# Utah State ImplementationPlan Emission Limits and Operating Practices

Section IX, PartH

Adopted by the Air Quality Board July 6. 2005Adoptedby theAir Quality Board 011 July 6. 2005


## Table ofContents
IX.H.I General Requirements I IX.H.2 Source-Specific ParticulateEmission Limits for SaltLake County 4

a. Bountiful City Power 4 b. Central Valley WaterReclamation Facility 5 c. Chevron Products Co 7 d. Flying

### J Inc., Big West Oil Co 9 e. Geneva RockProducts,Point ofthe Mountain 12 f. Holly Refining and Marketing Co 13 g. Interstate Brick 15 h. Kennecott Utah Copper: Mine and Coppenon Concentrator 16 J. KennecottUtah Copper: PowerPlant and Tailings Impoundment

.. 17 j. Kennecott Utah Copper: Smelterand Refinery 21 k. PacifiCorp, Gadsby PowerPlant 26 

### 1. Tesoro West Coast 27 m West Valley Leasing CO,tLC: WestValley PowerPlant 28 urce-5pecific Particulate Emission LimitsforUtah County 30

a. Altemative Requirements 35 b. Demonstrating Equivalency ofan Altemative Requirement 35 c. Procedure 36

Section IX, Part H, page 2Adoptedby theAir Quality Board on July 6, 2005 

## IX.H EMISSION LIMITS AND OPERATING PRACTICES (Adopted 24 September 1990 and updated June 28,1991; February 27,1997; July 3,2002; and July 6, 2005.) 

## IX.H.I General Requirements. The terms and conditions ofthis Subsection 

### IX.H.l shall apply to all sources subsequently addressed in Subsection IX.H.2 and 

### 3. Should any inconsistencies exist between these two subsections, the sourcespecific conditions listed in 

### IX.H.2 and 3 shall lake precedence.



### a. Stacktesting to showcompliance with the emission limitations for the sources in this appendix shall be perfonned in accordance with 40 CPR 60, Appendix. A; 40CFR 51 AppendixM; and R307-30S-5. The backhalfcondensibles are required for inventory purposes. Thefollowing test methods shall be used forthe indicated air contaminants: '(1) PMIQ For stacks in which noliquid drops are present, the following methods shall be used: 40CPR 51, AppendixM, Methods 201 or 201aplus the backhalfcondensibles using Method 202, or other appropriateEPA approved reference method, For stacks in which liquid drops are present, methods to eliminatethe liquid drops should be explored. Ifno reasonable method to eliminate the drops exists, then the following methOds shall be used: 40 CPR 60, Appendix. A, Method 5, Sa, 5d, 5e, plus backhalfcondensibles using method 202, or other appropriate EPA approved reference method. All particulate captured in the back halfshall be considered PM IO• ThePM IO captured in the front halfshall be considered for compliance purposes. Appendix 

### A. Method 6, 6A, 6B or6C (3) NOx Appendix A, Method 7, 7

### A. 7B, 7C, 7D or 7E (4) Sample Appendix A, Method I Location (5) Volumetric Appendix A, Method 2 Flow Rate (6) Calculations To determine mass emission rates, the pollutant concentration as dctennined by the appropriate methods above shall be multiplied by the volumetric flow ratc and any necessary conversion factors to give the results in the specified units ofthe emission limitation. Notification ofthe test date shall be provided at least 30 days prior to the test. A pretest conference shall be held ifdirected by the Executive Secretary. The emission point shall 

### be designed to conform to the requirements of40CFR 60, Appendix A, Method I, and Occupational Safety and Health Administration (OSHA) approvabJe access shall 

### be provided to the test location. Theproduction rate during all compliance testing shall 

### be no less than 90% ofthe maximumproduction achieved in the previous three (3) years.

Section IX, Part H, page 1Adoptedby the Air Quality Board allJuly 

### 6. 2005 b. Compliance with the annual limitations shall 

### be determined based on a rolling 12-month total. By the last day ofeach month a new 12-month total shall 

### be calculated using data from the previous 12 months.

c. Any information used to determine compliance shall 

### be recorded for all periods when the plant is in operation, and such records shall 

### be kept for a minimum offive years. Any or all ofthese records shall 

### be made available to the Executive Secretary upon request. d. All installations and facilities authorized by this regulation shall be adequately and properly maintained.

