO PETROLEUM CO,
"WOLF"POINT
NA
NA NA" NA
5. 123 1102 UG2
FARMERS UNION CENTRAL EXCHANGE
74 6 748
52.5 174? 249
"735 ND"
4.7 534 534
2.7 127 127
NO
ND
ND
'NO
ND
ND
"NA NA
394 ND
13"
13
73 ND
NA NA
NA ' 1C64 "" ND NO ' ~ NA"
30 30 ND NA NA NA
NA
ND
NO
459 ' ND
NO
NO NA NA NA
ND
NA
560 560 ND
83 " 83 ND '" 90
NA
NA
NA
NO
NA 3543 " '607"
ND NO
361 65
NA '3156 58 5
NO 3994 77 5
90 "" ND~ 464 "" 464
NA ' NA
NA
NA " ' NA
NA NA
NA "" _ NA
331 72
"39 '39
STATE TOTALS
5076 28 42
0 5 16
43
2168 643
17 3
90
0 11809 2689
-------
06/18/76 PACIFIC ENV t SONKENTAL SEP, VI CES PAGE 2
H YDRQCAP. SON
TABLE ^t-3
EMISSIONS IN TONS PER YEAR
COMPANY NAME
"CITY """"
REF.
CAP. '
( 1000
BPO) UNC"
STORAGE
TANKS
GSL/WATEa
SEPARATORS
""ACT ALL* UNC' " ACT"
ALL
FLUID
CATALYTIC
CRACKERS
UNC ACT " ALL'
LOADING/
UNLOADING
FACILITIES
"UNC ACT ALL'
OTHER
SOURCES
~UNC ACT ~
ALL
NORTH DAKOTA
"AMERICAN_01L COJ'I AMOCO J ""
KANOAN 53
74 1668
ND
ND
26 ND 801 801 ND
NA
N A NA 858 358
NCRTHLANO OIL C REFINING CO.
DICKINSON 5 ND
4^
UD"
CT>
"WESTLAND OIL"COMPANY"
HILLISTON
4.5
NA
ND
NA
ND
NA
ND
201
ND ND
201 ND
NA NA
HA
NA
NO "" ND
NA NA NA NA
WD
NA
72 68
STATE TOTALS
74 1668
201 227
sol eoi
935 930
UTAH
ACER IC AN OIL COMPANY {AMOCO}
~ SALT LAKE CITY 39 " 3385 3335 "" "ND NA NA ' ~ "NA" " "516 516 ND NA "NA NA 2312 240 0
" PHILLIPS PETROLEUM CO.
HOODS CROSS 24.0 83 83 ND NA NA NA HA NA NA NA NA NA 613 144 0
WESTERN REFINING COMPANY
WOODS CROSS "" " 10 ND HO ND " NA """ NA "" ' NA " KA NA NA " ' NA NA NA " 8 S 0
' CHEVRON OIL COMPANY
SALT LAKE CITY 45 433 433 NO NA NA NA 21 21 ND NA MA NA 2640 ?14 0
HUSKY OIL COMPANY
" NORTH SALT LAKE C "' " 23 " 1664 1747 """ NO NA " ' NA ~" NA ' ' NA NA NA "' NA NA ' ' NA ' ' ' 179 179 0
" CARIBOU FOUR CORNERS INC
HOODS CROSS 5 249 249 ND NA NA NA NA NA NA NA NA NA 23 25 0
PLATEAU INCORPORATED
ROOSEVELT ' '8 "NA NA NA "NA ' ' ' NA " NA 201 201 NO NA~~- NA ' NA "6 8' """" 0
-------
06/18/76
REF. STORAGE
CAP. TANKS
COMPANY NAME (1000
CITY ' "BPDI- Utt'C ffiT"
WYOMING
1 TESORO" PETROLEUM
NEWCASTLE 10.5 66 66
LITTLE AMERICA OIL CO
EVANSVILLE 24.0 2824 20 24
AMERICAN 0 J L~ { AMOCO > " '
CASPER 43.0 1217 E217
-P>
-J PASCO INC
SINCLAIR 48.6 531 531
TEXACO '
EVANSVILLE 21.0 4557 <>557
SAGE CREEK REFINING
COWLEY . 1.2 NA N A
HUSKY OIL " .
