Emission Reduction Credit Certifdate s-0002-2Proiect 2007 92071 6 The District has issued an Emission Reduction Credit (ERC) certificates for project #2007 920716 to Texaco Refining

I - San Joaquin Valley Unified Air Pollution Control District Southern Regional Office 2700 M St., Suite 275 Bakersfield, CA 93301

Quarter 1 1425 lbs.

Emission Reduction Credit Certifdate s-0002-2 /

/"

Qua& r 2 Quarter 3 Quarter 4 d 8 9 lbs. 1612 lbs. 1776 lbs.

Issued To: TEXACO REFINING A I 6 MARKETING INC. December 17, 1992

Location of Reduction:

For NO,

,/ Dikxtor of Permit Service

&>

3 tL43-3 I l 3 l . Z .

Emission Reduction Credit Cktificate / / P - Q ~ d / v l Y d b Y S-0002-3 / S - \ 2 ' 1 2 - 3 h R 7-

F&a+ / Issued To: TEXACO REFINING AND MARKETING INC.

December 17, 1992 / L0t1.? 5 ,/'

Lochtion of Reduction: NE Section'27, Township 29 South, Range 27 East 6451 Rosddale Highway, Area 1 of Texaco Refinery

/

/" For CO Reduction In The Amount Of:

Quarter 1 Quarter 2 Quarter 3 Quarter 4

/

4570 lbs. //5416 lbs. 5166 lbs. 5695 lbs. L

I/' i

[ ] Conditions Attached

Method Of Reduction [ ] Shutdown of Entire Stationary Source [XI Shutdownhf Emissions Unit [ ] Other:

/ /

Seyed adredin Director of Permit Services

@m- On Paper

San Joaquin Valley

Southern Regional Oftice * 2700 M St., Suite 275 Bakersfield, CA 73301

,/'

- 33- waL1

San Joaquin Valley Unified L4ir Pollution Control District /" Southern Regional Office * 2700 M St., Suite 275 Bakersfield, CA 93301

Emission Reduction Credit . S-0002-4

/' /

Issued To: TEXACO REFINING AND MARKETING INC. December 17, 1992

29 South, Range 27 East 1 of Texaco Refinery

Location of Reduction:

For PM,,

Quarter 1 Quarter 3 Quarter 4 1584 Ibs. d 7 7 Ibs. 1791 Ibs. 1974 Ibs.

5-Ibs0-q [ ] Conditions A

Director of Permit Services

i

/‘ San Joaquin Valley Unified ,4ir Pollution Control District Southern Regional Omce 2700 M St., Suite 275 Bakersfield, CA 9330 J

Quarter 1 Qua& 2

55479 lbs. 6$55 lbs.

Emission Reduction Credit Ce ,d ificate S-0002-5 I/‘

/’

Quarter 3 Quarter 4 62724 lbs. 69141 Ibs.

Issued To: TEXACO REFINING’N MARKETING INC. December 17,

Location of Reduction: 29 South, Range 27 East 1 of Texaco Refiner!

/ David J! Crow. APCO

. .

San Joaquin Valley ,

Unified Air Pollution Control District Southern Regional Omce 2700 M St., Suite 275 Bakersfield, CA 93301

Quarter 1 Quarter 2 Quarter 3 55479 lbs. 65755 lbs. 62724 lbs.

Emission Reduction Credit Certificate S-0002-5

Quarter 4 69141 lbs.


Location of Reduction: NE Section 27, Township 29 South, Range 27 East 6451 Rosedale Highway, Area 1 of Texaco Refinery

For SO, Reduction In The Amount Of:


Method Of Reduction [ ] Shutdown of Entire Stationary Source Ixl Shutdown of Emissions Unit [ ] Other:

David L. Crow, APCO

Seyed Sadredin Director of Permit Services

GES EMISSION REDUCTION CREDIT CERTIFICATE FINAL BILLING 12/17/92

TEXACO REFINING AND MARKETING INC. MR. DONALD SLACK P.O. BOX 1476 BAKERSFIELD, CA 93302

DECEMBER 17, 1992

APPLICATION HOURS RATE TOTAL FEE FEE NUMBER BILLED ($/HR) FEE PA1 D DUE ___________________________ -______ ___---_ --____-- -------- --------

2007027/101/201/304/401/601 15.5 33.40 517.77 650.00 0.00

TOTAL FEES DUE 0.00 CREDIT 0.00 TOTAL AMOUNT DUE 0.00

APPLICATION METHOD OF GENERATING REDUCTION QTR/SEC/TWN/RGE

2007027/101 REMOVAL OF INCINERATOR ID#16M101 NE/27/29S/27E /201/304/401/601

------__-__ ____________________________________ ..........................

APPROVED PROJECT EMISSIONS CHANGE AND NEW SOURCE REVIEW B.ALANCE

PROJECT ENGINEER: G&J&S

PROJECT #: q$07/b

NSPS PROJECT: - YES L N O

DATE: fa/'?/(?w 7

COMPANY NAME: cxA& / YWhflMA ~ 4 7 hhd,flG .L&.

,?i%7w7//0l/~Oi/%l/ oj -,,/e/ PROJECT DESCRIPTION: e& C v J&kd f szL49 iN&,uwArL

@C ,/tre NUMBERS:

LOCATION: Sec. ,U+ ? 7 T 273 R 27f APPROVAL DATE: / /

PROJECT'S EMISSIONS CHANGE (See ana lys is f o r d e t a i l s . ) :

- P o l l u t a n t : PM so, SO! NO: voc co

Change (+/-I*: & & /uA -L?& & 1 bm/day (OFFSET) (OFFSET)

NEW SOURCE REVIEW BALANCE: (Whole s t a t i o n a r y source s ince 9 / 78/79 . ):- P o l l u t a n t : PM SO, SO: NO: VOC CO

RECORD OF EMISSIONS REDUCTION BANKING:

Banking c e r t i f i c a t e issued f o r reducLion r e s u l t i n g from t h i s p ro jec t : -Yes - No

C e r t i f i c a t e ( s 1 issuance date: /%/ I7 / 9 2 - C e r t i f i c a t e ( s ) nurnSer(s): jeh2%

s 4 o o a 3 <-oo.a-q s-um a -5

RECORD OF USE OF BANKED EMISSIONS REDUCTION FOR THIS PROJECT:

C e r t i f i c a t e ( s 1 used as t radeo f f ( s ) :

* If ana lys i s inc ludes emission p r o f i l e s , i n d i c a t e maximum increase ( o r minimum reduc t ion) and a t t a c h copy o f p r o f i l e s .

PROOF OF PUBLICATION

State of California - s s County of Kern

I am a citizen of the United States and a resident of the County aforesaid: I am over the age of 18 years, and not a party to or interested in the above entitled matter. I am the assistant principal clerk of the printer of The Bakersfield Californian, a newspaper of general circulation, printed and published daily in the City of Bakersfield, county of Kern, and which newspaper has been adjudged a newspaper of general circulation by the Superior Court of the County of Kern, State of California, under date of February 5, 1952, Case Number 57610; that the notice, of which the annexed is a printed copy, has been published in each regular and entire issue of said newspaper and not in any supplement thereof on the following dates, to wit:

-

12/27

all in the year 1992

I certify (or declare) under penalty of perjury that the foregoing is true and correct.

3 gigna t ur e

Dated at Bakersfield, Ca DEC. 2 8 , 1992

ROSLYN T WILLIAMS

Proof of Publication of:

NOTICE OF FINAL ACTION

DEC 3 0 1992


! (Fl1)PROOF o f Story 'U83' Requested by 10JFlNELL (6F603) on 12/23/92 9:10:33

C\d U #83 ad type C Basket BFlD CREDIT Desk CREDIT Entered By 10JFlNELL On 12/23/92 at 9:lO For 10JFlNELL account 1KCCllS Class 520 Dis Sales 1 0 Ins Sales 10 Naoe E Y c1.P.C.D. SClN JM\QUIN VFlLL Phone (805) 8613682 Flddr 2700 M ST STE 275 GB/PO FINFlL FlCTION C i t y BMERSFIELD State IX Zip 933012370 Fld Start L2/27/92 Times 1 Stop 12/27/92 Rate L.1 38 Billing lines 2.66 Inches rotdl $34.20 Fldcost 34.20

Reaarks :

1 2 3 4 5 h 7 8 9

1 0 1 3 12: 13 14 15 l h 17 18 19 2Q 21 22 23 24 25 26 27 28 29 30 3 1 32 33

NOTICE OF F I N N GCTION ON PROPOSED STGT 1 O M R Y SOURCE EMISSION REDUCTION CREDIT (ERC)

Pursuant to Rule 230.1 of the San Joaquin Valley Unified Clir Pollu- tion Control District Rules and Regulations, the Rir Pollution Control Officer has made a find?, .-decision-tci issue Enission Reduc- I '

tion Credit Certificates #S-C#Q2-2, 9-3, '-4. and ' - 5 to Texaco Refining and Marketing, Inc for NOn, CO, P W I C ) , and Sow eoission reductions resulting front he reoaval of a tailgas incinerator serving the sulfur recovery operation tailgas treating unit at the Texaco Refinery s l o Rosedale Hwy. in Bakersf i eld.

The District's finalized analysis, pub1 i c conoent s and cert i f i rate are available for inspection at the District's Southern Region Office contact Glen Stephens of the Per- nit Services Division located at 2700~ * ' M * ' Street, Suite 275, Ba- kersfield, California 93301, (805) 86 1-3682. Deceober 27, 1992 (83)

- . . ..


- State of California ss County of Kern

I am a citizen of the United States and a resident of the County aforesaid: I am over the age of 18 years, and not a party to OK interested in the above entitled matter. I am the assistant principal clerk of the printer of The Bakersfield Californian, a newspaper of general circulation, printed and published daily in the City of Bakersfield, county of Kern, and which newspaper has been adjudged a newspaper of general circulation by the Superior Court of the County of Kern, State of California, under date of February 5, 1952, Case Number 57610; that the notice, of which the annexed is a printed copy, has been published in each regular and entire issue of said newspaper and not in any supplement thereof on the following dates, to wit:

-

10/26

all in the year 1992

I certify (or declare) under penalty of perjury that the foregoing is true and COKK-

Dated at Bakersfield, Ca OCT. 26, 1992

ROSLYN WILLIAMS I

Proof of Publication of:

4745

REQUEST FOR PUBLIC COMMENT r . /


'I, . ., ":'. '

,$C?CIG OF Story '#4745' Requested b y l0JFlNELL (SF603) on 10/23/92 8:36: 16

Fld & U4745 Fld type C Basket BFlD CREDIT Desk CREDIT Entered By l0JRNELL On l0/23/92 at 0:36 For LQJCINELL Flccount lKCFll5 Class 397 Dis Sales 10 Ins Sales 10 . Naoe E Y R.P.C.D. SFIN JOFlQUIN VFlLL Phone (805) 8613682 Flddr 2700 M ST STE 275 GB/PO PUB COMMENT * City BFlKERSFIELD State CR Zip 933012370 Fld Start 10/26/92 Tiaes I Stop 10/26/92 Rate Ll 49 Billing lines 3.49 Inches Total $44. 10 Fldcost 44. 10

Reearks: Rtten Tom G a f f

LN# OUTPUT TEXT ________________________________________---------------------------------------- ____________________--------------------------------

1 2 3 4 5 h 7 8 9

10 1 1 12 13 14

I 6 17 18 19 20 2 1 22 23 24 25 26 27 20 29 30 31 32 33 34 35 36 37 30 39 4 0 41 42 43

is . .

REQUEST FOR WBLIC COMMENT ON PROPOSED STRTIONFIRY SOURCE EMISSION REDUCTION CREDITS (ERC)

Pursuant to Rule 230. 1 of the San Joaquin Valley Unified Flir Pollu- tion Control District Rules and Regulations, the Flir Pollution Control Officer has nade a pre- lininary decision to approve epi.ssjons _red'yction credits to no

801 Ibsfqtr of W10, 5,695 lbsfqtr of CO, 69,141 lblqtr of SOX and 975 of 504 resulting fron the renoval of tailgas incinerator serving the sulfur recovery operation tailgas treating unit at the Teraco Refin- ery s/o Rosedale Hwy. in Rakers- field.

Pub1 ic coonents regarding the erpected air quality impact of this project will be received by the District for a period of thirty (30) days after publication of this notice and will receive due consideration before final action is taken.

~ --. .gbeate$ th.&& 1,776 ]'b<?qtr'-of' Nm,~:''-: ,I ~ ~ ..

R @ Q 2 V @ D The application for enissions reduct ions credits, support docu- nents and the District's air

ject #4091 9.20620 are available for

office with Glen St.ephens, located at 27CU) M Styeet, Suite 275, Ra- kersfield, California 93301, (805) 06 1 -360% October 26, 1992 (4745)

quality inpact analysis for pro- OCJ 3 7992 S4' 'oAQUIN VALLEy up,lFlEo

A P C D - ~ ~ u ~ ~ ~ ~ N REGlON inspection at the Southern Region

San Joaquin Valley Unified Air Pollution Control District

December 22, 1992

Donald J. Slack Supervisor Environmental, Safety & Health Texaco Refining and Marketing, Inc. P.O. Box 1476 Bakersfield, California 93302

Dear Mr. Bergstrom:

SUBJECT: Emission Reduction Credit Certificates and Final Public Notice - Proiect 2007 9207 16

Please find enclosed Emissions Reduction Credit certificates Nos. S-0002-2. S- 0002-3, S-0002-4 and S-0002-5, and a copy of the final public notice for the above project for emission reductions of N02, CO, PM,, and SO2 from the removal of a tailgas incinerator serving the sulfur recovery operation tailgas treating unit at the Texaco Refinery slo Rosedale Hwy. in Bakersfield.

Thank you for your cooperation in this matter. Should you have any questions please telephone Mr. Glen Stephens of the Permit Services Division at (805) 861- 3682.

Sincerely,


ss:gs Enclosures c: Tom Goff - Permit Services ManagerKouthern Region


December 22, 1992

Mr. Raymond Menebroker, Chief California Air Resource Board Project Review Branch Stationary Source Division P.O. Box 281 5 Sacramento, CA 9581 2

Dear Mr. Menebroker:

SUBJECT: Final Public Notice - Emission Reduction Credits Proiect 2007 92071 6

The District has issued an Emission Reduction Credit (ERC) certificates for project #2007 920716 to Texaco Refining and Marketing, Inc. for reduction of PM10, S02, NO2 and CO from the removal of a tailgas incinerator serving the sulfur recovery operation tailgas treating unit a t the Texaco Refinery s/o Rosedale Hwy. in Bakersfield. The District has received no public comment on this project. Enclosed is a copy of the .banking certificate documents and the final public notice.

Thank you for your cooperation in this matter. Should you have any questions please telephone Mr. Glen Stephens of the Permit Services Division a t (805) 861-3682.


ss:gs Enclosures c: Thomas Goff - Permit Services Manager/Southern Region


December 22, 1992

Mr. Matt Haber, Chief U.S. E.P.A. - Region IX New Source Section 75 Hawthorne St. San Francisco, CA 94105

Dear Mr. Haber:

SUBJECT: Final Public Notice - Emission Reduction Credits Proiect 2007 92071 6

The District has issued an Emission Reduction Credit (ERC) certificates for project #2007 920716 to Texaco Refining and Marketing, Inc. for reduction of PM10, S02, NO2 and CO from the removal of a tailgas incinerator serving the sulfur recovery operation tailgas treating unit a t the Texaco Refinery slo Rosedale Hwy. in Bakersfield. The District has received no public comment on this project. Enclosed is a copy of the banking certificate documents and the final public notice.

Thank you for your cooperation in this matter. Should you have any questions please telephone Mr. Glen Stephens of the Permit Services Division at (805) 861-3682.

Sincerely,'

Seied %adredin Director of Permit Services

ss:gs Enclosures c: Tom Goff - Permit Services Manager/ Southern Region

I .

;, .

NOTICE OF FINAL ACTION ON PROPOSED STATIONARY SOURCE EMISSION REDUCTION CREDIT (ERC)

Pursuant to Rule 230.1 of the San Joaquin Valley Unified Air Pollution Control District's Rules and Regulations, the Air Pollution Control Officer has made a final decision to issue Emission Reduction Credit Certificates #S-0002-2, '-3, '-4, and '- 5 to Texaco Refining and Marketing, Inc for NO,, CO, PM,,, and SO, emission reductions resulting from the removal of a tailgas incinerator serving the sulfur recovery operation tailgas treating unit at the Texaco Refinery s/o Rosedale Hwy. in Bakersfield.

The District's finalized analysis, public comments and certificate are available for inspection at the District's Southern Region office contact Glen Stephens of the Permit Services Division located at 2700 "M" Street, Suite 275, Bakersfield, California 93301, (805) 861-3682.

San Joaquin Valley Unified APCD Permit Services Division

TO: Seyed Sadredin Distrtct Manager o f Permit Services

&EA/ SSEPHEMS ' j .Pj FROM:

3 & & A Pes / O d I

DATE: lo/&/ra

RE: [ ] Intent to Deny ATClPTO I ] Deny ATC/PTO [c Preliminary Public Notice (NSRI 1 J Final Public Notice (NSR) 1 1 Other , .

RemarkslRecomrnendations: Otr/i&, f D / S f i , b & ,

R E S P O N S E

TO:

FROM: Seyed Sadredin Distrlct Manager of Permit Services

DATE:

!

. . . . . . . . . . . . . . ':: . . .

."-

. . . . . . . . . . . . . . . . . . . . . . . . . .

.... .... . . . . . . . .

FAX Transmittal Sheet San Joaquin Valley 2700 "M" Street, Suite 275

Unified Air Pollution Control District Bakersfield, CA 93301 + Voice: (805) 861-3682 Southern Region FAX: (805) 861-2060

From: Glen E. Stephens Date: 10/ / 9 2

To: T a n e l j r e n Name Company

Total Pages (including cover page): 2 FAX No.: 395-7540

Comments: Date of publication: (2-3 davs) Run one time onlv.

Please send proof and published notice to: Glen Stephens

Permit Services

.,

REQUEST FOR PUBLIC COMMENT ON PROPOSED STATIONARY SOURCE EMISSIONS REDUCTION CREDITS (ERC)

Pursuant t o Rule 230.1 o f the San Joaquin Val ley Un i f i ed A i r Po l l u t i on Control D i s t r i c t Rules and Regulations, the A i r P o l l u t i o n Control O f f i c e r has made a prel iminary decis ion t o approve emission reduction c r e d i t s no greater than 1,776 lbs /qt r o f N O , 801 l bs /q t r o f PM,,,, 5 , 6 9 5 l bs /q t r o f CO, 69,141 l b / q t r o f SOx and 975 o f Sd4 r e s u l t i n g from the removal o f a t a i l g a s inc inerator serving the s u l f u r recovery operation t a i l g a s t r e a t i n g u n i t a t the Texaco Refinery s/o Rosedale Hwy. i n Bakersf ield.

Public comments regarding t h i s prel iminary decis ion w i l l be received by the D i s t r i c t f o r a per iod o f t h i r t y (30) days a f t e r pub l i ca t i on o f t h i s no t i ce and w i l l receive due consideration before f i n a l ac t i on i s taken.

The appl icat ion f o r emission reduction c red i t s , support documents and the D i s t r i c t ' s a i r q u a l i t y impact analysis f o r p r o j e c t 4091 920620 are ava i l ab le f o r inspection a t the Southern Region o f f i c e wi th Glen Stephens located a t 2700 "M" Street, Sui te 275, Bakersf ield, C a l i f o r n i a 93301, (805) 861-3682.

GES


DISTRICT BOARD HEMBERS

Rick Jensen Chair Supervisor Madera County Pauline Laxwood Vice Chair Supervisor Kern county

Blair Bradley councilmember city of ceres Doug Vagim Supervisor Fresno County

Tom Bohigian councilmember city of Fresno soe Hsmmond Supervisor Kings county

supervisor nerced County

Supervisor San Joaquin County

supervisor Stanislaus County

Clyde could supervisor Tulare County ne1 McLaughlin councilmember city of wasco

Mike Bogna

Bill sousa

Nick B l O m

Mr. Mat Haher, Chief U.S. EPA - Region IX New Source Section

75 Hawthorne Street San Francisco, CA 94105

A-5-1

Re: Application #2007027/101/201/304/401/601 Project Description: Emission Reduction Credit (ERC)

Certificate for Emission Reduction from the Removal of Incinerator ID# 16M101

Dear Mr. Haber:

Enclosed for your review and comment is the analysis of Texaco Refining and Marketing Inc. request for emission reduction credits.

This project will he released to public notice approximately three days from the date of this letter. This will start the 30-day public period comment period.

Please submit your written comments on o u r analysis and draft documents as soon as possible to provide ample time for our review and consideration.

Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of the Engineering Evaluation Section at (805) 861-3682.

0

Sincerely,


GES

.I


DISTRICT BOARD UEUBERS

Rick Jensen Chair Supervisor Madera county Pauline Larwood Vice Chair Supervisor Kern County Blair Bradley Councilmember city of Ceres Supervisor Fresno County

Tom Bohigian Councilmember city of FreSnO Joe nsmmond Supervisor Kings County

Supervisor Nerced County


Supervisor Stanislaus County Clyde Gould supervisor Tulare County ne1 UcLaughlin CouncIlmembet city of w a x 0

Doug Vagim

nike Bogna

Bill sousa

Nick Blom

Mr. Donald J . Slack Supervisor - Environment Health and Safety Texaco Refining and Marketing, Inc. P.O. Box 1476 Bakersfield, California 93302



Dear Mr. Slack:

Enclosed for your review and comment is the draft notice and engineering analysis of preliminary decision to approve Emission Reduction Credits for the shutdown of incinerator ID# 16M101 located in Area 1 of the Texaco Refinery.

This preliminary decision will be noticed in the newspaper '

approximately three days from the date of this letter. Publication will start a 30-day public comment period,

Please submit any written comments you may have concerning this preliminary decision before the close of the public comment period.

Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of the Engineering Evaluation Section at (805) 861-3682.

Sincerely,


GES

Soahern Regional office 2700 M St, Suite 275 Bakersfield CA 93301


DISTRICT BOARD MEMBERS

Rick Jensen C h a i r Supervisor Hadera county Pauline Lawood Vice Chair Supervisor Kern County

Blair Bradley Councilmember city of ceres

Doug Vagim Supervisor Fresno county

Tom Bohigian councilmember City of Fresno

Joe Hammond Supervisor Kings County

Supervisor Xerced County


Supervisor stanislaus County

Clyde Gould Supervisor Tulare County

He1 McLaughlin Councilmember city of Wasco

Uike Bogna

Bill Sousa

Nick Blom

Mr. Raymond Menenbroker, Chief California Air Resources Board Project Review Branch Stationary Source Division P.O. Box 2815 Sacramento, CA 95812



Dear Mr. Menenbroker:

Enclosed for your review and comment is the analysis of Texaco Refining and Marketing Inc. request for emission reduction credits.

This project will be released to public notice approximately three days from the date of this letter. This will start the 30-day public period comment period.

Please submit your written comments on our analysis and draft documents as soon as possible to provide ample time for o u r review and consideration.

Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of the Engineering Evaluation Section at ( 8 0 5 ) 861-3682.

Sincerely,


G E S

southern Regional office 2700 M St, Suite 275 Bakersfield. CA Wl.

TO:

FROM:

DATE:

RE:

,

San Joaquin Valley Unified APCD Permit Services Division

Seyed Sadredin District Manager of Permit Services

d G m / szP,%fl SbM~er/r pes I O d

I

f o / w Y a

[ 1 intent to Deny ATClPTO I I Deny ATClPTO [fl Preliminary Public Notice (NSR) [ 1 Final Public Notice (NSR) [ I Other

R E S P O N S E

TO:

FROM: Seyed Sadredin District Manager of Permit Services

DATE:

" .

Y i Jan - Mar 642.83 782.58 55479.23 1425.41 4569.70

Apr - Jun 761.90 '-1 65754.88 1 1689.42 5416.08 1 ! Jul - Sep 726.77 1 884.77 62723.64 11 1611.54 5166.41 1

I 'I

Oct - Dec 801.13 1 975.29 69141.04 I 1776.42 5694.99 :

I

I

2007027/101/201/301/401/601 Page/

ERC APPLICATION REVIEW

... - . ....

2007027/101/201/301/401/601 Page 2

11. APPLICABLE RULES:

A. Rule 220.1: (New and M o d i f i e d S t a t i o n a r y Source Review Rule -- p o s t 09/19/91, r e v i s e d 03/11/92)

B. Rule 230.1: (Emission Reduction C r e d i t Banking -- adopted 09/19/91, r e v i s e d 03/11/92)

C. Rule 230.2: (Community Bank -- adopted 09/19/91, rev i sed 03/11/92)

111. PROJECT LOCATION:

NW Sec t ion 27 , Township 29 South, Range 27 East MDB&M 6451 Rosedale Highway., Area 1 o f Texaco R e f i n e r y

I V . METHOD OF GENERATING REDUCTIONS:

T a i l g a s p r e v i o u s l y burned i n i n c i n e r a t o r has been permanently d i v e r t e d t o new u n i t (ATC 2007245 -- t a i l gas t r e a t i n g u n i t ) . No emission reduc t i ons f o r t h e removal o f t h e o l d t a i l g a s i n c i n e r a t o r were used f o r t h e approval o f t h e new u n i t .

V. EQUIPMENT LISTING:

1 - T a i l g a s i n c i n e r a t o r , 16-M101 -- removed f rom s e r v i c e

See Attachment A f o r c o p i e s o f PTO t o be r e v i s e d and ATC?s t o mod i fy PTO #2007027A and f o r t h e new t a i l g a s t r e a t i n g u n i t (ATC #2007245). ATC?s have been implemented and new p e r m i t s a r e be ing prepared.

These

V I . CONTROL EQUIPMENT EVALUATION:

The emission r e d u c t i o n s were generated by equipment b e i n g taken o u t o f se rv i ce , and n o t by t h e a d d i t i o n o f c o n t r o l equipment. Therefore, no c o n t r o l equipment e v a l u a t i o n i s requ i red .

V I I . CALCULATIONS:

A. General :

C a l c u l a t i o n s w i l l summarize t h e H i s t o r i c a l Ac tua l Emissions (HAE). H i s t o r i c a l Ac tua l Emissions f o r each q u a r t e r i n t h e b a s e l i n e p e r i o d a r e c a l c u l a t e d us ing f u e l usage d a t a ( t o t a l o f f g a s t o c l a u s fu rnace) and source t e s t emission f a c t o r s f o r each a i r contaminant. Source t e s t da ta i s summarized i n Attachment 6.

2007027/101/201/301/401/601 Page 3

B. Fuel Consumption Data:

The d a t a below i s de r i ved from a p p l i c a n t s u p p l i e d data. The a p p l i c a n t supp l i ed da ta i s t h e average h o u r l y vo lumet r i c o f f g a s gas f l o w t o t h e i n c i n e r a t o r f o r d e s t r u c t i o n ( see Attachment 8). The q u a r t e r l y f u e l use were ob ta ined by by t h e f o l l o w i n g c a l c u l a t ions:

Mscf/hr . 24 hr/day . 30 days/monthl = Mscf/month Mscf/month . 90 d a y d q u a r t e r ' = Msc f /qua r te r

The f o l l o w i n g represents t h e r e s u l t s o f t h e c a l c u l a t i o n s :

Averaqe Q u a r t e r l y Fuel Use ( i n Mscf/Quarter) Jan-Mar Apr-Jun Jul-Sept Oct-Oec

I 0.0136 0.0166 I

1 52451.40 1 62166.24 1 59300.44 1 65367.60 j(

u 1.1753 0.0302 NA 0.0968 i!

Adjustments were made t o a p l i c a n t s u p p l i e d d a t a (March '90 da ta was n o t used) because montR i d e n t i f i e d d i d n o t c o i n c i d e w i t h 8 consecut ive ca lendar q u a r t e r s p reced ing t h e a p p l i c a t i o n f o r ERC banking C e r t i f i c a t e .

1 30 days/month used as an example. Ac tua l days/month f o r each month was used.

90 days/month used as an example. q u a r t e r

2 Ac tua l daydmonth used f o r each

2007027/101/201/301/401/601 Page 4

emiss ion reduc t i ons (AER) t o be banked a re i nc luded i n Attachment C. HAE f o r each q u a r t e r a re as f o l l o w s :

H i s t o r i c a l Ac tua l Emissions ( i n Lbs /Quar te r l Quar te r PMln so, so, NO, co

! ! ! I Jan - Mar I 714.26 , 869.53 61 643.59 1583.79 /j 5077.44 I/

I I 1,

1877.13 ii 6017.87 il

jl J u l - Sep jj 807.53 11 983.07 1 69692.93 /I 1790.60 [ 5740.45 [; i o c t - Dec /I 890.14 'mm! I 1973.80 I 6327.77 /I I/

~~ ~~ ~ ~ ~

E. Ad,justments t o I n i t i a l Emission Reductions:

1. E a r l y Implementat ion o f BARCT:

I n t h e San Joaquin V a l l e y U n i f i e d A i r P o l l u t i o n Con t ro l D i s t r i c t 1991 A i r Q u a l i t y A t ta inment Plan (AQAP) t h e r e a r e proposed measures f o r t h e c o n t r o l o f NO, emissions from e x t e r n a l combustion sources. The s e c t i o n t i t l e d Ex te rna l Combustion Devices -- B o i l e r s , Steam Generators, Process Heaters, D r i e r s i n t h e AQAP ( see Attachment 0) proposes NO!, c o n t r o l measures and l i s t s SCC and CES codes f o r e x t e r n a l combustion devices. Two o f t h e SCC and CES codes l i s t e d i n t h e above mentioned s e c t i o n a p p l y t o process gas i n c i n e r a t i o n a t a pe t ro leum r e f i n e r y source (SCC and CES codes 102007001 and 82081 r e s p e c t i v e l y ) . However, t h e proposed removal o f t h e i n c i n e r a t o r was approved by A u t h o r i t y t o Cons t ruc t ( A p r i l 18, 1991) p r i o r t o t h e issuance o f t h e AQAP (January 30, 1992); t h e r e f o r e , a 75%. HAE NO, reduc t i on , because o f e a r l y implementat ion o f BARCT (see Rule 220.1.V.61, i s no t r e q u i r e d .

