# @

State ofUtah GARY R. HERBERT G(J1Iemor GREG BELL Lielllenant Governor


### January 12, 2010 Mike Astin 

### Department of Environmental Quality Amanda Smith Executive Director DIVISION OF AlR QUALITY Cheryl Heying

Director



### DAQE-AN0101230031-10

Holly Refining & 

### Marketing Company 393 S 800W Woods Cross, UT 840871435 Dear

### Mr. Astin: (



### . . 

### Re: Approval Order: Modifications to DAQE-ANOlO1230027-Q9 to Add Two Boilers Davis County; CDS A; MAcr (part 

### 63), Major HAP 

### source, NESHAP (part 

### 61), NSPS (Part 60), NSR, Nonattainment or Maintenance Area, 

### PMlo 

### SIP / Maint Plan: PSD, Title 

### Y (part 

### 70) Major source . . Project Number: N0101230031 The attached document is the Approval Order for the above-referenced project. Future correspondence. on this ApprOVal Order should include the engineer's name as well as the DAQE number as shown on the upper right-hand comer ofthis letter. The project engineer for this action is Carmon Harry, who may be reached at (801) 536-4232. Sincerely,

## /'\'V\~ (\A _ 

# f\'

. . M.

# CberylHeYi~,~~ck~ Utah Air Quality Board

# tiV~ MCH:CAH:dn
cc: Mike Owens Davis County Health Department

150 North 

### i 950 West· Salt Lake City, UT
. Mailing Address: P.O. Box 144820· Salt Lake Cit;y, UT 84114-4820 Telephone (801) 536-4000· Fax (801) 5364099·T.D.D. (801) 536-4414 wl1I1p.deq.uU!h..go'll

. Prin"'d on lOO\lb recycled paper

## STATE OFUTAH Department ofEnvironmental Quality Division ofAir Quality

APPROVAL ORDER: Modifications to

# DAQE-ANOI01230027~09

. to Af,1d Two Boilers
. \ \ 

### Prepared By: CamronHarry, Engineer Phone: 

### (801) 536-4232 Email: caharry@utah.gov



## APPROVAL ORDER NUMBER DAQE.A.N0101230031-10

.... Date: January 12, 2010



## Holly Refining & 

## Marketing Company Woods Cross Refinery Source Contact: 

## Mr. Bo Bothwell Phone: (801) 299·6619

# ~~~g~

Executive Secretary
. UtahAir Quality Board

## Abstract Holly Refin41g & 

### Marketing Company (Holly) Woods Cross Refinery is requesting to install two (2) new 75,000 pounds ofsteamlhour steamboilers, Boiler #9 and Boiler #10. Holly is 

### inthe process ofinstalling and operatingnew sulfur

### removal units for on and offroadfuels in order to comply with federal regulations. These sulfur removal units have been built and as a result 

### the refinery's steam demand has increased. Wbile the possibility ofdebottlenecking exists with the increased steam capacity, the source wide emissions are capped bythe UtahPMIO 

### SlP. One ofthe additional boilers isneeded to meet current steamrequirements and the secondboiler is needed to provide redundancy when aboileris shut down for maintenance Or 

### during a processupset. This modification will.result, intOns peryear, in the following PTE increases: PMIO 

### +7.82, NOx 

### + 15.65, S02 

### +20.69, CO + 28.94. While this is an increase overthe values from Holly's existing AO, the new totals are less than 

### the existing

### limitations from section lX.H.2.fofthe PM10 

### SIP.
. Holly is located in

### West Bountiful, Davis County. Davis County is a maintenance area for ozone. Holly is located 4 miles north ofSaltLake County and is defined as a con1n'buting source for the Salt Lake County PM10 

### nonattainment area:While this source is located in

### an area currently designated as nonattainment for PM2.5, the preparation ofthis document 

### was completedprior to 

### the effective date of that designation. The Projecthas been evaluated and found to 

### be oonsistent with the requirements ofthe Utah Administrative Code Rule 307 (UAC R307). A public commentperiod was held 

### in accordance with UAC R307-401·7 andno comments were received.' This air quality AO authorizes the project with the following conditions, and failure to 

### comply with any oftbe conditions may constitute a violation ofthis approval order. This AO is 

### issuedto, 

### and applies to the following: Name ofPermittee: PermittedLocation: 

### HollyRefining& 

### Marketing Company Woods Cross Refinery 393 S 800W 393 South 800 West Woods Cross, UT 840811435 Woods Cross, UT 84087-143.5
UTM coordinates: 

### 424,000 m Basting, 4,526,277'mNorthing SIC code: 

### 2911 (pe1r9Ieum Refining) 

### Section I: GENERAL PROVISIONS I,1 ;All definitions, terms, abbreviations, and**ref~ences** 

### used in

### this AO conformto 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 notbe exceeded without prior approval. [R307-40 1] Mqdifications to the equipment orprocesses approved bythis AO that could affect the**~tnissions** 

### coveredby this AO mustbereviewed and approved. [R307-401-1] I.3DAQE-ANOI01230031-10 Page 3	 . 

### I.4 All records referenced in this AO orin other applicable rules, which arerequired to be kept by the owner/operator, shall be made available to the Executive Secretary or Executive Secretary's representative upon request, and the records shall include the two-year peribd priorto the date of the request. Unless otherwise specified 

