, I

# ~t"aP >..Ja.u'-" 

### DEPARTMENTOFENVIRONMENTALQUALITI T 

### DIVISIONOFAIRQUALITY
:-lormanH.Bangerter Governor ReolvtG Stateot U;an 1950WestNorn-.Temore KennethL.Alkema DivISion 01Air**O~alllv** SailLakeeNUtan ExeeutJveDirector Department01 EnViConmentalQuality (801)536·4000 F.BurnellCordner Direcu>r (801)536·4099Fax SaltLaKeCity, Ulan84114-4820
DAQE-894-91 November 25, 1991

James Van Orman Dept. of the Air Force AFLC HAFB, Utah 84056-5990

Re: Approval Order; Wording Change to Approval Order Dated June 22, 1988 Davis County CDS A1 NA

Dear Mr. Van Orman: The above-referenced project has been evaluated and found to be consistent with the requirements of the Utah Air Conservation Rules (UACR) and the Utah Air Conservation Act. A 30-day pUblic comment period was held and all comments received were evaluated. The conditions of this Approval Order (AO) reflect any changes to the proposed conditions which resulted from the evaluation of the comments received. This air quality AO authorizes the project with the following conditions and failure to comply with any of the, conditions may constitute a violation of this order: 1. Hill Air Force Base shall install and operate the boilers in Building 260 according to the information submitted in the Notice of Intent dated June 22, 1988. A copy of this AO shall be posted on site and shall be available to the employees who operate the air emission producing equipment. All employees who operate the air emission producing equipment shall receive instruction as to their responsibilities in operating the equipment in compliance with all of the relevant conditions. 2. The approved installations shall consist of two Cleaver Brooks DL35 boilers rated at 87.5 million BTU/hr each. The boiler installations**s~all** be complete with Cleaver Brooks low-NOx burner design. 3. This AO shall replace the AO dated June 22, 1988. 

### 4.2.4-823

Printeoonrecycleooa:JerMr. Van Orman November 25, 1991 Page 2

4. Visible emissions from any point or fugitive emission source associated with the installation or control facilities shall not exceed 20\ opacity. Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. 5. The combined total natural gas consumed for the two boilers shall not exceed 809.1 million standard cubic feet per 12-month period without prior approval from the Executive Secretary in accordance with R446-1-3.1, UAC. Compliance with the annual limitation shall be determined on a rolling l2-month total. Based on the first day of each montt a new 12-month total shall be calculated using the previous 12 months. Records of consumption/production shall be kept for all periods when the plant is in operation. Records of consumption/production shall be made available to the Executive Secretary or his representative upon request and shall include a period of two years ending with the date of the request. Production/Consumption shall be determined by calculations based on meter readings and/or examination of fuel bills. The records shall be kept on a monthly basis. 6. The owner/operator shall use only natural gas as a primary fuel and No. 2 Fuel Oil as a backup fuel in the boilers approved by this AO. If any other fuel is to be used, an AO shall be required in accordance with R446-1-3.1, UAC. 7. The sulfur content of any fuel oil burned shall not exceed 0.85 pounds of sulfur per million BTU heat input as determined by ASTM Method 0-4294-89 approved equivalent. The sulfur content shall be tested if directed by the Executive Secretary. 8. Emissions to the atmosphere from the indicated emission point shall not exceed the following rates and concentrations: A. 0.0053 Ib per 106 BTU heat input B. 0.10 C. 0.0038 

### o. 0.004 A stack test for any or all of the above pollutants shall be performed if directed by the Executive Secretary. Notification The applicant shall provide a notification of the test date at least 45 days prior to the test. A pretest conference shall be held if directed by the Executive Secretary. It shall be held at least 30 days prior to the test between the owner/operator, the tester, and the Executive Secretary. The emission point shall be 

### 4.2.4-824l-ir. Van Orman November 25, 1991 Page 3
designed to conform to the requirements of 40 eFR 60, Appendix A, Method 1, and occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approvable access shall be provided to the test location. PM10 For stacks in which no liquid drops are present, the following methods shall be used: 40 eFR 51, Appendix M, Methods 201 or 201a. The back half condensibles shall also be tested using the method specified by the Executive Secretary. For stacks in which liquid drops are present, methods to eliminate the liquid drops should be explored. If no reasonable method to eliminate the drops exists, then the following methods shall be used: 40 eFR 60, Appendix A, Method S, Sa, 5d, or Se as appropriate. The back half condensibles shall also be tested using the method specified by the Executive Secretary. All particulate captured shall be considered PM10. The back half condensibles shall not be used for compliance demonstration but shall be used for inventory purposes. Sample Location 40 eFR 60. Appendix A, Method 1, if required by test mehtod used Volumetric flow rate 40 eFR 60, Appendix A, Method 2, if required by test mehtod used Nitrogen oxides 40 eFR 60, Appendix A, Method 7, 7A, 7B, 7e, 7D or 7E Volatile organic compounds 40 eFR 60, Appendix A, Method 25 Carbon monoxide 40 eFR 60, Appendix A, Method 10