COOY 11.0 3689 3689
HUSKY OIL
CHEYENNE 25 1339 1339
State totals i4226"i4226 "
s REG I ON TOTALS'!1 25192 24649
PACIFIC ENVIRONHEMTAL SERVICES
TABLE 4-3
HYDROCARBON EMiSStGNS !N TONS P£R YEAR
"ALL ~ IMC
OIL/HATER
SEPARATORS
ACT
ND
NO
NO
NO
NO
NA
ND
ND
53
60
10
288 285
NA
67
169
6 76"
NA
'ALL UNC
6 . ND
10 NO
NO
NA
FL'JID
CATALYTIC
CRACKERS
ACT " ALL
LOADING/
UNLOADING
FACILITIES
Ui\'C ACT ' " ALL
PAGE 3
OTHER
SOURCES
"UNC ACT ALL"
NA NA NA NA
NA
NA 2064 2064
53 ND .NA NA NA NO ND
ND
60 ND NA NA NA NA NA NA
T09
91
NA
"09 NO
NO
NA
NA
NA
NA NA
67 ND J. 20 120 ND
ND
NA
NA
NA
HO
NA
NA
NA
ND
90 90
136 136
398 398
352 352
22
189 NO 363 363 NO NO NO MD 26 26
676"' 0 1284 1284 " 0" 0 "0 Q - 309i 3091"
0
0
1545 951
0 5747 4223
173
90
0 21891 7724
-------
06/22/76
PACIFIC ENVIRONMENTAL SERVICES
PAGE I
TABLE 4-4 _ ,
_ CARBON MONOXIDE EMISSIONS IN TONS PE<* YEAR
REF. COMBUSTION FLUID THERMAFOR FLUID OTHER
CAP. UNITS ' "'" CATALYTIC CATALYTIC COXERS SCl'RCSS
CC^PANY NAME (1000 CRACKERS CRACKERS
CITY BPDi UNC AC T ALL "UNC "ACT" "" ALL ' UNC" ACT " ALL" ' UNC ~ ACT" ALL UNC "~ ACT ALL
CCLORAOO
C 0 NT I N~f? fi14 L OIL COhrPAN y" (CONOC * — - - —
COMMERCE CiTY 30 26 26 NO _ 38893 38898 NO NA NA NA _ NA ¦ NA NA __ _ 4 .4 0
THE REFINERY CORPORATION
CCMMERCE CITY 21 8 '8 ND I7B92' 17892 NO " NA" " NA NA" NA NA NA 0 0 0
GARY' WESTERN "COMPANY " "
GILSCNITE 995 NO NO NO NA NA NA NA NA NA NA NA NA 0 0 0
UD • ....
CO
STATE TOTALS 34 34 0 56790 56790 0 0 0 1 0 0_ 0 0 4 4 0
P.CNTANA
_EXXrjfj CO. _ _
BILLINGS 45 ' ' NO " "NO " NO""' 6C256 NO N~D~ NA NA NA~ 24453 ' NO ND ~ C "o 0
B IG WEST 01 L CO. " " ""
KEVIN 5.123 NO NO _ ND NA NA NA _ NA NA NA NA NA NA 0 0 0
FARMERS U'JION CENTRAL EXCHANGE
Laurel"" """ ™ 42."5" " 36 36 ND 2875 4 ND ND NA NA NA" NA NA " N A """ " O" 0 " 0
CONTINENTAL OIL CO-
BILLINGS 52.5 ND ND ND 53874 531374 ND NA NA NA NA NA NA 0 0 0
PHILLIES PETROLEUM CO.
" GR E A 7 FALL S """ 6" ND NO NC~ " big'3 " "5193" ND NA "" NA " ""NA"" NA" " MA NA~ o'" 0 " ~ 0
WESTCG REFIMNG
CUT BANK 4.7 3 3 ND NA NA NA NA NA NA NA NA NA 0 0 0
TESCRO PETHCLEUM CO.
WCLF "POINT" ' 2.7"" 4 "4"" "N'C N A NA" " ~N'A "NA" NA""" "~NA'~ "~NA' " NA"" NA 0" " 0 0
-------
06/22/76
_CGMPANY NAME
city"'
PaClf|C ENVIRONMENTAL SERVICES
TABLE 4-4
CARBON MONOXIDE EMISSIONS IN) TONS PER YEAR
RfcF .
CAP.
(1000_
~ BPD j
COMBUST ION
UNI TS
UNC ACT ALL
FLUID
CATALYTIC
_CRACKE^S _
UNC "act all
THERMAFOR
CATALYT IC
CRACKERS
UN C ACT"" ALL'
PAGE
FLUID
COKFRS
OTHER
SOURCES
UNC ACT ALL UNC ACT ALL
NORTH DAKOTA
AMERICAN OIL CO. UHOCOI
MANOAN 53
NORTHLAND OIL t REFINING CO.
DICKINSON 5
NO
UO
VD
WESTLAND OIL COMPANY
W ILL ISTON
1 A NA "'
ND
201
ND
ND N A
NA
ND
NO NA NA NA
ND
"NA 4435 '" ND"
N A NA NA NA
NA NA
NA NA
NA NA
NA NA
"NA ' " NA
NA NA
"8 fiO~~ 12500 ND" ND NA' NA NA NA T " NA"
NA
NA
NA
NA
NA
NA
NA
STATfc TOTALS
6 2
0^
0 7 900? 2 3 99 fl
7653 44H9
-------
06/22/76
PA
CARBON MONOXI OS EHiSSICNS IN TOMS PER YEAR
REF. COMfl US TIGN Ft UJ 0 THERMAFOR _ FLUID OTHER
CAP. '"' UNITS " CATALYTIC CATALYTIC CQKERS SOURCES
CCMP&Nr NAME (ICOO CRACKERS CRACKERS
CITY"" 8PD J UNC ACT ALL UNC , ACT ALL ' UNC ACT ALL UNC " ACT ALL UNC ACT
WYOMING
TESQRO PETRCLEUM
NEWCASTLE 10.5 NA N A NA NA _ NA NA 256000 12300 . _N0 NA NA NA__
LITTLE AMERICA OIL CO
EVANSVILLE 24.0 " NA MA~ " N A N A NA" " N A "9855" 9055 NO NA NA NA
A^ERiCAN OIL (AMCCCI
O _ CASPER 43.0 5 b 56 NC 15500 ?.5500_ NO N A NA _ N A NA NA NA
O" ~ . .. - ' -
PASCO INC
SINCLAIR 46.6 NA N A "" NA '32325 '32325' NO NA NA " N A ' NA "" NA ~NA
TEXACO
rVANSVILLE 21.0 NA NA NA 17664 17664 NO NA , NA NA NA NA
SAGE CREEK REFINING
CCULFY "" 1.2 NA NA NA " NA NA NA "" MA NA ' NA" '"" NA " ' MA NA
HUSKY OIL
CCDY 11.0 4 4 NC 199 84 19984 NO NA NA NA MA MA NA 0 0
HUSKY OIL
"CHEYENNE " " 25 NA "NA "" NA ' 22504 22504 ' "NO " NA NA NA NA NA" NA 00
STATE TOTALS 61 61 0 107979 107979 0 265B55 22655 0 0 0 0 G 0
~REGION TOTALS* 227 227 0 447861 297846 0 273708 27144 0 24453 0 0 4 4,
-------
.06/21/76 P AC if IC ENVIRnNKP.MJil. SERVICES . PAr'F
TAPLF 4-5 .