### in this AQ or

### in other applicable state and federal rul,es, records shall be kept for a minimum oHive (5) years. [R307-401]


### I.5 At 

### all times, including periods ofstartup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, 

### in a manner consistent with good air pollution control practice for minimizing emissions. Determination ofwhether acceptable. operating and niaintenance procedures are being used will be based on information available to the Executive Secretary which may, include, but is not limited to, monitoring results, opacity observations, review of operating Ipld maintenance procedures, and inspection ofthe source. All maintenance performed on equipment authorized by this AO shallberecorded. [R307-401-4] 

### I.6 The o.:.vner/operatorshall comply with R307-150 Series. Inventories,

### resti~g and Monitoring. [R307-150]
. 

### I.7 The owner/operator shall comply with 

### VAC R307-107. General Requirements: Unavoidable Breakdowns. [R301-107] , . 

### 1.8 Holly Refining and Marketing shall continue to install the vacuumtower, associated heaters, upgrade the FCCU and solvent deasphalting unit, 

### make the required changes in storage tanks, install boilers 

### #9 and #10, and operate its facility in accordance with the tenns and conditions of this AO that were written pursuant to Holly's notice ofintent submitted to the Division of

### Air Quality on October 5, 2006. Holly shall notify theExecutive Secretary in writing when the installation ofthe equipment has been completed and the equipment is operational, as an initial compliance inspection is required. To insure proper credit when notifying the Executive Secretary, send your correspondence to the Executive Secretary, attn: Compliance Section. 

### Ifconstruction andlor installation have not been completed within eighteen months from the date ofthis AO, the Executive Secretary shall be notified in writj,ng on the status ofthe construction andlor installation. At that time, the Executive Secretary shall require documentation ofthe continuous construction and/or installation ofthe operation and may revoke the AO 

### in accordance with R307-401-18. [R307-401]


### Section II: SPECIAL PROVISIONS 

# n.A The approved installations shall consist ofthe following equipment: II.A.l Holly Refinery Perm,itted Source/ DAQE-ANOI0123003I-iO Page 4 

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IIA.18' (4·1) 4H1: FCC feed heater 68.4 MMBtulhrprocess furnace, fired on plant gas, restricted to 39.9 MMBtuIhr, equipped with Iow-NOx burners '. 

### (4.4a) 4K1A: KVG compressor west 660 hp internal combustion engine, fired on natural gas 

### (4·4b) 4K1B: KVG compressor east 660 hp internal combustion engine, fIred onnatural gas 

### (6·1) 6HI: Reformer charge and reheater furnace 54.7MMBtuIbrprocess furnace, fired on plant gas 

### (6-2) 6H3: Reformer reheat furnace 37.7 MMBtulbrprocess furnace, fIred on plant gas 

### (6-3) 

## 6H2: Prefrllctlonator reboilerheater 12.0 MMBtulhrprocess furnace, fIred on plant gas 

### (6·4a) 6K1 SVG compressor east 325 hp internal combustion engine, fired on'natural gas 

### (6·4b) 610: SVG compressor west 325 hp internal combustion engine, PIed on natural gas 

### (7-1) 7H3: HF alkylation depropanizer reboiler 33.3 MMBtuIhr process furnace, fired OJ;! plant gas 

### (7-2) 7H1: HF alkylation regenerationfurnace 4.4 

### M:MBtuJhr process furnace, fIred on plant gas 

### (8-1) 8H1: Crude furnace 99.0 MMBtu/brprocess furnace, fIred on plant gas, equipped with NGULNB 

### (9-1) 9Hl: DIIT reactor charge heater 8.1 MMBtulhr process furnace, fIred on plant gas 

### (9-2) 9H2: DIIT stripperreboiler 4.1 MMBtulbr process furnace, fIred on plant gas 

### (10-2) 10Rl: Asphalt mix heater 13.2 MMBtulbrprocess furnace, fIred on plant gas 

### (11·1) I1Hl: SRGP depentanizer reboiler 24.2 MMBtulhrprocess furnace, fired on plant gas 

### (11·2) 11Kl: Clark compressor 600 hp internal combustion engine, fired on natural gas 

### (12-1) 12H1: NHDS reactor charge furnace 50.2MMBtu/brprocess furnace, flIed on plant gas, equipped with :NGULNB

# ®
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ll.A.34 II.A.35 (13-1) 13H1: Isomerization reactor feed furnace 

### 6.5 11MBtu/hr process furnace, fIred on plant gas (17-1) SRU

- tailgas incinerator 

### For SRU

### under 20 LTPD (19-1) DHTreactor charge heater 

### 18.llVIMBtulbrProcesss Furnace, fired on plant gas, equipped with 

### low-NOx 

### burners 20H1: Reactor charge heater 

### 14.9lVIMBtulhrprocess furnace, fired on plant gas, equipped with 

### ULNB 20H2: Fractionator chargeheater, 

### 47.1 :MMBtulbrprocess furnace, fIred on plant gas, equipped with 

### ULNB (45-1) 45H1: Asphalt 

### mix and storage furnace , 

### 15.3 MMBtu/hr

### process furnace, fired on plant gas, equipped with 

### low-NOx 

### burners (68-2) 68H2: 

### North 

### in-tank asphaltheater 

### 0.8- MMBtulbr tank**he~ter,** 

### fIred with 

### natural gas (68·3) 68H3: South 

### in-tank asphalt heater, 

### 0.8 MMBtu/hr tank heater, fired with natural gas (51-4) Boiler #4 

### 35.6 MMBtulhr boiler. 

### fired on plant 

### gas (51-5) Boiler 

### #5 70.0 MMBtufhr boiler, fired on plant gas**(51~6)** 

### CO boilerfFCC scrubber 

### 60.0 MlYlBtu/hrboiler, fired on plant gas (51-7) FCC 34" CO boiler bypass 

### 34" Stack (51-8) Boiler 

### #8 92.7 MJ:v1Btulhr boiler" fired on plant gas, equipped with 

### low-NOx 

### burner (51-9) Boiler#9 

### 89.3 MMBtulhrboiler, fired on plant gas using SCR (51-10) Boiler#10 

### 89.3 MNfBtu/hrboiler, fired on plant gas using $CR (56) Watewater Treatment Plant (66-1) ProceSsflare south FlareDAQE-AN0101230031-10 Page 6 ll.A.36
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### (66.2) Process flare north Flare 