Apr - Jun 1 84.66 103.06 I 7306.10 9 187.71 )I 601.79 I

J u l - Sep 80.75 1 , 98.31 11 6969.29 J 179.06 574.05 1 I I, U U

Oct - Dec I) 89.01 108.37 I 7682.34 197.38 /I 632.78 1 I il

2007027/101/201/301/401/601 Page 5

For DeDOSit into the Community Bank (in Lbs/Oayl Quarter PM,, so, so1 NO; co

Jan - Mar 0.79 0.97 !I 68.49 1 1.76 I 5.64 1 I U I 8 I I U li y Jul - Sep , 0.88

0.97

1 Apr - Jun jj 0.93 I/ 1.13 1 80.29 2.06 11 6.61 /I I I

6.24 8 I

1.07 1 75.75 I( 1.95 i 2 I

1.18 83.50 2.15 A 6.88 /I

I Jan - Mar 642.83 1 782.58 1 55479.23 j/ 1425.41 11 4569.70 ! Apr - Jun 761.90 1927.521 65754.88 1689.42 1 5416.08 1

1611..54 11 5166.41 1 Jul - Sep I 726.77 1-1 62723.64 / Oct - Dec 801.13 69141.04 1 1776.42 1 5694.99 ,

F. Bankable Emission Reductions:

The HAE less the community bank adjustment and adjusted for the portion o f SO4 included in the PMIO emission factor gives bankable emission reductions of:

i

VIII. COMPLIANCE:

A. Rule 220.1:

1. Baseline Period:

During the processing o f the ERC application, the baseline period was evaluated to assure compliance with Rules 220.1.11.F. and 230.1.V.E. The baseline period (8 calendar quarters) used ends within 180 days of the removal of the old incinerator (e.g. April '90 - March '92) and, therefore, complies with Rules 220.1 and 230.1 requirements.

2. Calculations:

Community Bank allotment was deducted from the AER as prescribed in Rules 220:l.VI and 230.2.IV. Calculations in determining the AER were used as described in Rule 220.1. ERC complies with Rule 220.1.V.E.2.

2007027/101/201/301/401/601 Page 6

B. Rule 230.1:

The ERC application, eligibility and registration are all completed according to the requirements of Rule 230.1. The applicant has demonstrated the ERC to be valid by the definition in Rule 230.1.III.G.:

1. Real: The old incinerator did exist and was operated and had actual emissions at the location specified.

2. Surplus: The old incinerator has been replaced by a new incinerator (included on permit 2007245 -- see Attachment A). All emission increases from the new incinerator and associated equipment have been assessed under new source review. No emission reductions from the removal of the old incinerator were required for approval of emission increases from the new incinerator or for the approval of any other emissions unit.

3. Permanent: The incinerator has been taken out of service and rendered inoperable.

4 . Quantifiable: Emissions were quantified by actual fuel use data and source tests determined the emission factors that were used. HAE were discounted where a prohibitory rule or permit condition resulted in less emissions.

5. Enforceable: Permit to Operate 2007027A includes incinerator (16-M101) as part of the equipment on the subject PTO. On ATC 2007027B incinerator 16-MlOlhas been removed and tailgas normally exhausted to the incineration unit is now required to exhaust to the new Tail Gas Treating Unit listed on ATC 2007245. Location can be inspected for equipment operating without valid a PTO or ATC.

6. Timeliness: Application was submitted with in 180 days of when the reduction actually occurred.

ERC complies with Rule 230.1

C. Rule 230.2:

The 10% deductions from the AER's were made for the Community Bank and will be deposited to the Community Bank upon issuance of the ERC.

IX. RECOMMENDATION:

Upon completetion of 30 day public notice period issue Emission Reduction Credit Certificates S-0002-2, '-3, '-4, '-5 and '-6.

2007027/101/201/301/401/601

ATTACHMENT A

. 2007027/101/201/301/401/601 Page 4-a-

KERN COUNTY AIR POLLUTION CONTROL DISTRICT

2700 "M" STREET. SUITE 275

TELEPHONE: (805) 861-3682

PERMIT TO OPERATE B A K E R S F I E L O . CA. 93301 Number: 2007027(A)

PERMIT TO OPERATE IS HEREBY GRANTED TO: TEXACO REFINING & MARKETING INC.

FOR EQUIPMENT LOCATED AT: 6451 Rosedale Hwy. Bakersfield

EQUIPMENT OR PROCESS DESCRIPTION: Claus/ATS Sulfur Recovery Plant Unit $16

OPERATIONAL CONDITIONS LISTED BELOW.

THIS PERMIT BECOMES VOID UPON ANY CHANGE OF OWNERSHIP OR LOCATION. OR ANY ALTERATION

NOTE: The permittee may be required to provide adequate sampling and testing wrLLIm J. RODDY facilities. Equipment modification AIR POLLUTION CONTROL-OFFICER

i c. ..-. ...--> I

r ? I :, -.-_

,\ . . requires a new permit.

REVOCABLE: This permit does not authorize By: the emission of air contaminants in excess of those allowed by the Rules and Regulations of the K.C.A.P.C.D.

.. . . . l.. \ , . '--. '-.I--.

o r Period: 08-31-90 TO 08-31-91 .-I! /,, ,.?$-y,

CONDITIONAL APPROVAL: y:, ,+ \> Compliance with all conditions of appr,gE$,ilmposed by any applicable Authority to Construct is required for life of this equip

EQUIPMENT DESCRIPTION: equipment:

a. b. Amine solution H2S knockout drum, c. Muffle furnace. 16-P-1. d. First stage reactor, e. Second stage reactor. f. Sulfur condenser, 1G-VI03, g. Sulfur storage tank, 16-Tl01. h. Primary reactor (ATSI.

tiun\esbb modified by application. ! F k, 'it<.>:

Claus/ATS S u J f i r Recovery Plant Unit t16. including the following -*-

Sour water stripper overhead knockout drum.

i. Secondary reactor (ATS). , ; ~Ta'l.l.gas-inc~inerat~r~ -16- M101-;-- c5 L t ci% -4,,,c k. ATS storage tank, 16-T3, 1. Miscellaneous vessels, heat exchangers and pumps, m . Ammonia storage tank. n. Piping from sour gas oulet of MEA Regenerator (2007204) to Claus plant inlet piping.

OPERATIONAL CONDITIONS:

1. Emissions Monitoring System (EMS) structured and operated per plan on file with and approved by the District shall be operated and maintained for entire refinery, including this process unit.

SO2 - 506.4 lbm/hr. NO2 - 140.4 lbm/hr. and PM - 40.3 lbm/hr. If EMS is not operational. Claus ATS Sulfur Recovery Plant Unit t16 emissions shall not exceed the following rates: SO2 - 40.0 Ibm/hr, NO2 - 0.8 lbm/hr, and PM - 1.7 lbm/hr. (All EMA

2. Entire refinery emissions. as determined by EMS. shall not exceed the following rates:

...... . . . . . . . . . . . . . . . . . . . . . . . . . . .

... 2007027/101/201/301/401/601 , . . .

................. .. ................ . ... -. . -

Page 4-3

KERN COUNTY AIR POLLUTION CONTROL DISIRICT

A U T H O R I T Y T O C O N S T R U C T

2700 "M" StrecL Suite 275 BaLenficld, CA %301

(805) 861-3682

William I. Roddy Air Pollution Control Officer

AUTHORITY TO CONSTRUCT IS HEREBY GRANTED To.

TEXACO REFINING & MARKETING. INC.

AUTHORITY TO C O N n R U C T IS HEREBY GRANI€D FOR :

Modify Existinz Claus Sulfur Recovery Unit. n

Validation Signature :

Air Pollution 5 8 0 9149 015 I R e r . 61891

TEXACO REFINING & MARKETING INC. Permit #2007027(A) Page 2

3.

4 .

5 .

6 .

7.

8 .

9 .

10

rates are to be one hour averages). EMS printout demonstrating compliance With Condition t 2 shall be made available for 1nspection.by Dlstrict staff upon notice. Visible emissions from any Single emission point shall not equal or exceed 20% opacity (or R#l) for any more than an aggregate of three minutes in any one hour. Combustion contaminating emissions from any single emission point shall be less than 0.1 gr/scf calculated to 12% CO2. Tailgas incinerator exhaust gas Sulfur compounds concentration (as SO2) shall ot exceed 2000 ppm by volumne and shall be monitored and recorded. Claus plant and ATS plant components shall be equipped with temperature indicators as necessary to operate units in manner recommended by manufacturer. Tailgas incinerator burning chamber temperature shall be maintained at no less than 1200’34 and shall be monitored and recorded. Hydrocarbon emissions from source shall not exceed 2 , 4 7 6 . 9 lbm/day without prior District and 2 1 0 . 3 )

Marketing, Inc. to not exceed 2 0 . 0 or immediate compliance with Rule

recorded. (Rules 108 and

. Sulfur processing capacity of documented by Texaco Refining &

424 is required. (Rule 4 2 4 ) 11. Claus/ATS effluent sulfur continuously monitored and

12 . Operation shall not result beyond property boundary. (Rule 419)

3 3 . All connectors and piping shall be vapor-tight. (Rule 2 1 0 . 1 )

EMISSION SAMPLING LIMITS:

Sulfur Compounds: 40 .00 lbm/hr (as SO2) (Rule 2 1 0 . 1 )

-. .. . . ... . . . . . .

. . . ' 2007027/101/20 1/301/40 1/60 1

Page 2 of

6 Pages

20070278 Continued

EQUIPHENT DESCRIPTION: Modify ExistinF! Claus Sulfur Recoverv Unit, including the following equipment and design specifications:

A. B. C. D. E. P . G . H. I . J. K. L. M. N.

Acid gas K.O. drum 16-D-10A. (existing) Sour water gas K.). drum 16-D-10B. (existing) Condensate pump 16-P-101, (existing) Two process air blowers 16-C-101/102. (existing) Muffle furnace 16-F-1. (existing) Sulfur Coaleser 16-V-103. (existing) Waste heat boiler 16-H-101, (existing) Sulfur condenser 16-E-101, (existing) Catalytic Reactor two stage 16-D-101. (existing) Sulfur Condenser 16-E-102, (existing) SulPur storage pit 18-T-101. (existing) H2S/S02 ratio analyzer/controller. (existing) Miscellaneous vessels. heat exchangers and pumps, (existing) Tall Gas Treating Unit and Incinerator shared with 2007245. (new)

.'.? . . ::. i j

CONDITIONAL APPROVAL:

Pursuant to Rule 209, "condlt$onal,.approvaJi is hereby granted. Please be aware that all conditions o~.'approyalc;~ma~~ in effect for life of project unless modifications are app.y'k$&?\District.

,., . .<.- d

W'

DESIGN CONDITIONS:

1. No pressure relief valves shall be designed to relieve hydrocarbons or

2. Area 1 refinery fuel gas system shall be equipped with hydrogen sulfide

3. Unit shall be equipped with temperature indicators as necessary to operate

4 . All vessels. valves, flanges, connections and piping shall be designed and

5 . All sampling connections, open-ended valves or lines shall be equipped with

sulfur compounds to refinery fuel gas system. (Rule 209)

concentration monitoring/recording system. (Rules 209 & 422)

units in manner recommended by manufacturer. (Rule 209)

maintained in vapor-tight condition. (Rule 210.1)

two closed valves or be capped with blind flanges or threaded plugs except during actual use. (Rule 422)

6. All new drains shall be equipped with a trap (water seal). (Rule 422)

.. . . . .. .. . . ... . . . . . . .. .. .. ... .

. . , . , . ~ ~ ~ ~ ~ ~ 7 / 1 0 1 / 2 0 1 / 3 0 1 / 4 0 1 / 6 0 1

Page 3 Of

6 Pages

2 0 0 7 0 2 7 B Continued


a.

b. Vessels shall be depressurized (during turnaround) as required by Rule

c. Sulfur Unit feed gas and gas produced from this emissions unit shall not be

Area 1 fuel gas system sulfur content shall not exceed 0 . 1 0 gr/dscf as Hp. (Rule 422)

4 1 4 . 3 . (Rule 4 1 4 . 3 )

disposed of to flare except during upset breakdown conditions pursuant t o Rule 111 . (Rule 2 1 0 . 1 )

August 2 1 . 1990 shall not exceed 2 4 7 6 . 9 lbm/day without prior District approval. (Rule 2 1 0 . 1 ) Operation shall not result in odors detectable at or beyond property boundary. (Rule 419)

d. Hydrocarbon emissions from all emissions units existing in Area I prior to

e.

f. Operation shall not create a public nuisance. (Rule 419)


Emissions sampling limits are limits for 2007245 as they are a common emissions point and ions limit.

SPECIAL CONDITIONS:

aa .

bb.

cc .

dd . ee.

Texaco Refining and Marketing Inc. shall adhere to source testing, monitoring, recordkeeping and notification requirements of Rule 422 at all times. (Rule 422) During upset breakdown conditions pursuant to Rule 111 waste gas shall be disposed of only in manner approved by District under Authority to Construct 2007245. (Rule 2 1 0 . 1 ) Overall refinery sulfur production shall not exceed 87 lt/day unless Authority to Construct 2007248 is fully implemented. (Rule 4 1 9 ) Overall refinery sulfur production shall not exceed 128 lt/day after Authority to Construct 2007248 is fully implemented. (Rule 419) When the tail gas treating Unit is off line. total sour gas feed to SRU t l . SRU 13 and SRU t 4 shall not exceed:

4 2 . 0 0 MMSCP during the first year of operation of t.3 SRU. 5 6 . 0 0 MMSCP during the first two years of operation t 3 SRU. 8 4 . 1 2 MMSCP during any consecutive three years of operation

If any of these limits is exceeded, Texaco Refining and Marketing. Inc. shall construct a second tail gas treating unit (separate Authority to Construct requjred) (Rule 2 1 0 . 1 BACT Req)

20070278 Continued

SPECIAL CONDITIONS CONTINUED:

ff

gg

hh

ii

Texaco Refinine and Market

Page 4 of

6 Pages

IE. Inc. sha 1 monitor an - - record sour gas rate to SRU t l . SRU t3 and SRU t4 when tail gas treating unit is offline. >This information shall be submitted quarterly in refinery CEM report and original records be made available for District inspection upon request. (Rule 210.1)

Prior to implementation of this Authority to Construct Texaco Refining and Marketing shall establish a computerized emissions monitoring system capable of providing the District with the following on-line em'issions monitoring data on a call-up (in District office) basis:

Sour gas flow to each sulfur recovery unit,

Sour gas flow to each refinery flare.

Total sour gas production. A

SO2 concentration and SO2 emissions r m each tail gas treating unit.

Methods approved of by viewing the Control data Off an %@$$!!!ation er ule 210.1) shall be in a form

Continuous emissions monitoring and reporting system (Special Condition gg.) shall continuously log and report to District office all exceedances of applicable sulfur emissions limits. Authority to Construct 200'7245 shall be implemented concurrently with this Authority to Construct. (Rule 210.1)

STATE OF CALlFORh'IA AIR TOXICS BOT SPOTS REQUIREMENTS:

Facility shall comply with California Health and Safety Code Sections 44300 through 44384. (Rule 208.1)

STATIONARY SOURCE CURTAILMENT PLANS AND TRAFFIC ABATEMENT PLANS:

Facilities expected to emit 100 tons per year or more of carbon monoxide, hydrocarbons. particulate matter or oxides of nitrogen shall comply with KCAPCD Rule 613.

m. Rule 111 does not provide relief from legal action for volitions resulting from recurrent breakdown of same equipment.

Page 5 of

6 Pages

20070278 Continued

RULE 210.1 (NSR) ANALYSIS VALIDATION:

Maximum daily emission rate of each air contaminant from these emissions units under peraits 20070278. daily emissions limitation:

Particulate Matter (PM-IO): 23.64 lbm/day (Rule 210.1)

‘245 and ‘248 shall not exceed the following

Sulfur Comoounds: 137.76 lbm/day (of SO2) (Rule 210.1) 20.64 lbdday (of SO,) (Rule 210.1)

Oxides of Nitrogen: 84.00 lbm/day (as N O 2 ) (Rule 210.1)

Hydrocarbons : 1.68 lbm/day (Rule 210.1) stack 51.24 Lth/day (Rule 210.1) fugitive

-.I 1 Carbon Monoxide: 21.00 1b.nJday (Rule 210.1)

operator (with fuel consum€@b a . operational data, etc.) on daily basis and written documenta owmade readily available to District for period of three years.

Compliance with daily emiss shall be verified by source

RULE 210.1 (NSR) DAILY EMISSIONS LIMITATIONS: (See attached. )

-.: 3 . ., . 'I . . ' 2007027/101/201/301/401/601 Page 4-7

KERN COUNTY AIR POLLWON CONTROL DISTRICT

S T R

27 29s 27E


LDcation : S u n v p Inspection Date :

6451 Rosedale Hwy., Area 1

2700 "M" Street, Suite 275 Bakersfield, CA 93301 (so9 861-3682


lssW DATE : April 18. 1991 hPPuunoN NO. 2007245

FXPIRATIONDATE: April 18. 1993 DATE: May 29, 1990

AUTHORITY TO CONSTRUCT IS HEREBY GRANTED To:

TEXACO REFINING & MARKETING, INC.

In thc tvcnl LII AUTHORIN TO CONSIRUCT is rckucd 10 I m w omm, my -om innsuc &gnd to this quipmcnt dvling initial Ncr sourct Rc%iicr P m a s r e d m ViIh tbc inibl bcam of ibis dosummL

AUTHORITY TO CONSTRUCT IS HEREBY GRANED FOR :

Claus Sulfur Recovery Unit, Tail Gas TreatinL: Unit and Waste Gas Incinerator.


Air POllution 5 8 0 9149 015 (Rev . 6 / 8 9 )

Page 2 of

8 Pages

2007245 Continued

EQUIPMENT DESCRIPTION: Claus Sulfur Recovery Unit, Tail Gas Treating Unit and Waste Gas Incinerator, including the following equipment and design specifications:

A. B. C. D. E.

P. G. H. I. J. K. L. M. N. 0. P. 9. R. S.

T. U. V.

W. X. Y. 2.

AA. AB. AC . AD. AE.

AP . AG . AH.

SRU #3

Combustion air blower 17-CIOIA 3600 scfm with 250 hp electric motor. Spare combustion air blower 17-CIOlB 3600 scf with 250 hp electric motor, Acid gas K.O. drum 17-Dl01 2 ft. 6 in. dia x 8 ft. 10 i n . long, Two acid gas condensate pumps 17-P1OIA/B with 7.5 hp electric motors, Sour water stripper gas K.O. drum 17-D102 2 ft. 6 i n . dia x 8 ft. 10 in. long. Condensate pumps 17-P102A/B with 5 hp electric motors, Claus combustor 22.5 MMbtu/hr 17-SlO1, Thermal reactor 17R-101. Primary boiler 17-El01, Primary sulfur condenser 17-E102. Catalytic reactor 17-RI02 (three-stage), Final sulfur condenser 17-El05, Sulfur day tank 17-Tl01, Two sulfur transfer pumps 17-P103A/B with 15 hp electric motors, Sulfur storage tank 30 ft. dia x 3 0 i f t . high, Two sulfur loading pumps 17-P104A/-B,'i ith 20 hp electric motors, H2S/S02 ratio analyzer/controlle~~~ Spare H2S/SO2 ratio analyzer/c+kyller. Miscellaneous small vessels.@Tmps. heat exchangers and piping.

Tail Gas Treating Unit (~TzTbw..

.=,-\

liL 1;jQ *i

:\ r (all equipment new) 1:. ..

Tail gas reactor 17-RI03 9 ft. dia x 11 ft. long, Waste heat steam generator 17-EI09. Booster blower suction K.O. drum 17-Dl03 and booster blower discharge K.O. drum 17D-104 stacked over all 3 ft. 6 in. dia x 22 ft. high. Two booster blowers each 4100 scf with 250 hp electric motors. Quench column 17-VIO1 5 ft. 6 i n . dia x 4 1 ft. tall, Quench water trim cooler 17-Ell1 with bypass valves/piping, Quench water dual bank air fan cooler 17-P101 with two 15 hp electric motors and isolation piping/valves. Two quench water circulation pumps 17-P105A/B with 40 hp electric motors, Two quench water filters 17-D105A/B. Absorber 17-Vl02 4 ft. 6 in. dia x 53 ft. high, Two lean solvent trim coolers 17-E112A/B with isolation valves/piping, Lean solvent dual bank air fan cooler 17-Pl02 with two 15 hp electric motors and isolation valves/piping. Lean oil solvent filter 17-D106A/B. Carbon filter 17-Dl07. Carbon after filter 17-D108.

. . 2007027/101/201/301/401/601

Page 3 Of

8 Pages

2001245 Continued

EQUIPMENT DESCRIPTION CONTINUED:

AI. AJ. AK. AL . AM.

AN. A0 . AP . AQ . AR. AS. AT. AU . AV . AW. AX. AY .

BA . BE. BC. BD .

Two rich solvent pumps 1l-P107A/B with 20 hp electric motors, TWO lean solvent pumps 1l-P10lA/B with 20 hp electric motors, Lean rich solvent exchangers 1l-E113A/B with isolation valves/piping. Regenerator 11-V103 4 ft. dia x 100 ft. high, Regenerator overhead condenser dual bank with two 15 hp electric motors and isolation valves/piping 1l-PIO3. Two reflux pumps 1l-P108A/B with 5 hp electric motors. Solvent sump tank 11-TI04 6 ft. dia x 18 ft. long, Solvent sump pump 11-PI09 with 5 hp electric motor. Solvent sump filter 17-Dl11, Lean solvent storage tank 11-TI03 12 ft. dia x 15 ft. high, Solvent circulation pump 17-PI10 with 5 hp electric motor, Two condensate pumps 11-P111A/B with 25 hp electric motors, Two blowdown pumps lI-P112A/B with 25 hp electric motors, Hot oil heater 5 KMbtu/hr (permit exempt), Hot oil surge drum 8 ft. dia x 18 ft. high, Two hot oil circulation pumps 17-P113A/B w!th 25 hp electric motors, Miscellaneous small vessels, pumps, heat exchangers and piping.

Incinerator ,,*:.i'.,j ' J

Incinerator with 22 MMbtu/hr auxil:$&y, :fuel burner and 200 ft. stack, /,-i 1, %._'.:

Inlet H2S analyzer. %.. . In stack SO2 analyzer,

In stack 02 analyzer.

e-.; ! c;-+ .%,. ;'/ ... ~

- ,!. :. ' 7 ':

i\r, , <'


Pursuant to Rule 209. "conditional approval" is hereby granted. Please be aware that all conditions of approval remain in effect for life of project unless modifications are approved by District.

DBSIGN CONDITIONS:

1.

2.

3.

4 .

5.

6 . 7.

No pressure relief valves shall be designed to relieve hydrocarbons or sulfur compounds refinery fuel gas system. Area 1 refinery fuel gas system shall be equipped with hydrogen sulfide concentration monitoring/recording system. Unit shall be equipped with temperature indicators as necessary to operate units in manner recommended by manufacturer. (Rule 209) All vessels, valves, flanges. connections and piping shall be designed and maintained in vapor-tight condition. (Rule 210.1) All sampling connections, open-ended valves or lines shall be equipped with two closed valves or be capped with blind flanges or threaded plugs except during actual use. (Rule 422) All new drains shall be equipped with a trap (water seal). (Rule 422) Exhaust stack shall be equipped with continuously recording S02, and oxygen monitors. (Rule 108)

(Rule 209)

(Rules' 209 & 422)

. .

'. , . ' ~ ~ ~ 7 0 2 7 / 1 0 1 / 2 0 1 / 3 0 1 / 4 0 1 / 6 0 1

Page 4 of

8 Pages

2007245 Continued

DESIGN CONDITIONS CONTINUED:

8. Incinerator inlet shall be equipped with continuously recording H2S monitor on absorber overhead line: (Rules 108 & 210 .1 BACT req.)

9 . Air fan coolers 17-Pl01 . 17-PIO2. 17-Fl03 and exchangers 17-F112A/B and 17- E113A/B shall be sized to allow normal operation with one bank bypassed. (Rule 210.1 BACT r e q . ) Exhaust stack shall be equipped with adequate provisions facilitating the collection of samples consistent with EPA test methods; i.e., capped sample port in accessible location of uniform flow.

10.

(Ri$le 108.1) 4.y ;

,:;s7.>i -.-$..., <.? iJ ~.. * i ,. r

OPERATIONAL CONDITIONS: - --./

a.

b.

C.

d.

e.

f.

e.

h.

i.

./x. \,<\ Area 1 refinery fuel gas system(s) Sulfl,Ur c.ont.ent shall not exceed 0.10

Vessels shall be depressurized (duri:ng fu%around) as required by Rule

Sulfur UnIt feed gas and gas produced from this emissions unit shall not be disposed of to flare except during upset.breakdown conditions pursuant to

gr/dscf as HF. (Rule 4 2 2 ) f i T>.:: 4 1 4 . 3 . (Rule 414 .3 ) ";j.'

Rule 1 1 1 . (Rule 210.1) ..,.. Incinerator firebox temperature shal;i-''be .,,. . . not less than

Incinerator supplemental fuel shaTlil treated refinery gas with sulfuc'\conten /,-. L..: (Rule 209) : f f? 't '.

, ..

1200%. (Rule 209) a PUC carrier o r

Concentration of H2S in inciner,ator feed shall not exceed 10 ppmv H2S (moving 3-hour average). During normal and upset operation sour gas shall be balanced between all operating sulfur recovery units in a manner minimizing sulfur emissions. (Rule 209) Operation shall not.result in odors detectable at or beyond property boundary. (Rule 419) Operation shall not create a public nuisance. (Rule 419)

(Rule. 210.1 BACT req.)


Particulates (PM-IO): 0 . 9 9 ' lbm/hr (Rule 210.1)

Sulfur Compounds: 5 . 7 4 lbm/hr (of SO21 (Rule 2 1 0 . 1 ) 0.86 lbm/hr (of S o t ) (Rule 210.1)

Oxides of Nitrocen: 3 . 5 0 lbm/hr (as NO?) (Rule 210.1)

Hydrocarbons: 0.07 lbdhr (Rule 210.1) stack 2 . 1 4 lbm/hr (Rule 2 1 0 . 1 ) fugitive

Carbon Monoxide: 0.88 lbm/hr (Rule 2 1 0 . 1 )

Page 5 of

8 Pages

2001245 Continued

COMPLIANCE TESTING RBQUIRWNTS:

Compliance with all emissions sampling limits except fugitive hydrocarbons shall be demonstrated by District-witnessed sample collection by independent testing laboratory within 60 days of initial startup, and official test results and field data submitted within 60 days after collection. Compliance with fugitive hydrocarbon emissions shall be demonstrated by emissions testing. maintenance and reporting as required by Rule 414 .1 and 414 .5 . ,(Rule 1 0 8 . 1 )

SPECIAL CONDITIONS: A 1.1:

aa .

bb.

cc.

dd.

ee.

ff.

gg .

C:!*'l, Texaco Refining and Marketingqnc. %)all adhere to source testing, monitoring, recordkeeping aIY&..notif ication requirements of Rule 422 at all times. (Rule 422) Within one hour of upset ,yakdown pursuant to Rule 111 of any sulfur recovery unit waste gagdikpoGed of by flaring shall not exceed 12.13 mscfh in each area flare. (Rule'1419) In case of any exceedande'bf any sulfur compound emission limitation or any condition which results in flaring of sour gas. Texaco Refining and Marketing shall, within 30 minutes of initial exceedance. begin to reduce sour gas productlop by removing high sulfur feed stocks and reducing unit rates and shall reduce total sour gas to flares to no more than 25.46 Mscf/hr within four hours of initial exceedance. (Rule 209) Whenever sour gas is being flared and odor complaints are received, the District may request further reductions in operations necessary to reduce flaring of sour gas. Overall refinery sulfur production shall not exceed 87 lt/day unless Authority to Construct 2007248 is fully implemented. (Rule 419) Overall refinery sulfur production shall not exceed 128 lt/day after Authority to Construct 2001248 is fully implemented. (Rule 419) When the tail gas treating unit is off line. total sour gas feed to SRU t l . SRU t 3 and SRU t 4 shall not exceed:

42 .00 EfMSCF during the first year of operation of t3 SRU. 56.00 MMSCF during the first two years of operation t 3 SRU. 8 4 . 1 2 MMsCF during any consecutive three years of operation.

If any of these limits is exceeded, Texaco Refining and Marketing, Inc. shall construct a second tail gas treating unit (separate Authority to Construct required). (Rule 210 .1 BACT Req)

c-.;:. :. F'-.'. i>

1.L" I ,

(Rule 419)

Page 6 of

8 Pages

2001245 Continued


hh .

i i .

11

Texaco Refining and Marketing. Inc. shall monitor and record sour gas rate to SRU ti, SRU t2 and SRU $4 when tail gas treating unit is offline. This information shall be submitted quarterly in refinery CEM report and original records be made available for District inspection upon request. (Rule 210.1)

Prior to implementation of this Authority to Construct Texaco Refining and Marketing shall establish a computerized emissions monitoring system capable of providing the District with the following on-line emissions monitoring data on a call-up (in District office) basis:

sour gas flow to each sulfur recovery unit,

Sour gas flow to each refinery flare, fi $. +

Total sour gas production. L?--l., .-h .-.> , e.*-

so2 concentration and SO2 emissCons rate from each tail gas treating unit.

Methods of viewing data ar$'Popat Of information shall be in a form . ..i .;'

-. , .. ,. CI , ..\

approved by the Control

continuous emissions and reporting system (Special Condition ii.) shall report to District office all exceedances

(Rule 210.1)

of applicable sulfur emissions limits. (Rule 209)

STATE OF CALIFORNIA AIR TOXICS BOT SPOTS REQUIREMENTS:


STATIONARY SOURCE CURTAILMENT PLANS AND TRAFFIC ABATEKENT PLANS:

Facilities expected to emit 100 tons per year or more of carbon monoxide, hydrocarbons, particulate matter or oxides of nitrogen shall comply with KCAPCD Rule 613.

