# ~~· State ofUtah s== )**.~** DEPARTMENT OF ENVIRONMENTAL QUALITY DIVISION OF AIR QUALITY 150 NOM 1950 West M
....l

### o.

# "",,;.1 P.O. Box 144820 Dianne R.

## Nielson~ 

# I Salt Lake City, Utah**8411~820** (801) 5364000 Russell A. Roberts E.u<:utive Dire<:lor

# I
(801) 536-4099 Fax Dire<:lor
. (801) 538-4414 T.D.D. DAQE-403-95 May 8, 1995

W. Robert James OO-ALC/EM 7274 Wardleigh Road Hill Air Force Base, Utah 84056-5137 Re: Approval Order for Construction ofTwo Boilers Each in Buildings 1590 and 1703 Davis County CDS B NA l\'SPS Dear Mr. James: The attached document is an Approval Order for the above referenced project. Future correspondence on this Approval Order should include the engineer's name as well as the DAQE number as shown on the upper right-hand corner ofthis letter. Please direct any technical questions you may have on this project to Mr. Arjun Ram. He may be reached at (801) 536-4066. Sincerely,

# --j;,,~, 

# ;:1

-**~/I/I)** 

# .**/;~Y--**

_Russell A. Roberts; Executive Secretary

Utah Air Quality Board RAR:AR:dn
cc: Davis County Health Depanment

4.2.4-174

# STATE OF UTAH Department of Environmental Quality Division of Air 

# Quality APPROVAL ORDER FOR**.<~'"** 

# CONSTRUCTION OF TWO BOILERS EACH IN BUILDINGS 1590 & 

# 1703 PREPARED BY: Arjun Ram, Engineer



## APPROVAL ORDER NUl\ffiER DAQE-403-95 Date: .May 8, 1995 Source 

# HILL AIR FORCE BASE

Russell A. Roberts Executive Secretary Utah Air Quality Board 4.2.4-175DAQE-403-95 Page 2 Abstracr This Review/Approval Order isfor the installation ofrwo narural gasfired. 10w-NOx• watenube. steam boilers rared ar 27.6MMBTU /HR in Building 1590 and the installarion ofTWO natural gas fired. low NOx•firetube steam boilers. rared at 11.25 MMBTU/HR in Building 1703. These boilers would replace existing boilers in the buildings. which do not have low-NOx burners. This project does not result in an increase in acrual emissionsfrom the boilers; therefore. a 30-day public commenrperiod is not required for thisproject. All thefour boilers are capable ofusing #2fuel oil as backupfuel. Emissions from thefour boilers with a maximum of720 hours ofburningfuel oilper 12-monthperiod are 4.48 tonsperyear PM Jo• 15.96 tonsperyear SOx. 18.98 tonsperyearNOx• 20.05 tonsperyear CO. and 1.86tonsperyear VOc. Low-NOx technology in conjuncrion with a 10% opacity limitation and the use of natural gas asprimaryfuel are considered BeS[ A\/ailable QJnrrol Technology (BACT)for thisproject. The Notice ofIntent for the above-referenced project has been evaluated and has heen found to be consistent with the requirements ofthe Utah Air Conservation Rules (UACR) and**th~** Utah Air Conservation Act. However, air pollution producing sources and/or their air control fa.:i1ities may not be constructed, installed, established. or modified prior to the issuance of an Arrroval Order (AO) by the Executive Secretary ofthe Utah Air Quality Board. Unless you have comments which would require changes, the AO for this proje.:t will he hased upon the following conditions: 

# -, General Conditions: 1. This AO applies to the following company: Department OfThe Air Force OO-ALC/EM 7274 Wardleigh Road Hill Air Force Base, Utah 84056-5137 Phone Number: (801) 777-D359 Fax Number: (801) 777-4306 The equipment listed below in this AO shall be operated at the following location: LOCATION UTM COORDINATES: Building 1590: 4,553,750 m. Northing; 415.290 m. Easting Building 1703: 4,554,870 m. Northing; 414,210 m. Easting 2. Definitions ofterms, abbreviations, and references used in this AO conform to those used in the UACR, Utah Administrative Codes (UAC), and Series 40 ofthe Code of Federal Regulations (40 CFR). These definitions take precedence unless specifically 

# - defined otherwise herein.

4.2.4-176DAQE-403-95 Page 3 

### 3. HilI Air Force Base shall install and operate the natural gas fired boiler according to the information submitted in the Notice ofIntent dated December 22, 1994. 4. A copy ofthis AO shall be posted on site. The AO shall be available to the employees who operate the air emission producing equipment. These employees shall receive instruction as to their responsibilities in operating the equipment according to all ofthe relevant conditions Iisted below. 5. The approved installations shall consist ofthe following equipment (MMBTU/HR stands for million BTUs per hour): A. Two boilers (rated at 27.60 MMBTU/HR) and associated equipment in Building 1590 B. Two boilers (ra[ed at 11.25 MMBTU/HR) and associated equipment in Building 1703 

### Hill Air Force Base shall submit to the Division ofAir Quality (DAQ), the Manufacturer's name. Boiler's**~10del** and Serial Number (or equivalent information that will enable proper identifi.cation ofthe boilers), for each ofthe boilers approved by this condition before commencing the operation ofthe boilers. 6. 

### Hill Air Force Base shall permanently shut down the operation oftwo boilers in Building 1590 and two boilers in Building 1703 before commencing the operation of the boilers approved in Condition #5. 7. The Executive Secretary shall be notitied in writing upon stan-up ofthe installation as an initial compliance inspection is required. Eighteen months from the date ofthis AO the Executive Secretary shall be notitied in writing ofthe status of installation if construction/installation is not completed. At that time the Executive Secretary shall require documentation or the continuous installation ofthe operation and may revoke the AO in accordance with R307-l-3.1.5. UAC. Limitations and Tests Procedures 8. Emissions to the atmosphere from the stacks ofthe boilers approved in Condition #5 shall not exceed the following rates and concentrations (the lbslhr and ppmdv values are equivalent and the source has the option ofdemonstrating compliance with values in either ofthe units):
Source: Stacks of Boilers in Building 1590 Pollutant lbs/hr ppmdv (3 % 0", dry) NOx 1.33 40 CO 1.21 60
4.2.4-177DAQE-403-95 Page 4
Source: Stacks of Boilers in Building 1703 Pollutant lbslhr 

## I ppmdv (3 % 02' dry) NOx 0.54 40 CO 0.49 60 9. Stack testing to show compliance with the emission limitations stated in the above condition shall be performed as specified below lor each of the boilers specified in Condition #5: A. Emission Point Pollutant Testing Test Status Frequency Boiler Stack NO, '" @ CO '" @ B. Testing Status (To be applied above) 

### * No initial testing is required. However. the Executive Secretary may require testing at any time in accordance with R307-1-3.4.1, UAC. The source shall be tested if directed by the Executive Secretary. 

### ** Initial compliance testing is required. The initial test date shall be within 180 days after the start up of a new emission source, or the granting ofthe AO for an existing emission source. @ Test if directed by the Executive Secretary. Tests may he required if the source is suspected to be in violation with other conditions of this AO. C. Notification The applicant shall provide a notification of the test date at least 45 days before the test. A pretest conference shall be held if directed by the Executive Secretary. It shall be held at least 30 days before the test between the owner/operator, the tester, and the Executive Secretary. The emission point shall be designed to conform to the requirements of40 CFR 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. D. Sample Location 40 CFR 60. Appendix A, Method 1
4.2.4-178DAQE-403-9S Page 5 E. Volumetric Flow Rate 40 CFR 60, Appendix A. Method 2 F. Nitrogen Oxides (NO.1 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7e, 7D or 7E or an alternative method to be approved by the Executive Secretary. The test protocol shall be submitted for review at the time of notification ofthe test. G. Carbon Monoxide (CO) 40 CFR 60, Appendix A, Method 10 H. Calculations To determine mass emission rates (lbs/hr, etc.), the pollutant concentration as determined by the appropriate methods above shall he multiplied by the volumetric flow rate and any necessary conversion factors determined by 

# . the

., Executive Secretary to give the results in the specified units ofthe emission limitation. I. Source Operation The heat (gas) input rate during all compliance testing shall be no less than 90% ofthe rates listed in MMBTU/HR in Condition #5 ofthis AO. 10. Visible emissions from any point or fu/::-:tive emission source associated with the installation or control facilities shall not exceed 10% opacity. Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60. Appendix A, Method 9. Visible emissions from mobile sources and intermittent sources shall use procedures similar to Method 9, but the requirement for observations to be made at IS-second interVals over a six-minute period shall not apply. Any time' interval with no visible emissions shall not be included. 11. The following consumption limits shall not be exceeded without prior approval in accordance with R307-1-3.1, UAC; For each boiler in building 1590(rated at 27.6 MMBTUlhr): A. 242,000 decatherms (242 million cubic feet) ofmltural gas per 12-month period (l decatherm = 1,000.000 BTU) B. 141,000 gallons offuel oil to be burned per 12-month period C. 720 hours of operation burning fuel oil per l2-momh period
4.24-179DAQE-403-95 Page 6 For each boiler in building 1703 (rated at 11.25**?vl~1BTU!hr):** A. 98,550 decatherms (99 million cubic feet) of natural gas per 12-month period 

### B. 57,500 gallons offuel oil to be burned per 12-month period C. 720 hours ofoperation burning fuel oil per 12-month period Compliance with the annual limitations shall be determined on a rolling 12-month total. Before the fifteenth day of each month, a new 12-month total shall be calculated using data from the previous 12 calendar months. Records ofoil consumption shall be kept for all periods when the plant is in operation. Records of oil consumption shall be made available to the Executive Secretary or his representative upon request and shall include a period oftwo years ending with the date ofthe request. Consumption shall be determined by operating logs or vendor receipts. The records shall be kept on a dailv hasis. Hours ofoperation shall be determined by supervisor monitoring and maintaining of an operations log.

12. The owner/operator shall use only natural gas or liquid petroleum gas as a primary fuel and #2 fuel oil or light grade as a backup fuel in the boiler. If any other fuel is to be used, an AO shall be required in accordanl.:e with R307-1-3.1, UAC. Number two (#2) fuel oil may be used only when natural gas supply has been interrupted. 13. The sulfur content of any fuel oil burned shall not exceed 0.5 percent by weight. Sulfur content shall be decided by ASTM Method D-4294-89, or approved equivalent. The sulfur content shall be tested ifdirected by the Executive Secretary. Federal Limitations and Requirements 14. In addition to the requirements ofthis AO, all provisions of40 CFR 60. NSPS Subparts A and Dc, 40 CFR 60.40c to 60.48c (Standards ofPerformance for Small Industrial

- Commercial

- Institutional Steam Generating Units) apply to this installation. The owner or operator shall record and maintain records ofthe amount offuel combusted during each day. Each boiler must have an individual fuel use meter which cannot be reset. to determine how much fuel that boiler used each day. Records & Miscellaneous 15. All records referenced in this AO or in an applicable new source performance standard (NSPS), which are required to be kept by the owner/operator. shall be made available to the Executive SecreTary or his representative upon request. 

