,,",-..,-, (""" : ;

......... ..L- I -."- ..-.. .,.......,**:~~ T,;::~** **"~-,** 

## P 

# n ':­

....... . 

### 'H,':-ilJ .:.a 0:-;.: ., 

# . J
... .. 

### DEPARTME!\T OF Ei\VIRO:\:,:E;\,TAL QUALITY . 

### DIVISION OF AIR QUALITY
Michael O. Leavitt 150 NOM 1950 West o-n.or P.O. Box 144820 Dianne R. Nielson. Ph.D. SaIL Lake CiLy, ULah 84114-4820 Eu.cuIM DirecIDr (801) 536-4000 RUSRlI A. Roberts (801) 536-4099 Fax DirecIDr (801) 538-4414 T.D.D. 

### DAQE-824-94 September 29, 1994

James R. Van Orman Hill Air Force Base Headquarters Ogden Air Logistics Center Dept. of the Air Force Hill Air Force Base, Utah 84056 Re: Approval Order For Used Oil Burner/Boiler Permit Modification Davis County CDS B NA Dear Mr. Van Orman: 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.

RIA. Roberts, Executive Secretary Utah Air Quality Board RAR:AR:dn
cc: Davis County Health Department Mike Owens, EPA Region VIII Cheryl Prawl, Solid & 

### Hazardous Waste

4.2.4-434

Printed on recvc!ed paper

# STATE OF UTAH Department of Environmental Quality Division of Air 

# Quality APPROVAL ORDER FOR USED OIL BURNER/BOILER PERMIT MODIFICATION Prepared By: Arjun Ram, Engineering Technician Reviewed By: Dale Chapman, Engineer



## APPROVAL ORDER NU1\ffiER DAQE-824-94 Date: September 29, 1994 Source 

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

4.2.4-435

### DAQE-824-94 September 29, 1994 Page 2 Abstract Your request dated July 18, 1994, to change Approval Order rAO) DAQE-501-92. has been reviewed. The increasefor NO. emissionsfrom the approved used oil boiler while burning used oil is approved. The emissions were changed from 110ppmv as stated in the original NO! to 

### 240ppmv. The AO has been modified to reflect the requested change (Reference conditions #5for the changes). 

### This 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 AO retlect 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 ofthe cunditions may constitute a violation of this order. 1. 

### Hill Air Force Base shall install and operate the used oil fired boiler rated at 20.9 million BTU/hr in Building 1703 according to 

### the information submitted in the Notice of Intent dated March 27, 1990, with additional information submined dated October 31, 1990, and requests for modifications dated May 13, 1992, and July 18, 1994. This AO shall replace the AO DAQE-501-92, dated May 26, 1992. The boiler shall be a dual-fuel boiler with the capability of burning used oil. 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 compl iance with the appropriate and relevant conditions. 2. The approved installation shall consist of the following equipment: A. 500 hp Scotch Marine 3 Pass Boiler or equivalent. complete with dual (natural gas and used oil) burner

- Equivalency shall be determined by the Executive Secretary. B. Oil tiltration system C. 

### Associated piping. control. and alarms, chemical feed pump. chemical mixing tank, and appropriate tie-ins to 

### existing feed water and natural gas line systems 3. Visible emissions from the boiler shall not exceed 20% ooacitv. Opacity observation of emissions from stationary sources shal I 

### be conducted in accordance with 40 CFR 60, Appendix A, Method 9. 4. The following fuel consumption limits tor the boiler shall not be exceeded without prior approval in accordance with R307-1-3.1. UAC: 

### A. Used oil consumption

- 100,000 gallons**p~r** 

### 12-month period 

# -­ B. 

### Natural gas consumption

- 166.89 x 100 

### scf per 12-month period 4.2.4-436

### DAQE-824-94 September 29, 1994 Page 3 Compliance with the annual limitations shall**b~** 

### determined on a rolling 12-month total. Based on the first day of each month. a 

### new l2-momh total shall be calculated using the previous 12 months. Records 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 or his representative upon request. and shall include a period of two years ending with the date of the request. Natural gas fuel consumption shall be determined by examination of records from a fuel meter. Used oil consumption for the boiler shall be determined by examination of records from the used oil transfer log. The records shall be kept on a daily basis. 5. 

### Emissions to the atmosphere from the used oil boiler operating with 

### used oil shall not exceed the following rates and concentrations: A.**SO~** 

### I) 10.3 Ihs/hr 2) 

### 270 ppmdv (7% 

### oxygen, dry) B. 

### NO, 1) 

### 6.62 Ibs/hr 

### 2) 240 ppmdv (7% 

### oxygen. dry) 6. Stack testing to show compliance with the emission limitations in condition #5 operating with used oil shall be performed for the following emission points and air contaminants, as determined by the following test methods in accordance with 40 CFR 60. Appendix A, and as directed by the Executive Secretary: Pollutant Method First test 6 

### No later than Every 180 days 5 years after start-up 7 

### No later than Every 180 days 5 years after start-up Notification The applicant shall provide a notification ofthe test date at least 45 days prior to 

### the test. A pretest conference shall be held ifdirected 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) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. 

### 4.2.4-437-**'_~:::-~-;-** -9.1 

### September 29, 1994 Page 4 Sample location 40 CFR 60, Appendix A, Method 1, if required by test method use{! Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2, if require{! by test method use{! Calculations To determine mass emission rates (Ibslhr, etc.), the pollutant concentration as determine{! 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 I

### imitation. 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 at which the facility will be operated. 7. 

### The ash content of any used oil burned shall not excee{! 0.65 percent hv weight without prior approval in accordance with R307-1-3.1, UAC. The ash content shall be tested using the appropriate ASTM method if directed by the Executive Secretary. 8. 

### Used oil may be used for fuel, except that oil which contains more than 1000 ppm by weight oftotal halogen shall be considered hazardous and shall be treate{! as a hazardous waste and shall not be burned in the boiler. The halogen content shall be tested by ASTM Method 0-808-81 before used oil is transferred to the boiler tank and burned. 9. Use{! oil which does not exceed the following listed contaminants content is considered to be specification used oil per Used Oil Regulation 40 CFR 266 Subpart E § 

### 266.40: 

### A. Total halogens
. 1000 ppm by weight 

### B. Cadmium 2 

### ppm by weight C. Chromium 10 ppm by weight D. 

### lead 100 ppm by weight 

### E. Arsenic 5 ppm by weight In addition, the nitrogen content of the used oil shall not exceed 0.3 % (by weight) and the sulfur content ofthe used oil shall not exceed 0.5% (by weight). The flash point of the used oil shall not be less than 100 degrees Fahrenheit. The owner/operator shall provide test .::ertitication for each load of used fuel oil from 55 gallon drums or bulk carrier. Certifkation shall be either by his own testing or test

4.2.4-438

### DAQE-824-94 September 29, 1994 Page 5 reports from a testing contractor. Records of used fuel oil consumption and the test reports shall be kept for all periods when the plant is in operation. The records shall be made available to the Executive Secretary or his representative upon request. and shall include a period oftwo years ending with the date of the request. Used oil which does exceed the above listed contaminants content is considered to be offspecification used oil per Used Oil Regulation 40 CFR 266 Subpart E § 

### 266.40 and may be used except for halogens, but they are subject to the record keeping provisions of § 

### 266.43. 10. In addition to 

### the requirements of this AO, all provisions of 40 CFR 60, new source performance standards (NSPS) SubpartS A and Dc apply to this installation. Consult 40 CFR 60 for additional details on this regulation. For sources which are subject to NSPS (provided there is an opacity standard in the applicable NSPS), visible emission observations which are performed during the initial compliance inspection shall consist of 30 observations of six minutes each in accordance with 40 CFR 60.11 (b) and 40 CFR 60. Appendix A, Method 9. It 

### is the responsibility of the owner/operator of the source to supply these observations to the Executive Secretary. A certified observer must be used for these observations. Emission points which are subject to the initial observations are the boiler stacks. 11. All installations and facilities authorized by this AO shall be adequately and properly maintained. The owner/operator shall comply with R307-1-3.5 and 4.7, UAC. R307-1­ 3.5, UAC addresses emission inventory reporting requirements. R307-1-4.7, 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. 12. The Executive Secretary shall be notitied in writing upon start-up ofthe installation as an initial campIiance inspection is required. Eighteen months from the date ofthis AD 

### the Executive Secretary shall be notifIed in writing of the status of construction/installation if construction/installation is not completed. At that time, the Executive Secretary shall require documentation of the continuous constructionJinstallation of the operation and may revoke the AD 

### in accordance with R307-1-3.1.5, UAC. Any future modifications to the equipment approved by this order must also be approved in accordance with R307-1-3.1.1, UAC. This AD 

### 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.



### 4.2.4-439

### DAQE-S2:'-94 

# - September 29, 1994 Page 6 Annual emissions for this boiler are calculated at: 2.85 

### tons/yr for Paniculates 2.85 

### tons/yr for PM IO 

### 3.75 

### tons/yr for S02 10.86 

### tons/yr for NO.

3.17 

### tons/yr for CO 0.33 

### tons/yr for VOC 0.0008 

### ton/yr for Barium 0.0013 

### for Cadmium 0.0011 

### ton/yr for Chromium 0.0358 

### ton/yr for Lead These calculated emission rates are for the purposes of determining the applicability of prevention of significant deterioration (PSD) and nonattainment area major source requirements of the UACR. They are not to be used for purposes of determining compliance.