Rule 111 does not provide relief from legal action for violations resulting from recurrent breakdown of same equipment.

. . . . . 3:' . . 2007027/101/201/301/401/601

Page I OP

8 Pages

2007245 Continued


Maximum daily emission rate of each air contaminant from these emissions units under permits 20070278. '245 and '248 shall not exceed the following daily emissions limitation:

Particulate Matter (PM-IO): 23.64 Ibm/day (Rule 210.1)

S u l f u r Compounds: *....- ---13?.16 Ibm/day (of S02) (Rule 210.1) 20?64 lbm/day (of Sod) (Rule 210.1)

Oxides of NitroEen: ,/A<'-.A 8 4 . 0 0 lbm/day (as NO21 (Rule 210.1)

q, ,i i I. .., :">

1.68 Ibm/day (Rule 210.1) stack {&) ',.

Hydrocarbons: p 4.- \.:\ n 51.24 Ibm/day (Rule 210.1) fugitive L-L.'

Carbon Monoxide: 21.00 lbm/day (Rule 210.1)

Compliance with daily emissions limitations shall be verified by source operator (with fuel consumption data. operational data, etc.) on daily basfs and written documentation made readily available torDistrlct for period of three years.

RULE 210.1 (NSR) DAILY EMISSIONS LIMITATIONS: (See attached.)

. . .

2007027/ 10 1 /20 1/30 1/40 1 /60 1

ATTACHMENT B

. . 2007027/101/201/301/401/601

TEST DATE OPERATIONAL DATA DECEMBER 20, 1991

;AS TO CLAUS FURNACE MSCFHR

34.16

6FHS302 TOTAL O F TIME 1200

TEST RESULTS AND EMISSION FAC

PARTICULATE 1.02 LBIHR

1300 1400 1500 1600 1700 1800 1900

MSCFHR

AVG

QUARTERLY AVERAGE

1991 1992 30.82 30.89 23.26 30.80 30.46 32.68 27.33 32.50 33.23 32.22 10.01 30.52 31.63 32.71

32.46 33.12 33.84 34.20 34.39 34.03 34.03

MSCFHR 1 21.51 2 28.48 3 26.18 4 29.59

SULFATE so2 NOX co

1 2

PARTICULATE 19.94 20.64 SULFATE 10.95 11.33 so2 775.93 803.34 NOX 19.94 20.64 co 63.91 66.17

0.56 39.70 1.02 3.21

3 4

19.41 21.44 10.65 11.77

755.29 834.65 19.41 21.44 62.21 68.75

AUG

OCT NOV DEC

1990

18.82 22.63 26.79 28.95 27.50 28.86 25.84 30.16 24.81 21.71

Page p-3

)RS BMSCFHR

0.030 0.017 1.175 0.030 0.097

2007027/101/201/301/401/601 Page . 4-3

TABLE 3-1. SUMMARY OF SOURCE EMISSION TEST DATA ( 6 0 ° F )

U n i t Tested: Texaco R & M SRU Inc ine ra to r

Test Number Test Condition

Barometric Pressure ( i n . Hg) Stack Pressure ( i n . Hg) Stack Area (f t ' ) Elapsed Sampling Time (min.) Volume Gas Sampled (dscf )

GAS DATA

Average Gas Veloci ty ( f p s ) Average Gas Temperature ( O F )

Gas Flowrate (dscfm) Gas Analysis (Volume %)

Carbon Dioxide, dry Oxygen, d r y Water

1 Offse t

29.90 29.88

4.91 120.00 90.541

44.75 957.17

4,460

5.00 5.23 7.66

EMISSION CONCENTRATION

F i l t e r a b l e P a r t i c u l a t e (g r /dsc f ) Total P a r t i c u l a t e (g r /dsc f ) Total S u l f a t e (g r /dsc f ) co (PPm) 131.50

(PPm) 36.75

so* NO, ( P P m )

EMISSION RATE - l b /h r

F i l t e r a b l e P a r t i c u l a t e Total P a r t i c u l a t e Total S u l f a t e co 2.60 SO' NO, 1.19

Date: December 20, 1991

2 Offse t

29.90 29.88

4.91 120.00 90.541

44.75 957.17

4,460

4.98 5.08 7.66

0.0353 0.0485 0.0176 157.54 839.63

32.73

1.35 .1.85 0.67 3.11

37.94 1.06

3 Average Of f se t .

29.88 29.89 29.86 29.87

4.91 4.91 120.00 120.00 89.299 90.127

44.88 44.80 959.08 957.81

4,536 4,485

4.97 4.98 5.36 5.22 6.14 7.16

0.0180 0.0267 0.0300 0.0392 0;0115 0.0146 204.77 164.60 902.30 870.97

24.68 31.39

0.70 1.02 1.17 1.51 0.45 0.56 4.11 3.27

41.46 39.70 0 .81 1.02

3-2

2007027/101/201/301/401/601

ATTACHMENT C

Page C-)

MONTH ,

JAN '90 FEE '90 MAR '90 APR '90 MAY '90 JUN '90 JUL '90 AUG '90 SEP '90 OCT '90 NOV '90 DEC '90

JAN '91 FEB '91 MAR '91 APR '91 MAY '91 JUN '91 JUL '91 AUG '91 SEP '91 OCT '91 NOV '91 DEC '91

JAN '92 FEE '92 MAR '92

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

0 Not us

AVERAGE MONTHLY OFFGAS TO CLAUS FURNACE

Mscf/Hr Mscf/Mnth

0.00 0.00

(18.82). (583.42) 22.63 16293.60 26.79 ' 19931.76 28.95 20844.00 27.50 20460.00 28.86 21474.07 28.84 20764.80 30.16 22439.04 24.81 17863.20 27.71 20616.24

__- _ _ _

30.82 23.26 30.46 32.68 27.33 32.50 33.23 32.22 10.01 30.52 31.63 32.71

22930.08 15630.72 22662.24 23529.60 20333.52 23400.00 24723.12 23971.68

7207.20 22706.88 22773.60 24336.24

30.89 22982.16 30.80 20697.60 0.00 0.00

I because the month does not c o i n c i d e w i t h 8 ca lendar q u a r t e r s

QUARTER

JAN-MAR APR-JUN JUL-SEP OCT-DEC

_ _ _ - _ _ _ _ - _ _ _ _ - - _ _ - 4VERAGE QUARTERLY FUEL USE

( i n Mscf per q u a r t e r ) ________-___-_-____________ _____-______________-- - - - - - 52451.40 62166.24 59300.44 65367.60

. . ' 2007027/101/201/301/401/601

QUARTER


_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ PMlO 1 SO4 1 SO2 I NO2 I CO

714.26 869.53 61643.59 1583.79 5077.44 846.55 1030.58 73060.97 1877.13 6017.87 807.53 983.07 69692.93 1790.60 5740.45 890.14 1083.65 76823.38 1973.80 6327.77

________________________________________----- ____________________-------------------------

QUARTER


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


10% DEDUCTION FOR COMMUNITY BANK

PMlO 1 SO4 1 SO2 1 NO2 I CO Lb/Qtr

____________________------------------------- ______________-_____------------------------- 71.43 86.95 6164.36 158.38 507.74 84.66 103.06 7306.10 187.71 601.79 80.75 98.31 6969.29 179.06 574.05 89.01 108.37 7682.34 197.38 632.18

0.79 0.97 68.49 1.76 5.64 0.93 1.13 80.29 2.06 6.61 0.88 1.07 75.75 1.95 6.24 0.97 1.18 83.50 2.15 6.88

QUARTER


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

QUARTER


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

REMAINING EMISSION REDUCTIONS QUALIFYING FOR EMISSION REDUCTION CREDITS

Lb/Qtr PMlO I SO4 1 SO2 I NO2 I CO

642.83 782.58 55479.23 1425.41 4569.70 761.90 927.52 65754.88 1689.42 5416.08 726.77 884.77 62723.64 1611.54 5166.41 801.13 975.29 69141.04 1776.42 5694.99

REMAINING EMISSION REDUCTIONS QUALIFYING FOR

______________-_____--------_----_----------- ____________________-------------------------

EMISSION REDUCTION CREDITS Lb/Qtr

PMlO I SO4 I SO2 I NO2 1 CO ________________________________________----_ ............................................. 7.14 8.70 616.44 15.84 50.77 8.37 10.:9 722.58 18.57 59.52 7.90 9.62 681.78 17.52 56.16 8.71 10.60 751.53 19.31 61.90

2007027/101/20 1/301/401/60 1

ATTACHMENT D

2007027/101/201/301/401/601

199 I AIR QUALITY ATTAINMENT PLAN

Page fl-2-

EXTERNAL COMBUSTION DEVICES BOILERS, STEAM GENERATORS, PROCESS HEATERS, DRIERS

SOURCES AFFECTED: All existing boilers, steam generators, process heaters and driers subject t o permitting may be affected. This control measure does not apply t o boilers used t o generate electricity. SCC and CES codes are shown below.

EXISTING REGULATIONS: Kern County Rule 425.1 - Oxides of Nitrogen Emissions from Existing Steam Generators used in Thermally Enhanced Oil Recovery.

Fresno and Kern Counties Rule 408 (and other SJVUAPCD zones) - Fuel Burning Equipment

No SJVUAPCD or Zone prohibitory rule requires the use of one fuel in place of another.

DESCRIPTION OF CONTROL MEASURE: The District wil l reduce NOx emissions by implementing several rules that establish emission standards for different categories o f existing external combustion devices. Each separate rule wil l control NOx emissions from a distinct category with subcategories based upon size range and/or type o f combustion device, e.g. large steam generators, refinery process heaters, small package boilers. These rules and the requirements therein will be based on energy, environmental and economic factors specific t o the SJVAB at t h e time of rule development, and specific emission limits, exemptions and applicability criteria will be developed for each subcategory in each rule development process, after consideration o f e&ission limits achieved in practice and cost effectiveness.

This control measure wil l be implemented in four phases based o n source type and control type; several rules, or sets o f requirements within rules, may result f rom each phase o f the control measure. Each type of external combustion device operating in the SJVAB will be addressed in the control measure: equipment types not addressed during one phase o f the control measure will be addressed in another phase.

Phase 1 of the external combustion NOx control measure will target larger Combustion devices such as process heaters, boilers and steam generators, over a certain MMBtulhr heat input capacity. MMBtu/hr "cut-offs", used t o define

m

7 - 26

. . ; . . . ~ . .:.. ~. - ~. . . . . . ~ . . ~.

. . . . -. .... . . ~ . ..... .....

- . I

199 1 AIR QUALITY ATTAINMENT PLAN

applicability o f the rules, may vary for different equipment types; these cut-off values will be determined during rule development.

Recognizing that many SJVAB external combustion devices burn crude or fuel oil, Phase 2 of the control measure will address encouraging the use of "clean fuel" as a NOx reduction technique. The lowest NOx emissions for any type o f combustion device are achievable through combustion of natural gas in place o f other fuels; it is anticipated that the District will encourage (or require) switching t o natural gas, where such a swi tch is feasible and cost effective.

Smaller combustion devices will be addressed during Phase 3 of the external combustion control measure. Limits may, or may not be developed, depending on technological and economic feasibility.

Phase 4 wil l address driers used in food processing and other industrial processes.

Operators will be able to achieve the emission standards by applying available control technology such as oxygen trim, low-NOx burners, flue-gas recirculation (FGR), selective catalytic reduction (SCRI, selective non-catalytic reduction (SNCR), or radiant burners.

The suggested standards below are f rom the ARB Draft Determination o f BARCT for boilers, steam generators and process heaters. In the ARB Draft Determination, less stringent requirements are suggested for devices with fuel input less than 90,000 therms annually. The ARB BARCT determination will be the starting point for development of the external combustion NOx strategy, but as stated above, District rules and the requirements therein will be based on energy, environmental and economic factors specific t o the SJVAB and different source categories at the t ime o f rule development.

????F I I .. - "

Fuel Tvm Gaseous Fuel Liquid Fuel

EMISSIONS ESTIMATES:

Baseline Inventory: Anticipated Reduction: Remaining Emissions:

pom NOx @3% 0, 30 40

Ib NOJMMBtu 0.036 0.048

NOx - Tons/Dav - 1987 1994 1997 - 2000 89.1 6 85.89 87.67 88.49

65.73 66.47 66.98 20.76 21.26 21.51

7 - 27

... . .. . .. ~ _-.-_ ,.. ,. -. . . . .

'2007027/ 10 1 /20 1 /30 1 /40 1 /601

1991 AIR QUALITYATTAINMENT PLAN ~

-I- . .

The emissions reductions shown are based on the ARB Draft BARCT Determination for Boilers, Steam Generators and Process Heaters.

COST EFFECTIVENESS: For retrofit applications, technological feasibility and costs of control are dependent on energy availability, equipment location, type o f control, operating capacity modes, and physical size of the heater/boiler. Thus, some control techniques that are feasible for larger devices may not be practical for smaller devices because of cost or effect on efficiency. 'Burner replacement may be the most cost effective control technique for smaller boilers. ARB estimates the cost effectiveness o f several typical control technologies as shown below. In general, cost effectiveness improves with size of the unit and annual usage rate.

Unit Size Range Cost Effectiveness C m lMMBtu/hr l j$/ton NOx reducedl Low-NOx Burners 2 5 - 150 $300 - $27,000 Flue Gas Recirculation 10 - 350 $1,000 - $29,000 Selective Noncatalytic Reduction 50 - 375 $1,300 - $20,000 Selective Catalytic Reduction 50 - 3 5 0 $4.000 - $66,000

., .:., &I.

Santa Barbara County APCD estimates cost effectiveness for control o f NOx emissions from smaller boilers using radiant burner technology as shown below:

Boiler Size Total Cost Effectiveness JMMBtu/hr l EauiDment Cost $/ ton NOx reduced

1 $1 8,000 10,000 5 $25,000 3,000 10 $30,000 2,000

-. __

Mobil Oil Company has identified the cost o f retrofit of flue gas recirculation technology for their steam generators t o be approximately $36,000 per year per large (62.5 MMBtu/hr) steam generator. This retrofit reduces NOx f rom a single natural gas-fired generator by about 28 tons per year, for a cost effectiveness of $1,300 per ton of NOx reduced. Mobil Oil's steam generators using flue gas recirculation currently have limits o f 0.04 Ib/MMBtu.

As o f June 6, 1991, Kern River steam generator fuels cost $12 per barrel ($1 .SO/MMBtu) for produced oil and $2.75/mcf ($2.60/MMBtu) for produced natural gas. Assuming fuel costs remain constant, switching fuels f rom crude oil t o natural gas t o reduce NOx emissions would cost approximately $5,800 per ton of NOx reduced. However, with increased availability, local natural gas prices are

__I,,.

- 7 - 28

/ 1991 AIR QUALITYATTAINMENTPLAN

expected t o decrease. Additionally, flue gas sulfur scrubber operational costs, and maintenance costs associated with burning crude would be almost eliminated.

IMPLEMENTING AGENCY: SJVUAPCD

IMPLEMENTATION SCHEDULE:

Phase 1 Phase 2 Phase 3 Phase 4 Draft Rule: 10192 1 Ql93 1 0194 1 0195 Workshop Rule: 20192 2Q193 20194 20195 Adopt Rule: 40192 4Q193 40194 40195 Full Implementation: 40194 4Q195 40196 40197

ENFORCEABILITY: Compliance is dependent on initial and annual emissions tests, annual inspections. Requirements for continuous emission monitors on large sources, and maintenance o f operating logs will enhance the District?s ability to enforce any proposed regulation.

TECHNICAL FEASIBILITY AND PUBLIC ACCEPTABILITY: Technology for certain combustion devices is currently in use that can achieve the NOx emission standards suggested in the ARB BARCT Determination. Implementation of this measure will be affected by the availability o f clean fuels t o meet fuel conversion demands. Pipeline capacity increases are expected t o meet the increase in demand for natural gas. The MojaveIKern River Pipeline project, which is expected t o be completed in 1992, could provide an additional 1.1 billion scf of natural (equivalent t o approximately 200,000 barrels o f oil) gas per day. Public acceptability is expected to be neutral.

HEALTH, ENVIRONMENTAL, ENERGY, AND SOCIAL IMPACTS: Spent catalyst materials, including vanadium pentoxide, are considered hazardous materials and would have t o be deposited in a Class I landfill; the only operational Class I disposal site in California is in Kings County. Ammonia emissions may occur if SCR or SNCR is used. Combustion o f natural gas in place o f residual, distillate or crude oil will result in lower toxic, carbon dioxide, particulate and SO2 emissions. Additional electrical energy will be required to operate all control systems. The control measure will encourage natural gas fuel use over fuel or crude oil.

me??+:

.. 7 - 29

. . ~ . . ~ . . . . ~ . , . . . . . . ,

.. . . . - .. ...... -.. j . I . . ~ - . . . "..'-

. . .. ~~07027/101/201/301/401/601 Page @-b

1991 AIR QUALITY A TTAINMENT PLAN

Switching from crude or fuel oil combustion t o combustion of natural gas wil l reduce emissions o f polycyclic aromatic hydrocarbons and toxic metals, some of which are known carcinogens. Minor increases in emissions of benzene and formaldehyde may result from the increased use of natural gas.

INFORMATION SOURCES:

Air Resources Board. Draft Prooosed Determination of Reasonablv Available Control Technoloav and Best Available Retrofit Technoloav for Industrial. Institutional and Commercial Boilers. Steam Generators and Process Heaters. 1991.

Air Resources Board. 1989. Emissions Inventory Criteria and Guidelines Regulation Pursuant t o the Air Toxics "Hot Spots" Information and Assessment Act o f 1987. Sacramento, California.

Bakersfield Californian. April 74, 1997. "New pipelines to avert natural gas shortages in Kern".

Brinkman, P. E., Mobil Exploration and Production Company. 1990. Letter t o Scott Nester, Kern County APCD. June 20, 1990.

Kings County APCD. "Preliminary Staff Report: Proposed Adoption of Rule 428 - Emissions of Oxides of Nitrogen from Industrial, Institutional and Commercial Boilers, Steam Generators and Process Heaters in Kings County", July 1990.

Lisenbee, Bob, Kern County Assessor's Office. June 7, 1991. Telephone conversation with Scott Nester, Kern Zone.

Pease, Robert R., Martin L. Kay, Andrew Y. Lee. "Industrial Boilers: Status of Oxides of Nitrogen Regulations and Control Technology in the South Coast Air Quality Management District", 1989, Annual Meeting and Exhibition, Air and Waste Management Association, June 7 989.

Santa Barbara County Air Pollution Control District. 1990 Air Quality Attainment Plan. Control Measures N-5 SCAQMD, 7989, Control Measure C-7.

South Coast Air Quality Management District. Best Available Control Technoloav Guideline. October 1988.

.... : 7..

I- d

......

7 - 30

. ... . . . . ,. . . ,, . . _ -. . .,. , 1 .

_ . ' 2007027/101/201/301/401/601 Page 'Q- 7

1991 AIR QUALITY ATTAINMENTPLAN .- ... :.-.

South Coast Air Quality Management District. Rule 1 1 09 - Emissions o f Oxides of Nitrogen from Boilers and Process Heaters in Petroleum Refineries. August 5, 1988.

South Coast Air Quality Management District. Rule 1146 - Emissions of Oxides of Nitrogen from Industrial, Institutional, and Commercial Boilers, Steam Generators and Process Heaters. August 5, 1988.

South Coast Air Quality Management District. Draft Rule 1 1 77 - Best Available Fuel Standard. 1991

South Coast Air Quality Management District. 1989 Air Qualitv Manaoement Plan, "Appendix IV-A: Tier I , Tier I I and Contingency Control Measures". March 1989.

Tompkins, Gene. "Flue-gas Recirculation Works for Packaged Boilers, Too." Power, April 1990.

US Environmental Protection Agency. 1985. ComDilation of Air Pollutant Emission Factors, Fourth Edition. Research Triangle Park, North Carolina.

m. .. . ;e- .. . . . . ,..~~

SCC and CES Codes for External Combustion Devices

SCC

10200401 10200402 10200403 10200501 10200502 10200503 10200601 10200602 10200603 10200701 10200799 10200902 10201002 10201201 10300401 10300402 10300501 10300502 10300503 10300601 10300602 10300603 30290003 30600101 30600103 30600104 30600105 30600106 31000402 31000403 31000404 31000411 31000412 31000414 39000499 39000599 39000603 39000689 39000699 39oooa89 39001099

CES

471 42 471 59 471 67 58727 66795 66803 a2073 82081 83071

7 - 31

'_ _I - - *


December 2, 1992

Mr. Donald J. Slack Supervisor - Environment Health and Safety Texaco Refining and Marketing, Inc. P.O. Box 1476 Bakersfield, California 93302

Dear Mr. Slack:

Subject: Application #2007027/101/201/304/4011601 Project Description: Emission Reduction Credit (ERC) Certificate for Emission

Reduction from the Removal of Incinerator ID# l6M101

Thank you for your letter dated November 12, 1992. Texaco has expressed concerns about the baseline period used, and the separation of SO, from PM,, emissions. In response to your concerns the District responds in the following manner:

1. Rule 220.1 J1.F defines a baseline period as "2 consecutive years of operation." Rule 220.1.11.BB defines quarter for a non seasonal source as "a calendar quarter." Rule 220.1 .V. states: "All calculations shall be performed on a quarterly basis, unless specified otherwise." The above definitions explain how emissions must be quantified in 8 consecutive calendar quarters.

Because SO, is particulate matter pursuant to the definition in Rule 1020 .2.26 it must be included in the total PM,, catch in determining compliance with PM,, limits. SO4 is chemically a sulfur oxide, and, therefore, must be included in determining compliance with Sox limits. Banked SO, emissions can be used as offsets for PM,, or SOX emission increases, but not both. As requested by Mr. Steve Powell of your staff on November 24, 1992, the PM10 ERC will be revised to include the SO4 reductions. This will preclude these sulfate reductions from being considered as sulfur oxides in all future actions ( to prevent double counting).

2.

. .

Mr. Donald J. SlacklTexaco Refining and Marketing, Inc. December 2, 1992 Page 2

Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of Permit Services at (805) 861-3682.

Sincerely,


Post Onice Box 1476 Bakersfield CA 93302

Donald R Hall PlanlMana er Bakersfield %ant

Texaco Refining 6 Marketing Rc 8053264232

November 12, 1992

Mr. Sayed Sadredin Director of Permit Services San Joaquin Valley Unified Air Pollution Control District P.O. Box 1312 Fresno, California 93715

J

Re: Application 2OO7027/ 1011201 /3O4/401/601 Emission Reduction CreGii far Shutdown of Incinerator ID# 16Mi01

Dear Mr. Sadredin:

In response to your letter of October 22, 1992, TRMI has the following comments:

Page 3 of the analysis states that the March '90 data supplied by TRMI was not used because this month did not coincide with 8 consecutive calendar quarters preceding the application. In Rules 220.1 and 230.1, the baseline period definition does not refer to 8 consecutive calendar quarters. The baseline period is defined as a time period of at least 2 consecutive years within five years immediately prior to submission of a complete application, provided it is representative of normal operation. TRMI supplied 2 consecutive years of source data immediately preceding the shutdown of the incinerator. No adjustment to this data is necessary.

Page 3 of the analysis states that the PMlO factor included SO4 emissions as the total PMlO emissions. The PMlO factor was reduced by the SO4 factor to represent PMlO and SO4 emissions separately. This approach is not consistent with District policy concerning compliance with PMlO limits. Source operators are not allowed to subtract the SO4 fraction from the PMlO catch in determining compliance with PMlO limits. The ERC and compliance policies regarding the SO4 contribution to PMlO must be consistent.

If you have any questions, please contact Steve Powell at (805) 326-4426.

Sincerely

9 . P uq D. R. Hall

SGPllam 36/92

File: 34040-206

J cc: Glen Stephens SJWAPCD Southern Region

92 NOS i 5 FIY 12: 5 I

Post Office Box 1476 Bakersfield CA 93302

Donald R Hall Plant Mana er Bakersfield $,ant

Texaco Refining & Marketing Inc 8053264232

November 12. 1992

Mr. Sayed Sadredin Director of Permit Services San Joaquin Valley Unified Air Pollution Control District P.O. Box 1312 Fresno, California 93715

Re: Application 2007027/ 101/201/3O4/401/601 Emission Reduction Credit for Shutdown of Incinerator ID# 16M101

Dear Mr. Sadredin:

In response to your letter of October 22, 1992, TRMI has the following comments:

Page 3 of the analysis states that the March '90 data supplied by TRMI was not used because this month did not coincide with 8 consecutive calendar quarters preceding the application. In Rules 220.1 and 230.1, the baseline period definition does not refer to 8 consecutive calendar quarters. The baseline period is defined as a time period of at least 2 consecutive years within five years immediately prior to submission of a complete application, provided it is representative of normal operation. TRMI supplied 2 consecutive years of source data immediately preceding the shutdown of the incinerator. No adjustment to this data is necessary.

Page 3 of the analysis states that the PMlO factor included SO4 emissions as the total PMlO emissions. The PMlO factor was reduced by the SO4 factor to represent PMlO and SO4 emissions separately. This approach is not consistent with District policy concerning compliance with PMlO limits. Source operators are not allowed to subtract the SO4 fraction from the PMlO catch in determining compliance with PMlO limits. The ERC and compliance policies regarding the SO4 contribution to PMlO must be consistent.

If you have any questions, please contact Steve Powell at (805) 3264426.

Sincerely

-2 D. R. Hall

SGP/lam 36/92

File: 34040-206

cc: Glen Stephens SJVUAPCD Southern Region


DISTRICT BOARD HEHBBERS

Rick Jensen Chair Supervisor Hadera County Pauline Lamood Vice Chair supervisor Kern County

Blair Bradley Councilmember city o f Ceres Doug Vagim supervisor Fresno County

Tom Bohigian Councilmember City of Fresno

Joe Hammond Supervisor Kings County

supervisor Herced County


Hike Bogna

Bill Sousa

Nick Blom

Glenn S imj i an C a l i f o r n i a Air Resources Board P r o j e c t Review Branch S t a t i o n a r y Source D i v i s i o n P.O. Bos 2815 Sacramento, CA 95812

Re: A p p l i c a t i o n t2007027/101/201/301/401/601 N i s s i n g Attachment Pages

Dear Mr. Simj ian :

Per your phone cal l t o Glen S t e p h e n s on November 4 , 1992, w e a r e e n c l o s i n g t h e r e q u e s t e d a t t achmen t pages.

Should you have any q u e s t i o n s , p l e a s e t e l e p h o n e Mr. Glen E . S t e p h e n s of t h e Eng inee r ing E v a l u a t i o n S e c t i o n a t (805) 861-3682.

~~

Supervisor S i n c e r e l y , Stanislaus County Clyde Could supervisor Seyed S a d r e d i n Tulare Councy ne1 nclaughlin councilmember ././

Director of Pe rmi t S e r v i c e s 3 (:$! //

Clty of Wasco \..-

Thomas h.' Goff, P.E. Pe rmi t S e r v i c e s Manager

GES E n c l o s u r e s

southern Regional office 2700 M St, Suite 275 + Bakersfield, CA 93301.

ATTACHMENT A

' 2007027/101/201/301/401/601 . .)

Page 4-3-


2700 "M" STREET. SUITE 275 BAKERSFIELD. CA. 93301

PERMIT TO OPERATE TELEPHONE: (80s) 861-3682

Number: 2007027(A)

PERMIT TO OPERATE IS HEREBY GRANTED TO: TEXACO REFINING & MARKETING INC.

FOR EQUIPMENT LOCATE0 AT:

EQUIPMENT OR PROCESS DESCRIPTION:

OPERATIONAL CONDITIONS LISTED BELOW

6451 Rosedale Hwy. Bakersfield

Claus/ATS Sulfur Recovery Plant Unit +16

THIS PERMIT BECOYES VOID UPON ANY CHANGE OF OWNERSHIP OR LOCATION. OR ANY ALTERATIOX'.

NOTE: The permittee may be required to provide adequate sampling and testing WILLIAM J. RODDY facilities. Equipment modification AIR POLLUTION COSTR.OL-ijFF I CER .,-.

-.--> ! , t. ! : . . :\ ., 1

i c requires a new permit. ---_ REVOCABLE: This permit does not authorize By: i _/' , 6 --..---:---. the emission of alr contaminants in excess of those allowed by the Rules and Regulations of the K.C.A.P.C.D.

Compliance with all conditions of appr osed by any applicable Authority to Construct is required for life of this equip g9csp u$$& modified by application.

EOUIPMENT DESCRIPTION: Claus/ATS d f i r Recovery Plant Unit $16. including the following equipment:

a. Sour water stripper overhead knockout drum, b. Amine solution H2S knockout drum. c. Muffle furnace, 16-F-1. d. First stage reactor. e. Second stage reactor. f. Sulfur condenser. lG-V103. g. Sulfur storage tank, 16-Tl01. h. Primary reactor (ATS). i. Secondary reactor (AT'S).

k. ATS storage tank. 16-T3. 1. Mlscellaneous vessels, heat exchangers and pumps, m. Ammonia storage tank. n. Piping from sour gas oulet of MEA Regenerator (2007204) to Claus plant inlet piping


1. Emissjons Monltorlng System (EMS) structured and operated per plan on file with and

or Period: 08-31-90 TO 08-31-91 cq CONLlITIOXAL APPROVAL: 4

~ ~ a s 3 - n i d n e - r at o m Hi7- 5 X&JO

approved by the District shall be operated and maintained for entire refinery, including this process unit.

SO2 - 506.4 Ibm/hr, NO2 - 140.4 lbm/hr. and PM - 4 0 . 3 lbm/hr. If EMS is not operational, Claus ATS Sulfur Recovery Plant Unit t16 emissions shall not exceed the following rates: SO2 - 40 .0 lbm/hr. NO2 - 0.8 Ibm/hr. and PM - 1.7 lbm/hr. (All EMA

i 2. Entire refinery emissions, as determined by EMS. shall not exceed the following rates:

... .

