........ .. -­ :.:. -."=- -s- :-. !\. ." ~.­ - ~.

'" .• _. ~..... J' - --: ._..­

"1--" _:..!... __0.:- &1-'-:' 

DEPARTMENT OF ENVIRONMENTAL QUALITY 

DIVISION OF AIR QUALITY 

Miehael O. Luvia~

0-'; 150 Nonh 1950 West Reply 10: Sl.\te of Utah 

Dianne Division of Air Qualily R. Nielson. Ph.D. Salt Lake City. Ulah 84114 

~ov­ (801) 536-4000 P.O. Box 144820

Russell A. Roberts (80 I) 536-4099 Fax Salt Lake City. Utah 8~ 114-4820 

ou- (801) 536-4414T.D.D. 

August 27, 1993 DAQE-D752-93 

James R. Van Orman
 

Director of Environmental Management
 

DOO-ALClEM
 

7276 Wardlegih Road
 

Hill Air Force Base, Utah 84056-5127
 

Re: Modified Approval Order for: 

A. Replacement Boilers in Buildings 1624, 1904,2104.2203 

B. Paim Spray Booth in Building 751 

C. Carbon Brake Coating Process in Building 507
 

Davis County CDS Al NA
 

Dear Mr. Van Orman: 

The Division of Air Quality received a letter dated June 1, 1993, requesting that condition 4E of the 

Approval Order (AO) DAQE-492-92 be modified. Condition 4E required that the boiler stack be tested 

at 90%, 70%, and 50% of the boilers capacity. This condition was changed to required tesling at 90% 

of the boilers capacity. The new condition is now numbered 6E. Also. the generators Jisted in DAQE492-92 are now consolidated in a separate AO (DAQE 719-93). Therefore. they have been deleted from 

this AO. This air quality AO authorizes the project with the following conditions. Failure to comply 

with any of the conditions may constitute a violation of this order. 

1. Hill Air Force Base shall install and operate the following: 

A. The boilers located in Buildings 1624, 1904,2104. and 2203 

B. The paint spray booth located in Building 751 

C. The carbon brake coating process located in Building 507 

These shall all be operated according to the information submitted in the Notice of Intent 

dated April 24, 1991, and additional information submitted to the Executive Secretary 

Jated July 30,1991; December 26. 1991; January 8, 1992, and June 1, 1993. 

A copy of this AO shall be posted on site and shall be available to the employees who 

.operate the air emission producing equipment. All employees who operate the air 

emission producing equipment shall receive instruction as to their responsibilities in 

operating the equipment in compliance with all of the relevant conditions. 

4.2.4-489 

?ri"ted 0" recycled paper 
DAQE-0752-93 

Page 2 

2.	 Definitions of terms, abbreviations, and references used in this AO conform to those used 

in the Utah Air Conservation Rules (UACR), Utah Administrative Codes (UAC), and 

Series 40 of the Code of Federal Regulations (40 CFR). These definitions take 

precedence unless specifically defined otherwise herein. 

3.	 This AO shall replace the AO dated May 22, 1992 (DAQE-492-92). 

4.	 The approved installations shall consist of the following equipment: 

A.	 Replacement boilers located in Buildings 1624,2104, and 2203, rated at 250 HP 

- The boilers shall be equipped with low-NOx burners using natural gas as the 

primary fuel, with #2 fuel oil being used as the back-up fuel. 

B.	 Placing of an existing 400 HP boiler in Building 1904 using natural gas as the 

primary fuel with #2 fuel oil being used as the back-up fuel. 

C.	 A paint spray booth equipped with paint arrestor tilters located in Building 751 

and using low VOC compliance paint. 

D.	 An existing electric furnace to be used for baking Bendix P-Il coating on carbon 

brake disks in Building 507. 

5.	 Emissions to the atmosphere from the indicated emission point shall not exceed the 

following rates and concentrations: 

A.	 Exhaust stacks for 250 HP replacement hoilers in Buildings 1624, 2104, and 

2203: 

I) NO x - 40 ppm at 7% oxygen: 0.24 Ih/hr 

2) CO - 100 ppm at 7% oxygen 

B.	 Exhaust stack for 400 HP replacement boiler in Building 1904, - NOx - 1.84 

Iblhr 

C.	 Exhaust stack for carbon brake coating in Building 507 - Phosphorous Oxides ­

1.33 Ib/hr 

6.	 Stack testing to show compliance with the emission limitations of condition #5 shall be 

performed as specified below: 

A.	 Emission Point Pollutant Testing 

1.	 Boiler exhaust stacks 

in Bldgs 1624, 1904, 

2104, and 2203 NOx § *** 

CO */** ** 

4.2.4-490 
DAQE-D752-93 

Page 3 

2.	 Carbon brake coating 

exhaust in Bldg 507 PO. */** ** 

B.	 Testing Status (To be applied above) 

*	 No initial testing is required. However, the Executive Secretary may 

require testing at any time in accordance with R307-1-3.4.1, UAC. The 

source shall be tested if directed by the Executive Secretary. 

**	 The testing method shall be submitted to the Executive Secretary for 

approval before the testing is performed. The source shall be tested if 

directed by the Executive Secretary. 

§	 The stack shall be tested for NO. emissions compliance within 30 days 

of startup using a portable testing instrument approved by the Executive 

Secretary. 

***	 The boiler stack shall he. re~ested eve~y 30 ~8:'~~ 'J"~~:'~;~;- ~2\'S ± 10 

days. The maximum time between tests shall ne .») Doiler operating 

days. 

C.	 Test Procedure 

Boiler stack emissions testing shall be performed by the following procedure or 

an approved equivalent. Equivalency shall be determined by the Executive 

Secretary and approved prior to tests being conducted. 

D.	 Sample Pon 

A sampling POrt shall he installed in each boiler exhaust stack in accordance with 

40 CFR 60. Appendix A. Method #1 or as approved by the Executive Secretary. 

The sample port shall be safely accessible to the tester. operatOr, or inspector in 

accordance with OSHA standards. 

E.	 Operating Rate 

Each hoiler stack shall be tested in accordance with the schedule in Condition 

#6.A.1. The steam production or operating rate during testing shall be set at 

90% ± 10% of the boilers capacity. 

F.	 Test Instrument 

The test procedure shall he conducted using a portable testing instrument 

approved by the Executive Secretary. The testing instrument shall be calibrated 

on site with a suitable NBS referenced or traceable calibration gas in accordance 

with the instruction of the test instrument. 

4.2.4-491 
DAQE-G752-93 

Page 4 

G.	 Test Procedure 

The test shall be conducted in the following manner: 

1.	 The gas sample shall be drawn according to the instructions of the test 

instrument heing used. 

2.	 The sample value shall be determined from the test instrument. 

appropriate calculations made. and the data recorded. 

H.	 Failed Boiler Status 

If the boiler is unable to anain the emission limitation in condition #5. at anyone 

of the operating rates specified in condition 6E, the boiler shall be assigned to 

a lower position on the "use priority list" (used as standhy where possible) until 

the unit has heen repaired or maintenance performed and a successful retest 

completed. 

Maintenance and repairs of any hailer that fails the paiodical test shall be 

performed within 15 days or the hoikr shall he idled. 

If a hailer. that has failed a test", is repaired and a successful retest completed 

according to the limitations of Condition #5.A within 15 days, the boiler shall be 

determined to not have heen in violation. 

A boiler that fails the retest after repair shall be idled until further repairs are 

made and a successful retest completed. If the hoiler demand requires the boiler 

to be operated. it shall he hase loaded at the rate that will result in the lowest 

emissions rate possihle until the hoiler can he repaired and shown in compliance 

by the above test. 

Operating a hoiler that has failed the ahove "retest after repair" shall he 

determined [0 he a violation of this AO. 

I.	 Reports 

A copy of all test reports containing the test results. any calculations required, 

and the test instrument calibration data shall he retained by the owner/operator 

for two years. The reportS shall he made availahle to the Executive Secretary or 

his agent upon request. An annual summary report of all the test results with a 

copy of the periodical reports shall be submined to the Executive Secretary no 

later than January 31 of each year for the previous cal endar year. 

7.	 Visible emissions from the following emission points shall not exceed the following 

values: 

A.	 250 hp Boiler Building 1624 10% 

B.	 400 hp Boiler Building 1904 10% 

C.	 250 hp Boiler Building 2104 10% 4.2.4-492 
DAQE-0752-93 

Page 5 

D. 250 hp Boiler Building 2203 10% 

E. Paint spray booth Building 751 10% 

F. Carbon brake furnace Building 507 0% 

Opacity observations of emissions from stationary sources shall be conducted in 

accordance with 40 CFR 60, Appendix A, Method 9. Visible emissions from mobile 

sources and intermittent sources shall use procedures similar to Method 9, but the 

requirement for observations to be made at IS-second intervals over a 6-minute period 

shall not apply. 

8.	 The emissions of VOC from paint spray booth in Building 751 shall not exceed 0.040 

tons per 12-month period without prior approval in accordance with R307-1-3.1, UAC. 

Compliance with the limitation shall be determined on a rolling 12-month total. Based 

on the tirst day of each month, a new 12-month total shall be calculated using the 

previous 12 months. The emissions of VOC from the spray hooth shall be determined 

by maintaining a record of paints and thinners used. The record shall include the 

following data for each item used: 

A.	 Name of paint or thinner 

B.	 Weight in pounds per gallon 

C.	 Percent VOC by weight 

D.	 Amount used on a daily basis 

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 upon request, 

and shall include a period of two years ending with the date of the request. VOC 

emissions shall be determined by the following manner: 

VOC =	 (% Volatile hy Weight / 100) x (Density lh/gal) x (Gallons Consumed) 

/ (2.000 Ih/ton) 

The VOC content in pounds for each individual item or surface coating used shall be 

calculated. and then the total of all items shall be summed. such that the cumulative total 

shall not exceed the 0.04 tons per 12 month period as specitied. 

9.	 The owner/operator shall use only natural gas as a primary fuel and #2 fuel oil as a 

backup fuel in the replacement boilers located in Buildings 1624, 1904.2104. and 2203. 

If any other fuel is to be used. an AO shall be required in accordance with R307-1-3.1, 

UAC. 

10.	 The sulfur content of any fuel oil burned shall not exceed 0.5% hv weight. The sulfur 

content of any fuel oil or diesel fuel shall he tested if directed hy the Executive Secretary. 

11.	 The paint spray booth shall be equipped with a set of paint arrestor particulate filters or 

equivalent to control particulate emissions. All air exiting the booth shall pass through 

this control system before heing vented to the atmosphere. Equivalency shall be 

determined by the Executive Secretary. 

4.2.4-493 
DAQE-0752-93 

Page 6 

12.	 All installations and facilities authorized by this AO shall be adequately and properly 

maintained. The owner/operacor 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 reponing requirements. The owner/operacor shall 

calculate/estimate the excess emissions whenever a breakdown occurs. The sum total of 

excess emissions shall be reponed to the Executive Secretary for each calendar year no 

later than January 31 of the following year. 

13.	 The Executive Secretary shall be notified in writing upon start-up of the installation, as 

an initial compliance inspection is required. Eighteen months from the date of this AO, 

the Executive Secretary shall be notified in writing of the status of 

construction/installation if constructionlinstallation is not completed. At that time, the 

Executive Secretary shall require documentation of the continuous 

construction/installation of the operation and may revoke the AO in accordance with 

R307-1-3.1.5. UAC. 

Any future moditications to the equipment approved by this order must also be approved in accordance 

with R307-1-3.1.1, UAC. 

This AO in no way releases the owner or operator from any liahility for compliance with all other 

applicable federal, state. and local regulations including the UACR. 

Annual	 emissions from the source listed in this NOI are currently calculated at the following values: 

A.	 Total annual emissions for each of the 250 hp boilers located in Buildings 1624, 2104, 

and 2203 are the following values: 

I) 0.06 tons/yr for Particulate
 

2) 0.056 tons/yr for PM\o
 

3) 0.01 tons/yr for SO~
 

4) 0.47 tons/yr for NO, .
 

5) 0.13 tons/yr for VOC
 

6) 0.46 tons/yr for CO
 

B.	 Total annual emissions for the 400 hp boiler located in huild ing 1904 are the following 

values: 

1) O. I 1 cons/yr for Particulate
 

2) 0.10 cons/yr for PM,o
 

3) 0.02 cons/yr for SO::
 

4) 3.68 tons/yr for NO.
 

5j 0.22 tons/yr for VOC
 

6) 0.73 tons/yr for CO
 

C.	 Total annual emissions for the paint booth located in building 751 is 0.04 tons/vr for 

VOC. 

4.2.4-494 
DAQE-Q752-93 

Page 7 

D.	 Total annual emissions for the carbon brake coating process located in building 507 is 

1.32 tons!vr for pax' 

E.	 Total annual emissions. based on 100 hr/yr operation. for each emergency generator 

located in buildings 1212. and 1213 are the following values: 

1) 0.04 tons/yr for Particulate
 

2) 0.04 tons/yr for PMIQ
 

3) 0.04 tons/yr for SO:
 

4) 0.67 tons/yr for NOx
 

5) 0.05 tons/yr for VOC
 

6) 0.14 tons/yr for CO
 

7) 0.01 tons/yr for Aldehydes
 

These calculations are for the purposes of determining the applicability of PSD and nonanainment area 

major source requirements of the UACR. Except for VOc. they are not to be used for purposes of 

determining compliance. 

Sincerely, 

ussell A. Roberts, Executive Secretary 

Utah Air Quality Board 

RAR:JR:sbq 

cc:	 EPA Region vm. Mike Owens 

4.2.4-495
 
State of Uta.h 

DEPARTMENT OF ENVIRONMENTAL QUAUTY 

DIVISION OF AIR QUAUTY - Michael O. Leavin 

GoYc..­ 150 Nonh 1950 West Reply to: State of Utah 

Dianne R. Nielson. Ph.D. Salt Lake City. Utah 84114 Division oi Air Quality 

ExOC1&ivc Dircclor (801) 536-4000 P.O. Box 144820 

Russell A. Roberts (801) 536-4099 Fax Salt Lake City. Utah 84114-4820 

Dircclol" (801) 538-6621 T.D.D. 

Memorandum To: Lynn Menlove. New Source Review Manager 

From:	 Julie A. Rose. Engineering Technician Jt, 

Subject: Modify Approval Order for HAFB (DAQE-492-92) 

Date:	 August 16. 1993 

=============================================== 

On June 1, 1993, James Van Orman of HAFB wrote a letter to DAQ requesting that AO DAQE-492-92
 

be modified. Condition 4E of this AO reads as follows:
 

4.	 Stack testing to show compliance with the emission limitations of condition #3 shall be 

performed as specified below: 

E.	 Operating Rate 

Each boiler stack shall be tested in accordance with the schedule in Condition 

#4.A.1. The steam production or operating rate during testing shall be set at the 

following rates for testing: 

1)	 90% ± 10% of the boiler's capacity 

2)	 70% ± 10% 

3)	 50% ±'10% 

In order to ramp the boilers to specified load levels and stabilize them for 5 minutes before commencing
 

a test, HAFB has to add the by-pass exhaust ports and exhaust from 1,000 to 9.000 lbs of steam per
 

hour. It takes approximately 3-4 hours per boiler to complete a test at the specified loads, during which
 

time, the steam and energy is wasted and venting steam creates a very noisy atmosphere. This also does
 

not constitute economical operation.
 

These boilers may run close to 90% load during the winter months; however. during the summer months.
 

they may run at 40 %-50 % load or totally shut down.
 

HAFB is requesting that the operating rates in condition 4E be deleted to allow testing at the existing load 

conditions and firing rates. 

4.2.4-496 

Pnntec on recyc1ea oaper 
I recommend that the condition 4E be changed to require testing at at least 90% of the boilers capacity.
 

This will allow HAFB to operate at the boilers maximum capacity. The attached letter should be sent.
 

4.2.4-497
 
James R. Van Orman 

Director of Environmental Management 

OOALC/EM 

Headquarters Ogden Air Logistics Center 

Hill Air Force Base. Utah 84056-5990 

Re:	 Modified Approval Order for: 

A.	 Replacement Boilers in Buildings 1624, 1904,2104,2203 

B.	 Paint Spray Booth in Building 751 

C. Carbon Brake Coating Process in Building 507
 

Davis County CDS Al NA
 

Dear Mr. Van Orman: 

The Division of Air Quality received a letter dated June 1, 1993, requesting that condition 4E of the 

Approval Order (AO) DAQE-492-92 be modified. Condition 4E required that the boiler stack be 

tested at 90%,70%, and 50% of the boilers capacity. This condition was changed to required testing 

at 90% of the boilers capacity. THe new condition is now numbered 6E. Also, the generators listed 

in DAQE-492-92 are now consolidated in a separate AO (DAQE 719-93). Therefore, they have been 

deleted from this AO. This air quality AO authorizes the project with the following conditions. 

Failure to comply with any of the conditions may constitute a violation of this order: 

1.	 Hill Air Force Base shall install and operate the following: 

A.	 The boilers located in Buildings 1624, 1904,2104, and 2203 

B.	 The paint spray booth located in Building 751 

C.	 The carbon brake coating process located in Building 507 

These shall all be operated according to the information submitted in the Notice of 

Intent dated April 24, 1991, and additional information submitted to the Executive 

Secretary dated July 30. 1991; December 26, 1991; January 8, 1992. and June l. 

1993. 

A copy of this AO shall be posted on site and shall be available to the employees who 

operate the air emission producing equipment. All employees who operate the air 

emission producing equipment shall receive instruction as to their responsibilities in 

operating the equipment in compliance with all of the relevant conditions. 

