, I 

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

DEPARTMENT OF ENVIRONMENTAL QUALITIT 

DIVISION OF AIR QUALITY 

:-lorman H. Bangerter 

Governor 

1950 West Norn-. Temore Reolv tG State ot U;an 

Kenneth L. Alkema 

Sail Lake eN Utan DivISion 01 Air O~alllv ExeeutJve Director Department 01 EnViConmental Quality (801) 536·4000 F. Burnell Cordner
 

Direcu>r (801) 536·4099 Fax
 Salt LaKe City, Ulan 841 14-4820 

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 

Printeo on recycleo oa:Jer 
Mr. 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 

4.2.4-824 
l-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 

4.2.4-825
 
Mr. 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. 

4.2.4-826 
Mr. 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, 

t 6- 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
 

Jame s 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 

4.2.4-828
 
I. 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 106 per 

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 state the 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 106 SCF 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 in the 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 4.2.4-829 
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 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 million BTU/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 106 BTU 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 

4.2.4-830
 
C) 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. Specific control/production measures shall be outlined 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 area major source requirements of the UAC. They are not to be used 

f·or the purposes of determining compliance. 

DOUG\WP\HILLCHG.AO 

4 

4.2.4-831 
DEPARTMENT OF THE AIR FORCE ~~~~ • \ \ I

j

HEADQUARTERS OGDEN AIR LOGISTICS CENTER (AFLC) SEP 1 71991 HILL AIR FORCE BASE, UTAH 84056·5990 

AIR OIIAUTY 

16 SEP iSS1 

Mr Don Robinson
 

Chief, Permit Section
 

Department of Environmental Quality
 

Division of Air Quality
 

1950 W North 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 -_ •• '. • •. ...' .. __.'-' ­ ~~

4.2.4-832
 
Norman H. Bangerter ~" \" -,~ . 

Suzanne Danaoy. 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 authorization to puolish the attachea NOTICE in 

the Salt Lake Tribune ana Deseret News on May b, 198ci. 

Please mail the invoice ana affidavit of puolication to the Utah State 

Department of Health, Division of Environmental Health, Bureau of Air Quality, 

P.O. Box 16690, Salt Lake City, Utah 84116-0690. 

Sincerely, 

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

Bureau of Air Quality 

4.2.4-833 

Kenne[r1 L..AJkema. DJ/eGor • D/VlSlon of EnVlronmemal Heal[h 
NOT ICE
 

The following notices of intent to construct, submittea in accoraance with 

Section 3.1, Utah Air Conservation Regulations, nave been receivec for 

consiaeration by the Executive Secretary, Utah Air Conservation Committee: 

1. Crossroaas Refining, Inc., Precious Metals Refining, Salt LaKe County. 

2. Hill Air Force Base, Two Replacement Boilers in Boilerhouse 260, Davis 

County; 50 KW Diesel Generator in auilding 800, Davis County; 150 KW 

Diesel Generator in Building 887. 

3. Johnson Matthey, Increase Gola Production, Salt Lake 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 analyses have been 

completed ana no aaverse air quality impacts are expected. No Prevention of 

Significant Deterioration (PSD) increment will be consumed oy these 

proposals. It is the intent of the Executive Secretary to approve tne 

construction projects. 

The construction proposals ana estimates of the effect on local air quality 

are available for public inspection ana comment at the 8ureau of Air Quaiity, 

Utah State Department of Health, 288 North 1460 West, Salt Lake City, Utah 

84116-0700. Written comments receivea Dy the Bureau, 288 North 1460 West, 

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 of pUblication of notice, a hearing will 

be held in the area of the proposea 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 Replacement Boilers in Boilerhouse 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 - total hours 

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 Unit Manager --IOoo~~---J'--...L...:.-""":"_~--rApproved by Technical Evaluation Section Manager 

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 old boilers with two new 

packaged steam boilers. The existing boilers are ratea at 40,000 LB/HR. The 

new boilers are ratea at 70,000 LB/HR. 

The packaged steam bailers will 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, pressure relief valves, outlet aampers, ana 

stack. At 100% loaa, each boiler will be capable of delivering 70,000 LB/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 No.2 

fuel oil as a backup. At full load, the heat input per unit will oe 

87.5 million BTU per hour with an efficiency of 80.03%. 

There are currently eight boilers in Building 260. The average loaa factor is 

70-75%. The two new boilers are scheauled to become operative in summer 1986. 

II. EMISSION SUMMARY 

The steam demand varies considerably over the year. For this reason boilers 

are cyclea up ana down. There will be an emission increase as a result of the 

installation of these two new boilers. 

Emissions of The Two Existing Boilers Being 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 of The 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 Increase at Building 260 

Particulate 1.839 Ton/Yr 

PM10 1.103 Ton/Yr 

4.2.4-837 
Thayne Judd 

Page 3 

S02 0.221 Ton/Yr 

I'Dx 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 the generation of 

heat for production of steam for process use ana space heat is to use boilers 

which are fired on natural gas ana equippeo with low NO x burners. There are 

other options. The options for the generation of process steam are comoustion 

of: 

1.	 Natural gas 

2.	 No. 2 fuel oil 

3.	 No. 5 fuel 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 NO x design burners. The 

Cleaver Brooks low NOx burners reduce NO x emissions as much as 43%. All 

other sources of heat will have higher emissions than the proposeG heat 

generation method. 

The proposed natural gas fired Cleaver Brooks Moael DL-86 boilers with CB 

Industrial Burners for low NO x 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 

is not a new major source or a major moaification .. The followIng feaeral and 

state regulations have been examinea to determine their applicability to this 

notice of intent: 

1.	 Section 3.1.1, UACR - Notice of intent required for a modifiea 

source. This regulation appl ies. 