S T R

27 29s 27E

. _ _ .. .. __ . ... .- . ,-

2007027/101/201/301/401/601 .. I

Logtion : Sur~-up Lnrpxrioa Daw :

6451 Rosedale Hwy.. Area 1

. . . . . . . -.. . .... .. . . . . . -

Page 4 3

KERN COUNTY AIR P O L L W O N CONTROL DISfRICT


2700 W Strcer Suite 275 Bakerdie14 CA 93301

(so9 861-M82

ISSUE DATE : April 18, 1991 AF’PUCATlON Na 200’027B

D [ P ~ ~ H D A E : April 18. 1993 DATE: May 29, 1990

AUTHORITY TO CONSTRUCT IS HEREBY GF’JNTED To.


AUTHORITY TO CONSTRUCT IS HEREBY GRA!!TED FOR :

Modify Existing Claus Sulfur Recovery Unit. a


AI, Poilulion 580 9169015 1 1 1 ~ . 6 /69]


rates are to be one hour averages). 3 . EMS printout demonstrating compliance with Condition t 2 shall be made available for

inspection by District staff upon notice. 4 . Visible emissions from any Single emission point shall not equal o r exceed 20% opacity

(or Rzl) for any more than an aggregate of three minutes in any one hour. 5 . Combustion contaminating emissions from any single emission point shall be less than

0.1 gr/scf calculated to 12% C02. 6 . Tailgas incinerator exhaust gas sulfur compounds concentration (as S02) shall ot exceed

2000 ppm by volumne and shall be monitored and recorded. 7 . Claus plant and ATS plant Components shall be equipped with temperature indicztors as

necessary to operate units in manner recommended by manufacturer. a . Tailgas incinerator burning chamber temperature shall be maintained at no less than

1200CP and shall be monitored and recorded. 9 . Hydrocarbon emissions from whole-refinery statioyry source shall not exceed 2 , 4 7 6 . 9

lbm/day without prior District approval. 0.1 and 2 1 0 . 3 ) 10. Sulfur processing capacity of Claus plant documented by Texaco Refinin,. &

Marketing. Inc. to not exceed 2 0 . 0 long b$F!& or immediate compliance with Rule 424 is required. (Rule 424)

11. Claus/ATS effluent sulfur compound recorded. (Rules 108 and 209)

1 2 . Operation shall not result in odors ectable at or beyond property boundary. (Rule 4 1 9 )

13. All connectors and piping shall be vapor-tight. (Rule 210.1)


shall be continuously monitored and E? Sulfur Comoounds: 40 .00 lbm/hr (as SOz) (Rule 210 .1 )

i

.. . . . . -.--

Page 2 of

6 Pages

20070278 Continued

EQUIPHENT DESCRIPTION: Wodify Existintz Claus Sulfur Recovery Unit, including the following equipment and design specifications:

A. B. C. D. E. F. G. H. I. J. K. L. M. N.

Acid gas K.O. drum 16-D-10A. (existing) Sour water gas K.). drum 16-D-108. (existing) Condensate pump 16-P-101. (existing) Two process a i r blowers 16-C-101/102. (existing) Muffle furnace 16-F-1. (existing) Sulfur Coaleser 16-V-103, (existing) Waste heat boiler 16-H-I01.'(existing) Sulfur condenser 16-E-101, (existing) Catalytic Reactor two stage 16-D-IOI. (exfstfng) Sulfur Condenser 16-E-102, (existing) Sulfur storage pit 16-T-101. (existing) H2S/S02 ratio analyzer/controller. (existing) Miscellaneous vessels, heat exchangers and pumps, (existing) Tail Gas Treating Unit and Incinerator shared with 2007245. (new)

CONDITIONAL APPROVAL: __ -..--- j7

Pursuant to Rule 209. "condi~tional,,ap~~ov'a is hereby granted. Please be aware that all conditions {iapprov @ax in effect for life of project unless modifications are a %+iJ istrict.

DESIGN CONDITIONS:

I .



4. All vessels, valves. flanges. connections and piping shall be designed and

5. All sampling COnneCtiOnS. open-ended valves or lines shall be equipped with

No pressure relief va lves shal l be designed to relieve hydrocarbons or sulfur compounds to refinery fuel gas system. (Rule 209)

concentration monitoring/recording systeh.




(Rules 209 & 422)


i

.. . . . .. . .- .. .. .

' 2007027/101/201/301/401/601

Page 3 of

6 Pages

20070278 Continued


a.

b.

C.

d.

e .

f.

Area 1 fuel gas system sulfur content shall not exceed 0.10 gr/dscf as HS. (Rule 422) Vessels shall be depressurized (during turnaround) as required by Rule 414.3. (Rule 414.3) Sulfur Unit feed gas and gas produced from this emissions unit shall not be disposed of to flare except during upset breakdown conditions pursuant to Rule 111. (Rule 210.1) Hydrocarbon emissions from all emissions units existing in Area I prior to August 21. 1990 shall not exceed 2476.9 lbm/day without prior District approval. (Rule 210.1) Operation shall not result in odors detectable at or beyond property boundary. (Rule 419) Operation shall not create a public nuisance. (Rule 419)

2007245 as they are


Emissions sampling limits are a common emissions point and

SPECIAL CONDITIONS:

aa. Texaco Refining and Marketing Inc. shall adhere to source testing. monitoring, recordkeeping and notiflcation requirements of Rule 422 at all times. (Rule 422)

disposed of only in manner approved by District under Authority to Construct 2007245. (Rule 210.1)

cc. Overall refinery sulfur production shall not exceed 87 lt/day unless Authority to Construct 2007248 is fully implemented. (Rule 419)

dd. Overall refinery Sulfur production shall not exceed. 128 lt/day after Authority to Construct 2007248 is fully implemented. (Rule 419)

ee. When the tail gas treating unit is off line. total sour gas feed to SRU # I SRU t 3 and SRU 14 shall not exceed: .

42.00 MMSCP during the first year of operation of #3 SRU. 56.00 MMSCF during the first two years of operation .t3 SRU. 84.12 MMSCP during any consecutive three years of operation.

If any of these llnits is exceeded. Texaco Refining and Marketing, Inc. shall construct a second tail gas treating unit (separate Authority to Construct required) (Rule 210.1 BACT Req)

bb. During upset breakdown conditions pursuant to Rule 111 waste gas shall be

.. . , . .. . . . . . - . .. . .

. . . , . ~007027/101/201/301/401/60~ . . Page ,4-7

Page 4 of

6 Pages

20070278 Continued

SPECIAL COHDITIONS CONTINUED:

ff.

gg .

hh.

ii.

Texaco Refining and Marketing. Inc. shall monitor and record sour gas rate to SRU tl. SRU t 3 and SRU *4 when tail gas treating unit is offline. This information shall be submitted quarterly in refinery CEM report and original records be made available for District inspection upon request. (Rule 210.1)

Prior to implementation of this Authority to Construct Texaco Refining and Marketing shall establish a computerized emissions monitoring system capable of provlding the District with the following on-line emissions monitoring data on a call-up (in District office) basis:

Sour gas flow t o each s u l f u r recovery unit,

Sour gas flow to each reflnery flare.

Total sour gas production. A

SO2 concentration and SO2 emissions

Methods of viewing data and nformation shall be in a fori

m each tail gas treating unit.

approved by the Control Off

Continuous emissions monitoring and reporting system (Special Condition gg.) shall continuously log and report to District office all exceedances of applicable sulfur emissions limits. Authority to Construct 2007245 shall be implemented concurrently with this Authority to Construct. (Rule 210.1)



STATIONARY SOURCE CURTAILMENT PLANS AND TRAFFIC ABATEWENT PLANS:

Pacilitles expected to emit 100 tons per year or more of carbon monoxide, hydrocarbons, particulate matter or oxides of nitrogen shall comply with KCAPCD Rule 613.

HOTES:

Rule I11 does not provide relief from legal action for volitions resulting from recurrent breakdown of same equipment.

. . . . 2007027/10~/201/301/401/601

Page 4-8

Page 5 Of

6 Pages

20070278 Continued


Maximum daily emission rate o f each air contaminant from these emissions units under permits 20070278, '245 and '248 shall not exceed the following daily emissions limitation:

Particulate Matter (PM-101: 23.64 I b d d a y (Rule 210.1)

Sulfur Comvounds: 137.76 Ibm/day (of SO?) (Rule 210.1) 20.64 lbdday (of SO,) (Rule 210.1)

Oxides of NitroEen: 84.00 I b d d a y (as NO?) (Rule 210.1)

Hydrocarbons: 1.68 Ibm/day (Rule 210.1) stack (Rule 210.1) fugitive

Carbon Monoxide: day (Rule 210.1)

be verified by source operational data, etc.) on daily

made readily available to District f o r operator (with fuel consum

RULE 210.1 iNSRl DAILY HISSIONS LIMITATIONS: (See attached.)

. . : ' . \

. I .

. . .' 2d07027/l01/201/301/401/601 Page 4-7 KERN C O W ADl POLLUTION CONIROL DISTT(ICT


2700 W Street. Suite 275 Bakcnficld, CA 9331

(W5) 861-3682

S U E DATE : A p r i l 18. 1991 AF'PLlCATiON NO. 2007245

WIRATKINDATE: April 18. 1993 DATE: May 29, 1990

AUTHORITY TO CONSTRUCT 1s HEREBY GRANTED To:


!a &e cvcnl i~ AUTHORITY TO CDNSlTlUCT u rcioud LO a DCI own. my 6 0 s inricrw &ped IO rhir + p e n t dvrinp initL1 k r Sourrr Rcvicv Rmcs rsmaim mrb rbc

AUTHORITY TO CONSTRUCT IS HEREBY GRANIED FOR :

&u oi his docvsnr

Claus Sulfur Recovery Unit, Tail Gas Treatinz Unit and Waste Gas Incinerator.


Air Pol lul :~n 5 8 0 9 1 4 9 015 (Rev. 6/89)

. . , .

Page 2 of

8 Pages

2007245 Continued

EQUIPWBNT DESCRIPTION: Claus Sulfur Recovery Unit, Tail Gas Treatinc Unit and Waste Gas Incinerator, including the following equipment and design specifications:

SRU t 3

A. B. C. D. E.

P. G . H. I . J . K. L. M. N. 0. P. Q. R .' S.

T. U. V.

W. X . Y . 2 .

AA. AB. A C . AD. AE . i

AP .

Combustion air blower 17-CIOlA 3600 scfm with 250 hp electric motor, Spare combustion air blower 17-ClOlB 3600 scf with 250 h p electric motor, Acid gas K.O. drum 17-Dl01 2 ft. 6 in. dia x 8 ft. 10 in. long, Two acid gas condensate pumps 17-P1OIA/B with 7 . 5 h p electric motors. Sour water stripper gas K.O. drum 1 7 4 1 0 2 2 ft. 6 in. dia x 8 ft. 10 in. long. Condensate pumps 17-P102A/B with 5 hp electric motors, Claus combustor 22.5 MMbtu/hr 17-SIO1. Thermal reactor 17R-101, Primary boiler 17-EI01. Primary sulfur condenser 17-EI02. Catalytic reactor 17-RI02 (three-stage), Final sulfur condenser 17-El05. Sulfur day tank 17-Tl01. Two sulfur transfer pumps 17-P103A/B with 15 hp electric motors,

Tail gas reactor 17-Rl03 9 ft. dia x I1 it. long. Waste heat steam generator 17-El09. Booster blower suction K.O. drum 17-DI03 and booster blower discharge K . O . drum 17D-104 stacked over all 3 ft. 6 in. dia x 22 ft. high, Two booster blowers each 4100 scf with 250 hp electric motors, Quench column 17-VIO1 5 it. 6 in. dia x 41 ft. tall, Quench water trim cooler 17-Ell1 with bypass valves/piping. Quench water dual bank air fan cooler 17-FlO1 with two 15 hp electric motors and isolation piping/valves. Two quench water circulation pumps 17-P105A/B with 40 hp electric motors, TWO quench water filters 17-D105A/B. Absorber 17-VI02 4 ft. 6 in. dia x 53 ft. high, Two lean Solvent trim coolers 17-E112A/B with isolation valves/piping. Lean solvent dual bank air fan cooler 17-FlO2 with two 15 hp electric motors and isolation valves/piping. Lean oil Solvent filter 17-D106A/B.

AG. Carbon filter 17-DI07. AH. Carbon after filter 17-Dl08,

‘ ’2007027/101/201/301/401/601 , .

Page 3 of

8 Pages

2007245 Continued

EQUIPKENT DESCRIPTION CONTINUED:

AI. AJ , Ax. AL . AM.

AN. A0 . AP. AQ . AR. AS. AT. AU . AV . AH. AX. AY.

EA. BE. EC . ED.

Two rich solvent pumps 17-P107A/E with 20 hp electric motors, Two lean solvent pumps 17-P107A/B with 20 hp electric motors. Lean rich solvent exchangers 17-E113A/B with isolation valves/piping. Regenerator 17-’4103 4 it. dia x 100 it. high. Regenerator overhead condenser dual bank with two 15 hp electric motors and isolation valves/piping 17-P103. Two reflux pumps 17-P108A/B with 5 hp electric motors, Solvent sump tank 17-T104 6 ft. dia x 18 ft. long, Solvent sump pump 17-Pl09 with 5 hp electric motor. Solvent sump filter 17-0111. Lean solvent storage tank 17-T103 12 ft. dia x 15 ft. high, Solvent circulation pump 17-PI10 with 5 hp electric motor. Two condensate pumps I7-PlIfA/B with 25 hp electric motors, Two blowdown pumps 17-P112A/B with 25 hp electric motors. Hot oil heater 5 HMbtu/hr (permit exempt), Hot oil surge drun 8 ft. dia x 18 ft. high. Two hot oil circulation pumps 17-P113A/B w{th 25 hp electric motors. Miscellaneous small vessels, pumps, heat exchangers and piping.

Incinerator

Incinerator with 22 MMbtu/hr burner and 200 ft. stack, Inlet H2S analyzer. In stack SO2 analyzer, In stack 02 analyzer.


Pursuant to Rule 209. “conditional approval“ is hereby .granted. Please be aware that all conditions of approval remain in effect for life of project unless modifications are approved by District.

DESIGN CONDITIONS:

1.

2.

3.

4.

5.

6 . 7 .

No pressure relief valves shall be designed to relieve hydrocarbons or sulfur compounds refinery fuel gas systen. Area 1 refinery fuel gas system shall be equipped with hydrogen sulfide concentration monitoring/recording system. Unit shall be equipped with temperature indicators as necessary to operate units in manner recommended by manufacturer. All vessels, valves, flanges, connections and piping shall be designed and maintained in vapor-tight condition. All sampling connections. open-ended valves or lines shall be equipped with two closed valves or be capped with blind flanges or threaded plugs except during actual use. (Rule 422) All new drains shall be equipped with-a trap (water seal). (Rule 422) Exhaust stack shall be equipped with continuously recording S02. and oxygen monitors. (Rule 108)

(Rule 209)

(Rules 209 & 422)

(Rule 209)

(Rule 210.1)

'' ~007027/101/201/301/401/601 . . .

Page 4 of

8 Pages

2007245 Continued

DESIGN CONDITIONS CONTIhmD:

8. Incinerator inlet shall be equipped with ContinuousIy recording H2S nonitor

9. Air fan coolers 17-PIO1, 17-FI02. 17-P103 and exchangers 17-F112A/B and 17- on absorber overhead line.. (Rules 108 & 210.1 BACT req.)

E113A/B shall be sized t o allow normal operation with one bank bypassed. (Rule 210.1 BACT req.) Exhaust stack shall be equipped with adequate provisions facilitating the collection of samples consistent with EPA test methods; i.e., capped sample port in accessible location of uniform flow.

10.

( R a e 108.1)


a. Area 1 refinery fuel gas system(s) sul not exceed 0.10

b. Vessels shall be depressurized by Rule gr/dscf as Hp. (Rule 422)

414.3. (Rule 414.3) Sulfur Unit feed gas and gas produced frpm this emissions unit shall not be disposed of to flare except during upset'breakdown conditions pursuant to Rule 111. (Rule 210.1)

c .

c- r-

d. Incinerator firebox temperature sha?l-be not less than

gr/scf as H2S.

f. Concentration of H2S in IO ppmv H2S

1200%. (Rule 209) =; . . ased from a PUC carrier or

(moving 3-hour average). (Rule 210.1 BACT req.) During normal and upset operation sour gas shall be balanced between all operating sulfur recovery units in a manner minimizing sulfur emissions. (Rule 209) Operation shall not result in odors detectable at or beyond property boundary. (Rule 419)

g.

h.

i. Operation shall not create a public nuisance. (Rule 419)

EWISSION'SAKPLING LIUITS:

Particulates (PM-IO): 0.99 lbm/hr (Rule 210.1)

Sulfur ComDounds: 5.74 Ibm/hr (of SO?) (Rule 210.1) 0.86 Ibm/hr (of SO,) (Rule 210.1)

Oxides of Nitromn: 3.50 l b d h r (as NO?) (Rule 210.1)

Hydrocarbons: 0.07 lb d h r (Rule 210.1) stack 2.14 lbm/hr (Rule 210.1) fugitive

Carbon Monoxide: 0.88 lbm/hr (Rule 210.1)

' 2007027/101/201/301/401/601 . . .

I .

Page 5 of

8 Pages

2007245 Continued

COMPLIANCE TESTING REQUIREWENTS:

Compliance with all emissions sampling limits except fugitive hydrocarbons shall be demonstrated by District-witnessed sample collection by independent testing laboratory within 60 days of initial startup, and official test results and field data submitted within 60 days after collection. Compliance with fugitive hydrocarbon emissions shall be demonstrated by emissions testing. maintenance and reporting as required by Rule 4 1 4 . 1 and 4 1 4 . 5 . .(Rule 1 0 8 . 1 )

SPECIAL COHDITIONS:

aa.

bb.

cc.

dd.

ee.

ff.

gg .

~

to source testing, monitoring.

recovery unit waste g by flaring shall not exceed 1 2 . 7 3 mscfh in each area flare. In case of any compound emission limitation or any condition which results in flaring of sour gas, Texaco Refining and Marketing shall, within 30 minutes of initial exceedance. begin to reduce sour gas production by removing high sulfur feed stocks and reducing unit rates and shall reduce total sour gas to flares to no more than 2 5 . 4 6 Mscf/hr within four hours of initial exceedance. (Rule 2 0 9 ) Whenever sour gas is being flared and odor complaints are received. the Djstrict may request further reductions in operations necessary to reduce flaring of sour gas. (Rule 419) Overall refinery sulfur production shall not exceed 87 lt/day unless Authority to Construct 2007248 is fully implemented. (Rule 4 1 9 ) Overall refinery sulfur production shall not exceed 128'1t/day after Authority to Construct 2007248 is fully implemented. (Rule 4 1 9 ) When the tail gas treating unit is off line, total sour gas f e d t o SRU t l . SRU 13 and SRU t 4 shall not exceed:

4 2 . 0 0 MMSCP during the first year of operation of +3 SRU. 56.00 MMSCP during the first two years of operation :3 SRU. 8 4 . 1 2 MMSCP during any consecutive three years of operation.

If any oP these limits is exceeded, Texaco Refining and Marketing. Inc. shall construct a second tail gas treating unit (separate Authority to Construct required).

requirements of Rule 422 at all

pursuant to Rule 111 of any sulfur

(Rule 2 1 0 . 1 BACT Req)

Page 6 Of

8 Pages

2001245 Continued


hh. Texaco Refining and Marketing. Inc. shall monitor and record sour gas rate to SRU #I, SRU t2 and SRU #4 when tail gas treating unit is offline. This information shall be submitted quarterly in refinery CEM report and original records be nade available for District inspection upon request.

/ (Rule 210.1)

if. Prior to implementation of this Authority to Construct Texaco Refining and Marketing shall establish a computerized emissions monitoring system capable of providing the District with the following on-line emissions monitoring data on a call-up (in District office) basis:

Sour gas Plow to each sulfur recovery unit,

Sour gas flow to each refinery flare,

Total sour gas production. cz;

so2 concentration and SO2 em($,sr ns rate from each tail gas treating unit. %I ?\

Methods of viewing data of information shall be in a form approved by the Control

11.) shall continuously report to District office all exceedances

(Rule 210.1)

jj. Continuous emissions mo and reporting system (Special Condition

of applicable sulfur emissions limits. (Rule 209)

STATE OF CALIFORNIA AIR TOXICS HOT SPOTS REQUIREMENTS:


STATIONARY SOlTRCE CURTAILKENT PLANS AND TRAFFIC ABATEMENT PLANS:

Facilities expected to emit 100 tons per year or more of carbon monoxide. hydrocarbons, particulate matter or oxides of nitrogen shall comply with KCAPCD Rule 613.

Rule 111 does not provide relief from legal actfon for violations resulting from recurrent breakdown of same equipment.

. . . . . . . .

' 2007027/101/201/301/401/601

Page 7 of

8 Pages

2007245 Continued


Maximum daily emission rate of each air contaminant from these emissions units under permits 20070218, '245 and '248 shall not exceed the following daily emissions limitation:

Particulate Matter (PM-IO): 23.64 lbm/day (Rule 210.1)

Sulfur Compounds: ~ 1 5 7 . 7 6 Ibm/day (of SO2) (Rule 210.1) p-' 20)64 Ibm/day (of S O , ) (Rule 210.1)

84.00 lbm/day (as NO$ (Rule 210.1)

1.68 lbm/day (Rule 210.1) stack

(E

(9

51.24 Ibm/day (Rule 210.1) fugitive

21.00 lbm/day (Rule 210.1)

@ Oxides of Nitrogen:

Hydrocarbons: li" Q Carbon Monoxide:

Compliance with daily emissions limitations shall be verified by source operator (with fuel consumption data, operational data, etc.) on daily basis and written documentation made readily available to District for period of three years.


. .

i. ...

”

1.

2007027/101/201/301/401/601

ATTACHMENT B

’ 2007027/101/201/301/401/601 Page p - 3 . .

16FHS302 TOTAL OFFGAS TO CLAUS FURNACE TIME MSCFHR

1200 34.16 1300 32.46 1400 33.12 1500 33.84

I 1600 34.20 1700 34.39 1800 34.03 1900 34.03

i AVG 33.78

TEST RESULTS AND EMISSION FACTORS

PARTICULATE 1.02 0.03C SULFATE 0.56 0.01i s o 2 39.70 1.175 NOX 1.02 0.03C co 3.27 0.09;

LBlHR LBlMSCFHR

l6FHS302 TOTAL OFFGAS TO CLAUS FURNACE MSCFHR QUARTERLY AVERAGE

1990 1991 1992 MSCFHR

FE B 23.26 30.80 2 28.48 MAR 18.82 30.46 3 26.78

MAY 26.79 27.33 JUN 28.95 32.50 JUL 27.50 33.23 AUG 28.86 32.22 SEP 28.84 10.01 OCT 30.16 30.52 NOV 24.81 31.63 DEC 27.71 32.71

JAN 30.82 50.89 1 27.51

APR 22.63 32.68 4 29.59

QUARTERLY EMISSIONS LBIDAY

1 2 3 4

PARTICULATE 19.94 20.64 19.41 21.44 SULFATE 10.95 11.33 10.65 11.77 so2 775.93 803.34 755.29 834.65 NOX 19.94 20.64 19.41 21.44 co 63.91 66.17 62.21 68.75

i

-

2007027/101/201/301/401/601 Page ~ 4-3

TABLE 3-1. SUMMARY OF SOURCE EMISSION TEST DATA (60°F)

Unit Tested: Texaco R & M SRU Inc ine ra to r


Barometric Pressure ( i n . Hg) Stack Pressure ( i n . Hg) Stack Area ( f t 2 ) Elapsed Sampling Time (min.) Volume Gas Sampled (dsc f )

GAS DATA

Average Gas Velocity ( f p s ) Average Gas Temperature (OF) Gas Flowrate (dscfm) Gas Analysis (Volume %)

Carbon Dioxide, . dry Oxygen, d ry Water

1 Offset

29.90

4.91 120.00 90.541

29.88

44.75 957.17

4,460

5.00 5.23 7.66

EHISSION CONCENTRATION

F i l t e r a b l e P a r t i c u l a t e (g r /dsc f ) Total P a r t i c u l a t e (g r /dsc f ) Total S u l f a t e (gr /dscf ) co (PPm) 131.50

36.75 (PPm) so,

NO, (PPm)

EHISSION RATE - 1 b/hr

1 F i l t e r a b l e P a r t i c u l a t e Total P a r t i c u l a t e Total S u l f a t e t o s o 2

NO,

2.60

1.19

3-2

2 Offse t

29.90

4 .91 120.00 90.541

29.88

44.75 957.17

4,460

4.98 5.08 7.66

0.0353 0.0485 0.0176 157.54 839.63

32.73

1.35 .1.85 0 .67 3 . 1 1

37.94 1 .06


3 Average Offset .

29.88 29.86

4.91 120.00 89.299

44.88 959. 08

4,536

4.97 5.36 6.14

0.0180 0.0300 0;0115 204.77 902.30

24.68

0.70 1.17 0.45 4.11

41.46 0.81

29.89 29.87

4.91 120.00 90.127

44.80 957.81

4,485

4.98 5.22 7.16

0.0267 0.0392 0.0146 164.60 870.97

31.39

1.02 1.51 0.56 3.27

39.70 1.02

2007027/l01/201/301/401/601 Page C-]

ATTACHMENT C

MONTH

JAN '90 FEB '90 MAR ' 90 APR '90 MAY ' 90 JUN '90

' JUL ' 90 AUG '90 SEP '90 OCT '90 NOV ' 90 DEC '90

JAN ' 9 1 FEB ' 9 1 MAR ' 9 1 APR ' 9 1 MAY '91 JUN ' 9 1 JUL '91 AUG '91 SEP ' 9 1 OCT ' 9 1 NOV ' 9 1 DEC '91

JAN '92 FEB '92 MAR '92 0 Not u!

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


Mscf/Hr Mscf/Mnth _______________-____- - - - - - ______________-___-_-- - - - - 0.00 0.00

(18.82) (583.42) 22.63 16293.60 26.79 19931.76 28.95 20844.00 27.50 20460.00 28.86 21474.07 28.84 20764.80 30.16 22439.04 24.81 17863.20 27.71 20616.24

___ ---

30.82 23.26 30.46 32.68 21.33 32.50 33.23 32.22 10.01 30.52 31.63 32.71

22930.08 15630.72 22662.24 23529.60 20333.52 23400.00 24123.12 23971.68

7207.20 22706.88 22773.60 24336.24

30.89 22982.16 30.80 20697.60

0.00 0.00 I because t h e month does not c o i n c i d e w i t h

2007027/101/201/301/401/601

QUARTER


--------- -_-------

QUARTER


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

PMlO I SO4 1 SO2 1 NO2 1 CO . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . --_-______-___-___--____________________----- 71.43 86.95 6164.36 158.38 507.74 84.66 103.06 7306.10 187.71 601.79 80.75 98.31 6969.29 179.06 574.05 89.01 108.37 7682.34 197.38 632.78

ACTUAL HISTORICAL EMISSIONS

PMlO I SO4 I SO2 I NO2 I CO

714.26 869.53 61643.59 1583.79 5077.44 846.55 1030.58 73060.97 1877.13 6017.87 807.53 983.07 69692.93 1790.60 5740.45 890.14 1083.65 76823.38 1973.80 6327.77

L b / Q t r

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

QUARTER


--------- ----_-_-- PMlO 1 SO4 1 SO2 I NO2 1 CO

642.83 782.58 55479.23 1425.41 4569.70 761.90 927.52 65754.88 1689.42 5416.08 726.77 884.77 62723.64 1611.54 5166.41 801.13 975.29 69141.04 1776.42 5694.99

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .............................................


QUARTER


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

Lb/Day QUARTER I PMlO I SO4 I SO2 I NO2 .I CO

PMlO I SO4 I SO2 1 NO2 I CO ............................................. ---__________---_-_-____________________----- 7.14 8.70 616.44 15.84 50.71 8.37 10.19 122.58 18.57 59.52 7.90 9.62 681.78 . ' 17.52 56.16 8.71 10.60 751.53 19.31 61.90

2007027/101/201/301/401/601

ATTACHMENT D

Page 4-3 '~007027/101/201/301/401/601 . .

1991 AIR QUALITYATTAINMENTPLAN - EXTERNAL COMBUSTION DEVICES

BOILERS, STEAM GENERATORS, PROCESS HEATERS, DRIERS

SOURCES AFFECTED: All existing boilers, steam generators, process heaters and driers subject t o permitting may be affected. This control measure does not apply to boilers used to generate electricity. SCC and CES codes are shown below.




DESCRIPTION OF CONTROL MEASURE: The District will reduce NOx emissions by implementing several rules that establish emission standards for different categories of existing external combustion devices. Each separate rule wil l control NOx emissions from a distinct category with subcategories based upon size range andlor type of combustion device, e.g. large steam generators, refinery process heaters, small package boilers. These rules and the requirements therein will be based on energy, environmental and economic factors specific t o the SJVAB at the time of rule development, and specific emission limits, exemptions and applicability criteria will be developed for each subcategory in each rule development process, after consideration of ekission limits achieved in practice and cost effectiveness.

-i-c

This control measure will be implemented in four phases based on source type and control type; several rules, or sets of requirements within rules, may result from each phase of the controi measure. Each type of external combustion device operating in the SJVAB will be addressed in the control measure: equipment types not addressed during one phase of the control measure will be addressed in another phase.

Phase 1 of the external combustion NOx control measure will target larger combustion devices such as process heaters, boilers and steam generators, over a certain MMBtulhr heat input capacity. MMBtulhr "cut-offs", used t o define

7 - 26 i :

. .., - . . .

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

. . ... . . ,. . . . .. . . ~

. , ~~~7027/l01/201/301/401/601 Page -&-3.

1991 AIR QUALITYATTAINMENTPLAN _- .. --

applicability o f the rules, may vary for different equipment types; these cut-off values will be determined during rule development.

Recognizing that many SJVAB external combustion devices burn crude or fuel oil, Phase 2 of the control measure will address encouraging the use of "clean fuel" as a NOx reduction technique. The lowest NOx emissions for any type of combustion device are achievable through combustion of natural gas in place of other fuels; it is anticipated that the District will encourage (or require) switching to natural gas, where such a switch is feasible and cost effective.