2.	 Definitions of terms, abbreviations, and references used in this AO conform to those 

used in the Utah Air Conservation Rules (UACR), Utah Administrative Codes (UAC), 

and Series 40 of the Code of Federal Regulations (40 CFR). These definitions take 

precedence unless specifically defined otherwise herein. 

4.2.4-498 
Mr. VanOrman 

Page 4 

3.	 This Approval Order shall replace the Approval Order dated May 22, 1992 (DAQE492-92). 

4.	 The approved installations shall consist of the following equipment: 

A.	 Replacement boilers located in Buildings 1624, 2104. and 2203,rated at 250 

HP - The boilers shall be equipped with 'low-NO, burners using natural gas as 

the primary fuel, with #2 fuel oil being used as the back-up fuel. 

B.	 Placing of an existing 400 HP boiler in Building 1904 using natural gas as the 

primary fuel with #2 fuel oil being used as the back-up fuel 

C.	 A paint spray booth equipped with paint arrestor filters located in Building 

751 and using low VOC compliance paint. 

D.	 An existing electric furnace to be used for baking BendIX P-II coating on 

carbon brake disks in Building 507. 

5.	 Emissions to the atmosphere from the indicated emission point shall not exceed the 

following rates and concentrations: 

A.	 Exhaust stacks for 250 HP replacement boilers in Buildings 1624, 2104, and 

2203: 

1) NO, - 40 ppm at 7% oxygen: 0.24 Ib/hr 

2) CO - 100 ppm at 7% oxygen 

B.	 Exhaust stack for 400 HP replacement boiler in Building 1904. - NO, - 1.84 

Ib/hr 

C.	 Exhaust stack for carbon brake coating in Building 507 - Phosphorous Oxides 

- 1.33 lb/hr 

6.	 Stack testing to show compliance with the emission limitations of condition #5 shall be 

performed as specified below: 

A.	 Emission Point Pollutant Testing Retest 

Status 

1.	 Boiler exhaust stacks 

in Bldgs 1624. 1904. 

2104. and 2203 NO, x*'*

CO ;';::/:>,:.'><. 8.>< I 

2.	 Carbon brake coating 

4.2.4-499 
Mr. VanOrman 

Page 5 

exhaust in Bldg 507 *,** I ** . 

B. Testing Status (To be applied above) 

No initial testing is required. However, the Executive Secretary may 

require testing at any time in accordance with R307-1-3.4.1, UAC. 

The source shall be tested if directed by the Executive Secretary. 

** The testing method shall be submitted to the Executive Secretary for 

approval before the testing is performed. The source shall be tested if 

directed by the Executive Secretary. 

§ The stack shall be tested for NO, emissions compliance within 30 days 

of startup using a portable testing instrument approved by the 

Executive Secretary. 

The boiler stack shall be retested every 30 boiler operating days = 1V 

days. The maximum time between tests shall be 35 boiler operating 

days. 

C. Test Procedure 

Boiler stack emissions testing shall be performed by the following procedure 

or an approved equivalent. Equivalency shall be determined by the Executive 

Secretary and approved prior to tests being conducted. 

D. Sample Port 

A sampling port shall be installed in each boiler exhaust stack in accordance 

with 40 CFR 60, Appendix A, Method #1 or as approved by the Executive 

Secretary. The sample 'port shall be safely accessible to the tester, operator, 

or inspector in accordance with OSHA standards. 

E. Operating Rate 

Each boiler stack shall be tested in accordance with the schedule in Condition 

#6.A.1. The steam production or operating rate during testing shall be set at 

90% ..±. 10% of the boilers capacity. 

F. Test Instrument 

The test procedure shall be conducted using a portable testing instrument 

approved by the Executive Secretary. The testing instrument shall be 

calibrated on site with a suitable NBS referenced or traceable calibration gas 

in accordance with the instruction of the test instrument. 

4.2.4-500 
Mr. Van Orman 

Page 6 

G.	 Test Procedure 

The test shall be conducted in the following manner: 

1.	 The gas sample shall be drawn according to the instructions of the test 

instrument being used. 

2.	 The sample value shall be determined from the test instrument. 

appropriate calculations made, and the data recorded. 

H.	 Failed Boiler Status 

If the boiler is unable to attain the emission limitation in condition #5, at any 

one of the operating rates specified in condition 6E, the boiler shall be 

assigned to a lower position on the "use priority list" (used as standby where 

possible) until the unit has been repaired or maintenance performed and a 

successful retest completed. 

Maintenance and repairs of any boiler that fails the periodical test shall be 

performed within 15 days or the boiler shall be idled. 

If a boiler, that has failed a test, is repaired and a successful retest completed 

according to the limitations of Condition #5.A within 15 days, the boiler shall 

be determined to not have been in violation. 

A boiler that fails the retest after repair, shall be idled until further repairs are 

made and a successful retest completed. If the boiler demand requires the 

boiler to be operated it shall be base loaded at the rate that will result in the 

lowest emissions rate possible until the boiler can be repaired and shown in 

compliance by the above test. 

Operating a boiler that has failed the above "retest after repair" shall be 

determined to be a violation of this AG. 

I.	 Reports 

A copy of all test reports containing the test results. any calculations required. 

and the test instrument calibration data shall be retained by the owner/operator 

for two years. The reports shall be made available to the Executive Secretary 

or his agent upon request. An annual summary report of all the test results 

with a copy of the periodical reports shall be submitted to the Executive 

Secretary no later than 1anuary 3I of each year for the previous calend ar year. 

7.	 ','isible emissions from the following emission points shall not exceed the following 

values: 

A. 250 hp Boiler	 Building 1624 10% 

4.2.4-501 
Mr. VanOrman 

Page 7 

B. 400 hp Boiler Building 1904 10% 

C. 250 hp Boiler Building 2104 10% 

D. 250 hp Boiler Building 2203 10% 

E. Paint spray booth Building 751 10% 

F. Carbon brake furnace Building 507 0% 

Opacity observations of emissions from stationary sources shall be conducted in 

accordance with 40 CFR 60, Appendix A, Method 9. Visible emissions from mobile 

sources and intermittent sources shall use procedures similar to Method 9, but the 

requirement for observations to be made at 15 second intervals over a six minute 

period shall not apply. 

8.	 The emissions of VOC from paint spray booth in Building 751 shall not exceed 0.040 

tons per 12-month period without prior approval in accordance with R307-1-3. L 

UAC. Compliance with the limitation shall be determined on a rolling 12-month 

total. Based on the first dav of each month a new 12-month total shall be calculated 

using the previous 12 months. The emissions of VOC from the spray booth shall be 

determined by maintaining a record of paints and thinners used. The record shall 

include the following data for each item used: 

A.	 Name of paint or thinner 

B.	 Weight in pounds per gallon 

C.	 Percent VOC by weight 

D.	 Amount used on a daily basis 

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 upon 

request, and shall include a period of two years ending with the date of the request. 

VOC emissions shall be determined by the following manner: 

VOC =	 (% Volatile by Weight i 100) ;< (Density Ib/gal) ;< (Gallons Consumed) 

/ (2,000 lblton) 

The VOC content in pounds for each individual item or surface coating used shall be 

calculated, and then the total of all items shall be summed. such that the cumulative 

total shall not exceed the 0.04 tons per 12 month period as specified. 

9.	 The owner/operator shall use only natural gas as a primary fuel and #2 fuel oil as a
 

backup fuel in the replacement boilers located in Buildings 1624. 1904. 2104, and
 

2203. If any other fuel is to be used, an AO shall be required in accordance with
 

R307-1-3.1, UAC.
 

10.	 The sulfur content of any fuel oil burned shall not exceed 0.5% bv wei~ht. The 

sulfur content of any fuel oil or diesel fuel shall be tested if directed by the Executive 

Secretary. 

4.2.4-502 
Mr. VanOrman 

Page 8 

II.	 The paint spray booth shall be equipped with a set of paint arrestor particulate filters 

or equivalent to control particulate emissions. All air exiting the booth shall pass 

through this control system before being vented to the atmospnere. Equivalency shall 

be determined by the Executive Secretary. 

12.	 AlI 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 reponing 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. 

13.	 The Executive Secretary shall be notified in writing upon start-up of the installation. 

as an initial compliance inspection is required. Eighteen months from the date of this 

AO the Executive Secretary shall be notified in writing of the status of 

construction/installation if constructionlinstallation is not completed. At that time the 

Executive Secretary shall require documentation of the continuous 

construction/installation of the operation and may revoke the AO 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 AO in no way releases the owner or operator from any liability for compliance with all other 

applicable federal, state, and local regulations including the Utah Air Conservation Rules. 

Annual emissions from the source listed in this NOr are currently calculated at the following values: 

A.	 Total annual emissions for each of the 250 hp boilers located in Buildings 1624. : 104. 

and 2203 are the following values: 

I) 0.06 tons/yr for Particulate
 

2) 0.056 tons/yr for PMlO
 

3) 0.01 tons/yr for S02
 

4) 0.47 tons/yr for NO,
 

5) 0.13 tons/yr for VOC
 

6) 0.46 tons/yr for CO
 

B.	 Total annual emissions for the 400 hp boiler located in building 1904 are the 

following values: 

1) 0.11 tons/yr for Particulate
 

2) 0.10 tons/yr for PM lO
 

3) 0.02 tons/yr for S02
 

4) 3.68 tons/yr for NO,
 

5) 0.22 tons/yr for VOC
 

4.2.4-503 
Mr. VanOrman 

Page 9 

6)	 0.73 tonsiyr for CO 

C.	 Total annual emissions for the paint booth located in building 751 is 0.04 tons/vr for 

VOc. 

D.	 Total annual emissions for the carbon brake coating process located in building 507 is 

1.32 tons/vr for POx' 

E.	 Total annual emissions, based on 100 hr/yr operation, for each emergency generator 

located in buildings 1212, and 1213 are the following values: 

1) 0.04 tons/yr for Paniculate
 

2) 0.04 tons/yr for PMlO
 

3) 0.04 tons/yr for SO:
 

4) 0.67 tons/yr for NO,
 

5) 0.05 tons/yr for VOC
 

6) 0.14 tons/yr for CO
 

7) 0.01 tons/yr for Aldehydes
 

. These calculations are for the purposes of determining the applicability of PSD and nonattainment 

area major source requirements of the UACR. Except forVOC, they are not to be used for purposes 

of determining compliance.	 _. 

Sincerely, 

4.2.4-504
 
-, .' ' f ,~~ nR~CEJVED

DEPARTMENT OF THE AIR FORCE (tAl (lc~) UN 

HEADQUARTERS OGDEN AIR LOGISTICS CENTER (AFMCI U I'1 0 2 1993 

HILLAIRFORCEBASE,UTAH '! lAir Quality 

/ .Q I ~UN 1993 

Mr F. Burnell y6rd~er

Director, Di~~on of Air Quality 

1950 West ;North Temple 

p 0 BO~",~4820 Salt Lak:; City, UT 84114-4820 

Re: Request for Minor Modification of Approval Order DAQE-492-92, 

22 May 92, Replacement Boilers Bldgs 1624,1904, 2104, and 2203 

Dear Mr Cordner 

Condition 4. E. of the referenced Approval Order specifies testing each 

boiler stack at 90 percent, 70 percent and 50 percent of the boiler load. In 

order to ramp the boilers to the specified load levels and stabilize them for 

5 minutes before commencing a test, we will have to add the by-pass 

exhaust ports and exhaust from 1,000 to 9,000 lbs of steam per hour. It 

takes us approximately 3-4 hours per boiler to complete a test at the 

specified loads, during which time, the steam and energy is wasted and 

venting steam creates a very noisy atmosphere. This also does not 

constitute economical operation. 

These boilers may run close to 90 percent load during the winter months; 

however, during the summer months, they may run at 40-50 percent load 

or totally shutdown. 

We request the operating rates in condition 4. E. be deleted to allow testing 

at the existing load conditions and the firing rates. If you have any 

questions, please feel free to contact Jay Gupta at 777-0359. 

Sincerely 

J~R.J~~ JAMES R. VAN ORMAN 

Director of Environmental Management 

4,2.4-505 
,-...: 

,-:l - ­ .r--: .-" : 

... ---­ DEPARTMENT OF ENVIRONMENTAL QUALITY 

DIVISION OF AIR QUALITY 

Nonnan H. Bangerter 

Governor 1950 West Norm TernOle i'1eoly to: State of L.::a~. Kenneth L. Alkema 

Salt Lake City. Utah J,vlSlon 01 A" Oualltv Executive Director 

(801) 536-4000 Deoartmem of Envlronmenlal Qua:,tv F. Burnell Cordner 

Director (801) 536-4099 Fax Sail Lake City. Utah 84114·4820 

DAQE-127-92 

February 7, 1992 

Newspaper Agency 

Legal Advertising Department 

157 Regent Street 

Salt Lake City, Utah 84111 

This letter will confirm the authorization to pUblish the attached NOTICE in 

the Salt Lake Tribune and the Deseret News on February 14, 1992. 

Please mail the invoice and affidavit of publication to the Utah State 

Department of Environmental Quality, Division of Air Quality, P.O. Box 16690, 

Salt Lake City, Utah 84114-4820. 

Sinceli'ely, 

d

./

l 

I.,/ Ii II 

tLUVv' 

Cheery Love r 

Office Technician
 

Division of Air Quality
 

MK:cl 

Enclosure 

4.2.4-506
 
NOTICE 

The following no~ices of intent to construct, submitted in accordance with 

Section 3.1, Utah Air Conserva~ion Rules, have been received for consideration 

by the Executive Secretary, Utah Air Quality Board: 

1.	 Kim Heimsath
 

Mountain Fuel
 

180 East 100 South
 

Salt Lake City, Utah 84139
 

Twelve Natural Gas Fired IC Engines at Six Stations; One Natural 

Gas Fired Emergency Generator 

Six Locations, all new minor sources in attainment areas 

The emissions from these sources can be summarized as follows: 

A) There are no existing emissions at any of the proposed locations. 

B) Controlled and uncontrolled emissions are equal at all locations. 

C) The emissions of NOx and CO are the only pollutants of concern. 

Emissions of NOx and CO are less than 20 TPY each at all of the 

proposed locations. Emissions of all other pollutants are 

negligible. 

2.	 James R. Van Orman 

Headquarters Ogden Air Logistics Center 

Hill Air Force Base, Utah 84056-5990 

Replacement Boilers in Buildings 1624, 1904, 2104, 2203 

Paint Spray Booth in Building 751 

Carbon Brake Coating in Building 507 

Emergency Generators in Buildings 1212 and 1213 

Davis County CDS A1 NA 

The emissions from the sources listed in this NOI will be as follows: 

4.2.4-507 
Total emissions from the boilers in Buildings 1624, 1904, 2104, and 2203: -


Current Emissions 

Particulate 0.16 ton/12-month period 

PMlO 0.14 

S~ 0.04 

NOx 5.00
 

CO 1.00
 

VOC 0.24
 

New Total Emissions 

Particulate 0.25 ton/12-month period 

PMIO 0.22 

S~ 0.05 

NO" 5.09 

CO 1. 68 

VOC 0.51 

Total emissions from the paint spray booth in Building 751: 

VOC 0.04 ton/12-month period 

Total emissions from the Carbon Brake Coating Process: 

1.32 ton/12-month period 

Total emissions from the Emergency Generators in buildings 1212, and 1213: 

New Total Emissions fer 2 Generators 

Particulate 0.08 ton/12-month period 

PMIO 0.07 

S~ 0.08
 

NO"
 1.34
 

CO 0.28
 

VOC 0.10
 

Aldehydes 0.02
 

The generators will each be run a maximum of 100 hours per 12-month period 

(for maintenance). The above invent~ry is relevant to the proposed facilities 

only in this Nor and not to all of HAFB. 

4.2.4-508 
3.	 John Cuthbertson
 

LOS Hospital
 

325 8th Avenue
 

Salt Lake City, Utah 84143
 

Boiler Replacement
 

Salt Lake County CDS B NA
 

The emissions from this source will be as follows: 

Existing Emissions (including coal burning) 

Particulate 6.18 ton/yr 

PMlO 6.18 

S~ 156.90 

NOx 74.20 

CO 31.'40 

vee non meth 0.37 

Increased (Decreased) Emissions 

Particulate (5.05) ton/yr
 

PMlO (5.05)
 

S~ (154.40)
 

NOx (53.70) 

CO (24.00) 

vee non meth 0.82 

Total Emissions 

'O?-~~.~•. 1?t.e 2..1: ":".':)-:/y~

PMlO 1.13
 

S~ 2.48
 

NOx 20.50
 

CO 7.39
 

voe non meth	 1.19 

4.2.4-509 
The engineering evaluations and air quality impact analyses have been 

completed and no adverse air quality impacts are expected. It is the intent 

of the Executive Secretary to approve the construction projects. 

The construction proposal and estimates of the effect on local air quality are 

available for pUblic inspec~ion and comment at the Division of Air Quality, 

Utah State Department of Environmental Quality, 1950 West North Temple, Salt 

Lake City, Utah 84116-0690. written comments received by the Division, at the 

same address on or before March 14, 1992 will be considered in making the 

final decision on the approval/disapproval of the proposed construction. 

If anyone so requests to the Executive Secretary in writing, within 15 days of 

publication of the Notice, a hearing will be held to explain the project and 

technical rationale for proposed action. A hearing will be scheduled as close 

as practicable to the proposed project location. Comments obtained during a 

hearing will be evaluated and considered by the Executive Secretary before 

making a final decision on the approval/disapproval of the projects. 