2.	 Section 3.1.8, UACR - Application of best availaole control 

technology (BACT) required at all emission points. This regulation applies. 

3.	 Section 3.1.9, UACR - Rules for relocation of temporary sources. 

This source is a permanent source. Therefore, this regulation does 

not apply. 

4.	 Section 3.2, UACR - Particulate emission limitations for existing 

sources which are located in a nonattainment 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 to the ~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 of stacks to that heignt DetermineD to be gooD 

engineering practice. The formulas useD to Determine gooa 

engineering practice are found in 40 CFR 51.1. A deminimus heignt 

of 65 meters (213.2 feet) is allowed. This source has no stacks 

which exceeD 65 meters in height. It is in compliance with this 

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 required by 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.	 Section 4.1.9, UACR - EPA MethoD 9 to 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. This emission point burns oil as a backup 

fuel. The limitation is 0.85 LB of sulfur per 106 BTU 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 of Air 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 Air Force Base shall install the two Cleaver Brooks Moael 

DL-86 natural gas firea boilers (these are replacement boilers) 

according to the information submitted in the notice of intent 

dated February 23, 1988. 

2.	 All installations and facilities authorizeD by this approval order 

shall be adequately and properly maintained. 

3.	 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. 

4.	 The sulfur content of any fuel oil burned shall not exceeo 

0.85 poundS of sulfur per million BTU heal: input as determinea by 

ASTM Method 0-4239-83. The sulfur content shall be testeD only if 

directeD by the Executive Secretary. 

5.	 Natural gas consumption for the two new Cleaver Brooks boilers 

shall not exceea a total of 66.49xl06 SCF per 3O-oay perioD 

(based on a 30-oay rolling average) without prior approval in 

accordance with Section 3.1, UACR. Recoras of consumption shall be 

kept for all periODS when the plant is in operation. Records of 

consumption shall be made available to the Executive Secretary upon 

4.2.4-840 
Thayne Judd 

Page 6 

request, ano shall include a perioD of two years enoing with the 

date of the request. Consumption shall be aetermineo by 

calculations based on meter recoras ana/or fuel bills. 

6.	 The boiler stacks shall be stack testea if directeo by the 

Executive Secretary. The emission rate for each boiler stack shall 

not exceed any of the following values: 

A.	 Particulate - 0.0053 Lb per 106 BTU heat input 

B.	 NOx - 0.10 Lb per 106 BTU heat input 

C.	 CO - 0.0038 Lb per 106 BTU heat inRut 

D.	 VOC (nonmethane) - 0.004 Lb per 106 BTU heat input 

The test methods usea shall be as follows: 

A.	 Particulate - 40 CFR 60, Appendix A, Methoo 5 

B.	 NO x - 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 

A pretest conference shall be held if oirected by the Executive 

Secretary. It shall be hela at least 30 aays prior to tne test 

between the owner/operator, the tester, ana the Executive 

Secretary. The exhaust stack neea not be designeo to acco~nooate

testing. However, if tne Executive Secretary uetermines a stack 

test is necessary, whatever modifications needea to meet the 

requirements of 40 CFR 60, Appendix A, Methoa 1 and the 

requirements of Occupational Safety and Health Administration 

(OSHA) for providing approvaole access to the test site shall be 

made. 

7. The owner/operator shall use only natural gas as a fuel in the 

bollers. If any other fuel is to be 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 shall be notified in writing upon start-up 

of the installation, as an initial compliance inspection is 

required. 

Any future modifications to the equipment approved by this order must also be 

approved in accordance with Section 3.1.1, UACR. 

This approval order in no way releases the owner or operator from any 

liability for compliance with all other applicable federal, state, ana local 

regulations including the Utah Air Conservation Regulations. 

DER/sh 

1350q 

4.2.4-841 
/" 

SOURCE: TWO BOILER CHANGE-OU7 EM!5~: .- :: :='~.SE

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::;: "T iJiJ./ '/r: 

________~c _n Ci fJ J1EIHaNE 

vae r-iEl HANE " . 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 

Dr-~TE:. 01-APR T T <V:C . -::,>:;::S • _ I Il-. 

N\lNUt1 L 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.•.. __ 11 Dr: '-;',::::':":-..
 

\)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' ;3 0 I LER FUEL. C OMSUMP T I ON NO I 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? 

1 10 

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 

MCF IYR 

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~iGAS CONSUMPTION IN MILLION CUBIC FT. ! YR FROM 

__--.J.F_L!El__C'O.~Sl)~tlP. T ION UANi\JUAL OPERAT ION) / (FUEL. HEAT VALUE) .._.. 

APPROVAL ORDER CONDITION . 809. I MCF IYR 

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 ~-:

4.2.4-844
 
DEPARTMENT OF THE AIR FORCE
 

HEADQUARTERS OGDEN AIR LOGISTICS CENTER (AFLC I
 

HILL AIR FORCE BASE. UTAH 840158
 

FEB 2 3 19R~

Mr F. Burnell Cordner, Executive Secretary 

Utah Air Conservation Committee 

Bureau of Air Quality 

288 North 1460 West 

PO Box 16690 

Salt Lake City UT 84116-0690 

Re: Notice of Intent to Construct 

Dear Mr Cordner 

In compliance with section 3.1 of the State Air Conservation Regulations, 

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, environmental Mgt Office 

RECEIVED" 

AIR QUALITY 

FEB 291988 

4.2.4-845
 
NOTICE OF INTENT TO CONSTRUCT
 

REPLACE EXISTING BOILERS U8 & #9, 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 boiler will 

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 operation may 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 with new 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 lXl06 CD FT LB/IO 6 CU 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 6 BTU 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 operation will be cyclic as explained above. 

4.2.4-847