# .­ 4.2.4-180DAQE-403-95 Page 7 Examples of records to be kept at this source shall include the following as applicable: A. Fuel consumption B. Test results 16. All instaJlations and facilities authorized by this AO shall be adequately and properly maintained. All pollution control vendor recommended equipment shall be installed. maintained. and operated. Instructions from the vendor or established maintenance practices that maximize pollution control shall be used. All necessary equipment control and operating devices. such as pressure gauges. amp meters, volt meters. flow rate indicators. temperature gauges, continuous emission monitors (CEMs), etc.• shall be installed and operated properly and easily accessible to compliance inspectors. 11. The owner/operator shaJl comply with R307-1-3.5, UAC. This rule addresses emission inventory reporting requirements. 18. The owner/operator shall comply with R307-1-4.7. UAC. This rule addresses unavoidable breakdown reporting requirements. The owner/operator shall calculate/estimate the excess emissions whenever a breakdown occurs. The total of excess emissions shall be reported to the Executive Secretary as directed for each calendar vear. 19. This source is required to pay an annual emission fee upon start-up. The fee wiJl be based on calculated annual emissions listed at the end ofthis AO. This fee is valid until inventory data for one year are available for the source. The owner or operator of this source will be billed upon start-up for all emissions that are considered "chargeable" as ofthat date. Any future modifications to the equipment approved by this order must also be approved in accordance with R307-l-3.1.1. UAC. 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 UACR. Annual emissions for this source (four boilers in Condition #5) are currently calculated at the following values: Pollutant Tons/vr A. PM:o 4.48 

### B. SO..
. . . . 15.96 C. NOx . . . . . . ... 18.98 

### D. CO.
. . . . .. . .. 20.05 

### E. VOC 1.86
4.2.4-181DAQE-403-95 Page 8 These calculations are for the purposes ofdetermining the applicability ofprevention of significant deterioration (PSD) and nonanainment area major source requirements of the UACR. They are not to be used for purposes ofdetermining comp]iance. In accordance with the requirements ofTitle V of the 1990 Clean Air Act, the following pollutants may be subject to an operating permit fee. Both the fees rate and the class ofpollutants are subject to change by State, the Federal agencies. or both. Pollutant Tons/vr A. Particulate 4.48 B. 502 . • • . • • • • • . • . . . . . . . . . . . • •• 15.96 

### C. NOx 18.98 D. VOC 1.86 Approved By);, ,i./

# /~fj/ 

# f'
,--,\ "j**/!~** /

. .' I I. 

# ," .;/**/I/~** • "--- ..v f, """ /j :. " Russell 

## A. Roberts. Ex.ecutive'Secretarv \ -Utah Air Quality Board
.

4.2.4-182**.~ ~~**  , 

### .

## ., 

# ... ".,

..... . .. , 'j ..J ••
. .::-s • , ,; '-* DEPARTMENT OF ENVIRONMENTAL QUALm' 

### .: :. .

# .. ". DMSION OF AIR QUALITY Michael O. Luvia 150 NOM 1950Wellt o.-r­ P.O. Box 144820 Dianne R. NieiIOD. Ph.D. Salt I...akt City, Utab 84114-4820 E.=cuaYe Dinlclar (801) 536-4000 Ruueil A. Rabens (801) 536-4099 Fax ov­ (80l) 538-4414 T.D.D. DAQE-I04-95 February 8, 1995

W. Roben James OO-ALCIEM i274 Wardleigh Road Hill Air Force Base. Utah 84056-5137 Re: Intent to Approve Construction ofTwo Boilers Each in Buildings 1590 and 1703 Davis County CDS B NA NSPS Dear Mr. James: The attached document is an Intent to Approve with Fee Statement for the above referenced project. Future correspondence on this Approval Order should include the engineer's name as well as the DAQE number as snown on the upper right-hand corner ofthis letter. Please direct any technical questions you may have on this project to Mr. Arjun Ram. He may be reached at (801) 536-4066. Sincerely, /7
.

(,..,**~.,** /1**.-/7~** I .', ."....**V""//~~** ,I, -,**//~ L~R.**  MeDlove', Manager New Source Review Section LRM:AR:dn
cc: Davis County Health Depanrnent

4.2.4-183

?rinteo on recvc:ea DaDer

# STATE OF UTAH Department ofEnvironmental Quality Division of Air Quality INTENT TO APPROVE CONSTRUCTION OF TWO BOILERS IN BUILDING 1590 AND TWO BOILERS IN BUILDING 1703 PREPARED BY: Arjuo Ram 

### INTENT TO APPROVE NUMBER DAQE-I04-95 Date: February 8, 1995 Source 

# HILL AIR FORCE BASE
Russell A. Roberts Executive Secretary Utah Air Quality Board

4.2.4-184DAQE-104-95 February 8. 1995 Page 2 

### AbsTracr This ReviewiApproval Order isfor rhe insrallarion oflWO 

### natural gasfired, 10w-NOx . warenube. sream boilers rared ar 27.6

### MMBTUIHR in Building 1590 and

### rhe insrallarion ofrwo narural gas fired, low NOx •firerube sream boilers. raredar 11.25

### MMBTUIHR in Building 1703. These boilers would replace existing boilers in 

### rhe buildings, which do nor have 10w-NO xburners. This

### projecr does nor resulrin an increase in actual emissionsfrom rhe boilers: rherefore, a 3D-daypublic commentperiod is nor required for rhisprojecr. All rhefour boilers are capable ofusing #2

### fuel oil as backupfuel. Emissionsfrom rhefour boilers with a maximum of720 hours of burningfuel oilper 12-monthperiodare 4.48 

### ronsperyear PM Jo, 15.96 

### ronsperyearSOx, 18.98 

### ronsperyear NOx . 20.05 ronsperyear CO. anti 1.86 

### ronsperyear VOc. Low-NO x rechnology in conjuncrion wirh a 10% opaciry limiration anti rhe use of narural gas asprimaryfuel are consideredBesrAvailable Control Technology (BACT)for rhisprojecr. The Notice ofIntent for the above-referenced project has been evaluated and has been found to be consistent with the requirements ofthe Utah Air Conservation Rules (UACR) and the Utah Air Conservation Act. However, air pollution producing sources and/or their air control facilities may not be constructed, installed. established, or modified prior to the issuance of an Approval Order (AO) by the Executive Secretary ofthe Utah Air Quality Board. Unless you have comments which would require changes, the AO for this project will be based upon the following conditions: RECOMMENDED APPROVAL ORDER CONDITIONS General Conditions: 1. This AO applies to the following company: Depanmem OfThe Air Force OO-ALCIEM 7274 Wardleigh Road Hill Air Force Base, Utah 84056-5137 Phone Number: (801) 777-Q359 Fax Number: (801) 777-4306 The equipment listed below in this AO shall be operated at the following location: LOCATION UTM COORDINATES; Building 1590: 4.553.750 m. Northing; 415.290 m. Easting Building 1703: 4,554,870 m. Northing; 414.210 m. Easting 2. Definitions ofterms. abbreviations, and references used in this AO conform to those used in the UACR, Utah Administrative Codes (UAC), and Series 40 ofthe Code of 4.2.4-185DAQE-104-95 February 8, 1995 

### Page 3 Federal Regulations (40 CFR). These definitions take precedence unless specifically defined otherwise herein. 3. Hill Air Force Base shall install and operate the natural gas fired boiler according to the infonnation submined in the Notice ofIntent dated December 22, 1994. 4. A copy ofthis AO shall be posted on site. The AO shall be available to the employees who operate the air emission producing equipment. These employees shall receive instruction as to their responsibilities in operating the equipment according to all ofthe relevant conditions listed below. 5. The approved installations shall consist ofthe following equipment (MMBTUIHR stands for million BTUs per hour): A. Two boilers (rated at 27.60 MMBTUfHR) and associated equipment in Building 1590 B. Two boilers (rated at 11.25 MMBTU/HR) and associated equipment in Building 1703 Hill Air Force Base shall submit to the Division ofAir Quality (DAQ), the Manufacturer's name. Boiler's Model and Serial Number (or equivalent infonnation -., that will enable proper identification ofthe boilers), for each ofthe boilers approved by this Condition, before commencing the operation ofthe boilers. 6. Hill Air Force Base shall pennanentiy shut down the operation oftwo boilers in Building 1590 and two boilers in Building 1703 before commencing the operation of the boilers approved in Condition #5.
. 7. The Executive Secretary shall be notified in writing upon stan-up ofthe installation as an initial compliance inspection is required. Eighteen months from the date ofthis AO the Executive Secretary shall be notified in writing ofthe status of installation if construction/installation is not completed. At that time the Executive Secretary shall require documentation ofthe continuous installation ofthe operation and may revoke the AO in accordance with R307-1-3.1.5, UAC.

4.2.4-186

### DAQE-104-95 February 8, 1995 Page 4 Limitations and Tests Procedures 8. Emissions to the atmosphere from the stacks ofthe boilers approved in Condition #5 shall not exceed the following rates and concentrations (the lbslhr and ppmdv values are equivalent and the source has the option ofdemonstrating compliance with values in either ofthe units):
Source: Stacks ofBoilers in Building 1590 Pollutant lbslhr ppmdv (3 %O:!, dry) NOx 

# I 1.33 CO 

# I 1.21 

### 60 Source: Stacks ofBoilers in Building 1703 Pollutant lbslhr ppmdv (3% O:!, dry) NOx 0.54 CO 0.49 60 9. Stack testing to show compliance with the emission limitations stated in the above condition shall be performed as specified below for each ofthe boilers specified in Condition #5: 

### A. Emission Point Pollutant Testin2 

# :rm Frequency Boiler Stack**NO~** 

### * @ CO 

### * @ B. Testing Status (To be applied above) * No initial testing is required. However, the Executive Secretary 

### may require testing at any time in accordance with R307-1-3A.l, U AC. The source shall be tested if directed by the Executive Secretary. ** Initial compliance testing is required. The initial test date shall be within 180 days after the stan up ofa new emission source, or the granting ofthe AO for an existing emission source. @ Test ifdirected by the Executive Secretary. Tests may be required if the source is suspected to be in violation with other conditions ofthis AO.
4.2.4-187DAQE-104-95 February 8, 1995 Page 5 

### C. Notification The applicant shaH provide a notification ofthe test date at least 45 days before the test. A pretest conference shall be held ifdirected by the Executive Secretary. It shall be held at least 30 days before the test between the owner/operator. the tester, and the Executive Secretary. The emission point shall be designed to conform to the requirements of40 CFR 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. 