Date of Notice: February 14, 1992 

4.2.4-510
 
UTAH DIVISION OF AIR QUALITY
 

NEW/MODIFIED SOURCE PLAN REVIEW
 

James R. Van Orman
 

Director of Environmental Management
 

Headquarters Ogden Air Logistics Center
 

Hill Air Force Base, Utah 84056-5990
 

ENGINEER:	 Nando Meli Jr. 

RE:	 Replacement Boilers in Buildings 1624, 1904, 

2104, 2203 

Paint Spray Booth in Building 751 

Carbon Brake Coating in Building 507 

Emergency Generators in Buildings 1212 and 1213 

Davis County CDS A1 NA
 

DATE: January 21, 1992
 

NOTICE OF INTENT DATED: July 30, 1991
 

PLANT CONTACT: Jay Gupta
 

PHONE NUMBER: (801) 777-6742
 

PLANT LOCATION: Hill Air Force Base, Davis County
 

FEES: ,.,.-., 

Filing Fee $1500.00 

Computer Usage Fee $000.00 

Notice to Paper $00.00 

Travel - 00 miles at $O.23/mile sooo.oo 

Total $1500.00 

APPROVALS: 

Engineering Unit Manager 

Applicant Contact Made / - .) ?- .. l Y/ 

4.2.4-511
 
I. DESCRIPTION OF PROPOSAL -


A. Replacement Boilers 

Buildings 1624, 1904, 2104, and 2203 each have two existing boilers. One is 200 

HP and the other one is 150 HP. An energy study has shown that if the larger 

boiler (200 HP) was to fail, then the mission essential load could not be 

entirely supplied by the smaller (150 HPJ boiler. There will be no change to the 

200 HP boilers. 

HAFB proposes to replace the 150 HP boilers with new 250 HP boilers in Buildings 

1624, 2104, and 2203. In Building 1904, the 150 HP boiler will be replaced with 

an existing 400 HP boiler which is presently idle. The new boilers will be 

Kewanee Classic III, 150 PSI, packaged scotch design firetube boilers or approved 

equal, capable of firing gas or oil. 

Gas will be used as the primary fuel with #2 oil being used as the back-up fuel. 

Boiler data and dimensions are shown in Attachment #1 of the NOI. Design 

criteria for the boilers a~2 ~3 ==::cws: 

Data for each 250 hp Boiler 

Boiler rating (each)	 250 HP, three boilers required 

Primary fuel	 Natural Gas 

Bask-up Fuel	 #2 Oil 

Steam Rate	 8,625 lbs/hr 

Total heat input	 10.45 MM BTU/hr 

Total heat output	 8.37 MM BTU/hr 

Thermal efficiency	 80% 

Fuel firing rate	 Gas (1000 BTU/SCF) 174.16 SCFM 10,450 

SCFH 

#2 Fuel Oil 140,000 BTU/Gal 74.4 GPH 

Estimated stack gas volume	 gas firing 4270 ACFM
 

oil firing 4345
 

Flue gas temperature 

Data for 400 hp Boiler 

Boiler rating	 400 HP 

Primary fuel	 .Natural Gas 

Bask-up Fuel	 #2 Oil 

Total heat input	 16.74 MM BTU/hr 

Thermal efficiency	 80t 

Fuel firing rate	 Gas (1000 BTU/SCF) 18,414 SCFH 

#2 Fuel Oil 140,000 BTU/Gal 131.5 GPH 

B. Paint Spray Booth 

A small bench type paint spray booth measuring approximately S'W x 7'H x 6'D, 

complete with paint arrestor filters, exhaust plenum, and a fan will be used to 

paint small aircraft instruments. 

Paint usage in very small quantities (20-25 gallons per year) and very low voe 

content will be used (less than 3.5 Ibs VOC/gallon). At a face velocity of 150 

feet per minute, exhaust volumetric flow rate in estimated to be 3500 SCFM. 

Vendor data on paint spray booth :s Attachment 2 of the NOI. 

C. Carbon Brake Coating 

2 

4.2.4-512 
An existing electric furnace, not being used at the present time, will be used 

for baking Bendix P-11 coating on aircraft carbon discs in Building 507. The 

furnace measures approximately 3' x 3' x 6' deep. Six SCFM continuous nitrogen 

purge will be used. A small vent pipe will exhaust vapors to the atmosphere. P11 coating decomposes on heating to form phosphorous oxides. 

D. Emergency Generators 

Two emergency generators (with a capacities of 200 KW and 125 KW) will be 

installed in Buildings 1212 and 1213. They will serve as a back-up power source 

to equipment in these buildings. A 1900 gallon above ground diesel fuel tank 

will be used as a fuel source. 

II. EMISSION SUMMARY 

The emissions from the sources listed in this NOI will be as follows: 

Total emissions from the boilers in Buildings 1624, 1904, 2104, and 2203: 

Current Emissions 

Particulate 0.16 ton/12-month period 

PMlO 0.14 

S~ 0.04 

NOx 5.00 

CO 1.00 

VOC 0.24 

New Total Emissions 

Particulate 0.25 ton/12-month period 

PMlO 0.22 

S~ 0.05 

NOx 5.09

CO 1. 68
 

VOC 0.51
 

Total emissions from the paint spray booth in Building 751: 

VOC 0.04 ton/12-month period 

Total emissions from the Carbon Brake Coating Process: 

1.32 ton/12-month period 

Total emissions from the Emergency Generators in buildings 1212, and 1213: 

New Total Emissions for 2 Generators 

Particulate 0.08 ton/12-month period 

PM10 0.07
 

S~ 0.08
 

NOx 1.34
 

CO 0.28
 

VOC 0.10
 

Aldehydes 0.02
 

The generators will each be run a maximum of 100 hours per 12-month period. The 

above inventory is relevant to the proposed facilities only in this Nor and not 

to ~he entire HAFB. The total inventory for HAFB is not currently available. 

3 

4.2.4-513 
III. BEST AVAILABLE CONTROL TECHNOLOGY (BACT) ANALYSIS 

BACT will be required at all emission points. The following is a description of 

the pollution control equipment proposed and the recommendation of the 

Engineering Section: 

Boiler Replacements 

The emission points under review in this area are the boiler stacks. The 

Engineering Section recommends the following limitations as BACT for the new 

boilers: 

A. NOx - 40 ppm at 7\ oxygen (measured as NOz) 

B. CO - 100 ppm at 7\ oxygen 

C. 10\ opacity 

The proposed Low-NOx natural gas fired boilers in buildings 1624, 2104, and 2203 

are cesigned to meet these li~itations. No other options were considered. 

A cost analysis was done on retrofitting the proposed 400 hp boiler in building 

1904 with a low NOx burner. After reveiwing the cost analysis it was determined 

that it would not be cost effective to equip the boiler with a low NOx burner. 

Paint Spray Booth 

The emissions from the paint spray booth will be controlled by using a paint 

arrestor filters with an opacity limit of 10\. A low VOC compliant paint, 3.5 

lbs VOC/gallon or less, and a limit on the total VOCs is being recommended as 

BACT at this facility. The Engineering Section recommends the following limits 

as BACT: 

A. 10\ opacity 

B. VOC emissions from booth limited to 0.04 ton/yr 

Carbon Brake Coating 

Hill AFB has indicated in their Nor that there will be no controls on the 

emissions to the atmosphere from the carbon brake coating process in Building 

507. 

Screening type modeling was submitted by HAFB that indicated the emission 

concentration would be 0.011 mg POx/m3 at the property line, located 150 meters 

from Building 507. The Threshold Limit Value for phosphoric acid is 1 mg/m3. 

This value was divided by 100 to give an acceptable limit value for a unhealthy 

person of 0.010 mg/m3. Due to the conservative nature of modeling, the 

Engineering Section recommends that this process be accepted with no controls on 

the emissions with 0\ opacitv as BACT. 

Emergency Generators 

The NOI indicated that there would be no controls on the emissions from the 

emergency generators. The Engineering Section knows of no controls at this time 

for small diesel engines. A limitation on the number of hours of operation and 

fuel quality is the best current control for this type of source. 

The Engineering Section recommends that BACT for the generators be the following: 

A. 20\ opacity 

4 

4.2.4-514 
B.	 S.ulfur content of diesel fuel that is equal to or less than the 

sulfur content of on-highway diesel fuel 

C.	 Annual hours of operation for maintenance not to exceed to 100 per 

generator 

IV.	 APPLICABILITY OF FEDERAL REGULATIONS AND UTAH AIR CONSERVATION RULES 

This Notice of Intent is for a minor modification to an existing major source. 

It is not a new major source or a major modification. The following federal 

regulations and state rules have been examined to determine their applicability 

to this Notice of Intent: 

1.	 R446-1-3.1, UAC - Notice of intent required for a modified source. 

This rule applies. 

2.	 R446-1-3.1.5, UAC - Continuous program of construction required to 

begin within eighteen months of Approval Order date. If a 

continuous program of construction is not proceeding, the Exec~tive

Secretary may revoke t~e A?p~oval Orc2~.

3.	 R-446-1-3.1. 7 (A), UAC - Notice of Intent not required for fuel 

burning equipment with a rated capacity of less than 5 x 106 BTU per 

hour using no other fuel than natural gas. A Notice of Intent is 

required because the boilers have a capacity greater than 5 x 106 BTU 

per hour, and they will use #2 :uel oil as a back-up fuel. 

4.	 R-446-1-3.l.7 (F), UAC - Notice of Intent not required for the use 

of certain compounds which are not photochemically reactive. This 

list includes 1,1, 1-trichloroethane. However, if the source is 

emitting more than 10 tons/yr of any compound, a Notice of Intent 

must be filed. This rule applies. 

5.	 R-446-1-3.1.8 (A), UAC - Application of best available control 

technology (BACT) required at all emission points. This rule 

applies. 

6.	 R-446-1-3.1.8 (D), UAC - Enforceable offset of 1:1 required for new 

sources or modifications which would produce an emission increase 

greater than or equal to 25.00 tons per year of any combination of 

PMIO, S02, and NOx • This is required in Salt Lake, Davis, and Utah 

Counties and in any area that impacts these three counties as 

defined in the rule. The effective date is November 15, 1990. The 

sources listed in this NOI produce a combined emission rate that is 

less than 25.00 tons per year. No offset is required. 

7.	 R-445-1-3.1.9, UAC - Rules for =elocation of temporary sources. 

This source is a permanent source. Therefore, this rule does not 

apply. 

8.	 R-446-l-3. 1. 12, UAC - Requirement for installation of low-NOx burners 

on all existing sources whenever existing fuel combustion burners 

are replaced, unless the replacement is not physically practical or 

cost effective. The effective date is November 15, 1990. This rule 

does not apply as there are no replacement burners. However, BACT 

requires the 10w-NOx burners on the new boilers that have been 

proposed. 

9.	 R-446-1-3.2.1, UAC - Particulate emission limitations for existing 

sources which are located in a nonattainment area. ~his rule has 

been superseded by the PMlO SIP, except for Weber County. The 

effective date is November 15, 1990. The sources listed in Weber 

5 

4.2.4-515 
county are as follows: -- A.	 Farmers Grain Coop 

B.	 Fife Rock Products 

C.	 Interpace Corporation 

D.	 Parsons Asphalt Plant 

E.	 Pillsbury Company 

F.	 Teledyne Incinerator 

G.	 Gibbons and Reed Asphalt 

This source is not listed in the SIP. Therefore, this rule does not 

apply. 

10.	 R-446-1-3.3.2, UAC - 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 represents 

a minor modification to an existing major source. Therefore, this 

rule does not apply. 

11.	 R-44f;-l-3.S, UAC - Emi£"sion i.r;nentory reporting :-2:;,..:':"::-ements. This 

rule requires any source which emits 2S tons or more per year of any 

pollutant to submit an emission inventory to the Division of Air 

Quality at least every third year or as determined necessary by the 

Executive Secretary. HAFB must comply with this rule. 

12.	 R-446-1-3.6.3, UAC - PSD Increment Consumption - This rule lists the 

allowable PSD increment consumption. Under the PSD rules, the 

entire state has been triggered for TSP, S~, and NO • The allowable x 

increments are as follows: 

A.	 Class I areas -, 1) S ug/m3 (annual)
 

2) 10 ug/m3 (24 hour)
 

B.	 Class II areas
 

1) 19 ug/m3 (annual)
 

2)	 37 ug/m3 (24 hour) 

A.	 Class I areas 

1)	 2 ug/m3 (annual) 

2)	 5 ug/m3 (24 hour) 

3)	 25 ug/m3 (3 hour) 

B.	 Class II areas
 

1) 20 ug/m3 (annual)
 

2) 91 ug/m3 (24 hour)
 

3) 512 ug/m3 (3 hour)
 

A.	 Class I areas - 2.5 ug/m3 (annual) 

B.	 Class II areas - 25 ug/m3 (annual) 

6 

4.2.4-516 
13. 

14. 

15. 

16. 

17. 

IS. 

There are also Class III increments, which do not apply in Utah. 

The above increments apply at all locations, unless the area is 

already nonattainment. The entire increment may not be available at 

all locations due to previously permitted sources consuming 

increment. This source is located in a nonattainment area. 

R-446-1-3.6.5 (b), UAC - Prevention of significant deterioration 

(PSD) review requirements for new majo~ sources or major 

modifications. This Notice of Intent does not~represent a new major 

source or a major modification under PSD rules. Therefore, this 

rule does not apply. { 

i 

R446-1-3.6.6 UAC - Increment violations. Th"is rule requires the 

UACB to promulgate a plan and implement rules to eliminate any PSD 

increment violations which occur in the state. No known violations 

have yet occurred. 

R-446-1-3.8, UAC Stack height rule. This rule limits the 

creditable height of stacks to that height determined to be good 

engineering practi=e. The formul~s used to determine good 

engineering practice are found in 40 CFR 51.100. A deminimus height 

of 65 meters (213.2 feet) is allowed. The sources listed in this 

NOI have no stacks which exceed 65 meters in height. It is in 

compliance with this rule. 

R-446-1-3 .11, UAC - Visibility screening analysis requirements. 

This rule requires all new major sources or major modifications to 

undergo a visibility screening analysis to determine visibility 

impact on any mandatory Class I area. This Notice of Intent does 

not represent a new major source or a major modification under UACR 

rules. Therefore, this rule does not apply. 

R-446-1-4.1.2, UAC - 20\ opacity limitation at all emission points 

unless a more stringent limitation is required by New Source 

Performance Standards (NSPS) or BACT or National Emission Standards 

for Hazardous Air Pollutants (NESHAPS). In this case, some points, 

which are subject to NSPS or BACT, will have to meet more stringent 

opacity limitations as follows: 

A. Boilers, Building 1624 - 10% opacity 

B. Boilers, Building 1904 - 10\ opacity 

C. Boilers, Building 2104 - 10\ opacity 

D. Boilers, Building 2203 - 10% opacity 

E. Paint spray booth, Building 751 - 10\ opacity 

F. Carbon brake furnace, Building 507 - 0\ opacity 

G. Emergency generator, Building 1212 20\ opacity 

H. Emergency generator, Building 1213 - 20\ opacity 

An opacity of 0\ is recommended for the carbon brake coating exhaust 

stack located in Building 507 due to the toxicity of the POx 

emissions. 

R-446-1-4.1.9, UAC - EPA Method 9 to be used for visible emission 

observations. This rule applies. 

7 

4.2.4-517 
19.	 R-446-1-4.2.1, UAC - Sulfur content limitations in oil and coal used --.." for combustion. This source burns natural gas as a primary fuel 

source, and uses #2 fuel oil as a back up fuel source for its 

boilers. The emergency generators will use diesel fl,lel. The 

limitation in the rule is 0.85 pounds of sulfur per 100 BTU heat 

input. The proposed fuel oil will be limited to 0.50% by weight 

sulfur and the engine fuel will be recommended as "on-highway" grade 

fuel. 

20. R-446-1-4.7, UAC - Unavoidable breakdown reporting requirements. 

This rule applies. Section 4.7.1 discusses reporting requirements. 

A breakdown for any period longer than 2 hours must be reported to 

the Executive Secretary within 3 hours of the beginning of the 

breakdown, if reasonable, but in no case longer than 18 hours after 

the beginning of the breakdown. A written report is required within 

7 calendar days. The report shall include the estimated quantity of 

pollutants (total and excess). Section 4.7.2 d~scusses penalties. 

, 21.	 R-446-1-4.9, UAC - Review requirements for volat~le organic compound 

(VOC~ sources located ~~ a nonattainment area for ozone constructed 

in 1980 or earlier. This rule does not apply to the paint spray 

booth at Hill AFB in building 751 because the booth is new. 

However, the rule may have been used as a guidance document in 

determining BACT for the spray booth. 

22.	 R-446-1-5, UAC - Emergency episode requirements. This rule applies. 

23.	 ,,-446-:'-"7, Ul.C - riir .c-'oi.l.uc::..on Episocie Plan - This plan prov:..cies c:he 

basis fer ~aking action to prevent air poll~tant concen~~ations :rom 

reaching levels which could endanger the public health, or to abate 

such concentrations should they occur. All sources in a 

nonattainment area or impacting a nonattainment area must submit a 

plan outlining what they will do in an emergency episode. This 

regulation applies to Salt Lake, Davis, and Utah Counties. This 

rule applies. 

24.	 New Source Performance Standards (NSPS) - There are no NSPS for any 

of the proposed industrial process. 

25.	 National Emission Standards for Hazardous Air Pollutants (NESHAPS) ­

There is no NESHAPS for this industrial process. 

26.	 National Ambient Air Quality Standards (NAAQS) - This source is 

located in Davis County,. which is a nonattainment area for ozone. 

