DAQE-IN101240025-13

September 12, 2013 

Jerry Lockie 

Silver Eagle Refining - Woods Cross Inc. 

2355 S 1100 W 

PO Box 870298 

Woods Cross, UT 84087-0298 

Dear Mr. Lockie: 

Re: Intent to Approve: Reclassification as a Synthetic Minor Source. 

 Project Number: N10124-0025 

The attached document is the Intent to Approve for the above-referenced project. The Intent to Approve 

is subject to public review. Any comments received shall be considered before an Approval Order is 

issued. The Division of Air Quality is authorized to charge a fee for reimbursement of the actual costs 

incurred in the issuance of an Approval Order. An invoice will follow upon issuance of the final 

Approval Order. 

Future correspondence on this Intent to Approve should include the engineer's name as well as the DAQE

number as shown on the upper right-hand corner of this letter. The project engineer for this action is John 

Jenks, who may be reached at (801) 536-4459. 

Sincerely, 

Martin D. Gray, Manager 

New Source Review Section 

MDG:JJ:kw 

cc: Davis County Health Department 

195 North 1950 West • Salt Lake City, UT 

Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 

Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 536-4414 

www.deq.utah.gov 

Printed on 100% recycled paper 

State of Utah 

GARY R. HERBERT 

Governor 

GREG BELL 

Lieutenant Governor

Department of 

Environmental Quality 

Amanda Smith 

Executive Director 

DIVISION OF AIR QUALITY 

Bryce C. Bird 

Director 
STATE OF UTAH 

Department of Environmental Quality 

Division of Air Quality 

INTENT TO APPROVE: Reclassification as a 

Synthetic Minor Source. 

Prepared by: John Jenks, Engineer 

Phone: (801) 536-4459 

Email: jjenks@utah.gov 

INTENT TO APPROVE NUMBER

DAQE-IN101240025-13 

Date: September 12, 2013 

Silver Eagle Refining - Woods Cross Inc. 

Petroleum Products Refining 

Source Contact: 

Blaine Zwahlen, Engineer 

Phone: (801) 298-3211 

Email: bzwahlen@silvereaglerefining.com 

Martin D. Gray, Manager 

New Source Review Section 
ABSTRACT 

Silver Eagle Refining - Woods Cross Inc. (Silver Eagle) has submitted an NOI to be reclassified as a 

synthetic minor source for criteria pollutants. The project will result in the decommissioning of several 

existing furnaces, reformer compressors and storage tanks; change the contents of other tanks; restore the 

internal floating roofs on two existing tanks; construct a new hydrotreater unit with two new furnaces and 

establish an average daily crude processing rate for the facility. The project will result in reduced overall 

PM10, PM2.5, NOx, SO2 and VOC emissions. Silver Eagle is located in Woods Cross, Davis County. 

Davis County is a nonattainment area of the NAAQS for PM2.5 and a maintenance area for Ozone. 

Following this project Silver Eagle will become minor under the provisions of the Title V program. 

Emissions from this project result in the following emission changes, in tons per year: PM10 (including 

PM2.5) -4.53, PM2.5 -10.41, NOx -52.66, SOx -66.07, VOC -109.31 and CO2e + 20,747.5. 

The resulting potential to emit totals, in tons per year, are as follows: PM10 (including PM2.5) = 14.47, 

PM2.5 = 8.59, NOx = 72.44, SOx = 2.03, CO = 85.04, VOC = 65.82, total HAPs = 11.81 and CO2e = 

106,518.3. 

The NOI for the above-referenced project has been evaluated and has been found to be consistent with the 

requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be 

constructed, installed, established, or modified prior to the issuance of an AO by the Director. 

A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the 

intent to approve will be published in the Salt Lake Tribune and Deseret News on September 16, 2013. 

During the public comment period the proposal and the evaluation of its impact on air quality will be 

available for the public to review and provide comment. If anyone so requests a public hearing within 15 

days of publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as 

close as practicable to the location of the source. Any comments received during the public comment 

period and the hearing will be evaluated. The proposed conditions of the AO may be changed as a result 

of the comments received.

Name of Permittee: 

Silver Eagle Refining - Woods Cross Inc. 