### D. Sample Location 40 CFR 60. Appendix A, Method 1 E. Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2 F. Nitrogen Oxides (NO.} 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D or 7E or an alternative method to be approved by the Executive Secretary. The test protocol shall be submitted for review at the time ofnotification ofthe test. G, Carbon Monoxide (CQ) 40 CFR 60, Appendix A, Method 10 H. Calculations To determine mass emission rates (lbslhr, 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 ofthe emission limitation. I. Source Operation The heat (gas) input rate during all compliance testing shall be no less than 90% ofthe rates listed in MMBTUIHR in Condition #5 ofthis AO. 10. Visible emissions from any point or fugitive emission source associated with the installation or control facilities shall not exceed 10% opacity. Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. Visible emissions from mobile sources and intermittent
4.2.4-188DAQE-104-95 February 8, 1995 Page 6
sources shall use procedures similar to Method 9. but the requirement for observations to be made at 15-second intervals over a six-minute period shall not apply. Any time interval with no visible emissions shall not be included. 11. The following consumption limits shall not be exceeded without prior approval in accordance with R307-1-3.1, UAC: For each boiler in building 1590 (rated at 27.6 MMBTUlhr): A. 242.000 decatherms (242 million cubic feet) ofnatural gas per 12-month period (1 decatherm = 1,000,000 BTU) B. 141,000 gallons offuel oil to be burned per 12-month period C. 720 hours ofoperation burning fuel oil per 12-month period For each boiler in building 1703 (rated at 11.25 MMBTUlhr): A. 98,550 decatherms (99 million cubic feet) of natural gas per l2-monm period B. 57.500 gallons offuel oil to be burned per 12-month period 

### C. 720 hours ofoperation burning fuel oil per 12-month period Compliance with me annual limitations shall be determined on a rolling 12-month total. Before the fifteenth day of each month, a new 12-month total shall be calculated using data from the previous 12 calendar months. Records ofoil consumption shall be kept for all periods when the plant is in operation. Records of oil consumption shall be made available to the Executive Secretary or his representative upon request. and shall include a period oftwo years ending with the date ofthe request. Consumption shall be determined by operating logs or vendor receipts. The records shall be kept on a daily basis. Hours ofoperation shall be determined by supervisor monitoring and maintaining ofan operations log.

12. The owner/operator shall use only natural gas or liquid petroleum gas as a primary fuel and #2 fuel oil or light grade as a backup fuel in the boiler. If any other fuel is to be used, an AD shall be required in accordance with R307-1-3.1. UAC. Number two (#2) fuel oil may be used only when natural gas supply has been interrupted. 13. The sulfur content of any fuel oil burned shall not exceed 0.5 percent by weight. Sulfur content shall be decided by ASTM Method D-4294-89. or approved equivalent. The sulfur content shall be tested ifdirected by the Executive Secretary.

4.2.4-189DAQE-104-95 February 8, 1995 Page 7 Federal Limitations and Requirements 14. In addition to the requirements ofthis AD. all provisions of40 CFR 60, NSPS SubpartS A and Dc. 4{) CFR 60.4{)c to 6O.48c (Standards ofPerfonnance for Small Industrial

- Commercial

- Institutional Steam Generating Units) apply to this installation. The owner or operator shall record and maintain records ofthe amount offuel combusted during each day. Each boiler must have an individual fuel use meter wbich cannot be reset, to detennine how much fuel that boiler used each day. Records & Miscellaneous 15. All records referenced in this AD or in an applicable new source perfonnance standard (NSPS), which are required to be kept by the owner/operator. shall be made available to the Executive Secretary or his representative upon**r~uest.** Examples of records to be kept at this source shall include the following as applicable: A. Fuel consumption 

### B. Test results 16. All installations and facilities authorized by this AD shall be**ad~uately** and properly maintained. All pollution control vendor recommended equipment shall be installed, maintained, and operated. Instructions from the vendor or established maintenance practices that maximize pollution control shall be used. All necessary equipment control and operating devices, such 

### as pressure gauges, amp meters, volt meters, flow rate indicators, temperature gauges, continuous emission monitors (CEMs), etc., shall be installed and operated properly and easily accessible to compliance inspectors. 17. The owner/operator shall comply with R307-1-3.5, UAC. This rule addresses emission inventory reponing requirements. 18. The owner/operator shall comply with R307-1-4.7, UAC. This rule addresses unavoidable breakdown reponing**r~uirements.** The owner/operator shall calculate/estimate the excess emissions whenever a breakdown occurs. The total of excess emissions shall be reponed to the Executive Secretary as directed for each calendar 

### year. 19. This source is required to pay an annual emission fee upon start-up. The fee will be based on calculated annual emissions listed at the end ofthis AD. This fee is valid until inventory data for one 

### year are available for the source. The owner or operator ofthis source will be billed upon stan-up for all emissions that are considered "chargeable" 

### as ofthat date.

4.2.4-190DAQE-104-95 February 8, 1995 Page 

### 8 Any future modifications to the equipment approved by this order must also be approved in accordance with R307-1-301.1, UACo 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 UACRo Annual emissions for this source (four boilers in Condition #5) are currently calculated at the following values: Pollutant 

### Tons/yr A. PMIO ' •••• 0 0 0 4.48 B.**SO~** 0 0 0 . o. 15.96 C. NOx ' . 0 . 0 . 0 0 18.98 D. CO 20.05
0 ••••• 0 •••••••• E. VOC
..... 0 1.86

••••••• 0 • These calculations are for the purposes ofdetermining the applicability ofprevention of significant**d~terioration** (PSD) and nonattainrnent area major source requirements ofthe UACR. They are not to be used for purposes ofdetermining compliance. In accordance with the requirements of Title V ofthe 1990 Clean Air Act, the following pollutants may be subject to an operating permit fee. Both the fees rate and the class ofpollutants are subject to change by State, the Federal agencies, or both. Pollutant 

### Tons/yr A. Particulate
.. 0 0 . 0 0 . 0 0 0 . 0
.. 4.48 B. S02 0 0 . 0 o. 15.96 C. NOx 0" 0 0 0 . 0 0 . o. 18.98 D. VOC , .. 0 0 0 . 0 0 0 . 1.86 Sincerely, 

# /r?**~"** /. .....me= I", ./ -' 1 .
. A.,< :...... 

# -'E5'n:R: Merilove, Manager New Source Review Section

4.2.4-191DAQE-I04-95 February 8, 1995 Page 9

Hill Air Force Base Construction of Two Boilers In Bldg 1590 an Two Boilers in Bldg. 1703)

P'iling Fee Review EngiIiBazrs @ S50.00/hr Modeler hours @ $50.00/hr Coaputer Fee Hotice To Paper Travel miles @ SO.23/mile S S $ $ $ S 1000.00 0.00* 0.00* 0.00* 0.00* 0.00 Total Charges 

## . 

# . . Aaount paid to Date S S 1000.00 0.00 

## -..

.

Balance Due
. . • . . S 1000.00

* These costs are included in the Filing P'ee. 

# Pl.... reait a copy of this iJlYOice with your**pa~t.** Please send payment to: Utah Division of Air Quality 150 North 1950 We.t Salt Lake City, utah 84114-8420 (801) 536-4000

4.2.4-192

### UTAH DIVISION OF AIR QUALITY NEW/MODIFIED SOURCE PLAN REVIEW W/Rdben.James 

### OO

..ALClEM 

### 727AWardleigb.R6ad**Hil~Air** .•**F(JrcellaSe;p~** 

## .••.**~4P??~5.137** RE: N4tice.cflritentto.ConstructTwo BOilersill Building 1.590 and
.

## Two Boiiers in BOOdingJ763
.. . .. . . . . ... .. . . .**Da~is** County, CDS B; NA; NSPS ENGINEER:**A.i.ffiri~am** DATE: NOTICE OF INTENT DATED:**D~mber·** 22,
...1994 PLANT CONTACT: Mr. Andreas Zekorn PHONE NUMBER: (8(l1)777-4)359 FAX NUMBER**(~PJ)7774306** PLANT LOCATION: Bui1<iing 1596 (2boilers)**andBuildingJ70~(2b<>il~rs),HillAirForceBase** UTM COORDINATES: lluildingJ590: 4;553;750 m; •**.Noithi~g;A15,2901ll;&StiDg** 

# JJMY8mg•.**!!q~:1,?5*,~(}..··m~~~~~tl~;.·114-~~1(}.~.~~Dg** FEES: Basic Approval Order Fee $1000.00 Review Engineer

- XXX)( total hours at $50.00lhour $000.00 Modeler

- XXXX hours at $50.00/hour $000.00 Notice To Paper
.. . . . . . . . . . . . . . . . . . . . . . . . . . . .. $000.00 Travel

- 00 miles at $0.23/mile
. . . . . . . . . . . . . . . . . . . .. $000.00 TOTAL .,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . $1000.00 APPROVALS: Review Engineer 

# &Q 

# ?/z

# /9 r**---::(S::-ig-na-I-tL-""re:....&7"'::D~a-te-)-----"1~-;7H-.-J+------------**

F:\AQ\ENGINEER

### \if.Rtti\t\WP\AO\HAFJ!;.li()I;a.p

4.2.4-193TYPE OF IMPACT AREA Attainment or Non-Attainment Non-Attainment Non-Attainment Pollutants
. . . . . . . PMlO SOx Ozone CO NSPS Applies yes NSPS Subpans A and Dc apply to this source NESHAP Applies no Toxic Pollutants no Toxic Major Source
. . . . . . . . . . . . . . . .. no 

### [> lO tpy of anyone Hazardous Air Pollutant(HAP) of 

### > 25 tpy of any combination of HAPs] New Major Source no Major Modification no PSD Permit
. , . . . . . . . . . . . . . no PSD Increment
. . . . . . . . . . . . . . . . no (modeling) Send to EPA no Operating Permits Program
. yes (NSPS applies) Title V Major Source
. . . . . . . . . . . . . . . . no Process Path
. Regular AO Processing EMISSIONS SUMMARY Total Emissions for 2 Boilers to be Installed in Building 1590. Each Rated at 27.6 :MMBTUfHR Pollutant rateCt,py) PM IO ••••••••• 3.18 S02
. . . . . . . .. 11.34 NOx 13.49 CO 14.24 VOC , 1.32