### (68-1) Propane piUlare Flare 

### Tank 23: Storage'vessel •petroleum liquids 14,600Bbl capacity storagetank with a fixedroof

, 

### Tank 35: Storage vesSel

- petroleumliquids 105,000Bbl capacity storage tank with a ftxed roof 

### Tank71: Storage vessel- petroleum liquids 67,155 Bbl capacity storage tank with'internal floatingro9f, primary anI! secondary seals 

### Tank

# 72: Storage vessel- petroleumliquids 124,388 bbl storage vessel 

### with floating roof, primary and secondary seals 

### Tank 79 10,000 Bbl capacity storage tank with a fixed roof 

### Tank 167 1,300,000 gallon sbur water storage

### ,tank Tank 323: Storage vessel-**petrole~** 

### liquids , 14,686 bbl capacity storage tank with internal floating roof, 'and primary seal 

### Storage 

### tanks Three 14,000 Bbl NaSHtanks (two currently installed) Two 7,100 Bbl caustic tanks (one currently installed) One 80,000 Bbl 

### fuel oil tank (not yet installed) One50,000 Bbl cuttertank (riot yet installed) 

### Emergency equipment L Diesel powered water well No.3 2. Caterpillar diesel fire pump No.1 3. CaterpiJ.lar diesel fire pump No.2' 4, Detroit Diesel fire pump 5. Diesel powered plant airbackup compressors (3) 6. Diesel powered standby generator, BoilerHouse 7. Dieselpowered standby generator, Central Control RooJ,n 

### Three amine units Two new units 

### Fluid catalytic cracking unit FCC includes 02 skid, item#4-97-0010 

### DHT Distillate hydro-desulfurization treatment unitDAQE-AN0101230031-10 Page? II.A.50 II.A.51 ,
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### Cooling tower #7 

### Gas oil hydrocracking unit Includes reactor charge heater and fractionator charge heater 

### Vacuum tower and vacuum furnace heJlter 15.2 MMBtulhr using ultra low-NOlt burners 

### Hot oil heater 99 MMBtu/hr using ultra low-NOlt burners 

### Asphalt 

### tankheaters two new in-tank heaters sized at 0.8 

### MM:J3tu1br each 

### SRUrrGI (2) Two new Claus sulfur recovery units withtail gas recovery, each sized at 50 long tons of sulfur per day
. 

### Sour water strippers (2) One existing unit (#18), and one new unit (#22) with ammonia stripper 

### NaSH 

### sour gas treatmentunit Sized at 50 long tons ofsulfur per day 

### Hydrogen plant Two hydrogen reforn;ter feed furnaces, each sized at 123.1 MMBtu/hr using ultra low-NOlt burners " 

### Crudeheater 35MMBtu/hr using ultra low-NOlt burners 

### ETF portable diesel generator 135 kW diesel-fired generator 

### SOz Emissions Cap Sources S02. Emissions Cap Sources: includes (4-4b) 4K1B: KVO compressor east, (8-1) 8Rl: Crude furnace, (10-2) 10Rl: Asphalt mix heater, 20H2: Fractionator charge heater, ETFportable diesel generator, (4-4a) 4K1A: KVGcompressor west,(51-8)Boiler#8, Hydrogen plant, (6­ 1) 6H1: Reformer charge and reheaterfurnace, (7-2) 7HL HF alkylation regeneration' furnace, (51-4) Boiler#4, (68-2) 68H2: North in-tank asphalt heater, (51-9) Boiler#9, (6-4a) 6Kl SVG compressor east, (7-1) 7H3: HF alkylation depropanizerreboiler, (9-1) 9Hl: DHT reactor charge heater, 20H1: Reactor charge heater, (6-2) 6H3: Reformer reheat furnace, (45­ 1) 45HL Asphalt mix and storage furnace, (19:1) DIIT reactor charge heater, (4-1) 4Rl: FCC feed heater. (6-3) 6H2: Prefi:actionator reboiler heater,' (13-1) 13H1: Isomerization
. reactor feed furnace. Vacuumtower and vacuumfurnace heater, Asphalt tank heaters, (12-1) 12R1: NHDS reactor charge furnace, (51·5) Boiler#5, Hot oil heater, (9-2) 9H2: DHT stripperreboiler, (11-1) I1Hl: 

### SROP depentanizerreboiler, (68-3) 68H3: South in-tank asphalt heater. (6-4b) 6K2: ;3VO compressor west, (51-10) Boiler #10DAQE-AN0101230031-10 Page 8 II.A.62 NO" Emissions Cap Sources NOx Emissions Cap Sources: includes (4-4b) 4KIB: KVG compressor east, (8-1) 8H1: Crude furnace. (10-2) 10H1: Asphalt mixheater. 20H2: Fractionatorcharge heater, ETFportable diesel generator, (4-4a) 4K1A: KVG compressor west, (51-8) Boiler#8, Hydrogen plant, (6­ 1) 6H1: Reformer charge and reheater furnace, (7-2) ?HI: HF alkylation regeneration fwnace,**(~1-4)** Boiler