2355 S 1100 W 

PO Box 870298 

Woods Cross, UT 84087-0298 

Permitted Location: 

Petroleum Products Refining 

2355 So. 1100 West 

Woods Cross, UT 84087 

 UTM coordinates: 423,200 m Easting, 4,524,300 m Northing, UTM Zone 12 

 SIC code: 2911 (Petroleum Refining) 

Section I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the

UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to 

those rules. [R307-101] 

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] 
DAQE-IN101240025-13 

Page 3

I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions 

covered by this AO must be reviewed and approved. [R307-401-1] 

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the 

owner/operator, shall be made available to the Director or Director's representative upon request, 

and the records shall include the two-year period prior to the date of the request. Unless otherwise 

specified in this AO or in other applicable state and federal rules, records shall be kept for a 

minimum of five (5) years. [R307-415-6a] 

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall,

to the extent practicable, maintain and operate any equipment approved under this Approval Order 

including associated air pollution control equipment in a manner consistent with good air pollution 

control practice for minimizing emissions. Determination of whether acceptable operating and 

maintenance procedures are being used will be based on information available to the Director 

which may include, but is not limited to, monitoring results, opacity observations, review of 

operating and maintenance procedures, and inspection of the source. All maintenance performed 

on equipment authorized by this AO shall be recorded. [R307-401-4] 

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. 

[R307-107] 

I.7 The owner/operator shall comply with UAC R307-150 Series. Inventories, Testing and 

Monitoring. [R307-150] 

Section II: SPECIAL PROVISIONS 

II.A The approved installations shall consist of the following equipment: 

II.A.1 Refinery

Source Wide 

II.A.2 BenSat Furnace

12 MMBtu/hr furnace, fired on plant gas and/or natural gas 

II.A.3 F-231: Crude Unit #1 Furnace

30 MMBtu/hr furnace, fired on plant gas and/or natural gas 

II.A.4 HT: Hydrotreater Unit

Fired with two furnaces, controlled with existing flares 

II.A.5 HT Charge Furnace

19.55 MMBtu/hr furnace with low-NOx burners, fired on plant gas 

II.A.6 HT Fractionator Furnace

27.6 MMBtu/hr furnace with low-NOx burners, fired on plant gas 

II.A.7 H-104: MDDW Heater

27 MMBtu/hr furnace with low-NOx burners, fired on natural gas only 

II.A.8 H-103: MDDW Reboiler Heater

10 MMBtu/hr heater, fired on natural gas only 
DAQE-IN101240025-13 

Page 4

II.A.9 F-501: Vacuum Furnace

11 MMBtu/hr furnace, fired on plant gas and/or natural gas 

II.A.10 B-1: Boiler #1

23,000 lbs/hr steam furnace, fired on plant gas and/or natural gas 

II.A.11 B-2: Boiler #2

23,000 lbs/hr steam furnace, fired on plant gas and/or natural gas 

II.A.12 Distillate Dewaxing Unit (MDDW)

II.A.13 Vacuum Distillation Unit (VDU)

II.A.14 Cooling Towers

Two (2) cooling towers 

II.A.15 Sulfur Recovery Unit (NASH Unit)

II.A.16 Two Railcar Loading Terminals

North and South Loading Terminals 

II.A.17 Finished Products and Intermediates Loading Rack

Submerged Loading Normal Service 

II.A.18 Vapor Recovery Unit (VRU)

Vapor Recovery Unit on Gasoline Loading Rack 

II.A.19 North Flare

Flare for combusting gases from process relief valves and excess plant gas 

II.A.20 Refinery Flare

Flare for combusting gases from process relief valves and excess plant gas 

II.A.21 Isomerization Furnaces

Two (2) Isomerization Unit Process Furnaces 

II.A.22 HTR-50401

Isomerization Unit Hot Oil Heater (1.5 MMBtu/hr) 

II.A.23 HTR-50402

Isomerization Unit Stabilizer Heater (10 MMBtu/hr) 