4.2.4-194Total Emissions for 2 Boilers to be Installed in Building 1590. Each Rated at 11.25 MMBTU/HR Pollutant rateCtpv) PM IO ••••••••• 1.30 

### 502 ..•.••.••• 4.62 NOx 5.50 CO 5.80 VOC 0.54 Total Emissions from this Project for the 4 Boilers Summarized in the Above Tables to be Installed in Buildings 1590 and 1703 Pollutant rateftpy) PM IO ••••••••• 4.48 S02
. . . . . . . .. 15.96 NOx 18.98 CO 20.05 VOC 1.86



# .­

4.2.4-195

### Abstract
This Review/Approval Order isfor the installation of two naJural gasfired, 10w-NOx , watertube, steam boilers rated at 27.6 

### MMBTU/HR in Building 1590 andthe installation of two natural gasfired, low NOx ,firetube steam boilers, ratedat 11.25 

### MMBTU/HR in Building 1703. These boilers would replace existing boilers in the buildings, which do not have 10w-NOx burners. This projectdoes not result in an increase in actual emissionsfrom the boilers and therefore, a 30-daypublic commentperiod is not requiredfor thisproject. Allthefour boilers are capable ofusing #2

### fuel oil as backupfuel. Emissionsfrom the four boilers with a maximum of720 hours ofburningfuel oilper 12-monthperiodare 4.48 tonsperyear PM ,07 

### 15.96 

### tonsperyear SOx, 18.98 

### tonsperyearNOx , 20.05 tons peryear CO, and 1.86 

### tonsperyear VOc. Low-NOxtechnology in conjunction with a 10% opacity limitation and the use of natural gas asprimaryfuel are considered**Be~t** 

### Available Control Technologyfor thisproject. 1. 

### DESCRIPTION A. This ReviewI

### Approval Order is for the installation oftwo natural gas-fired, low-NOx, 

### watertube, steam boilers rated at 27.6 :M:MBTU/HR 

### in Building 1590 and the installation of two natural gas-fired, low NOx, 

### frretube stearn boilers, rated at 11.25 :M:MBTU/HR in Building 1703. These boilers would replace existing boilers in the buildings, which do not have low-NOx 

### burners. Provisions are included for the use of fuel oil as a backup fuel. ..-., This will be limited in the Approval Order (AD) to less than 200 hours per year. B. The primary pollutants of concern are nitrogen oxides (NOx) 

### and carbon monoxide (CO). Nitrogen oxides are fonned at high temperatures when atmospheric nitrogen combines with atmQspheric oxygen. CO is a product of incomplete combustion due to a lack oxygen, low residence time, or poor mixing. II. BEST AVAILABLE CONTROL TECHNOLOGY (BACD ANALYSIS BACT for the boilers covered under this review (from previously established BACT guidelines, stated in the generic permit review for boilers) is determined to be: 1. An 

### opacity limitation of 10% shall apply to 

### the boiler stack.

4.2.4-196

### 2. The NOI states that the boilers can meet NOx 

### emission limit (concentration) of less than 40 ppm. which is as stringent as is required ofa 100 M:MBTU/HR boiler according to the following equation: 

### NO:< ppm 

### $( 

### 82. 105 -0. 4211 

### x( Boiler Rating )) where:NOx 

### ppm = 

### NOx 

### limitation corrected to 3% 

### Oxygen Boiler Rating = 

### Rating in 106 

### BTUIHR 3. Natural gas or Liquid Petroleum Gas (LPG) shall be used as the primary fuel. Number 2 fuel oil or cleaner fuel shall be used as a backup fuel. ill. 

### APPLICABILITY OF FEDERAL REGULAnONS A.l\ID 

### ITTAH AHMINISTRATIVE CODES WAC) This review is for a new minor source or minor modification. It is not a new major source or a major modification. The following federal regulations and state rules have been examined to detennine their applicability to this source category: 1. 

### R307-l-3.l, UAC

- Notice ofIntent required for a new source, modified source, or a new piece of control equipment. This rule applies. 2. R307-l-3.1.7 (A), UAC - A Notice ofIntent is not required for natural gas fuel burning equipment with a rated capacity of less than 5 x 106 

### BTU per hour. TIris rule does not apply because the boilers are rated at more than 5 I 

### \fMBTU/HR. 3. R307-l-3.1.8 (A), UAC

- Application of best available control technology (BACT) required at all emission points. TIris rule applies. 4. R307-l-3.1.8 (C), 

### UAC

- Approval of the UAQB is required before the Executive Secretary.can approve a source under Section 3.6.5 that consumes more than 50% 

### of a PSD increment. This rule does not apply because a PSD pennit is not being issued. 5. R307-1-3.1.8 (0), 

### UAC

- Enforceable offset of 1.2:1 required for new sources or modifications that would produce an emission increase greater than or equal to 50.00 tons per year of any combination of PMIQ, S02, and NO ' 

### This is x 

### required in Salt Lake, Davis, and Utah Counties and in any area that affects these three counties as defmed in the rule. The effective date is November 15, 1990. Offsets are not required because the four new boilers are going to 

### replace four existing boilers which have actually been emitting pollutants to the airshed. The new boilers would have 10w-NOx 

### technology, and therefore, they would emit less pollutants than the existing boilers.
4.2.4-197

### 6. R307-1-3.1.8 (D), UAC

- Enforceable offset of 1:1 required for new sources or modifications that would produce an emission increase greater than or equal to 25.00 tons per year but less than 50 tons per year of any combination of PM 10' 

### SO:!, and NO,. This is required in Salt Lake. Davis. and Utah Counties and in any area that affects these three counties as defmed in the rule. The effective date is November 15, 1990, Offsets are not required because the four new boilers are going to replace four existing boilers which have actually been emitting pollutants to the airshed. The new boilers would have low-NO, technology, and therefore, they would emit less pollutants than the existing boilers. 7. R307-1-3.1.9, UAC

- Rules for relocation of temporary sources. This source is a permanent source, Therefore, this rule does not apply. 8. R307-1-3.1.12, UAC

- Requirement for installation of low-NO, burners on all

. existing sources whenever existing fuel combustion burners are replaced,

unless the replacement is not physically practical or cost effective. The effective date is November 15, 1990. 

## If a Notice of Intent is receivedfor a replacement, the definition of Low-NO x is: limit[ppm] = 

### 82.1 - ( boiler rating[MMBnJ/HR] 

### * 0.421 ) where the limit is given in ppm corrected to 3

### % O2 and

### applies to 

### natural gas fired external combusn'on equipment rated at or below 100MMBTU/HR heat input. ,Th1S 

### NOI meets the requirements ofthis rule. The boilers would emit less 40 ppm NOr 9. R307-1-3.2.L UAC

- Particulate emission limitations for existing sources that are located in a nonattainment area. This rule has been superseded by the PM\o SIP, except for Weber County. The effective date is November 15, 1990. 

### This source is not in a non-attainment area for PMIO 

### and PM IO 

### is not a pollutant ofconcern for emissions from natural gas fired boilers. 10. R307-1-3.3.2, UAC

- Review requirements for new major sources or major modifications that are located in a nonattainment area or which impact a nonattainment area. This Notice ofIntent does not represent a new major source or a major modification. Therefore, this rule will not apply. 11. R307-1-3.5, UAC

- Emission inventory reporting requirements. This rule requires any source that emits 25 tons or more per year ofany pollutant to submit an emission inventory to the Division ofAir 

### Quality at least every third year or as determined necessary by the Executive Secretary.

4.2.4-198

### This rule applies to Hill Air Force Base as a pan of their annual emission inventory reponing requirements for major sources. The emissions from these boilers will be included as a pan of the base-wide emissions inventory. 12. R307-l-3.6.3, UAC

- PSD Increment Consumption

- This rule lists the allowable PSD increment consumption. Under the PSD rules. the entire state has been triggered for TSP,**SO~,** 

### and**NO~.** 

### The allowable increments are as follows: 

## TSP Three Hour 24 Hour Annual Class I Area 

### 10**~g/mJ** 

### 5**~g/mJ** 

### Class II Area 37**~g/mJ** 

### 19**~g/mJ SO~**  

### Class I Area 

### 25**~gimJ** 

### 5**~glmJ** 

### 2**~gimJ** 

### Class II Area 

### 5U**~g/mJ** 

### 91**~g/mJ** 

### 20**~g/mJ** 

### NOx 

### Class I Area 

### 2.5**~glmJ** 

### Class II Area 

### 25**~g/mJ**


### There are also Class III increments, which do not apply in Utah. The above increments apply at all locations, unless the area is already nonattainment. The entire increment may not be available at all locations due to previously permitted sources consuming increment. Modeling analysis is not routinely performed for air pollution sources with emissions below the following levels:

4.2.4-199

### Criteria for Screen Modeling (Tons per Year) Nonattainment Areas Attainment Areas TSP 10 10 PM 10 

### 5 5 SO:! 10 20 NOx 

### 20 20 CO 25 50 VOC 10 20 0 3 

### 5 5 Generic scenarios were modelled for the largest size (100 M}.1]3TU/HR) 

### using worst case assumptions for stack gas temperature, stack dimensions, and meteorology. No increment violations were shown to occur as a result ofthe addition of a boiler using Low NOx 

### technology. 13. R307-l-3.6.5 (b), 

### UAC

- Prevention of significant deterioration (PSD) review requirements for new major sources or major modifications. This Notice of Intent does not represent a new major source or a major modification under P5D rules. Therefore, this rule does not apply. 14. R307-l-3.6.6, UAC

- Increment violations. This rule requires the UAQB to promu:gate a plan and implement rules to eliminate any PSD increment violations that occur in ·the state. No known violation has yet occurred. A typical 100 MMBTU/HR 

### boiler was modelled for increment consumption. Any boiler rated at or less than 100 M:MBTU/HR 

### would not consume more than the following increment at the points ofmaximum impact: 

### A. TSP annual
. 0.09 j-Lg/m3 

### B. TSP 24 hr
. 

### 0.37 j-Lg/m3 

### C. 502 

### 3 hr
. 

### 0.04 j-Lg/m3 

### D. 

### 502 

### 24 hr
. 

### 0.02 j-Lg/m3 

### E. S02 annual 0.00 j-Lg/m3 

### F. NOx 

### annual 0.54 j-Lg/m3 

### 15. R307-l-3.8, UAC

- Stack height rule. This rule limits the creditable height of stacks to that height determined to be good engineering practice. The formulas used to 

### determine good engineering practice are found in 40 CFR 51.100. A deminimus height of 65 meters (213.2 feet) is allowed.