Phase 4 will address driers used in food processing and other industrial processes

Operators will be able to achieve the emission standards by applying available control technology such as oxygen trim, low-NOx burners, flue-gas recirculation (FGRJ, selective catalytic reduction (SCR), selective non-catalytic reduction (SNCRJ, or radiant burners.

The suggested standards below are from the ARB Draft Determination of BARCT for boilers, steam generators and process heaters. In the ARB Draft Determination, less stringent requirements are suggested for devices with fuel input less than 90,000 therms annually. The ARB BARCT determination will be the starting point for development of the external combustion NOx strategy, but as stated above, District rules and the requirements therein will be based on energy, environmental and economic factors specific to the SJVAB and different source categories at the time of rule development.

-7 --;

Fuel TvDe Gaseous Fuel Liquid Fuel

EMISSIONS ESTIMATES:

Baseline Inventory:

Remaining Emissions: ,f Anticipated Reduction:

I

I '...

.. :; *~&+ j E

pom NOx 633% 0, tb NOJMMBtu 30 0.036 40 0.048

NOx - TonslDay 7987 - 1994 - 1997 - 2000 89.16 85.89 87.67 88.49

65.13 66.41 66.98 20.76 21.26 21.51

7 - 27

!

. . 2007027/101/201/301/401/601

1991 AIR OUALITYATTAINMENTPLAN - The emissions reductions shown are based on the ARB Draft BARCT Determination for Boilers, Steam Generators and Process Heaters.

COST EFFECTIVENESS: For retrofit applications, technological feasibility and costs of control are dependent on energy availability, equipment location, type of control, operating capacity modes, and physical size of the heaterlboiler. Thus, some control techniques that are feasible for larger devices may not be practical for smaller devices because of cost or effect on efficiency. Burner replacement may be the most cost effective control technique for smaller boilers. ARB estimates the cost effectiveness of several typical control technologies as shown below. In general, cost effectiveness improves with size of the unit and annual usage rate.

Unit Size Range Cost Effectiveness jMMBtu/hrl ($/ ton NOx reduced)

Low-NOx Burners 25 - 1 5 0 $300 - $27,000

Selective Noncatalytic Reduction 50 - 375 $1,300 - $20,000 Selective Catalytic Reduction 5 0 - 3 5 0 $4,000 - $66,000 ,

Flue Gas Recirculation 10 - 3 5 0 $1,000 - $29,000 . ,

Santa Barbara County APCD estimates cost effectiveness for control of NOx emissions from smaller boilers using radiant burner technology as shown below:

Boiler Size Total Cost Effectiveness JMMBtulhrl Eauioment Cost $/ton NOx reduced

1 $1 8,000 10,000 5 $25,000 3,000 10 $30,000 2,000

Mobil Oil Company has identified the cost o f retrofit o f flue gas recirculation technology for their steam generators to be approximately $36,000 per year per large (62.5 MMBtu/hr) steam generator. This retrofit reduces NOx from a single natural gas-fired generator by about 28 tons per year, for a cost effectiveness of $1,300 per ton of NOx reduced. Mobil Oil's steam generators using flue gas recirculation currently have limits o f 0.04 Ib/MMBtu.

As of June 6, 1991, Kern River steam generator fuels cost $12 per barrel ($1 .9O/MMBtu) for produced oil and $2.75/mcf ($2.60/MMBtu) for produced natural gas. Assuming fuel costs remain constant, switching fuels from crude oil to natural gas to reduce NOx emissions would cost approximately $5,800 per ton of NOx reduced. However, with increased availability, local natural gas prices are

i f .

7 - 28

.. . .: ,

. '2007027/101/201/301/401/601 Page d-5

fl'..,. 1991 AIR QUALITYATTAINMENTPLAN

expected to decrease. Additionally, flue gas sulfur scrubber operational costs, and maintenance'costs associated with burning crude would be almost eliminated.



Phase 1 Phase 2 Phase 3 Phase 4 Draft Rule: 1 Q192 1 Q193 1 0194 1 0195

'Workshop Rule: 20192 2Ql93 20194 20195 Adopt Rule: 40192 4Qi93 40194 40195 Full Implementation: 4Q194 40195 40196 40197

ENFORCEABILITY: Compliance is dependent on initial and annual emissions tests, annual inspections. Requirements for continuous emission monitors 'on large sources, and maintenance of operating logs will enhance the District's ability to enforce any proposed regulation.

TECHNICAL FEASIBILITY AND PUBLIC ACCEPTABILITY: Technology for cerfain combustion devices is currently in use that can achieve the NOx emission standards suggested in the ARB BARCT Determination. Implementation of this measure will be affected by the availability o f clean fuels t o meet fuel conversion demands. Pipeline capacity increases are expected to meet the increase in demand for natural gas. The MojaveIKern River Pipeline project, which is expected t o be completed in 1992, could provide an additional 1.1 billion scf of natural (equivalent to approximately 200,000 barrels of oil) gas per day. Public acceptability is expected t o be neutral.

HEALTH, ENVIRONMENTAL, ENERGY, AND SOCIAL IMPACTS: Spent catalyst materials, including vanadium pentoxide, are considered hazardous materials and would have t o be deposited in a Class I landfill; the only operational Class I disposal site in California is in Kings County. Ammonia emissions may occur i f SCR or SNCR is used. Combustion of natural gas in place of residual, distillate or crude oil will result in lower toxic, carbon dioxide, particulate and SO2 emissions. Additional electrical energy will be required t o operate all control systems. The control measure will encourage natural gas fuel use over fuel or crude oil.

t &> f i.

7 - 29

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

. .2007027/101/201/301/401/601

.">._.., 1991 AIR QUALITYATTAINMENTPLAN

Switching from crude or fuel oil combustion to combustion of natural gas will reduce emissions of polycyclic aromatic hydrocarbons and toxic metals, some of which are known carcinogens. Minor increases in emissions o f benzene and formaldehyde may result from the increased use of natural gas.


Air Resources Board. Draft Prooosed Determination of Reasonablv Available

lnsfitutional and Commercial Boilers, Steam Generators and Process Heaters. 1991.

j L

Air Resources Board. 1989. Emissions Inventory Criteria and Guidelines Regulation Pursuant t o the Air Toxics "Hot Spots" Information and Assessment Act of 1987. Sacramento, California.


Brinkman, P. E., Mobil Exploration and Production Company. 1990. Letter to Scott Nester, Kern County APCD. June 20, 1990.



Pease, Robert R., Martin L. Kay, Andrew Y. Lee. "Industrial Boilers: Status of . Oxides of Nitrogen Regulations and Control Technology in the South Coast Air

Quality Management District", 1989, Annual Meeting and Exhibition, Air and Waste Management Association, June 1989.


. . .... : :. . .. .. -*>

South Coast Air Quality Management District. Best Available Control Technoloav Guideline. October 1988.

7 - 30

i

. ~ ~ 0 7 ~ 2 7 / ~ 0 1 / 2 0 1 / 3 0 1 / 4 0 1 / 6 0 1 . . Page 'u-7

199 I AIR QUALITY A TTAINMENT PLAN 5. *..

rc

South Coast Air Quality Management District. Rule 1109 - Emissions of Oxides of Nitrogen from Boilers and Process Heaters in Petroleum Refineries. August 5, 1988.


South Coast Air Quality Management District. Draft Rule 11 77 - Best Available Fuel Standard. 1991

South Coast Air Quality Management District. 1989 Air Qualitv Manaoement Pkn, "Appendix IV-A: Tier I , Tier I I and Contingency Control Measures". March 1989.


US Environmental Protection Agency. 1985. Comoilation of Air Pollutant Emission Factors, Fourth Edition. Research Triangle Park, North Carolina.

.cc, ..I. . *:; .. . . . . . .


SCC

10200401 10200402 10200403 10200501 10200502 10200503 10200601 10200602 10200603 10200701 10200799 10200902 10201002 10201201 10300401 10300402 10300501 10300502 10300503 10300601 10300602 10300603 30290003 306001 01 30600103 30600104 30600105 30600106 31000402 31000403 31000404 3100041 1 31000412 31000414 39000499 39000599 39000603 39000689 39000699 39000889 39001099

CES

47142 471 59 471 67 58727. 66795 66803 82073 82081 83071

7 - 3 1

Sari Joaquin Valley


R i c k Jensen Chair Supervisor Madera County Pauline Laroood Vice Chair

Unified Air Pollution Control District October 22, 1992

Mr. Raymond Menebroker, Chief California Air Resources Board Project Review Branch Stationary Source Division P.O. Box 281 5 Sacramento, CA 9581 2

Supervisor Kern County

Blair Bradley Councilmember City of Ceres Doug Vagim Supervisor

Re: AoDlication #2007027/1011201/304/401 I 601 Proiect DescriDtion: Emission Reduction Credit IERC) Certificate for Emission Reduction from the Removal o f Incinerator ID# 16M101

Fresno County

City of Fresno

Kings County

Supervisor Merced County

San Joaquin county

Supervisor Stanislaus county

- Supervisor Tulare County

Councilmember City of Wasco

Tom Bohigian Councilmember Dear Mr. Menebroker:

Supervisor Joe Hammond

Enclosed for your review and comment is the analysis o f Texaco Refining and Marketing Inc. request for emission reduction credits.

This project will be released to public notice approximately three days from the date of this letter. This will start the 30-day public

Mike Bogna

Bill Sousa

Nick Blom period comment period.

Clyde GOuld

Me1 McLaughlin review and consideration.

Supervisor

Please submit your written comments on our analysis and draft documents as soon as possible to provide ample time for our

Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of the Engineering Evaluation Section at (805) 861 -3682.


c: Tom Goff - Permit Services Manager/Southern Region

David L. Crow - Executive Dlrector/APCO Po Box 1312 - Fresno, CA 93715 - 1999 Tuolunme Street. suite 200 - (209 ) 497-1000 - FAX (209) 233-2057


October 22, 1992

DISTRICT Mr. Mat Haber, Chief MEMBERS U.S. EPA - Region IX

New Source SectionlA-5-1 Chair 75 Hawthorne Street

San Francisco, CA 94105

Re: Aoolication #2007027/101/201/304/4011601

BOARD

Rick Jensen

Supervisor Madera county Pauline Lamood Vice Chair Supervisor

Blair Bradley CouncilmemBer

Kern County Proiect DescriDtion: Emission Reduction Credit (ERCI

City of Ceres

Fresno county Dear Mr. Haber:

Certificate for Emission Reduction from the Removal o f Incinerator ID# 16M101

Doug Vagim Supervisor

Tom Bohigian Councilmeuber

Joe City Hammond O f Fresno Enclosed for your review and comment is the analysis of Texaco Refining and Marketing Inc. request for emission reduction credits.

This project will be released to public notice approximately three days from the date of this letter. This will start the 30-day public

Supervisor

Supervisor

Supervisor period comment period.

Supervisor

Clyde Gould Supervisor review and consideration.

Kings County

Merced County

San Joaquin County

Stanislaus county

Tulare County


Mike B o w

Bill Sousa

Nick Blom Please submit your written comments on our analysis and draft documents as soon as possible to provide ample time for our

Me1 McLaughlin Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of the Engineering Evaluation Section at (805) 861-3682.

Sincerely,

M L SeyLd Sadredin Director of Permit Services

c: Tom Goff - Permit Services Manager/Southern Region

David L. Crow - Executive Director/AF'CO PO Box 1312 - Fresno. CA 93715 - 1999 Nolunne street, suite 200 - (209) 497-1000 - FRX (209) 233-2057


Rick Jensen Chair Supervisor Madera County Pauline Larxood Vice Chair Supervisor Kern County Blair Bradley Councilmember City of Ceres Doug Vagim Supervisor Fresno County

Tom Bohigian Councilmember City of Fresno Joe Hammond Supervisor Kings County

Supervisor Merced Countv

Mike B o w

-

Sari Joaquin Valley Unified Air Pollution Control District

October 22, 1992


Re: ADDliCatiOn #2007027/1011201l304/401 I601 Proiect Descriotion: Emission Reduction Credit (ERCI Certificate for Emission Reduction from the Removal o f Incinerator ID# 16M101

Dear Mr. Slack:

Enclosed for your review and comment is the draft notice and engineering analysis of preliminary decision to approve Emission Reduction Credits for the shutdown of incinerator ID# 16M101 located in Area 1 of the Texaco Refinery. ~1

Bill Sousa Supervisor San Joaquin County

Supervisor Stanislaus County

Supervisor Tulare County


Nick Blom

Clyde Gould

Me1 McUlughlin

This preliminary decision will be noticed in the newspaper approximately three days from the date of this letter. Publication will start a 30-day public comment period,

Please submit any written comments you may have concerning this preliminary decision before the close of the public comment period.

Thank you for your cooperation in this matter. Should you have any questions, please telephone Mr. Glen E. Stephens of the Engineering Evaluation Section at (805) 861 -3682.

Sincerely,

Seyed Gdredin Director o f Permit Services

c: Tom Goff - Permit Services ManagerlSouthern Region - - David L. Crow - Executive Director/APCO

PO Box 1312 - Fresno. CA 93715 - 1999 Tuolumne Street, Suite 200 - (209) 497-1000 - FAX (209) 233-2057

i

REQUEST FOR PUBLIC COMMENT ON PROPOSED STATIONARY SOURCE EMISSIONS REDUCTION CREDITS (ERC)

Pursuant to Rule 230.1 of the San Joaquin Valley Unified Air Pollution Control

District Rules and Regulations, the Air Pollution Control Officer has made a

preliminary decision to approve emission reduction credits no greater than 1,776

Ibslqtr of NO,, 801 lbslqtr of PM,,, 5,695 lbslqtr o f CO, 69,141 Iblqtr of SO, and

975 of SO, resulting from the removal of a tailgas incinerator serving the sulfur

recovery operation tailgas treating unit at the Texaco Refinery slo Rosedale Hwy.

in Bakersfield.

Public comments regarding this preliminary decision will be received by the District

for a period of thirty (30) days after publication of this notice and will receive due

consideration before final action is taken.

The application for emission reduction credits, support documents and the

District's air quality impact analysis for project 4091 920620 are available for

inspection at the Southern Region office with Glen Stephens located at 2700 "M"

Street, Suite 275, Bakersfield, California 93301, (805) 861 -3682.

2007027/101/201/301/401/601 Page 1

ERC APPLICATION REVIEW

Glen E. Stephens App. Rec.: 07/15/92 Date: 09/22 /92

Facility Name: TEXACO REFINING AND MARKETING INC.

Mailing Address: P.O. Box 1476 Bakersfield, California 93302

Applicant Name: Donald J. Slack, Supervisor Environmental, Safety & Health

Contact Name: Steve Powell Phone Number: (805) 326-4426

Application: 2007027/101/201/301/401/601 Project #: 920716

Deemed Complete: 08/17/92 Reviewed by: Submittal Date:

Review Date:

I. SUMMARY:

Texaco Refining and Marketing Inc. (TRMI) has removed from operation the tailgas incinerator listed as item I'jll on Permit to Operate (PTO) 2007027A (see Attachment A). The tailgas normally burned in the incinerator listed on PTO 2007027A has been permanently diverted to a new tailgas treating unit, included on permit 2007245 (see Attachment A) as "Tail Gas Treating Unit". The removal of the old tailgas incinerator was authorized by ATC 2007027B (see Attachment A). Authority to construct for the new unit was not based on offsets to be provided for by the removal of the old tailgas incinerator listed on 2007027A. Texaco has applied to bank the emissions from the tailgas incinerator as an Emission Reduction Credit (ERC) Certificate pursuant to Rule 230.1 Subsection 1V.B. Historic Actual Emissions have been adjusted for 10% to be deposited to the Community Bank. The following emission reductions have been found to qualify for banking:

(in Lbs/Ouarter)

2007027/101/201/301/401/601 Page 2

11. APPLICABLE RULES:

A. Rule 220.1: (New and Modified Stationary Source Review Rule -- post 0 9 / 1 9 / 9 1 , revised 0 3 / 1 1 / 9 2 )

0 9 / 1 9 / 9 1 , revised 0 3 / 1 1 / 9 2 ) B . Rule 230 .1 : (Emission Reduction Credit Banking -- adopted

C. Rule 230.2: (Community Bank -- adopted 0 9 / 1 9 / 9 1 , revised 0 3 / 1 1 / 9 2 )

111. PROJECT LOCATION:

NW Section 2 7 , Township 29 South, Range 27 East MDB&M 6 4 5 1 Rosedale Highway., Area 1 of Texaco Refinery

IV .

V.

VI.

METHOD OF GENERATING REDUCTIONS:

Tailgas previously burned in incinerator has been permanently diverted to new unit (ATC 2007245 -- tail gas treating unit). No emission reductions for the removal of the old tailgas incinerator were used for the approval of the new unit.

EOUIPMENT LISTING:

1 - Tailgas incinerator, 16-M101 -- removed from service See Attachment A for copies of PTO to be revised and ATC's to modify PTO 82007027A and for the new tailgas treating unit (ATC # 2 0 0 7 2 4 5 ) . These ATC's have been implemented and new permits are being prepared.

CONTROL EOUIPMENT EVALUATION:

The emission reductions were generated by equipment being taken out of service, and not by the addition of control equipment. Therefore, no control equipment evaluation is required.

VII. CALCULATIONS:

A. General:

Calculations will summarize the Historical Actual Emissions (HAE). Historical Actual Emissions for each quarter in the baseline period are calculated using fuel usage data (total offgas to claus furnace) and source test emission factors for each air contaminant. Source test data is summarized in Attachment B.

2007027/101/201/301/401j601 Page 3

B. Fuel ConsumDtion Data:

The data below is derived from applicant supplied data. The applicant supplied data is the average hourly volumetric Offgas gas flow to the incinerator for destruction (see Attachment B). The quarterly fuel use were obtained by by the following calculations:

Mscfjhr - 24 hrjday - 30 daysjmonth' = Mscfjmonth Mscf /month * 90 days /quarter2 = Mscf /quarter

The following represents the results of the calculations:

Jan-Mar Apr-Jun Jul-Sept Oct-Dec Averaae Ouarterlv Fuel Use fin MscflOuarter)

Adjustments were made to applicant supplied data (March '90 data was not used) because month identified did not coincide with 8 consecutive calendar quarters preceding the application for ERC banking Certificate.

C. Emission Factors:

Incinerator was source tested (District witnessed source test) on December 20, 1991; the results of the source tests (Verified by District staff) are listed below. However, the PMIO factor

factor must be reduced by the SO includes SO4 emissions as the total PMlO.

SO4 emissions separately. the source test factors.

factor to represent PM1 an Therefore,

The a%justed factors are liste8 below

Emission Factors From Source Tests (in LbsiMscf)

adjusted Emission Factors Used (in LbsfMscfl

D. Historical Actual Emissions (HAE):

Based on the emission factors used. The product of the emission factors and the actual fuel used results in the historical actual emissions. Calculations to show W E , adjustments and actual

30 daysjmonth used as an example. Actual daysjmonth for each month was used.

90 days/month used as an example. for each quarter

Actual daysjmonth used

2007027/101/201/301/401/601 Page 4

emission reductions (AER) to be banked are included in Attachment C. HAE for each quarter are as follows:

Qua Historical Actual Emissions (in LbsIOuarter)

Jan - Mar

E. Adjustments to Initial Emission Reductions:

1. Earlv ImDlementation of BARCT:

In the San Joaquin Valley Unified Air Pollution Control District 1991 Air Quality Attainment Plan (AQAP) there are proposed measures for the control of NO, emissions from external combustion sources. The section titled External Combustion Devices -- Boilers, Steam Generators, Process Heaters, Driers in the AQAP (see Attachment D) proposes NO, control measures and lists SCC and CES codes for external combustion devices. Two of the SCC and CES codes listed in the above mentioned section apply to process gas incineration at a petroleum refinery source (SCC and CES codes 102007001 and 82081 respectively). However, the proposed removal of the incinerator was approved by Authority to Construct (April 18, 1991) prior to the issuance of the AQAP (January 30, 1992); therefore, a 75% HAE NOX reduction, because of early implementation of BARCT (see Rule 220.1.V.B), is not required.

2. ::

Rule 220.1.V1., states a portion of all onsite actual emissions reductions created after the adoption of Rule 220.1 (September 19, 1991) shall be used to fund the Community Bank and 10% of AER shall be deposited to the Community Bank; remaining AER qualifies for the ERC Certificate:

For DeDOSit into the Communitv Bank fin LbstOtr) Ouarter PM. ,-. so 1 so.. NO, - co , ,

IOct - Dec I 89.01 1 108.37 11 7682.34 11 197.38 11 632.78 11

* 2007027/101/201/301/401/601 Page 5

For Deposit into the Communitv Bank (in LbsIDav)


The HAE less the community bank adjustment and adjusted for the portion of SO4 included in the PMIO emission factor gives bankable emission reductions of:

Bankable Emission Reductions (in LbsIOtrL

VIII. COMPLIANCE:

A. Rule 220.1:

1. Baseline Period:

During the processing of the ERC application, the baseline period was evaluated to assure compliance with Rules 220.1.11.F. and 230.1.V.E. The baseline period (8 calendar quarters) used ends within 180 days of the removal of the old incinerator (e.g. April ‘90 - March ‘92) and, therefore, complies with Rules 220.1 and 230.1 requirements.

2. Calculations:

Community Bank allotment was deducted from the AER as prescribed in Rules 220.1.VI and 230.2.IV. Calculations in determining the AER were used as described in Rule 220.1. ERC complies with Rule 220.1.V.E.2.

. 3d07027/101/201/301/40~/601 Page 6

B. Rule 230.1:

The ERC application, eligibility and registration are all completed according to the requirements of Rule 230.1. applicant has demonstrated the ERc to be valid by the definition in Rule 230.1.III.G.:

1. Real: The old incinerator did exist and was operated and

The

had actual emissions at the location specified.

2. Surplus: The old incinerator has been replaced by a new incinerator (included on permit 2007245 -- see Attachment A). All emission increases from the new incinerator and associated equipment have been assessed under new source review. No emission reductions from the removal of the old incinerator were required for approval of emission increases from the new incinerator or for the approval of any other emissions unit.

3. Permanent: The incinerator has been taken out of service and rendered inoperable.

4. Quantifiable: Emissions were quantified by actual fuel use data and source tests determined the emission factors that were used. HAE were discounted where a prohibitory rule or permit condition resulted in less emissions.

5. Enforceable: Permit to Operate 2007027A includes incinerator (16-M101) as part of the equipment on the subject PTO. On ATC 2007027B incinerator 16-MlOlhas been removed and tailgas normally exhausted to the incineration Unit is now required to exhaust to the new Tail Gas Treating Unit listed on ATC 2007245. Location can be inspected for equipment operating without valid a PTO or ATC.

6. Timeliness: Application was submitted with in 180 days of when the reduction actually occurred.


C. Rule 230.2:

The 10% deductions from the AER's were made for the Community Bank and will be deposited to the Community Bank upon issuance of the ERC.

IX. RECOMMENDATION:

Upon completetion of 30 day public notice period issue Emission Reduction Credit Certificates S-0002-2, / - 3 , I - 4 , '-5 and I-6.

District Board Members RICK JENSEN, Choir

PAULINE IARWOOD. V i r h i r S u p n W , M a Cmty

Supm;sor, Kern Counfy BILLSOUSA

CmniJmemkr, Cily o f k 5 MIKEBOGNA

DOUG VAGlM

TOM STEARNS

IOEHAMMOND

Super&. Merrd Cmty

S u p & , Frano Covnly

C ~ ~ n c J m e m k r , City of Cld

Super&, Kings Comfy CLYDE GOULO

s"pemisor, Tvhn Covn1y hlEL McIAUGHLIN Cmn~dmnnhr, City of Wnvo


Southern Region 2700 "M" Street, Suite 275

Bakersfield, California 93301

- Stanislaus

Tulare

(805) 861-3682 \L_l

August 17, 1992



Certificate for Emission Reduction from the Shut Down of Incinerator ID# 16M101

Dear Mr. Slack:

Your application for ERC Certificate for the above-referenced project has been received by the Air Pollution Control District, and has been reviewed for completeness.

Based on this preliminary review, the application appears to.be complete. However, because emission reductions are quantified on a calendar quarter basis, to obtain full emission reduction credit from the shut down, you must provide operational data for March 1992, because January - March is one calendar quarter. Please be aware that during the processing of this application, the District may request additional information to clarify, correct or otherwise supplement the information on file.

Thank you for your cooperation. please telephone Mr. Thomas Goff of Permit Services at (805) 861- 3682.

Sincerely,

Seyed Sadredin District Manager of Permit Services

b

Should you have any questions,

Thomas E. Goff, P.k. Permit Services Manager

GES

David L G o w Executive Director I APCO P.O. Box 1312 * Fresno, California 93715 2314 Mariposa Street #I00 (209) 488-3330 FAX (209) 488-3134

@ Pdnd on recycbc papa.

Donald R Hail Texaco Refining & Post Office Box 1476 Bakersfield CA 93302 8053264232 Plant Mana er Marketing Inc

Bakersfield%ant

July 9, 1992

Mr. Tom Goff Permit Services Manager San Joaquin Valley Unified APCD 2700 "M" Street, Suite 275 Bakersfield, CA 93301

Dear Mr. Goff:

Attached is a banking certificate application form and a check for $650 to cover filing fee costs. A banking certificate is requested for emission reductions resulting from the shutdown of the SRU #1 incinerator (2007027). The incinerator was shutdown in March, 1992. Emission reductions are based on the previous two years operating data and a source test performed on December 20, 1992.

If you ha;e any questions concerning this application, please contact Steve Powell at 326-4426.

Sincerely,

D. R. Hall

SGP/lam 15/92 Enclosures

File: 34040-206


1601 "H" Stree1,Suite 150 Bakercfitld, Cdlifornir 93301 Telephone: (8051 861.3682 .\

'"<) , -' 1 '

s 9. T Y P W R P R l N f NAME OF SIGNER:

9 m Q f J 3r: 5h-dc

APPLICATION FOR:

TITLE OF SIGNER:

5&Quv;sw - E f f p . 3 DATE. PHONE NO.:

$4y?z (Bas) 3z-4253-

0 Authority to Construct IATCl 0 Permit to ~ p e r s t s (PTO) Banking Certificate

0 ATC - Modification 0 PTO - Modiflcation 0 Transfer of Location

0 ATC - Renewal 0 PTO -Transfer of Ownership J 4207 f 6 A N APPLICATION IS REOUIRED FOR EACH SOURCE OPERATION AS DEFINED IN RULE 102. SECTlONcc.

1. PERMIT TO BE ISSUED TO: . Name of organization to operate the following equipment:

Texaco Refining and Marketing, Inc. . 2. MAILING ADDRESS:

P. 0. Box 1476. Bakersfield, California LOCATION A T WHICH THE EOUIPMENT IS TO BE OPERATED:

6451 Rosedale Highway, Bakersfield, California

Z i p m e : 93302 3.

93308

4. GENERAL NATURE OF BUSINESS:

Petroleum Refining EOUIPMENT FOR WHICH APPLICATION IS MADE: 5.

Banking certificate application shutdown of SRU #1 Incinerator 16M101

Provide additional information as required by District "Instructions'*.

6. TYPE AND ESTIMATED COST OF AIR POLLUTION CONTROL EQUIPMENT:

7. TYPE AND ESTIMATED COST OF BASIC PROCESS EOUIPMENT:

INTRODUCTION:

The tailgas incinerator 16-M101, was used to incinerate tailgas from Sulfur Recovery Unit #1 (ATC #2007027), located at the Area 1 facility. In March, 1992, tailgas from SRU #1 was permanently diverted to a new tailgas treating unit (ATC #2007245), and 16-M101 was shutdown. Texaco Refining and Marketing Inc., is requesting that a banking certificate be issued for the PMIO, S04, S02, NOX, and CO emission reductions resulting from the shutdown of 16-M101.

CALCULATION PROCEDURE:

Emissions are based on the previous two year operating history and a source test performed on December 20, 1991. See. the attached spreadsheet and test report for details.

REQUIRED FINDINGS:

I . Application must be submitted within 180 days of reduction:

2.

The tailgas incinerator was shutdown in March, 1992. This application will be submitted in July, 1992. The application meets the 180 day deadline.

Emissions must be real, surplus, permanent, quantifiable, and enforceable:

The emissions are real and quantifiable based on the emissions test and operational data supplied.

The emissions are surplus as the reductions were not required by any rule or regulation, or by any permitting action.

The emission reductions are permanent and enforceable as incinerator 16M101 is inoperable and both SRU #1 and the new tailgas treating unit are under District permit.


2700 "M" STREET, SUITE 275 BAKERSFIELD. CA. 93301

PERMIT TO OPERATE TELEPHONE: (805) 861-3582

Number: 2007027(A)

PERMIT TO OPERATE IS HEREBY GRANTED TO: TEXACO REFINING & MARKETING INC


EQUIPMENT OR PROCESS DESCRIPTION: Claus/ATS Sulfur Recovery Plant Unit #I6


THIS PERMIT BECOMES VOID UPON ANY CHANGE OF OWNERSHIP OR LOCATION, OR ANY ALTERATION.

NOTE: The permittee may be required to provide adequate sampling and testing WILLIAM J. RODDY facilities, Equipment modification AIR POLLUTION CONTR,OL-OFF I CER requires a new permit. ---_ ,..->

I ',! ., .-/=> REVOCABLE: This permit does not authorize By: i 1 0

the emission of air contaminants in excess \ C----*

'.-' ( c, of those allowed by the Rules and Regulations of the K.C.A.P.C.D. For Period: 08-31-90 TO 06-31-91

CONDITIONAL APPROVAL: Compliance with all conditions of approval imposed by any applicable Authority to Construct is required for life of this equipment unless modified by application.

EQUIPMENT DESCRIPTION: Claus/ATS Sulfur Recovery Plant Unit #16. including the following equipment:

a. b.

d . e. f. g. h. i. 1. k. 1. m. n.

C.

Sour water stripper overhead knockout drum, Amine solution H2S knockout drum, Muffle furnace, 16-P-1. First stage reactor, Secbnd stage reactor, Sulfur condenser, 16-V103. Sulfur storage tank, 16-T101. Primary reactor (ATS). Secondary reactor (ATS), Tailgas incinerator. 16-M101. ATS storage tank. 16-T3. Miscellaneous vessels, heat exchangers and pumps, Ammonia storage tank. Piping from sour gas oulet of MEA Regenerator (2007204) t o Claus plant inlet piping.