NITROGEN OXIUE EMISSIONS IN TOMS P£P YEAR
P.EF, OIL-FIRED GAS-FIRED _ C f)MT">—p ; RED CnAl.-eiRFO OTHER
"cap. COMBUST ICN " " ~ 'COMBUST jlir*'" ' ' "cn.'"Bi)STihN " COMBUST jn'j SHURCFS
CC.P1MY NAME (1000 UNITS LIMITS UNITS UN T T S
CITY BPD» UN C ACT ALL UNC ACT ALL UNC ACT aLL CNC ACT ALL UNO ACT ALL
C 0 L rR AO"1
CONTINENTAL OIL COMPANY (CCMOC
COMMERCE CITY 3 0 162 lb2_ NO 25 S 2 58 f-'O 34 5 34 5 ND MA NA NA 15 7 __Jj? 7
T H F REFINERY CORRTPAT I DM
CP^'-'ERCF CITY 21 0 7 0 7" ND 220" 220 >U> 39"" 39" NO NA ' NA MA 92 92
GARY ViESTEP-.N COMPANY
cn r, ILSCNI JF 995 flfi NA NA 10 4 104 ND A?90 4 ^90 WD N A MA NA 7 _ 1
STAT E TCTALS 249 ?49 0 583 503 0 4675 4 675 0 0 0 0 257 257
HO N T A NA
EXXCN C^.
HILLINGS 45 MA NA MA 131 131 Nil 5S2 58? ND MA NA NA 683 683
B I C, V-FST OIL CO «
KEVIN 5.123 NA fit, NA 65 65 fvD NA 1 NA NA NA NA N A
FA P "gq S UNION CENTRAL FxrnANGE _
L AU^EL 42.5 "MA MA Fit 2~32 T32 ^ ND 234 21j4 ND ' N4 NA FTK FTS 148
CONTINENTAL OIL CO.
BILLINGS 52.5 MA MA NA 451 451 ND 433 433 ND HA MA NA 179 179
PHILLIPS PETRPL EUM CO.
G»EAT FALLS 6 NA MA NA 8/ 37 NO MA NA NA NA- NA 71 TT
HESTCO REFINING
CUT fiANK _ A'7- _ '_JA 158 _„i58 _ ND N" _ __ f"^ _ ''1A_ _ NA __
TE STPO PETROLEUM CO.
WCLF POINT 277 4 4 ND a 8 NT) T3 II FFi fTa FTH FIT"
STATE TOTAlVs "" " "4 '• 0" 1134 U3V""" "" 0 1314 1314" "" "0" ' 0" " 0 0""' 103P' 1039
-------
_ 06/21/76 PACI F ic _ENV; ponmfnt AL JS.PV IC FS . . PAGE
~A3L E 4- 5 ;
N! TROGE N_CX| OE _.EK|SS!0N3_ IN JONS PEP, _YEAR
p EF . 0 IL-FIREO GAS-F!Rf0 CO^n-F ! P^D COAl-FIPFO ¦ HT HFR
"CAP." CC'mRUST ICN 'COMBUST'ION'" " CCMBIJ ST \ ON ~ COMRUST IO>J SOURCES
COMPANY NAME I 1 OOP UN I T S UN i T S UNITS UK1! T S
CITY BPO) UNC ACT ALl UNC ACT ALL UHC ACT ALL UNC ACT A|_L UNC ACT ALL
NORTH DAKOTA
AMfPICAN CIL CO. (AMOCOi
"AMDAN 5 3 NA MA NA 6 1 6 1 NO 906 906 NO NA . Ml NA ?58 20S_
NnR THLA NO 0IL_& QTiJ
DICKINSCN """" ~5 " MA NA NA NA" NA NA 37 37 NO " NA MA NA
HE STL AND TIL COMPANY
<-n u Lkkf5J-GM_ 4.3 NA NA NA 2 C- 20^ NO _NA NA NA h_A MA MA
ro
STATE TOTALS 0 0 0 82 62 0 944 944 0 C 0 0 2 r> B 2 5 fi
UTAH
AM FP IC AM PtL COMPANY (AMOCO > ^ '. . .
S 4 L T LiKf CITY 39 MA NA NA FTa NA NA 1011 1011 NO FT3 FHv 1 6 6 16 6
PHILLIPS PETROL EUM CO.
WOODS CROSS 24.0 NA NA NA NA NA MA 372 - 372 NO NA NA NA 1449 1449
W£STF°N RFFIMING CCf-'PANY ; .