___:Dsell A. Robens, Executive Secretary Utah Air Quality Board

4.2.4-440Michael o. Leavitt Goven>or Dianne R. Nielson, Ph.D. Sxccalive DU=tor Russell A. Roberts DU=tor



### To: Through: Through:


### From: Date: 

### Subject: DEPARThffiNT OF ENVIRONMENTAL QUAlITY DIVISION OF AIR QUAUTY

150 North 1950 West Reply to: State of Utah Salt Lake City, Utah 84114 Division ofAir Quality (801) 536-4000 P.O. Box 144820 (801) 536-4099 Fax Salt Lake City, Utah 84114-4820 (801) 536-4414 T.D.D. 

## :MEMORANDUM
File Lynn R. 

### Menlove, Manager, New Source Review Section, Utah Division of Air 

### Quality Dale Chapman, Engineer 

### ill, New Source Review Section Utah Division of Air 

### Quality 

# .Jc., AIjun Ram, 

### Enviromnental Engineering Technician September 29, 1994 AO Modification for Used Oil Boiler at 

### Hill Air 

### Force Base
Abstract 

### Hill Air 

### Force Base (HAFB) 

### has requested permission to modify the allowable emission rates listed on their current AO for their used oil boiler. The maximum allowable concentration of NOx 

### emissions will change from 110 to 240 ppmdv and the maximum allowable concentration of S02 emissions will change from 39 to 270 ppmdv. This will require a modification of the AO DAQE-50l-92, dated May 26, 1992. The increase has been requested because the boiler could not meet the concentration limits specified for S02 and NOx 

### in the existing AO. Also, a discussion with the manufacturer (Internal Combustion, Monroe, Wisconsin) revealed that there is no 10w-NOx 

### technology available for used oil boilers, and that the boiler that HAFB presently has, is BACT for dual fuel (oil and natural gas) boilers. The amount of gas used and the total oil burned per year would be the same as before. The total allowable emissions will increase from 10.05 to 10.86 TPY for NOx 

### and decreases from 6.72 to 3.75 TPY for S02' The decrease in allowable S02 emissions results from the overestimation of allowable S02 emissions in the previous AO. The minimal increase in allowable NOx 

### emissions will be more than offset by the decrease in 

### allowable S02 emissions, since both are considered to be PMlO 

### precursors. This issue was previously discussed in the Level ill 

### staff meeting of the NSR section, and the

.- increase in concentrations was approved. This will not result in 

### a violation of any State or Federal rules. 4.2.4-441

### Recommendation It is recommended that the proposed emission rates be accepted as BACT, as requested. The minimal increase in 

### NOx 

### will be more than offset by the decrease in**SO~** 

### emissions, and therefore, a waiver is requested from the public comment process.

A $400 fee needs to be charged to HAFB for the AO modification.

F:\AQ\ENGINEER\ARAM\WP\MEMOS\HAFB

_**UOB.~**



### 4.2.4-442

## ) 

# Calculation NOX , I \ i ' 

# t 1-, 

# F 

# -4 Molecular weight for

# ~~OX : 46 Ib/lb Mole ,---­ " ' !' (/ pl/'v 

### II " lr1­ L :} I I, 

## f ,/ ),-0')4/' , I·

, 

## . 

## I) 

# h'l[:,f 01 l't' t 

### <'. r}q' 

### (J--"" ( S-Factor for waste oil :

## 12~OO SCFIMMBTU i 

## Y./ S-Factor for Natural Gas: 11 990 SCFIMMBTU 

# If

# ()')~ /' 2.64E-03 Ib Mole/SCF NOX (I ' ./ 

### 1/ 

# ()d ,2" II ' ,I :, \ ,

.. 

### c: 

## Y'j J. I I ',; 

### '! 

## If,. J, I.' 133000 BTU/gal oil v rJ' I" 

### t' J , 'c' , /l '1/ I ' HHV of oil : HHVof Gas: 1000 BTUlSCF v 

### f) 

### Pi (f 

# t 

# f ! 

### r 

### 'J Ie... 

# 'I 

# r Firing rate Natural Gas:
.

## ~?Q.SCF/IT!~n (-'-pIA 

## !){,e.. (.f /,) I' 

## n,/i,

## ~I 

# !'''). C')\I./'. 

## YI lFiring rate Waste Oil : 'tftYsgal/hr,) 

### 0";\ .",1 ;,1), ",) IA() " ,. I ""-t ,I I, ,1 i Q.A. ,,;)... \ I ). ) (-1 ( 1C. ( 

### J' Ii**4.~** 

### \ I) 'I &l) ( f) \

### ~"j;.4'('.' . Heat Input : 20.9 MMBTUlHr 

# 1**r~** 

# , , .T:"\"jj---. ",; I I 1,/" " I

. .. /' •. ( \ ') '6 ) Max Oil Firing : 100000 gal/yr 

### t '\ -,.1. II**,~** J1/ 

### I8 r '/1

r. " Max Gas Firing : 7985 hr/yr " 

## I I 

## 6 () Ob,. r I A

## I ' {) I .) 

### I I ' ,\ f I" I I '(", I ", \' 

# (0.) (Emlsslonllmll Waste-Oil: 160 ppmv

### 36fj~f 

# In.,' I (, 'I

### ~', hf () 1/1\" "( Emission Gas: 70 ppmv J ) I f;. 

### Combustion of Waste Oil 11 

# t I' Combustion of Natural Gas 

# ?p-e/t**uV~.** /,,1,...--1

## (~f'>" 

# r**~!** 1 ) 

# 6'**Ob~** 

### 4-;-884 '115 NOXlhr

# ~1'291~NOXJhi> 0.237 Ib NOXlMMBTU 0:llf21i)

### NOXlMMBTU ,:L516 tons/yr 1/ 

# ", a.soo**t'orls/yOr~'\**

# L-'H~ , -- - - - 

### - - -- 

### -- 

### - - -

## ~T 

# r/
.l:>. N 

### 3.100 Ib NOXltn AP 42 

### 2.100 Ib NOXlhr AP 42 

### 1.000 tons**~OXlyr** 

### AP 42 

### 8.384 tons NOXlyr AP 42 

# t 

# --­ w I ( , - t**~f'** 

### ,'\ L 

## I·1"J (:) )f /b ') 'I 1 ,,'(}u 

# ?IFf

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

# .'**j'~,** , ' .J 0 1·"' (

# Combustion of Waste Oil Calculation of**~OX** 

## I Gal..OiI
160 SCFNOX X 12200 1.00E+06 SCF Rue Gas 1.00E+06 0.032 Ib NOXIGal 

## Calculation of Ib NOX 

## I hr SCFFlueGas BTU X 2.64E-03 IbMole SCFNOX X 46 Ib IbMole X 133,000 BTU gal Oil

0.032 III NOXlGal X 155 gal/hr 4.884 Ib NOXlhr 

## Calculation of Ib NOX I 

## MMBTU 

## =

160 SCFNOX 1.00E+06 SCF Flue Gas X 12200 SCF Flue Gas**~BTU** X 2.64E-03 IbMole SCFNOX X 46 Ib IbMole
p.237 Ib ti0XIMMBTU 

## Cil)culation of tons NOX 

# I 

# yr 0.032 Ib NOXlGal 

# t**1.51~** tOfls/yr 

# i X 100000 gal/yr X 1 2000 tons Ib 

## =


# ) ) )

# Combustion of Natural Gas
cmculatlon of Ib NOX 

## I MMBTU
70 SCFNOX 1.00E+06 SCF Flue Gas X 11990 SCF Flue Gas 

### MMBTU X 2.64E-03 IbMole" 

### SCFNOX X 46 Ib IbMole 0.102 Ib**NO~MBTU**

### ~culatlon 

## of Ib NOX 

## I SCF
0.1 02 IbNOX 

### MMBTU X 1000 

### BTU 

# ro= = 

## 1**01·~~~ !~**  NOXlSCF 

## Cillculation of Ib NOX 

## I hr
0.102 IbNOX 

### MMBTU 

### X 20.9**~BTU** hr =
2.129 'b NOXlhr

### ~Iatlon 

## of tons NOX 

## I yr 2.1290 Ib 

### X 7985 +>. hr N 

# k**~.5qQ ,o"8/y~**  lJl hr yr X 1 2000 tons Ib ==

# Calculation of NOX using AP 42 Emissionfactors
EfTlissionfactor Nitrogen Oxides Waste Oil : 20lb/1000 gal Emlsslonfactor Nitrogen Oxides Natural Gas: 100 Ib/mill SCF