.
e. The definitions contained in R307-101-2, Definitions, apply to Section IX, Part

### H. f. Visible emissions shall be as follows except as otherwise designated in specific source subsections: 

## * baghouse applications shall not exceed 10% opacity; '" scrubber andESP applications shall not exceed 15% opacity; '" combustion sources without control facilities shall not exceed 10% opacity; 

### * fugitive emissions shall not exceed 15% opacity; and '" fugitive dustand all other sources shall not exceed 20% opacity. g. Opacity observations ofemissions from stationary sources shall be conducted in accordance with 40 

### CPR 60. Appendix A, Method 

### 9. Forintermittent sources and mobile sources opacity observations shall be conducted usingprocedures similar to Method 

### 9, but the requirement for observations to 

### be made at I5-second intervals over a six minute period shall not apply.

. h. All unpaved roads and other unpaved operational areas that are used by mobile equipment shall 

### be water sprayed and/orchemically treated tocontrol fugitive dust. Treatment shall 

### be ofsufficient frequency and quantity to maintain the surface material in 

### a damp or moist condition. unless the ambient temperature is below freezing. The opacity shall not exceed 20% during all times. If chemical treatment other than magnesiumchloride is to be used, the plan must 

### be approved by the executive secretary. Records ofwater and/orchemical treatment shall be kept for all periods when the plant is in operation. The records shall include the following items: A. Date; B. Number oftreatments made. dilution ratio, and quantity; C. Rainfall received, ifany, and approximate amount; and D. Time ofday treatments were made. Records oftreatment shall be made available to the executive secretary upon request and shall include a period oftwo years ending with the date ofthe request.

1. Petroleum Retineries. (1) All petroleum refineries in or affecting the PM 10 nonattainmentlmaintenance area shall, for the purpose ofthis PMIO SIP: (a) remove a minimum of95% ofthe sulfurfrom feed streams processed by the sulfur recovery unit (SRU) for all periods ofoperation except for startup, shutdown, or malfunction ofthe SRU. The feed streams to be processed shall include the acid gas from the amine regeneration unit and the sour-water stripper. SRU efficiency shall 

### be estimated and reported to the Executive Secretary a minimum ofonce per year.
Section IX, Part H, page 2Adoptedby the Air Quality Board on July 6, 2005


### (b) reduce the H2

### S content ofthe refinery plant gas to 0.10 grainJdscf(160 ppm) or less, except during startup, shutdown, or malfunction ofthe amine plant. Compliance shall 

### be based on a roUing average of24 hours. The owner/operator shall install and maintain a continuous monitoring system for monitoring the H2

### S content ofthe refinery plant gas and a continuous recorder to record the H2

### S in the plant fuel gas. The monitoring system shall comply with all applicable sections ofR307-170 and 40 CPR 50, Appendix

### B. Specification 7. As used herein, refinery "plant gas" shall have the meaning of"fuel gas" as defined in 40CPR 60, Subpart

### J, and may be 

### used interchangeably. 

### Ifthe monitorreading is not available, the refinery plant gas shall 

### be sampled as closely to the monitor location as safely possible at least once each day. The sample shall be analyzed for sulfur content by use ofa chemical detector tube capable ofreading the required concentration (e.g., DragerHydrogen Sulfide No. lID orequivalent). Fornatural gas, compliance is assumed while the fuel comes from a public utility. (c) no longer burn fuel oil in external combustion equipment, exceptduring periods ofnatural gas curtailment oras specified in IX.H.2. External combustion shall mean combustion that takes place at no greaterpressure than one inch ofmercury above ambient pressure. (d) achieve an emission rate equivalentto no more than 9.8 kg of

### S02 per 1,000 kg ofcoke burnofffrom any Catalytic Cracking unit by use oflow-SOx catalyst orequivalent emission reduction techniques orprocedures, including those outlined in 40 CPR60, Subpart

### J. Unless otherwise specified in IX.H.2, compliance shall 

### be determined daily based on a rolling sevenday average. (e) not exceed 20% opacity at any process flare. Opacity at catalytic cracking units, including those with ESP facilities, shall notexceed 20%, with compliance to

### be determined in accordance with Subsection (g) above. (2) ComplianceDemonstrations. (a) (a)Compliance with the maximum daily (24-hr) plant-wide emission limitations for PMlO, 

### S02, and NOx shall be 

### determined by adding the calculated emission estimates for all fuel burningprocess equipment to those from any stack-tested or CEM-measured source components. NOx and 

### PMIO emission factors shall be 

### determined from AP-42 orfrom test data. For SOx. the emission factors are: Natural gas: EF

# =0.60 IblMMscf Propane: EF

### =0.60 Ib/MMscf Plant gas: the emission factor shall be 

### calculated from the H2S measurement required in IX.H.I.i(l)(b). The emission factor, where appropriate, shall 

### be calculated as follows: (lb 

### SOlMMscfgas) 

## =(24 hr avg. ppmv H2

### S)/106 

### * (64 lb SOz/lb mole) 

## * (106 

### scflMMscf) 1(379 

### scflib 

### mole)

Section IX. Part H, page 3Adoptedby the Air Quality Boardon July 

### 6. 2005 Fuel oils (when permitted): The emission factor shall 

### be calculated based on the weight percent ofsulfur, as detennined by ASTMMethod D-4294-89 or approved equivalent, and the density ofthe fuel oil, as follows: EF(lb SO:z/k gal) 

### = density (lblgal) 

## * (1000 gallk gal)'" wt.% SIlOO 

## * (64lb SOi32lb S) Where mixtures offuel are used 

### in an affected unit. the above factors shaH be weighted according to the use ofeach fuel. (b) Daily emission estimates for stack-tested source components shall 