WOODS CROSS 10 NA MA NA NA NA NA T65 165 NO "~F5 tTK FT^ 0 1>
CHEVRON OIL COMPANY
SALT LAKE CITY 45 NA NA NA 486 486 MO 692 692 534 NA NA NA 157 157
HiJSKY OIL COMPANY
no»th salt lak E C 2l NA NA nI H B FID 573 CT5 FiD FTS FT* N3 ?~
CARIBOIJ FCiJP CORNERS 1MC ~ " ------ -
WOOOS CROSS 5 NA NA MA 8 f) NO NA I* A NA NA N A NA 0 0
PI ATgA'J I NC0Rp0 R ATF0
poos EVELT 8 NA MA frA [73 175 FTS I00 RID ?JD fTS ITS FPv ZT1) 6 b
-------
Jf(>/Z\Ll(>. PACIFIC. ENVJRPNMEWAL SFRVICtS __J. 1 PAGE
TAOLE 4-5
NITROGEN OXIDE EMISSIONS IN TONS PFP YFAR __ _ _
PEF. 01L- FI RED G A S - F IH E 0 COWW-F 1 PEO 'COAL-FIRFD _ _ PT HER
c^p^ r.c"e.HST i'r:j """cbt-'RUST ions " ""cnwujsft'nN combustion sources
CPMPflNY NAME (lfirn UN I ' S UN I T S I)'IT'S UN i T S
CITY SPD) IJNC ACT ALL UNC ACT ALL IJMC AC1 ALL UNO ACT ALL UNC AC T AIL
_W Y r M J N G
TE SC"P PFTPPLFlie
^l EfcC ASTLE
10.5 MA HA
NA
NA
MA
MA
48
4 8
131 MA
L I TTLc AFRICA CI L_ CC
EVAMSVILLE 24.6 MA
NA
NA
lis in
I t a 4 90 ~ 490 " 5 7a NA
HA
NA
NA
B 1
21 ? 1
SHFPKAN PJL ( A MOT 0)
O CAJPE". __
_PiSCP INC
S I" C L A IR
43.0 NA
4H.t NA
MA NA 29_4 2'J 4 319 178 __ 17 3^ 1208 NA_
NA NA 4 16 4X6 416 515 5 15 598" NA"
MA
NA"
N A
NA
14 14
16 7 "" 16 7
TE X£Cn
E VA'ISVillE
21.0 MA
sir,f c-epk refining
C ° WL E Y 1.2"
MA
flA
MA
NA
NA
253 253 250 634 634 762 MA
N A
NA
NA
N A
NA
NA
NA
') A
NA
NA
NA
? 3 4 234
HUSKY PIL
CPOY
_HU5KY OIL
cheyenne"
1 I. 0
38 33
219 219
?26 NA NA N A
2 5 115 115 13 7 118 118 i4S 'I A
NA
" N A
NA
NA
N A
M A
NA
" N A
45
45
113 ~ 113
STATE TOTALS
154 154 186 1420 1420 14SC 18f>6 1 H66 3279
733 733
*REr,IPN TPTSLS*
407 407 136 3728 3728 1460 11638 11833 3813
0 4131 4131
-------
SECTION 5. REGULATION COMPARISON
5.0 Each of the state agencies in Region VIl'I has developed a set cf air
pollution regulations dealing with emissions from sources in their
jurisdiction. Application of these regulations to sources at petroleum
refineries results in no limitations for several pollutants at many
refineries. In Colorado, some refineries are subject to more strict
limitations than are others. The various rules applied in each state,
or the lack of them are discussed in more detail below. Tables
5-1A and B, 5-2, 5-3, and 5-4 which appear at the end of this section,
summarize the applicable regulations used in this study.
5.1 COLORADO
Thestate of Colorado is divided into several regions by the Colorado
Air Pollution Control Commission operating under the jurisdiction of
trie Colorado Department of Health. Hydrocarbon regulations in the Denver
Metropolitan Air Pollution Control Area which affect two refineries, are
the only limitations which are more strict than those in the other
designated Air Pollution Control areas in this state.
There are separate particulate emission limitations governing com-
bustion units, process equipment, and "incinerators. There is no dif-
ferentiation between new and existing units for the combustion and process
equipment regulations, however, limitations governing new incinerators
Sre more strict than those governing existing units. Regulations
governing sulfur dioxide emission limitations for combustion and process
equipment are the same, however, the regulations differentiate between
new- and existing sources.
Regulations governing the Geand Mesa County Intra-State Air Pollution
Control Area limit emissions from organic storage facilities, pumps
and compressors, and hydrocarbons released from waste gas disposal.
The Denver-Metropolitan APC area uses the same hydrocarbon regulations as
Grand Mesa County Intra-State APC area, but is more strict by limiting
504
-------
emissions from loading racks, and oil-water separators. There are no
regulations in the state of Colorado governing emissions of nitrogen
oxides and carbon monoxide.
5.2 MONTANA
Regulations governing the particulate emission limitations for new
combustion units are more strict than those applied to existing units.
There is a state regulation governing particulate emissions from existing
process equipment, and for new equipment the state refers to New
Source Performance Standards as noted in Title 40, Chap. 1, Part 60,
CFR, except Section 60.10. Particulate emission limitations for new
incinerators are more strict than those for existing incinerators.
There are no sulfur dioxide emission limitations governing process
equipment found in a refinery. Regulations governing combustion
units have provisions which exempt refineries processing less than
10,000 BPD crude oil charge and waste gas 'incineration if the heat
content is less than 300 BTU/ft^. There were insufficient data
available in many cases to determine if v/aste gas streams from the
refineries were exempt.