# ~bustion 

# of Waste Oil ),.' ') ).1

## ~' a

# y, 

# ? ' ,." V

# ~. Ib/gal X 155 gal/hr 

## = 3.100 Ib NOX/hr /1 0 " ./ I

### ~Iculatlon 

## of tons NOX 

# I yr 20 Ib/gal X 100000 gallyr X 1 tons/lb = 1000 2000 

### 1.9QO**,of1~ ti0Xl~r**  

### ! 

## 4 D 

## Ib/ 

## I b 1;3 X 60 mln/hr =


### 2·1**O~** 

### Ib, 

### NQXlflf 

## Calculation of tons NOX 

## I yr 2.100 Ib X**79~5** hr X 1 tons/lb = .t>. hr yr 2000 N 

# :k 8.384**.o~s tiOXl~f**  0'1 e" 1 

## (J

## f !I 1 

## I' II X 350 SCF/min I • - r Ib/SCF c:=::::>



# ) ) )IU



## ( Date: 7/8/94 ) 

# (Message:) RECEIVED 

# \FAX COVER SHEET) JUL 08 1994 

# Air 

# Quality 

# From: Andreas Zekom**ED~roDDEI1tal** MaDagmmtDirccrol'3te 

### OO-ALCIEME 7214 Wardleigh Road 

### BiU AFB,UT84056·5137 n1: CoDUlerdaJ: 801·777.{J3S9 DSN 458-0359 

### Fax:ColJl:l:lerl:iaJ:801.777-4306 

# To: Name: Arjun Ram 

## Organization: DAQ 

## Fax No.: 

## 5364099 L 

## Dear 

## Mr. Arjun 

## Ram I 

## attached are lsome information from the burner manufacturer and 

## the analaysis of the nitrogen Icontent ofthe waste oil. I I I 

## Sincerely i I i 

# ,i#JhtlJJ

, Andreas Zekorh



# J 4.2.4-447 

## (Total ,umber ofpages including cover sheet: 9

### ,

# ...

, """ I**~u--~O-.JJ~ .~.~.**  ••vr.. '-'**~,,~-** ....**~=-~a:J~ :~,** **e{'·lS-~ r·~:~**  1.:-. lj tal 

### Dr 1162



### ,--­ 

# -

J.lESTERN ANALnrCAL I 

### INC. 

### 2417 CONSTITUTION BOULEVARD SALT LAKE CITY. UTAH 84119-1225 

### PHONE 1801) 57S-923&**O~** 

### la0G) 

### 3&3-5924**F~~** 

### (501) 973-7635 CEiTU'ICA'TE OF ANALYSIS i 

### June 

### 15, :1994 PS4-317 i 

### ACCT: 

### No.i 1909 

## YOUR PURCHASE ORDER; F-47659-S4-M87Sa 

## HILL All FOIC! 

## BASE Hi. JIM BATES 

## iMH 

## BILLING 514 

## H.A.'.I UTAH &4055
I I 

### Dear 

## Hr•.**~ates:** ,**~aaaaitta~** 

## harawith Af6 

## th6**~lytie&l** 

### dAtA**f~r** 

## tha**tt~aa** 

### oil samples 

### analysis. ; delivered to om-. 

### laboratory for nitrogen DATE \UCElVED: Jtme 

### 13, 1994 

### nAn \01 ANALYSIS. June 

### 14, 1994 

## RECEIVED BY: Julie Lopez SAMPIJ! N 

## IDEm'IFICA:'!ION % 

### Sample :11 \ 

### 0.29 SUple 42 : 0.23 

## SamJlle .3 0.19

E. 

### H. PHILIlIPS 

### Laboratory iDirector 

## EHPIj 

### 1 4.2.4-448·ILL-'cll::i-l':l':l4 lid: Idl t-t<U'\ c.NV!r<UNf'lCN I HL rlHNHUl:;f'\t;N I IU

I 

# 18:**!!¥!rJ~~Js,~9.MBUSTION** I 

### 351·21st SIref!I. 

### Monrve. 

### Wlseonlin 63566-27;8· Phon,: 5081325-3141 • F.r. SfJ8f32S.4319. Telu 

### II: 9101280-2170
, , I 

### .'-Yr­ INDUSTRIAL ANO COMMERCIAL. BURNERS AND BOILERS " I j I**,~** ;"";" -""../r-

__ .'\

..

/ r 'Y'J

.... j**~)./** IJ_

. ,.J**,~-;,,7-.**

3une 1&. 1951l4: 

### Hill Air Porce Base 

### OO-ALC/EME Att: lUke 

### Graziano 7276**Wardleig~** 

### Road 

### Hill 

### Air Porce Base, OT 84056 

### Re: Boiler KaissioDs
! Dear Mr. 

### GZ"aZiano:

I 

### Please 

# f1Dd eztclosed two (2) 

### copies of oU%' 

### Boiler Eaissjon GUide

.. well as a 9Taph wi 

### th 

### fuel bound 111

### trogen versus expected 

### NOx 

### emissioDS.**Y~u** 

### notice that 

### the range OD 

### the graph 

### varies and so


### .- tor your 

### standard "D ft 

### burner you 

### should use the 

### upper 11ne as the**refereDce~** POl" 

### the 

### wasteloil Nb1ch you are f1ring, in my 

### opinion the 

### burner system**pres.n~ly** 

### installed on your boiler is the best available teChnology for HOz 

### reduction.

I 

### If you have**a~y** 

### questions, 

### please let
.. know. Sincerely,

;**IKDOST~AL** 

### COMBOSTIOK
i

## WVrYJ~ R. Ki. 

### Black 

# i

. RXBlsa 

### EDclosures: 10-1155, 

### Charts

I 

### cc: KeD 

### lIann:inen I



### 4.2.4-449IU

tCl5al 

### Job Name: Olstrlbutor: Attn: 

### SO#**~.x** No. Tel No. 

## I r 

# \ ESTIMATED Burner Emissions

I I 

### I.C. Burner

## Mode~ • DEG-210-P BTU's per Hour
­ I ; 

### Fuel • Natural Gas
, , 95304099 P.05



### 21,000,000

PPMv (Corrto 

### 3% 02) Pounds per 

### 1

## ,000,000 BTU's 

### TOTAL Pounds per Hour 

### @ 100% Firing 

## Rate

, I I 

### Particulate fPM-1 0) 

## N1A 

## 0.0060 0.13 I i 

### 0.0367 Carbon MonoxidJ 

## (COl 50
I 

## i SOx (c8 PPM

# wtJ SUlfur 

### in Fuel) 

## 0.4 0.0007 ! i 

## 15 

# vee (Methane 

## + Non-Methanel 

### 0.0080

I i I I 

## NOx I 

### 70 0.0844 1 I i i I I I I 

### ReQuired Combustion Air (60 DeQrees 

### F.l SCFM 

# i Flue Gas Volume 1(400 Declrees F. Gross) ACFM Flue Gas Veloc' 

## 0.77 

## 0.01 0.17 1.77

2193 3,815 6.888 

# ,­
4.2.4-451lU

NCDCIllQA 

# - Job Name: Otstnbutor: Attn: 

### SO# Fax 

### No. Tel No. 

# ESTIMATED Burner Emissions I.C. Burner Model .' DEG·210-P BTU's per Hour • 21,000,000 Fuel· 

## #2 Oil Gallons per Hour • 160.0 

### PPMv (Corr

### to 3% 02) Pounds per 

### 1,000,000 BTU's TOTAL Pounds 

### per Hour 

### @100CKtFiringRate

Particulate 

### (PM·1

# e)} NlA 0.021 

## 0.44 Carbon Monoxide (COl 

## 50 0.039**~,** 

### 0:82

, 

### SOx «0.5% wt. 

### Sulfur in 

## Fuell 290 

### 0.539 

## 11.32 

# vee (Methane 

## + Non-Methane) 

### 10 0.006 0.13 NOx «.04%wt. 

### Nitroaen in 

### Fuell 

### 120 0.157 3.30

SCFM 

### 3867 R 

### uired Combustion Air


## rees F. Gross 

### ACFM 

## 6748
r Minute Flue Gas 

### Veloe' 

### 2148

4.2.4-452IU

t.Cll!IIlC 

### Job Name: Dlstrlbutcr: 

### Attn: SC» 

### Fax 

### No. 

### Te' No. 

# ESTIMATED Burner Emissions

, I.C. Burner Modeli • DEG·210-P BTU's per Hour • 21,000,000**J~ ~.**  /".**r/~· '~..**  . , " --tv-I
. . i··..;;..· ; / . 