### #4, (68-2) 68H2: Northin-tank asphalt heater. (51-9) Boiler#9, (6-4a) 6K1 SVG compressor east, (7-1) 7H3: HF alkylation depropanizer reboiler. (9-1) 9H1: DHr reactor charge heater. (17-1) SRU

- tailgas incinerator, 20HI: Reactor charge heater, S02 Emissions Cap Sources, (6-2) 6H3: Reformerreheat furnace, (45-1) 45H1: Asphalt mix and storage furnace, (19-1) DHTreactor charge heater, SRUITGI (2), (4-1) 4Hl: FCC feed heater, (6-3) 6H2: Prefractionator reboiler heater, (13-1) 13H1: Isomerization reactor feed furnace, (51-7) FCC 34" CO boiler bypass, Vacuum tower and vacuum furnace heater, Asphalttankheaters, (12-1) 12Hl: NHDS reactor charge furnace. (51-5) Boiler#5, Hot oil heater, (9-2) 9H2: DHT stripper reboUer, (ll-l) llHl: SRGP depentanizerreboiler, (51-6) CO boilerlFCC scrubber, (68-3) 68H3: Southin-tank asphalt heater, (6-4b) 6K2: SVG compressor west, (51-10) Boiler#10
. II.A.63 PMlo Emissions Cap Sources PM10 Emissions Cap Sources: includes (8-1) 8Rl: Crude furnace. (10-2) lOH1: Asphalt 

### mix heater, 20H2: Fractionil-tor charge heater. 

### BTF portable diesel generator, (51-8) Boiler #8, Hydrogen plant, (6-1) 6H1: Reformer charge and reheaterfurnace, (7-2) 7H1: HF alkylation regeneration'furnace, (51-4) Boiler

### #4, (68-2) 68H2: North in-tank asphalt heater, (51-9) , Boiler #9. (7-1) 7H3: HF alkylation depropanizer reboiler, (9-1) 9H1: DHTreactor charge heater. (1771) SRU

- tailgas incinerator, 

### ZOH1: Reactor charge heater, 

### (6-Z) 6H3: Reformer reheatfurnace, (45-1) 45Hl: 'Asphalt 

### mix and storage furnace, (19-1) DHT reactor charge heater, SRUrrGI (2), (4-1) 4H1: FCC feed heater, (6-3) 

### 6HZ: Prefractionatorreboiler heater. , ! (13-1) 13H1: Isomerization reactor feed furnace, Vacuup:1 tower and vacuum furnace heater, Asphalt tank heaters, (12-1) 12H1: NHDS reactor chargefurnace, (51-5) Boiler#5, Hot oil heater, (9-2) 9H2: DHT stripper reboiler, (11-1) 11H1: SRGP depentanizer reboiler, (51-6) CO boilerlFCC scrubber, (68-3) 68H3: South in-tank asphalt heater, (51-10) Boiler#10 

# n.B Requirements and Limitations n.B.1 Conditions onPermitted Source n.B.l.a Stacktesting to detennine compliance shall be performed in accordance·with the requirements ofSection IX.H.loa ofthe PMIQ SIP. The source shall be tested if directed by the Executive Secretary.,
. The (51-6) CO BoilerlFCC Scrubber shall be tested for PMIQ compliance at least once every five years. [R307-150] n.B.lob The emissions ofNO" from heaters 8H1 and 12H1 shall not exceed 0.10 Ib/mmBtu on a 3­ hour average basis each. Compliance shall be determined by stack test to be performed every five (5) years.

. The emissions ofNOx from boilers #9 and #10 shall not exceed 0.020 Ib/mmBtu on a 3-hour

average basis each. Compliance shall be determined by stacktest to be performed every five (5) years,DAQE-AN010123003i-10 Page 9 ' Except as specified below, emissions ofNOx shall be determined through use of40 

### CPR 60, Appendix A. Method7. 7A, 7B, 7C, ID, 7E, or other testing methods approved by the Executive Secretary. Emissions ofNOx and 

### S02 from the FCCU**~hall** be determined through use of it 

### CEM. The monitoring system shall comply with all applicable sections ofR307-170-1, and 40 

### CFR 60.**App~ndix** B, Specifications 2 (NOJ and 3 (02), [R307-401, R307-170] II.B.l.c The applicant shall provide a notification ofany performance test date at least 30 days prior to the test A pretest conference shall 

### be held ifdirected by theExecutive Secretary. It shall be held at least 30 days prior to the test between the qwner/operator. the tester, and the Executive Secretary. The emission point shall 

### be designed to conform to the l-equirements of40 

### CPR 60, Appendix A, Method 1, and ofthe Occupational Safety and Health Administration (OSHA) or Mine Safety and HealthAdministration (MSHA). A sample location shall be chosen as outlined 

### in 40 

### CPR 60 Appendix A. Method 

### 1. The volumetric flow rate shallbe determined by 40 CPR 60 Appendix 

### A,Method2. To determine mass emission rates, the pollutant concentration as determinedOy the appropriate methods above shall be multiplied bythe volumetric flow rate**an~** 'any necessary conversion factors determined 

### by the Executive Secretary to give the results 

### in the**·~pecifi.ed** units ofthe emission limitation. For an existing sourcelemissionpQint. the production rate during fl1l compliancetesting shall be no less than 90% ofthe maximumproduction achieved 