Although hydrocarbon emission limitations are concerned with organic
compound storage and oil-water separators, there is a provision in the
regulations which exempts refineries processing less than 7,000 BPD of
crude oil charge. Refineries not exempt from the regulation shall comply
with regulations governing organic compound storage by January 1, 1977.
There are no regulations governing the emissions of nitrogen oxides and
carbon monoxide.
5.3 NORTH DAKOTA
Regulations governing new combustion units in the North Dakota State
Department of Health Regulations are more strict than those for e>r!sting
-""''-'-Si tiowevcr, when technology develops new_^-cr0~! equipment compatible
with present plants, the plants
-------
new sources when directed by the department. Regulations governing
the emissions from process equipment are the same for both new and
existing sources, however, if the control equipment has a collection
efficiency of 99.7% or greater the source is considered to be in
compliance. It is conceivable that one could consider the internal
cyclones of an FCC as control equipment, and apply for this exemption.
However, if one were to consider the hypothetical case of an FCC with
a fresh feed rate of 1,000 barrels of fresh feed per hour, and a catalys
to oil ratio of 9, this would give a fresh feed process weight of 157.5
tons/hour and a circulating catalyst rate of 1,417.5 tons/hour. Apply-
ing the exemption to the North Dakota process weight rule would yield
an allowable pounds/hour rate of:
1,417.5 tons/hr (1-.997) x (25000 lb/ton) =
= 8505 Ib/hr
Application of Rule 54 of the old Los Angeles Air Pollution Control
District would allow this unit approximately 23 lbs/hour if the fresh
feed rate alone was used, and 30 lb/hour if the circulating catalyst
rate was included. If the above unit was not exempted from the process
weight rule, 82 lb/hour would be allowed. Particulate regulations
governing emissions from incinerators are identical for both new and
existing units.
Regulations governing sulfur dioxide emissions are the same for both
existing and new sources, however, the only regulations which can be
applied to process equipment concern ambient standards. Hydrocarbon
regulations apply to organic storage, loading racks, pumps and
compressors and waste gas disposal in refineries designated as new
sources only. There are no regulations limiting emissions of nitrogen
oxide and carbon monoxide.
UTAH
Regulations governing emissions from new combustion units are the
same as those concerning existing units, however, the regulations do
not apply to emissions from CO boilers. New and existing process
equipment are also governed by an emission limitation. Although there
506
-------
is a regulation governing new and existing incinerators! those units
with a charge less than 10,000 lbs/hour are exempt from the particulate
emission limitation. There are no regulations governing the emissions
of sulfur dioxide, hydrocarbon vapors, nitrogen oxides and carbon
monoxide.
5.5 WYOMING
Although the regulation governing particulate emissions from new
units "is more strict than those governing existing units, the regulation
is concerned with sol id-fuel-fired sources. By definition, fuel oil is only
considered to be a solid fuel in Wyoming. There is a regulation governing
new process equipment which is more restrictive than the particulate
emission limitations of existing equipment. The regulations governing
incinerators have the same standard for new units and existing units.
There are no Wyoming regulations, other than ambient regulations,
governing the emissions of sulfur dioxide from combustion units and
process equipment. There are only ambient regulations governing hydro-
carbon losses from organic compound storage, loading racks and waste
gas disposal systems.
Wyoming's nitrogen oxide regulations are more strict for new sources
than for existing sources. There are no limitations, other than ambient
regulations, governing the emissions of carbon monoxide.
507
-------
TABLE 5-1A: APPLICABLE PARTICULATE REGULATION COMPARISONS
UNIT
COMBUSTION' UNITS
PROCESS EQUIFMENT
Regula-\.
tory Agency
EXISTING UNITS
NEW UKITS
EXISTING EQUIPMENT
NEW EQUIPMENT
State of
Colorado
PE - 0.5 if FI sS 1.0 x lo6 BTU/!ir
If 1.0 X 106 BTU/Ur < FI C 500.0 s 106BTU/Hr
PE - 0.5 (FI)-0"-6
PE » 0.1 if 500.0 x 106ETU/i!r =£ FI
Where:
PE ¦ Particulate Emissions in lbs/10^BTU
FI « Fuel Input in 10^ BTU/iir
" ' '{
Saras 83 existing units
E - 3.59(P)0-62 if P<30 T/Hr
E - 17.31(F)0-16 if 30 T/Krs;?
where:
E " Emissions in l.bs/lir
P » Process Weight in Tons/Hr
Sane as existing unita
State of
Kontana
Up to and including 10 x lO^ETU/Hr iicot Input:
0.60 lb/10°BTU
100 x 105 BTU/IIr Heat Input
0.40 lb/106BTU
1000 x 105BTU/Hr heat input:
0.28 lb/106BTU
10,000 x lO^BTU heat input and above:
0.19 lb/106BTU
Interpolation requires Tigure 1 in regulations
Up to and including
lO^BTll/ilr. heat input
0.60 lb/106BTU
100 x lO^BTij/Hr heat
Input:
0.35 lb/106ETU
1000 x lO^BTU/Iir heat
input:
0.20 ib/10 BTU
10,000 x 106BTU/Hr heat
input and above:
0.12 lb/106BTU
If ?<30 T/'l!r
n - i.io(p)0'67
If P > 30 T/Hr
0.11
E - 55.0 (P ' ) -&0
Where:
P " Process weight in Ton3/Hr.