## Fuel. #6011 Gallons per Hour
- 140.0
PPMv Pounds per TOTAL Pounds per Hour 

### (Corrto 

## 3% 02) 1,000.000 BTU's @ 100% Firing 

## Rate
%08 0.82 

## 21.86

0.26 8:25 

## ? ,?.-r;c (0')/ t-Kl(t

### jCf"

## :;:.--<­ ::; 1- .::; 

### 4 

## 7 P /IJ; Reauired Combustion Air (SO Cearees F.) SCFM**3~867** 

### Flue Gas Volume 

### 1(400 Dearees 

### F. Gross) 

### ACFM**6~748** 

### Flue Gas Velocitvl (24" Staek Diameter) Feet per Minute 

## 2:148

4.2.4-453

### --

- -

--



### ---

-- 

### --- ---- 

### ---- -

### -- 

### u
u 2.0 -';':;'--U

:I loS



# - :e ... CIt 

### c: 1.2 0 'iii .!! 

### E 1.0 W M 0 0.1 CIJ U
0.•

•.3 0.0 

### o

N 

### 1. VI 

### SOx Emissions ConlJeralon Curves 

# vae Conversion Curves 

### (3%°2) (3% 02) UJY Anal"" 

# V

.­ --_.­ -- ... .._+­

_ ..

### - . _.. - ­ 

# V

-



# - 

# V

./

# V

- / 

# / / / 

# / V 

# / 

# ,

.. .. 

## . . . 0.' • .. / 

# '/

- 

# 1/ '" 

# r-- Ul
....0
2044 UN 2,22 0.011

-
U':I 

# I 0.040**·2.00--·-·---·~--O;041**

U. C ,Q O.OIS 

# .- 

# ­ UJ! 

# - 

# - r! 0 ' .•JO 

# ... e**:~** U1r7J E

....25 W 

## • 0 O.Ollt G.l7 0.011 

# 0." 

# g

0.44 0.011 0.32 0.001

I I. I • • I I I • I 0.00 0.0 100**2~** )DO 400 IDa 100 700 100 laD 1000 1100 1200 o II 20 )Q 40 10 '0 TO .0 10 100 UO 120 SOx Emissions (PPM) 

## voe**~mlss'ons** (PPM) 

### #2&.8011 

# 1_\1":- .2'::'011 ,

# ,eo) Natural Gas 

### &Propane 

### Convqrslan Equations Conversion Equations 

### .2 &

### 16Oil: 

### .2 &

### #6**O~: ~atural**  Gas & Propane: 

### PPM

# = (1b./MMB1U) X 538 PPM 

### =(lb.IMMBTU) X 2000 PPM = (lb.lMM8TU) X 2500 

### 1b.IMMBTU

### =(PPM) 1538 Ib.IMMBTU = (PPM) 12000 Ib.IMMBTU 

# = (PPM) 12500 D

_

ry Analys,s 

# /

- 

# -L

­

-..­**~....,-;- .<=~~**  

# L**f~** /./ 

# ./

_ ..; "",,_.­ 

# VI /



### - 

# / /' ---,L-­ 

# , / 

# L

,­**--~-** - 

### /-­ / 

# 17 / 1--- --,-- '-­ // 

# / / 

# / --­

.­ '-­ 

### - 

### "

• '
__ 0 

# / - - - 

### - 2 t) 

# tl 

# F m I 0 

# ... \D \D



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## P 3

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# i

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# --

--

-- 

### '-'i "'t;:"/

-

# .. - .__. 

# -.

.,. -"- 

### ) 

# ) 

# fj ,.J
NOx Emissions**Converslo~** 

### Curves CO Conversion Curves 

## (3% Oat (3% 02) Dry 

### An!!!._I. DIY An:.lysis 0.24 

# ! /'1 r--' If _. 

### / 

# L-**~-**



### .. 

# :i . . ...... .. .:..
. .. -:**~....,.** 

## .", 

# V L · .... 1-



# _

..

# ,--_. .. - --", -'- 

### / 1-- r-' 

### ,---

# -It I r---' -.- 

# L /

- .- 1- ;-- . 

# 1/

- 

### -- - r--- 

### /- 

# ,-- r---

-- t--. 

### I

# --~ -. -r--- - ,- 

### - 

## -- 

## - --A-- .-r--- 

# l/i 0.14 

# T f-...I_._ I
.. 0.21 Ul

.. 1 I t--**~-~** --I

__ __**~_I·-l_** - J- -.---­ 

### 1.20**~q~**



# - 0.18 I---.--+-----I-I-I

.. -J----J--I -1--1- -1-' 

# ; 0.11 

# - --1--·1-1--1----1---1-' --t­ -- ­ lI.1. O.t. 

# i g .. / 

# _.\­ D.U 

# ..... .,. 

# - en 

### c --·---l--I- -1·- - -. - - _.\ 

### c •. n 

### .9 o.n 0

## :~ 0.10 0.10 

# --- -- -or j E 

# 8 IU 

### a 0.08 I-.-I--I----t-
-- - ---- -----.- --­


# ... I Z 0.01 w 0

-0- ._ .•

__ . __ ._ .--­ 0.01 1-- I I 0,0'
'.0" 0.04 I 

# '-l",'-r0.01 0.02 

# --Il-il- t

0.0 0.0 

### o 2. 40 "
.. 

### teo flO t40 '60 110 200 220 240 

### o 20 40 00 .0 toO 120 140 150 180 200 no 2.0 NOx Emissions (PPM) CO Emissions (PPM)



### - .2&.6011

- .2&1I60JI

- - Natural Gas & propane 

### - - Natural Gas & 

### Propane

J:> Conversion 

### EQuaiiOOi Cgnversion EQuations N 

### '2  

### OR: Natural Gas & Propane: 

### 112 & fI6 Oil: Natural Gas & Propane: 

### .h til PPM

# = (lb./MMBTU) X 763 PPM 

### = (lb.lMMBTU) X 829 PPM = (Ib.lMMBTU) X 1270 PPM:: (Ib.lMMBlU) X 1361 til Ib.IMMBTU 

### = (PPM) 

### I 763 Ib.lMMBTU

# = (PPM) 1829 1b./MMBTU

# = (PPM) 11270 Ib./MMBTU 

### = (PPM) 1 1361 

# ; i

.­ lSI 

# .. 

# § 

# j



# I

d



## ... 

# " IJl 0 

# e' lSI 

# g' CIl -u ir 

## f8



# .. n

### ';17-1;'(;'j7 e Oil 

### Environment4' dcterization of 911 ( 

# ( 

# I

Vl a: w -l 

## .... 0 ce w a: < -l :z 

## .... :z 0 

## ....IVl :::l 0 u -l 

## .... 0 0 w Vl :;:) :z 

## .... a: :;:) 0 Vl :z a 

## .... Vl Vl 

## .... :::E: w w I­ <: -l :;:) U 

## ....Ia: <: n.
Ul '<t W -l ce <: I­ '­ "0

.... eII<­ >, Vlll'­ ell 111"0**'-eII~** '- v o >< u. u w u Vl 1110

....... e '- V! o ell e '-N'­ V! 

# ... V! 0 '­ .,.. en e w



# - t III "0**e~** ell 0 0\

.... U. IOIIlU '-IIlVl ClI'_ ........... > e V! <we 

## .... 10 '­ 0\

o

## '"



## .... "­**~"O** < ::I ell III**~~** III OVell >- ell V '- >< v!'-w 10 0**~uo** '­ ell N

v NC 1>4 00 u

.I: V V! e <01>4

u

e ell**CII~~** u ""._ '-100 eII:lC n.

..... e 0·
...**O\~** <U L'_ 0...,.. CJ >,>­ I­ ,..... '<t 0 0\ \0 0 0\ Ul 0 N 

## .... 0 0 N 0 '<t ,..... 0 co 

## ..., 0 co

...... 

## .... 0 N 0 0 0 0 0 <:) 0 0 0 0

0\ ,..... 

## .... 0 0\ N M 0 0 

## .... ..., 0

# . N \0 0 0 0\ 

## ..., 

## .... 0

# . \0 ,..... '<t 0 

## ..., co N 0 

## .... co 0 Ul -.r 

## .... 0 0 0 0 0 0 0 0 0 0

N 

## .... co M

# . '<t \0 ,..... -.r 0 -.r N Ul Ul M M Ul



# . co In co \0 0 M -.r \0



# · ,..... ,..... ,..... '<t 

## .... ,..... 0\ M N ,.....



# · 0 0 0 0 0 0 0 0 0

0 M

...... 0



## .... .... 0 0

...... co 0\ \0

# . \0 Ul ,..... M ...; 0 \0 co Ul

N 

## ..., 

## .... v 

## .... 0 0



# . . 0\ 0 co 

# · a 

## .... N 0\



# . . Ul 0

# · a 0 0 0 a 0 a 0 0 0 u
0 ..0 Ul NI u co 0 N ,..... V


# · 0 "0 co 0 "0 0 ..0 \0



# · 0 Ul

...... \0 N 0 

## .... N

N N N \0 \0 \0 \0 \0 0 0 0 0 0 0 0 

### , I 0

## · :z :z :z :z :z :z :z :z 

# - \0 N



# . v



## .... e
0\ e


### .

## ... '­ ell ell e


### .

## ... a Ol e 0 \oJ 

## ....
...... <: ....., I­ \oJ 

# - \0 ,..... "0 c: '<t 

## '" >< v



# - e

...... 0 N 

# . &'1 III 

## .. E 111111 ell**)(~~** 

## ....
.,.. Or"'" III 000 >, 0 Vl

.......... <U

..... L...J >'r- e or- or- 0 0

.. L +J V

.... 0..., ell e III

. a: 0::1

"0 e 

# .. with an average value of 0.73 

### lb/hour [0.34 

### lb/ml This is significantly higher than the literature for commercial boilers firing residual oil; but with the much higher ash content of used oil, wh**1.5~.** 