II.A.24 Emergency Equipment

Two (2) diesel fired emergency firewater pumps: 460 hp & 300 hp 

One (1) diesel fired emergency generator: 369 hp 

II.A.25 Naphtha Railcar Loading System

II.A.26 Tank Farms Process Drains

II.A.27 Tank 00: Storage vessel - API Separator Wastewater

9,038 barrel storage vessel with fixed roof 

II.A.28 Tank 1: Storage vessel - API Separator Wastewater

61,668 barrel storage vessel with floating roof 
DAQE-IN101240025-13 

Page 5

II.A.29 Tank 2: Storage vessel - yellow wax crude

28,409 barrel storage vessel with floating roof 

II.A.30 Tank 3: Storage vessel - vacuum tower bottoms

9,916 barrel storage vessel with fixed roof 

II.A.31 Tank 9: Storage vessel - gas oil

4,979 barrel storage vessel with fixed roof 

II.A.32 Tank 10: Storage vessel - HT distillate

4,849 barrel storage vessel with fixed roof 

II.A.33 Tank 11: Storage vessel - gas oil

4,874 barrel storage vessel with fixed roof 

II.A.34 Tank 12: Storage vessel - gas oil

4,991 barrel storage vessel with fixed roof 

II.A.35 Tank 15: Storage vessel - HDS fractionator bottoms

30,598 barrel storage vessel with fixed roof 

II.A.36 Tank 16: Storage vessel - Atmos. Tower Bottoms

9,918 barrel storage vessel with fixed roof 

II.A.37 Tank 17: Storage vessel - petroleum liquids

9,738 barrel storage vessel with fixed roof 

II.A.38 Tank 18: Storage vessel - yellow wax crude

33,409 barrel storage vessel with floating roof 

II.A.39 Tank 19: Storage vessel - HT distillate

11,207 barrel storage vessel with floating roof 

II.A.40 Tank 20: Storage vessel - heavy vacuum gas oil

11,207 barrel storage vessel with fixed roof 

II.A.41 Tank 23: Storage vessel - petroleum liquids

33,391 barrel storage vessel with floating roof 

II.A.42 Tank 24: Storage vessel - yellow wax crude

33,391 barrel storage vessel with floating roof 

II.A.43 Tank 25: Storage vessel - HT naphtha

6,658 barrel storage vessel with fixed roof 

II.A.44 Tank 26: Storage vessel - petroleum liquids

6,463 barrel storage vessel with floating roof 

II.A.45 Tank 27: Storage vessel - petroleum liquids

10,979 barrel storage vessel with floating roof 

II.A.46 Tank 28: Storage vessel - petroleum liquids

10,990 barrel storage vessel with floating roof 

II.A.47 Tank 29: Storage vessel - petroleum liquids

9,800 barrel storage vessel with cone roof
DAQE-IN101240025-13 

Page 6

II.A.48 Tank 31: Storage vessel - diesel additive

200 barrel storage vessel with fixed roof 

II.A.49 Tank 41: Storage vessel - petroleum liquids

4,162 barrel storage vessel with floating roof 

II.A.50 Tank 42: Storage vessel - ethanol

5,260 barrel storage vessel with floating roof 

II.A.51 Tank 43: Storage vessel - ethanol

1,523 barrel storage vessel with floating roof 

II.A.52 Tank 47: Storage vessel - petroleum liquids

627 barrel storage vessel with fixed roof 

II.A.53 Tank 48: Storage vessel - petroleum liquids

627 barrel storage vessel with fixed roof 

II.A.54 Tank 61: Storage vessel - petroleum liquids

9,905 barrel storage vessel with fixed roof 

II.A.55 Tank 62: Storage vessel - recovered slop oil

246 barrel storage vessel with fixed roof 

II.A.56 Tank 81: Storage vessel - NASH

2,604 barrel storage vessel with fixed roof 

II.A.57 Tank 83: Storage vessel - caustic

808 barrel storage vessel with fixed roof 

II.A.58 Tank 84: Storage vessel - caustic

120 barrel storage vessel with fixed roof 

II.A.59 Tank 85: Storage vessel - caustic

271 barrel storage vessel with fixed roof 

II.A.60 Tank 86: Storage vessel - caustic

977 barrel storage vessel with fixed roof 

II.A.61 Tank 101: Storage vessel - petroleum liquids

33,634 barrel storage vessel with floating roof 

II.A.62 Tank 102: Storage vessel - naphtha

22,157 barrel storage vessel with floating roof 

II.A.63 Tank 103: Storage vessel - petroleum liquids

33,580 barrel storage vessel with floating roof 

II.A.64 Tank 104: Storage vessel - petroleum liquids

33,508 barrel storage vessel with floating roof 

II.A.65 Tank 105: Storage vessel - petroleum liquids

15,887 barrel storage vessel with floating roof 

II.A.66 Tank 106: Storage vessel - heavy naphtha

15,848 barrel storage vessel with floating roof
DAQE-IN101240025-13 

Page 7

II.B Requirements and Limitations 

II.B.1 The Refinery

II.B.1.a Silver Eagle shall notify the Director in writing when the installation of the new equipment has 

been completed and is operational. The new equipment includes the following: Hydrotreater 

unit with two new furnaces (19.55 MMBtu/hr and 27.6 MMBtu/hr). To ensure proper credit 

when notifying the Director, send your correspondence to the Director, attn: Compliance 

Section. 