SO2 - 506.4 lbm/hr. NO2 - 140.4 lbm/hr. and PM - 40.3 lbm/hr. If EMS is not operational, Claus ATS Sulfur Recovery Plant Unit #I6 emissions shall not exceed the following rates: SO2 - 40.0 lbm/hr. NO2 - 0.8 lbm/hr, and PM - 1.7 lbm/hr. (All EMA

2. Entire refinery emissions, as determined by EMS. shall not exceed the following rates:

t.


rates are to be one hour averages).

inspection by District staff upon notice.

( o r R#1) for any more than an aggregate of three minutes in any one hour.

0.1 gr/scf calculated to 12% C02.

2000 ppm by volumne and shall be monitored and recorded.

necessary to operate units in manner recommended by manufacturer.

12oOOP and shall be monitored and recorded.

Ibm/day without prior District approval. (Rule 210.1 and 210.3)

Marketing, Inc. to not exceed 20.0 long tons per day o r immediate compliance with Rule 424 is required. (Rule 424)

recorded. (Rules 108 and 209)

419)

3. EMS printout demonstrating compliance with Condition #2 shall be made available for

4. Visible emissions from any single emission point shall not equal o r exceed 20% opacity

5 . Combustion contaminating emissions from any single emission point shall be less than

6 . Tailgas incinerator exhaust gas sulfur compounds concentration (as S02) shall ot exceed

I. Claus plant and ATS plant components shall be equipped with temperature indicators as

8 . Tailgas incinerator burning chamber temperature shall be maintained at no less than

9 . Hydrocarbon emissions from whole-refinery stationary source shall not exceed 2,476.9

10. Sulfur processing capacity o f Claus plant shall be documented by Texaco Refining 8,

11. Claus/ATS effluent sulfur compounds content shall be continuously monitored and

12. Operation shall not result in odors detectable at or beyond property boundary. (Rule

13. All connectors and pjping shall be vapor-tight. (Rule 210.1)


Sulfur Compounds: 40.00 Ibm/hr (as SO2) (Rule 210.1)

TEST bATE OPERATIONAL DATA ~&E'M:BER 20, 1991

iAS TO CLAUS FURNACE MSCFHR

34.16

6FHS302 TOTAL OF TIME

1200 1300 1400 1500 1600 1700 1800 1900


PARTICULATE 1.02 0.030 L B ~ H R ILBMSCFHR

AVG

MSCFHR QUARTERLYAVERAGE

32.46 33.12 33.84 34.20 34.39 34.03 34.03

PARTICULATE SULFATE s o 2 NOX co

SULFATE s o 2 NOX co

1 2 3 4

19.94 20.64 19.41 21.44 10.95 11.33 10.65 11.77

775.93 803.34 755.29 834.65 19.94 20.64 19.41 21.44 63.91 66.17 62.21 68.75

0.56 39.70

1.02 3.27

33.78

PRECEDING 2 YEARS OPERATIONAL DATA

MAY

AUG SEP OCT NOV DEC

1990

18.82 22.63 26.19 28.95 27.50 28.86 28.84 30.16 24.81 21.71

1991 1992 30.82 1 30.89 23.26 30.80 30.46 32.68 27.33 32.50 33.23 32.22 10.01 30.52 31.63 32.71

MSCFHR 1 27.51 2 28.48

1 3 26.78

0.017 1.175 0.030 0.097

EMISSION OFFSET STUDY SULFUR PLANT INCINERATOR

December 20, 1991

Prepared f o r

Texaco Refining & Marketing, Inc. 6451 Rosedale Highway

Bakers f ie ld , C a l i f o r n i a 93308

January 1992

Prepared by

. S t e i n e r Environmental, Inc. 4930 Boylan S t r e e t

Bakers f ie ld , C a l i f o r n i a 93308

Report PS-92-2677/Project 7123-92

TABLE OF CONTENTS

S e c t i o n P a g e

. . . . . . . . . . . . . . . . . . 1 INTRODUCTION 1-1

2 TEST MATRIX 2-1

3 T E S T R E S U L T S 3-1

4 SAMPLING EQUIPMENT AND PROCEDURES . . . . . . . 4- 1

. . . . . . . . . . . . . . . . . .

. . . . . . . . . . . . . . . . . .

5 ANALYSIS PROCEDURES . . . . . . . ': . . . . . . 5- 1

6 QUALITY ASSURANCE . . . . . . . . . . . . . . . . 6- 1

APPENDIX A . STEINER ENVIRONMENTAL RAW DATA . . A- 1

ii

. .

SECTION I

INTRODUCTION

At the request of Texaco Refining & Marketing, Inc., Steiner

Environmental, Inc. conducted an emission offset study on the existing

sulfur plant incinerator on December 20, 1991. The purpose of these

tests was to determine particulate and gaseous emission rates before

this incinerator is shut down and the new incinerator i s started up.

Triplicate EPA Method 5/8 tests were conducted to measure partic-

0 ulates, sulfates and SO,. Triplicate CARB Method 1-100 tests were

conducted to monitor NO,, CO, CO, and 0,.

Section 2 of this report presents the test matrix for this

program.

1-1

SECTION 2

TEST MATRIX

Table 2-1 presents t h e t e s t m a t r i x f o r t h i s program. P a r t i c u l a t e

Test #1 was n o t inc luded i n t h i s study because t h e quar t z sampling nozz le

was broken d u r i n g the t e s t .

Sec t i on 3 o f t h i s r e p o r t presents t h e t e s t r e s u l t s .

TABLE 2-1. TEXACO INCINERATOR TEST MATRIX

Test No. Test Parameter Test Time - Date

12/20/91 1 N O x / C O / C O ~ / O z 12:50 pm - 1:50 pm

2 NOx/CO/COz/Oz 2:30 pin - 3:30 pm

2:30 pm - 4:40 pm

3 N O x / C O / C O z / O ~ 5:30 pm - 6:30 pm

5:35 pm - 7:45 pm

Particulates/Sulfates/SO,

Particulates/Sulfates/SO,

2-1

SECTION 3

TEST RESULTS

Tab le 3-1 summarizes t h e r e s u l t s o f t h e emiss ion o f f s e t t e s t s

per fo rmed on t h e e x i s t i n g s u l f u r p l a n t i n c i n e r a t o r . A l l d a t a a r e

r e p o r t e d a t 60°F and 29.92. i nches Hg.

3-1

TABLE 3-1. SUMMARY OF SOURCE EMISSION TEST DATA (60°F)

U n i t Tested: Texaco R & M Date: December 20, 1991.

Test Number 1 2 3 Average Test Cond i t i on O f f s e t O f f s e t O f f s e t

Barometr ic Pressure ( i n . Hg) 29.90 29.90 29.88 29.89 Stack Pressure ( i n . Hg) 29.88 29.88 . 29.86 29.87 Stack Area (ft') 4.91 4.91 4.91 4.91

Volume Gas Sampled ( d s c f ) 90.541 90.541 89.299 90.127

0 SRU I n c i n e r a t o r '

Elapsed Sampling Time (min.) 120.00 120.00 120.00 120.00

0

GAS DATA

Average Gas V e l o c i t y ( f p s ) 44.75 Average Gas Temperature ( O F ) 957.17 Gas Flowrate (dscfm) 4,460 Gas Ana lys i s (Volume %)

Carbon Diox ide, d r y 5.00 Oxygen, dry 5.23 Water 7.66


F i l t e r a b l e P a r t i c u l a t e ( g r / d s c f ) To ta l P a r t i c u l a t e ( g r / d s c f ) To ta l S u l f a t e ( g r / d s c f ) co (PPm) 131.50

NO, (PPm) 36.75 SO2 (PPm)

EMISSION RATE - l b / h r

F i l t e r a b l e P a r t i c u l a t e Tota l P a r t i c u l a t e To ta l S u l f a t e co 2.60

1.19 SO2

NO,

44.75 957.17 4,460

4.98 5.08 7.66

0.0353 0.0485 0.0176 157.54 839.63 32.73

1.35 1.85 0.67 3.11

37.94 1.06

44,88 44.80 959.08 957.81 4,536 4,485

4.97 4.98 5.36 5.22 .6.14 7.16

0.0180 0.0267 0.0300 0.0392 0:0115 0.0146 204.77 164.60 902.30 870.97 24.68 31.39

0.70 1.02 1.17 1.51 0.45 0.56 4.11 3.27 41.46 39.70 0.81 1.02

3-2

,

SECTION 4

SAMPLING EQUIPMENT AND PROCEDURES

This s e c t i o n o f t h e r e p o r t descr ibes t h e equipment and procedures

used t o conduct t h e p a r t i c u l a t e t e s t s on t h i s program.

4 . 1 PRELIMINARY MEASUREMENTS

Before conduct ing the s tack t e s t s a s e r i e s o f p r e l i m i n a r y measure-

ments were made t o determine:

I The l o c a t i o n o f t he sampling s i t e and the number and l o c a t i o n

o f t he sampling p o i n t s t o be used (EPA Method 1)

I The v e l o c i t y , temperature, and pressure o f t he gases i n the

s t a c k (EPA Method 2)

I The composi t ion o f t h e stack gases (EPA Method 3)

I

Using t h e r e s u l t s o f these p r e l i m i n a r y measurements and t h e

The mois ture content o f t he s tack gases (EPA Method 4 )

c a l i b r a t i o n constants f o r t he sampling t r a i n , a s e r i e s o f c a l c u l a t i o n s

were made t o determine t h e va lue o f K, a constant , and N,, i d e a l nozzle

diameter, r e q u i r e d t o r u n an i s o k i n e t i c t e s t accord ing t o t h e equat ion:

4- 1

where

An a c t u a l nozzle, whose diameter was as c lose as p o s s i b l e t o the

i d e a l nozz le diameter, was se lected f o r t h e t e s t . l s o k i n e t i c sampling

r a t e s f o r each sampling p o i n t i n t h e s tack were computed us ing t h e

\ equat ion:

Since K and N, are known, and remain constant d u r i n g a t e s t , t h e on ly

v a r i a b l e s a r e t h e meter temperatures, t he s tack gas temperature and the

v e l o c i t y pressure f o r each sampling p o i n t .

4 . 2 PREPARATION OF THE PARTICULATE-SO, SAMPLING TRAIN

A l l sampling t r a i n components were c leaned i n the l a b o r a t o r y

(soap and water, t ap water r i n s e , d i s t i l l e d water r i n s e , and I P A r i n s e )

t o e l i m i n a t e prev ious contaminat ion.

sealed and t ranspor ted t o the sampling s i t e i n a mobi le l a b .

Method 5/8 equipment used t o measure p a r t i c u l a t e s ( f i l t e r a b l e and t o t a l )

and SO, c o n s i s t e d o f :

The sampling t r a i n components were

The EPA

I A c a l i b r a t e d 316 s t a i n l e s s s t e e l nozz le f o r i s o k i n e t i c

sampl i n g

A heated Quar t z sampling probe (6 f e e t l ong ) equipped w i t h an

S-type p i t o t tube and a thermocouple t o measure s tack

v e l o c i t y , pressure and temperature

I

4-2

e

*

'I

I

I

a

A heated Pyrex g lass f i l t e r h o l d e r con ta in ing a weighed

100-mm Whatman 934 AH g lass f i b e r f i l t e r

A Pyrex g lass impinger t r a i n i n an icebath ( imp inger 1

conta ined 100-ml 80% I P A ; a Pyrex g lass f i l t e r h o l d e r

c o n t a i n i n g a 47-mm Whatman 934 AH f i l t e r ; bubb ler 2 and

impinger 3 each conta ined 100-in1 o f 3% H202; bubb ler 4

conta ined a weighed amount o f s i l i c a g e l )

An u m b i l i c a l t o connect t he probe and sample box t o t h e

c o n t r o l module

A c o n t r o l module con ta in ing a vacuum pump, a c a l i b r a t e d dry

gas meter and a c a l i b r a t e d o r i f i c e meter t o measure the

pressure, temperature and f l o w r a t e throughout t h e t r a i n .

\

The sampling t r a i n was charged i n t h e mobi le l a b us ing f r e s h l y

Each impinger and i t s con ten ts was weighed t o the prepared reagents.

nearest 0.1 gm on a c a l i b r a t e d e l e c t r o n i c balance.

and reagents were r e t a i n e d f o r subsequent ana lys i s .

l o c a t i o n s were marked on t h e probe using a high-temperature marker. The

sampling t r a i n was completely assembled and l i f t e d t o t h e sampling s i t e .

Blanks o f a l l f i l t e r s

The sampl ing p o i n t

4.3 SAMPLING PROCEDURES FOR PARTICULATE-SO, SAMPLING TRAIN

P r i o r t o a t e s t , t h e sampling t r a i n was heated and leak-checked a t

15-inches Mercury t o i nsu re leakage was l e s s than 0.02 o r 4% o f t he

average sampling r a t e .

sampling t ra in 'was i n s t a l l e d on t h e u n i r a i l and t h e probe was i n s e r t e d

i n t o t h e s tack a t t he f a r t h e s t p o i n t . An i s o k i n e t i c sampling r a t e was

c a l c u l a t e d us ing an HP-41CV c a l c u l a t o r f o r each sampling p o i n t on the

t r a v e r s e ( 6 p o i n t s per t raverse ; 2 t r ave rses a t 90"). Each p o i n t was

sampled f o r an equal p e r i o d o f t ime (10 minutes) and a l l p e r t i n e n t da ta

The S-type p i t o t tube was a lso leak-checked. The

0

4-3

were recorded on the da ta sheet f o r each p o i n t .

were mainta ined a t 250°F throughout the t rave rse .

impinger t r a i n were mainta ined a t ~ 3 8 ° F .

probe was withdrawn from t h e s tack and t h e e n t i r e sampling t r a i n was

t r a n s f e r r e d i n t a c t t o t h e nex t sampling p o r t . Another t r a v e r s e o f t he

s tack was completed and t h e sampling t r a i n was withdrawn f o r t h e f i n a l

leak-check.

h ighes t vacuum achieved d u r i n g the t e s t .

checked a t t h i s t ime.

a i r f o r 15-minutes us ing t h e h ighes t AH measured du r ing t h e t e s t .

The probe and sample box

The gases l e a v i n g t h e

A t t h e end o f a t raverse , t he

Th is leak-check was performed a t 15-inches Mercury o r a t t h e

The S-type p i t o t tube was a l s o

The sampling t r a i n was then purged w i t h ambient

A f t e r

t h e t r a i n was purged, t h e f i l t e r ho lder and impinger t r a i n were sealed

w i t h aluminum f o i l and lowered t o t h e mob i le l a b f o r sample recovery.

4.4 SAMPLE RECOVERY PROCEDURES FOR PARTICULATE-SO, SAMPLING TRAIN

Sample recovery f o r t he nozz le and probe occurred on t h e s tack.

The nozz le and probe were.brushed and r i n s e d t h r e e t imes us ing ACS

reagent grade acetone i n t o a po lyethy lene sample b o t t l e . Sample recovery

f o r t h e f i l t e r ho lder and impinger t r a i n occur red i n t h e mobi le l a b . The

100-mrn f i l t e r was removed from the 4-inch f i l t e r ho lder and sealed i n i t s

p e t r i d i sh .

pu t i n t o t h e p e t r i d i sh .

The g lass f i b e r s s t u c k ' t o t h e gasket were scraped o f f and

The f r o n t h a l f o f t h e 4- inch g lass f i l t e r

ho lde r was brushed and r i n s e d w i t h acetone.

f rom the icebath , wiped d r y and weighed t o t h e nearest 0.1 gm.

contents o f impinger 1 were t r a n s f e r r e d t o a po lye thy lene sample b o t t l e .

The back h a l f o f t he 4- inch g lass f i l t e r ho lde r , t h e g lass connectors,

impinger 1, and the f r o n t h a l f o f t he 2- inch f i l t e r h o l d e r were r i n s e d

w i t h 80% I P A and the r i n s i n g s were t r a n s f e r r e d t o t h i s same b o t t l e .

Each impinger was removed

The

The

,47-mm f i l t e r f rom the 2-inch, f i l t e r ho lder was sealed i n i t s p e t r i d ish .

4-4

The contents of bubbler 2 and impinger 3 were transferred to a poly-

ethylene sample bottle.

the 2-inch filter holder, bubbler 2, the connector, and impinger 3 were

transferred to this same bottle. All sample bottles and petri dishes

were marked and labeled.

field data sheet was also labeled with the sample ID numbers. The

sampling train was then recharged in preparation for the next test.

4.5 SAMPLING PROCEDURES FOR CONTINUOUS MONITORING

Distilled water rinsings of the back half of

A chain-of-custody log was completed and the

The continuous monitors used in the Steiner Environmental Mobile

Monitoring Lab are shown in Table 4-1.

the continuous monitoring system.

monitor stack gases for NO,, 0,, CO and CO, strictly follow CARB

Method 1-100.

Figure 4-1 is a schematic of

The procedures used to continuously

Sample was taken from the stack (at a single point) using a 316

stainless steel probe. A heated Balston filter holder and fiberglass

filter (99.9999 percent efficiency retention of 0.6 micron particles) was

connected to the outlet of the probe.

heated Teflon sample line (maintained at >250°F) by a Teflon-lined dia-

phragm pump to a 316 stainless steel refrigeration type conditioner

(Hankison Model E-4G-SS). The sample gas was passed through the

Sample gas was transported through

conditioner two separate times under vacuum before entering the pump,

then two additional times under pressure. The clean, dry sample gas

(-35OF) was then transported to the continuous analyzer system through

an unheated Teflon line. A series o f flowmeters, valves, and regulators

maintain constant flow through the system at a constant pressure.

Calibrations of the continuous analyzers were performed using EPA

Protocol 1 calibration gases (il%) for NO, and NBS certified calibration

4-5

TABLE 4-1. CONTINUOUS MONITORING LAB - TRAILERS 1, 2 AND 4

NO, CHEMILUMINESCENT ANALYZER - THERMO ELECTRON MODEL 10

Response Time (040%) Zero Drift Linearity *1% of full scale Accuracy

Operating Ranges

I .5 sec - NO mode: 1.7 sec - NO, mode Negligible after 1/2 hour warmup

Derived from the NO or NO, calibration gas, il% of full scale

0-2, 10, 25, 100, 250, 1000; 2500 and 10,000 ppm

0, ANALYZER, FUEL TYPE - TELEDYNE MODEL 326

output 0-10 v flowrate = 2 scfh 0-2.5

Response Time (O-W%) 60 seconds Accuracy

output 0-1 v ti% of scale at constant temperatures: ti% of sca!e of *5% of reading, whichever kgreater, over the operating temperature range

Operating Ranges 06%. 10%. 25% 0, Fiowrate 2 scfh

CO&O INFRARED ANALYZER - ANARAD MODEL AR-600 . Response Time (040%) 5 seconds Zero Drift *1% Span D r i i *1% Linearity 1% Resolution output 0-1 v Operating Ranges Flowrate 1000 cc/min

Less than 1 % of full scale

020% C0,/0~10,000 ppm CO

CO GAS FILTER CORRELATION - THERMO ELECTRON MODEL 48 Response Time, (0-95%) Zero Drift Span Drift Linearity Accuracy output Operating Ranges flowrate

Response Time (040%) Zero D r i Linearity Accuracy output operating Ranges Flowrate

Pen Response Input Spans Zero Set Accuracy Dead Band Linearity

Recording Pen Chart Width

chart speed

1 minute r0.2 ppm CO Less than 1% full scale in 24 hours *I% full scale, all ranges t0.1 ppm CO 0-10 v 1. 2, 5. 10, 20, 50, 100, 200, 500, 1000 pprn 5-21pm

SO, UV ANALYZER - DUPONT MODEL 400

Less than 60 seconds Less than 2% full scale in 24 hours ti% full scale t2% full scale

0-100 ppm, 1-1000 pprn 500 - 1500 cc/min

0.35 seconds Full Scale 1. 2. 5. 10, 20, 50. 100 MV Stable access entire chart-width *loo% 35% of Span .15% of Span .25% of Span 1. 2, 5. 10, 20, 50. 100 cm/min; 1, 2, 5. 10, 20, 50 cm/hr: fast advance 100 cm/min: LED indicator: forward and reverse selector Fiber tip pen 250 mm

0-5 V

STRIP CHART RECORDERS (3) - UNSEIS 7025

SCOTSMAN TRAILER

Fully insulated Air Corditloned - 8 feet x 14 feet x 1 1 feel 4-6

1. Filter 0.6 k 99.9999 percent efficient 2. Duct 3. 316 stainless steel probe 4. 3/8-inch. heated (250°F) Teflon 5. Four-pass conditionerdryer, 31 6 stainless steel internals 6. 3/8-inch. unheated Teflon 7. Teflon-lined sample pump 8. 3/8-inch unheated Teflon 9. Rotameter 10. 1 /cinch Teflon tubing 11. Calibration gas manifold 12. Calibration gas selector valve 13. Calibration gas cylinders 14. Backpressure regulator 15. Auxiliary analysis port 1

Sampling Loca t ion

.

FlGURE 4-1. SCHEMATlC OF CONTINUOUS MONlTORlNG SVSTEM

4-7

e

gases ( r l % ) f o r CO, CO, and 0,.

included i n t h e Appendix of t h i s r e p o r t . All p e r t i n e n t da t a ( d a t e , time,

test l o c a t i o n s , ana lyzer range, cal gas value) were recorded on both t h e

f i e l d da t a s h e e t s and continuous ana lyzer s t r i p c h a r t s in t h e f i e l d .

Copies of t h e gas c e r t i f i c a t i o n s a r e

A t the s t a r t of a test day, a leak-check was performed. The

A sample probe was removed from t h e s t ack and the end was sealed.

leak-check was successful only i f p ressure a t t h e ana lyzer system and

flow through t h e rotameters t o t h e ind iv idua l ana lyzers a l l dropped t o

zero .

tes t day.

A mandatory leak-check was performed a t t h e completion of each

An i n i t i a l c a l i b r a t i o n was performed a t the s t a r t of a t es t - period by introducing zero and span gases f o r each analyzer and making

t h e necessary adjustments.

continuous monitor s t r i p c h a r t s and f i e l d d a t a s h e e t s .

check was completed a t the end of a t e s t and adjustments ( i f necessary)

t o t h e ana lyze r s were made in prepara t ion f o r another t e s t .

An ex t e rna l c a l i b r a t i o n of t h e sampling system was performed a t

t h e s t a r t of a t e s t day.

t i r e sampling system from the probe t i p .

had t o be wi th in +5% of the c e r t i f i e d t ank value before t e s t i n g could

proceed.

test day.

Cal ibra t ion gas va lues were recorded on t h e

A c a l i b r a t i o n

€ P A Protocol 1 gas was flowed through t h e en-

The response of t h e ana lyzers

An ex terna l c a l i b r a t i o n was a l s o performed a t t h e end of each

Test d a t a were c o l l e c t e d by recording 10-minute averages from the

s t r i p c h a r t recordings onto the fiel’d d a t a sheets.

the tes t per iod were averaged and r epor t ed .

Data c o l l e c t e d over

e

SECTION 5

ANALYSIS PROCEDURES

This section of the report describes the procedures used to

analyze the samples collected during the test program.

performed in the Steiner Environmental cl imate-controlled laboratory.

All analysis were

5.1 ANALYSIS OF PARTICULATE-SO, SAMPLES

‘5.1.1 Nozzle. Probe, Filter Holder Wash

The volume of the acetone washings was measured and the washings

were transferred to clean, tared, aluminum weighing dishes. The dishes

were placed on temperature-controlled water bath under a fume hood and

gently heated to dryness (100°F).

desiccated and weighed repeatedly at 6-hour intervals until a constant

weight was achieved (to the nearest 0.01 mg with a tolerance of tO.l mg

between weighings). The ACS reagent grade acetone blank was treated in

the same manner.

5.1.2 Filter

The dishes with the dry residue were

,

The 100-mm filter was removed from its petri dish and transferred

to an oven where it was heated for 2 hours at 105°C. The filter was then

desiccated and weighed repeatedly at 6-hour intervals until a constant

weight was achieved (to nearest 0.01 mg with a tolerance of tO.l mg

between weighings).

same manner.

An unused, tared blank filter was treated in the 0 5-1

5.1.3 Filterable Particulate Sulfate

The acetone washings residue'and the 100-mm filter were combined

and then leached with distilled water to remove sulfate and the leachate

was diluted to 100-ml. An a1 iquot was passed through ion exchange resin and titrated against 0.01N BaC1, (which was previously standardized

against 0.0100N H,SO,) using the barium-thorin titration procedure

specified in EPA Method 8.

were treated in an identical manner.

5.1.4 Condensible Particulate, Sulfate. and SO,

The acetone blank and 100-mm filter blank

The 47-mm glass fiber filter was leached with distilled water and

the leachate was added to the contents and washings from impinger 1. The

volume was measured and the entire volume was transferred to a clean,

tared glass evaporating dish.

controlled hot plate under a fume hood and gently heated to dryness

(150°F).

repeatedly at 6-hour intervals until a constant weight was achieved (to

nearest 0.01 mg with a tolerance of <0.1 mg between weighings).

residue was dissolved in distilled water and diluted to 100-ml using

\

The dish was placed on a temperature-

The dish with the dry residue was desiccated and weighed

The dry

distilled water and analyzed for sulfate using the barium-thorin

titration procedure. Approximately 5.0-1111 of 0.1N HC1 was added to the

aliquot prior to titration with the BaC1, to prevent NH, interference.

Three percent H,O, was then added to the aliquot and the sample was

titrated again to determine how much SO, had been removed due to reaction

with NH, in the IPA.

treated in the same manner.

A blank 47-mm filter and 80% IPA solution were

5-2

0 5.1 .5

The volume o f contents and washings f r o m bubbler 2 and impinger 3

was measured and an a l i q u o t was analyzed f o r s u l f a t e using t h e barium-

t h o r i n procedure. A 3% H,O, b l a n k was t r e a t e d i n t h e same manner.

0

5-3

SECTION 6

QUALITY ASSURANCE

' 0

0

6.1 PARTICULATE/SO, SAMPLING EQUIPMENT

A detailed record of repair and maintenance to each sampling train

Preventative maintenance to each system is performed periodi- is kept.

cally to avoid complete component breakdown during a field test.

A detailed record o f sampling system calibrations is also kept.

Calibration data for the sampling nozzles, pitot tubes, dry gas meters

and orifice meters are available for review.

Assurance Branch biannual audits of the dry gas meter and orifice meter

combinations are also logged and verify our in-house calibration data.

The calibration data for the equipment used on this program can be found

Results of the EPA Quality

in the Appendix o f this report.

6.2 LAB ANALYSIS

All field samples are assigned a label and an ID number. This I D

is also affixed to a chain-of-custody log and to the field data sheet to

eliminate any chance of sample mixup. ' Prior to analysis, all glassware is thoroughly cleaned (soap and

water, tap water rinse, distilled water rinse, IPA rinse) to eliminate

any contamination.

are treated the same as a sample (dried in an oven, desiccated and

weighed repeatedly at 6-hour intervals until a constant weight is

The evaporating dishes used t o evaporate the washings

6- 1

achieved).

d i l u t i o n s a re a l l NBS Class A t o i n s u r e accurate measurements. A l l

weighings a re c a r r i e d o u t on a S a r t o r i u s Research Model R160P e l e c t r o n i c

semi-micro balance supported by a marble t a b l e i n a separate room from

the main a n a l y t i c a l l abo ra to ry . The balance i s c a l i b r a t e d r e g u l a r l y

against an NBS Class S-1 weight .

The glassware used t o measure volumes and make t r a n s f e r s and

A l l reagents used i n the f i e l d and i n t h e l a b o r a t o r y a re ACS

reagent grade and blanks o f these reagents are evaluated f o r every s e t

o f t e s t s . Blanks are taken i n t h e f i e l d f rom t h e squeeze b o t t l e s and

n o t t he o r i g i n a l con ta ine r . Records a re kept on these blanks t o i nsu re

c o n s i s t e n t q u a l i t y o f t he reagents. P r i o r t o use, t he I P A i s a l s o

analyzed t o i n s u r e no peroxides are present which could l e a d t o h i g h

SO, and low SO, values.

A q u a l i t y c o n t r o l program c o n s i s t i n g o f d u p l i c a t e analyses ( t o

measure p r e c i s i o n ) , spikes ( t o measure recovery e f f i c i e n c y ) o r a n a l y s i s

o f b l i n d standards suppl ied by EPA’s Q u a l i t y Assurance Branch ( t o measure

accuracy) i s implemented f o r each t e s t program. Table 6-1 summarizes-the

r e s u l t s o f t h e QC checks on t h i s program.

i p a t i o n i n the EPA biannual a u d i t s f o r SO, are kept on f i l e and v e r i f y

our in-house QA/QC e f f o r t .

6.3 CONTINUOUS MONITORS QUALITY ASSURANCE

Records o f our l a b ’ s p a r t i c -

The NO, analyzer are c a l i b r a t e d be fo re and a f t e r each t e s t us ing

an EPA P ro toco l 1 gas (tl%) t r aceab le t o NBS. The CO, CO, and 0,

analyzers a re c a l i b r a t e d before and a f t e r each t e s t us ing a NBS c e r t i f i e d

gas m i x t u r e (*I%).

t h e Appendix o f t h i s r e p o r t

Copies o f t he c a l i b r a t i o n gas c e r t i f i c a t e s appear i n

6-2

A sampling system check was performed a t t h e beginning and end o f

each t e s t day.

sampling probe and measuring t h e system response.

was t o check t h e system f o r leaks and sample l oss .

Th is was done by i n t r o d u c i n g an EPA Pro toco l 1 gas a t t he

The purpose o f t h i s

M u l t i - p o i n t c a l i b r a t i o n l i n e a r i t y checks o f t he cont inuous

analyzers were performed on J u l y 19, 1990 through J u l y 24, 1990. These

r e s u l t s were w e l l w i t h i n CARB l i m i t a t i o n s o f G?% o f f u l l sca le . Tables

6-2 through 6-6 l i s t t he r e s u l t s o f these checks.