### Further, particulate sizing measurements test sites Indicated that 80 to**90~** 

### of the parti submicron in nature and would be readily inhalab Few data are available about the fate of in SUlfur, nitrogen, phosphorus, and halides during general, the form of emissions resulting from th the source and type of waste oil and the nature Some examples of inorganic emissions expected fr inc 1ude: 

# • Sulfur

-- the majority of the sulfur con as sulfur dioxide**(SO~)** 

### with some sulfur acid (H SO). Small mounts of sulfur a

### emissio~s**~nd** as boiler deposits in

### sulf~ Approximately 0.152 

### to 0.465 

### lb**SO~/milli** 

### used oil containing 0.16 

### to 0.361 

### ulfur 

# • Nitrogen

-- as gaseous emissions, nitroge nitrous oxide (NO) and nitric oxide (NOZ ) boiler deposits (as nitrate and nitrite c ammonia compounds are other sources of ni instances. Some nitrogen emissions data 

# • Halides and phosphorus

-- organic bromine compounds are emitted as hydrobromic, hyd acids. Phosphorus, in comparison, is emi form of phosphates. I 

### ORGANIC EMISSIONS With respect to organic emissions from comme 12.5 

### million Btu/hour), EPA's data Indicate that cies will range from**99~** 

### to greater than**99.9~,** 

### w 

### destruction and removal efficiencies of 99.4 

### to 9 strong correlations were observed by EPA between boiler sizes or firing techniql' However, one the data was that the destructL {fie i 

### enc Ies f0I I

I

I -------- 34 Waste Oil
TABLE 21. USED OIL PROPERTIES BY OIL TYPE TABLE 22.**L~r-t"Z'r** POTENTIAL IMPACTS AND IMPACT RE OF USING UNTREATED USED OIL AS

Property Automotive 011 s Low High Indus t ria 1 011 sa Low High Property Spec I'lc

gr••lty Potentia'**I~pact'** rom.tlon 0' concentrltlon gr.dlenlS when co..,lned In Itor.ge tank, with dlltflhte 011 •• 0 Stora .1. col
• Sep.r.

prior Physical Properties Viscosity, SUS (at 100oF) 87 API gravity (at 60oF) 19.1 Spec Hi c grav ity 0.9396 Water, vol '.t 0.2 Bottom sedimsnt and water, vol 0.1 F1ashpoint, F 174 Carbon residue, wt t 1. 82 Ash, sulfated, wt t 0.03 Benzene insolubles, wt 0.56 Gasoline dilution, vol t 2.0 Heating value, Btu/lb 13,580 w.tor fuel line ',....,zln9 o U.e wi

• RMOVI

pretre 837 143 330 Burner ,la
....,ut o Use wi

31.3 25.7 26.2 fh
..e. 0.8692 0.9002 0.8972 Incon.lstent heating .alue o Use fo 33.8 0.1 4.6 t Ion. 42 • Rt",ov' 430 315 gretrt 4.43 

# -- -- b Co
... e Sludge buildup In Itorlge unk o Storlg 6.43 3.2 5.9 'olld' 110'" 3.33 • Ute wetl 9.7 ,Iudge 19,316 17,268 18,008 • AelllOv,.

_____ _ p.!.etre. Chemical Properties line Itralnor fouling • AelllOval

Fatty oils, wt t 

# -- -- 0 60 'o.el p Chlorine, wt t 0.17 0.47 <0.1 0.83 Abru!on of po'lthe dhpl.c
...ont Jl'I

.... • $epirlt Sulfur, wt 't 0.17 1. 09 0.54 1. 03 Ie.I, por t pr lopello Zinc, ppm 260 1,787 Ca 1c1 urn, ppm 211 2,291 • R
...... I protru Baritnn, ppm 9 3,906 Phosphorus, ppm 319 1.550 Abr.,ton 

### 0' burner**nOlll~,** • U.e wttl Lead. ppm 85 21.676 • Ar-ov.' pretrfl Al uminum, ppm <0.5 758 Iron. ppm 97 2,401 A'h 'o""lng Hul th hll.rd 10 hoflor-cleanfng • U\e or ••terf.h prrsonnrl
• ROIlO •• 1

___________________--=t::.o_,use**~Limfted** data avafl abl e for used industrial 011 s. SUltng and corro'ion of hut tran.ftr • Use In ( Values for industrial oils are for regular not sulfated ash. sUl'"hcrs • R'lIlOv.l to use Source: Kirk-Othmer (12) Hn.rdou
... h,lon, • Use wlO contl'"ol
• R
...... l to use I reduce the fouling and corrosion of boiler heat exchange surfaces or emission Ash dlspoul probl
.... • R
..... I of metallic contaminants that would result from waste oil combustion. In to use order to obtain a significant metall ic contaminant removal, higher level Source: GCA CorpardIon lUI adv anc ed reproce Ssing techniques mu st be ut11 ized (14). FinaP" a comparison of the properties of used automotive 011 5 •. ' 'I, virgin di Jte and residual fuels is shown 1n Table 23. This tab· conjunctA th Table 8, provides an overall picture of used 011

# com~ .Ion

## ,~ BOILER PLANT 1703 WASTE OIL BOILER 90% LOAD 

### 0 CO O:<r 02 NOX SITEMP AfTEMP S02 I I 1/19/94 11- 8 

# -- 5.8 141 490 84 78 

### .'

## - 1121/94 " ,- 26 

## - 

# .. 6.1 150 i 530 74 81 

### , 1/31/94 /',' 

### - 6 L::" 6.9 144 408 59 66 / 211/94 /; r ,. 7 l.<-: 6.7 155 529 78 63 r

LOW FIRE 1/21/94**~I.-** 29**~:::** 5.61 114 341 74 75 1/31/94 

### q; 3**~.9'** 8.1 108 206 59 52

211/94 

### t? 2 '/ 9.1 110 359 78 42 [' .1



### F-'



### 4.2.4-458

# - RECEIVED DEPARTMENT OF THE AIR FORCE HEADQUARTERS OGDEN AIR LOGISnCS CENTER (AFMC)

# ~1ru L 201994 HILL AIR FORCE BASE. UTAH 

# Air Quality

. (lOy**':v.~L** 

# S8x h::--..i/·-;L 

## 3**i",7~.** J \.­**',~.':'-"J**

.**_~".:.~kt:.** r. ...... 

### 18 July 1994 OO-ALCIEM 7274 WARDLEIGH ROAD HILL AFB, UT 84056-5137 i? I

## /~ -?- 2- C ')

## ~f~J,. /jI**..)"J~.x** I

_ _ • 

### Mr. Russell A. Roberts ')'

. i.-
--- ./ - ..:..' -**'~** r- -- -" \ I '-' _""'

. J_' , 'I / 

### State of Utah Division of Air Quality P.O. Box 144820 Salt Lake City, Ut 84114-4820
Re: Waste Oil Boiler Approval Order DAQE-50l-92

Dear Mr. Roberts Stack testing of the waste oil boiler prior to startup from 19 January to 1 February 1994 showed that the emissions of NOx and SOx were above the limits of the Approval Order. An analysis of the waste oil indicates an average content of 0.21 % fuelbound nitrogen and a sulfur content of 0.2%. As the fuelbound nitrogen content varies depending on th composition of the waste oil, we expect a nitrogen content up to'''-0.3%. The NOx emissions for this nitrogen content are calculated to 40 -, by the manufacturer (Atch.l). As low NOx burners are not available for firing waste-oil_ and natural.,.gas in a dual burner, this boiler has the Best Availabk-­ 

### Control Technology concerning the NOx-Emissions. 

# ­

-

-



### 4.2.4-459

# - Calculations of the annual emissions are included as Atch. 2. According to our new calculations, the increase of the emissions IS 

### less than I ton per year over the current Approval Order. We request a change of the Approval Order to the following limits while burning waste oil. -240 ppm NOx or nitrogen content not greater than 0.3 percent. -sulfur content not greater than 

# Q.5 percent Compliance with the content requirements above can be done by testing the waste oil in the tank before transfering it to the boiler feed tank. Burning of the waste oil could be limited to 100,000 gal per year. With a firing rate of 140 gaUhr the waste oil boiler will run only 27 days a year for burning waste oil. The rest of the year the boiler will run with natural gas. 