The Division of Air Quality guidelines do not call for this source, 

to be modeled for any pollutant. However, modeling was done for POx', 

The Division has found through experience that, because of the small 

quantity of emissions involved and the conservative predictions made 

by modeling, a source or emission point of this small size is very 

unlikely to cause a new violation of the NAAQS or make a significant 

contribution to the existing violation for ozone. 

Screening type modeling was submitted, on the carbon brake coating 

process in bldg. 507, by HAFB that indicated the emission 

concentration would be 0.011 mg POx/m3 at the property line, located 

150 meters from the building. The Threshold Limit Value for 

phosphoric acid is 1 mg/m3 • This value was divided by 100 to give 

an acceptable limit value for a unhealthy person of 0.010 mg/m3 • Due 

to the conservative nature of modeling, the Engineering Section 

recommends that this process be accepted with no controls on the 

emissions with 0% opacity as BACT. 

8 

4.2.4-518 
27.	 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 facility, 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 c!evice whose primary 

function is the reduction of air pollutants 

6)	 Relocation or change in ownership 

Also see Section 1.92, which is the State's definition. It is a 

planned increase in emissions. This Notice of Intent is a minor 

modification. 

28.	 40 CFR 60.15, Definition of Reconstruction - the replacement of 

components of an eXisting facility to such an extent that: 

1)	 The fixed capital cost of the new components exceeds 50\ of 

the fixed capital cost that would be required to construct a 

comparable entirely new facility and 

2)	 It is technologically and economically feasible to meet the 

applicable standards set forth in this part 

This Notice of Intent is not a reconstruction. 

29.	 R-446-1-1.89, Definition of Major Modification It means any 

physical change in or change in the method of operation of a major 

source that would result in a significant net emission increase of 

any pollutant. A net emissions increase that is significant for VOC 

shall be considered significant for ozone. A physical change or 

change in the method of operation shall not include: 

A.	 Routine maintenance, repair, or replacement 

B.	 Use of an alternative fuel or raw material by reason of an 

order under Section 2a and b of the ESECA of 1974 or by reason 

of a natural gas curtailment plan pursuant to the Federal 

Power Act 

C.	 Use of an alternative fuel by reason of an order under Section 

125 of the CAA 

D.	 Use of an alternative fuel at a steam generating unit to the 

extent that the fuel is generated from municipal solid waste 

E.	 Use of an alternative fuel or raw material by a source: 

9 

4.2.4-519 
1 ) 

January 

which the 

6, 

source 

1975, unless 

was capable 

such change 

of accommodating 

would be prohibited 

before -


under any enforceable permit condition 

2) which the source is otherwise approved to use 

F.	 An increase in the hours of operation or the production rate 

unless such change would be prohibited under any enforceable 

permit condition 

,

t 

G.	 Any change in ownership at a source 

This Notice of Intent is not a major modification. 

V. RECOMMENDED APPROVAL ORDER CONDITIONS 

l.	 Hill Air Force Base shall install and operate the following: 

A.	 The boilers located in Bt:ildings 162L.!, 1904, 2104, and 2203 

B.	 The paint s,pray booth located in Building 751 

c.	 The carbon brake coating process located in Building 507 

D.	 The emergency generators located in Buildings 1212 and 1213 

These shall all be operated according to the information submitted 

in the Notice of Intent dated April 24, 1991 and additional 

information submitted to the Executive Secretary dated July 30, 

1991; December 26, 1991; and January 8, 1992. 

A copy of this Approval Order shall be posted on site and shall be - available to the employees who operate the air emission producing 

equipment. All employees who operate the air emission producing 

equipment shall receive instruction as to their responsibilities in 

operating the equipment in compliance with all of the relevant 

conditions. 

2.	 The approved installations shall consist of the following equipment: 

A.	 Replacement boilers located in Buildings 1624, 2104, and 2203, 

rated at 250 HP - The boilers shall be equipped with 10w-NOx 

burners using natural gas as the primary fuel, with #2 fuel 

oil being used as the back-up fuel. 

B.	 Placing of an existing 400 HP boiler in Building 1904 using 

natural gas as the primary fuel with #2 fuel oil being used as 

the back-up fuel 

C.	 A paint spray booth equipped with paint arrestor filters 

located in Building 751 and using low VOC compliance paint. 

D.	 An existing electric furnace to be used for baking Bendix P-11 

coating on carbon brake disks in Building 507. 

E.	 Two emergency generators located in: 

a) Building 1212 - generator rated at 200 KW 

b) Building 1213 - generator rated at 125 KW 

10 

4.2.4-520 
3.	 Emissions to the atmosphere from the indicated emission point shall 

not exceed the following rates and concentrations: 

A.	 Exhaust stacks for 250 HP replacement boilers in Buildings 

1624, 2104, and 2203: 

1) NO - 40 ppmdv at 7% oxygen; 0.24 lb/hr x 

2)	 CO - 100 ppmdv at 7% oxygen 

B.	 Exhaust stack for 400 HP replacement boiler in Building 1904, 

- NOx - 1.84 lb/hr 

C.	 Exhaust stack for carbon brake coating in Building 507 - POx ­

~.33 lb/hr i 

4.	 Stack testing to show compliance with the em4ssion limitations of 

condition	 #3 shall be performed as specified ~low:
 


 

A.	 Emission Point Pollutant Testing Retest 

Status 

1.	 Boiler exhaust stacks 

in Bldgs 1624, 1904, 

2104, and 2203 NOx *** 

CO * * 

2.	 Carbon brake coating 

exhaust in Bldg 507 */** ** 

B.	 Testing status (To be applied above) 

* No initial testing is required. However, the	 Executive

Secretary may require testing at any time in accordance 

with R446-1-3.4.1, UAC. The source shall be	 tested if 

directed by the Executive Secretary. 

The testing method shall be submitted to the	 Executive ** 

Secretary for approval before the testing is performed. 

The source shall be tested if directed by the Executive 

Secretary. 

The stack shall be tested for NOx emissions compliance 

within 30 days of startup using a portable testing 

instrument approved by the Executive secretary. 

***	 The boiler stack shall be retested every 30 boiler 

operating days ± 10 days. The maximum time between 

tests shall be 35 boiler operating days. 

C.	 Test Procedure 

Boiler stack emissions testing shall be performed by the 

following procedure or an approved equivalent. Equivalency 

shall be determined by the Executive Secretary and approved 

prior to tests being conducted. 

J.	 Sample Port 

A sampling port shall be installed in each boiler exhaust 

11 

4.2.4-521 
stack in accordance with 40 CFR 60, Appendix A, Method #1 or 

as approved by the Executive Secretary. The sample port shall 

be safely accessible to the tester, operator, or inspector in 

accordance with OSHA standards. 

E.	 Operating Rate 

Each boiler stack shall be tested in accordance with the 

schedule in Condition #4.A.l. The steam production or 

operating rate during testing shall be performed under the 

following three operating rates: 

1)	 90% %10% of the boiler's capacity 

2)	 70% ±10% 

3)	 50% HO% 

F.	 Test Instrument 

The ~~=~ procadure shall be conduc~e~ us~ng a portable testing 

instrument approved by the Executive Secretary. The testing 

instrument shall be calibrated on site with a suitable NBS 

referenced or traceable calibration gas in accordance with the 

instruction of the test instrument. 

G.	 Test Procedure 

The test shall be conducted in the following manner: 

1.	 The boiler shall be:· 

a)	 ramped to the designated production rate in 

Condition 4.E, 

b)	 allowed to stabilize for a minimum of 5 minutes. 

2.	 The gas sample shall be drawn according to the 

instructions of the test instrument being used. 

3.	 The sample value shall be determined from the test 

instrument, appropriate calculations made, and the data 

recorded. 

H.	 Failed Boiler Sta~us

If the boiler is unable to attain the emission limitation in 

condition #3, at anyone of the operating rates specified in 

condition 4E, the boiler shall be assigned to a lower position 

on the "use priority list" (used as standby where possible) 

until the unit has been repaired or maintenance performed and 

a successful retest completed. 

Maintenance and repairs of any boiler that fails the 

periodical test shall be performed within 15 days or the 

boiler shall be idled. 

If a boiler, that has failed a test, is repaired and a 

successful retest completed according to the limitations of 

Condition #3.A within 15 days, the boiler shall be determined 

to not have been in violation. 

12 

4.2.4-522
 
A boiler that fails the retest after repair, shall be idled 

until further repairs are made and a successful retest 

completed. If the boiler demand requires the boiler to be 

operated it shall be base loaded at the rate that will result 

in the lowest emissions rate possible until the boiler can be 

repaired and shown in compliance by the,above test . .

Operating a boiler that has failed thet above .. retest after 

repair" may be determined to be a viola~ion of this Approval 

Order. :

, I.	 Reports 

A copy of all test reports containing the test results, any 

calculations required, and the test instrument calibration 

data shall be retained by the owner/operator for 2 years. The 

reports shall be made available to the Executive Secretary or 

his agent upon request. An annual summary report of all the 

test results with a copy of the periodical reports shall be 

submitted to the Executive Secretary no later than January 31 

of each year for the previous calendar year. 

5.	 Visible emissions from the following emission points shall not 

exceed the following values: 

A.	 250 hp Boiler Building 1624 10\ 

B.	 400 hp Boiler Building :";'04 10\ 

C.	 250 hp Boiler Building 2104 10% 

D.	 250 hp Boiler Building 2203 10% 

E.	 Paint spray booth, Building 751 10% 

F.	 Carbon brake furnace, Building 507 0% 

G.	 200 kw Emergency generator Building 1212 20% 

H.	 150 kw Emergency generator Building 1213 20% 

Opacity observations of emissions from stationary sources shall be 

condocted in accordance with 40 CFR 60, Aooend ix A, /-Aotbod 9. 

Visible emissions from mobile sources and intermittent sources shall 

use procedures similar to Method 9, but the requirement for 

observations to be made at 15 second intervals over a six minute 

period shall not apply. 

6.	 The emissions of VOC from building 751 shall not exceed 0.040 tons 

per 12-month period without prior approval in accordance with R446­

1-3.1, UAC. Compliance with the limitation shall be determined on 

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

new 12-month total shall be calculated using the previous 12 months. 

The emissions of VOC from the spray booth shall be determined by 

maintaining a record of paints and thinners used. The record shall 

include the following data for each item used: 

A.	 Name of paint or thinner 

B.	 Weight in pounds per gallon 

C.	 Percent VOC by weight 

D.	 Amount used on a daily basis 

13 

4.2.4-523 
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 upon request, and shall include a period of 

two years ending with the date of the request. VOC emissions shall 

be determined by the following manner: 

VOC	 (% Volatile by Weight / 100) * (Density lb/gal) * 

(Gallons Consumed) / (2,000 lb/ton) 

The VOC content in pounds for each individual item or surface 

coating used shall be calculated, and then the total of all items 

shall be summed, such that the cumulative total shall not exceed the 

0.04 tons per 12 month period as specified. 

7.	 The emergency generators in Buildings 1212 and 

to 100 hours of maintenance operation per 

period. If excess hours of operation are use 

conditions, the Executive Secretary shall be 

213 shall be limited 

ngine per 12-month 

ecause of emergency 

tified. 

Compliance with the limitation shall be determ ned 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 

hours of operation shall be kept for all periods when the plant is 

in operation. Records of hours of operation 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. Hours of operation shall be determined by supervisor 

mOn~LOrl.ng ana mal.llLal.r.ing or an operaLions log. 

8.	 The owner/operator shall use only natural gas as a primary fuel and 

#2 fuel oil as a backup fuel in the replacement boilers located in 

Buildings 1624, 1904, 2104, and 2203. If any other fuel is to be 

used, an Approval Order shall be required in accordance with R446-1­

3.1, UAC. 

9.	 The sulfur content of any fuel oil burned shall not exceed 0.5% by 

weight. The sulfur content of any fuel oil or diesel fuel shall be 

tested if directed by the Executive Secretary. 

10.	 The paint spray booth shall be equipped with a set of paint arrestor 

particulate filters or equivalent to control particulate emissions. 

All air exiting the booth shall pass through this control system 

before being vented to the atmosphere. Equivalency shall be 

determined bv the Executive Secretary. 

11.	 All installations and facilities authorized by this Approval Order 

shall be adequate1y and properly maintained. The owner/operator 

shall comply with R446-1-3.5 and 4.7, UAC. R446-1-3.5, UAC 

addresses emission inventory reporting requirements. R446-1-4.7, 

UAC addresses unavoidable breakdown reporting requirements. The 

owner/operator shall calculate/estimate the excess emissions 

whenever a breakdown occurs. The sum total of excess emissions 

shall be reported to the Executive secretary for each calendar year 

no later than January 31 of the following year. 

12.	 The Executive Secretary shall be notified in writing upon start-up 

of the installation, as an initial compliance inspection is 

required. Eighteen months from the date of this Approval Order 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 construction/installation of the - 14 

4.2.4-524 
operation and may revoke the Approval Order in accordance with R446­

1-3.1.5, UAC. 

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

approved in accordance with R446-l-3.l.l, UAC. 

This Approval Order in no way releases the owner or operator from any liability 

for compliance with all other applicable federal, state, and local regulations 

including the Utah Air Conservation Rules. 

Annual emissions from the source listed in this Nor are currently calculated at 

the following values: 

A.	 Total annual emissions for each of the 250 hp boilers located in 

Buildings 1624, 2104, and 2203 are the following values: 

1) 0.06 tons/yr for Particulate
 

2) 0.056 tons/yr for PHlO
 

3) 0.01 tons/yr for S~
 

4) 0.47 tons/yr for NOx
 

5) 0.13 tons/yr for VOC
 

6) 0.46 tons/yr for CO
 

B.	 Total annual emissions for the 400 hp boiler located in building 

1904 are the following values: 

1)	 0.11 tons/yr for Particulate 

L)	 0.10 tons/yr for PMlO 

:; )	 0.02 t.ons/yr :or S02 

4)	 3.68 tons/yr for NOx 5)	 0.22 tons/yr for VOC 

6)	 0.73 tons/yr for CO 

c.	 Total annual emissions for the paint booth located in building 751 

is 0.04 tons/yr for vac. 

D.	 Total annual emissions for the carbon brake coating process located 

in building 507 is 1.32 tons/yr for POy • 

E.	 Total annual emissions, based on 100 hr/yr operation, for each 

emergency generator located in buildings 1212, and 1213 are the 

following values: 

1 ) 0.04 tons/yr for Particulate
 

2) 0.04 tons/yr for PMlO
 

3) 0.04 tons/yr for S~
 

4) 0.67 tons/yr for NOx
 5) 0.05 tons/yr for voc
 

6) 0.14 tons/yr for CO
 

7) 0.01 tons/yr for Aldehydes
 

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. 

NANDO\WP\HAFB-GB.ENI 

15 

4.2.4-525 
MEMORANDUM 

Hill Air Force file, Engineering Section, DAQ 

FROM: Nando Heli Jr., Environmental Health Engineer 

SUBJECT: Justification for the use of an existing 400 hp boiler in 

building 1904. 

DATE: January 15, 1992 

Hill Air Force Base submitted. some information dated January 8, 1992 to 

substantiate their claim for using an existing 400 hp boiler. In building 1904 

they are replacing a 150 hp boiler with an existing boiler and burner. The 

letter provides some information as to the cost effectiveness of using the 

existing burner and not a low NOx burner. Carl Broadhead talked to a 

manufacturer representative and came up with the following information: 

Cost of low NOx burner $45,000.00 

Cost for installation and chamber modificataion 25,000.00 

Total cost 70,000.00 

Using Hill A.F. Base information to get a cost analysis for the amount per year 

for NO reduct ion: x 

Annualized capital cost assuming 20 year life at 8% rate
 

$70,000.00 x capital recovery factor
 

70,000.00 x 0.1019
 

$ 7,l33.00/year for 20 years
 

NO emissions with existing burner = 3.68 tons/yr
 x 

NOx emissions with low NOx burner = 1. 67 tons/yr
 

NO reduction = 2.01 tons/yr
 x 

S/ton of NOx reduction = S 7,133.00/year 

2.01 tons/year 

S3556.00/ton 

It would not be cost effective to require the use of a low NOx burner in building 

1904. Therefore, the Engineering section recomends that the existing boiler be 

used without a low NOx burner. 