### in the previous three years. [R307­ 165]
. " 

### IT.B.l.d Visible emissions shall not exceed the following specifications: 

### All scrubbers: 15% opacity All baghouses: 10% opacity' All combustion sources without controls: 10% opacity FCCUnit/(51-6): 20% opacity (8-1) 

### 8Rl Crude Furnace: 20% opacity Flares

- 20% opacity
. All fugitive emissionpoints

- 20% opacity Opacity observations ofemissions from stationary sources shall be conducted in accordance' with 40 CPR 60, Appendix. A, Method 9. [R307-401] 

### IT.B.1.e The amine plants shall reduce theHiS content oftherefinery fuel gas to 0.10 grainldscf (160 ppm) or less. The owner/operator has installed and maintains a continuous monitoring system for monitoring the 

### H2S content ofthe refinery fuel gas and a continuous recorder to record the H 2S 

### in the refinery fuel gas. The monitoring system shall comply with all applicable sections ofR307-170-1, and 40 CPR 60, Appendix 

### B. Specification 7. [R307-40l] n.B.l.f Except as outlined in conditions n.B.1.g andn.B.1.h, the total hours of operation for testing and maintenance purposes for 

### all emergency diesel-powered equipment shall not exceed 300 hours per 12-monthperiod, without priQr approval in accordance withR307-401. Compliance with the annual limitation shall be determined.on a rolling 12-month total. By**th~** last day**o~** each month a new l1-moritb total shall be calculatedusing theprevious 12months. Records

### DAQE-ANOlOI230031-10 Page 10 ofthe hours ofoperation shall be kept for all.periods

### ~hen the plant is in operation. Records ofthe hours ofoperation shall be made available to the Executive Secretary or the Executive

, Secretary's representative upon request, and shall include a period oftwo years encling with the

date ofthe request The total hours ofoperation may be determined by 

### an engine hour totalizer installed on each engine, but a separate record ofnon-emergency hours 

### shall be kept on a 

### weekly basis. Emissions from this equipment shall not be included under the emissions cap. [R307-401] Il.B.l.g Except for use in emergency generators, fuel oil shall not be burned in any existing

, combustion device at the refinery except during periods ofnatural gas curtailment. Emergency generators shall be used for electricity producing operation only during the**perio~s** 

### when electric power from the public utilities is intemlpted, orforregular maintenance ofthe generators. ,Records documenting generator usage shall be kept in a log and they shall show thedate the generator was used, the duration in hours ofthe generator usage, and the reason for each generatorusage. Torch oil may be burned in the FCC(]regenerator to assist in starting, restarting, maintaining hot standby, or maintaining regenerator heat balance. Small (<100 HP) 

### portable fuel oil-powered equipment is exempt from the requirements ofthis AO and related emissions

# are not to be used for purposes ofdeteImining compliance. [R307­ 401] II.B.l.h I 

### The 

### ETF portable diesel generator shall not be operated more than 

### 1,300 hours per rolling 12­ month period without prior approval in accordance with R307-401. Thetotal hours of operation shall be 

### determined by

### ,an engine hour totalizer or by supervisor monitoring and maintaining ofan operationslog. [R307-40lJ Il.B.l.i The throughput ofthe catalytic cracking unit shall not exceed 3,250,000 balTels per rolling 12­ month period. Compliance with the annual throughput limit shall be measured with a throughput**~low** 

### meter. [R307-401J !I.B.l.j**Compli~ce** 

### with fueannuallirnitations shall be deterririned on a rolling 12-month total except where specifically exempted or otherwise provided for. By the last day ofeachmonth, anew 12-month total shall ,be calcula.ted using the previous 12 months. Records shall be keptfor a period offive years. [R307-40J.] II.B.2 Conditions on the SRU/Tail gas incinerators (3 units) 

### II.B.'2.a Copies ofthe SRU Operating Instruction/Standard shall be 

### made available to the Executive Secretary upon request. [R307-401] !I.B.2.b Holly shall utilize monitors to measure volumetric flow rates from the Unit 17 SRU stack. The flow measurement shall be in accordance w,ith the requirements of40 CPR 52, Appendix E; 40 CPR 60Appendix B; or 40 CFR 75, Appendix A. 

### [R307-40 1] II.B.2.c The three SRUs shall each achieve 95% reco)'ery efficiency for all 

### periods ofoperation except during periods ofstartup, shutdown ormalfunction ofthe SRU 

### [R307-40IJ

### DAQE-ANOI01230031-10 Page 11 n.B.2.d The Unit 17 SRUITail gas incinerator shall be equipped with 

### aCEMS to measure S02 emissions. The95% recovery efficiency shall be determined on a daily basis; however compliance shall be determined on a 30-day rolling average basis by measuring the flow rate and concentration ofhydrogen sulfide (H2S) in 

### the feed streams going to the Unit 17 SRU and by measuring the S02 

### emissions with the CEMS at the**~RU** 

### incinerator. The flow rate shall be determined continuously; the H2 S concentration**~hall** 

### be determined quarterly for the first four quarters and at least semiannually thereafter. The flow rate and the H

### 2 S concentration values shall be used to determine the daily feed rate.· The 95% recovery efficiency for the new SRVs shall be determined on a daily basis; however compliance shall be determined as 

### outlined in**Se~tion** 

### IX.H.l.i ofthe PM\o SIP. [R307-401] n.B.2.e 

## .An sulfur pit emissions shall be routed to 

### an SRU**inc~eJ;:ator.** 

### [R307-401] 1I.B.2,f If 

### sulfur input to the Unit 17 

### SRU exceoos 20 long tons per day, NSPS Subparts A and J 

### shall apply. (40 CPR 60 Subpart J]'

. 