4.2.4-200

### 16. R307-l-3.11, UAC

- Visibility screening analysis requirements. This rule requires all new major sources or major modifications to 

### undergo a visibility screening analysis to determine visibility impact on any mandatory Class I area. 

### This review does not represent a new major source or a major modification under UACR rules. Therefore, this rule does not apply. 17. R307-1-4.1.2, UAC

- 20% opacity limitation at all emission points. Unless a more stringent limitation is required by New Source Performance Standards (NSPS) or BACT or National Emission Standards for Hazardous Air 

### Pollutants (NESHAPS). In this case, an opacity limitation of 10% is recommended as . BACT. 18. R307-l-4.1.9, UAC

- EPA Method 9 shall be used for visible emission observations. This rule applies. 19. R307-1-4.2.1. UAC

- Sulfur content limitations in oil and coal used for combustion. This source will be permined to 

### bum #2 fuel oil or lighter bener as a backup fuel. The limitation in the rule is 0.85 pounds of sulfur per 106 

### BTU heat input. 20. R307-l-4.6, UAC

- Continuous Emission Monitoring Systems Program

­ Reporting and technical requirements for continuous emission monitoring systems. It covers breakdowns and**quart~rly** 

### reports for continuous monitoring systems. Section 4.6.5 states that this regulation applies to the 

# .­ following: A. Sources required to install CEMS as required by the following documents: 1) NSPS 2) 

### State Implementation Plan 3) 

### Approval Order 4) 

### Consent Decree 5) Administrative Orders and Agreements B. 

### Any source that constructs after the promulgation ofthis rule, two or more emission points that may interfere with VEO's, shall install an opacity monitor on each stack. This source is not required to install CEMs. 21. R307-l-4.7, UAC

- Unavoidable breakdown reporting requirements. This rule applies. Section 4.7.1 discusses reporting requirements. A breakdown for any period longer than two hours must be reported to the Executive Secretary within three hours'ofthe beginning ofthe breakdown, if

### reasonabie, but in no case longer than 18 hours after the beginning ofthe breakdown. A wrinen 4.2.4-201

### report is required within seven calendar days. The report shall include the estimated quantity ofpollutants (total and excess). Section 4.7.2 discusses penalties. -

22. R307-1-4.9. UAC

- Review requirements for volatile organic compound (VOC) sources located in a nonattainment area for ozone constructed in 1980 or earlier. TIlls rule covers specific processes. Boilers are not covered in this rule. 23. R307-1-5, UAC

- Emergency episode requirements. TIlls rule requires the Executive Secretary to determine the stage and extent of an air 

### pollution episode based on pollution levels and meteorological conditions. Under section 40 ofthe Code of Federal Regulations. part 51, subparts 150 and 151, it is required that sources plan emergency measures based upon the severity of the Non-Attainment area in which they operate. In Utah, these rules require that CO sources in CO Non-Attainment areas and sources of Ozone precursors in Ozone Non-Attainment ares. who emit 25 tons per year or more, submit an Emergency Episode Plan which provides for additional pollution reductions in the event of an Air Pollution Alert, Warning or Emergency Episode. These plans can include total shut-down of the process. (Some sources are required to submit an emergency episode plan in the PM IO 

### SIP). HAFB is not located in a CO non-attainment area. For Ozone precursors, a basewide plan should be available/submitted. 24. New Source Performance Standards (NSPS)

- 40 CPR 60.40c to 60.48c, NSPS, Subpart Dc, Standards ofPerformance for Small IndustrialCommercial-Institutional Steam Generating Units

- The effective date is June 9, 1989. i\n 

### affected facility is each steam generating unit for which construction, modification, or reconstruction commenced after June 9, 1989 and that has a maximum design heat input capacity of 100 million BTU/hr or less, but greater than 10 million BTU/hr. The standards are as follows: Sulfur Dioxide If

### coal is the only fuel, no owner/operator shall cause to be discharged into the atmosphere any gases which: A. Contain SO: in excess of 10% ofthe potential SO: emission rate (90% reduction) B. 

### Contain S02 in excess of 1.

### 20 lb per million BTU heat input If

### oil is the only fuel, no owner/operator shall cause to be discharged into the atmosphere any gases which:

4.2.4-202A. Contain S02 in excess of 0.50 lb per million BTU heat input B. As an alternative

- No owner/operator shall combust oil that contains greater than 0.50% sulfur by weight. Percent reduction requirements are not applicable. This requirement applies. The S02 emission limits. fuel oil sulfur limits. and percent reduction requirements apply at 

### all times. including periods of start-up, shutdown. and malfunction. There is no limit for natural gas fIred boilers. Particulate Ifcoal is the only fuel (or coal with other fuels) and the heat input is 30 million BTU/hr or greater. no owner/operator shall cause to be discharged into the atmosphere any gases which: A. Contain TSP in excess of 0.05 lb per million BTU heat input (coal only or coal with other fuels) and has an annual capacity factor for the other fuels of 

### 10% or less B. Contain TSP in excess of 

### 0.10 Ib per million BTU heat input (coal only or coal with other fuels) and has an annual capacity factor for the other fuels of greater than 

### 10% and is subject to a federally enforceable requirement limiting operation to an annual capacity factor greater than 10% for fuels other than coal If wood is the only fuel (or wood with other fuels except coal) and the heat input is 30 million BTU/hr or greater. no owner/operator shall cause to be discharged into the atmosphere any gases which: A. Contain TSP in excess of

### 0.10 lb per million BTU heat input (wood only or wood with other fuels except coal) and has an annual capacity factor for wood greater than 30% B. Contain TSP in excess of

### 0.30 Ib per million BTU heat input (wood only or wood with other fuels except coal) and·has an annual capacity factor for wood of 30

### % or less and is subject to a federally enforceable requirement limiting operation to an annual capacity factor for wood of 30% or less Thereis no limitation for natural gas fIred equipment. Opacity
4.2.4-203

### No owner/operator that combusts coaL wood, or oil and has a heat input capacity of 30 million BTIJ/hr or greater shall cause to be discharged into the atmosphere any gases that exhibit 20% opacity or greater. except for one six minute period per hour of not more than 27% 

### opacity. The TSP and opacity standards apply at all times. except during periods of start-up, shutdown, and malfunction. There is no limitation for natural gas fired equipment. Testing (Methods are found in 40 

### CFR, Part 60, Appendix A ) If only coaL only oil. or a mixture ofcoal and oil is combusted, the procedures in Method 19 are used to determine the hourly SO: emission rate. For TSP, the following methods shall be used: Method 1 shall be used to select the sampling site and the number of sampling points. The sampling time for each run shall be at least 120 minutes and the minimum sampling volume shall be 60 dscf. Method 3 shall be used for gas analysis when applying Method 5, 5B, or 17. 

# - Method 5, 5B, or 17 shall be used as follows: A. Method 5 may be used only at facilities without wet scrubber systems. B. Method 17 may be used at facilities with or without wet scrubbers, provided the stack gas temperature does not exceed 320°F. C. Method 5B may be used in conjunction with a wet scrubber system. D. Method 9 shall be used for determining opacities. Monitoring The owner/operator ofan affected facility subject to 

### the S02 limits in 60.42c shall install and operate a CEM for measuring 502concentrations and either O2or CO2at the outlet ofthe S02 control device or at the stack outlet. The owner/operator ofan affected facility subject to the percent reduction requirements shall install and operate a CEM for measuring SO; concentrations and either O2or CO2 

### at both the inlet and outlet ofthe 502control device. The owner/operator of an affected facility combusting coal, residual oil, or wood that is subject to the opacity standards shall install and operate a CEM for measuring the opacity.
4.2.4-204",,-.. Record keeping requirements Natural gas-fIred boilers rated at or less than 100 :MMBTIJ/HR but more than 10 :MMBTIJ/HR have only one requirement under this NSPS. Subsection 60.48c contains the reporting and record keeping requirements for affected facilities. Paragraph g of this Subsection requires:

"(g) The owner or operator of each affected facility shall record and maintain records ofthe amount of fuel combusted during each day". Under this requirement "each boiler" must have an individual "fuel use meter" to determine how much fuel that boiler used each day to be in compliance with Paragraph (g). This requirement applies. 25. National Emission Standards for Hazardous Air Pollutants (NESHAPS)

­ There is no NESHAPS for this industrial process. 26. National Ambient Air Quality Standards (NAAQS)

- TIlis permit can be used throughout the state of Utah. Within the state, we have the following nonattainment areas: Salt Lake Countv, which is a nonattainrnent area for PM IO, S02, ozone, and CO (Salt Lake City only). Utah County, which is a nonanainment area for PM IO and CO (Provo City only). Davis County, which is a nonattainment area for PM 10 and ozone. Tooele County, which is a nonattainment area for S02 in the eastern mountains above 5600 feet. Weber County, which is a nonattainment area for CO (Ogden only). All other areas are in attainment for all pollutants.

4.2.4-205

# - This source has been modeled as a 100 M:MBTUIHR source for TSP. PM\o, S02, NOx, 

### ozone, CO. The scenario included 200 hours per year of#2 fuel oil combustion. The increases are listed below. Backgrounds are in addition to 

### these values. The results are as follows:

I 

### Pollutant Flow Rate (g/s) 

### Averaging Time Maximum Concentrati on (ug/m3) 

### NAAQS (y.g/m3) 

### Percent of NAAQS
PM 10 

### 0.288 24-HR 0.37 150 0.24 ANNUAL 

### 0.09 50 0.18**NO~** 

### 1.701 ANNUAL 

### 0.54 100 0.54**SO~** 

### 0.0126 3-HR 0.04 1300 0.00 24-HR 0.02 365 0.00 ANNUAL 

### 0.00 80 0.01 CO 1.281 1-HR 4.07 40000 0.01 8-HR 2.85 10000 0.03 VOC as 0 3 

### 0.0585 1-HR 0.19 235 0.08
For VOC emissions, there is no model that can predict an ozone impact directly from V0C emissions. However, since VOC are precursors to ozone fonnation, this new source will contribute to the existing exceedances ofthe ozone standard in Davis County. The amount ofthat contribution has not been decided. The ozone nonattainment area ofDavis and Salt Lake Counties must show reasonable funher progress toward attainment ofthe standard. This source, along with all 

### other VOC sources having emissions above ten tons per year, may have to apply more controls to lower the VOC emissions. This would be a SIP change action. 27. 40 CPR 60.14, DefInition ofModifIcation

- Any physical or operational change to an existing facility that results in an increase in the emission rate to 

### the atmosphere of any pollutant to 

### which an NSPS standard applies. The following are not by themselves considered modifIcations: 1) Maintenance, repair, and replacement 