============================================================================== 

4.2.4-526
 
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4.2.4-528
 
ADOPTED VALUES ADOPTED VALUES I , I, TWA STEL ; TWA STH ! Substance [CAS N] ppm·' mg/m3t/ ppm·' mg/m3t' I 

I Subslance [CAS N] ppm·' mg/m3t/ ppm·' mg/m3t) I 

·Phenol 1108-95-21­ I Plasler of Paris, see Calcium sulfa Ie Skin (1987) ___ 5 19 - ­ Platinum 1744000-41 0­ Phenothiazine 1!I2-84-21­ I Melal (1981) .... - 1 - N 

Skin (1986) .......... - 5 ­ on Soluble salls, as PI (\981) 0002 - ·N-Phenyl-beta-naphthyl- I 

I Polychlorobiphenyls, see Chlorodiphenyls amine (\35-88-61 (1979) _. A2 A2 - - N I Polyletrafluoroelhylene tp-Phenylenediamine .q: decomposition products 1106-5O-31( - Skin) 0.1 - i (1972) ...... - 81 -­ Phenyl elher 1101·8481.
 , Portland cemenl (1986) . I Ole' . vapor (1976) ........... 1 7.0 2 14 I Potassium hydroxide I
 

Phenylelhylene, see Styrene, monomer I
 i (1310-58-31 (1977) -....... C 2
 ·.Phenyl glycidyl ether (PGE) I _Idl ·Propane 174-98·61 (1981)'. (122·60-11 (1002) .... 1 6.1 - ­ t ooP/lenylhydrazine !.pr~,~~~~ lS~II\~~~) . A2 A2

110063-01- Skin ..... (5,A2) (22,A2) (1O,A2) (44,A2) ! Propargyl alcohol 

.Phenyl mercaptan : 1107-19-71-Skin (\987) _ 1 2.3 (108-98-51 (1978) ....... 0.5 2.3 - -


Phenylphosphine I·{J-~~~~)iola.ctone .'~7.57 ..81 .. 0.5,A2 1.5,A2
 1638·21-1) (1977) ....... C 005 C 0.23 - - tPropionic acid 179.0941 .. 10 30 (15) (45)
 Phorale 1298·02·21­ Propoxur 1114,26-11 (1987) 0.5 Skin /19761 ............ 0.05 0.2
 n-Propyl acelate 

Phosdrin, see Mevinphos 1109-6041 (1976) ...... 200 835 250 1040 Phosgeno 175·44·51 (1978) ... 0.1 040 - ­ n-Propyl alcohol 171-23·81­

Phosphine 1780351·21 (1976) 03 042 1 14 I Skin (19761 .. 200 492 250 615
 Phosphoric acid _Idl
 , Propylene 1115-07·11 (19761
 17664·38·21 (1976) . - 1 - 3 ' Propylene dichloride
 

Phosphorus (yellow) I 178-87·5) (1976) ...... - - 75 347 110 509 17723-14-0) (19861 .... 0.1 ,-Propylene glycol dinilrate 

tphosphorus oxychloride : 164234341- Skin (1985) . 005 0.34 11002587-31 ............ 0.1 0.63 (0.5) (31)
 I Propylene glycol mono- Phosphorus pentachloride melhyl ether
 

11002&-13-61 (1980) .. 0.1 0.85 1107-98-21 (1976) ...... 100 369 150 553
 Phosphorus pentasullide 

11314-8031 (1976) .. 1 3 (II) Simple aspl'/Xianl; see definition in Ihe 'Introduclion to Ihe Chernical SubsI3nces."
 

Phosphorus trichloride (e) The value is lor IOlal dust conlaining no asbeslos and < 1% crystalline silica.
 

17719-12-21 (1982) ....... 0.2 1.1 0.5 2.8 ; Capilal lellels A& [J reler 10 Appendices; C denoles ceiling Iimi!
 

Phthalic anhydride I()Adopted values encrosed are on the Nolice 01 Inlended Changes lis! Consull il i!
 

lor currenI proposal for change.
 185-44-9) (1987) ..... 1 6.1 I; I'" Idenlifies substances for which there are also BEls (see BEl seclion). Substances m-Phlhalodinitrile identified in (he BEl documenlations lor melhemoglobin inducers (fol which I; (626-17-5) (1977) ......... 5 ­ methemoglobin is the principle loxicity) and organophosphorus cholineslerase tPicloram (1918-02-11 ....... - 10 - (20) inhibilors are part of this nolalion. i


tPicric acid 188·89·11- Skin. - 0.1 - (0.3) I' • Subslance idenlilied by olher sources as a suspecled or conlilmed human car· I: Pindone 183-26-11 (1987) .... - 0.1 - cinogen. See the compliation in Ihe Appendix 10 Ihe Uocumenlation of TlVs, pp.
 

Piperazine dihydrochloride A·5(86)-A·9(86).
 

1142-6431 (19821 ......... - 5 - - . Substance for which OSHA and/or NIOSH has a Permissible Exposure limit (PEl)
 or a Recommended Exposure lImil (REl) lower Ihan the TlV.
 2-Pivalyl-l,3-indandione, see Pindone 

t See Nolice of Inlellded Changes.
 

34 I
 35 

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I 

4.2.4-530 
MEMORANDUM
 

Hill Air Force file, Engineering Section, DAQ 

FROM: Nando Heli Jr., Environmental Health Engineer 

SUBJECT: Justification for the use of an existing 400 hp boiler in 

building 1904. 

DATE: January 15, 1992 

Hill Air Force Base submitted some information dated January 8, 1992 to 

substantiate their claim for using an existing 400 hp boiler. In building 1904 

they are replacing a 150 hp boiler with an existing boiler and burner. The 

letter provides some information as to the cost effectiveness of using the 

existing burner and not a low NOx burner. Carl Broadhead talked to a 

manufacturer representative and came up with the following information: 

Cost of low NOx burner S45,000.00 

Cost for installation and chamber mOdificataion 25,000.00 

Total cost 70,000.00 

Using Hill A.F. Base information to get a cost analysis for the amount per year 

for NOx reduction: 

Annualized capital cost assuming 20 year life at 8% rate = 

S70,000.00 x capital recovery factor = 

70,000.00 x 0.1019 = 

s 7,133.00Iyear for 20 years 

NOx emissions with existing burner = 3.68 tons/yr 

NOx emissions with low NOx burner = 1.67 tons Iyr 

NOx reduction = 2.01 tons/yr 

S/ton of NOx reduction = S 7,133.00/year 

2.01 tons/year 

S3556.00/ton 

It would not be cost effective to require the use of a low NOx burner in building 

1904. Therefore, the Engineering section recomends that the existing boiler be 

used without a low NOx burner. 

================================================;============================= 

4.2.4-531 
, '_,-- - A<\~' i 

,~ "T"\,,-, \J[,-...!J-C_i_: --- (,~'\ ...// 

'(J"T"'{'-, ;, 

, ~~C'f.' ''>-~''~' -.v> ) 

DEPARTMENT OF THE AIR FORCE \, 

HEADQUARTERS OGDEN AIR LOGISTICS CENTER (AFLC) 

HILL AIR FORCE BASE. UTAH 84056-5990 

JAN 0 9 1992 fN't 

"0 ..-,1:', ,-­

8 January 1992 

Mr F. Burnell Cordner, Executive Secretary 

Department of Environmental Quality 

Division of Air Quality 

1950 West North Temple 

Salt Lake City UT 84114-4820 

Re: Our NOI, 24 Apr 91, with Supplement, 30 Jul 91 

Boilers-Bldgs 2203, 1624, 2104, 1904; Paint Booth-Bldg 752; Carbon 

Brake-Bldg 507; Emergency Generators-Bldgs 1212, 1213; Additional 

Info: BACT Boiler-Bldg 1904 

Dear Mr Cordner 

Per telephone request from your staff member Mr Nando Meli, we have provided 

the BACT and cast/benefit analysis for retrofitting the proposed old boiler in 

Bldg 19@4 with a new low NOX burner as follows: 

Bldg 19@4 currently has two boilers which are grandfathered. These are 250 

and 400 HP respectively. In the event that the 400 HP boiler goes down, it 

will be necessary for us to fire the proposed 400 HP boiler to meet the area"s 

steam demand. 

This existing boiler has a 1974 manufacturing date. This boiler was operated 

in Bldg 1132 for a period of 6-8 years and, since then, has been in storage 

near Bldg 2~25 for the last 8-10 years. Since the boiler is so very old, we 

do not know the combustion chamber modifications that may be required before 

the boiler can be ~et~ofitted with a new low NOX burner technology. 

Based on a quotation f~om Burner Energy Systems, Placentia, CA, approximate 

cost of a new low-NOX combination burner = $45,000 

installation costs = $20,000 

Estimated cost of combustion chamber modifications = $50,000 

Total capital cost = $115,@~0

Annualized capital cost assuming 20-year life at 87. rate = 

= $115,000 x capital recove~y facto~

= $115,000 x 0.1019 

= $ 11,718 

Estimated annual maintenance cost fo~ the new bu~ner and controls, say 

$ 5,000/yr 

Total annual cost = $ 16,718 

NOX emiSSIons with the existing burner 

(our supplement, 3~ Jul 91) = 3.68 tons/yr gas firing 

-"

= 5.26 tons/y~ oil firing 

4.2.4-532 liP=-==- COMBAT STRENGTH THROUGH LOGISTICS 
-


NOX emissions with new low-NOX burner = 38 ppm - new boiler 

ppm - retrofit boiler 

From Burner and Energy systems graph, 

using 40 ppm @ 37. O~ or 

IS-I. excess = 0.5 lb NOX/l~ BTU 

Total heat input	 = 16.74 mm BTU/hr 

Hours of operation	 = 4,000 hrs.yr 

NOX emissions = 0.05	 lb NOX x 16.74 MM BTU x 4,008 hrs x ton 

11M BTU hr yr 2,000 lbs 

= 1.674 ton NOX/yr 

NOX reduction =3.68	 - 1.674 =2.0 tons/yr 

Slton pollutant = S16,718 = S8,359/ton pollutant 

2 

Based on the above analysis, it will cost approximately S8,300 to abate a ton 

of NOX. The proposed boiler is almost 18 years old. Based on this analysis, 

and bearing in mind the age of the boiler, we request a determination whether 

or not we need to retrofit this boiler with a new low-NOX burner. Please note 

that if the current burner becomes inoperable, we will replace it with a new 

low-NOX burner. We request expeditious review of this NOI. 

If you need additional information, please feel free to contact Jay Gupta at 

777-4618. 

;=~-4
 .-/~N S. HILL 

Ch, Environmental Compliance Div 

Environmental Management Directorate 

,.,-" 

4.2.4-533
 
20:31 NO.057 - P001/002
 

FAX j:ot( ­ I . i 

: 

/

. uj)tJ ).f£ '- /

I 

! 

cF (1,Jt,Y­ 'Mr F. Burnell Cordner, Executive Secretary . 'i ,.-,

S/~M n {b,t7V1 RJ~~ Dept. of Environmental Quality ~~. y r: 

Pivision of Air Quality . NExt aJk.

11950 W. North Temple ~,Y ~~/'f'A ';'sfll 

ISLC, UT 84114·4820 I /1tu: AFIJ. 

Re: Our NOI 24 Apr 91 with Supplement 30 Jul 91 I 

Boilers Bldgs. 2203,1624,2104,1904, Paint Booth Bld~7S1, Carbon Brake 

Bldg 507, Emergency Generators Bldgs 1212,1213 I I 

Additional Information: BACT Boiler, Bldg 1904 

pear Mr Cordner: 

Per telephone request from your staff member Mr Nand Meli, we 

provide the BACT and cost/benefit analysis for retrofitt ng the prpposed 

old boiler in Bldg 1904 with a new low NOx burner, as f 110ft'S: 

I 

I 

Bldg 1904 currently has two boilers which are grandfat ered. Th./;se are 

250 and 400HP respectively. Tn the event that 400HP b ·ler goes own, it 

will be necessary for us to fire the proposed 400HP boil r to mee: the 

area's Sleam demand. i 

I 

This existing boiler has 1974 manufacturing date. This oiler was I 

operated in Bldg 1132 for a period of 6·8 years 'and, sin e then, hllS been 

in storage near Bldg 2025 for r.he last 8-10 years. Since e boiler is 50 

.... ery old, we do not know the combustion chamber mod fieltions that may 

be required before the boiler can be retrofitted with a ne low NOx 

burner technology. ' 

eased on a quetation from Burner & Energy Systems, PI C~ Approx cost of a new low NOx combination burner ;;:$4 ,000. I 

JnstalJation cost =$2 .000. 

Estimated cost of combustion chamber modifications=$5 ,000. 

Total capital cost ::::$1 S,CDO. 

Annualized capital cost assurr:ing 20 year life & 8% rate, 

=$1 15,OOO.XCapital Recovery Fac or i 

I 

=S115,OOO.XO.I019 

=$11,718. 

4.2.4-534 
11/02/08 20:31 NO. 057 - P002/002 

! 

I 

: 

i 

I 

d contrc)ls. 

say S5.000./Yr 

;Total annual cost =$1 .718. 

Estimated annual maintenance cost for the new burner 

I 

NOx emissions with the eXIsting burner (our supplement 30 luI 91) 

;:;;3.68 Tons/yr Gas fuing 

=5.26 Tons/yr Oil firing
 

Note: Oil firing serves only as a back-up. !
 

NOx emissions with new low NOx burner 30PPM-New ~oiler
 

4OPPM-Retroflt boiler 

From Burner & Energy Systems graph, I 

I 

40PPM at 3% 02 or 15% excess air =0.05 Lb NOx/MM B 

Total heat input =16.74 MM Btu 

·Hours of operation ;;4.000 Hrs/yr 

NOx emissions = .05 Lb NOxlMM Btu X 16.74 MM Btu r X 4.0001 Hrs/yr X 

Ton/2.000 Lbs 

1.674 Ton/yr
 

NOx reduction ;:;; 3.68-1.674=2.0 Ton/yr
 

S/Ton pollutant = S16.718./2:;$8.359./Ton pollutant
 

:Based on the above analysis. it will cost approximately 8300. to ~bate a 

ton of NOx. The proposed boiler is almost 18 years old. ased on this 

analysis and bearing in mind the age of the boiler. we equest a i 

determination whether or not we need to retrofit this b Her with Ia new 

low NOx burner. Please note that if the existing burner !becomes 

inoperational. we will replace it with a new low NOx b~rner. We ~request

an expeditious review of this NOI. i 

!f you have any questions. please feel free to contact 1a Gupta at 777­

:4618. 

:Sincerely 

IBob Van Orman 

.Director, Environmental Management 

4.2.4-535 

I 

i 

I ~~£ 2 OF Z. 
-------------------------------------------------

------------------------------------------------

----------------------------------------------------

I
 

/P-t'£-?'/
 

/t'IUkiZ fi.7ec.E bJJ:E; v;:;: Th~R~ IS·NO !NV~2SION

A~OSPH~qIC-STA?-:~:7Y'?ARA~~E2:s %F-;: A/O~ Zy /4~ '7'1 - , . .-

SPILL SITE ~OU~~N~SS LENGT~ ~~ 50 

THIS IS A GAS REL~AS~'

HC'!GHT OF LEAK ABOVE: GROUl\:l) l.~ 6 M 

-EMISS.ION·RATE IS 'w 01' KG/MrN 

CHEMICAL ~s STILL LEAKH!S .­

CO~C:NTRATIQN AV~RAGING T~~E IS 15 MIN ELAPS~D TrM~ S~~C~ START 7C _"

,_...." 

HErSHT ABOVE "GRDUND IS 0 DO~NW~~~ DISTANC2 rs 150 ~Ru3S~!I\rz) DrSTA~-lC~ :::5 o·r·; 

:.1t::.

...... 

e:-' -, . STAF:T ,,-~.:..:.....:...- IS MIN H2IG~: OF INTEREST IS 0 M 

90% PROB HAZARD D!ST = 1B2 

~~D ~IDTH :8~

:::.=-~, THE MA !:'1ur--r DISTANC~ FOR wOl , : I: :8 87 

THE rfAX I MUM DIS7A~C~ ~OR .02

-~--------------------------

ELA~SED T!M= SZN~~ START.OF SPI~~ :s 60 ~~N

.- H·E-r:;PT- '0'1:":' IN-ER-S- .. s 0 M- .'.. - .' .::. .• .J. 00;1. . '. ~_:. t ~t:. I .... ..:.. ...._..':- J. .'.--:-. .• 

. . ..' ....... ... - .... , ... -- .'-':" .......
 

. 90%·PROB·:~~ZARD DIS'·.= -iS2 M 

··:::-iAL..~;-·.DTR--· AND WTDTH:~ lSG:":- 75 D~13 :':" '.' '.' ~:- . ~- & •• .. .. - • .-: . .. TciE.~.AXTMUM ~:STANC=: FOR. 01 ;:'PM is 87 i'l 

_·:tHE!"1AXIMUM nISTANC:=: FOR _03 P?M IS '~8 1"1 

....; 05'~PPM '-IS TGG HIG:-i 

. . . ,' 

...... 

.... 

....

.,;., 

'<:. 

-.. , .~.-: -­ .... :',:,:--.• .:.-:.:.. ':.... .'.-.' 

.. ..-... 

4.2.4-536 
--------------------------------------------------

{-

Hil: A:=B 

D~TE: 10-11-1991
 

TIME: !.2:00·LST
 

CONT~NUOUS RELEASE
 

CHEMICAL = Phosphoric Qxides
 

.MOLECULAA l,IJElGHT -. 63
 

..
 

TEMP£~TURE:''';' 22 C
 

~,-.	 WI~JD.. DIRECTION = 0
 

!.A,!IND S?t:ED· =- 3 l"i/S
 

SUflkE.L.E.VATI ON: ANGLE IS 42 ~ESRE~S
 

CL;.DLii:f::.cciv..ER:~::tS~2·..EI GHTI-iS
 

· CLOUD TYP~~.!S 'MIDDU; (Ac, A~~ Be.
 

GRCUNDIS'DRY
 ... ,THERE:.IS :;:NO~~NVERS m.t
 .. P;rMOSPHERiC'~STAB.Ir..:.!TY· PAF-:AMETER IS
 

S?ILL··siTE··.RCLISHNESS LENGI~ .!.~ 1(:
 

. .:. .:..•.;.. .. '.. ; ~-~ ,..
 

TtiI SIS ..A..GAS· RELEASE
 

HE!SHT OF:LEAK ~OVES20~ND IS 6 M
 

EM1.S--0NRAIE -So Q' ---1M-hi
 ·::u~...°ICl.·A·L·;::"I:S":ST:~t I" ~., ~A'·K:\.~"~ ,;,.~ ~'.~ .....', ...•1-_ .~_ ..Lt"(t= 

_ CDNCENTRATrON·AVS::~AGING '7IME :S ::'5 M~"~
 

.SL4PSED· ..TIME:.SINCE.START OF S:=·ILI.... :S 240 ;.;~~~
 

"HE-i:'G8T:: ABoVEGRQUND IS_(~ M
 

. ..·D9>~·~. N[).:::.D"i$TAN~E;:·~ 8.:.1. 50' M
 

.>, ..CROSSWIND.:.::DISTA,,'\CCE.·...IS .. ¢M .
 . :.:~ '~'.'~::'. .' '. ..::.~;..;.;;.-=--~.:- __.-.-----.-----~:....~-------_..:..._-- . - .. ' : ,;7 .. :01'. 