### n.B.2.g The refinery may exercise an 

### option to trade allowed annual SRU S02 

### emissions for cap sources' S02 

### emissions in the event the Unit 17 SRU is operating at better than 

### 95% efficiency. This option shall not 

### be made available until at least one year ofdata (12 efficiency determinations), as 

### described below, has been collected and a trade-offrequest is submitted to and approved by the Executive Secretary. The (Unit 17 SRU) 24-hour minimum .operating efficiency shall have been demonstrated to be no less 

### than 95%. When the SRU efficiency, as determined below, is greater than 

### 95%, adjustments tothe annual S02 

### emission limit fOJ; 'cap sources (see Special Provisions ILA.61(S02), JI.A.62 (NOJ, 

### and 1I.A.63 (pM 10) 

### for**~e** 

### definitions ofcap sources] may be 

### made by the following procedure: An adjusted alUlUal cap emission limit is the annual cap sources' emission limit adjusted upward. This adjustment is derived from S02 emission decreases resulting from a 

### better than 95% 

### efficient SRU operation. The adjusted

# annual cap emissi.9n limit shall only be used for compliance demonstration purposes. The combined annual total cap sources' and 

### SRU S02limit 

### used for attainment and maintenance demonstration shall not be increased. Daily compliance limits shall not be adjusted. [R307-401)



## . . n.B.3 Conditions on**SO~** 

### emissions sources 

### n.B.3.a The emission ofS02 

### into the atmosphere [excluding the (51-6) CO BoilerlFCC Scrubber, emissi.ons from**flar~** 

### and during SRU down times} shall not exceed 954 tons/year. Emissions of S02 shall be limited as follows: Emission Points EInissions (TPD) TotalEmissions (tons/yr)' 

### .(17-1) SRU Tail Gas Incinerator 1.60 582 

### SRU Tail Gas 

### Incinerator#1 0.25 

### 90 SRU Tail Gas Incinerator #2 0.25 

### 90 Emission Cap sources 0.53 

### 192

### DAQE-AN0101230031-10 Page 12 Tons Per Day (TPD) 

### =Daily 24-hol,U" total. Daily means an interval oHimebetween two con'secutive midnights.

. For all above listed emission 

### points 

### a CEM shall be used to determine compliance as oulined

in 

### II.B.3.d. [R307-401] n.B.3.b Prior to the installation ofthe FCC Scrubber butnot**aft~r** 

### December 31, 

## 20 12, the emissions of S02 into the atmosphere from the (51-6) CO Boiler shall not exceed the following: 3.147 TPD or 1148.83 tons/year
. Upon installation ofthe FCC Scrubber but no latter than December 31, 2012, the emissions Qf S02 into the atmosphere from die (5106) CO BoilerlFCC Scrubber shall not exceed the following: 1.93**TP~** 

### or 706 tons/year. Tons Per Day (TPD) = 

### Daily 24-hour total. Daily means an interval 

### oftimebetween two consecutive midnights. For emission point (51-6) stack testing shall beperformed as outlined in condition n.B.l.a
.. [R307-401] n.B.3.c The follm.ying sources shall not be regulated for S02 emissions, nor shall they be included in the emission limitation totals herein: (66-1) Process Flare South (66-2) Process Flare North (68-1) Propane Pit Flare Emergency Equipment [R307-401] n.B.3.d S02 

### emissions for the emissions cap sources shall be determined'by applying the following emission factors or emission factors determined from the most currentperformance testingto the relevant quantities offuel burned. S02 emission factors for the various fuels shallbe as. follows: Natural gas - 0.60 lb S02ftv.lMscf(Compressors Only) Plant gas - The emission factor to be 

### used in conjunction with plant gas combustion shall be determined through the use ofa continuous emissions monitor which will measure the H

### 2 S ' content ofthe fuel gas in parts per million by volume (ppmv). Daily emission factors Shall be calculated using average daily H

### 2 S content data from the continuous emissions monitor
. (CEM). The emission factor shall be calculated as follows:
. (lb S02fMMscfgas) 

### = (24 hr 

### avg. ppmv H

### 2 S)/l01\6 '" (64lb S02/lb mole) '"**(10~** scflM:M:scf)/(379 

### scflIb mole) Fuel oil

- The emission factor to be ·used in conjunction with fuel oil combustion (during natural gas curtailments) shall be calculated based on the weight percent of sulfur, as determined by 

### ASTM Method 0-4294-89 or approved equivalent, and the density ofthe fuel. oil, as follows:·DAQE-AN0101230031-10 Page 13 (lb of S02l'kgal) 

## =(density lb/gal) 

## * (1000 gal/kgal) 

## * (wt. %S)/100 >I< (64 g SOz/32 g S) The weight percent sulfur and the fuel oil density shall berecorded for each day any fuel oil is combusted. Fuel oil may be combusted only during periods ofnatural gas curtailment. The sulfur content ofthe fuel oilshall be tested ifdirected by the Executive Secretary. Fuel Consumption shall be measured as follows: Natural gas consumption shall be detennined by the meter totalizer onthe natural gas supplied to the plant. ' Plantgas consumption shall be determined through the use offlow meters. Fuel oil consumption shallbe measured each day by means ofleveling'gaugeson all tanks that supply oil to combustion sources. . The equations used to determine emissions for the emission cap'sources shall be as follows: Emissions (tons/day) 

