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 Synth etic Minor Source.

Project Number: N10124-0025

The attached document is the Intent to Approve for the above-referenced project. The Intent to Approv e 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 cos ts 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 sho uld include the engineer's name as well as the DAQE

number as shown on the upper right-hand corner of t his letter. The project engineer for this action i s 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 Ea gle) has submitted an NOI to be reclassified as a

synthetic minor source for criteria pollutants. Th e project will result in the decommissioning of sev eral

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

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

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

PM 10 , PM 2.5 , NO

x , SO 2 and VOC emissions. Silver Eagle is located in Woo ds Cross, Davis County.

Davis County is a nonattainment area of the NAAQS f or PM 2.5 and a maintenance area for Ozone.

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

Emissions from this project result in the following emission changes, in tons per year: PM 10 (including

PM 2.5 ) -4.53, PM 2.5 -10.41, NO

x -52.66, SO

x -66.07, VOC -109.31 and CO 2 e + 20,747.5.

The resulting potential to emit totals, in tons per year, are as follows: PM 10 (including PM 2.5 ) = 14.47,

PM 2.5 = 8.59, NO

x = 72.44, SO

x = 2.03, CO = 85.04, VOC = 65.82, total HAPs = 11.8 1 and CO 2 e = 106,518.3.

The NOI for the above-referenced project has been e valuated and has been found to be consistent with t he

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

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

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

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

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

available for the public to review and provide comm ent. 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 refe rences used in this AO conform to those used in the

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

those rules. [R307-101]

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

Page 3

I.3 Modifications to the equipment or processes app roved 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 a pplicable rules, which are required to be kept by t he

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

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

specified in this AO or in other applicable state a nd 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, shu tdown, 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 equipmen t in a manner consistent with good air pollution

control practice for minimizing emissions. Determin ation 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, monitorin g results, opacity observations, review of

operating and maintenance procedures, and inspectio n of the source. All maintenance performed

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

I.6 The owner/operator shall comply with UAC R307-1 07. General Requirements: Breakdowns.

[R307-107]

I.7 The owner/operator shall comply with UAC R307-1 50 Series. Inventories, Testing and

Monitoring. [R307-150]

Section II: SPECIAL PROVISIONS

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

II.A.1 Refinery

Source Wide

II.A.2 BenSat Furnace

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

II.A.3 F

- 231: Crude Unit #1 Furnace

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

II.A.4 HT: Hydrotreater Unit

Fired with two furnaces, controlled with existing f lares

II.A.5 HT Charge Furnace

19.55 MMBtu/hr furnace with low-NO

x burners, fired on plant gas

II.A.6 HT Fractionator Furnace

27.6 MMBtu/hr furnace with low-NO

x burners, fired on plant gas

II.A.7 H

- 104: MDDW Heater

27 MMBtu/hr furnace with low-NO

x burners, fired on natural gas only

II.A.8 H

- 103: MDDW Reboiler Heater

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

Page 4

II.A.9 F

- 501: Vacuum Furnace

11 MMBtu/hr furnace, fired on plant gas and/or natu ral 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 valv es and excess plant gas

II.A.20 Refinery Flare

Flare for combusting gases from process relief valv es 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 roofDAQE-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 roofDAQE-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

- petr oleum 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 roofDAQE-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 w hen the installation of the new equipment has

been completed and is operational. The new equipme nt 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 corresponden ce to the Director, attn: Compliance

Section.

If installation has not been completed within 18 mo nths from the date of this AO, the Director shall be notified in writing on the status of the c onstruction and/or installation. At that time, the Director shall require documentation of the con tinuous 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 point s 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% opa city.

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 s ources (other than the flares) shall be conducted according to 40 CFR 60, Appendix A, Metho d 9 or as directed by the Director.