··TWC···CONC·-=-'N·T·.R'A'-l T·'"'N·:··TS· '··0')5 ~!:::'.~ . ·'-'1 :"''""" .M';") · _".:.~.-:-:'- :. _. _w _ 1., ."_' __ .lw It .J 

'- ---------------------------------------­ __ -..-- -	 . . - .

· =:LAPSED TIME S:::NC::>STP:RT C:= S?::-L.. :::S 250 M:i'; 

~EIGH!._OF._":INTER=.ST_.. IS (;. r: 4.2.4-537 . . . 

.. . .. . ~90~.:::_~~~_.H8?~~<D. !JIST = 275. 

.,' .~.H~Z~RD DIR.. ; :(~ND WIDTi-i 180 .r. - 75 DEG
 

. :0Er·~A;::IML;:..:1·D:S7ANCE ;:':JE=: r',· ??:-:i IS ~~. ;-~
 

:..~.:.:.:·.. ;·~THE·~.MA~r-t~UM.·:.:D-!STANCE :-:-;~-~ • ~;~ PP:"i. IS .=.~ l..t
 

~,:·~~Di~:~:i?;~:·~:~~J::.·.~~~:;T~9·~.I.G
) -

.-

, _.'

" ,

)

,

,

\

:.--~.'-:'':':-'''-; :" .... --:-

.~. -...;.

:- '; .... ..' . ..:... ..

.. -..

. -..~:.'. ; .. " -.-

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

~.:::.::~ .

.- .

4.2.4-538
DET1'-!!.ED DOCUMENTATION F;.e.s'" ~tI,/Jt.E of ,;J~&S P£)~I?/IJIA/4 -:"'#£ AdPEL.. 

tlJ~-' P? A:f;v/!E Ir)/Pv .IJ&"£P ~PU'"?";

Purpose: AFTOX ~il1 deter.mine toxic chemical, concentrations and give 

the user the option of calculating a toxic cor=~dor, the concen~ratio~

at a specific locationr or the maximum'concentration ~~d its locat~on.

2.,	 P.;>plicatioD: AFTOX .....as devel.oped for real time analysis of toxic 

chemical releas~s.usage of.AFTOX is governed by APR 355-1, AWS 

Supplement' 1. It is writt~ so that ]l}iiS base weather station.s' Ca.!l 

apply AFT9X,,~0 continuous or instantaneous, gas or, liquid releases 

from either, ground or elevated. sources. It can also be applied to 

hea.ted plumes from smokestacks. .?-.FTOX ,contains seventy-six chemicals 

on file and has the capability to add othQr chem.ical.s. . 

3.	 Structure: A detailed explanation of AFTOX is contained in 1>..FGL-TR88-0009. 'AFTOX is comoosed of several files which are linked' 

together. The program- files are DSP1.EXE, - DSP2 .EXE, DSP.HP .EXE, a.."1d 

DSP3.EXE. The file structur~ is as follows; 

a.	 DSPl: This file dete~;nes the chemical nrooerties and meteoroloaical 

conditions. Schematic representation- is- shown in Figure 1. ­

Figure 1. DS?l Flow Diagram 

<Station Data> 

I 

<nate and. Ti.!ne> 

I 

<Type of Release> ----buo~-ant plt;me 

I	 I 

,instantaneous or continuous I 

I I 

<Chemical Data> I 

I I 

CALCUT--r.i"_TE I 

Solar J>.ngle. ----------- [ , 

I 

<Temperature, Wind, Cloud Amount> 

l 

[ I
 

Dl>.Y NIGET
 

<Cloud Type> I
 

! I
 

I CbLCU~;TE I I
 

lSolar Insolation I I
 

! I
 

snow cover? -----yes---------l I
 

I I (
 

no [ I
 

I ! I
 

<Ground	 Mois~ure> ------------->\<--------------------1 

I 

( CALCU~_TE [ 

IReat Flux I 

I 

<Inversion Height> 

4.2.4-539 
I CALCULA.TE	 I 

IFrictionVelocitv, lO-m Wind Speed I 

I Monm-Obukhov Length 1 

I 

.' 1 CALCULATE ! 

{Stability Parameter \ ------buoyant plume 

I	 I 

<Roughness Length at: Spill Site> EXIT 

I to DSPEP 

1 CllCULATE I 

,Properties of AirI 

I 

chemical properties on file? -------------no 

{	 I 

yes	 ----- gas --------->\ 

I	 I 

liquid	 I 

[	 [ 

I CALCULATE I r 

IChemical Properties I ----->EXIT to DSP2 

Major computations of DSPl are described as follows: 

(1). Solar elevation ~gle: DeteDnined using date, t~~e, la~itude

and longitude. 

(2). Sensible heat flux: DeteLmined bv one of t~o methods, depend~it

on daytime or nighttime conditions. 

(a). Day: Cloud ~~ount, tempe=ature, ~o~~d state, and solar insolation (from solar angle, cloud 'amount and cloud type) . used.. 

(b) •. Night: Cloud amount only is used. 

(3). ·Turbu~ence parameters: Friction velocity, IO-meter wind speed, 

and Monin-obukhov length. axe interre.lated and a:ce de.tenn.ined 

iteratively from. initial estimates based on the wind speed, heat 

f~ux, surface pressure, and surface roughness. 

(4).	 Stability pa~~eter: One 0= two methods of computation are used. 

(a). Method ..1:· :Tn.r:bulenc~ pa.rameters de.sc=ibed in (3) _above are .used. .. - .. - . 

(b) •. Method. 2: -Standard. deviation of the,winddireetion and ~-nd

speed':at 10 m :are. used. 

(5). '.Air propert~es: 'Density and viscosity.are compute~ from 

tempel:"2..ture and pressure. . (6). Chem:ical'-orone-rties: For a liouid. chemical wh.:ich is. in. the data 

fi.le, the~vaPor:pressure, ~iquid .dellsi.ty, .and vapor-. density 'are 

.,. ··.computed::from the:.chemical data, the air· tem?erature,. . and·' 

pressure., _ . 

b.	 DSP2 : .. This. fi1.e.:dete:on.i.nes the source ·conditions. (e~g.,· emission 

rate· duration of.:spi.ll, area.:of spill,: and source: strength).~:·;:.:-.. processinqthrough.;:nSP2:·is':dependent.:·OIl.. type' of;re1.ease.·:. The:··.. :. 

air,temperature:is~compared.:to the chem:ical~s boil.i.J::l.g·. point to 

deteI:mine.if,it: is 'a-caseous or l.·icruid'soill. If the chemi.c·aY 

of .interest is.. noton~file.,':de.fault settings may be used L.. 

or user.may i.nput molecular we"Tght, - vapor pressure, and whether 

re~ease is_ a ~iqu.id or gas to determine source. strength.· 

Schematic ~epresentation of qSP2 is. sho....-n·in Figure 2. 

F~~ure 2. DSp2 Flow Diagram .
 4.2.4-540
 

DSEl
 

·1 . 
I I 

GAS I,IQUID 

I I
 

<Height of Leak> I
 . I \ 

, I	 [ 

continuous instanta..'"leous continuous	 instantaneous 

I I	 t 

<Emission Rate> O..mount Spi~led> v......mission Rate> <.Amount Spilled> 

I 1 i 

<Spill Duration> I C1i...LCUT.......:zi.TE I <Spill Duration> 

! ! Area I I
 

I Q...LOJI.}.TE I I lCALCULATEl
 

I J..mount I I CALCULATE I [ .A..'11.ount!
 

I Spilled I I Source j I Spilled t
 

I I Strength! I
 

\ I , CALCUL..~TE 1
 

1 I I 1'..rea I 

I I I 

I ! reasonable? ---no--> <Area> 

I I I 

I I yes CALCUT·A.'l'E ,	 't:"'.....-~ -.... __ ....... ..: __. r
 I	 1 I ,	 l ......... -~ ..... -...-._-"- .. a I
 

1 !	 R2.::.e 

I [ I 

1 I I CALCULAT=: I 

I I IEvaporation I 

I .! I Time I 

I [ J I 

[---------------->1-------->1<------1<-------------------1 

I 

EXIT to DSP3 

(1)	 _ COntinuous gas release: Uses the emission rate and the total 

t~e of the spill to compute ~he total amount spilled. The 

emission rate is the source strength.·· 

(2)	 • Instantaneous gas release: Uses the amount spilled and air 

densitv to determine the initial vol~e of the snill. 

(3).	 Continuous liquid release: The evaporation rate- into the 

atmosphere is the source strength. If the area of tae spill 

is knorm, it is used to dete=mi.n.e the evanoration rate. If the 

area is· unknown, then the evaporation rate is -set eaual t.o the 

emission rate· and an area is calculated. If ~is c~lculated area 

appears unreasonably large, then user may ~~put a smaller area 

which will. give a new evaporation rate. An alternate method 

exist for chemicals rd.th.out full data· information. Evaporation 

rate is~· determi.!1ed.using ..spill. area, pool temperature, chemica.l 

molec.ular weight .. and vapor pressure.: If V2.riables are unknown, 

the "model assumes the worst case and the evapora-.::ion :::::ate is set 

equa~ to the emission rate. 

(4).	 ~stantaneous ~iquid release: Uses the amount spil~ed, area 

covered,. chemical and air nrooer-~es to comoute the evanoration 

rate. Tbe evaporat.ion· rate i; set equal to~ the sou.::ce ;trength. 

The amount spil~ed and the evaporation rate deter.m£ne the total 

evaporation time •.. The alternate method listed in (3) above is 

used if ch~cal data is not available. 

c.	 DSPRP:This file determines the source,conditiocs for a buoyant 

from a stack (e.g., emission rate, du-~tion of· spill, heigh~ of 

spill) _. Source strength is set equal tome emission rate. As 

4.2.4-541 t? "',- L /IF f 
;/ . ' .. :.~: shown in .. Figu:=e 3, a.tmospher:"c conditions d.ete~e p:=ocessing

-. 

_ - .... through·the .modu~e •. 

vi.gure 3~ DSPHP Flow Diagram ­ DSP1. 

I 

<Molecular Weight> 

I 

<Emission Rate> 

I 

effluent still being emitted?-----------no 

I	 I 

yes <.Elapsed time 

r of emissioD> 

I I 

<Sta.ck Eeight>----------<----------­

I 

Stack height above ~version?-----------yes

I 

no 1 

END 

.--" _~ .. __ .L... .... """ 

.. -~.:- -- "..:;." 

1
 

1
 

I C~..LCtJh.~TE I
 

IBuoyancy Fluxl 

I 

I 

DNSTABLEATMOSPEERE 

I 

I CALCOLA'I'E 

(Equilibrium 

I Distance 

-I 

I CALCULATE 

IEauilibriurn 

I Height 

I 

t 

I 

1<-----------1 

Eeightl 

(1.) •	 If stack height is above the i~version, then progr~ terminates 

since surface input meteorological conditions most likely do not 

apply above the inversion. 4.2.4-542 

~A-f,f	 -7LJrtf' 
.	 / 

/.(ll ..;':eu';'yatl:'" allY-': I~ is de~e=io.<>d usio.g ~!l<> ah"temperatur<>, s-as .....; :~. :stack ....empera....ure~ volume flow rate, and g=avitational 

::.: _:: acca~eration.

(3) .. Unstable or·neutral conditions: T!le buoyancy flux is used to 

. :··:computa .tile distance downst=eam vrn.~rQ the ecrui:li.briu.m heigb.t is 

reached. This distance, the buoyancy flux, -and wi~d speed 

determine the equilibrium. height_ 

(4) .	 Stable conditions; The buoyancy flux, wind speed, and potential 

temperature lapse rate (based on the degree of stability) are 

used to compute the equi~ibri.um height. DOWDwi..:.~d dist2.!2ce where 

equ~librium height occurs is not needed. 

(5).	 Effective plu..-rne height: This is equal to the. suru of the 

equilibrium height c.Ild st:ack height above ground. Model assumes 

gas is released at the effective height for dispersion calCUlations. If the effective height is above the inversion height, it: 

is set equal to the in~ersio~ height. This is a conservative 

approach-for calculating g=ound concentrations. 

d.	 DSP3: This file computes the hazard area (determined by concentration), concentration at a given location and time, or maximum conce~­

tration and location, and outputs the results. The t}~e of output dete~nes the processing through the file, as sho~u in tae 

flow diagram of Figure 4. 

'i.g-ure 4. DS?3 Flow Diagram 

DSP2 or DSPli.? 

I 

l-<---------------------I-----------------~->-l

I	 I I 

1?TION 1	 OPTIO~ 2 OPTION 3 ,.,....--.. oured plot) {conce..'1.tration at (max conc~t=ation)
 

I ~i~~dt~e) I
 

<Concentration I .<Elevation> ..
 

of Interest> <Elevation>·1
 

I	 I I 

<EleVGtion> <Downwind Distance>	 I 

[	 . I· .. - [ 

output plot <Crosswind Distance> r
 

;.ckground on scree..Tl [ I
 

I I -I
 

1---->1---------------------->1<--------------------1<-1 

j	 I I 

[ I. CALCULATE I [
 

1 I Dispersion t . !
 

1 ICoefficients I no
 

\ ·1:- and I I
 

I IConcentration [ I
 

! [----------:-:-:--1 I 1----.------,------> maxiinum.?
 

I I I . I
 

! equals contour I I
 

o<---concentrat.ion'? I yes
 

I ! I
 

yes I ]
 

I I I
 

lot concentration I I
 

I - 1 I
 

-plot comp~ete? I !
 

I I	 I 4.2.4-543 ye& I	 ! 

I :	 It 
/

FAX FO/( .. IIANPO Ne-Li 

PRDM ; 7A'I t:tlt'7'~" HAFt! -, 

Rill Fir Force Base-Utah RECEIVEU 

Nando Meli OCT 01,7991 Div of Air Quality 

1950 W North Temple AIR OJ IAl ITy SLC UT 84114 

Ref: Additional Infonnation on our NO! dated 24 Apr 91 and 

supplement transmitted 30 Jul 91, Boile:!:'s Bldgs 2203,1624,2104,1904 

and Ca~bon Brake Coating Bldg 507. 

Pe:!:' our telecon of 27 Sept, we provide additional ;nformation as 

follows: 

We will ~evise boilers purchase requisitions to require low NO~

burners with NO~ ~ating of 40 ppm or less. Excep~ion to this is an 

old existing boiler for bldg 1904. We are not replacing the burner 

for this boiler. 

MSDS for the Bendix P-j1 coa~~~q is enclosed. This coa~ing contains 

phosphoric acid ~~d mono-alw~i~UD phosphate as oyidan~s. the exact 

composition is not available ci~e to proprieta~ reasons. 

The coating ov~~ temperature is 900 degrees C, the exhaust pipe is 

1 inch ;n diameter and point of discharge will be app=oximately 20 

feet abo~e grade. At 900 degrees Cr the cischarge volume will be 

about 20 acfm • 

The hours of operation for the coating process will be 2000 hrs/yr 

nominal and 4000 hrs/yr rn.a:-:imum. Based on this, max;!nu:n POx 

emission =ate will be as follows: 

250(gal)x8.33xl.5(S Gr)x.85(Evap)x45~xl!200?xl/3600=O_157Gm/Sec 

Nominal POX emission rate will be 0.0835 8m/Sec. 

Jay GU~

EJ:Ir~n Engr 

4.2.4-544
 
.......
 

ALL!ED-SIGNAL AE~QSPACE COMPANY 

A L!N1T OF ALlU::D-SIGN.:il INC_ 

BEN~rX ~HEELS ~ND BRAKES OIVISrO~

~ATERrAL 5~FETY D~TA 5kEEr 

The f':lllc~lir.g cat:l. ~~." be I..:.SCU to c::::,:~ly \-lith OSHA'::; H=::i1('t~ Co.n~t;:'1ic~tio:"'l

St'::!1~_~:·M .::Jr"]. rFn i9l-:>.120C. 7:-;,"-: ~tcl~;;l.Jr;:: ;;;,,-;0"';. IU_'looil-:·.... t.:r .. l:e '-[."\I',:".u1 te~ ~l­

-~;::::e~iric: l""equirements. 