### If you have any questions, please contact Mr. Andreas Zekom at 777-0359
Sincerely

# J~**R.JavJ!)~** JAMES R. VAN ORMAN Director of Environmental Management

Attachments NOx Emissions Chart Calculation NOx Calculation SOx 4.2.4-4600

0 

# - -l M -l 

### d 0 :0--, 

### Z



# -­ a
c.J 

# Z



# m. Z 0 (f] 

### :.. 

## c 

# 3

Z 

# :: C<


# .... U -l \(') 0 

### d

M 0 

### d

In 0 

# g III 

## c::

......... .J



### c= III 0 S-t. 

# .­ Z 'C 

# § 0 t:Q
.­ III ::3 

# m. l---l O"l 0 0 0 

### d 

# X 0 

# Z 0 0 M 0 

### co C\l 0 (0 C\l 0 C\l 0 C\l C\l 0 0 C\l 0 

### co -t 0 (0 -+ 1 0 -t 0 C\l -t 0 0 -t 0 

### co 0 \.0 0 0 C\l 

# ,,­

4.2.4-461

# Calculation NOX

Molecular weight for NOX : S-Factor for waste oil : S-Factor for Natural Gas:


### HHV of oil : 

### HHV of Gas : Firing rate Natural Gas: Firing rate Waste Oil : Heat Input: Max Oil Firing: Max Gas Firing: Emlsslonllmlt Waste-Oil: Emissions Natural Gas: 

### Combystion of Waste Oil 0.047 Ib NOXIGal 6.617 Ib NOXlhr 0.355 

## Ib NOXIMMBTU

..

# -.-

.**---~-._) ~.363**  

### tOfls/Yf-­



## ------ ----1­ 46 Ib/lb Mole 12200 SCFIMMBTU 11 

### 990 SCFIMMBTU 2.64E-03 Ib MolelSCF NOX

133000 BTU/gal oil 1 000 BTU/SCF

350 SCF/min 140 gal/hr 

### 20.9 MMBTUlHr 100000 gal/yr 7985 hr/yr

240 ppmv



### 70 ppmv

### Combustion of Natyral Gas 2.129 Ib NOXlhr 0.102 Ib NOXIMMBTU

## ~.500**t-~;;siyr)** 

## j- -----_ .. -- --- -­ 2.8QQ

### I~ NPXlhr AP 

## 12 2.100 Ib**NOXl~f** AP 42 N 

### 1. 000**~ons** 

### NOXlYf AP 42 

### 8.384 tOfls NOXlyr AP 42 

### 1. 0\ 

# ) ) 

# ) IV

## ) 

# Combustion of Waste Oil
cmculatlon of Ib NOX 

# LGal 011
240 SCFNOX X 12200 SCFFlueGas 1.00E+06 SCF Flue Gas 1.00E+06 

### BnJ 0.047 Ib NOXlGal

### ~tlon 

## of Ib NOX 

## I 

# tn
0.047 Ib NOXlGal X 140 gal/hr 6.617 'b NOXlhr

### ~culatlon 

## of Ib NOX 

## I MMBTU

240 SCFNOX X 12200 SCF Flue Gas 1.00E+06 SCF Flue Gas 

### Mv1BnJ X

=

X 2.64E-03

2.64E-03 IbMole SCFNOX

Ib Mole SCFNOX X

X 46

46 Ib Ib Mole

Ib Ib Mole X 133,000 

### BTU gal Oil**0.~5~** Ib**NO~M,BTU** 

## Calculation of tons NOX 

## I Yf 0.047 Ib NOX/Gal X 100000 gal/yr X 1 tons = 2000 Ib -4 N**2.3~~** t0f!s/Vr 

# t 0\ w

# Combustion of Natural Gas
Calculation of Ib NOX 

## I MMBTU
70 SCFNOX 1.00E+06 SCFFlueGas X 11990 SCF Rue Gas 

### M\IIBTU X 2.64E-03 IbMole SCFNOX X 46 Ib IbMole 

### 0.102 Ib NOXlMMBTU 

## Calculation of Ib NOX 

## I SCF
0.102 IbNOX 

### M\IIBTU X 1000 

### BTU OCF 

## =
101.868 Ib NOXlSCF 

## .calculation of Ib NOX 

## I 

# In
0.102 IbNOX 

### M\IIBTU X 20.9 

### M\IIBTU hr 

## =
2.129 Ib NOXlhr 

## Calculation of tons NOX 

## I 

# yr

.l;. 

### N
I .l;. 0\ .l;. 2.1290 Ib hr 

### 8.500 tons/yr X 7985 hr yr X 1 2000 tons Ib 

## =


# ) ) 

# )

## ) 

# Calculation of NOX using AP 42 Emissionfactors
Emissionfactor Nitrogen Oxides Waste Oil : 20 Ib/l000 gal Emisslonfactor Nitrogen Oxides Natural Gas: 1 00 Ib/mill SCF 

# Combustion of Waste Oil
20 Ib/gal 

## x 140 gallhr 

### = 2.800 Ib NOXlhr 1000 

## Calculation of tons NOX 

## I yr 20 Ib/gal X 100000 gal/yr 

### X 1 tonsllb = 1000 2000 1.000 tons NOXlyr 

# Combustion of Natural Gas
100 Ib/SCF 

# x 350 SCF/min 

## x 60 min/tu 

## = 1000000 2.100 

## Ib NOXlhr

### ~ation 

## ofjons NOX 

# Lyr 2.100 Ib X 7985 hr X 1 tons/lb 

# = hr yr 2000 -4 N :.". 8.384 tons NOXlyr r". 01 Vl

# Calculation SOX

Molecular weight for SOX: 64 Ib/lb Mole S-Factor for waste oil : 12200 SCFIMMBTU S-Factor for Natural Gas: 11 990 SCFIMMBTU 2.63E-03 Ib Mole/SCF SOX HHV of 

### 011 : 133000 BTU/gal oil HHVofGas: 1 000 BTUlSCF Firing rate Natural Gas: 350 SCF/min Firing rate Waste Oil : 140 gallhr Heat Input: 20.9 MMBTU/Hr Max Oil Firing: 100000 gal/yr Max Gas Firing: 7985 hr/yr 

### Emlsslonllmlt In ppm : 270 ppmv Emission Gas In ppm: 0.34 

### ppmv 

## t·, , I 

### CQmbystion Qf Waste 011 (1I.M, 

### CQmbystlon Qf Natural Gas

, '/ : 

### 0.074 Ib SOX/Gal (,)**~;:",** 

### ) 

# s,.) If! (; 

### 1 0.330 Ib SOX/hr I, :) 'J \' I

## ~.1 

## -,) .- 'T[ l " 

### 0.014 Ib SOXlhr



### 0.555 Ib SQXlMMBTU r,'- )' ) j j'

# ~,I:> 

# (**~.~~~ ~~** **~~XIMMBTU** ,·1 

# Ci!S9 tQns/y;:; 

# . / ; '7

# r1f/..1!)' 

## j .' ,,0.057 tQns/Yf

---.. - -

.._--- -**.~** 

### 10.290 Ib SOX/hr AP 42 

### 0.013 Ib SOXlhr AP 42



### 3.675 tQPS SOXlYr AP 42 

### 0.050 tQns SOXlYr AP 42 N 

# I I .h 0\ 0\ 

### 3.725 tQns SOXlyr 

# ) ) )r

## 1 

# Combustion of Waste Oil ')

Calculation.of Ib SOX 

## I Gal Oil
270 SCFSOX X 12200 1.00E+06 SCF Rue Gas 1.00E+06 

### 0.074 III SOX/Gal 

## Calculation of Ib SOX 

## I hr SCF Flue Gas BTIJ X 2.63E-03 IbMole SCFSOX X 64 Ib IbMole X 133,000 BTIJ gal Oil

0.074 Ib SOX/Gal X 140 gallhr 

### 10.330 Ib SOX/hr 

## Calculation of Ib SOX 

## I MMBTU =

270 SCFSOX 1.00E+06 SCF Rue Gas X 12200 SCFFlueGas**~EJTU** X 2.63E-03 IbMole SCFSOX X 64 Ib IbMole


### 0.555 Ib SOXIMMBTU 

## kaJculation of tons SOX 

## I 

# yr 0.074 Ib SOX/Gal X 100000 gal/yr X 1 tons 

### = 2000 Ib 

### 3.689 tons/v," .j:>. IV .j:>. 

### .L.. 0\ -...!

# Combustion of Natural Gas
C
0.34 SCFSOX 1.00E+06 SCF Rue Gas X 11990 SCF Flue Gas 

### MMBTU X 2.63E-03 IbMole SCFSOX X 64 Ib IbMole 0.001 Ib SOXIMMBTU 

## Cl.lculatjon oUb SOX 

## I SCF
0.001 IbSOX 

### MMBTU X 1000 

### BTU 9:F =
0.687 Ib SOXlSCF 

## Calculation of Ib SOX 

## I 

# hr
0.001 IbSOX 

### M'v1BTU X 20.9 

### MMBTU hr =
0.014 Ib SOXlhr 

## kalcul.mlon of tons SOX 

## I 

# yr

N 

### .b 01 00 0.0143 Ib hr 

### 0.057 

### '0!1s/vr X 7985 hr yr X 1 2000 tons Ib =



# ) 

# ) )

## ) 

# ) 

# ) Calculation of SOX using AP 42 Emissionfactors
Emissionfactor Sulfur Dioxide Waste Oil : 147 Ib/1000 gal Emlsslonfactor Sulfur Dioxide Natural Gas: 0.6 Ib/mill SCF Sulfurcontent in Waste Oil : 0.5 % 