E - Rate of emission in Lbs/Rr
Subject to new source
performance standards
Title 40, Chapter I,
Pert 60, CFR, except
Section 60.10
State of
North Dakota
0.8 lb/10^BTU However, when technology
develops new control equipment compati-
ble with present plants, they shall
comply with state standards for new
sources when directed by the department
If 10 x 106BT'J/I!r or
less;
0.6 lb/105BTU
If greater than
10 x lO&BTU/l'.R;
E « 0.811 (i;)-"-i31
kfnere;
E « Allowable* par-
ticulate emieaioa
in lb/hr.
H ¦" Heat input ii)
1063TU/lir
If P < 30 Tons/Hr:
E - 4.10(P)0,67
If P >30 Tono/llr:
E = 55.0(?0,11) -40
Where:
? - Process weight rate in Tons/Hr
E ¦= Rate of Emission in lbs/hr
If collection equipment has
efficiency of 99. IX or greater,
source ia considered in compliance
Satze as existing process
Equipment
-------
TABLE 5-1A: APPLICABLE PARTICULATE REGULATION COMPARISONS (cont)
cn
o
UNIT
COMBUSTION UNITS
PROCESS EQUIPMENT
Regula-
tory Agency^^
EXISTING UMlTS
NEW Iftfirs
SXISlXtK, EQUIPMENT
NEW EQUIPMENT
State of
Utah
If 10 v. lO^BTU/IIr or Less:
0.60 lb/106BTU
If 10 x 106STU/!lr < C <10,000 x 106ETU/Kr:
A - 0.87 (C-0"16)
Where A *» Allowable eraisoion rate in
lb/lO^BTU
C = Total rated capacity in 10^BTU/Hr.
If C >10,000 x 106 BTU
A - 0.20 lb/106BTU
Does not apply to CO boilers
Same as existing
¦
r •• . . ¦
If Process weight is<30 Tons/ilr
E «¦ 4,10(P0,37)
If Process weight is >00 Tons/Us:
0 11
E - 55.0 (P' ) -40
inhere;
E « Emissions in Ibs/hr
P ¦ Process veight ia Tons/hr
Same as exinting
State of
Wyoming
6
If 10 r. 10 BTU/hr or leas
0.6 lb/106BTU
If ,10 X 106DTU/Hr to 10,COO x 106BTU/Hr
A „ J3.fi.0fi3 6
I". 1743 lb/hr/10 BTU
Where:
0.10 lb/106BTU for solid
fuel fired cources.
Nets; Fuel oil i3
considered solid fuel
If process weight rate is less than
or equal to 30 tona/hr;
E " 4.10 (P°*67)
If process weight rate ia greater
than 30 Tons/li.::
Oil
E » 55.0 (P ) -40
If process weight rate
is less than or equal to
30 Tons/Hr
E « 3.59 (P0-62)
If proces3 weight is
greater than 30 Tons/Hr:
A " Allowable emissions lb/10^BTU
I " Heat input in 10^BTU/Hr
6
If greater than 10,000 x 10 iiTU/Ur:
0.16 lb/106BT'J
Where;
E *» Emissions in lbn/hr
P • Froceas weight in tons/hr.
E - 17.31 (P0-16)
'•Jhere: ¦
E « Emissions in lbs/hr
F « Process weight rate
in tons/hr.
-------
TABLE 5-IB.
APPLICABLE PARTICULATE REGULATION COMPARISONS
UNIT
Regula-^v
tory AgencV\^^
INCINERATORS
EXISTING UNITS
NEW UNITS
State of
Colorado
0.15 gr/dscf @ 12% CO
Effective Jan. 1, 1977
0.10 gr/dscf @ 12% C02
0.10 gr/dscf @
12% C02
State of
Montana
If burn< 200 lb/hr waste;
0.3 gr/dscf @ 12% C02
If burn >200 lb/hr waste;
0.2 gr/dscf @ 12% CO2
0.1 gr/dscf @
12% C02
State of
North Dakota
All incinerators which are
to burn types 2,3,4,5 and 6
waste must have auxiliary fuel
burners of capacity and design
to assure a temperature in
the secondary combustion
chamber of at least 1500 F
for a maximum of 0.3 second
retention time.
If<1000 lb/hr refuse burned;
E = 0.00515 (R0-90)
If>1000 lb/hr refuse burned;
E = 0.0252 (R°'67)
Where:
E = Allowable emission
rate in lb/hr
R = Refuse burning rate
in lb/hr.
Same as
existing
incinerators
State of
Utah
Units with charge less than
10,000 lbs/hr are exempt.
Units with 10,000 lbs/hr
charge or more shall not
discharge particulate matter
in excess of 0.16 lb/100 lbs
charge
Same as
existing
State of
Wyoming
0.20 lb/100 pounds charged
Same as
existing
510
-------
TABI.E 5-2: APPLICABLE SULFUR DIOXIDE REGULATION COMPARISONS
unit
Regula-
tory Agency^^^
COMBUSTION UNITS
PROCESS EQUIPMENT
EXISTING UNITS
NEW UNITS
EXISTING EQUIPMENT
NEW EQUIPMENT
State of
Colorado
500 ppra maximum concentration
January 1, 1975:
Submit detailed compliance schedule
ond control equipnent plans
January 1, 1978
500 ppm and 5 Tons/day niax. emission
or:
150 ppm max. emission
500 ppm maximum concentration
January I. 1975:
Source to be designed or
contracted rcust be
designed for:
500 ppm end 5 Tone/day max,
cmiss ion
or
150 ppm ma::, emission
Same os Combustion Unite
Eacie as Combustion Ur.its
State of
Montana
Liquid or solid fuels shall not contain
more than 1 pound sulfur per million BTU
fired.