### 4.2.4-825Mr. Van Orman November 25, 1991 Page 4

Calculations To determine mass emission rates (lbs/hr, etc.), the pollutant concentration as determined by the appropriate methods above shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Executive Secretary to give the results in the specified units of the emission limitation. Source Operation For a new source/emission point, the production rate during all compliance testing shall be no less than 90\ of the production rate listed in this Approval Order. For an existing source/emission point, the production rate during all compliance testing shall be no less than 90\ of the maximum production achieved in the previous 3 years. 9. All records referenced in this AO or in an applicable NSPS or NESHAPS, which are required to be kept by the owner/operator, shall be made available to the Executive Secretary or his representative upon request. 10. All installations and facilities authorized by this AO shall be adequately and properly maintained. The owner/operator shall comply with R446-1-3.5 and 4.7, UAC. R446-1-3.5, UAC addresses emission inventory reporting requirements. R446-1-4.7, UAC addresses unavoidable breakdown reporting requirements. The owner/operator shall calculate/estimate the excess emissions whenever a breakdown occurs. The sum total of excess emissions shall be reported to the Executive Secretary for each calendar year no later than January 31 of the following year. 11. The owner/operator of any new major source or major modification anywhere in Utah shall submit to the Executive Secretary an emergency plan within 60 days of the date of this AO. The plan shall identify what control/production measures the owner/operator shall implement when an emergency episode is declared by the Executive Director of the Department of Environmental Quality. Specific control/production measures shall be outlined for all three levels (Alert, Warning, Emergency). The values for the various levels are listed in R446-1-S, UAC. The emergency plan shall approved by the Executive Secretary. Any future modifications to the equipment approved by this order must also be approved in accordance with R446-1-3.1.1, UAC.



### 4.2.4-826Mr. Van Orman November 25, 1991 Page 5

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 the Utah Air Conservation Rules. Annual emissions for these boilers are currently calculated at the following values: A. 2.02 tons/yr for**Par~iculate** B. 1.21 tons/yr for PM10 C. 0.24 tons/yr for S02 D. 37.62 tons/yr for NOx E. 1.50 tons/yr for VOC F. 14.16 tons/yr for CO The annual emissions for the entire base are not quantified at this time. These calculations are for the purposes of**determini~;** the applicability of PSD and nonattainment area major source requirements of the UAC. They are not to be used for the purposes of determining**~ompliance.** Sincerely, 

# t6- C.U'r"1/l'

# t.l 

# t :JiLL .• Burnell**~rdner~1€xecutive** Secretary Utah Air Quality Board FBC:DJ':cl

cc: EPA Region VIII, Mike Owens Davis County H.ealth**Depar~ment**



### 4.2.4-827

# - UTAH DIVISION OF AIR OUALITY NEW/MODIFIED SOURCE PLAN REVIEW
James Van Orman Dept. of the Air Force AFLC HAFB, Utah 84056-5990
ENGINEER: Doug Jones RE: AD of June 22, 1988 for 2 Boilers, Wording Change Davis County, CDS A1 NA DATE: November 6, 1991 NOTICE OF INTENT DATED: September 16, 1991 PLANT CONTACT: James Van Orman PHONE NUMBER: (801) 777-7651 PLANT LOCATION: Hill Air Force Base, Building 260 FEES: Filing Fee $00.00 Review Engineer - 3 hours at SSO.OO/hour $150.00 Modeler - 0 hours at $SO.OO/hour $000.00 Computer Usage Fee $000.00 Notice to Paper 000.00 Travel

- 00 miles at SO.23/mile SOOO.OO Total $150.00 APPROVALS:

Applicant Contact Made

4.2.4-828I. Description of Proposal Hill Air Force Base has sent a Notice of Intent: dated September 16, 1991 requesting modifications to an Approval Order issued June 22, 1988. This Approval Order allowed the use of two natural gas fired boilers. Condition #5 of the Approval Order allows 66.49 x 106 SCF per rolling 30-day period. The request is for a change in the volume of natural gas allowed to 136 x 106per rolling 30 day period. Hill Air Force Base is also asking for this volume of gas consumed per 30-day period be converted to the volume of gas consumed per rolling 12-month period at the same rate. There appears to be an error in the original Approval Order wording of the allowed natural gas consumed. The request is for the combined design capacity of the boilers; the Approval Order reflects approximately the design capacity of one boiler but does not statethe consumption as that allowed for each boiler. There are no changes in the recommended Approval Order conditions. II. Emission Summary The total emissions for this source (the entire base) are not quantified at this time. There are no net emission decreases or increases represented by this Notice of Intent. The total emissions for these boilers are as follows. Total Emissions from the Two Boilers Particulate 2.02 tons/year PM10 1.21 SOx 0.24 NOx 37.63 CO 14.16 VOC 1.21 III. Review of Rules and Regulations A review of the rules and regulations is not required since the Notice of Intent represents a change in wording and not a change in operating parameters or emissions. IV. BACT ANALYSIS The BACT analysis was completed with the original review for the June 22, 1988 Approval Order. No changes to this review are being made. V. Calculations The request for 136 x 106SCF is the number represented in the original Notice of Intent and the number used in the original calculations. No new calculations of emissions are necessary. If the proposed change in wording from a 30-day rolling total to a 12-month rolling total is accepted, then this number will not be represented in the Approval Order. The original calculations were based on operation of the boilers 4300 hours per year for each boiler. Consumption of natural gas at these operating hours is equal to 809.1 million SCF for the combined consumption of both boilers. This number was used inthe original calculations. No new calculations are necessary. The proposed change is to 809.1 million standard cubic feet per rolling 12-month period. VI. RECOMMENDED APPROVAL ORDER CONDITIONS
2 