# Combustion of Waste Oil
147 Ib/gal 

# x 140 gallt'lr 

# x 0.5 = 10.290 Ib SOXlhr 

### 1000 

## Calculation of tons SOX 

## I yr 147 lb/gal 

### X 100000 gallyr X 1 tonsllb 

# x 0.5 :: 3.675 

### tons SOXlyr 

### 1000 2000 

# Combustion of Natural Gas
0.6 Ib/SCF 

# x 350 SCF/min 

# x 60 min/hr :: 

### 1000000 0.013 'b SOXlhr 

## Calculation of tons SOX 

# I yr 0.013 Ib X 7985 

### hr X 

### 1 tonsllb :: 

### hr yr 

### 2000 0.050 

### ,ons**SOXly~**

N 

# t 0\ \0.1Ll-AIR**F~CE BAS~**  UTAH**~o-::>~** •**'~**



### Montie R. 

### Keller, Manager Technical Evaluation 

### Bureau of Air Quality 1950 

### West North Temple salt Lake 

### City, Utah 84116-0690 

### RE: Intent to 

### Approve Waste 

### oil Boiler, Building 1703 

### (BAQE-201-91) Request 

### for an 

### Extension of Comment Period DearMr 

### Keller 

### We request an extension of comment period to II May, 1991 

### to allow 

### us to 

## fully evaluate and comment on 

### condition 9 of the 

### referenced J:ntent 

### to Approve. We will 

### request a meeting 

### to discuss this matter with 

## you. sincerely

# J~I<.~~ James R. van annan 

### Director· of Environmental 

### Management



# A. 

# L

# =- COMBAT STRENGTH THROUGH LOGISTICS 4.2.4-470**TOO~** 

## wa/::nv-oo 90tt /././. T09.g. 

## n:n 16lsvroUTAH BUREAU OF AIR QUALITY NEW/MODIFIED SOURCE PLAN REVIEW James R. Van Orman Director of Environmental Management Department of the Air Force Headquarters Ogden Air Logistic Center Hill Air Force Base, Utah 84056-5990 RE: Waste Oil Boiler and Two Davis County CDS A1 Tanks, Bldg 1703
ENGINEER: J. Tim Blanchard DATE: February 25, 1991 NOTICE OF INTENT DATED: March 27, 1990 PLANT CONTACT: Jay Gupta PHONE NUMBER: (801) 777-7651 PLANT LOCATION: Hill Air Force Base, Bldg 1703 FEES: Filing Fee $100.00 Review Engineer

- 15 hours at $50.00/hour $750.00 Modeler

- 00 hours at $23.22/hour $000.00 Computer Usage Fee $000.00 Notice to Paper $24.00 Travel

- 00 miles at $0.23/mile sOOO.OO Total $874.00 APPROVALS: Engineering Unit Manager

# ~~~'~-T---~a2~~-~~~~~7J~~/;'L------------ Applicant Contact Made
Evaluation Section Manager Technical



### 4.2.4-471I. DESCRIPTION OF PROPOSAL Hill 

### Air Force Base has filed a notice of intent dated March 27, 1990. They are proposing to install and operate a boiler in Building 1703. The proposed boiler will be equipped with a dual burner capable of firing waste oil and natural gas. The proposed boiler will use natural gas as the primary fuel. Waste oil will be burned as it 

### is available. As a part of the base waste minimization plan, HAFB 

### is proposing to burn waste oil in the proposed boiler and recover generated heat for process steam. The boiler will have the following equipment/parameters: A. 500 hp Scotch Marine 3 Pass B. Low NOx rated dual burner 

## c. Two (2) existing 20,000 gallon waste oil storage tanks D. Oil filtration system E. Associated piping 

### F. Chemical feed pump, chemical mixing tank, appropriate tie-ins to existing feed water, natural gas line systems, and controls and alarms Waste oil will be collected in two existing 20,000 gallon tanks located approximately 2 miles from the boiler. One tank will be used at a time to accept waste oil from throughout the base. The following will contribute to the waste oil used: A. PD 680 Solvent (15%) B. Turbine engine oil (11%) C. lP-4 Turbine engine oil (13%) D. Waste crank case oil (19%) E. Hydraulic fluid (25%) F. Purge Fluid (17%) Waste oil is collected from the sources in 55 gallon drums and will be tested in bulk for halogen content using the Blastine Test. Waste oil passing this test will be pumped into the waste oil collection tank. Once the waste oil collection tank is full, a sample will be taken from the tank for a metal and halogen test. If no halogenated solvents**a~e** found and metals are**~ithin** permit limits, the waste oil will be transferred to the boiler fuel tank and burned.



### 4.2.4-472Building 1703 has two existing 250 hp gas-fired boilers which will continue to operate on natural gas. The following numbers only describe the proposed waste oil boiler operation: A. Annual operating hours 1) 645 hours per year for the waste oil operation 2) 7,985 hours per year for the natural gas operation B. Proposed boiler capacity

- 20.9 x 106 BTU/hr C. Fuel

- natural gas/waste oil D. Heating values 1) 133,000 BTU/gallon of waste oil 2) 1000 Btu/scf of natural gas E. Fuel input 1) 155 gallons of waste oil per hour 2) 20,900 scf of natural gas per hour F. Stack diameter

- 28 inches G. Stack height

- 30 feet above ground 

### II. EMISSION SUMMARY The emissions from this new emission point will be as follows: Particulate 2.85 tons/year PM 10 2.85 tons/year S02 6.72 tons/year 

### NOx 9.85 tons/year CO .3.17 tons/year VOC 0.33 ton/year Barium 0.0008 ton/year Cadmium 0.0013 ton/year Chromium 0.0011 ton/year Lead 0.0358 ton/year



# - 4.2.4-473

# -. III. BEST AVAILABLE CONTROL TECHNOLOGY (BACT) ANALYSIS BACT will be required for all emission points. This includes both the boiler and the waste oil tank. Boiler The proposed boiler is equipped with a low NOx designed burner that is guaranteed by the manufacturer for 75 ppmv or less for NOx emissions. This low NOx designed burner is recommended as BACT for the proposed boiler. The boiler must be properly maintained and operated in good working condition. The use of waste oil fuel which meets the sulfur standards established in 40 CFR Part 60 Subpart Dc is required. For fuel oils, the NSPS standard is 0.50 lb of sulfur dioxide per million BTU heat input. Regarding metal contents, the. oil must meet the specifications which are outlined in 40 CFR 266, Subpart E, "Used Oil Burned for Heat Recovery". Section 1.132, UACR defines the term "significant". No. 2b in the definition states the following: "For purposes of Section 3.6, it shall also mean: b. In reference to a net emission increase or the potential of a source to emit a pollutant subject to regulation under the Clean Air Act not listed above, any emission rate." 

# -. Therefore, if HAFB already had a PSD permit, this would be a significant emission increase under PSD. The engineering section recommends that BACT for the metals emissions be compliance with 40 CFR 266, Subpart E and a consumption limitation as proposed. The quantities of CO, VOC, S02 and PM 10 annual emissions listed in Section II are such that it is not cost effective to install control systems for these pollutants. It is recommended that BACT for these listed pollutants be the proper operation and maintenance of the boiler in accordance with the manufacturer's instructions. Waste Oil Tank The only pollutant in question here is VOC emissions. Emissions associated with the waste oil tanks are from tank breathing losses and working losses. Due to the low true vapor pressure of waste oil (less than 1.50 psia). and the small tank sizes, the engineering section recommends that BACT for these two tanks be a fixed roof tank. A vapor recovery system is not cost effective for tanks with these amounts of proposed emissions.



### 4.2.4-474IV. APPLICABILITY OF FEDERAL AND UTAH AIR CONSERVATION REGULATIONS (UACR) This notice of intent is for a modification to an existing major source. It is not a new major source or a major modification. The following federal and state regulations have been examined to determine their applicability to this notice of intent: 1. Section 3.1.1, UACR

- Notice of intent required for a modification. This regulation applies. 2. Section 3.1.8, UACR Application of best available 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 3.1.10, UACR

- Additional information requirements for a new major source or major modification which emits precursors of ozone and impacts an area of nonattainment for ozone. This notice of intent does not represent a new major source or a major modification. Therefore, this regulation does not apply. 5. Section 3.2, UACR

- Particulate emission limitations for existing sources which are located in a nonattainment area. HAFB is listed in this regulation. As of the date of the regulation, the boilers are limited to 20% opacity. This new boiler is not listed in this regulation. Therefore, this regulation does not apply. 6. Section 3.3.1, UACR

- Emission limitations for new major sources or major modifications which are located in a nonattainment area or which impact a nonattainment area. This notice of intent does not represent a new major source. Therefore, this regulation will not apply. 7. Section 3.3.2, UACR

- Review requirements for new major sources or major modifications which 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. 8. Section 3.5, UACR

- Emis sion 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 Bureau of Air Quality every year. HAFB must comply with this regulation. Therefore, HAFB shall include emissions from sources listed ir. this approval order in its annual emission inventory.