### be made by multiplying the latest stack-tested hourly emission rate times the logged hours ofoperation (or other relevant parameter) for that source componentfor each day. This shall not preclude a source from determining emissions through the use of

### a CEM that meets the requirements ofR307­ 170. (c) The sulfurdioxide concentration in the flue gas ofSulfurRecovery Units shall 

### be determined by a continuous emission monitor that meets orexceeds 

### the requirements contained in 40 CFR 60, Appendix B, Performance Specification 2. The monitor shall 

### be maintained and calibrated in accordance with R307- 170. The mass flow rate ofthe flue gas shall 

### be detennined by a volumetric flow measurement device that meets orexceeds the requirements contained in 40 CPR 52Appendix E. (d) Any parameters necessary to determine compliance, including but not limited to: CEM data, fuel gas meter readings, hours ofoperation for stack-tested source components, and the calculated emissions, shall 

### be recorded on a daily basis. Theserecords shall 

### be kept for a minimum offive years. Any orall ofthese records shall 

### be made available to the Executive Secretary upon request. (e) The emissions increase (above normal operations) experienced during the SRUroutine turnarounds shall not 

### be included in the daily (24-hr) or annual compliance demonstrations. (f) Emissions due to upset flaring shall not be included in the daily (24-hr) or annual compliance demonstrations. (3) SRU maintenance period (a) The routine turnaround maintenance period (expected every 2 to 5 years for approximately a 15 day period) for a SulfurRecovery Unit shall only 

### be scheduled during the period ofApril 1 through October 31. The projected SRU turnaround period shall be submitted to the Executive Secretary by April 1ofeach year in which a turnaround is planned. Notice shall also be provided the Executive Secretary 30 days priorto the planned turnaround. (b) Alternatively, a source may choose to conduct its turnaround maintenance outside ofthe window identified in paragraph 3.A above; however, in such case the exemption provided in Subsection IX.H.1.i(2)(e) above shall no longer apply.

Section IX, Part H, page 4Adoptedby theAir Qualiry Boardon July 6, 2005 

### f. HOLLY REFINING AND MARKETING CO. (1) PM 10 Emissions
DAILYLIMIT: Combined emissions ofPM 10 from all external combustion process equipment, including the SulfurRecovery UnitTail Gas Incinerator, shall benogreater than 

### 0.444 tons 

### perday. Emissions for the group ofexternal combustion process equipment shall be determined 

### daily by multiplying the appropriate emission factor from section IX.H.l.i.2 orfrom testing below by the relevant parameter (e.g. hours ofoperation. feed rate, orquantity offueI cornbusted) ateach affected unit, and summing the results for the group ofaffected units. The emission factor for the (51-6) CO Boiler shall 

### bedeterminedby stack test. Testing isrequired once at least every five years. (2) S02Emissions DAILYLIMIT: Combined emissions of

### S02 from gas-fired compressor drivers and all external combustion process equipment, including the SulfurRecovery Unit Tail Gas Incinerator, shall be no greater than 4.714 tons perday. Emissions for gas-rued compressordrivers and the group ofexternal combustion process equipment shall be determined daily by multiplying the appropriate emission factor from section IX.HJ.i.2 or from testing below by the relevant parameter (e.g. hours ofoperation. feed rate, or quantity offuel combusted) at each affected unit, and summing the results for the group of affected units. Fuel Oil

- The weightpercent sulfur and the fuel oil density shall berecorded for each day any fuel oil is combusted. Fuel oil may be combusted in external combustion process equipment only during periods ofnatural gas curtailment. The emission factor for the (51-6) COBoiler shall be determined by stacktest. Testing is required at least once every five years. Compliance with Subsection IX.H.I.i.(I)(d) above shall be determined as part ofeach test. Alternatively, S02 emissions from the (51-6) CO Boilermay be determined using a Continuous Emissions Monitor (CEM) in accordance with rx.H.l.i.2.b. Emissions from the 

### SRUrrGI sha]] 

### be determined daily by multiplying the sulfurdioxide concentration in the flue gas by the mass flow ofthe flue gas. (3) NOxEmissions: (a) DAlLYLIMIT: Combined emissions ofNOx from gas-fired compressor drivers and all external combustion process equipment, including the Sulfur Recovery Unit Tail Gas Incinerator. shall be no greater than 

### 2.20 tons per day.

Section IX, Part H, page 13Adopted by theAir Quality Boardon July 6, 2005 

### Emissions for gas-fired compressor drivers and the group ofexternal combustion process equipment shall 

### be detennined daily by multiplying the appropriate emission factor from section IX.H.1.i.2 by the relevant parameter (e.g. hours ofoperation, feed rate, or quantity offuel combusted) at each affected unit, and summing the results for the group ofaffected units. (b) 12-MONTH LIMIT: 

### Combined emissions ofNOx from gas-fired compressor drivers and all external combustion process equipment. including the SulfurRecovery Unit Tail Gas Incinerator. shall be

### no greater than 693.0tons perrolling twelve-month period.

Section IX. Part H. page 14