If installation has not been completed within 18 months from the date of this AO, the Director 

shall be notified in writing on the status of the construction and/or installation. At that time, 

the Director shall require documentation of the continuous construction and/or installation of 

the operation and may revoke the AO. [R307-401-18]

II.B.1.b Visible emissions from the following emission points shall not exceed the following values:

1. Point or fugitive emissions associated with the installation or control facilities from 

 combustion sources shall not exceed 10% opacity. 

2. Diesel combustion shall not exceed 20% opacity. 

3. Fugitive emissions shall not exceed 15% opacity, except fugitive dust. 

4. Fugitive dust emissions shall not exceed 20% opacity. 

5. Flares shall produce no visible emissions except for periods not to exceed five minutes 

 during any two consecutive hours. 

6. All other points shall not exceed 20% opacity. 

Opacity observations of emissions from stationary sources (other than the flares) shall be 

conducted according to 40 CFR 60, Appendix A, Method 9 or as directed by the Director. 

Visible fugitive dust emissions from haul-road traffic and mobile equipment in operational 

areas shall not exceed 20% opacity at any point. Visible emission determinations shall use 

procedures similar to Method 9. The normal requirement for observations to be made at 15-

second intervals over a six-minute period, however, shall not apply. Visible emissions shall be 

measured at the densest point of the plume but at a point not less than 1/2 vehicle length behind 

the vehicle and not less than 1/2 the height of the vehicle. 

Opacity observations of emissions from the flares shall be conducted according to 40 CFR 60, 

Appendix A, Method 22. [R307-401] 

II.B.1.c The Silver Eagle shall use natural gas, and/or plant fuel gas as a primary fuel in all plant fuel 

burning equipment except as otherwise specified. Fuel oil may be fired as a backup fuel only 

during periods of natural gas curtailment or to test oil-burning capability of units. Testing may 

be done one hour per month. [R307-401] 

II.B.1.d The Silver Eagle shall use only natural gas, and /or plant fuel gas that has an H2S content no 

higher than 0.10 grain/dscf (based on a 3-hour rolling average) as a fuel for any fuel burning 

devices subject to 40 CFR 60 Subpart J. [R307-401]

II.B.1.e All fuel oil consumed shall be ultra-low sulfur diesel or better. Sulfur content shall be 

determined by ASTM Method D-4294-89, or approved equivalent. [R307-401] 
DAQE-IN101240025-13 

Page 8

II.B.1.f VOC products shall be stored only in tanks that have the appropriate emissions controls as 

specified by NSPS and/or R307-327. Silver Eagle shall maintain records to demonstrate the 

true vapor pressure of the products stored in each tank and the type of emission controls 

applied to each tank. [R307-401] 

II.B.1.g The Silver Eagle Refinery shall not exceed the following throughput value:

15,000 barrels per day (bpd) of crude on a 30-day rolling average. 

Throughput shall be determined by loading/unloading records and maintenance of an 

operations log. Compliance shall be calculated daily. [R307-401-8] 

II.B.2 Conditions and Limitations

II.B.2.a Total emissions to the atmosphere from all regulated emission points and all regulated fugitive 

emissions shall not exceed the following rates: 

Pollutant/Period Emission Limit Units

PM10

Annual 14.47 tons/yr 

SO2

Annual 2.03 tons/yr 

NOx

Annual 72.44 tons/yr 

[R307-401] 

II.B.2.b The following emission factors shall be used to calculate daily and annual emissions:

Pollutant/Source Emission Factors Units Reference

SO2

Natural Gas Combustion 0.60 lbs/MMscf AO limit 

Plant Fuel Gas Combustion 

(Note 2) (Note 1) lbs/MMscf Calculated 

NOx

Natural Gas or Plant Fuel Gas 

Combustion 140 lbs/MMscf AP-42 

Natural Gas or Plant Fuel Gas 

with Low NOx burners 81 lbs/MMscf AP-42 

PM10

Natural Gas or Plant Fuel Gas 

Combustion 5 lbs/MMscf AO limit 

Note 1: Emission factor shall be calculated from the H2S content of the plant fuel gas as shown 

in Condition II.B.2.c. 