### 2) An increase in production rate of an existing facility, if

### that increase


# - can be accomplished without a capital expenditure on that facility

4.2.4-206

### 3) An 

### increase in the hours of operation 4) Use of an alternate fuel or raw material if. 

### before the date any standard under this pan becomes applicable to 

### that source type, as provided by 60.1, the existing facility was designed to accommodate that alternative use 5) The addition or use ofany system or device whose primary function is the reduction of air 

### pollutants 6) Relocation or change in ownership Also see Section 1.92, which is the State's definition. It is a planned increase in emissions. This review might be used for modifications. The NOI does not represent a modification. 28. 40 CPR 60.15, Definition ofReconstruction

- the replacement ofcomponents of an existing facility to 

### such an extent that: 1) The fixed capital cost ofthe new components exceeds 50% 

### ofthe fixed capital cost that would be required to construct a comparable entirely new facility and 2) 

### It is technologically and economically feasible to meet the applicable standards set forth in this pan This review will**gen~ral1y** 

### not be used for a reconstruction, however, R307-l3.1.12, UAC, requires the installation of Low NOx 

### burners whenever burners are replaced. The NOI does not represent a reconstruction. However, the boilers will have Low NOx 

### burners installed. 29, R307-1-1, Defmition ofMajor Modification

- It 

### means any physical change in or changes in the method ofoperation of a major source that would result in a significant net emission increase of any pollutant. A net emissions increase that is' significant for VOC shall be considered significant for ozone. A physical change or change in 

### the method ofoperation shall not include: A. Routine maintenance, repair, or replacement B. Use ofan alternative fuel or raw material by reason of an order under Section 2a and b ofthe ESECA of 1974 or by reason of a natural gas curtailment plan pursuant to the Federal Power Act C. Use of alternative fuel by reason of an order under Section 125 of the CAA 

### 4.2.4-207

# - D. 

### Use of an alternative fuel at a steam generating unit to the extent that the fuel is generated from municipal solid waste E. Use of an alternative fuel or raw material by a source: 1) 

### which the source was capable of accommodating before January 6, 1975, unless such change would be prohibited under any enforceable permit condition 2) which the source is otherwise approved to use F. An 

### increase in the hours ofoperation or the production rate unless such change would be prohibited under any enforceable permit condition G. Any change in ownership at a source This rule does not apply.

4.2.4-208

### RECOMMENDED APPROVAL ORDER CONDmONS General Conditions: 

### 1. This Approval Order (AD) applies to 

### the following company:

The equipment listed below in 

### this AO shall be operated at the following. location: LOCATION UTM COORDINATES: 

### Buj.ldiI).gJ590;. 4,553)

### 750 mjN&rthirig;i**415~290m.EiStillg**

### ~~~14ingl,'79~:4,55~,87g111

## .•**:No~J.lg;41~~7.P}I1ljli#StP.1g** 2. DefInitions of tenns, abbreviations, and references used in 

### this AO confonn to those used in the Utah Air Conservation Rules (UACR), Utah Administrative Codes (UAC), and Series 40 of the Code of Federal Regulations (40 CFR). These defInitions take precedence unless specifically defmed otherwise herein. 3. 

### Hill Air Force Base shall install and operate the natural gas fIred boiler according to the infonnat.on submitted in 

### the Notice ofIntent dated December 22, 1994. 4. A copy of this Approval Order (AD) shall be posted on site. The AO shall be available to the employees who operate the air 

### emission producing equipment. These employees shall receive instruction as to their responsibilities in operating the equipment according to all of the relevant conditions listed below. 5. The approved installations shall consist ofthe following equipment (MMBTU/HR 

### stands for million BTUs per hour): 

### A. Two boilers (rated at 27.60 M1vffiTUIHR) and associated-equipment in 

### BU,ilding**~590;** B. 

### Two boilers (rated at 11.25 M:MBTU/HR) 

### and associated equipment in 

### Building 1703. Hill 

### Air Force Base shall submit to DAQ, the Manufacturer's Name, Boiler's Model and Serial Number (or equivalent information that will enable proper 4.2.4-209

# - identification ofthe boilers), for each ofthe boilers approved by this Condition, before commencing the operation of the boilers. 6. Hill Air 

### Force Base shall pennanently shut down the operation oftwo boilers in 

### Building 1590 and two boilers in Building 1703 before commencing the operation ofthe boilers approved in Condition #5. 7. The Executive Secretary shall be notified in writing upon start-up ofthe installation, as an initial compliance inspection is required. Eighteen months from the date ofthis Approval Order the Executive Secretary shall be notified in writing ofthe status of installation if

### constnlctioniinstallation is not completed. At that timethe Executive Secretary shall require documentation of the continuous installation ofthe operation and rnay revoke the Approval Order in accordance with R307-1-3.1.5, UAC. Limitations and tests procedures 

### 8. Emissions to the atmosphere from the stacks of the boilers approved in Condition #5 shall not exceed the following rates and concentrations (The lbs/hr and ppmdv values are equivalent and the source has the option of demonstrating compliance with values in either ofthe units):



# - I Source: Stacks ofBoilers in Building 1590 

# I Pollutant lbs/hr ppmdv (3 % 

### O:!, dry) NOx 1.33 40 

### CO 1.21 60 

## I Source: Stacks ofBoilers in Building 1703 

## I Pollutant lbs/hr ppmdv (3 % 

### 0c, dry) NOx 

### 0.54 40 CO 0.49 60

4.2.4-210

### 9. Stack testing to show compliance with the emission limitations stated in the above condition shall be perfonned as specified below for each ofthe boilers specified in Condition #5: A. Emission Point Pollutant Testing Test Status Frequencv Boiler Stack NOx 

### * @ 

### CO 

### * @ B. 

### Testing Status (To be applied above) No initial testing is required. However, the Executive Secretary 

### * may require testing at any time in accordance with R307-1­ 

### 3.4.1, UAC. The source shall be tested if

### directed by the Executive Secretary. 

### ** Initial compliance testing is required. The initial test date shall be within 180 days after the start up of a new emission source, or the granting of the Approval Order for an existing emission source. @ 

### Test if

### directed by the**~ecutive** 

### Secretary. Tests may be required ifthe source is suspected to be in violation with other conditions of this AO. C. Notification The applicant shall provide a notification ofthe test date at least 45 days before the test. A pretest conference shall be held if

### directed by the Executive Secretary. It shall be held at least 

### JO days before the test between the owner/operator, the tester, and the Executive Secretary. The emission point shall be designed to confonn to the requirements of40 CPR. 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
.. D. Sample Location 40 CFR 60. Appendix A, Method 1 E. Volumetric flow rate 40 CFR 60,-Appendix A, Method 2 F. Nitrogen oxides (NO.1 4.2.4-21I

# - 40 CPR 60, Appendix A, Method 7, 7A, 7B. 7C, 7D or 7E or an alternative methodto be approved by the Executive Secretary. The test protocol shall be submitted for review at the time of notification ofthe test. G. Carbon monoxide (CO) 40 CFR 60, Appendix A, Method 10 H. 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. 1. Source Operation The heat (gas) input rate during all compliance testing shall be no less than 90% of the rates listed in MMBTU/HR in Condition #5 ofthis AG. 10. Visible emissions from any point or fugitive emission source associated with the installation or control facilities shall not exceed 10% opacity. Opacity observations ofemissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. Visible emissions from mobile sources and intennittent sources shall use procedures similar to Method 9, but the requirement for observations to be made at l5-second intervals over a six-minute period shall not**app~y.** Any time interval with no visible emissions shall not be included. 11. The following consumption limits shall not be exceeded without prior approval in accordance with R307-1-3.1, UAC: Foreach boiler in building 1590 (rated at 27.6 MMBTU/hr): A. 242,000 decathenns (242 million cubic feet) ofnatural gas per 12­ month period (1 decathenn = 1,000,000 BTU) B. 141,000 gallons offuel oil to be burned per l2-month period C. 720 hours of operation burning fuel oil per l2-month period For each boiler in building 1703 (rated at 11.25 MMBTU/hr): A. 98,550 decatherms (99 million cubic feet) of natural gas per 12-month period B. 57,500 gallons offuel oil to be burned per 12-month period C. 720 hours of operation burning fuel oil per l2-month period
4.2.4-21

### Compliance with the annual limitations shall be detennined on a rolling 12­ month total. Before the flfteenth day of each month, a new 12-month total shall be calculated using data from the previous 12 calender months. Records ofoil consumption shall be kept for all periods when the plant is in operation. Records of oil consumption shall be made available to the Executive Secretary or hisrepresentative upon request and shall include a period oftwo years ending with the date ofthe request. Consumption shall be determined by operating logs or vendor receipts. The records shall be kept on a dailv basis. Hours of operation shall be detennined by supervisor monitoring and maintaining of an operations log.

12. The owner/operator shall use only natural gas or liquid petroleum gas as a primary fuel and #2 fuel oil or light grade as a backup fuel in the boiler. If 

### any other fuel is to be used, an Approval Order shall be required in accordance with R307-1-3.L UAC. Number two (#2) fuel oil may be used only when natural gas supply has been interrupted. 13. The sulfur content of any fuel oil burned shall not exceed 0.5 percent by weight. Sulfur content shall be decided by ASTM Method D-4294-89, or approved equivalent. The sulfur content shall be tested if

### directed by the Executive Secretary.



# - Federal Limitations and Reguirements 14. In addition to the requirements ofthis Approval Order, all provisions of40 CFR 60, NSPS Subpans A and Dc, 40 CFR 60.40c to 60.48c (Standards of Performance for Small Industrial

- Commercial

- Institutional Steam Generating Units) apply to this"installation. The owner or operator shall record and maintain records of the amount offuel combusted during each day. Each boiler must have an individual fuel use meter which cannot be reset, to determine how much fuel that boiler used each day.**Recor~ &~cellaneous**  

### 15. All records referenced in 

### this Approval Order or in an applicable NSPS, which are required to be kept by the owner/operator, shall be made available to the

. . * 

### ExecutIve Secretary or his representative upon request. Examples of records to be kept at this source shall include the following as applicable: A. Fuel consumption

4.2.4-213B. Test results 16. All installations and facilities authorized by this Approval Order shall be adequately and properly maintained. All pollution control vendor recommended equipment shall be installed, maintained, and operated. Instructions from the vendor or established maintenance practices that maximize pollution control shall be used. All necessary equipment control and operating devices, such as; pressure gauges, amp meters, volt meters, flow rate indicators, temperature gauges, CEMs, etc., shall be installed and operated properly and easily accessible to compliance inspectors. 17. The owner/operator shall comply with R307-1-3.5, UAC. This rule addresses emission inventory reporting requirements. 18. The owner/ operator shall comply with R307-1-4.7, UAC. This rule addresses unavoidable breakdown reporting requirements. The owner/operator shall calculate/estimate the excess emissions whenever a breakdown occurs. The total ofexcess emissions shall be reported to the Executive Secretary as directed for each calendar year. 19. This source is required to pay an annual emission fee upon stan-up. The fee will be based on calculated annual emissions listed at the end of this Approval Order. This fee is valid until inventory data for one year are available for the source. The owner or operator ofthis source 