### 4.2.4-8291. Hill Air Force Base shall install and operate the boilers in Building 260 according to the information submitted in the Notice of Intent dated June 22, 1988. A copy of this Approval Order shall be posted on site and shall be available to the employees who operate the air emission producing equipment. All employees who operate the air emission producing equipment shall receive instruction as to their responsibilities in operating the equipment in compliance with all of the relevant conditions. 2. The approved installations shall consist of two Cleaver Brooks OL-86 boilers rated at 87.5 millionBTU/hr each. The boiler installations shall be complete with Cleaver Brooks low-NOxburner design. 3. This Approval Order shall replace the Approval Order dated June 22, 1988. 4. Visible emissions from any point or fugitive emission source associated with the installation or control facilities shall not exceed 20% opacity. Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. 5. The combined total natural gas consumed for the two boilers shall not exceed 809.1 million standard cubic feet per 12-month period without prior approval from the Executive Secretary in accordance with R446-1-3.1, UAC. compliance with the annual limitation shall be determined on a rolling 12-month total. Based on the first day of each month a new 12-month total shall be calculated using the previous 12 months. Records of consumption/production shall be kept for all periods when the plant is in operation. Records of consumption/production shall be made available to the Executive Secretary or his representative upon request and shall include a period of two years ending with the date of the request. Production/Consumption shall be determined by calculations based on meter readings and/or examination of fuel bills. The records shall be kept on a monthly basis. 6. The owner/operator shall use only natural gas as a primary fuel and No. 2 Fuel Oil as a backup fuel in the boilers approved by this Approval Order. If any other fuel is to be used, an Approval Order shall be required in accordance with R446-1-3.1, UAC. 7. The sulfur content of any fuel oil burned shall not exceed 0.85 pounds of sulfur per million BTU heat input as determined by ASTM Method 0-4294-89 approved equivalent. The sulfur content shall be tested if directed by the Executive Secretary. 8. Emissions to the atmosphere from the indicated emission point shall not exceed the following rates and concentrations: A) Particulate 0.0053 Ib per 106BTU heat input B) NOx 0.10 C) CO 0.0038 0) VOC 0.004 The test methods used shall be as follows: A) Particulate

- 40 CFR 60, Appendix A, Method 5 B) NOx- 40 CFR 60, Appendix A, Method 7
3 

### 4.2.4-830C) CO

- 40 CFR 60, Appendix A, Method 10 D) VOC

- 40 CFR 60, Appendix A, Method 25 The applicant shall provide a notification of the test date at least 45 days prior to the test. A pretest conference shall be held if directed by the Executive Secretary. It shall be held at least 30 days prior to the test between the owner/operator, the tester, and the Executive Secretary. The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, and Occupational Safety and Health Administration (OSHA) approvable access shall be provided to the test location. 9. All records referenced in this Approval Order or in an applicable NSPS or NESHAPS, which are required to be kept by the owner/operator, shall be made available to the Executive Secretary or his representative upon request. 10. All installations and facilities authorized by this Approval Order shall be adequately and properly maintained. The owner/operator shall comply with R446-l-3.5 and 4.7, UAC. R446-l-3.5, UAC addresses emission inventory reporting requirements. R446-l-4.7, UAC addresses unavoidable breakdown reporting requirements. The owner/operator shall calculate/estimate the excess emissions whenever a breakdown occurs. The sum total of excess emissions shall be reported to the Executive Secretary for each calendar year

...- _.::a._..:.... ...._ \,00.--1 - - -_ 1". ••";:; - ----'-' '::; J • 11. The owner/operator of any new major source or major modification anywhere in Utah shall submit to the Executive Secretary an emergency plan within 60 days of the date of this Approval Order. The plan shall identify what control/production measures the owner/operator shall implement when an emergency episode is declared by the Executive Director of the Department of Environmental Quality. Specificcontrol/productionmeasures shall beoutlined for all three levels (Alert, Warning, Emergency). The**val~es** for the various levels are listed in R446-l-S, UAC. The emergency plan shall approved by the Executive Secretary. Any future modifications to the equipment approved by this order must also be approved in accordance with R446-l-3.l.l, UAC. This Approval Order in no way releases the owner or operator from any liability for compliance with all other applicable federal, state, and local regulations including the Utah Air Conservation Rules. Annual emissions for these boilers are currently calculated at the following values: A. 2.02 tons/yr for Particulate B. 1.21 tons/yr for PMlO C. 0.24 tons/yr for S02 D. 37.62 tons/yr for NOx E. 1.50 tons/yr for VOC F. 14.16 tons/yr for CO The annual emissions for the entire base are not quantified at this time. These calculations are for the purposes of determining the applicability of PSD and nonattainment areamajor source requirements of theUAC. They are not to be used f·or the purposes of determining compliance. DOUG\WP\HILLCHG.AO

4 

### 4.2.4-831

# ~~~~ • \ \ I 

### DEPARTMENTOFTHEAIRFORCE j HEADQUARTERSOGDENAIRLOGISTICSCENTER(AFLC) 

# SEP 1

# 71991 HILLAIRFORCEBASE,UTAH84056·5990 AIROIIAUTY 

## 16SEPiSS1
Mr 

### Don Robinson Chief, Permit Section Department of Environmental Quality Division of Air Quality 1950 WNorth Temple Salt Lake City, utah 84114-4820 RE: Boiler Numbers 8 

### &9, Building 260 Request for Amendment to A. 

## o. Dated 22 June 88, BAQE-256-88 Dear Mr Robinson In our 4 Sep 91 meeting regarding 30 day rolling average for the natural gas consumption for the two boilers, we request that the condition 5 of the permit be modified to allow for 136X106 

### SCF per.30 days of natural gas firing rate at design value. Additionaly, we request that the rolling average period be revised to a 12 month period.