TABLE 6-1. QA/QC RESULTS

Test No. Test Parameter DUD (%)

2 F i l t e r a b l e S u l f a t e 99.6

3 F i l t e r a b l e S u l f a t e 99.2

EPA SO, Lo t 0584 9XXX

2 Condensible S u l f a t e 99.7

3 Condensible S u l f a t e


2 so, 100.0

3 SO, 99.4


Rec (%)

99.7

99.1

101.9

99.7

6-3

TABLE 6-2. NO, CALIBRATION SUMMARY e-

'

Analyzer: TECO Cal i brator Manufacturer: Environics

Model : 10 AR

Serial Number: 8816-103-5

NO, CALIBRATION AND LINEARITY CHECKS

Model : . 201-1520 Serial Number: 1122

% Difference Calibration Flow, Oil Flow, Std. NO, out Chart + 2%

Points + cc/min cc/rnin ppm ppm Fulf Scale t .I

Zero

en% URL

1

2

3

0 0 0

4826.8 84.3 20.1 20.1 0

5000 -

4846.3 62.3 14.9 15.05 + 0.6 4865.9 41.8 9.96 10.2 + 0.96 4885.5 21.2 5.05 5.2 + 0.6

Calibration Flow, Dit. Row. Std. Points cc/min cc/rnin

6-4

% Difference NO, out Chart + 2%

PPm ppm Full Scale

0 0 0 Zero WOO - - 80% URL 8233.4 597.6 79.3 79.3 0

1 8387.6 499.3 59.6 60 + 0.4

2 8536.9 300.5 39.8 40.1 + 0.3

3 8688.6 152.3 20.2 20 - 0.2

TABLE 6-2. NO, CALIBRATION AND LINEARITY CHECKS (Concluded)

TECO Model 10-AR/Trailer #2/July 20, 1990

% Difference Calibration Flow, DII. Flow. Std. NO, out Charl + 2%

Points cc/rnin cc/min PPm PPm Full Scale n I

0 0 0

80% URL 8035.2 805.6 802 802 0

Zero 8837.9 -

1 8235.9 595.6 593.7 600 + 0.63 2 8436.6 398.4 397.4 402 + 0.46 3 8634.8 20 1 200.3 202 + 0.17

-

2

3

R a n g e a p p m

0

3480.7 442.1 992.3 1002.5 + 0.408 3703.4 222.8 499.7 . 500 + 0.012

6-5

TABLE 6-3. CO CALIBRATION SUMMARY

Monitoring Trailer: 2 Calibrated by: JP 7/19/90

Analyzer : ANARAO Cali brator Manufacturer: Environi cs

CO CALIBRATION AND LINEARITY CHECKS

Serial Number: 1793 . Serial Number: 1122

0

6-6

% Difference Calibration Flow, Dit. How. Std. co out Chart +2% Po1nts cc/rnin cc/min PPm ppm Fuli Scale

Zero

80% URL

1

2

3 '

0 0 0 984.5 - 201.3 794.1 7931 7931 0

394.6 587.2 5945 5920 - 0.25

590.4 392.7 3971 4100 + 1.29

786.2 198.3 2002 21 20 + 1.18

0

Model : 48 I Model : 201-1520 -

Serial Number: 25149-219 Serial Number: 1122 - CO Standard: AAL114, AAL5660 Concentration: 1003 ppm, 9942 ppm Cylinder Pressure: 1300 psi -

TABLE 6-4. CO CALIBRATION SUMMARY

% Difference Calibration flow. Dil. flow, Std. co out Chart C2%

Points cc/min cc/mln PPm PPm Full Scale 1

I I

Zero 9329.8 - 0 0 0

80% URL 8585.9 747.8 80.3 80.3 0

1 8771.8 552.7 59.4 60 + 0.6

2 8957.8 369.6 39.7 39.9 + 0.2

3 9146.3 186.8 20 20 0 - -

Cali brator Analyzer: TECO Manufacturer: Envi roni cs

CO CALIBRATION AND LINEARITY' CHECKS

Range 0-20 pprn

0

6-7

TABLE 6-4. CO CALIBRATION AND LINEARITY CHECKS (Concluded)

TECO Model 48/Trailer #2/July 24, 1990

Zero

80% URL

1

2

3

Range 0-500 ppm

9800 - 0 0 0

9236.8 384.8 397.6 397.6 0

9332.3 289.3 299.1 305 t 1.18

9430.2 194.3 200.9 202.5 t 0.32

4374 44.2 99.5 102 t 0.50

+

% Difference Calibration flow, Dil. flow, Std. co out Chart +2%

Points cc/min cc/min PPm PPm Full Scale I 1

Zero

80% URL

1

2

3

9800 -- 0 0 0

8850.2 778.5 803.6 803.6 0

9045.9 575.3 594.3 600 + 0.57

9239.3 384.5 397.3 402 + 0.47 9435.1 194.3 200.6 205 + 0.44

8

. ..

6-8

TABLE 6-5. CO, CALIBRATION SUMMARY

Monitoring Trailer: 2 Calibrated by: JP 7/19/90

Analyzer : ANARAO

Model : AR 602

Serial Number: 1793

Form MULTI-G(B/QI)

Cali brator . .

Manufacturer: Environics Model : 201 -1 520

Serial Number: 1 1 2 2

6-9

TABLE 6-6. 0, CALIBRATION SUMMARY

Analyzer: Tel edyne

Model : 326A

S e r i a l Number: 43292

Cal i b r a t o r Manufacturer: Environics

Model : 201-1520

S e r i a l Number: 1122

% Difference Calibration Flow. DiI. flcw. Std. 0, out. Chart +2%

Points cc/min c:/tnin % % Full Scale n d

0 0 0

80% URL 822.9 622.8 20.07 ’ 20.07 0

Zero 1500 -

1 984.5 498.2 15.12 15.2 + 0.32

2 1145.9 332.9 10.13 10.05 - 0.32

3 1309.9 168.1 5.12 5.0 - 0.48 -

% Difference Calibration Flow, Dil. Flow, Std. 0, out Chart +2%

Points cc/min cc/min % % Full Scale I A

Zero

80% URL

1

2

3

0 0 0

4041.2 897.7 8.10 8.18 0

4258.9 662.3 6.05 6.15 + 1.0

4476.8 442.3 4.05 4.12 + 0.7

4694.6 222.8 2.04 2.08 + 0.4

5000 -

6-10

TABLE 6-6. 0, CALIBRATION AND LINEARITY CHECKS (Concluded)

Zero

80% URL

1

2

3

Teledyne Model 326A/Trailer #2/July 19, 1990

8837.9 I 0 0 0

8054.8 806.8 4.10 4.10 0

8250.6 596.4 3.03 3.10 + 1.4

8446.4 398.7 2.03 2.10 + 1.4

8642.1 20 1 1.02 1.05 + 0.6

Range 0-5 % '

6-11

APPENDIX A

STEINER ENVIRONMENTAL R A W DATA

e

A- 1

e

D Steiner Environmental, Inc. - - - -

S A M P L I L POINT LOCATION DATA SHEET

Date /i! -20-41 Test Location SRU 3Z.d C I ‘mPr2a.3 Upstream Dist./Dia. 36 ’ Downstream Dist./Dia. 2 4 No. o f Sampling Points 12 Stack Dimension 30 ” Coupling Length A - 12.75’’

75’ eopc /Do‘cocla pedp aA) A p o u l J ~

- / I . 2- 3 :inch MPT/FPT/Flanqe

7CM Ouay bibOKs XEQ A T

~~

SAMPLING POINT RELOCATION: /o Ode

A - 2

Steiner Environmental, Inc. - - - VELOCITY TRAVERSE DATA SHEET

P l a n t TeXaca - POSEJLIP

T e s t L o c a t i o n 5RU r d LZOizRA+6 rP. S t a t i c Pressure ( i n . wg) -0.33 Barometr ic Pressure 29 .55 Probe TypelLength 0 / A ' P i t o t C o e f f i c i e n t 0 . S q Stack Dimension 3n

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B . ZERO AND SPAN DRIFT PERCENT CALCULATIONS

Company : TEXACO R&l D a t e : 1 2 / 2 0 / 9 1

S t a t i o n : SRU INCINERATOR

I

I _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ( _ _ _ _ _ _ _ _ _

: I n i t i a l S p a n 7 . 5 8

I M e a s u r e d S p a n 7 . 6 2

: Z e r o D r i f t 0.00

I _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ I _ _ _ _ _ _ _ _ _

I

I

I _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ) _ _ _ _ _ _ _ _ _

F i n a l , A c t u a l S p a n I 7 . 6 2

P e r c e n t D r i f t . I 0 . 5 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - _ I _ _ _ _ _ _ _ _ _

* * * * * * * * *

F i n a l , A c t u a l S p a n = M e a s u r e d

8 P e r c s n t D r i f t = ( F i i a l , .ictus

S p a n - Z e r o Dr

S p a n - I n i t i a

ft

S p a n ) / I n i t i a l S p a n x 1 0 0

A - 1 7

- Steiner Environmental, lnc. - - - - - -. . . 0

SAMPLE HANDlING/lOG-IN

S i m a t u r e , CHAIN-OF-CUSTODY

Da t e / T i me S i g n a t u r e Date /T ime

A-18

- Seiner Environmental, Inc. -

a Date: 1 2 - 2 0 -9 I

Test Location: TPY~C.-, S R ~

SAMPLE HANDLING/LOG-IN

CHAIN-OF-CUSTODY Siqnature DatelTime Siqnature Dat e/T i me

It -20 -1 I / Z W I2 -d T. "I/

A-I9

A N A L Y T I C A L R E P O . R T

SAMFLE TYFE :FEW ANALYSIS (9) DATE : 0 1 - 0 7 - 9 2 SAMPLING METHOD :M5/8 SAMPLE COMPONENT :Acetone REQUESTED BY :Texaco/Rosedale, SRU Incinerator, 1 2 - 2 0 - 9 1

ANALYST : MC 0

ANALYTICAL METHOD :GRAVIMETRIC

Test Samp 1 e Anaiytical iiesult No. Volume (total sample)

(ml) Uncorrected Blank Corr. (9) - - - - - - - - - - - - - - - - - - - - - - - - - -_-_----- - -_- - - - - -_-__ _ _ - - _ _ - _ _ _ _ _ -

1 1 7 3 0 . 1 2 3 5 6 0 . 1 2 3 3 8

2 1 7 3 0 . 0 4 2 3 3 0 . 0 4 2 7 5

B 1 ank 100 0 .00010

A-20

2021.10000

2021.00000

2020.90000

2020.80000

2020.70000

' - y 2020.60000 w - - r : _I 2020.50000

5 ; E z 2020.40000 % S

2020.30000

2020.~0000

2020.10000

2020.00000

20 19.90000

20'19.YUOOO

z I- H

A-21

I I 7

I I ,. ,y ,, i r !

j I I i

I

I i ,/

i ! i I I

I

I I

j ,,./ 1 I 1 F' I i

/ I ! I I j

i i , i /' I i

! I I ! ,,/' ~

!

U

__

I I ! I I / i ! 1 i 1.

i i

I

/ I ,

I I I

A N A L Y T I C A L R E P O R T

SAMPLE TYPE :FILTERABLE PARTICULATE DATE : 01-06-92 SAMPLING METHOD :M5/8 ShMPLE CGMPGNXNT :IO0 m FILTER AN’ALY ST : MC & KG XEQUESTED BY :Texaco/Rosedale, SRU Incinerator, 12-20-91 ANALYTICAL METHOD :GRAVIMETRIC

Test Filter Analytical Result No. NO. (total sample)

Uncorrected Blank Corr. (9) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ _ _ _ _ _ _

1 669

L 673 9

Blank

0.08386.

0.06128

0 . 0 0 0 0 0

. .

0.08386

0.06128

A-22

SRU Incinerator, 12-20-91 595.50000

595.00000

594.00000'

593.50000

593.00000

I 592.50000

Run No. 1

0.0 . 20.0 -10.0 60.0 so.0 TIME (seconds)

+ Filter Weight at Zero time : 0.59326

100.0 120.0

A-23

551.00000

550.50000

- CTi - 580.00000 z s O r 9 2 579.50000 z s SI- + ' a 579.00000 z

- a r7, n

a 575.50000

57S.00000

SRU Incinerator, 12-20-91 Run No. 2

0.0 20.0 40.0 60.0 so.0 100.0 120.0 TIiME (seconds)

+ Filter Weight at Zero time : 0.57570

A-24


SAMPLE TYPE :CONDENSIBLE PARTICULATE DATE : 0 1 - 1 0 - 9 2 SAMPLING METHOD ' : ~ 5 / a SAMPLE COMPONENT :SO% IPA + Amf ANALYST : REQUESTED BY :Texaco/Rosedale, SRU Incinerator, 1 2 - 2 0 - 9 1 ANALYTICAL METHOD :GRAVIMETRIC

Test Sample Analytical Result No. Volume (total sample)

Uncorrected Blank Corr. (9) - - - - - - -__- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ 1 3 60 0 . 0 7 7 9 1 0 . 0 7 7 0 6

2 8 5 0 . 0 7 0 5 0 0 . 0 6 9 7 6 .. L

I PA B1 ank 100 0.00015

AMF Blank 100 0 . 0 0 0 9 4

DI Blank 1 0 0 0 . 0 0 0 6 3

A-25


SAMPLE TYPE :FILTERABLE SO4 DATE : 01-07-91 SAMPLING METHOD :M5/8 SAMPLE COMPONENT :FHW t MF ANALYST : MC REQUESTED BY :Texaco/Rosedale, SRU Incinerator, 12-20-91 ANALYTICAL METHOD :BaC12 Titration

Test Samp i e Samp 1 e TITER mls Analyt. Result No. Volume Aliquot o r (total sample)

(Absorbance) mg H2S04 _- - - - - - - - - _ _ _ - - _ _ _ _ _ _ _ _ _ - - - - - - - _ - - - - - - _ _ _ _ _ - - - - - _ _ _ _ _ _ _ _

1 100 10 11.58 59.1c

2 100 10 5.14 26.09

Blank 100 io 0.05 0 . 2 6

'b Duplicate = 99.6 RUN NO. 1 99.2 RUN NO. 2

% CONFIDENCE = 99.7 EPA SO2 LOT' 0584 9XXX NORMAL I TY _ 0.010460251 -

A-26


SAMPLE TYPE :CONDENSIBLE SULFATE DATE : 01-10-92 SAMPLING METHOD :M5/8 '

ShiPLE COMPONENT :ZHW t M F ANALYST : WB REQUESTED BY :Texaco/Rosedale, Sa3 Incineracor, 12-20-91 ANALYTICAL METHOD :BaCL2 Titration

Test Samp 1 e Sample TITER mls Analyt. Result No. Volume Aliquot or (totai sampie)

(Absorbance) mq' H2S04 _ _ _ _ _ _ _ _ - - _ _ - - - _ _ - _ _ _ _ _ - - - - - - - - - - _ _ - - - _ _ _ _ - _ - - - _ _ _ _ _ - - - _ '1 100 1 c 8.57 44.41

2 100 10' 7.84 40.61

IPA Blank 100 10

AMF Blank 100 10

DI Blank 100 10

% Duplicate = 99.7 RUN NO. 1

0 . 0 5

0.06

0.06

0.26

0.31

0.31

% Recovery = 99.1 RUN NO. 2 % CONFIDENCE = 101.9 EPA SO2 LOT 0584 9XXX NORMAL i TY - 0.010638298 -

A-27

A N.A L Y T'I C A L R E P O R T 6

SAMPLE TYPE SAMPLING METHOD SAMPLE COMPONENT

ANALYTICAL METHOD

Test No.

REQUESTED aY

_ _ - - - - - - _ - _ _ _ - -

: so2 DATE : 01-06-92 :M5/8

:Texaco/Rosedale, SRU Incinerator, 1 2 - 2 0 - 9 1 :aaCL2 Titration

: 3 % H202 ANALYST : Me

Sample Samp 1 e TITER mls Analyt. Result Volume Aliquot or (total sample)

(Absorbance) z g H2SC4 - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ - - _ _ - - - - - - - _ _ _ _ _ _

440 1 0 3 9 6 . 1 0 . . 8 9 1 3 . 1 9 1

2 400 1 0 4 6 1 . 8 0 9 4 4 7 . 0 8

Blank

% Duplicate = 100.0 RUN NO. 1 9 9 . 4 RUN NO. 2

0 . 0 5

% CONFIDENCE = 9 9 . 7 EPA SO2 LOT 0581 9XXX NORMAL I TY - 0 . 0 1 0 4 3 8 4 1 3 -

0 . 2 6

11-28

www

SOURCE TEST CALCULATIONS

PLANT : TEXACO Rhd SRU INCINERATOR

RUN NO. : 2

DATE : DECEMBER 20, 1991

STANDARD TEMP. : 60 DEG. F

METER TEMP. STACK TEMP. SQ.RT. d P METER ORIFICE METER VOLUME METER Y BAR. PRESSURE COND.(Vlc)

GAS .AN.ALYS I S

78 DEG. F 957.17 DEG. F

- -

= 0.4802 in. H20 1.86 in. H20

= 92.865 Cu.Ft. = 1.0048 = 29.90 in.Hg

162.1 m l

- -

5.08 % 0 2 4.98 ' % CO2

STATIC PRES$.= ! CD - -

- i STACK I.D. - I DUCT LEXGTH = ! DUCT WIDTH

I TEST TIME ; NOZZLE DIA. =

0.00 % co 89.94 % N 2

I STACK AREA = - -

-0.26 in. H20 0.840 30 .00 inch

inch inch

120 .00 min. 0.3310 inch

4.909 Sq.Ft.

Vm(std) = [ T(std) + 460 / 29.92 ] x Vm x Y x 90.541 dscf - ( P b + (dH / 13.6)) / (Tm + 460) ...... -

7.514 s c f .

0.077 ! Lower

- Vw(std) ~(8.9148 x 1 0 e - 5 ) x (Tstd + 460) x Vic -

Bws = Vw(std) / (Vm(std) + Vw(std)) ............. - - ! Bws I value

1.000 I used. Bws @ Saturated Conditions Vapor Press. o f H20 - @ Dew Point Temp. / (Ps, in.H$.) .............. -

%EA =(%02 - O.j%C0)/(0.264%N2 - (%02-0.5%CO)) X 100 = 27,22

29.00 - Md =(.11 x %C02)+(.32 2 %02)+[.28 x (%N2 + %CO)] -

28.16 - M s = (Md x (1-Bws)) i ( 1 8 . 0 x BWS) .............. -

29.88 in. Hg - P(stack) Pbar + [Pstatic / 13.61 ............ -

v s = 85.49 x CP x (Sq.Rt.dP) x [Sq.Rt.(Ts + 460) 44.75 ft/sec

13,181 acf/min

- / (Ms x P s ) ] .............................. - Qs v s x As x 60 - - .............................. Qs(Std) = QS x (l-Bws)x((Tstd + 160)/(Ts + 460))

3 , 3 6 0 dscf/min - x (Ps/29.92) ........................ - I = (Tsc460) x [(0.002669 x Vlc) + (Vm(std)/(Tstd +

460)/ 29.923 x 100 / (Time x P s x An x v s x 60) = 99.59 %

A-29

www

PLANT : TEXACO R & I SRU INCINERATOR

STANDARD TEMP.:

METER TEUP. 68.51 DEG. F STACK TEMP. 959.08 DEG. F SQ.RT. dP = 0.4825 in. H20 METER ORIFICE 1.81 in. H20 METER VOLUME = 90.045 Cu.Ft. METER Y 1.0048 BAR. PRESSURE 29.88 in.Hg COND.(Vlc) = 126.1 ml

GAS AXALYSIS : 5.36 % 02 4.97 % c02

. RUN NO. : DATE :

60 DEG. F

1 STATIC PRESS.= : CP ! STACK I.D. -

DUCT LEXGTH = DUCT WIDTH =

I . STACK AREA 1 TEST TIME - I NOZZLE DIA. =

0 .00 % CO 89.67 % X2

- - -

-

3 DECEMBER 20, 1991

SOURCE TEST CALCULATIONS

* : ~ * : ~ O * * t * * Y * b * * * * * $ ~ Y * * * * : ~ * * * * Y * * ~ * * * * ~ * * ~ ~ Y * * ~ * * ~ * * * * Y b * * ~ * * * * * ~ * * * * * * * * * . .

Vm(std) = [ T(std) t 4 6 0 / 29.92 ] x Vm x Y x - (Pb f (dH / 13.6)) / (Tm t 160) ...... -

Vw(std) ~(8.9148 x 10e-5) x (Tstd + 460) x Vic -

B w s ; = Vw(std) / (Vm(std) +.Vw(std)) ............. -

@ Dew Point Temp. / ( P s , in.Hg.) .............. - %EA =(%02 - 0.5~0)/(0.261m2 - (%oz-o.~%co)) x i o o =

Md =(.44 x %C02)+(.32 x %02)+[.28 x (%N2 + %CO)] -

&IS = (Md x (1-Bws)) t (18.0 x BWS) .............. -

P(stack).= Pbar t [Pstatic / 13.61 ............ -

-

-

Bws @ Saturated Conditions = Vapor Press. of H20 -

-

-

-

v s = 85.49 x / (Ms x

Qs = v s x As

Qs(std) Q s X

I (Tst4601

CP x (Sq.Rt Ps)] ...... x 60 ...... x (l-Bws)x( Ps/29.92) .

dP) x (Sq.Rt.(Ts t 460) - - ....................... - - .......................

- - Tstd t 460)/(Ts + 460)) ...................... x [(0.002669 x Vlc) + (Vm(std)/(Tstd +

$60)/ 29.921 x 100 / (Time x Ps x An x v s x 60) ::

-0.31 in. H20 0.840 30.00 inch

inch inch

120.00. min. 0.3910 inch

4.909 Sq.Ft.

89.299 dscf

5.846 scf

0.061 : Lower I Bws 1 v a l u e

1.000 : used. 29.27

29.01

28.33

29.86 in. Hg

44.88 ft/sec

13,217 acf/min

. 4,536 dscf/min

96.58 5'4

A-30

EMISSION RATE CALCULATIONS

PLANT :TEXACO R&l RUN NO. : 2 SRU IVCIVERATOR DATE : DECEMBER 20, 1991

STANDARD TEMP. : 60 DEG. F 0 2 CORR. : 3.0 %

L * * * ~ * * * * * X Y * * * * * S I * * * L Y H X * L * U * Y X * L * L * X * * * ~ * ~ ~ * * ~ * * * * * * * * * ~ ~ ~ : * ~ ~ ~ * * * * * * * * * Front Half Wash (FHW) 0.12338 grams : Vm(std) 90.541 ft3 Mass Filter (MF) 0.08386 grams ! Vw(std) 7.514 ft3 Back Half Wash (BHW) 0.07706 grams : Qs(std) 4,460 dscfm Front Half Sulfate (FHS) 59.10 mg H2S04 : Bws 0.077 Back Half Sulfate (BHS) 44.41 mg H2S04 I CO2 4.98 % H202 Catch (SO2) 8913.19 mg H2S04 : 0 2 5.08 % . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . F-FACTOR _ - - - _ - - - 10E6 x [3.64(%H) + 1.53(%C) + 0;57(%S) + 0.14(%N) - 0.46(%02)] / (Btu/lb) x [(Tstd t 460)/528] ......... d s c f /MMB t u

FILTERABLE PARTICULATE

15.432 x (FHW + MF) / [Vm(std) + Vw(std)] .......... 0.0326 gr/scf 15.132 x (FHW + hlF) / ' Vrn(s1d) ...................... 0.0353 gr/dscf gr/dscf x (12 / %CO2) ............................... 0.0.851 @ 12% CO2

F-Fac x 1.4286E-4 x L20.9 / (.20.9-%02)],x gr/dscf .. 1 b/XIMB t u

TOTAL PARTICULATE

13.'432 x (FHW + MF + BHW) / [(Vm(std) + Vw(std)] ... 0.0447 gr/scf 15.432 x (FHW + MF + BHW) / (Vm'(std). ............... 0.0485 gr/dscf gr/dscf x ( 1 2 / %CO2) .............................. 0.1168 @ 12% CO2 0.00857 x Qs(std) x gr/dscf ........................ 1.85 Ib/hr F-Fac x 1.4286E-4 x [ 2 O . Y / (20.9-%02)] x gr/dscf .. 1 b/MMB t u

TOTAL S.ULF.ATE

0.015432 x (FHS + BHS) / [Vm(std) + Vw(std)] ....... 0.0163 gr/scf 0.015432 x (FHS +. BHS) / Vm(std) ................... 0.0176 gr/dscf gr/dscf x ( 1 2 / X 0 2 ) .............................. 0 .0425 @ 12% CO2 0.00857 x Qs(std) x gr/dscf ........................ 0.67 Ib/hr

_-_________- - -____- -__

0 . 0 0 8 5 7 x Qs(std) x gr/dscf ........................ 1.35 Ib/hr

__-_____- - -_____- a

_-- -____-__-_

F-Fac x 1.4286E-4 x [20..9 / (20.9-%02)] x gr/dscf .. 1 b/iWMB t u

SULFUR DIOXIDE (SO2)

1.60864 x [ T ( s t d ) + 160) x (mg H2SO4) / 1 98.076 x Vm(std)] ........................................... 839.63 ppm ppm x [(20..9 - Oxygen Corr.) / (20.9 - %02)] ....... 950.02 @ 02 corr. ppm x (1 - Bws) .................................... 775.29 ppm (wet) 8.2233-5 x Qs(std) x 64.062 x ppm / [T(std) + 1601.. 37.94 lb/hr 'F-Factor x 64.062 x [1.3711E-6 / [T(std)+ 46011 x IZO.9 / (20.9 - " 4 0 2 ) ) x ppm ........................ 1 b/MMB t u

-------____-----____

lb/hr / (dscfm x 60 min/hr) ........................ 1.42E-04 Ib/dscf

0 SULFUR (S) (Ib/ClMBtu S O 2 ) / 2 ................................. 1 b/WB t u (lb/MMBtu Total Sulfate) x ( 3 2 / 98.076) ........... 1 b/MMB t u Total Suli'ur ........................................ 1 b/MlMB t u

A-31

EMISSION RATE CALCULATIONS

PLANT :TEX'ACO R&M RUK NO:: 3 SRU INCINERATOR DATE : DECEMBER 20, ,1991

STANDARD TEMP. : 60 DEG. F 02 CORR. : 3.0 %

X:Y Yt * :Y 3 %1% 0 * :: % * 1 X * X :U C * * * * * % * * * * Y * ZC % Y 1: 1: * 3 * * *. * * * * * Y * * * * * Y X * * * * * * * * * 8 * * * * Y

Front Half Wash (FHW) . 0 . 0 4 2 7 5 grams I Vm(std) 89.299 ft3 Vass Fi 1 ter (MF) 0.06128 grams I Vw(std) 5.846 ft3 Back Half Wash (BHIV) 0.06976 grams I Qs(std) 4,536 dscfm Front Half Sulfate (FHS) 26.09 mg H2SO-I Bws 0.061

H202 Catch (SO2) 9447.08 mg.H2S04 I 02 5.36 % . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

F-FACTOR

10E6 x [3.64(%11) + 1.53(%C) + 0.57(%S) + 0.14(%N) -'

0.46(%02)] / (Btu/lb) x [(Tstd + 460)/528] ......... dscf/MMBtu

FILTERABLE PARTICULATE

15.432 x (FHW + >IF) / [Vm(std) + Vw(std)] .......... 0.0169 gr/scf

Back Half Sulfate (BHS) 40.61 mg H2S04 I CO2 4.97 %

-___----

_-___-- - - - - - - - -_____-- 15.432 x (FHK i MF) i Vm(std) ...................... 0.0180 grjdscf gr/dscf :: (12 / %CO?) ....................... ; ....... 0.0434 @ 12% c02 0 . 0 0 8 5 7 x Qs'(std) x gr/dscf ......................... 0 .70 Ib/lrr F-Fac x 1.4286E-4 x [20.9 / (20.9-%02)4 x gr/dscf .. 1 b/blMBt u

TOTAL PARTICULATE _____------------ 15.432 x (FHW + MF + BHW) / [(Vm(std) + Vw(std)] ... 0.0282 gr/scf 15.432 x (FHW + MF + BHW) / (Vm(std) .........:...... 0.0300 gr/dscf gr/dscf x (12 / %C02) ................................ 0.0725 @ 12% C02

F-Fac x 1.4286E-4 x [20.9 / (20.9-%02)] x gr/dscf .. 1 b/hlhlB t u

TOTAL SULFATE

0.015432 x (FHS + BHS) / [Vm(std) + Vw(std)] ....... 0.0108 gr/scf. 0.015432 x (FHS + BHS) / Vm(std) ................... 0.0115 gr/dscf gr/dscf x (12 j %C02) .............................. 0.0278 @ 12% C02

F-Fac x 1.4286E-4 x L20.9 / (20.9-%02)] x gr/dscf .. 1 b/MMB t u

SULFUR DIOXIDE (S02)

1.60864 x [T(std) + 4601 x (mg H2SO-I) / [ 98.076 x Vm(std)] ............................................ 902.30 ppm ppm x i(20.9 -.Oxygen Corr.) / (20.9 - % 0 2 ) ] ........ 1039.33 @ 0 2 corr.