### will be billed upon stan-up for all emissions that are considered "chargeable" as ofthat date. Any future modifications to the equipment approved by this order must also be appro"
. in accordance with R307-1-3.1.1, 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**~·tah** Air Conservation Rules. Annual emissions for this source (four boilers in Condition #5) are currently calculated at the following values: Pollutant tons/vr 

### A. PM IO • • • • • • • • • • •• 4.48 B. SOz.
. . . . . . 15.96 C. NOx 18.98 D. CO..
. . . . .20.05 

### E. VOC·.
. . . . . . . . . .. 1.86 

# -

4.2.4-214

### These calculations are for the purposes ofdetennining the applicability ofPSD and nonattainrnent area major source requirements ofthe UACR. They are not to be used for purposes ofdetennining compliance. In accordance with the requirements ofTitle V ofthe 1990 Clean Air 

### Act, the following pollutants may be subject to an operating pennit fee. Both the fees rate and the class of pollutants are subject to change by State, the Federal agencies. orboth.
Pollutant tons/yr F. Particulate.
. . . . . . . . . . . . . . . .. 4.48 G. S02' , 

### 15.96 H. NOx . . . . . . . . 

### 18.98 1. 

### VOC.
. . . . . . . . . . . . . . . . . . .. 1.86



### " 4.2.4-215""_0. _., .... ''''_I'li'"-I'lr

......**11~.,~~"1** ,u :i5364e99 P.lal 

# }**CF~** COYfR

# SHE~ECEIVED JAN 3 11995**/~**



## (Date:31Jan

# 95 ) 

# (Message:) From: Air Quality AndreasZekom EnTironmentalManagementDirectorate Oo-ALCIEME 1274WardleighRoad H1IlAFB,UT 84056.5137 Tel: Cormnercial801.777-o3S9 DSN 458-0359 Fax:Commerci:dS01·777-4306 

# To: Name: Arjun 

### Ram Organization: DivisionofAirQuality 

## Fax No.: 

## (801) 536-4099 Hi 

### Arjun I 

### Here are the calculationforthe 

### boilers inBUilding 1590and BUilding 1703. We have an decrease in emissions for the

### boilers in

### Building 1703 and almostthe same emissions inBuilding 1590 so that 

### we have over all 

### adecrease in

### emissions for this NOr.

# ~~ /' -I" : 

### ANDREAS ZEKO I



### Total numberofpages including

### coversheet: 

# S 4.2.4-216 !.., ... , ..,...,. .__ • 1
..._1' _.'
..... 1
..._;'\0._10 •••_ '''''''' ''1

I I I , : i ,

### ~·IB"!l1~.· I I I Heatinput 27.600.000.00 BTlTlhr Operating Hours 8760 hrJyr EmissionFactors

I AP-42 Table 1.4-1

- 1.4-3iLowNOx Burner i 

### Natural Gas I 

## PM SOx NOx 

### CO HC

I Industrial 13.7 0.6 81.0 61.0 2.8 I I Emission faetors inIbsllO"ls cu ft ! I Calc:ulatioD

, Coasumption/hr 

## i 27600 SCFIhr Consumptionlyr 241,776.000 SCFlyr I 

## i I Emjssigg.4l I 

### i NahlJ]l 

### emIndustrial Boiler PM SOx NOx 

## co HC Iblyr 3312.3 145.1 19583.9 14748.3 673.1 tonslyr 

# 166 0.07 9.79 737 " 034 No,; EmbsigDs 

### ! Limit 40 ppm Operation 8760 hr Conversionppm-IbIMMB1U 0.048 IblMMBTU CaleulaticmIbt1:ar 1.065 Iblbr
:1 CaleulationIbIyr 9332.7 lblyr Calculationtonslyr 

### I**4~6~** .tonsIyr

.. I Iota! emissions 

### from bothboilers 

## i PM I 6624.71blyr I 3.31 tonslyr +-1**·~4** • SOlt I 290.1 Ib/yr 0.15 tonslyr NOx 118665.5 lWYT 9.33 toDsIyr - ·l7 CO 

## i 29496.7 Ib1yr 14.75 toIWyr -+- 

### 5'.56 He 

## I 1346.2 Iblyr 0.67 toosIyr 

### -tJ-

### 53+- <:;-::>? '-:"-V'N ; : • Nj" :-<.**.~~L.:** 

## i

. . . ., I**~.** 2 J.•,:; '.J .• IV..L ,"') '1"**'-./~;..-L.A.** .... J,' ' I 

### i 4.2.4-2I 7,_"

_ ........ -_ .... _. " •. _ ... "" '

__' ._. '\ I 

# - Heatinpu[ Operating Hours I 16,45<4000.00 BnJlhr
I 8760 hrJyr Emission

### Facton AP42Table 1.4-1

- 1.4-3Low NOx Burner 

### Namral Gas Industrial 

## p¥ 13.7 SOx 0.6 NOx .140.0 CO 61.0 

## He 2.8 Emission factors in Ibs/l0"6cuft CalmJptioo Consumptionlbr Consumptionlyr , 16450 SCFIhr
, 144,102.000 SCF/yr

Natunl

## em IndustrialBgUer**p~** SOX NOx CO 

## He ( .·lblyr 1974.2 86.S 20J74.3 8790.2 401.2

toD5Jyr**O.~** 0.04 1.0.09 4.40 0.20 I NO;Emjuions Limit 40 ppm Operation 8760 br Conversionppm-IblMMBnJ 0.0481bIMMBTIJ**Cal~on** JbIbr 0.635 Iblbr CalcaJation IbIyr 5562.4 Ibtyr Calculation toasIyr J 2.78 tonslyr "
Total emiMjon,from bothbgUm 3948.4 Ib1yr 1.97 torJSIyr SOx PM 172.91b/yr 0.09 tODSI)T NOx 11124.9 Ib1yr $.56 toDSlyr CO ; 17S80.4 Ib1yr**8.79~** He 802.4IbIyr**0.40~**

4.2.4-218oJ"" -'-'''';**(.,I~......** 

# ,**I"'~** I**~,'W"** .1
......... ",**~'l** n ..... I**I""n~ ~I'"**  I 'u

Hearinpul 11.250l5OO.oo BnJlbr OpenbngHours II 8760 hr/yr
I . I I I I EmissioaFacton AP-42Table 1.4-1

- 1.4-3Low NOx Burner I I NAtUral Gas I 

## PM SOx NOx 

### CO 

## He Industrial. 

# d.7 0.6 81.0 61.0 2.8 I Emissionfactors inIbs/l0"-6 en ft I CalculatioD Consumptiontbr 

# i11250.5 SCFJhr Consumptionlyr 98,.554,380 SCF/yr I '

r 

### Emissions I Namral GasIndustrial

# BOilL PM SOX NOx 

## co HC

I Iblyr 13'0.2 59.1 7982.9 , 6011.8 274.4 I lOnslyr 

# O'r 0.03 3.99 3.01 0.14 NOX [mls:siODs 

## I 1 I Limit 40 ppm 8760 hr 

## I
r r Conversionppm-lblMMBTU 0.048 IbIMM:BTU CalculationJbIbr I 0.4341blhr Ca1culation lbIyr I 3804.3 Iblyr Calculationtonslyr 1.90 tons/yr f I Total emig;ions

### fmm both PM 2700.4 Ib/yr 1.3S tonslyr SOx 118.3 Iblyr 0.06 IOnslyr NOx 7608.5 Iblyr 3.80 tonsI)T CO 12023.6 Iblyr 6.01 tenWyr 

### He 548.81blyr 0.27 lODSIyr

4.2.4-219

# ----"""""""-­

, ,

# :B,M~ IBmmI¢mg

# J1'~l(o)llil;~

, Heatinput OperatingHours EmissionFactors 10.251.000 BnJlbr 

## ! 8760 br/yr I ,
AP-42 Table 1.4-1

- 1.4-3

## Low NOx Burner NaturalGas 

# I SOx NOx 

### CO 

## He Industrial 13L1 I I Emissionfactors inIbsll0"6cu ft 0.6**.~40.0 (@:"~**  ./-' 2.8

I 

## i Consumption/br Consumptionlyr I I , 

### I 10257 SCFJhr 89,851.320 SCPIyr

, , I E.mjWgns 

## i I I Hamra! GM Indu!tttia! BoHCt 

# -
lblyr tDDSIyr 

# mn Emissions 

# P¥**l~l.O** 0.62

I 

### I I SOX 53.9 0.03 NOx 12579.2

;6.29 

### CO 5430.9



## r - ,



# .. HC 250.1 0.13



### 40 ppm Limit 

# I I i Conversionppm-lblMMB'TIJ CalculationlbIhr , i c.IculalionIb1yr I 

### ! CalculationtonsIyr I I I I Igr.aI

### emissions

### frnm bptb bpilers ! . Operation 0.0481blMMBnJ 0.3961blhr 3468.3 Iblyr 1.73 tcnYyr 8760 hr

PM SOX NOx 

### CO 

## He 2-161.9 Ib1yr 107.81b/yr 6936.7 lbIyr 

### !10961.9 Iblyr SOO.3 Ibiyr 1.23 tonslyr O.OS tons!yr 3.47 toDSiyr 5.48 tonslyr 0.25 toDsIyr

4.2.4-220

# RECEIVED DEPARTMENT OFTHE AIR FORCE 

## DEC 2 71994 HEADQUARTERS OGDEN AIR LOGISTICS CENTER (AFMC) HILL AIR FORCE BASE. UTAH 

# Air 

# Quality 22 Dec 1994

QO-ALCIEM 7274Wardleigh Road 

### Hill AFB UT 84056-5137 

### Mr. Russell A. Robens State ofUtah DivisionofAirQuality P.O. Box 144820 SaltLakeCity Ut 84114-4820
Re: Notice ofIntenttoconstructtwo replacementboilers in Building 1590 and two replacementboilers in Building1703
Dear

### Mr. Robens We submitthis Notice ofIntent to receive approval to begin construction oftwo replacement boilers in Building 1590 and two replacementboilers in Building 1703.