Visible fugitive dust emissions from haul-road traf fic and mobile equipment in operational areas shall not exceed 20% opacity at any point. V isible emission determinations shall use procedures similar to Method 9. The normal require ment 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 s hall 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 plan t fuel gas as a primary fuel in all plant fuel

burning equipment except as otherwise specified. F uel oil may be fired as a backup fuel only during periods of natural gas curtailment or to tes t 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 /o r plant fuel gas that has an H 2 S content no

higher than 0.10 grain/dscf (based on a 3-hour roll ing 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 eq uivalent. [R307-401]DAQE-IN101240025-13

Page 8

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

specified by NSPS and/or R307-327. Silver Eagle sh all 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 foll owing throughput value:

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

Throughput shall be determined by loading/unloading records and maintenance of an operations log. Compliance shall be calculated dai ly. [R307-401-8]

II.B.2 Conditions and Limitations

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

emissions shall not exceed the following rates:

Pollutant/Period Emission Limit Units

PM 10 Annual 14.47 tons/yr

SO 2 Annual 2.03 tons/yr

NO

x Annual 72.44 tons/yr

[R307-401]

II.B.2.b The following emissi on factors shall be used to calculate daily and ann ual emissions:

Pollutant/Source Emission Factors Units Reference

SO 2 Natural Gas Combustion 0.60 lbs/MMscf AO limit

Plant Fuel Gas Combustion (Note 2) (Note 1) lbs/MMscf Calculated

NO

x Natural Gas or Plant Fuel Gas

Combustion 140 lbs/MMscf AP-42

Natural Gas or Plant Fuel Gas

with Low NO

x burners 81 lbs/MMscf AP-42

PM 10 Natural Gas or Plant Fuel Gas

Combustion 5 lbs/MMscf AO limit

Note 1: Emission factor shall be calculated from t he H 2 S 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 pe rmit means either refinery generated fuel gas or a mixture of refinery generated plant fuel gas a nd 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 sta ck test report is approved by the Director, the

new emission factors shall be used to calculate emi ssions from that date forward. Stack tests exceeding the approved emission factors shall not b e considered a violation of this AO. [R307-
401]

II.B.2.c The SO 2 emission factors for plant fuel gas shall be determ ined as follows:

The H 2 S content of the plant fuel gas shall be measured, in parts per million by volume (ppmv), by a continuous emissions monitor located downstrea m of the refinery fuel gas drum. Daily plant fuel gas emission factors shall be calculated as follows using average hourly H 2 S content

data from the CEM:

(lb SO 2 / 10^6 scf gas) = (24 hr avg. ppmv H 2 S)/10^6 * (64 lb SO 2 / lb mole) / (385.65 scf / lb mole measured at 68 deg. F)

[R307-401]

II.B.2.d Compliance with the SO 2 , NO

x and PM 10 daily emissions limitations in Condition II.B.2.a s hall

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 combust ed 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 (MMsc f/24 hrs) / (2,000 lb/ton)

The gas stream, providing natural gas/plant fuel ga s 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 th e 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 determi ned on a rolling 12-month total. Based on the first day of each month, the previous month's d aily (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 SO 2 , NO

x , and PM 10 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, calib rate, maintain, and operate a continuous monitoring system

located downstream of the primary fuel mixing drum to determine compliance with the SO 2 emission limits and the H 2 S limits of NSPS subpart J. The owner/operator sha ll record the output of the system, for measuring the H 2 S concentration in the plant fuel gas. SO 2 emissions rates shall be calculated assuming 100% of the H 2 S in the plant fuel gas is combusted forming

SO 2 at a ratio of 34 lbs of H 2 S equals 64 lbs of SO 2 . The monitoring system shall comply with all applicable sections of R307-170 and 40 CFR 60, Appendix B, Specification 7 - H 2 S. 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 cont inu ously monitored with equipment that will

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

Page 10

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

transmitters and/or transducers for the meter measu rement parameters shall be performed at least once every 120 days. The response of each in dividual transmitter/transducer shall be checked against a standard to verify on overall acc uracy of the meter reading to within plus or minus two (2) percent of the full scale of the mete r. The accuracy of each

transmitter/transducer tested shall be calculated a s 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 s hall be considered to have passed the two (2) percent overall accuracy criterion. The specificat ion 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 distilla tion 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 t wo to five years for a period of approximately 15 days) for the SRU shall only be sc heduled during the period from April through October. The projected periods/forecasts f or the SRU (NASH) turnarounds shall be submitted to the Director by the end of the first c alendar quarter of each year planned and 30 days prior to the turnaround a notice shall be give n to the Director. Neither the emissions increase (above normal operations) experienced duri ng 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 Instruc tion/Standard shall be made available to the Executive Secretary upon request.