Gaseous fuels shall not contain more
than 50 grains per 1C0 ftJ, calculated
as H2S at standard conditions.
Does not apply to waste gas incineration
if less than 300 BTU/Ft^. Does not apply
to refineries less than 10,000 BPD.
Sam:: ao existing ecurces
Hone
Hone
State of
North Dakota
3.0 lbs S02/106BTU Heat Input
Same as existing unite
Ambient Regulation
Ambient Regulation
State of
Utah
None
None J None
!
None
State of
Wyoaing
None
j
None I None
!
None
fi
1
-------
TABLE 5-3. APPLICABLE HYDR0CAK30H REGULATION COMPARISONS
UNIT
P.egula-
tory Agency
VOLATILE
ORGANIC
STORAGE
LOADING
RACKS
1
!
OIL-WATER
SEPARATORS
PtfKPS AND
COKPRESSORS
WASTE GAS
DISPOSAL
State of Colorado:
Denver-Metro A?C
Fi:ted roof, floating roof
or vapor recovery for
tanks >40,000 gain; floating
roof for 11 psia or less.
Equipped with vapor collec-
tion and disposal system
in good working order.
Prevent drainage frcm
iouiiirg device when
removed. System to
remain vapor tight at all
times. Collection equip-
ment not to exceed 1.24 lb.
vapor e:nis3Jon per 1000 gals
loaded. If less than 20,000
gal. per calendar day loading
exempt from vapor recovery
requirement, but must have
97% submerged fill.
If unit handles
200 gals or more per
day cf organic mater-
ials) with Raid vapor
pressurc>0.5 pound,
oust have vapor tight
solid cover, floating
roof, or vapor recov-
ery and disposal
system
Mugt be equipped with
mechanical seals or
othc;: equipment of equal
effic^ fcp.cy.
Hydrocarbon compounds
from polymer synthesis
process emission source
shall be burned at
1300°*F for 0.3 seconds
or longer. Blo^dovn
emissions to be burned
in smokeless flare or
equivalent.
Grand Mesa County
Intrastate
Same as above
Nona
None
Sane as above
Same a9 above
State of Montana
Fixed roof, floating roof
or vapor recovery system if
65,000 gals or ir.ore above
2.5 psia.
Refineries processing lees
than 7000 EPD crude oil
charge are exempt.
None
If unit handles 200
gals or more per day
of petroleum product,
must have vapor tight
fixed roof, floating
roof, or vapor re-
covery and disposal
system.
L'oes not apply to
crude oil production.
None
Hone
State of North
Dakota
If capacity is greater than
65,000 gals will be pressure
tank capable of ..laintaining
working pressure, or equip-
ped with floating roof or
vapor recovery and disposal
systera. If not pressure
tank or equipped with vapor
recovery, must be equipped
with submerged fill.
New loading facilities
handling 20,000 gals per
day or more must be equip-
ped with submerged fill or
oihcr vapor emission control
systens¦
•lone
All rotating pumps and
compressors handling
volatile organic com-
pounds shall be equipped
with mechanical seals or
other equipment of equal
efficiency.
All waste gas cust be
flared. Flares are to
have GEokelese operation.
State of Utah
None
None
None
None
None
State of
Wyoair.g
Ambient
Ambient
None
None
Ambient
-------
TABLE 5-4. APPLICABLE N0V AND CARBON MONOXIDE REGULATION COMPARISONS
X
UNIT
j
NITROGEN OXIDES
1
CARBON MONOXIDE
Regula-
tory Agency
EXISTING COMBUSTION UNITS
NEW COMBUSTION UNITS
State of
Colorado
None
None
None
State of
Montana
None
None
None
State of
Utah
None
None
None
State of
Gac Fired: 0.23 lb/106BTU
Gas Fired: 0.20 lb/106JTU
Ambient
Wyoming
Oil Fired:
If heat input< 250 x 10^ BTU/lir
0.60 lb/10°BTU
If heat input >250 x 10 BTU/Hr
0.16 lb/106BTU
Solid Fossil.Fuel:
0.75 lb/10b3TU
Oil Fired: 0.30 Ifc/10S3TU
Solid Fosuil Fuel: j
0.70 lb/106BTU
State of
North Dakota
None
ilone |
None
-------
SECTION 6. NEW SOURCE PERFORMANCE STANDARDS
6.0 The Federal Government has promulgated standards which apply
specifically to new sources. The newly constructed or modified
sources in a refinery which are subject to NSPS regulations
are summarized in Figure 6-1. The current status of each new
source existing or under construction in this Region is dis-
cussed below.
Type of Unit
Pollutant
Effective
Date
2,
3;
¦4.
Steam-Generators 250 x
10^ BTU/'hr
/L Coal or oil fired
Be Coals Gil or gas
fired
Fuel, Gas Combustion
Units
Catalytic Cracking
Regenerators
Volatile Hydrocarbon
Storage Tanks
Ao 655000 gallons
Capacity
Bc 65,000 but 40>000
Gallons capacity
Particulate
SO.
x
,f0x
Particulates
CO
Hydrocarbon:
Hydrocarbons
8/17/71
8/17/71
8/17/71
6/11/73
6/11/73
6/11/73
6/11/73
3/8/74
Figure 6-1: Applicability of NSPS Standards
at Petroleum Refineries
514
-------
6.1 There are nine sources subject to NSPS in Region VIII. A summary of
the compliance status of these sources is shown in Table 6-1.