### - Description Building 1590 Twoofthe four existingboilers inBuilding 1590with AQillS numbers 3524 and 3525 are tobereplacedby two Low NOx Watenube SteamBoilers with a maximum steam capacity of23,000lbs/hreach. This convens to 27.6 MMBTUboilerheat input. ConversionIb steamlhrto BTU/hr 23000 lb/hr x 1.2 x 103 

### = 27,600,000 BTU/hr • •conversion factor according to AP42 Appendix A Bothboilers run primarily with natural gas with#2 fuel oil as abackup fuel. Each boiler is connectedto a stack 

### as shown in Atch. 1. Building 1703 Twoexistingboilers in Building 1703 are to be replaced with two Low NOxWetbackFire Tube Boilers with a steamcapacity of 8625 Ibs/hr or acapacity of250 hp
. 

## • Conversion hp to BTU/hr 250 hp x 45000 BTUIhp hr

### = 11,250,500 BTU/hr· •conversion factor accordingto AP42 Appendix A Bothboilers run primarily with natural gas with#2 fuel oil as abackup fuel. Eachboiler is connectedto a stack 

### as shown in Atch. 2.

4.2.4-221

### Emissions AP42 Emission factors for natural gas combustion (Table 1.4-1 to 1.4-3) (TTNBulletinboard AP42) Emission factors (Low NOx Burner)

- __**.:~** Filterable PM 6.2 1 b/106 fe - Condensible PM 7.5 Ib/l06 fe " Sulfurdioxide 0.6 1b/l06 ft3 Nitrogen oxides 811b/106 ft3 , Carbonmonoxide 61 Ib/106 ft3 Total Organic Compounds 5.8 Ib/106 ft3 /' Total Particulate is the sumofthe filterable PM andcondensible PM. All PMemissions can be assumedto belessthan 10 microns. Methane comprises 52 percent oforganic compounds. TheNonMethane VOC emission factor is: 2.784 Emissions for the boilers are calculated as follows: Heatinput IDIV thennal operating emission emissions natural gas effiency hours factors BTU/hr x 111000 SCFIBTU x 0.80 x 8760 hrs/yr x Ib/SCF = lb/yr Airemissions from two replacementboilers in Building 1590 are each: 

### Particulate 3312.31b/yrv Sulfurdioxide 145.1 Ib/yr ­ Carbonmonoxide 14748.3 lb/yr ­ VOC Nonmethane 673.1 Ib/yr

­ 

# - As a Low NOx Burneris to beinstalled. the emission limit is 40ppm NOx (correctedto 3% Oxygen). Thecalculations for NOxare as follows:
• Conversionppmto 1bIMMBTU 40ppm/ 829 

### =0.048 IblMMBTU I Calculation ofhourlv emissions:

- ­ 0.048 IblMMBTU

# *27.6 MMBTUIhr 

### * 0.80 3) 

### = 1.065 Ib/hr 3'rhennaleffiency is 80 

### % Potential to emitfor NOxis: /L..' ,r_' 1.0651blhr 

### * 8760hr/yr 

# =9332.7 Ib/yr " --< "c

- .' t • 

### =4.67 tons/yr , J Total emissions from both boilers in Building 1590are: 

### Particulate 6624.71b/yr

- 3.31 tons/yr ," Sulfurdioxide 290.1lb/yr 0.15 tons/yr Carbonmonoxide 29496.71b/yr- 14.75 tons/yr' VOCNonmethane 1346.2 1b/yr ' 0.67 tons/yr-- NOx 18665.4 Ib/yr 9-:33_tons/yr ,:..;' :.,-:t .**~"";,...,;)J"** With installatiOD...oftwoLow NOx burners in Building 1590 we will reduce NOx emissions by 53%. Building 1703 Emission factors and calculation methods are the same as for Building 1590. 42.4-2220.048 lblMMBTU 

## * 11.3 MMBTU/hr

## * 0.80

# =0.434 lb/hr Bothboilers in Building 1703 will run 8760 hr/yr. 0.434lb/hr 

## * 8760 hr/yr 

## =3801.1 lb/yr = 1.90 tons/yr Total emissions from bothboilers in Building 1703 are: Particulate 2700.4 lb/yr./ 1.35 tons/yr/ Sulfurdioxide 118.3 lb/vr " 0.06 tons/yr Carbonmonoxide 12023.6 ib/yr / 6.01 tons/yr.· VOCNonmethane 548.8 lb/yr­ 0.27 tons/yr/ NOx 16O&5lb/yr**3~tons/yr** .:0-,.1. -r -:..I**~_** I _ -' Withinstallation oftwo Low NOxburners in Building 1703 we will reduce NOx emissions by 70%. 

### Air cleaning devices No additional aircleaning devices will be installed. 

### Location UTMcoordinates are not available for Building 1590 and 1703. Longitudeandlatitude for the Buildings are: Building 1590 Building 1703 Longitude 112:00:32.38 112:01:19.66 Latitude 41:07:55.70 41:08:31.87 .'-/

. ....**..:,~:.:.~/** ..**~5'fJ ~IS-,Z.:.!:.:**  4$ ':"

.. :. l..')
. N .1**).'~** . ­ ,.",,-,. 

### Operating Schedule Bothboilers in Building 1703 will run 8760hours peryear. Thetwo boilers in Building 1590 willbe shut down in summer. 

### Construction Schedule Theconstructionis scheduledfor all boilers as follows: Startconstruction: February 1995 Endconstruction: October 1995 Startupboiler:
. October 1995 Ifyou have any questions, please call

### Mr. Andreas Zekorn at 777-0359. Sincerely

# ,14j)~

# ~:B;iT JAMES Acting DirectorofEnvironmentalManagement Attachments: 1. PlanofboilerinBldg 1590 2. Planofboilers inBldg 1703 4.2.4-223w , I'**L~** .;> 

# . \ FEED PIPING 

# . o o 

### 0 

### I 

# { I I r-(El CHEMICAL 

# (**Illc~** 

# 2 ,(E I BOILER FEED PUMPS IN BASEMENT---1 FEEDER I. 

## r=t==t=f HIX 

# 1° TANK I POT O.C. TO IE 1--.......... I 

### 1f or 

### T "IT II 

## V

, FOS &

............ - r" 

# I

# IrfG '

.. " FOR -u" u .......... ;)..... 

# I NEil CONDENSATE SURGE TANK

## VI RECONNEC '\ l'oo.. G " _., " \ 12"¢ x 11'-0" I (1000 GAV' J

### lA' TANK LEV Ul I

### ~~ SAFETY --oF

### ~BOILERFEErfVALVING 

# I I:> 

# r,,1--r1 .-**~,-'** 

# .-,:>\ (EJPIPI 

### II 

# 1/1 VALVE Ii). I TYP RnTH BQl.LERS I - 

## Ig 'I I P-2" -. : 1 1 ) 

# II TVP -......

### (~~ )...-, 

### 1 1 1 1 _1_
_ _ f-

### _~ L - L - CONNECT TO

### Ul '\ 11 17\ 

# I**~f** ITE 

### I -.., 

# I CONDENSATE "0 250H,P.150PSI\..!.; CLASS 3/1--
__ STEAM BOILER**~~** 

### I CONNECT NE 6" CONNECTION............ 1"

# ~~ (8625 LB/HR J 17 

## lo- TUBE REHOVAL LINE TO, (e: (E J 6" STEAM 

### I'--- 

# I l - __ ,., f- - -- - -- -

### (~ - f-f- - I- REA 

# I lP-1.1/2" .--- LINE UN N ""l 

### 'r!-./ IL ,- .... TANK (Pl.",.' P '-r'L.J ,) VTR DEAERATOR I I

.... t 

### I,..... IL ," 1 

# I 13 "t-' 

# r '1"

# /~ 

# 1 3

# ~E> V1R NEW DEAERA U- ,1./ /.;'
_ I--

_ DRAINER. P 1

# =**--FO~** f"OR- _OS_ I

## OE"AE~ bF1E> J IN BASEMEN 3"

### ~/1" VTR, 

# I BRINE '" :8 PLANT 1 

## :::c=J**~E** A I It- 

# i-<: 0) G_ THill ( E) HOTOR 

## '-.....-./' GE - 17---.: 

# -l.... I " I'

. ) CONTROL CE

## 'l.ll' 

# I
IL

## ~F CFr 

# t**~ ~** \I '\ I 

## r AIR COMPRESSOR l E-ALK. I-- -, 

# I 

# t l, ,(TYP. BOTH BOIL Sl\"

## ~3/1" \ 

# I I n**~-~)-,I** I 

# 1 \ -t------­ 20"

## STA~K**~~~** CONNECT 3/""
. (E) EXISTING 

# Ii / I

# ~I I TYP. (2 I t- 1_ CHEMICAL FEED LINE HE)

# ~- TO BOILER FEEDIIATER

# ~1 f\ I 6" CONNECTION

# ~I**---..~** CONNECTION (BOTH BOILERS I

# l~ TUBE REMOVAL 

# I 1 (E) 6" STEAM

### l~ ., - ---0-0--

- - - -- - (...-

-

### -~ - I- REA 

# I 

# I H. P. 

## N "" 

## Yj:J 17\ 250 150 PSI 

## 17 r-.:@E) ,a: I

.... tlJ , \..!.; STEAM BOILER I 1 OFT. 

# I

.. ,,... (8625 LB/HR I 

# +- I' /1" I l _

### ~OS D as - - - - - I 

# @ '<:t 0 , N ,L:

__ - -

## -TO~ - - -

## ~' IE> I J/""/ 3" OFT. N P.O.C. TO (E I

- G 0 G- '<:t I 3" GAS LINE "', 

### ,-< 

# T NATURAL GAS

# =**'~6' ~OCATEO**  J.) I N GA FUEL TRAIN (TY

. OIL PUMP

### A~D I '<:t S FLOW METER I" BOTH BOILERS J .

...... HEATERS. I YP. 

# @ I BOTH BOlLE S l.

## B~~~E 1 • 1'-( E I FLOOR DRAINI \ TANK I C) \ • 

### 1 (TVP. -2 I 

## I c---- 

## 'I 

# mu: I

{ II ,II I-/7'" '1(/ 

## I

: CSl I
. !Xl

"'" PIPE MANlfO:"O l"TO 3/"'" FROM \,lATER LEVEL SENSOR FOR FEEOVATER REGULATOR**~-------** AUXILIARY LOV \,lATER CUTOFF ...--------\,IATER LEVEL GAUGE GLASS 

# I: \,IATER COLUMN \,lITH PROBES FORCED DRAFT fAN------, STEAM DRUM

STEAM PRESSURE_ - _ _ _ _ _ _ _ GAUGE I (0-300 I PSIG)



### • 

# \

I L t> t>.**~t>** . . \;>
.. t>
. II'

.. II' to \;>.• t>..

. \>' '7' II' .t>

4.2.4-225 

# BOILER ELEVATION