Note 2: The term plant fuel gas as used in this permit means either refinery generated fuel gas 

or a mixture of refinery generated plant fuel gas and natural gas. 
DAQE-IN101240025-13 

Page 9

When stack testing is conducted, the emission factors shall be updated to correspond with 

the results of the latest stack test. When the stack test report is approved by the Director, the 

new emission factors shall be used to calculate emissions from that date forward. Stack tests 

exceeding the approved emission factors shall not be considered a violation of this AO. [R307-

401] 

II.B.2.c The SO2 emission factors for plant fuel gas shall be determined as follows:

The H2S content of the plant fuel gas shall be measured, in parts per million by volume (ppmv), 

by a continuous emissions monitor located downstream of the refinery fuel gas drum. Daily 

plant fuel gas emission factors shall be calculated as follows using average hourly H2S content 

data from the CEM: 

(lb SO2 / 10^6 scf gas) = (24 hr avg. ppmv H2S)/10^6 * (64 lb SO2 / lb mole) / (385.65 scf / lb 

mole measured at 68 deg. F) 

[R307-401] 

II.B.2.d Compliance with the SO2, NOx and PM10 daily emissions limitations in Condition II.B.2.a shall 

be determined by applying the appropriate emissions factors from Conditions II.B.2.b and 

II.B.2.c to the relevant quantities of fuel combusted in all furnaces, heaters, boilers and 

compressors as follows: 

For plant fuel gas the following equation shall be used: 

Emission Factor (lbs/MMscf) * Gas Consumption (MMscf/24 hrs) / (2,000 lb/ton) 

The gas stream, providing natural gas/plant fuel gas to all furnaces, heaters, boilers and 

compressors, shall be measured by meters monitoring the flow to each combustion device. 

Total annual emissions shall be calculated using the sum of all the individual meters. [R307-

401] 

II.B.2.e Compliance with the daily emissions limitations of Condition II.B.2.a shall be determined by 

adding the daily results of the natural gas, plant fuel gas, and fuel oil combustion. Results shall 

be tabulated on a daily basis. 

Compliance with annual limitations shall be determined on a rolling 12-month total. Based on 

the first day of each month, the previous month's daily (24-hour) emissions shall be summed 

for a monthly total. Annual emissions shall be the summation of the last 12 monthly totals. 

Results shall be tabulated monthly. 

The flares shall not be regulated for SO2, NOx, and PM10 emissions, nor shall they be included 

in the emissions limitations in Condition II.B.1.a. SRU turnaround emissions are not to be 

included in the emissions limitations of Condition II.B.2.a. [R307-401] 

II.B.2.f Silver Eagle shall install, calibrate, maintain, and operate a continuous monitoring system 

located downstream of the primary fuel mixing drum to determine compliance with the SO2

emission limits and the H2S limits of NSPS subpart J. The owner/operator shall record the 

output of the system, for measuring the H2S concentration in the plant fuel gas. SO2 emissions 

rates shall be calculated assuming 100% of the H2S in the plant fuel gas is combusted forming 

SO2 at a ratio of 34 lbs of H2S equals 64 lbs of SO2. The monitoring system shall comply with 

all applicable sections of R307-170 and 40 CFR 60, Appendix B, Specification 7 - H2S. 

Notification about RATA testing shall be submitted 45 days prior to testing. [R307-401] 

II.B.2.g Silver Eagle generated plant fuel gas shall be continuously monitored with equipment that will 

determine the quantity of plant fuel gas consumed. The meters outputs shall be located such 
DAQE-IN101240025-13 

Page 10

that an inspector/operator can safely read the output at any time. An accuracy check of the 

transmitters and/or transducers for the meter measurement parameters shall be performed at 

least once every 120 days. The response of each individual transmitter/transducer shall be 

checked against a standard to verify on overall accuracy of the meter reading to within plus or 

minus two (2) percent of the full scale of the meter. The accuracy of each 

transmitter/transducer tested shall be calculated as follows: 

ACC = 100 x [(Standard - Reading) / Full Scale ] 

If each transmitter/transducer has an accuracy (ACC) value within plus or minus one (1) 

percent of tranducer full scale, the meter system shall be considered to have passed the two (2) 

percent overall accuracy criterion. The specification for the measurement standard(s) and/or 

alternative methods of calculating overall accuracy shall be established by the company and 

shall be submitted to the Director for approval. [R307-401, 40 CFR 75] 

II.B.3 Vacuum Distillation Unit (VDU)

II.B.3.a All vacuum ejector exhaust from the vacuum distillation unit shall be incinerated in one of the 

process heaters. [R307-401] 

II.B.4 Sulfur Recovery Unit (SRU)

II.B.4.a The SRU shall be at least 95% effective in removing sulfur from the streams fed into the unit. 