### JAMES R. VAN ORMAN

...**:-:~~** 

### Director 01 

### Environmental Management.1

"':'J

'**~~** __ - ',1 -_ •• '. • •. ... ..

# __.'-'



## ­

4.2.4-832Norman H.Bangerter**~"** \"**-,~** . SuzanneDanaoy.M.D

..MPH**:'t·~U!~Vt·**

### u: rt '(**~:"** 

### BAQE-252-88

April 27, 1988

Newspaper Agency Salt Lake Tribune Legal Advertising Department 157 Regent Street Salt Lake City, Utah 84111
Gentlemen: This letter will confirm the authorizationtopuolish the attachea NOTICE in the Salt Lake Tribune ana Deseret News on May b, 

### 198ci. Please mail the invoice ana affidavit ofpuolication to theUtah State Department ofHealth, DivisionofEnvironmental Health, Bureau of Air Quality, P.O. Box 16690, Salt Lake City, Utah 84116-0690.
Sincerely,

# ~~~1\-(}-~}{'-;"i~L Sheri Holloway 

## JEngineering Section Bureau ofAir Quality

4.2.4-833

Kenne[r1 L

..AJkema. DJ/eGor • D/VlSlonofEnVlronmemal Heal[h

### NOT ICE The following notices of intent to construct, submittea inaccoraance with Section 3.1, Utah Air ConservationRegulations, nave been receivec for consiaerationby theExecutiveSecretary, Utah Air ConservationCommittee: 1. Crossroaas Refining, Inc., Precious Metals Refining, SaltLaKe County. 2. Hill Air ForceBase, Two Replacement BoilersinBoilerhouse 260, Davis County; 50 KW Diesel Generator in auilding 800, Davis County; 150 KW Diesel Generator inBuilding 887. 3. Johnson Matthey, Increase Gola Production, SaltLake County. 4. Genwal Coal Company, Temporary Crusher, Emery County. 5. Ashley Valley Engineering, escalante Cogeneration Plant, Garfiela County. 6. J&J Mill ana Lumber, Concrete olock Plant, washington County. The engineering evaluations ana air quality impact analyseshave been completed ana no aaverse air quality impacts are expected. No Prevention of SignificantDeterioration (PSD) increment will be consumed oy these proposals. It is the intent of theExecutive Secretary to approve tne constructionprojects. The constructionproposals ana estimates of the effect on local air quality
are available for public inspection ana comment at the8ureau of Air Quaiity, Utah StateDepartment of Health, 288 North 1460 West, SaltLake City, Utah 84116-0700. Written comments receiveaDy the Bureau, 288 North 1460West, P.O. Box 16690, Salt Lake'City, Utah 84116-0690, on or before June 4, 1988



# -.

4.2.4-834

### will be considerea in maKing the final decision on the approval or Gisapproval of the proposea construction. If anyone so requests within 15 days ofpUblication ofnotice, a hearing will be held inthe area oftheproposea construction, installatlon, mooification, relocation or establishment. Date of Notice: May 6, 1988 

### a</sh 7226Q



# -

4.2.4-835----'

............t--"'---'-{-...::........;o....-r-=---­ 

### UTAH BUREAU OF AIR QUALITY NEW/MODIFIED SOURCE PLAN REVIEW FOR:

Mr. Thayne judd**Depar~ment** 

### of the Air Force Environmental Management Office Hill Air Force Base, Utah 84056 Re: Two ReplacementBoilers inBoilerhouse 260 Davis County, CDS Al
Date: April 18, 1988 Notice of Intent Dated: February 23, 1988**Plan~** 

### Contact: Jay Gupta Phone Number: (801) 777-6742 Plant Location: Hill Air Force, Utah
Filing Fee Review Engineer

- totalhours Modeler

- total hours Computer time

- total hours Notice To Paper Travel

- total miles 11.5

( ( (



### $ 

### $22.08/hr $18.07/hr

0.23/mile )
Total =

=

=



### =

=

=

= 

### $ $ 

### $ 

### $ $ $
$ 

### 100.00 253.92

24.00

377.92 Approved by Engineering UnitManager**--IOoo~~---J'--...L...:.-""":"_~--r** 

### Approved by Technical Evaluation SectionManager 1350q

4.2.4-836

### Thayne Juad Page 2
I. DESCRIPTION OF PROPOSAL Hill Air Force Base (HAFB) has filea a notice of intent aated February 23, 1988 in which they propose to replace two existing oldboilerswith two new packaged steam boilers. The existing boilers are ratea at40,000 LB/HR. The new boilers are ratea at 70,000 LB/HR. The packaged steam bailerswill be Cleaver Brooks Model DL-86 complete with waterwall tubes, furnace section, boiler convection section, "CB" burner, lower drum, upper steam arum, soot blowers, ana all associated piping, controls, safety interlocks, pressurereliefvalves, outlet aampers, ana stack. At 100% loaa, each boiler will be capable of delivering 70,000 LB/HR of steam at an operatingpressureof 125 psig and steamquality of99.5%. Each unit will be designed to fire natural gas as theprimary fuel with No.2 fuel oil as a backup. At full load, theheat input per unit willoe 87.5millionBTU per hour with an efficiency of 80.03%. There are currently eightboilers inBuilding260. The average loaa factor is 70-75%. The two new boilers are scheauled to become operativein summer 1986. II. EMISSION SUMMARY The steam demand varies considerably over theyear. For this reason boilers are cyclea up ana down. There willbe an emission increaseas a result ofthe installation of these two new boilers. Emissions ofThe Two ExistingBoilersBeing Replaced Particulate 0.184 Ton/Yr PM10 0.110 Ton/Yr 502 

