,,",-..,-, (""" : ; ......... ..L- I -."- ..-.. .,.......,


:~~ T,;::~ "~-, P	 n ':­ ....... . 'H,':-ilJ	 .:.a 0:-;.: .,


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

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 of this 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 increase for NO. emissions from the approved used oil boiler while burning used oil is approved. 

The emissions were changed from 110 ppmv as stated in the original NO! to 240 ppmv. The AO has been 

modified to reflect the requested change (Reference conditions #5 for 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 of the 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 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) 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 Iimitation. 

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 of total 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 of the 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 of two 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 of the installation as 

an initial campI iance inspection is required. Eighteen months from the date of this 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 PMIO 

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 

4.2.4-440
 
Michael 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 of Air 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 rFiring 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 MMBTUlHr1r~ , , .T:"\"jj---.",; I 

I 1,/" " I . .. /' •. ( \ ')'6 ) Max Oil Firing : 100000 gal/yr t '\ -,.1. II ,~ J 1/ I8r '/1 

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

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 ~f' I ( , - t ,'\ L I ·1"J (:) )f /b ') 'I 1 ,,'(}u 

?IFf -..---~. .'j'~, , ' 

.J 0 1·"' ( 
Combustion of Waste Oil 

Calculation of ~OXI 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= = 

101·~~~ !~ 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 ~' ay, ? ' 

,." 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 b1;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 

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

) ) )
 
IU 

( Date: 7/8/94 ) 

(Message:)
 

RECEIVED 

\FAX COVER SHEET) JUL 08 1994 

Air Quality 

From: 

Andreas Zekom ED~roDDEI1talMaDagmmt Dirccrol'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 of the waste oil. I 

I 

I 

Sincerely i 

I 

i 

,i#JhtlJJ , Andreas Zekorh 

J 4.2.4-447 ( Total ,umber of pages including cover sheet: 9 
,...
 ~u--~O-.JJ~ .~.~. , """ I

•• 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 

EHPI j 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 

INDUSTRIAL ANO COMMERCIAL. BURNERS AND BOILERS " I j 

.'-Yr­

;"";" 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 "Dft 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 

4.2.4-449
 

IU 

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 

(Corr to 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 

Carbon MonoxidJ (COl 50 0.0367 I 

i 

SOx (c8 PPM wtJ SUlfur in Fuel) 0.4 0.0007 

! 

i 

vee (Methane + Non-Methanel 15 0.0080 I 

i 

I 

NOx I

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 

,­

4.2.4-451 
lU 

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 

R uired Combustion Air SCFM 3867

rees F. Gross ACFM 6748 

Flue Gas Veloe' r Minute 2148 

4.2.4-452
 
IU 

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 

(Corr to 3% 02) 1,000.000 BTU's @ 100% Firing Rate 

%08 

0.82 

21.86 

0.26 

8:25 

? ,?.-r;c (0')/ t-Kl(tjCf" :;:.--<­

::; 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: 

0 1.2

'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) 

1_\1":- #2&.8011 .2 '::'011 , ,eo) Natural Gas &Propane 

Convqrslan Equations
 

Conversion Equations
 .2 &16 Oil: 

.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 

...
 

lSI

..

e1 

.... 

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P 

3 

-j 

0 

i

\D 

\D 

'U 

,., ,) ) #iJ#; ) e 
--

--

--

'-'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 

. . ........ .:.. . .. -: ~....,. .", 

VL · 

.... 

_..,--_... - --", -'- 1-

/ 

r-' ,--- 1--

-It I 

r---' -.-

L / .- 1-;-- . -

1/ 

r--- - r--- /-,-- - --

--t--. I 

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

--A-- .-r--- l/i 

0.14
 

Ul 0.21 f-...I_._ I ..T .. 1 I t-- ~-~ --I__ __ ~_I·-l_ - J- -.---­ ~q~ 1.20

- 0.18 I---.--+-----I-I-I..-J----J--I -1--1- -1-' 

; 

0.11 - O.t. lI.1. --1--·1-1--1----1---1-'--t­ -- ­ i 

g
 ..
 

/

..... D.U _.\­ -.,. en c c •.n --·---l--I- -1·- - -. - - _.\ .9 o.n 0 

j 0.10 :~E 0.10 --- -- -or

8 

IU 

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

... I Z w 0.01 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&1I60JI - .2&.6011

- - Natural Gas & Propane - - Natural Gas & propane

J:> Conversion EQuaiiOOi Cgnversion EQuations N 

'2 & #6 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
 

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j
 

I
 

d 

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0 


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'; 17-1;' (;'j7 

e Oil Environment4' dcterization of 911 ( ( I 

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co 

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.... 

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co M. 