,;11 of ~t'e p.2r tic:ula.te i:1 g r ediet"1.l:s in Carbc~ Disk E:-ak!:? f1"" i:::: tier, r::\=tel·i~l

~1"'oc~'.:l;s ~f"e siiitef'"ecJ tCJ:;~ther to forrn 03. solid m.at.:rLa.!. Hc::~r::~ ;-:~H":':'1.i!.l·

aSS;lC i:~t~c,j o-li th Exp~s~re to or CC:'1t.;c'= with ;::~r~ :.i~st:::. c::rf ·the I ~~':S:::1 . 

it'lqrC?ci~r1t~ ere not expec:tC'c t:::: be ~iCJnif.ic.c::.nt_ _ All i.ed-Siyn.ai hdS 1. ist.t·' 

.=.11 of the es::enti~l ingre.·dien":s p!"l:sent in a. series of prec-.:~t.s cf't!lis 

qeneral c~sc.ription_ The r2~ommended expe~U~G !i~its·ar~ t~ose f~r- ~~~

most haz~rdO~S su~z~ance in a c.la~s of sl..:.bstanc.es. Ex~~~ 70r~ul~t~~ns ~l

~rc~rieta.y and ther~fcre confidential. Precise p~cc~ct in~er~~ti~~ ~ilt

not bli' di!!c.1C5.~d, otr>.er t1i.an in ac.ccrd.::..c.e witl"1 a.p~li:=':'ble l..~.ws •.l'""z~ rc-g:.(­

latio~s, or wit~out a ~ritte~ Sec.e:=y ~~ee~ent_

~11~e0-S~gnal shall in no :vent be re$pcnsible fer any d~~~~~s cf a.~i

!'"latI.Lr<: or ~ir.d olrac:"cly 0':"" i...-:ci;-Ectly re'.>ultim; frc~ cr u.~ising Cl.,;:' :::f ti.. ' 

~~bli~~tio~ or uSg of c~ ~~li~nce ~~c~.data CCt~tai~2d ~erei~_ ~·~rc ~~i:~~~~

cr i~plied war-ra,:-1ty 07 ~:"':y ki~d, i~C:!t.,;dir:9 wa.r:-c;nties cf .~c:rch~~l\:.. iL:~I~='j1 : 

fit:":t:S5 fa.- tJS~, ~ith ~e'Spect to tt~e F"r-ic"ticn Ma:t2~ial ~r"'=-~!...:.::;'s C~ to th·1 

d~~a her~in is made h~re~nde'.

-------------------------------------------------------------- -----_._­

Atlie~-Si9~al·Aerc5pace Comp3~Y De te Pl-e~~.£d: .:r':::'T1.~a.r --; -(, j 9:3::: 

a unit of Alli=d-Sign~l !nc_ ?'ED:areo By: ~_ L. t.!ce:C 

Eendix ~he~ls a ..d 3rak~s Division 

Adur~ss: P.O. Eox 10 

South Bend, Indian~ 46624 

._------------------------------------- ---------_.--" . -- - --..._----­

SECTION II - Hez~rdo~s !ng':""ccients/!dentity lnformati~n

Oxid~tio~ Pen~~r2~~

P/~ 7~'0~n~ r~_,,)

Cammon NGr.\e<s) ~"'CGrH TLV OS~A PEL 

PhOSphor-ic:: Ac:id l~g/m=:

Mono-~luminum-?hosph2te 2~C;; (AL) /~-;: ,"'

""".... 

- ic: Ac id NA 

Poage of 4 

4.2.4-545 
---

----------------------------------------------------------------------------

..LV' V'" ................ ...
 1,-' :.:.",	 (~~-.::,. '...:.'~~~ \::.. ... ~~

~J ~.

-. SSCTrCN tIl 

O.:J iIi ng Po i n t : 1 CO':OC Specific Gravi.ty: 

Vapor Pressure:(mm Hg_);:)2tY'C -0.028::: Melting Pcslnt: 

V~por D~nsity:<Air = 1] a2~oC - 1.964 Evaporation R~t~: .,.... "I""t 

(Butyl Acet_~e = 1) 

Solubility in Water: - ( >100g/100~1 ) 

Ap;::3'2arance cane Ocor: Transpare;1t (Oderless) liquid 

-------------------------------------------------~------------ ----------.

SECTION tv - F~ra and E~plosior'l Hazard Data 

Flash Point (Method Used): Not	 NA L =; • UEL: 

fl2.mr::~:::le
 

inguishing ~dia: Net flilc:r.:able
 

SpecL:ll Fire f-ighting Proceol;res: Use SElf-centai~ed b1eathing e~~~ratu~.

Use dry chemical~ Carbon Dioxid~, or foam fer fighting lires. 

tJn~:~u~l Fire eno Exp losior'l Hazards; Dcl.ngerous; wh~n h:2a 1:=:1 to =.~-:=c;::::­

pcsiticn, emits· toxic ~um~s of POw. 

SECTION V - Reactivity Data 

Sta!:lility: Unst.able:	 Conditions to Avoid: 

know_ .., Stable: '" 

Inccmpatibillty (Materials to Avoid): Strc~g bases (Caustics) 

H2..z2...... ~·:::.~= necocr-pC'~ iti on or EyProduc: ts: nF.'r:nmpnses upon l"1:?d t i. -:og -:..~ : C~ :-I~

toxic and/o~ corrosive gases or fl;mes of POw 

Poly;;;e:-ization:	 May Occur: Conditions to 

will Not Occur: V 

A 

4.2.4-546 Pagl;' 2 of 4 
---------------

.- ..... - -' 

SECTION V~ - Health Ha~ard D~ta

Route(s) oT E~pcsu~e: r :'"1M a 1 a t: ion? Yes Skin" Yes 

To~ic when heated to above lOO?C. 

Health H~zards (Acute ~nd Chrcni~):

Cor~osive to skin and ~yes.

Cu~cinog~nici~y Listing: NTF? 

NA 

TARe ~cncg":"'ar.h;;?

NA 

8~} {;; Rftf,JtI cl :'~cl·

NA 

Msdic~l Conditions Ge~erally As~rav~ted by E~pcs~~e: :":O.tH:-' Ct,:;:-:-'"(.:?!"1 t 1. y 

known 

c=ei;~ncy and F!rst Aid Proc:dures: 

If penetrant contacts eyes,skl.n, clothes (rel71ovel, fl:,,;s:l ::::.:::...ec~atEly

with lar~= amounts of cold water. W~sh ey=s fO~2 ~i~i~u~ of IS mi~­

u.tes~ C.:1.11 a. physicilI~. !-f ingested, i=:ledlatel~' cal t a ph-ysicL-::.n. 

S2CTION VIr p'rec:::au t ions for Safe Hanel i ng ar~d U~E'

Steps To Be T~~en in CaSE Material is Re!~asE'ci cr Spill~d:

Ne~tralize spill with scdiu~ b:c~.~c~ate r - _.-J -. 'l -...;. ... ~-~ .. ­ material. 

Uaste Oi~posal M~thod:

CautiouSly add to an excess of wdter. {\dj~.t$t pr: ::0 neu Lr~ 1. Separat~ any inscluble solids 2nd package -for'" waste disposal_ 

'cautions to be T~ken in Handling and Storing: 

Store at rOom temperature away from strong b~5es.

4,2.4-547 Page 3 of 4 
-... . ~.. '" 

."--,, 

MSDS NO. 400 

.­

Other Precautions: 

Do not Wear contact lenses; see cootrol measures. 

SECTION VIII - Control·tleasu~es

Provide adequate general or local·ventilations to keep vapors. 

below P.E.L. for phosphoric acid (1 Eg/m3) and alumiouc (2 og/e3). ,-----~---

Protective Gloves: Acid - resistant ~ubber gloves. 

-

Eye Protection: Safety Glasses: Ch~ical goggles or face shield. 

Other P=otective Clothing or E~uip~enc: Acid - resistant apron. 

k/liygiene Practices: wash work clotbes separacely from other 

:'.J.othes. -. 

4.2.4-548 

Page 4 of 4 

@ ----_ .. .... ...... 
DEPARTMENT OF THE AIR FORCE
 

HEADQUARTERS OGDEN AIR LOGISTICS CENTER (AFLCl
 

HILL AIR FORCE BASE. UTAH 84056-5990
 

Mr F. Burnell Cordner, Executive Secretary 

Bureau of Air Quality 

1950 West North Temple 

P.O. Box 16690 

Salt Lake City UT 84116-0690 

RE:	 Request to supplement our NOI, 24 Apr 91, Replacement 

Boilers Bldgs 2104 and 1904 

Dear	 Mr Cordner 

On 24 Apr 91, we submitted a Notice of Intent to construct two 

replacement boilers in Bldgs 2203 and 1624. In addition to 

these, we also propose to install similar boilers in Bldgs 2104 

and 1904. We request our referenced NOI be supplemented to 

include these boilers. Design data and emissions from these 

boilers is provided. 

If you have any questions, please feel free to contact Jay Gupta, 

EME, 777-6917. 

Sincerely . ( 

)0Nvtu R. U~~

JAME S R. VAN ORMAN ,...":"~.~~ 2 Atch 

1. Design Data/Emissions Director o( Environmental Management 2. Vendor Brochure 

4.2.4-549
 

-Ii;IiC-- COMBAT STRENGTH THROUGH LOGISTICS
 
REPLACEMENT BOILERS 

BLDGS 2104 & 1904 

Bldg 2104: 

Bldg 2104 has two boilers; one is 200HP and the other 150HP. An 

energy study has shown that if the larger boiler (200HP) was to 

fail, then the mission essential load could not be met by the 

smaller (150HP) boiler. There will be no change to the 200HP 

boiler. We propose to replace the 150HP boiler with a new 250HP 

boiler. Vendor brochure on the new boiler is attached. Design 

data is as follows: 

Boiler rating 250HP 

Primary fuel Natural Gas 

Back-up fuel #2 oil 

Steam Rate 8,625 Lbs/hr 

Total heat input 10.45MM BTU/hr 

Total heat output 8.37MM BTU/hr 

Thermal efficiency 80% 

Gas heating value 1,000 BTU/SCF 

Gas firing rate 10,450 SCFH, Add 10% = 11,500 SCFH 

oil heating value 140,000 BTU/gal 

oil firing rate 1.24 GPM, Add 10% = 1.4 GPM 

Estimated Stack Gas Volume; gas firing 4,270 ACFM 

oil firing 4,345 ACFM 

Flu Gas Temperature 465 of 

EMISSIONS: 

Existing (150HP) Boiler: 

Boiler HP = 150 

Theoretical heat input = 150 HP X 33,472 BTU/HP = 5.02 MM BTU 

Fuel to Steam efficiency = 80%
 

Total heat input = 5.02 = 6.275 MM: BTU/hr
 

0.8 

Boiler probably averages out at 70 - 75% load 

Fuel firing rate:	 Gas (1,000 BTU/SCF) = 6,275 SCFH 

oil (140,000 BTU/gal) = 44.82 GPH 

operating hours: Only one boiler runs at a time and they 

alternate. These boilers operate from 15 Oct to 15 May and are 

generally shut-down during the summer. Estimate 5 months, 

24 hours operation each boiler = 3,600 hours. Use 4,000 hours. 

Emission factors AP-42, Tables 1.4-1 and 1.3-1 

- 4.2.4-550
 
Gas Firing: 

Pollutant 

Fuel 

lXl06 CFH 

E.F. 

LB/I06 Cu Ft 

EMISSIONS 

LB/Hr TPY 

Particulate .00627 3 .02 .04 PMl.o = .02 

SOX .00627 .6 Neg Neg 

NOX .00627 100 .627 1.25 

HC .00627 6 .125 .08 

CO .00627 20 20 .25 

Oil Firing 

Pollutant 

Fuel 

1X103 GPH 

E.F. 

LB/10 3 Gal 

EMISSIONS 

LB/Hr TPY 

Particulate .045 2 .09 .18 PMl.o = .09 

SOX .045 142 S 1.28 2.55 

NOX .045 20 .90 1.80 

HC .045 .34 .01 .03 

CO .045 5 .22 .45 

S = 0.2 wt ?<­ 0 Sulfur, typical 

New (250) Boiler: 

Gas Firing 

Pollutant 

Fuel 

lX106 CFH 

E.F. 

LB/I06 Cu Ft 

EMISSIONS 

LB/Hr TPY 

Particulate .0115 3 .03 .07 PMl.o = .03

SOX .0115 .6 Neg .01 

NOX .0115 100 1.15 2.3 

HC .0115 6 .07 .13 

CO .0115 20 .23 .46 

4.2.4-551
 
oil Firing -,

Fuel E.F. EMISSIONS 

Pollutant 1X103GPH LB/103Gal LB/Hr 

Particulate .084 2 .17 .33 PM10 = .17 

SOX .084 142 S 2.38 4.77 

NOX .084 20 1.68 3.36 

HC .084 .34 .03 .06 

CO .084 5 .42 .84 

Net increase in emissions: 

Gas Firing NOX = 1.05 TPY 

oil Firing NOX = 1.56 TPY 

SOX = 2. 22 TPY 

BLDG 1904 

An existing boiler (a grandfathered source) had been removed from 

service in Bldg 1132 and was in storage near Bldg 2025. We 

propose to put this ~iler back in service in Bldg 1904. Design 

data and estimated emissions are as follows: 

Boiler HP = 400 

Theoratical heat input = 400 HP X 33,472 BTU/HP 

= 13.39 MM BTU 

Thermal efficiency = 80% 

Total heat input = 13.39 = 16.74 MM BTU/Hr 

0.8 

Fuel firing rate: Gas (1,000 BTU/SCF) = 16,740 SCFH, 

Add 10% = 18,414 SCFH 

Oil (140,000 BTU/Gal) = 119.6 GPH, 

Add 10% = 131.5 GPH 

Operating Hours = 4,OOO/Yr 

Emission Factors AP-42, Tables 1.4-1 and 1.3-1 

4.2.4-552
 
EMISSIONS 

Gas Firing 

Fuel 

Pollutant 1X106 CFH 

Particulate .0184 

SOX .0184 

NOX .0184 

HC .0184 

.11 .22 

CO .0184 

Oil Firing 

Fuel 

Pollutant 1X103GPH 

Particulate .1315 

SOX .1315 

NOX .1315 

HC .1315 

CO .1315 

E.F. 

LB/106 Cu 

3 

.6 

100 

6 

Ft 

EMISSIONS 

LB/Hr TPY 

.05 .11 PM10 

.01 .02 

1.84 3.68 

= .05 

20 .37 .73 

E.F. 

LB/103 Gal 

2 

142 S 

20 

.34 

5 

EMISSIONS 

LB/Hr TPY 

.26 .52 PM10 

3.73 7.46 

2.63 5.26 

.04 .08 

.65 1.31 

= .26 

4.2.4-553
 
___'CEWANEE,	 _
 CLASSIC III (60 H.R thru 800 H.R) ­

150 PSI STEAM 

Packaged Scotch Design Firetube Boiler 

Oil, Gas, Combination Oil/Gas Fired 

• Boiler. Burner package IS U/L listed. 

•	 These units. rated at 5.0 square feet of fireside neatlng 

surface per bOiler horsepower. maXimize efficiency and 

servtce life. 

•	 CLASSIC "' Packages are offered In 14 sizes ranging from 

2.009.000 to 26.780.000 Btu/Hr 160 to 800 Bhoj fired by a 

Kewanee gas. oil. or comOination gas~1i burner. 

• Meets the requirements of ASME Code for 150 pSI Steam 

\tCrking Pressure. IHigher WOrking pressures available.) 

• Three Pass Design features a rear combustion C!l<lmber that's 

totally surrounded by water. This eliminates me need for 

refraCtory baffles. reduces COStly maintenance. eliminating 

refraCtory replacement Heat loss is mlnimlZeCI and 

over1leatlng of trle rear tube sheet is prevented. The wetback 

surface becomes additional primary heating surface. 

ImprOVlng bOiler performance. . 

• All heating surfaces are accessible WithOut disturbing burner 

equipment. redUCing inspeCtion and maintenance costs By 

uSing separate tube sheets the development of excessrve 

stresses caused by temperature differenoals between me 

passes are eliminated. All tubes are roller expanded and 

beaded. 2" bOiler tubes are used on 60-250 hp and 2/; 

tubes on 300-800 hp. 

( • FaCtory installed 22 gauge enameled steel Jacket INitn glass 

or mineral fiber Insulation. Extra density insulation IS used at 

seleCted locations for additional proteCtion at potential 

. pressure points. 

•	 Hinged steel front flue doors lined wim refractory Insulation 

contained by welded steel liner and guaranteed for a period 

of 10 years. Gasket gives gas-tight construC!Jon for 

pressurized firing 

RATINGS & DATA - 150 PSI STEAM 

-
 , , UNIT NUMBER I 50 , 70 80 i 100 125 

":;J,;-..., -- _I 50 70

2.3~3 ~1~~~'P~'''H'O~; '':':'2 ii~F ..................::: ',bs' ~m
 2.~ IS 

Steam Gross OuIDUt. ............... SlJ. 11 8.370
 9.765 

FIring Rate 

Gas 11.000 BTU/CU It) 

Oil (1~0.000 BTU) 

Oil (150000 BTU) 

, Healing Sur1ace - ASME 

! Safely Valve CapaCity 

; Insulaflon Thickness 

! Minimum Stack Diameter 

: Steam Space 

. Disengaging Area 

Waler Conient iful:) 

MBh 

gDh 

gph 

SQ. ft 

Ibs 

In. 

In. 

cu It. 

SQ It. 

galS 

[w nOtmal waterline) gals. 

Annrol weight fluill lOS 

Dry weight los. 

,upersedes Bulletin 20A-3 

January. 1988 

: 

112.511 12.930 

17.9 I 20.9 

16.7 19.5 

, 300 I 350 

I 2.~00 I 2.800 

1V,' IV,' 

12' 12' 1 

I 

i 80 , 100 ! 125 I 2.676 I 3.348 ! 4.184 

12760 I 3.450 , 4.3 13

111.160 ; 13.950 I 17.438 

i

I 3.3~6 : 4 185 i 5.23 I i 

239 I 299: 3741 4481 598 

96	 118 i 65 I 7.5\ 64 I 

17.6 I 20. I n 8 I 219.1 295 1 335 i 

! 378 ! 437 ~99 I 591 i36 I 675 

i 330 i 381 ! ~36 I 519 5~7 , 75: 

8.855	 I 9.8~~ I 1I .064 13.131 I 15.834 

5.700	 I 6.200 I 6.900 8.200 I 9,700 

'.	 . .:	 .. ~- .... ' ... ~.(,.-~-:~.

• Units tumlshed INim complete line of conuols consistmg of 

combination water column. pump control. low water cut~ff.

s.afety vatvels). steam pressure gauge. operating and limit 

pressure controls and 3" flue aas mermometer. ---.. 