### 4.2.4-475

# ,­ 9. Section 3.6.5(b), UACR

- Prevention of significant deterioration (PSD) review requirements for new major sources or major modifications. This notice of intent does not represent a major source or a major modification under PSD rules. Therefore, this regulation does not apply. 10. Section 3.8, UACR

- Stack height rule. This regulation 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 51.1. A de minimums height of 65 meters (213.2 feet) is allowed. This proposed boiler does not have stacks which exceed 65 meters in height. It is in compliance with this regulation. 11. Section 3.11, UACR

- Visibility screening analysis requirements. This regulation 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 notice of intent does not represent a new major source or a major modification under UACR rules. Therefore, this regulation does not apply. 12. Section 4.1.2, UACR

- 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). This regulation applies. 13'. Section 4.1.9, UACR

- EPA Method 9 to be used for visible emission observations. This regulation applies. 14. Section 4.2.1. UACR

- Sulfur content limitations in oil and coal used for combustion. This notice of intent does contain oil combustion. However, the limitation actually imposed ( 0 . 5% sulfur by weight) is more stringent and takes precedence. 15. Section 4.7, UACR

- Unavoidable breakdown reporting requirements. This regulation applies. 16. Section 4.9, UACR Review requirements for volatile organic compound (VaC) sources located in a nonattainment area for ozone. The waste oil combustion is not covered in this regulation. The capacity of the waste oil storage tank is less than the regulated capacity of 40,000 gallons, and the true vapor pressure is less than 1.52 psia. This regulation will not apply. 17. Section 5, UACR

- Emergency episode requirements. This regulation applies. 18. National Emission Standards for Hazardous Ai;:**?oll~tants** (NESHAPS)

­ There are no NESHAPS for this notice of intent. 

# -,

4.2.4-47619. National Ambient Air Quality Standards <NAAQS)

- This Source is located in Davis County, which is a nonattainment for ozone. The Bureau of Air Quality guidelines does not call for this source modification to be modeled for any pollutant. The Bureau has found through experience that. because of the small increase in quantity of emissions involved and the conservative predictions made by modeling, a source or emission point of this small increase is very unlikely to cause a new violation of the NAAQS. 20. 40 CFR**50~40c** to 50.48c, NSPS, Subpart Dc. Standards of Performance for Small Industrial-ColIUllercial-Institutional Steam Generating Units

- This regulation applies. The effective date is June 9, 1989. An 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 les s, but greater than 10 million BTU/hr. The heat input is 20.9 million BTU/hr. The standards are as follows: Sulfur Dioxide If oil is the only fuel, no owner /operator shall cause to be discharged into the atmosphere any gases which contain S02 in excess of 0.50 Ib per million BTU heat input. Particulate



# - If oil is the only fuel and the heat input is 30 million BTU/hr or less but greater than 10 million BTU/hr. there is no standard. There are also recordkeeping requirements. 21. 40 CFR 50.110b to 50.1I7b, NSPS. Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessel s) for Which Construction, Reconstruction. or Modification Commenced after July 23. 1984. This regulation applies to the following tanks: A. Storage capacity greater than or equal to 151 cubic meters (40,000 gallons) with a volatile organic liquid whose true vapor pressure is from 5.2 kPa to 75.5 kPa B. Storage capacity greater than or equal to 75 cubic meters but less than 151 cubic meters (40.000 gallons) with a volatile organic liquid whose true vapor pressure is from 27.6 kPa to 76.6 kPa This regulation will not apply to these two tanks.



# ,.­ 4.2.4-47722.

V. 1.

2. RECOMMENDED APPROVAL ORDER 40 CFR 60.14. Definition of Modification Any physical or operational change to an existing facility which 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 faci:ity, if that increase can be accomplished without a capital expenditure on that facility 3) An increase in the hours of operation 4) Use of an alternative fuel or raw material if, prior to the date any standard under this part 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 of any system or· device whose primary function is the reduction of air pollutants 6) Relocation or change in ownership This notice of intent is a modification under this rule. 

# - CONDITIONS Hill Air Force Base shall install and operate the waste oil fired boiler rated at 20.9 million BTU/hr in Building 1704 according to the information submitted in the notice of intent dated March 27, 1990 and additional information submitted to the Executive ·Secretary dated October 31,**1990~** The boiler shall be a dual fuel boiler with the capability of burning waste oil. 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 the appropriate and relevant conditions. The approved installation shall consist of the following equipment: A. 500 hp Scotch Marine 3 Pass boiler or equivalent complete with dual (natural gas and waste oil) burner

- Equivalency shall be determined by the Executive Secretary. B. Oil filtration system; and C. Associated piping, control, and alarms, chemical feed pump. chemical mixing tank, and appropriate tie-ins to existing feed water and natural gas line systems.



### 4.2.4-4783. Visible emissions from the boiler shall not exceed 20% opacity. Opacity observation of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. 4. The following fuel consumption limits for the boiler shall not be exceeded without prior approval in accordance with Section 3.1, UACR: A. Waste oil consumption

- 100,000 gallons per 12 month period B. Natural gas consumption

- 166.89 x 106 scf per 12 month period Compliance with the annual limitations**sh~ll** 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 shall be kept for all periods when the plant is in operation. Records of consumption 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. Natural gas fuel consumption shall be determined by the use of records from a fuel meter. Waste oil consumption for the boiler shall be determined by the use of records from the waste oil transfer log. The records shall be kept on a daily basis. Hours of operation shall be determined by supervisor monitoring and maintaining of an operations log.
5. The emissions of sulfur dioxide from the boiler while burning waste oil shall not exceed 0.50 lb per million BTU heat input. 6. Stack testing to show compliance with the emission limitation of condition 15 shall be performed as specified below: Testing Status Ini tial comp.liance testing is required. The initial test date shall be within 180 days after the start up of a new emission source. NotificationThe 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) or Mine Safety and Health Administration (MSHA) approvable access shall be

..

# - provided to the test location
. 

### 4.2.4-479Sample Location 

# -. 40 CFR 60. Appendix A. Method 1 Volumetric flow rate 40 CFR 60. Appendix A. Method 2

40 CFR 60. Appendix A. Method 6 or 19 CalculationsTo 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 at which the facility will be operated. 7. The ash content of any waste oil burned shall not exceed 0.65 percent by weight. The ash content shall be tested using the appropriate ASTM method if directed by the Executive Secretary. 8. The waste oil used for fuel shall contain no more than 1000 ppm by weight of total halogen. The halogen content shall be tested by ASTM Method D-808-81 before waste oil is transferred to the boiler tank and**burne.~** .. 

## Jr .,0J.

......,.,J...>.."-\ 9. The**fOllowing~limitations** of metal centent in waste oil shall not be exceeded: A. Total halogens

- 1000 ppm by weight B. Cadmium - 2 ppm by weight C. Chromium

- 10 ppm by weight D. Lead

- 100 ppm by weight E. Arsenic - 5 ppm by weight The owner/operator shall provide test certification for each load of waste fuel oil from 55 gallon drums or bulk carrier. Certification shall be either by his own testing or test reports from a testing contractor. Records of waste fuel oil consumption and the test reports shall be kept for all periods when the plant is in operation. The records 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. 

### 4.2.4-48010. In addition to the requirements of this approval order, all provisions of 40 CFR 60, NSPS Subparts A and Dc apply to this installation. 11. Eighteen months from the date of this approval order the Executive Secretary shall be notified in writing of the status of construction of this project unless the construction is complete and operation has commenced. 12. All installations and facilities authorized by this approval order shall be adequately and properly maintained. 13. 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**complianc~** with all other applicable federal, state, and local regulations including the Utah Air Conservation Regulations. Annual emissions for this boiler are calculated at 2.85 tons/yr for particulates, 2.85 tons/yr for PM 10 ' 6.72 tons/yr for S02, 9.85 tons/yr for NOx ' 3.17 tons/yr for CO, 0.33 tons/yr for VOCs, 0.0008 ton/yr for barium, 0.0013 for cadmium, 0.0011 ton/yr for chromium, and 0.0358 ton/yr for lead. These calculations are for the purposes of determining the applicability of PSD and nonattainment area major source requirements. of the UACR. They are not to be used for purposes of determining compliance. TIM.B HAFB1703



### 4.2.4-481

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### DEPT. OF THE AIR FORCE: -' LOCATION: HILL AFB

- BUiG 1703

- DUAL; FUEl. BOILER ==.""....,.,...



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