## =Emission Factor (lblMMscf) 

## * Natural 

### GaS Consumption (MMscfi'day)/(2,OOO lb/ton)

,Emissions (tons/day) 

# = Emission Factor (lblMMscf) .,. Plant Gas Consumption (MMscf/day)/(2,OOO lb/ton) Emissions (tons/day)

# = Emission Factor (lblkgal) 

## *Fuel Oil.Consumption (kgal/24 

### hrq)/(2,OOO IMon) Total daily S02 emissions for the sources included in the emissions cap shall be calculated by adding the daily results ofthe above'S02 emissions equations for natural gas, plantgas, and fuel oil combustion; Results shall be tabulated for every day, and records shall bekept which include the 

### CEM readings for 

### H2S (averagedfor each one:-hour period), all meterreadings 

### (in the appropriate units), fuel oil parameters (density and wt. %8,recorded for. each day any fuel, oil is.burned) , and the calculated emissions. [R307-40lJ
. 

### II.B.4 Conditions on**NO~** emissionssources 

### II.BA.a MaximumNOx emissions to the atmosphere shall not exceed 2.09 tons per day. The emissions (. ofNO. from all sources shan not exceed 669 tons/year. [R307-401] ILBA.b The following sources shall not be regulated for NOx emissions, nor shall they be included 

### in the emission limitation totals herein: (66-1) Process Flare South (66-2) Process Plare North (68-1) Propane PitFlare Emergency Equipment [R307401J 

### II.B.4.c NO. emissions for the Emissions Cap Sources shall be determined by applying thefollowing emission factors or emission factors determined from the most current performance testing to the relevant quantities offuel combusted.DAQE-ANOlO123003l-l0 Page 14 Boilers and Furnaces: Natural gas/refinery fuel gas combusted using Low NO. burners: BllbslMMscf Natural gas/refinery fuel gas combusted using Ultra-Low NO.burners: 4llbsIMMscf Natural gas/refmery ftlel gas combusted using all other burners: 140 IbslMMscf Natural gas/refmery fuel gas combusted u'sing SCR: 4llbslMMscf All fuel oil combustion:· l20lbsIKgal Where "Natural gaskefinery fuel gas" shall**repres~nt** any combustion ofnaturaI gas, refinery fuel gas, or combination ofthe two in the associated burner. Daily natural gas consumption shall be determined by the meter totalizer on the natural gas supplied to the plant. Daily plant gas consumption shall be determined through the use offlow meters. Daily fuel oil consumption shall be monitoredby means ofleveling gauges on all tanks that supply combustion sourcell. Fuel oil consumption shall be allowed only during periods of natural gas curtailment. The equations used to determine emissionsfor the boilers and furnaces shall be as follows: Emissions (tons/day) 

# =Emission Factor (lbJMM:scf) 

## * Natural Gas Consumption (N.lMscflday)/(2,OOO lb/ton) Emissions (tons/day) 

### = Emission Factor (lblMMscf) 

# * Plant Gas Consumption (M1vfscf/day)/(2,OOO lb/ton) Emissions (tons/day) = Emission Factor (lblkgal) 

## * Fuel Oil Consumption (lcgal/day)/(2,OOO lb/ton)
.**Compressor~:** The NOx Emission Factor for natural gas (finn supply) combustion inthe compressor drivers shall be 3400 lblMMscf. Daily natural gas (fum supply) consumption for the compressor drivers shall be quantified by meters, which shall be installed ifnecessary, that will differentiate the flow ofnatural gas to the compressors from the flow to the boilers and furnaces. The eInissions shall then be determined using the following equation: Emissions (tons/day) 

### = Emission Factor (lblNlMscf) 

# *Natural 

### Gas Consumption CMMscflday)/(2,OOO lb/ton) Total 24-hour NO. emissions for sources included in the emissions cap shall be calculated by adding the results ofthe above NOx equations for plant gas, fuel oil, and natural gas combustion. Results sliall be tabulated for every day, andrecords shall be kept which include the meterreadings (in the appropriate units), emission factors, and the calculated emissions. See Section IX.H.l.i(2) ofthe PMIO SIP for details ofcompliance determination. [R307-401]DAQE-ANOI01230031-10 Page 15 

### n.B.5 Conditions on PM10 

### emissions sources 

### n.B.5.a Prior to the installation ofthe FCC Scrubber. but no later than December 31. 2012. the emissions ofPM1o into the atmosphere from the (51-6) COBoiler shall not exceed 0.36 TPD or 131.4 tons/year. PMIO emissions from the emission capped sources shall not exceed 0.13 TPD or 47 tons/year.



### n.B.5.b Upon the installation ofthe FCC Scrubber. butno later than December 31,2012. the
. emissions ofPM1o into the atmosphere from the (51-6) CO BoilerlFCC Scrubber shall not exceed 0.09 TPD or 32tons/year. PM10 emissions 

### fromthe emission capped sources shall not exceed 0.13 TPD or 47 tons/year
.. [R307-401] The following sources shall not beregulated for PM10 emissions, nor shallthey be included in

.the emission limitation totals herein:
. (4-4a)4K1A KVG CompressorWest (4-4b) 4K1B KVG CompressorEast (6-4a) 6Kl SVG Compressor East (6-4b) 6K2 SVG Compressor West (66-1) Process Flare South (66-2) ProcessFlare North (68-1) Propane PitFlare
. Emergency Equipment [R307-401] 

### n.B.5.c PM10 emissions for the Emissions Cap Sources shall bedetermined by applyingtbe following emission factors or emission factors determined from the most current performance testing to the relevantquantities offuel combusted 

### in eachunit. PMIO Emission Factors for the combustion sources will be as follows: Natural gas: 5 lb PM1ofIv[M:scf Plant gas: 5 lb PMll/MMscf ThePM10 emission factor for fuel oil combustion shallbe determinedbased on the H2S '. content ofthe fuel oil as follows: . - PMlO (lblkgal) = (10 ;I; wt %S) 

### + 3 Daily natural gas consumption for each cap source shan be detenni.ned by the meter totalizer on the natural gas supplied to the pICUlt.
. Daily plant gas consumption for each cap source shallbe determinedthrough the use offlow meters.