Shut down for routine maintenance (expected every two to five years for a period of 

approximately 15 days) for the SRU shall only be scheduled during the period from April 

through October. The projected periods/forecasts for the SRU (NASH) turnarounds shall be 

submitted to the Director by the end of the first calendar quarter of each year planned and 30 

days prior to the turnaround a notice shall be given to the Director. Neither the emissions 

increase (above normal operations) experienced during the SRU routine turnarounds nor those 

from process flaring shall be included in the daily (24 HR) or annual compliance 

demonstrations. Copies of the SRU Operating Instruction/Standard shall be made available to 

the Executive Secretary upon request. 

In the event the SRU efficiency drops and remains below 95%, the refinery shall isolate the 

problem within five days from discovery. A permanent repair or modification shall be 

accomplished within 15 days from the day of discovery. If the repair proves to be satisfactory, 

i.e., no repeat failure modes of the same type occur for at least 30 days, the efficiency drop 

shall not be considered a violation. A separate failure within the 30-day period shall constitute 

a new event. 

SRU efficiency shall be estimated and reported to the Director a minimum of once per year via 

the following method: Over a minimum of three and a maximum of seven operating days or 

other period of time as approved by the Director, the total H2S output from the SRU plant fuel 

gas (prior to mixing with natural gas) and the concentration of sulfur in the inlet and outlet 

streams from the low pressure NASH unit shall be measured. From these parameters the SRU 

efficiency shall be calculated. An alternate method may be used if approved by the Director. 

[R307-401] 

II.B.4.b The SRU throughput rate during SRU testing will be used to determine the maximum monthly 

operating rate of the unit. The SRU throughput rate during the test plus 10% becomes the 

monthly maximum allowable operating rate. Additional testing at higher throughput rates will 

be required to establish a higher monthly maximum allowable operating rate if the existing 

monthly maximum allowable throughput rate is to be exceeded. The maximum monthly SRU 

operating rate so determined shall in no way supersede the constraints established in the 

emissions limitations section of the AO. [R307-401]
DAQE-IN101240025-13 

Page 11

II.B.4.c Silver Eagle shall notify the Director of test dates at least 30 days prior to a stack test or SRU 

compliance test. A pretest conference shall be held if directed by the Director. The conference 

shall be held at least 30 days prior to the test and shall be attended by the owner/operator, the 

tester, and the Director or representative. [R307-401] 

II.B.5 Vapor Recovery Unit (VRU)

II.B.5.a Vapor Recovery Unit on Loading Rack: The loading device shall not leak and shall be 

designed and operated to allow no more than an average of 15cc drainage per disconnect for 

five consecutive disconnects. All loading and vapor lines shall be equipped with fittings which 

make a vapor tight connection and shall be closed prior to disconnection to prevent release of 

VOC. In no case shall vapor emissions to the atmosphere exceed 0.64 lb/1000 gallons 

gasoline/ethanol transferred. An approved inspection program shall be in place prior to the 

compliance test. Necessary repairs to lines, joints, etc., shall be completed as soon as 

practicable as specified in R307-328. All transport vessels loading gasoline/gasohol shall be 

equipped with compatible bottom load connections and vapor recovery systems. [R307-401] 

II.B.6 Emergency Equipment

II.B.6.a All emergency generators shall be used for electricity producing operation only during the 

periods when electric power from the public utilities is interrupted, or for regular maintenance 

of the generators. Records documenting generator usage shall be kept in a log and they shall 

show the date the generator was used, the duration in hours of the generator usage, and the 

reason for each generator usage. Firewater pumps shall be used only for emergency and 

maintenance/testing purposes. 