•	 1".11 CLASSIC III Units are faCtory firetested. firing the unit Wlm 

the specified fuel. adjustlng fuel & air ratios plus Checking all 

controls and operating sequence. A detailed report of ttlis 

test IS de/rvered to the purchaser wlm each unit. 

•	 Guaranteed fuel to steam efficienCIes at 25 percent to 100 

percent of full rating. 

150 I I 200 Ii 250 300 coo 1 500 I 600 i 750 

_..' I 

150 200 I 250 300 600 I 800

5021 : 6.695 20.085 1 25.106 750 26,78C , 6.369 i 10.0~3 I 5 75 5.900 8.625 i 10.350 20,700 25.875 27.60& I 2C 925	 . 27.895 .: 34.875 , 41.8~5 83.690	 104610 I 111.600 

I I 

6.2i8 : 6.370	 

350

350 COO 500

11)16 13.390 16.738

12.075 13.800 17250 ~8.820 55.795 69,750

110.463 I	 12.55~ I1~.646 116,740 120.925 125.110 I 31.383 i 33.~75 . 

22 3 i 2791 349 I 41 91 5581 

I 400 500 I 625 750 .000 [' I 3.200 ~.OOO i 5.000 5000 e000 

lY,' 1v,' 11',' 2" 2' 1

I 12' 12' I 1~' '"," , 6': 

.5 

7471 89.7 104.61 1196 149.5 I 179.41 224.2: 2391 

69.8! 83.7 976 11161 139.51 1674: 209.2 2232: 

1,2S0 ; 1.500 1)50 I 2.000 I 2.500 I 3.000 I 3,75C I 3,750·.f 

10,000 112.000 'I 14.000! 15.000 20.000 '24.000 30.000 I 30.000 I 

2": 2' I	 2': 2' 2": 2" I 2' I 2"

20' i 20' 20' I 2~' 2~' i 27' 30' I 30' I 3~.81 4311 4991 69.71 77.11 8iOI :07t)~1 5371 601 69.51 7531 83.01 91.1 ~12TI 112.7 

1474 1 987 I 2302 

1:214	 i 1664 1929 

36,771 42,798 

20.200 23.600 

• Except 800 HP =".7 Sq. Ft/Bhp
 

DIMENSIONS. [Y\tA, SUBJECT TO CHf'J\lGE WITHOUT NOTICE
 

.	 2729 3.004 3526 , (394 • 4.394 I 

2:208 I 2.427 I' 2:375 I 3.589 i 3.589 I 

150.855 56.952 167.507 83.5C6 83.S-C5 I 

28,100 31.900 38.1 00 ~6.900 46.:0.,Q..!~

Bulletin 201 

Aprll.19L 

4.2.4-554 

Look ahead with KEWANEE. 
., HH M 

v x l, ­ B 

o o 'l. 

,- - U • . 

•. BB FF AA A•• 

A,­

60 H.P thru 250 H.P. 

HH -L--------.-v--· M . 

- .' x -,l,~

B - F'7'-' -0 -~ o 

c w 

H 

~- -_. BB .-. 

I ,P ,...cc.. 

..... .. •••• II••• 

N 

300 H.p. thru 800 H.P. ..._,,~HSIOHS (Ieel·inclles) /"' 

I UNIT NUMBER 60 I 70----r8011ii0 I 125 150 i - ZOO I' 250/1 300 ;--350- I .00 500 -600 -:- iso--:--jocl 

! A' ~O~r~l~n~h ••••••• _ ••••••••••-••-.-••-••-••-.-.~~1~~M~"~1~1~1~~+1~1~2~~~M~"~1~1~~~'~\',"~1 ~14~~~M~"~'1~1~~~r~I~1~7~1;~~"~I~~~~1;7~~~"~1~19~~~1'>~"~!~1~~S;~~"~i~2~;9;"~72~l';10;1'>~"~: 2S1M"i~~2~" j A' Oviralllenoll1 indudino luDe removal....... 14'4"
 

; B -O~ralIWldth............................... 5'5"
 

,c -O~raliheioht.............................. 6'0'
 

,0 ~Botiercen1erhnetoorutesIWldll'l.......... 3'l'h"
 I

B8 - Base width .....................-............
 

cc - BlSll heioht .................................
 

I EE - BlSll to rear 01 DOuer .. ;.................... 

'0 _ Base to Iront of Durner ..................... 

Tube removal space ........................ 

1'0" 

2'2'h" 

3'O'h" 

I 4'0" 

1'5" 

1'0" 1'3" 

7'10\':" 

5'5" 

4" 

3'2'1:" 

5'6" 

.'2'" 

I" 

3'6" 

2'r 

1'1'­

S'~"

I 4'6" 

4'2'" 

-

1'0" 

4'2'" 

3'4" 

6" 

1'9\':­

4'1" 

5'11" 

16'2W 18'1 V," I 17'8",. 21'4" 21'1\'>" I 27'01''', 28'2" 27'4'h" , 31'4" I 28'8","1 31'6' 33'01'>" I 40'S\'>" i 40'51'1" 

I 5'5" 'I 5'5" I 5'11\'>": S'll'h" i 6'5~" II 6'5V,"

6'0" 3~1'~:" II 36:~~ 'I 6'r II 7'3" ,'4" 

, 3'1~" n -., 3'41'>" 3'S" 3'8" 

, 1'0' I 1'0' 1'0" I 1'0' 1'0' I "0" 

2'2'h" 2'2'h" I 2'4\,>" 2'4'h" 2'r 2'9" 

3'O'h" 3'O'h" I 3'61'>" 3'6\'>" I 3'9'h" J'g,;" 

4'0" 4'0' 4'6" 

i I 

I 4'6" 5'0" , 5'0' 

I 1'5" I 1'5" I ,'S" 1'8" I 1'11" I 1'''" 

... I 1'0" 1'0' 1'2'" 1'2" 1'4" I 

"3" 1'3" 1'5" 1'5" 17" I '7­

S'lO' ~g\'," ~6" 11'4" 11'3'1:" I 14'3"

5'5" 5'5" I 6'2" I I I ,
 6'2" I 5'8" 6'8"

4'
 6" 

I I 3'2"'" 

5'6' 6'9" 

7'11" 

1" 11,1, I 3'6" 3'6" 3'8Y>" S'll \',"

1~" 2" 

6'3Y," 10'6'1:" 

.'6" 57" 

.'6" -

5'S'I:" 

1'0' 

- 1'3' 

5'0" 10'0' 

3'10' 

8" 

2'1\'>" 

47" 

3'4' 

"rl"/ S'2'

6'10" 12'1"

I 4" ~" 4' ~" I

ny," I 3'21'>" J'2v'" 3'2'1:" 3'2'1:" 5'6" 6'3" 6'J" 6'9" , 

I 4'9~" I S'3\'>" J'3" 4'9" 5'0'1:"

I 1'1/ , 'I? 11f,· ,%­ 3'6" J'6" 3'6" 3'5" I 

4'B" 4'3W 6'l'h" 6'0" 

1\'>" 1~" lY>" 1~~"

7'3" 6'10Y," 7'6~" n" 4'6" 5'2\'>" 5'21','

- 57" 

4'11\'>" - - -
 57"
 S'8\'>" 5'5\1," 

1'3" I 1'3" I 1'0' 1'3" 

5'10" 5'0" I 6'S" 6'B" I 3'6" 3'6" I 3'4" 3'10' 

6" 6" 6" 8" 

2'0'1:" 2'51'>" 27'1:" 2'6" 

47" 4'11" 4'1'" 5'2"

7'9Y>" 7'5" ~3" ~1'1:"

I TO' 8'on"ls'o'h" i ~Ol'>"' g'Ol'!" 9'6' I 9'6" i 9'6:
 

I 7'11" 9'2'h" ~2'h" I ~11~"1 ~11'h" 11'1~", 11'11'''1 11'l'h" .
 I 3'11" 4'5" 4'5" 4'11", 4'n" 5'2" I 5'2" I 5'2" ;
 

I 1-, 1'2" , ''2" I "4"' , ".. 1'4" I 1" . I~, I - I 2'r "10' I "10" I 2'10' 2'10" I 2'10" ! 2'4" 2'4" I 

I 4'01'>" I 4'61'>" 4'6'h" 5'O~" I 5'0';'" 5'S~" I 5'8n" 5'8Y>" ! , 5'6" I 6'6" 6'6" I 7'6" , 7'6' i S'O' ! S'O" I S'O" ,

, I 1 I 2'1" i 2'6" I 2'6" i 2'10" I 2'10' I 3'1" I 3'1' I 3'1" 

"8" l'S" I 1'8" 2'0' ! 2'0' : 2'3" I 2'6' 2'6" I

I 

1'11" I 1'11" 2'3" I 2'3" , 2'6" I

I 

2'g" 2'r 1'11" I I 

14'9\'," 16'9" lS'5'i." I 16'101'2. 1 17'10W I I 1~"1 217" 21'7" , I ! 8'2" . 8'2" 1 9'2\'>" 

! 6" 6" 8" 8" 

, 3"2".7" ~'61'>" 4'61'>" 4'6\'>" 

n" S'3'1:" 3'4' ~4"

8'6" S'2\'>" n" 7'2"

1y,' I In" 2' 2\'>" 

3'8" 4'1' , ~'8' I 4'" I 8'111'>" 9'0' 10'6\'>" I 8'9"

2"' I 2" 2" I 2" 

1~11M'1 11'2" ; 13'1 I':" t 12'0' 

5'10' 

- 5'11 'I:"
 

1'3"
 

10'0"
 

4'2'"
 

8"
 2"81':" 

5'2" 

t2"5\'>" 

6'9" I 5'9' ! 7'5V," 

- I - I ­ S'6'1:" 9'4~" I S'S~"

1'3" 1'3" 1'3' , 

147" I 16'3" I 15'11" ! 17'3" I 17'6" I 21'2" ! 21'2" ! 

t

, 1 i----w­ nO" ~'lO' 5'4' 5'4- I 5'9' 5'9' 

10" , o· 10' 10" I s· I 8" ! 10' I i ! I 2'4" 2',~' I 2'9" 7S· I 3'~'I:" 2'91);' I 2'9\'>" I I - - - I - I I ­ I 11'8~" ! '3:a~"1 12'2'1."1r 

13']" 14'0' I 177" ! In" , I I I -

i 9'2' 

8' 

4'6\'>" 

9'4' 

9'9'1:" 

2'1:" 

I 4'8' 

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R ill' DOx to Sl'I II ...........................
 Burner to front of boiler, ...................
 

Boiler centertine heiOhl .....................
 

Shel diameter, .....................,.......
 

Furnace diameter ...........................
 

e ue e 

Flue ouUet diameter ........................
 

Flue ou1letllanoe diameler .................
 

flue outlet centerline .......................
 

flue outlet heioht ...........................
 

Sllpply size 300 lb. ANSlflanoe .............
 

Sllppty centerline ...........................
 

SllplJlY neioht ...............................
 

f~edwater centertine - ~acn SIde ..........
 

feedwaler size - NP'T .....................
 

Reill' blawofl - centerline to reill' ot DOiler ••
 

8Iawotl centertine to cenlertine .............
 

Blawofl size - both - NPT ................
 

Safety val~ centerune ......................
 

Normal W:llertine ...........................
 

Handhole centerkne ........................
 

ManhOle centerline .........................
 

Base heiOht - 1I00r to DOIler ...............
 

Base Ienoth .................................
 

4,2.4-555 

KEWANEE BOILER COMPANY, INC. 

A subsidiary of Coppus Engineering Corporation 

101 Franklin Street. Kewanee. Illinois 61443 

13091853-3541" Fax: (3091 852-0424 © 1989 K~Wilne-e Boi '~r Cn In( 
, 

1 

. -", .i 

For CL/\SSfC [i f Packagc'd Scotch Deslg'l Fi rct:;(:;e
 

Oil. Gas, Cornbin~ltjon Oii/Gas Firec
 

. III usre-c 

wa~ 5",Jf"~': 2:f o:-"C-":"(! for Oil. r.arura; C2S 0' ;:;:o;:.c:re 

...;as. or com::)II-.3i.:':J:". ,~,:.-v~. (,r,nc EaC1l Kev.'<l~ Fore",: 0,2:'1 

Burner 15 custom c;'tj;~<-<:,<."'d fotthe paCK-age It fIres. 2SSw,,('\.:; 

long. depend.3:J:e a":;': e-cc:-.)m;c.31 service. 

•	 Nflv'~"'. lA Contro: C2:J,,"": f-:<J[:.IreS elearonrc F:a.~ S,afc-c..,arG 

'and programmn:; CO'1:(O::'. 'elr flow safety SlNltCTl. COjec­


v.~rlng. num:::>ere--:::: ,-:,[';'),:".,3: "TIp and console
 

6C-2SC HP 3:):)- 800 HP 

•	 CLfo.'sSIC II: U,'1lts a:e e-q~I~;:r.<:,·.r;?: /:t'·...;a~ P;e-sure or!-Y' 

A(Qm:ZIr>g 6ur~r" Pressure ."-.tOm,z<:Ig units fire light oil. ar'ld 

co:n;:l::-,awo",: oas-l'o:'; oj' hi r.;::>m,ZI;-":; unl~ fire NO.6 (l00 rip 

t,J 8C1J ru/ or-IIOh;er oil. a:-.j como,:'.aUClO oas-oi!. Botl1 

pressurf '<J()(J' a,~ atomlze<i un,rs <Jre of f.a~ retention des'gr. 

•	 5.e<ond oil solenoid "'<l!V'e flJfT1IS~ 25 star>Varc on 

6Q H:=-800 HP 60iier> 

f :::>e 4K 

f\.lTIHGS & OAT" 

! 7' I a I •

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!~~~~...................... i _ "1,-~I -!' 13000_ ,I 3000_	 !, 3:XX:_ i Q;)j lsooc j6QOC II &"JOC I, CV''« l1?OQC' I' 1SOOO 11 SOOC ZOOX'!2 tJOC 13XlOO '»»;1
 , lOG 6 0<: I I?O(Y.. 3:xlC 3-."'()(): ....0')() :ff.iV! eooo SOOO 100..-':; 1?DOO 15000 1seal I 

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surE P.)~DES BUu.£TlN 2CA~
 

RU~l£TI~ 20A·/, A;Jrli. /929
 

;.orli;~') 1982
 

4.2.4-556 Look ahead ~~'ith !(EE,il4lrJp,-:E. I<£"...--:.A~~F£ 'J'::>:LER COMPANY. :IJC. 

A '.~ J~·\!·1:~V·\· o~ .~:(,/, J./) n'JI; ;t,.a;."r.I I,J (\.., .-..:',; .=<:Iorl 

ii 
DEPARTMENT OF HEAL7H
 

DI\J1SION OF E\vlRON~1E;\7AL HEALTH
 

288 NO"~ 1 .60 west 

00 Sox t 6690 ~. \ .', Jl~ I. t' , II r.'1 ,••r 

Sail LaKe Cd" lJ~an 84116·0690 

cOl) 5::8·6108 

3AQE-6BB-88 

November 9. 1988 

Newspaper Agency 

Salt Lake Tribune 

Legal Advertising Department 

157 Regent Street 

Salt Lake City, Utah 84111 

Gentlemen: 

This letter will confirm the authorization to publish the attached NOTICE in the 

Salt Lake Tribune and Deseret News on November 18, ~988.

Please mail the invoice and affidavit of publication to t.he Utah State Deparment 

of Heal th , Division of Environmental Health, Bureau of Air Quality, P.O. 

Box 16690, Salt Lake City, Utah B4116-0690. 

S~~)f~ David Kopta. Manager Engineering Unit 

Bureau of Air Quality 

Enclosure 

DK/cc 

4.2.4-557
 
/ ~.

NOTICE
 

The following notices of intent to construct, submitted in accordance with 

Section 3.1, Utah Air Conservation Regulations. have been received for 

consideration by the Executive Secretary. Utah Air Conservation Committee: 

1.	 Indian Oil Company. Used Oil Recycling Plant, Utah County 

2.	 FCI Chemical Engineers. Gypsum Excavat~on and Handling. Salt Lake 

County 

3.	 Amoco Oil Company. 3ackup ?lare System on Loading Racks. SAlt Lake 

County 

4.	 Department of the Air Force. Carbon Brake Repair Facility, Bldg. 267, 

Davis County 

5.	 Brackenbury, Conn and Associates, Portable Tank Leaching Operation, 

Duchesne County 

6.	 Advance Foam Plastics, Expanded Polystyrene Plant. Salt Lake County 

7.	 Golden Eagle Environmental and Recycling Services, API Separator and 

14 Storage Tanks, Davis County 

8.	 Morton Thiokol, Inc., Changes to X-17 Automotive Products Facility, 

Weber County 

The engineering evaluations and air quality impact analyses have been completed 

and no adverse air quality impacts are expected. No Prevention of Significant 

Deterioration (PSD) increment will be consumed by these proposals. It is the 

intent to the Executive Secretary to approve the construction projects. 

The construction proposals and estimates of the effect on local air quality are 

available for public inspection and comment at the Bureau of Air Quality, Utah 

State Department of Health, 288 North 1460 West, Salt Lake City, Utah 84116­

0690. Written comments received by the Bureau, 288 North 1460 West, P.O. Box 

16690, Salt Lake City, Utah 84116-0690, on or before December 16, 1988 will be 

considered in making the final decision on the approval or disapproval of the 

proposed construction. 

If anyone so requests within 15 days of publication of notice, a hearing will 

be held in the area of the proposed construction, installation. modification. 

relocation, or establishment. 

Date of Notice: November 18, 1988 

4.2.4-558