### , Daily fuel oil.consumption shall be monitored by means ofleveling gages on all tanks that supply fuel oil to combustion sources. Fuel oil consumption shall be allowed only during periods ofnatural gas curtailment.
. . The equations used to determine emissions for theboilers and furnaces shall be as follows:DAQE-AN0101230031-10 Page 16 Emissions (tons/day) 

# =Emission Factor (lblMMscf) 

# * Natural Gas Consumption (MMscflday)/(2,000 lb/ton)' , Emissions (tons/day)

# = Emission Factor (lblMMscf) ole Plant Gas Consumption (MMscf/day)/(2,OOO lb/ton) Emissions (tons/day) ;:::; EmissionFactor (lblkgal) 

## * Fuel Oil Consumption (kgallday)/(2,OOO
. I lb/ton) Total 24-hour PMIO emissions for the sources included in the einissions cap shall be calculated by adding the daily results ofthe above PM 10 .emissions equations for natural gas, plant gas, 

### ancI fuel oil**coinbustio~.** Result& shall be tabulated for every day, andrecords shall be kept which include all meterreadings (in the .appropriate units), fuel oil parameters (wt. %S), and the calculated emissions. For the details ofcompliance demonstration, refer to Section IX.H.1.i(2) ofthe PM10 SIP. [R307-401]


### Section ill: 

### APPLICABLE FEDERAL REQumEMENTS In addition to therequirements ofthis AO, 

### all applicable provisions ofthe following federal programs have been foundto apply to this installation. This AO in no way releases the owner or operator from 

### any liability for compliance with another applicable federal,**st~te,** and local regulations including UAC R307. NSPS (part 60), J: PetroleumRefmeries NSPS (Part 60), Dc: Small Indus ComInstitnSteamGenratr· I I MACT (part 63), CC: .PetroleumRefineries
. 

### I,: I NBSHAP (Part 61), FF: BenzeneWaste Operations NSPS (part 60), GOG: VOC EquipLeaks Petro Refineries. /' MACT (Part 63), 

### ZZZZ: Recipro. Int. Comb Engine (RlCE) 

### l' NSPS (Part 60), QQQ: VOC Bmis Petro RefWastewtr Sys NSPS (part 60), 

### A: General Provisions MACT (Part 63), UUU:Petro Refineries Cat Crkg,Ref,SPU MACT(part 63), R: Gasoline Distribution NSPS (Part 60), Kb: VolatLiqlPetroStorageVesseI7/23/84



### PERMIT HISTORY This AO is based 

## On the following documents: . .

Is Delived From

.Supersedes Is Derived From Is Derived From**Addi~onal** Information: CO SourceWide PTEs dated November 17,2009 DAQE-ANOr01230027-C9 dated November 3, 2009 Updated NO! dated October 19,2009 NO! dated September 28, 2009" DAQE-ANO 10 1230031-10 Page 17


## ACRONYMS
The following lists cOmlnonly used acronyms and associated translations as they apply to tbis document: 40CFR AO BACT 

### CAA CAAA CDS CEM" CEMS CPR CO COM DAQ DAQE EPA

### HAP6rHAP~ 

### ITA· 

### LBIHR MACT 

### MMBTU NAA NAAQS 

### NESHAP



### .. Nor

NOx NSPS NSR PM10 PM2.5 PSD 

### PTE R307 R307-401 S02 Title 

### IV Title V TPY UAC UDAQ VOC Title 40 ofthe Code ofFederal Regulations Approval Order Best Available ControlTechnology Clean Air Act Clean Air Act Amendments Classification Data System (used byEPA to classify sources by size/type) Continuous emissions monitor Continuous emissions monitoring system Code ofFederal Regulations Carbon monoxide Continuous opacity monitor Division ofAir**QuaJ.i~** (typically interchangeable with UDAQ) This is a document tracking code for internal UDAQ use Environmental Protection Agency Hazardous 

### air pol1utant(s)
. Intent to Approve Pounds perhour
. MaximumAchievable Control Technology Million BritishThermal Units Nonattainment Area .National Ambient

### Air Quauty Standards National Emission Standards for**~ardous** 

### Air Pollutants Notice ofIntent Oxides ofmtrogen
. New SourcePerformance Standard New Source Review
. . 

### " Particulate matterless than 

### 10 microns 

### in size Particulate matter less than 

### 2.5 microns in size Prevention ofSignificantDeterioration Potential to Emit Rules Series 307 Rules Series 307

- Section 401 Sulfur dioxide Title 

### IV ofthe Clean 

### AirAct· Title V ofthe Clean 

### Air Act Tons per year Utah Administrative Code Utah Division ofAir Quality (typically interchangeable with DAQ) Volatile organ.lc compounds