### 0.022 Ton/Yr t'D

### x 

### 5.148 Ton/Yr CO 1.287 Ton/Yr VOC 0.103 Ton/Yr Methane 0.110 Ton/Yr Emissions ofThe Two Proposea New Boilers Particulate 2.023 Ton/Yr PM10 1.214 Ton/Yr 502 

### 0.243 Ton/Yr t'D

### x 

### 37.625 Ton/Yr CO 14.160 Ton/Yr" VOC 1.505 Ton/Yr Methane 1.214 Ton/Yr Proposed Emission IncreaseatBuilding 260 Particulate 1.839 Ton/Yr PM10 1.103Ton/Yr 4.2.4-837

### Thayne Judd Page 3
S02 

### 0.221 

### Ton/Yr I'D

### x 32.477 

### Ton/Yr CO 12.873 

### Ton/Yr VOC 1.402 

### Ton/Yr Methane 1.103

### Ton/Yr III. BEST AVAILABLE CONTROL TECHNOLOGY (BACT) ANALYSIS The recommenaed best available control technology (BACT) for thegeneration of heat for production of steam for process use ana space heat is touse boilers which are fired on natural gas ana equippeo with low NOxburners. There are otheroptions. The options for the generationof process steam are comoustion of: 1. 

### Natural gas 2. No. 2 fuel oil 3. No. 5fuel oil 4. Coal The emission factors in AP-42 

### show that natural gas has the lowest emission rate per unit of heat. The gas ourners will be low NOxdesignburners. The Cleaver Brooks low NOxburners reduce NOxemissions as much as 43%. 

### All other sources ofheat willhave higher emissions than theproposeG heat generation method. The proposed natural gas fired Cleaver Brooks Moael DL-86 boilerswith CB Industrial Burners for low NOx firing are recommended as having applieo BACT. IV. APPLICABLE UTAH AIR CONSERVATION REGULATIONS (UACR) This notice of intent is for a mooification to an existing major source. It isnot anew major sourceor a major moaification

.. The followIng feaeral and stateregulations have been examinea to determine their applicability to this notice of intent: 1. Section 3.1.1, UACR

- Notice ofintent required for amodifiea source. This regulationapplies. 2. Section 3.1.8, 

### UACR

- Application ofbest availaolecontrol technology (BACT) requiredat allemission points. This regulation applies. 3. Section 3.1.9, UACR

- Rules for relocation oftemporary sources. This source is a permanent source. Therefore, this regulation does not apply. 4. Section 3.2, 

### UACR

- Particulateemission limitations for existing sources which arelocated in anonattainment area. HAFB is listed in this regulation (existing boilers, 20% 

### opacity limitation). 4.2.4-838

### Thayne JUdD Page 4 However, any new emission points at HAFB will not be subject to this regulation. 5. Section 3.3.2, UACR

- Review requirements for new major sources or major modifications wnich are locateD in a nonattainment area or which impact a nonattainment area. This notice of intent Does not represent a new major source or a major mODification. Therefore, this regulation will not apply. 6. Section 3.5, UACR

- Emission inventory reporting requirements. This regulation requires any source which emits 25 tons or more per year of any pollutant to submit an emission inventory tothe**~ureau** 

### of Air Quality every year. This source must comply with this regulation. 7. Section 3.6.5(b), UACR

- Prevention of significant deterioration (PSD) review requirements for new major sources or major mODifications. This source aoes not aualify as a new major source or a major modification unaer PSD rules. Therefore, this regulation Does not apply. 8. Section 3.8, UACR

- Stack height rule. This regulatlon limits the creDitable height ofstacks to thatheignt DetermineD to be gooD engineering practice. The formulas useD to Determine gooa engineering practice are found in40 CFR 51.1. Ademinimus heignt of 65 meters (213.2 feet) is allowed. This source has no stacks which exceeD 65 meters inheight. It is 

### in compliance withthis regulation. 9. Section 3.11, UACR

- Visioility screening analysis requirements. This regulation requires all new major sources or major modifications to unoergo a visibility screening analysis to determine visibility impact on any manDatory Class I area. This source is not a new major source or a major modification unDer UACR rules. Therefore, this regulation does not apply. 10. Section 4.1.2, UACR

- 20% opacity limitation at all emission points unless a more stringent limitation is requiredby New Source Performance Stanaaros (NSPS) or BACT or National Emission StanDaros for Hazardous Air Pollutants (NESHAPS). In this case, the 20% opacity limitation applies. 11. Section4.1.9, UACR

- EPA MethoD 9to be used for visible emission observations. This regulation applies. 12. Section 4.2.1, UACR

- Sulfur content limitations in oil ana coal useD 'for corrbustion. Thisemissionpointburns oil as a backup fuel. The limitationis 0.85 LB of sulfurper 106BTU heat input.
4.2.4-839

### Thayne Judd Page 5
13. 

### Section 4.7, UACR

- Unavoidable breakdown repJrting requiremenl:s. This regulation applies. 14. Section 4.9, UACR

- Review requirements for volatile organic compouna (VOC) sources locatea in a nonattainment area for ozone. This process is not covered in this regulation. 15. Section 5, UACR