Continental Oil Company in Commerce City, Colorado has installed
a new combustion unit which burns refinery gas. The compliance
status of this source is unknown due to the lack of a documented
sulfur content for the refinery gas. Gary Western Company located
in Gilsonite, Colorado has installed two 40,000 BBL floating roof
storage tanks which were found to be in compliance. In Montana,
there were no sources subject to NSPS.
Northland Oil and Refining Company in Dickinson, North Dakota has
four units subject to NSPS. The three fixed roof storage tanks
were found to be in compliance with available information, and the
combustion units were found to be in compliance from information
available.
Western Refining Company in Woods Cross Utah has two 10.,000 barrel
storage tanks whose compliance status is unknown. Plateau, Inc,
in Roosevelt, Utah has an FCC regenerator which may be subject to
NSPS. It is not known if the unit is equipped with a CO boiler,
and there is some doubt as to whether the source is subject to
NSPS since the exact construction start date was not available.
There are no known NSPS sources located in Wyoming.
515
-------
TABLE 6-1
06/21/76 PACIFIC ENV I RHNMg ?IT AV. SFPViCFS
STATUS Of . RJjf I Mt? V SPURC E S wiTK PESPEC7 . T n r.;$p S P ECiJI.A TION S
CO'-IP L I ANCE
COMPANY NAME CITY UNIT STATUS REMARKS
CTJ-PR ADO
CONTINENTAL OIL COfPANY (CTN0CG1 COMMERCF CITY COMRUSTION UNIT £U
GARY WESTERN COMPANY v GIL SON] TP FLOATING. ROOF STORAGE T A\|X I
MONTANA " '
NO NSFS SOURCES Hi THIS STATE
n
^ NORTH DAKOTA
NORTt-LAND OIL C REFINING CD. DICK INSON COMBUSTION UNIT I
FIXED RO^F STPRAGF TA"'K I
_ fixed nor.f stqr/ige_ t« i_
FIXED ROnr STORAGE TANK I
UTAH
WESTERN REFINING CC P PA NY WOODS CROSS " FLOATING ROOF STnp4GF TANK "CU
"PLATEAU INCORPORATED ROOSEVELT FCC-P EGE NERAT OR ~~ CU
WYOMING
NO N S°S SOURCES IN THIS STATE
-------
SECTION 7.
LITIGATION
Although there is no known current litigation in Region VIII, there
are two refineries which have actions pending which may result in liti-
gation, Farmers Union Central Exchange (CENEX) located in Laurel,
Montana was inspected.by EPA personnel cn Auguest 7, 1975. The
No. 3 boiler was found to ba out of compliance with visible emission
limitations and a Notice of Violation (NOV) was issued. It is not
known if the refinery contested the charge of non-compliance.
The Continental Oil Company (CONOCO) Refinery in Billirigs9 Montana
was "inspected by EPA personnel on August 6, 1975. A visible emission
observation 'was performed on the FCC regenerator which was found to
be out of compliance. It is not known if a NOV was issued for this
source or if the refinery is involved in litigation.
517
-------
SECTION 8. REFINERY DATA FORMS
In order to 'reduce the data from each of the refineries in the
Region into a common format, the codes on following pages
were used to produce data forms for each plant. Data from
these forms were then keypunched and entered into a refinery
data system which is maintained on a magnetic disc system.
The use of the codes is straightforward in all but three
case:-:
1) The "Priority" code is used to classify the entire plant
and-is based upon the highest priority compliance status
of any individual source in the plant. It does not
necessarily pertain to all sources within the plant.
P.) Data source codes may be applied to either emission data
oF comp'T lance "data" for "each source"," "Emission data "source""'
refers to the manner in which the emission data was
gathered such as by AP42 emission factor calculation*
source test or inspection. The compliance data source
refers to the.agency which performed the compliance
evaluation such as a state or local agency or a PES
project engineer.
3} Compliance status codes refer to compliance with emission:
regulations only. For example, the "N0S" code only tells
that the source is not in compliance with emission regula-
tions and a compliance schedule has been negotiated and agreed
upon. The code does nofimply that the plant is or is not
meeting the requirements of the schedule. This information
can on'l.y be shown in the "Remarks" area.
518
-------
Table 8-1: STANDARDS AND COPES
Card 1
Card 2
State Codes - APTD-1135
Litigation -1- No
2-Yes
AQCR - APTD-1135
Refinery Capacity - Given in 10^ BPD
Priority - 1 - Not in Compliance, Not on
a Schedule
2 - Compliance Status Unknown
3 - Not in Compliance, on a
Sc hed'ule
4 - In compliance
Source coass - See followi
pages
Operating Hours - hr/yr
NSPS - 1 - No
2 - Yes
Card 3
Pollutant
PAR - Particulates
S0X - Sulfur Oxides
C0 - Carbon Monoxide
HC - Hydrocarbons
N0X - Nitrogen Oxides
H6 - Hydrofluoric Acid-
H2S- Hydrogen Sulfide
S04 - Sulfuric Acid
(5P - Opacity
FUG - Fugitive Particulates
0DR - Odors
Data Sources
Control Equipment
Compliance Status
- PES
NEDS
CDS
STATE
CNTY - Local Agency
CITY - Local Agency
REF - Refiner
TEST - Source Test
APTD-1135s 999 = Unknown
I - In Compliance
NNS- Not in Compliance, No schedule
NOS - In compliance, on a schedule
CU - Unknown
NR - No Regulation
AP-42
EPA .
INSP -
Inspection
519
-------
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