Emergency generators and firewater pumps hours of operation for maintenance firing purposes 

shall not exceed 100 hours per rolling 12-month total for each. To determine compliance with 

a rolling 12-month total, based on the first day of each month a new 12-month total shall be 

calculated using data from the previous 12 months. Monthly calculations shall be made no 

later than 20 days after the end of each calendar month. [R307-401]

Section III: APPLICABLE FEDERAL REQUIREMENTS 

In addition to the requirements of this AO, all applicable provisions of the following federal programs 

have been found to apply to this installation. This AO in no way releases the owner or operator from any 

liability for compliance with all other applicable federal, state, and local regulations including UAC

R307. 

NSPS (Part 60), A: General Provisions

NSPS (Part 60), J: Standards of Performance for Petroleum Refineries

NSPS (Part 60), Ja: Standards of Performance for Petroleum Refineries for Which Construction, 

Reconstruction, or Modification Commenced After May 14, 2007

NSPS (Part 60), K: Standards of Performance for Storage Vessels for Petroleum Liquids for Which 

Construction, Reconstruction, or Modification Commenced After June 11, 1973, and Prior to May 19, 1978

NSPS (Part 60), Ka: Standards of Performance for Storage Vessels for Petroleum Liquids for Which 

Construction, Reconstruction, or Modification Commenced After May 18, 1978, and Prior to July 23, 1984

NSPS (Part 60), Kb: Standards of Performance for Volatile Organic Liquid Storage Vessels (Including 

Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After 

July 23, 1984

NSPS (Part 60), GGG: Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for 

which Construction, Reconstruction, or Modification Commenced After January 4, 1983, and on or Before 

November 7, 2006

NSPS (Part 60), QQQ: Standards of Performance for VOC Emissions From Petroleum Refinery Wastewater 

Systems

NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion
DAQE-IN101240025-13 

Page 12

Engines

MACT (Part 63), A: General Provisions

MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary 

Reciprocating Internal Combustion Engines

MACT (Part 63), BBBBBB: National Emission Standards for Hazardous Air Pollutants for Source Category: 

Gasoline Distribution Bulk Terminals, Bulk Plants, and Pipeline Facilities

Title V (Part 70) area source

PERMIT HISTORY 

The final AO will be based on the following documents: 

Supersedes AO DAQE-AN101240024-12 dated October 29, 2012

Is Derived From Source Submitted NOI dated April 1, 2013

ADMINISTRATIVE CODING 

The following information is for UDAQ internal classification use only: 

Davis County 

CDS A 

MACT (Part 63), Nonattainment or Maintenance Area, Title V (Part 70) area source, NSPS (Part 60), 
DAQE-IN101240025-13 

Page 13

ACRONYMS 

The following lists commonly used acronyms as they apply to this document: 

40 CFR Title 40 of the Code of Federal Regulations

AO Approval Order

BACT Best Available Control Technology

CAA Clean Air Act

CAAA Clean Air Act Amendments

CDS Classification Data System (used by EPA to classify sources by size/type)

CEM Continuous emissions monitor

CEMS Continuous emissions monitoring system

CFR Code of Federal Regulations

CMS Continuous monitoring system

CO Carbon monoxide

CO2 Carbon Dioxide

CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1

COM Continuous opacity monitor

DAQ Division of Air Quality (typically interchangeable with UDAQ)

DAQE This is a document tracking code for internal UDAQ use

EPA Environmental Protection Agency

FDCP Fugitive Dust Control Plan

GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i)

GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)

HAP or HAPs Hazardous air pollutant(s)

ITA Intent to Approve

LB/HR Pounds per hour

MACT Maximum Achievable Control Technology

MMBTU Million British Thermal Units

NAA Nonattainment Area

NAAQS National Ambient Air Quality Standards

NESHAP National Emission Standards for Hazardous Air Pollutants

NOI Notice of Intent

NOx Oxides of nitrogen

NSPS New Source Performance Standard

NSR New Source Review

PM10 Particulate matter less than 10 microns in size

PM2.5 Particulate matter less than 2.5 microns in size

PSD Prevention of Significant Deterioration

PTE Potential to Emit

R307 Rules Series 307

R307-401 Rules Series 307 - Section 401

SO2 Sulfur dioxide

Title IV Title IV of the Clean Air Act

Title V Title V of the Clean Air Act

TPY Tons per year

UAC Utah Administrative Code

UDAQ Utah Division of Air Quality (typically interchangeable with DAQ)

VOC Volatile organic compounds