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-.r 

0 

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N 

Ul 

Ul 

M 

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co 

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co 

\0 

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0 0 0 0 0 0 0 0 0 

·

0 

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co 

0\ 

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\0 

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...,

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· a .... N 0\ . . Ul 

0 

a 0 0 0 a 0 a 0 0 

· 0 

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0 

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I u 

co 0 

N,..... V 

0 

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"0 

co 

0 "0 0 

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...... \0 N 

0

.... N 

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

0 0 0 0 0 0 

0

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0· :z :z :z :z :z :z :z :z 

-\0 

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. 

v 

....

e 

0\ 

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e
 0 \oJ
 .... 

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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 f0 
I

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 

Ind us t ria1 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 

pre tre 837 143 330 

31.3 25.7 Burner ,la....,ut o Use wi 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.... • $epi rlt 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.' 

Al uminum, pretrfl ppm <0.5 758 

I ron. 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 Corpard Ion lUI 

adv anc ed rep roce S sing tec hn i ques 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 ,. 

r 7 l.<-: 6.7 155 529 78 63

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
 
DEPARTMENT OF THE AIR FORCE - RECEIVED

HEADQUARTERS OGDEN AIR LOGISnCS CENTER (AFMC) 

HILL AIR FORCE BASE. UTAH ~1ru L 20 1994

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 '-' _""' , 'I / . J_'

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 

4.2.4-460 
0 

-0 

-l 

-l 

M

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
 

1000 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: 100 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: 1000 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· , , CQmbystion Qf Waste 011 (1I.M, I CQmbystlon Qf Natural Gas , '/ : 

0.074 Ib SOX/Gal (,) ~;:", ) If! (; s,.)

10.330 Ib SOX/hr I, :) 'J \' I ~.1 -,) .- 'T[ l " 0.014 Ib SOXlhr 

0.555 Ib SQXlMMBTU 

,·1 r,'- )' ) j j' ~,I:> ( ~.~~~ ~~ ~~XIMMBTU Ci!S9 tQns/y;:; . / ; '7 r1 f/..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 

Dear	 Mr 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 16lsvro 
UTAH 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 

Technical Evaluation Section Manager

4.2.4-471
 
I.	 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. 

4.2.4-472 
Building 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
 

PM10 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 PM10 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. 

4.2.4-474
 
IV.	 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. -, 

4.2.4-476
 
19. 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 / opera tor 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. 

,.­

4.2.4-477
 
22. 

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. 

4.2.4-478 
3.	 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 

Initial comp.liance testing is required. The initial 

test date shall be within 180 days after the start up of 

a new emission source. 

Notification 

The applicant shall provide a notification of the test 

date at least 45 days prior to the test. A pretest 

conference shall be held if directed by the Executive 

Secretary. It shall be held at least 30 days prior to 

the test between the owner/operator, the tester, and the 

Executive Secretary. The emission point shall be 

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 . 

4.2.4-479 
Sample 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 

Calculations 

To determine mass emission rates (lbs/hr. etc.), the 

pollutant concentration as determined by the appropriate 

methods above shall be multiplied by the volumetric flow 

rate and any necessary conversion factors determined by 

the Executive Secretary to give the results in the 

specified units of the emission limitation. 

Source Operation 

For a new source/emission point, the production rate 

during all compliance testing shall be no less than 90: 

of the production rate 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. 

4.2.4-480 
10. 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 PM10 ' 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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4.2.4-482
 
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-
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4.2.4-483
 
~SOURCE: BOlLER - WASTE OIL COr~USTION

:.> 1 

CONTROLLED 

COl'lF'ANY tWiE: DEPT. OF THE AIR FORCE: -' 

LOCATION: HILL AFB - BUiG 1703 - DUAL; FUEl. BOILER ==.""....,.,... 

.. 

~':-OrOOOO

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4.2.4-484 
0,_•• ­

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iOTAL PAR1JCULAiE 

SuuRCE: BOILER - NATURAL GAS FIPJ:D 

COMPANY NAHE~ DEFT. OF THE AIR FORCE 

L~CAiION: -H1LL ArB - BLDG 1703 - DUAL FUEL BOILER 

.0':' hrii·.'­ • it •••• t " t " •• " • ) • t •••• t t t " t " t t •• t t • " ... t t 

~MCF/YH

riO CON:.n IONS 

••• t . 

4.2.4-485
 
Lt = Lb +Lw 173.7:;4 a,SIYR 

luNlYR =(LB/YRl!(2000 LB/TONl •••••••••••••••••••• 0.OB7 TOlllYR 

4.2.4-486
 
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(BREATHIllG LOSS) ••••••••••• t •••••••• t ••••• 101.97 LBSIYR

iONIYR = (LEIrRJ(2000 LBfTOlD . 0.051 TONIYR 

-


4.2.4-487
 
............................ 

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130.0 Ib/lb-~ole

(SIi. 

4.2.4-488