- Emergency episode requirements. This regulation applies. 16. New Source Performance Stanaaras (I'-JSPS)

- There is no NSPS for tnis inaustrial process. 17. National Emission StanDarDs for Hazardous Air Pollutanl:s (f\£SHAPS)

- There is no f\£SHAPS for this inaustrial f)rocess. 18. National Ambienl: Air Quality StanDards (NAAQS)

- This source is located in Davis County which is a nonattainment area for ozone. The Bureau ofAir Quality guidelines dO not call for this source to be modeleD for ozone. Therefore, it is very unlikely that any new violation of the NAAQS for ozone will occur. V. RECOrviMEI\OED APPROVAL ORDER CONDITIONS 1. Hill AirForce Base shall install the two Cleaver Brooks Moael DL-86 natural gas fireaboilers (these arereplacement boilers) according to the information submitted in the notice ofintent dated February 23, 1988. 2. All installations and facilities authorizeD by this approval order shallbe adequately and properly maintained. 3. Visible emissions from-any point or fugitive emission source associated with the installationor control facilities shallnot exceed 20% opacity. Opacity observationsofemissions from stationary sources shallbe conducted inaccorDance with40 CFR 60, Appendix A, Method 9. 4. The sulfurcontent ofany fuel oil burned shall not exceeo 0.85 poundS of sulfur per millionBTU heal: input as determinea by ASTM Method 0-4239-83. The sulfur content shallbe testeD only if directeDby the ExecutiveSecretary. 5. Natural gas consumption for the two new CleaverBrooks boilers shall not exceea a total of 66.49xl06SCF per 3O-oay perioD (based on a 30-oay rolling average) withoutprior approval in accordance withSection 3.1, UACR. Recoras of consumption shallbe kept for all periODS when the plant is in operation. Records of consumption shall be made available to the ExecutiveSecretary upon 4.2.4-840

### Thayne Judd Page 6 request, ano shall include aperioD oftwo yearsenoing with the date ofthe request. Consumption shallbe aetermineoby calculationsbased on meter recoras ana/or fuel bills. 6. The boiler stacks shallbe stack testeaifdirecteo by the Executive Secretary. The emission rate for each boiler stack shall not exceed any ofthe following values: A. Particulate

- 0.0053 Lb per 106BTU heat input B. NOx- 0.10 Lb per 106BTU heat input C. CO

- 0.0038 Lb per 106BTU heat inRut D. VOC (nonmethane)

- 0.004 Lb per 106BTU heat input The testmethods usea shallbe as follows: A. Particulate

- 40 CFR 60, Appendix A, Methoo 5 B. NOx- 40 CFR 60, Appenoix A, Method 7 C. CO

- 40 CFR 60, Appenaix A, Methoa 10 D. VOC

- 40 CFR 60, Appenaix A, Methoa 25 Apretest conference shallbe held ifoirectedby theExecutive Secretary. It shallbe hela at least 30 aays prior totne test between theowner/operator, the tester, ana theExecutive Secretary. The exhaust stackneea notbe designeo to**acco~nooate** 

### testing. However, iftneExecutive Secretary uetermines a stack test isnecessary, whatever modificationsneedea tomeet the requirements of40 CFR 60, Appendix A, Methoa 1and the requirements ofOccupationalSafety and Health Administration (OSHA) for providing approvaole access to the test site shallbe made. 7. The owner/operator shall use only natural gas as a fuel in the bollers. Ifany other fuel is tobe used, an approval oroer shall be required in accordance with Section 3.1, UACR. Diesel fuel may be used only as an emergency backup fuel. 8. The Executive Secretary shallbe notified inwritingupon start-up ofthe installation, as an initial compliance inspection is required. Any future modifications to theequipment approved by this order must also be approved in accordance withSection3.1.1, UACR. This approval order in no way releases the owner or operator from any liability for compliance with allother applicable federal, state, ana local regulations including the Utah Air Conservation Regulations. DER/sh 1350q 4.2.4-841/"

.- ::**:='~.SE** 

### SOURCE: TWO BOILER CHANGE-OU7**EM!5~:** 

### COMPANY NAME: HILL AFB. BLDG. 260. LOCATION: LAYTON , UT**DP.IE~.Ql-:-APR~~S'B8...-** __D.!.:30: 13 PM 

### lOTAL**~NNUAL** 

### EMISSIONS 

### ESTIMATE TSP .t.**S3~'** 

### PM-IO .1.. l**c.~J ::J~~/**  \'R "

....5.QX

__ . '.'

_ TCi·J/'y'R 

### '....,-, :\iDX ..Jo.:.:... -:- .' 

### ":]t,:,i\ :: 

## co l:C' S7::;: "TiJiJ./'/r:

________**~c** _nCifJ J1EIHaNE vae r-iElHANE " . 1. 1:J3

: "': i:';i. : .1

... • I 

### -'**~xrSTI:~G** 

### BOILERS



# - t1INUS



### -**~ROPOSED** 

### BOILERS GIVES INCREASES LISTED**ABOV~**



### 4.2.4-842

# )

-. ,"__ _" r_",

_ 

### SOURCE. -"

..­ COMPANY NAr-E. ' DL.DG. 