In the event the SRU efficiency drops and remains b elow 95%, the refinery shall isolate the problem within five days from discovery. A permane nt repair or modification shall be accomplished within 15 days from the day of discove ry. If the repair proves to be satisfactory, i.e., no repeat failure modes of the same type occu r for at least 30 days, the efficiency drop shall not be considered a violation. A separate fa ilure within the 30-day period shall constitute

a new event.

SRU efficiency shall be estimated and reported to t he 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, t he total H 2 S output from the SRU plant fuel gas (prior to mixing with natural gas) and the conc entration of sulfur in the inlet and outlet streams from the low pressure NASH unit shall be me asured. From these parameters the SRU efficiency shall be calculated. An alternate metho d may be used if approved by the Director.
[R307-401]

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

operating rate of the unit. The SRU throughput rat e during the test plus 10% becomes the monthly maximum allowable operating rate. Addition al testing at higher throughput rates will be required to establish a higher monthly maximum a llowable 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 supers ede the constraints established in the

emissions limitations sec tion of the AO. [R307

- 401]DAQE-IN101240025-13

Page 11

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

compliance test. A pretest conference shall be hel d if directed by the Director. The conference shall be held at least 30 days prior to the test an d 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 de vice shall not leak an d shall be

designed and operated to allow no more than an aver age of 15cc drainage per disconnect for five consecutive disconnects. All loading and vapo r lines shall be equipped with fittings which make a vapor tight connection and shall be closed p rior to disconnection to prevent release of VOC. In no case shall vapor emissions to the atmos phere exceed 0.64 lb/1000 gallons gasoline/ethanol transferred. An approved inspecti on program shall be in place prior to the compliance test. Necessary repairs to lines, joint s, etc., shall be completed as soon as practicable as specified in R307-328. All transpor t vessels loading gasoline/gasohol shall be equipped with compatible bottom load connections an d vapor recovery systems. [R307-401]

II.B.6 Emergency Equ ipment

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

periods when electric power from the public utiliti es is interrupted, or for regular maintenance of the generators. Records documenting generator u sage 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 s hall be used only for emergency and maintenance/testing purposes.

Emergency generators and firewater pumps hours of o peration for maintenance firing purposes shall not exceed 100 hours per rolling 12-month tot al 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 m onth. [R307

- 401]

Section III: APPLICABLE FEDERAL REQUIREMENTS

In addition to the requirements of this AO, all app licable provisions of the following federal program s have been found to apply to this installation. Thi s 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 Pet roleum Refineries NSPS (Part 60), Ja: Standards of Performance for P etroleum Refineries for Which Construction, Reconstruction, or Modification Commenced After May 14, 2007 NSPS (Part 60), K: Standards of Performance for Sto rage Vessels for Petroleum Liquids for Which
Construction, Reconstruction, or Modification Comme nce d After June 11, 1973, and Prior to May 19, 1978 NSPS (Part 60), Ka: Standards of Performance for St orage Vessels for Petroleum Liquids for Which
Construction, Reconstruction, or Modification Comme nced After May 18, 1978, and Prior to July 23, 1984

NSPS (Part 60), Kb: Standards of Performance for Volatil e Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Constru ction, Reconstruction, or Modification Commenced Af ter July 23, 1984 NSPS (Part 60), GGG: Standards of Perfor mance for Equipment Leaks of VOC in Petroleum Refin eries 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 V OC Emissions From Petrol eum Refinery Wastewater Systems NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal CombustionDAQE-IN101240025-13

Page 12

Engines MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pol lutants 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 (Par t 70) area source

PERMIT HISTORY

The final AO will be based on the following documen ts:

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 clas sification 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

CO 2 Carbon Dioxide

CO 2 e 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 Pollu tants

NOI Notice of Intent

NO

x Oxides of nitrogen

NSPS New Source Performance Standard

NSR New Source Review

PM 10 Particulate matter less than 10 microns in size

PM 2.5 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

SO 2 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 interchange able with DAQ)

VOC Volatile organic compounds