### 260: BOILERS 8**I~** i...OC.c>.TION: :_.:'-"'[::' '

..' I T T<V:C

.**Dr-~TE:.** 01-APR-: :,>:;::S • _ I Il-. N\lNUt 1L Ej''Il**~;S** ==<:.:'"S If'II;'TE I**~,~** TDhIS/y'R =­

___.LEMISS::..::; '-';,,=-:-OR) (GAS CONSUMPTION) (i TCN/200D LDS) TOTAL**PAR7I:~~~~~** (-'M-10 , SOx

.. _ , .. NOx. CO. , ,



### _.Voc.•..

__11Dr:'-;',::::':":-

.. \)Oe, METH

SEPT. 1985 VOLuME 

### SECTION ;. ::,-'-'.::'**~~)M8IJS:I001** SCi.iR':::ES .'.. I}. 

### NATURA:'"

_..::.**~_·;;':;~..'STION** ;p,BLE 1.

### J<**':~'. :>"''-,~L**  BOILi:::PS 

### ,I.e _. :..!JCJ**:-1ILL_.:8i'~** BTU/HR)



### BAG DEFAULT 

### VALUE PM10 

### NEDS SOURCE CLASSIFICATION 

### CODES 302 

### SULFUR CONT. 

## = 2000 GR/1E6 

### SCF NOX CO

"

### _."­

GAS**CONSUI·;Pi:::G~·j ~i'4**  

### MILLIO!'1 CU8IC FT. ! 

### vR 

### FRor-1**_(~VEL** .CONSUMPTION)(ANNUAL 

### OPERATION)!(FUEL HEAT VALUE) 

### FROM GAS CONSUMPTION 

### RECORDS HOURL'r' ;30 ILER FUEL. COMSUMPT ION NOI I!\lFO 

### HOURS/YR OPERATION SCHEDULE: 

### Nor 

### INFORMATION. FUEL**HE~T** 

### :ONTENT. 0 0
I_J. :;'.



## - ' 0, O. 184 1' "\

.l. 1.1**(-...-;~** _)e-c..



### -4·3 -'07 '="I.J I 10? 110

5. (I 3. 0 G, 6 140. 0

35. 0

2. 8 3. rJ

73, 5 100, 00

683. 9 930, C T'

TONS/'{R 

### TONS/YR TONS/YR TDi--iS/YR 

### TONS/YR TONS/YR TONS/YF:

l...BS/!"'iCi= L13S/MCF LI3Slr1CF LBS/MCF 

### l-SS/MCF**~BS/MCF** L3S/f"'!CF



### MCFIYR 

### MMBTU/HR HR/YR BTiJ/CU FT

4.2.4-843

# f

._.CONTRoLLED.ANNU&Ei'lISSION Ri"",TE ESTII'1ATE 

### FOR: SOURCE: 2 PROPOSED B8iLERS COMPANY NAME: HILL AFB, BLDG. 260, 

### BOILERS 8 

### &9 

### FILE: T2 LOCATION: LAYTON , VT

.**_-DAT..E..:--O.l--=A?R..~9.88** __. _ 

### TIME: 11:43:07..AM 

### ANNUAL EMISSIONS ESTIMATE IN TONS/YR 

## =

._._..__**.(EMISSlDN-E~CTOR)** 

### LGAS_CONSUMPTION) (1 TON/2000 

### LBS) TOTAL PARTICULATE

. 2.023 

### TONS/YR PM-IO

.. 1.214 

### TONSI''I''F:

._..So.x

..__. _.."'_""

_ . C.24.3.IONS/YR NOx

. :17. 

### 625 TONS/YR CO.

. . . . . . . . . . . . . 14. 

### 160 TONS/YR



## .._ vm:: n.on-..MElli

. 

### 1.5o.5.IONS/YR VOC, METH........

. . 1. 214 

### TONS/YR
AP-42 FOURTH EDITION SEPT. 

### 1985 VOLUME 1 SECTION 1 

### EXTERNAL COMBUSTION SOURCES 1

..4 

### Nt-.TVRAL Gi?\S 

### COMBUSTION TABLE 1.4-1 

### INDUSTRIAL BOILERS (10- 100 

### MILLION BTUiHR) EMISSION FACTOR IN LES/MILLION CUBIt FEET OF GAS COMBUSTED



### .__**P_~R** TIC

### ULA'IE 

### BAG DEFAULT 

### VALUE .,. . . . . . . . . . . . 

### 5. Q**_LJl~-:t1CF** 

### PMIC NEDS SOURCE CLASSIFICATION CODES 3. 0 

### LBS/MCF S02 SULFUR CONT. 

## = 2000 

### GR/IE6 SCF

.. O. 6 LBS/MCF 

### NO.X '."

.. :Nor INFO. 93. 0 

### LBS/MCF CO

. 35.0 

### LBS/MCF-' NON 

### l"lETHANE 

### vac NOI INFO. 3. 7 

### LBS/t'lCF



### .. .-t1.E.Ttlf'.NE:

.'.'

.**~. Q.b~~/M~i** 



### GAS CONSUMPTION IN MILLION CUBIC FT. ! 

### YR FROM



### __--.J.F_L!El

__**C'O.~Sl)~tlP.** 

### TIONUANi\JUAL OPERATION)/ (FUEL.

### HEAT VALUE)

.._ .. 

### APPROVAL ORDER CONDITION

. 809. I 

### MCFIYR 

### HOURLY BOILER FUEL COMSUMPTION: NOI INFO

. 175.00 MMETU/HR 

### .HOI

..LR.S./YR_Op,ERf,TION SCHEDULE: NOI INFORMATION

. 4,300.0 HR/YR FUEL HEAT CONTENT.

. . . . . . . . 930. 0 BTU/CU**~-:**



### 4.2.4-844DEPARTMENT OFTHE AIR FORCE HEADQUARTERSOGDEN AIR LOGISTICS CENTER (AFLCI HILLAIR FORCE BASE. UTAH 840158 

## FEB 2 3**19R~**



### Mr F. Burnell Cordner, Executive Secretary Utah Air Conservation Committee Bureau ofAir Quality 288 North 1460West 

### PO Box 16690 Salt Lake 

### City UT 84116-0690 

### Re: Notice of Intent to Construct Dear Mr Cordner Incompliance with section 3.1 of the State Air ConservationRegulations, attached are three Notices of Intent to Construct for projects at Hill AFB. If 

### this office can provide additional information, please feel free to contact Jay Gupta at 777-6742.
Sincerely 1 Atch Notices of Intent to Construct (3)

# ~~.~ THAYNE H.JUDO,Col, USAF Chief,environmentalMgtOffice



# RECEIVED" AIRQUALITY 

## FEB 291988

4.2.4-845

### NOTICE OF INTENT TO CONSTRUCT REPLACE EXISTING BOILERS 

## U8 	, BLDG 260 HILL AIR FORCE BASE, UTAH
1. PROJECT DESCRIPTION: Hill AFB proposes to replace two existing old boilers each rated at 40,000 lbs/hr steam with two new packaged steam boilers each rated at 70,000 lbs/hr steam. The packaged steam boilers will 

### be Cleaver Brooks Model DL-86 complete with waterwall tubes, furnace section, boiler convection section, "CB" burner, lower drum, upper steam drum, soot blowers and all associated piping, controls, safety interlocks, pressure relief valves, outlet damper and stack. At 100% load, each boilerwill 

### be capable of delivering 70,000 lbs/hr of steam at an operating pressure of 125 psig and steam quality of 99.5%. Each unit will 

### be designed to fire natural gas as the primary fuel with #2 fuel oil as a back up fuel. At full load, the total heat input to each unit will 

### be 87.5 million BTU/hr with unit efficiency of 80.03%. 2. POLLUTANT EMISSIONS: At present, boiler house in building 260 houses 8 boilers. Because both boiler load and steam demand vary considerably, boilers are often cycled to meet varying process and heating steam reqUirements. For instance, some boilers may be shut down completely for several months during the summer due to low heating steam demand while in winter months continuous operationmay be required to meet increasing heating steam demand. Due to cyclic nature of operation, it is fairly accurate to assume an average load factor of 70-75% to reflect emissions 

# ­ averaged over the entire year. Additionally, since existing boilers are being replaced withnew boilers of larger capacity, only incremental emissions represent the net increase in emissions from this project. Emissions from existing boilers are estimated based on calendar year 1987 average fuel consumption, operating hours and using the EPA publication, AP-42, Emission Factors. Emissions from the replacement boilers are estimated using Cleaver Brooks Stack Emission Data. These emissions are representative of Cleaver Brooks CB burners and industrial burners and is a compilation of the results of laboratory and field tests. (i) Emissions From Existing Boilers: Total gas consumption 73,536,000 CD FT/YR 

### Emission Factors: AP-42, Vall, 4 Ed, Table 1.4-1 FUEL 

### E.F. 

### EMISSIONS POLLUTANT lXl06CD FT LB/IO6CU FT LBLYR TONS/YR Particulate 73.536 3 220.6 0.1 SOX 73.536 0.6 44.1 0.02 NOX 73.536 140 10,295 5.14 HC 73.536 5.8 426.5 0.21 OJ 

### 73.536 35 

### 2,573.8 1.29



### 4.2.4-846

### (ii) Emissions From New Boilers: Data (ea. boiler): Primary fuel: Natural gas Approximate heating value: 930 

### BTU/sCF Approximate operating hours: 4,300 100% Load 75% Load 50% Load Steam Flow Lbs/Hr 70,000 52,500 35,000 Total Heat Input 

### MBTU/HR 87.5 64.9 43.0 Fuel Fired SCFM 1,570 1,164 772 

### Excess Air % 

### 10 10 10 Flue Gas Temp 

### OF 485 435 400 Flue Gas to Stack Lbs/Hr 74,795 55,437 36,768 ACFM 28,575 20,060 12,784 SCFM 15,748 11,672 

### 7,741 Emissions (two boilers): E.F. Emissions (tons/yr) Pollutant Lb/lO

### 6BTU PPM**100~~** 

### Load 75% Load 50% Load Particulates 0.01 3.76 2.8 1.85 NOX 0.10 85 37.6 27.9 18.5 HC 0.004 10 1.5 1.1 .74 SOX AA. 

### Based on average load factor of 75%, Net increase in NOX emissions = 

### 27.9 - 5.1
= 

### 22.8 tons NOX/Yr 3. AIR CLEANING DEVICES Cleaver Brooks standard low NOX burner design is the Best Available Control Technology (BACT) for control of nitrogen oxides (NOX) from boiler**stacks~** 

### Recent developments and modifications of burner design has resulted in NOX reduction of as much as 43%, i.e., 85 ppm compared with 150 ppm NOX emissions from these burners a few years ago. 4. EMISSION POINTS: Each boiler will discharge approximately 12,000 SCFM via 42" diameter stack. Point of discharge will be 

### about 30' above ground. 5. SAMPLE .POINTS: No sampling points are anticipated. 6. OPERATING SCHEDULE: New boilers are scheduled to go into operation this summer. Their operationwill be cyclic as explained above.

4.2.4-847