8.223E-5 x Qs(std) x 64.062 x ppm / [T(std) + !+SO].. 41.46 lb/hr F-Factor x 64.062 x [1.3711E-6 / [T(std)+ 46011 x i20.9 / (20.9 - % 0 2 ) ] x ppm .... ; ................... 1 b/MMB t u lb/hr / (dscfm x 60 rnin/hr) ........................ 1.52E-04 lb/dscf

0.00857 x Qs(std) x gr/dscf ........................ 1.17 lb/hr

-_____- - -____

0.00857 x Qs(std) x gr/dscf ........................ 0 . 4 5 Ib/hr

-----_-----_-__--___

. ppm x ( 1 - Bws) .................................... .846.86 ppm (wet)

I bj.tllhlB t u (Ib/>l.thlBtii SO?) / 2 ............ : ..................... Total S u l f u r ........................................ 1 b/>lMB tu

SULFUR ( S )

(lb/\lhlBtu 'Total Su'lfate) x (32 / 98.076) ........... 1 b/;MMB t u

A-32

PLANT TEXACO R&U

Temp. Std. : 6 0 dF Press. Std.: 2 9 . 9 2 in. Hg. 3 % 0 2 Correction

SOURCE SRU ISCINERATOR

Run No. 1 2 3 AVERAGE

Date 1 2 / 2 0 / 9 1 1 2 / 2 0 / 9 1 1 2 / 2 0 / 9 1 Oxygen ( % ) 5 . 2 3 5 . 0 8 5 . 3 6 5 . 2 2 Qs(std), dscfm 4 , 4 6 0 4 , 4 6 0 4 , 5 3 6 4 , 4 8 5 NOx, p p m 3 6 . 7 5 3 2 . 7 3 2 4 . 6 8 3 1 . 3 9 SO2, p p m co, P W 1 3 1 . 5 0 1 5 7 . 5 4 2 0 4 . 7 7 1 6 4 . 6 0 HC, p p m F-Fac t or

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

S O 2 , MW = 6 4 . 0 5 8 0 SO2. lb/hr s o 2 ; ppm @ 0 2 SO2, I b/blME t u

CO, MW = 2 8 . 0 1 0 CO, lb/hr 2 . 6 0 CO, p p m 13 0 2 1 5 0 . 2 6 CO, lb/XMEtu ,

HC, MW = 1 6 . 0 4 3 HC, lb/hr

HC, lb/MMEtu HC, p p m @ 0 2

3 . 1 1 1 7 8 . 2 1

4 . 1 1 2 3 5 . 8 5

3 . 2 7 1 8 8 . 1 1

* lb/hr = 8 . 2 2 3 E - 5 x Qs(std) x MW x p p m / (Tstd + 4 6 0 )

* p p m @ 02 = ppm measured x [ ( 2 0 . 9 - 0 2 % correction) / ( 2 0 . 9 - %02 measured)]

* Ib/MMBtu =

.* lb/Bbl ( e F-Factor x MW x ( 1 . 3 7 1 1 3 - 6 / (Tstd + 4 6 0 ) ] x ( 2 0 . 9 /

2 0 . 9 - 0 2 % ) ] x p p m

b/MMBtu) x (MblBtu/Bbl)

A-33

DRY G.\S YETER / O R I F I C E XETER CXLIBRXTIO?I DATA

Date ............ 10-29-91 Bar. Press. in-.Hg 29.67 Meter Box No. ... 635

Dry Gas heter No. ... 2409937 'Standard Test Xeter X . 69279 Operator ............ JP

I . dHs rs vs I (in. H20) (dF) (ft3) I__________________________

.67.0 183.329 -1.2 66..9 160.348

I.Xva/Net : 66.5 . 22.981

68.0 210.175 I

t I (rnin) I

y = Vs x (Pbar f (dHs / 13.61) x (Avg. Td 7 4601. / [ Vd x (Pbar + (dH / 13.6)) x ( Ts + 460)l

KO = T(Vs/t) x [(Tdo + 460) / (Ts + 46011 x I(Pbar + (dHs/13.6) / (Pbar - (dH/13.6)1 / T((Tdo + 460) x dH) / (Pbar + (dH/13.6)) x (Mm)1'0.5

dH : 0.5 1.0 1.5 2.0 3.0 -1vg. ------ ------ -__---_ __--__ --_--- ----- y : 0.9976 0.9969 1.0072' 1.0096 1.0126 1.0048

KO : 0.7502 0.7307 0.7315 0.7228 0.7183 0.7307 y : 0.63 % Relative Std. Dev.

KO : 1.50 % Relative Std. Dev. A-34

S td. Dev.

9.0064

0.0109

- - - - - - - -

REPORT O F ' A N 2 L L Y S I S

CUSTOHER ORDER NUMBER: SP2750-90RFL.11 PAGE 2

CYLINDER NO.: CC98760 12/12/98 12/27/90 .%dWr lab. m e 1 8440

Nitric Oxide 206.9 2 2.1 ppm GIUS S/N 136 06/27/92 206.9 p p 207.4 P P ~ C y l 1 l d . C t Cancinwu 206.8 p p 207.1 porn

Nitrogen,OZ-Free Balance ' ' cc7341 ChdlUDllneafellfa 206.4 D- 206.7 w m Cylinder Preesure: 2000 psig R 247.5 p p L a s t Cal Data: 18/23/90 Hem: 206.7 ?p 207.1 p p ........................................................................................ CYLINDER NO.: cc9a703

mplwr lab. n a d 8440 12/12/90 12/27/90 'a Nitric Oxide 205.1 2 2.1 ppm mas SIN 136 w z 7 r 9 z 281.8 PB 205.2 ppn .Cylinder # Con+inwu' 205.2 ppo 205.7 ppo

Nitrogen,OZ-Free Balance ' cE734i chdldnescenca 204.5 irrn 2os.o ¶om

Mean: 204.9 p p 20S.3 ppm Cylinder Pressure: 2000 psig R 247.5 p p , I a s C Cal Dates l0/13/90

CC98760 xox 206.9 ppm CC98701 NOx 19.76 ppm NO 2 P P m NO 2 <0.35 ppm

CC98703 NOX 205.1 ppm ccga699 VOX 19.85 ppm NO 2 PPm NO2 tO.1 ppm

% = mole-$

The above analyses were performed in accordance.with EPA-1987 Traceability ? r o t o c o ~ 1 .1. Section 3.0 .4 , Procedure Gl. A-35

PAGENO. 2 OF 2

6 SCOTT - MARRIN, INC. 2001 THIRD ST., UNIT H RIVERSIDE, CALIFORNIA 92507

REPORT OF ANALYSIS

CUSTOMER ORDER NUMBER: B1. -SP-2750-90 Rel. 6

CYLINDER NUMBER cc7380 Replicate 11/9/90 82.5 ppm 11/16/90 82.9 ppm Analysis 82.7 ppm 82.7 ppm Data On 82.3 ppm . .- 83.0 ppm NO: Mean 82.5 ppm 82.9 ppm

CONCENTRATION (v/v) 82.7 2 0.8 ppm

COMPONENT Nitric Oxide

Nitrogen Dioxide <0.4 ppm

Nitrogen* Balance Expiration Date NO: 5/16/92'

Cylinder Pressure: 2000 psig

*Oxygen-free.

above analysis was performed in accordance with Section 3.0.4 of the revised EPA trace- ) )

(Lnstitute of Standards & Technology by direct intercomparison with GMIS, cylinder number ) (CC12643 at 99.3 ppm Nitric Oxide in Oxygen-free Nitrogen. The analysis was performed using ) (a Monitor Labs Model 8440, S/N 136 analyzer with continuous chemiluminescence detection. The)

)

'.: d i t y protocol No. 1 dated June 9, 1987. The analysis is traceable to the National

(last multipoint calibration was performed 10/23/90.

CYLINDER NUMBER COMPONENT CONCENTRATION (vlv)

A-36

SMF - Cd

SCOTTMARRIN, INC. 2001 THIRD ST. UNIT H RIVERSIDE. CA 92507

TELEPHONE (714) 784-1240 w = 111 I (-

. a REPORT OF ILNZXLYSIS EPA PROTOCOL GAS MIXTUFU3S

PAPE0l

SUE POWERS STEINER ENVIRONMENTRL 4930 BOYLAN STREET BAKERSFIELD, CA 93308

TO: DATE : 01/14/91

ppn = umole/mole % = mole-%

The above analyses were performed in accordance with EPA-1987 Traceability Protocol # 1, Section 3.0.4, Procedure G1. f

SCOTT-MARRIN, INC. 2001 THIRD ST. UNIT H RIVERSIDE, CA 92507 W = 111 I TELEPHONE (714) 784-1240

TO: STEI0l

REPORT OF ANALYSIS NIST TFCACEABLE GAS M I X T U F 3 Z S

SUE wmxi

BAKFRSFIELD, CA 93308'

STEINER ENVIRONKENTAL, INC. 4950 BO- STREET

DATE: 11/20/91

CUSTONER ORDER NUMBER: SP-2750-90REL43 PAGE 1

<xxxxxxxxxxxxxxxxxxXi< i<XXXXX><XXXXZ<XXX><~x> NIST TRACEABLE

CYLINDER NUHBER COMPONENT CONCENTRATION(V/V) REFERENCE STANDARD

CC60269 Carbon Monoxide 38.2 2 0.4 ppm SRM 2614a Carbon Dioxide 15.93 + 0.16 % SRM 1675b Oxygen 7.58 2-0.08 % SPA 2658a Nitrogen ' Balance

The above analyses by intercomparison

% mole-%

are traceable to the National Institute of Standards and Technology

Where indicated, volumetric and gravimetric reference standards are traceable thru use with the reference standards listed above.

of our analytical 491.

J.T. Marrin

Analyst :

H.S . Calhoun

SCOTT-MARRIN, INC. 2 0 0 1 T H I R D ST. UNIT H R I V E R S I D E , CA 92507

T E L E P H O N E (714) 7 8 4 - 1 2 4 0 I = 111 I i

REPORT OF ANALYSIS NIST T-CEABLE G A S MIXTURES

STEI0l

SUE POWERS STEINER ENVIRONMENTRL, INC. 4930 BOYLAN STREET BAKERSFIELD, CA 93308

TO: DATE: -11/18/91

CUSTOMER ORDER NUMBER: SP-2750-90REL44 PAGE 1

CC2 6 5 Carbon Konoxide 399 2 4 ppm Carbon Dioxide 9.15 + 0.09 % Oxygen 0.975; 0.010 % Nitrogen Balance

SRM 1680b SRH 1675b SRM 2657

p p = umole/mole % = mole-%

The above analyses are traceable t o t h e National I n s t i t u t e of Standards and Technology by intercomparison with t h e re ference s tandards l isted above. Where ind ica t ed , volumetr ic and gravimetric r e fe rence s tandards are t r aceab le t h r u u s e of our analyticab palanqe, N I S T R e p o r t NO. MUAP 232.09/20p491.

M.S. Calhoun . // J . T . Harr in

KERN COUNTY RESULTS

4P0 %02 lb/hr g r / s c f , .cr/scf@T K.C. Vm(std) = 9 0 . 5 4 K . C . Q ( s t d ) = SITE -RUN *r/dscf

O U W - 2 PM 0 .0482 0 .0445 0 .1162 5 . 0 8 1 . 8 p J

KERN COUNTY RESULTS

K . C . Vm(std) = 9 0 . 5 4 K . C . Q ( s t d ) 4452

S ITE-RUN gr/dscf gr/scf gr/scf@T%C %02 l b / h r

OUTLET- 2 PM 0.0353 0.0326 0.0850 5.08 1.35' OUTLET- 2 SO4 0.0177 0.0164 0.0428 5.08 0.68 J

SI TE-RUN ppm(dry) ppmlwet) l b / h r ~

O U W - 2 SO2 841.25 776.65 37.96

SITE-RUN ppm( dry) ppm@3%02 %02 l b / h r OUTLET-'Z NOx 32.7 37.0 5.08 1.06"

SITE-RUN ppm(dry) ppm@%02 %02 1 b/ hr OUTLET- 2 CO 157.00 177.64 5.08 3.10

. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

2007027/101/201/301/401/601 Page4

ERC APPLICATION REVIEW Glen E. Stephens App; Rec.: 07/15/92 Date: 09/22/92

F a c i l i t y Name: TEXACO REFINING AND MARKETING INC.

Mail ing Address: P.O. Box 1476 Bakersfield, Cal i forn ia 93302

Applicant Name: Donald J. Slack, Supervisor Environmental, Safety & Health

Contact Name: Steve Powell Phone Number: (805) 326-4426

Application: 2007027/101/201/301/401/601 Project #: 920716

Deemed Complete: 08/17/92 Reviewed by:

I. SUMMARY:

Texaco Refining and Marketing Inc. (TRMI) has removed from operation the ta i lgas incinerator l i s t e d as item "j" on Permit t o Operate (PTO) 2007027A (see Appendix " A " ) . The ta i lgas normally burned i n the incinerator l i s t e d on PTO 2007027A has been permanently diverted t o a new ta i lgas t rea t ing un i t , included on permit 2007245 (see Appendix " A " ) as "Tai l Gas Treating Unit". The removal o f the o ld ta i lgas incinerator was authorized by ATC 20070278 (see Appendix " A " ) . Authority t o construct f o r the new u n i t was not based on o f f se ts t o be provided f o r by the removal o f the o ld ta i l gas incinerator l i s t e d on 2007027A. Texaco has applied t o bank the emissions from the ta i lgas incinerator as an Emission Reduction Credit (ERC) Cer t i f i ca te pursuant t o Rule 230.1 Subsection 1V.B. H is to r ic Actual Emissions have been adjusted f o r 10% t o be deposited t o the Community Bank. reductions have been found t o qua l i f y f o r banking:

The fol lowing emission

l i n Lbs/Quarter)

2007027/101/201/301/401/601 Page 2

11.

I11

I V .

V.

V I .

V I 1

APPLICABLE RULES:

A. Rule 220.1: (New and Modified Stationary Source Review Rule -- post 09/19/91, revised 03/11/92)

B. Rule 230.1: (Emission Reduction Credit Banking -- adopted 09/19/91, revised 03/11/92)

C. Rule 230.2: (Community Bank -- adopted 09/19/91, revised 03/11/92)

PROJECT LOCATION:

NW Section 27, Township 29 South, Range 27 East MDB&M 6451 Rosedale Highway., Area 1 o f Texaco Refinery

METHOD OF GENERATING REDUCTIONS:

Tailgas previously burned i n incinerator has been permanently diverted t o new u n i t (ATC 2007245 -- t a i l gas t rea t ing uni t ) . No emission reductions f o r the removal o f the o ld ta i l gas incinerator were used f o r the approval o f the new uni t .

Figure #I: Maps showing General Location o f incinerator taken out of service.

EQUIPMENT LISTING:

1 - Tailgas incinerator, 16-MI01 -- removed from service

See Attachment PTO #2007027A and f o r the new ta i l gas t rea t ing u n i t (ATC #2007245). These ATC's have been implemented and new permits are being prepared.

" A " f o r copies o f PTO t o be revised and ATC's t o modify

CONTROL EQUIPMENT EVALUATION:

The emission reductions were generated by equipment being taken out o f service, and not by the addit ion o f control equipment. Therefore, no control equipment evaluation i s required.

CALCULATIONS:

A. General :

Calculations w i l l summarize the His tor ica l Actual Emissions (HAE). H is tor ica l Actual Emissions f o r each quarter i n the baseline period are calculated using fue l usage data ( t o t a l offgas t o claus furnace) and source t e s t emission factors fo r each a i r contaminant. Source tes t data i s summarized i n Attachment "B".

07027/101/201/301/401/601 I

I '

I

I 1 I

I /I :

r'

I

cr 3

a LL

-

z 0 I- o 0

-I

I- o

W

0

- a 7

a a

..

.

>. .

2007027/101/201/301/401/601 Page 4

8. Fuel ConsumDtion Data:

The data below i s der ived from app l i can t suppl ied data. The app l ican t suppl ied da ta i s the average h o u r l y vo lumetr ic o f fgas gas f l ow t o the i n c i n e r a t o r for d e s t r u c t i o n (see Appendix "B" ) . The q u a r t e r l y f u e l use were obtained by by t h e f o l l o w i n g ca l cu la t i ons :

Mscf/hr . 24 hr/day . 30 d a y p o n t h ' = Mscf/month Mscf/month . 90 days/quarter = Mscf/quarter

The f o l l o w i n g represents t h e r e s u l t s o f t h e ca l cu la t i ons :

Average Quar te r ly Fuel Use ( i n Mscf/Gluarter) Jan-Mar Apr-Jun Ju 1 -Sept Oct-Dec

52451.40 621 66.24 59300.44 65367.60 I I I Y Adjustments were made t o app l i can t supp l ied data (March '90 data was no t used) because month i d e n t i f i e d d i d n o t co inc ide wi th 8 consecutive calendar quar te rs preceding t h e a p p l i c a t i o n for ERC banking C e r t i f i c a t e .

C. Emission Factors:

I n c i n e r a t o r was source t e s t e d ( D i s t r i c t witnessed source t e s t ) on December 20, 1991; t h e r e s u l t s o f t he source t e s t s ( V e r i f i e d by D i s t r i c t s t a f f ) are l i s t e d below. inc ludes SO4 emissions as t h e t o t a l PM,*. faetef-mtlst-be-fet1tree~-b7-t4e-S~,-fae+Gef-te-fepfesent-PM~~-a~~-S~~ emisste~s-sepafateSy~--T4e-a~~~stet-faet~s-afe-~ts+Get-be~ew-~4e seafee-tes+G-faetefs. emissions represented separate ly ; there fore , t h e SO4 f a c t o r i s de le ted and no a d d i t i o n a l adjustments are made t o the o r i g i n a l source t e s t f ac to rs .

However, t h e PMIO f a c t o r T4efefefe~-t4e-PMte

The app l i can t decided not t o have SO,

Adjusted f a c t o r on t h e f o l l o w i n g page.

Emission Factors From Source Tests ( i n Lbs/Mscf) PMln so, so, NO, voc co

I li 0.0302 0.0166 1.1753 0.0302 NA 0.0968

A~4aste~-Em~ssie~-fae+Gefs-~set-~in-tbsjMsef~ -----p~ --------se ----------se----------Ne----------'~e€----------€e

---e7e+36 ---e7e+66 ---+:+?53 ---e783e2 ---- NA ---e7e9.s8

30 dayshon th used as an example. Actual days/month f o r each month was used.

90 dayshon th used as an example. quar te r

I

Actual days/month used f o r each 2

2007027/101/201/301/401/601 Page 5

Adjusted Emission Factors Used ( i n Lbs/Mscf) PMI0 so, so, NO, voc co

I R I 0.0302 NA 1.1753 0.0302 NA 0.0968

0. H is to r ica l Actual Emissions (HAE):

Based on the emission factors used. factors and the actual fue l used resul ts i n the h i s to r i ca l actual emissions. Calculations t o show HAE, adjustments and actual emission reductions (AER) t o be banked are included i n Attachment " C " .

The product o f the emission

HAE f o r each quarter are as follows:

H is to r ica l Actual Emissions ( i n Lbs/Quarter) Quarter PPI,, so, so, NO, co

a

E. Adjustments t o I n i t i a l Emission Reductions:

1. Early Implementation o f BARCT:

I n the San Joaquin Valley Unif ied A i r Po l lu t ion Control D i s t r i c t 1991 A i r Quality Attainment Plan (AQAP) there are proposed measures f o r the control o f NO, emissions from external combustion sources. The section t i t l e d External Combustion Devices -- Boilers, Steam Generators, Process Heaters, Driers i n the AQAP (see Appendix "0") proposes NO, control measures and l i s t s SCC and CES codes f o r external combustion devices. Two o f the SCC and CES codes l i s t e d i n the above mentioned section apply t o process gas incineration a t a petroleum ref inery source (SCC and CES codes 102007001 and 82081 respectively). However, the proposed removal o f the incinerator was approved by Authority t o Construct (Apr i l 18, 1991) p r i o r t o the issuance o f the AQAP (January 30, 1992); therefore, a 75% HAE NO, reduction, because o f early implementation o f BARCT (see Rule 220.1.V.B), i s not required.

2. Communitv Bank Allowance Reduction:

Rule 220.1.V1., states a port ion o f a l l onsite actual emissions reductions created a f te r the adoption o f Rule 220.1 (September 19, 1991) shal l be used t o fund the Community Bank and 10% o f AER shal l be deposited t o the Community Bank; remaining AER qua l i f i es f o r the ERC Cer t i f icate:

2007027/101/20 1 /301/40 1 /60 1 Page 6

For Deposit i n t o the Community Bank ( i n Lbs/Qtr] Quarter PM,, so, so, N 0, co

Jan - Mar 158.38 66-95 6164.36 158.38 507.74 I I1 I1 I

Apr - Jun 1 187.71 R +e3-e6 1 7306.10 187.71 I 601.79 I I I

J u l - Sep 1 179.06 II 96-34 6969.29 II 179.06 574.05 I n I,

Oct - Dec 1 197.38 I +e8:3+ 1 7682.34 B 197.38 1 632.78

For Deposit i n t o the Community Bank ( i n Lbs/Oay)

Apr - Jun I 2.06 P S A 3 R 80.29 R 2.06 R 6.61

J u l - Sep 1 1.95 +:e+ 75.75 1.95 6.24

SrS6 83.50 R 2.15 R 6.88 Oct - Dec 2.15


The HAE l ess the community bank adjustment g ives bankable emission reduct ions o f :

Bankable Emission Reductions ( i n Lbs/Qtr]

VIII. COMPLIANCE:

A. Rule 220.1:

1. Basel ine Period:

During the processing o f t he ERC app l i ca t i on , the basel ine per iod was evaluated t o assure compliance w i t h Rules 220.1.11.F. and 230.1.V.E. The basel ine per iod (8 calendar quar te rs ) used ends w i t h i n 180 days o f the removal o f t h e o l d i n c i n e r a t o r (e.g. A p r i l ’90 - March ’92) and, there fore , complies w i t h Rules 220.1 and 230.1 requirements.

2007027/101/201/30 1/40 1 /60 1 Page 7

2. Calculations:

Community Bank allotment was deducted from the AER as prescribed i n Rules 220.1.VI and 230.2.IV. Calculations i n determining the AER were used as described i n Rule 220.1. ERC complies wi th Rule 220.1.V.E.2.

B. Rule 230.1:

The ERC application, e l i g i b i l i t y and reg is t ra t ion are a l l completed according t o the requirements o f Rule 230.1. applicant has demonstrated the ERC t o be va l id by the d e f i n i t i o n i n Rule 230.1.111.0.:

1. Real: The o l d incinerator d i d ex i s t and was operated and

The

had actual emissions a t the location specified.

2. Surplus: The o l d incinerator has been replaced by a new incinerator (included on permit 2007245 -- see Appendix A). A l l emission increases from the new incinerator and associated equipment have been assessed under new source review. No emission reductions from the removal o f the o l d incinerator were required f o r approval o f emission increases from the new incinerator o r f o r the approval o f any other emissions uni t .

3. Permanent: The incinerator has been taken out o f service and rendered inoperable.

data and source tes ts determined the emission factors tha t were used. permit condition resulted i n less emissions.

5. Enforceable: Permit t o Operate 2007027A includes incinerator (16-Ml01) as par t o f the equipment on the subject PTO. removed and ta i lgas normally exhausted t o the incineration u n i t i s now required t o exhaust t o the new Ta i l Gas Treating Uni t l i s ted on ATC 2007245. Location can be inspected f o r equipment operating without v a l i d a PTO or ATC.

when the reduction actual ly occurred.

4. Quantifiable: Emissions were quanti f ied by actual fue l use

HAE were discounted where a prohibitory r u l e o r

On ATC 20070278 incinerator 16-MlOlhas been

6. . Timeliness: Application was submitted wi th i n 180 days o f


C. Rule 230.2:

The 10% deductions from the AER’s were made f o r the Community Bank and w i l l be deposited t o the Community Bank upon issuance o f the ERC .

2007027/101/201/301/401/601 Page 8

I X . RECOMMENDATION:

Upon completion o f 30 day p u b l i c n o t i c e per iod, issue Emission Reduction C e r t i f i c a t e s S-0002-2, '-3, '-4 and -5. See pages 9 - & f o r emission reduct ions on d r a f t ERC C e r t i f i c a t e s .

X. BILLING INFORMATION:

According t o Rule 306 t he a p p l i c a t i o n f o r ERC C e r t i f i c a t e 4007612/401/501/601 requ i res a non-refundable $650 fee. The $650 fee has been paid. The fee t o be pa id t o the D i s t r i c t w i l l equal $33.40 f o r each hour the Engineer has spent processing the app l i ca t i on ; p lus $16.61 f o r one hour o f c l e r i c a l time. I f the previous descr ibed t o t a l exceeds $650 t he d i f f e rence s h a l l be pa id by the app l ican t p r i o r t o issuance o f t he ERC C e r t i f i c a t e . Ca lcu la t ions show the maximum engineer processing t ime and the app l ican t no t t o pay add i t i ona l fees i s 18.96 hours.

Page. 5 2007027/101/201/301/401/601 , I . ,

Quarter 1 1425 lbs.

Southern Regional Office 2700 M St., Suite 275 * Bakersfield, CA 93301

~~

Quarter 2 Quarter 3 Quarter 4 1689 lbs. 1612 lbs. 1776 Ibs.

Emission Reduction Credit Certificate s-0002-2



For NO, Reduction In The Amount Of:


Method Of Reduction [ ] Shutdown of Entire Stationary Source [XI Shutdown of Emissions Unit [ ] Other:

David L. Crow. APCO


Page

2 0070a 7 / / b I / H p t f f vw p%ae La

.

Southern Regional Office 2700 M St., Suite 275 Bakersfield, CA 93301




For CO Reduction In The Amount Of:

Quarter 1 Quarter 2 Quarter 3 Quarter 4 4570 lbs. 5416 lbs. 5166 lbs. 5695 lbs.


Method Of Reduction [ ] Shutdown of Entire Stationary Source [XI Shutdown o f Emissions Unit [ ] Other:

David L. Crow, APCO

Page Seyed Sadredin Director of Permit Services

A

Southern Regional Office 2700 M St., Suite 275 Bakersfield, CA 93301

~~ ~

Quarter 1 1584 lbs.


Quarter 2 Quarter 3 Quarter 4 1877 lbs. 1791 lbs. 1974 lbs.



For PM,, Reduction In The Amount Of:



David L. Crow, APCO


Page

D"..,.

I .

2 0 0 7 0 2 7 / 1 0 1 / 2 n i / 3 n i ~ 4 o i / 6 ~ i

Southern Regional Oflice 2700 M St., Suite 275 Bakersfield, CA 93301




For SO, Reduction In The Amount Of:

Quarter 1 Quarter 2 Quarter 3 Quarter 4 55479 lbs. 65755 lbs. 62724 lbs. 69141 lbs.



David L. Crow, APCO


Page

r

ATTACHMENT A

. . . . .. . . . . - . , ,

' I I

Pagal,-d -5 .., L.

.e 2007027/101/201/301/401/601 - , *- . ,


PERM'T To OPERATE 2700 "M" STREET. SUITE 275 BAKERSFIELD. CA. 93301 TELEPHONE (805) 861-3682

Number: 2007027(A)

PERMIT TO OPERATE IS HEREBY GRANTED TO: TEXACO REFINING & MARKETING INC


EQUIPMENT OR PROCESS DESCRIPTION:


THIS PERMIT BECOMES VOID UPON ANY CHANGE OF OWNERSHIP OR LOCATION, OR ANY ALTERATION.

NOTE: The permittee may be required to provide adequate sampling and testing WILLIAM J. RODDY facilities. Equipment modification AIR POLLUTION CONTROL-GFF I CER

ClaUS/ATS Sulfur Recovery Plant Unit #16

c. requires a new permlt. <-.

REVOCABLE: This permit does not authorize By: . --. , ---1 . . .> \ I ! .' .. l; ! \ .,, , ,

I

the emission of air contaminants in excess of those allowed by the Rules and Regulations of the K.C.A.P.C.D.

CONDITIONAL APPROVAL: Compliance with all conditions of appr posed by any applicable Authority to Construct is required for life of this equip rQf? s' modified by application.

EQUIPMENT DESCRIPTION: Claus/ATS 4 r Recovery Plant Unit #16. including the following equipment:

a. Sour water stripper overhead knockout drum. b. Amine solution H2S knockout drum, c. Muffle furnace, 16-P-1, d. First stage reactor. e. Second stage reactor, f. Sulfur condenser, lG-V103, g . Sulfur storage tank, 16-Tl01, h. Primary reactor (ATSl, i. Secondary reactor (ATS).

k. ATS storage tank, 16-T3. 1. Miscellaneous vessels, heat exchangers and pumps,

n. Piping from sour gas oulet of MEA Regenerator (2007204) to Claus plant inlet .piping.



SO2 - 506.4 Ibm/hr. NO2 - 1 4 0 . 4 lbm/hr. and PM - 40.3 lbm/hr. If EMS is not operational, Claus ATS Sulfur Recovery Plant Unit #16 emissions shall not exceed the following rates: SO2 - 40.0 Ibm/hr. NO2 - 0 . 8 lbm/hr, and PM - 1.7 Ibm/hr. (All EMA

or Period: 08-31-90 TO 08-31-91 4

Mal-1-gas-Mcfne r a t orr-l6-M-l-Ok- s XLl;flJOd/L

. m. Ammonia storage tank.

2. Entire refinery emissions. as determined by EMS, shall not exceed the following rates:

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

/ i .. . 'I' 2007027/101/201/301/401/601 Page . . k.3. :,

KERN C O W AIR POLLUTION CONTROL DLTRICI'

APPUCATlON NO 20070278 April 18. 1991 -

issue DAFA :

MpIRAllONDATE: April 18. 1993 DATE: Hay 29. 1990


s T

27 29s

R Location : s(M-up lnspenion Daw :

27E 6451 Rosedale Hwy.. Area 1

AUTHORITY TO C D N m U C T IS HEREBY GRANTED To:

TEXACO REFINING & MARKETING. INC.

AUTHORITY TO CONSTRUCI' IS HEREBY G W FOR :

Modify Existing Claus Sulfur Recovery Unit.


c 2007027/101/201/301/401/601

t)

TEXACO REFINING 61 MARKETING INC. Permit #2001027(A) Page 2

3 .

4 .

5 .

6 .

7.

8 .

9 .

10

11

rates are to be one hour averages). EMS printout demonstrating compllan with C inspection by District staff upon n-.-ce.

dition #2 s 11 be ma ? avai ble for

Visible emissions from any single emission point shall not equal or exceed 20% opacity ( o r R#1) f o r any more than an aggregate of three minutes in any one hour. Combustion contaminating emissions from any single emission point shall be less than 0.1 gr/scf calculated to 12% C O 2 . Tailgas incinerator exhaust gas sulfur compounds concentration (as $ 0 2 ) shall ot exceed 2000 ppm by volumne and shall be monitored and recorded. Claus plant and ATS plant components shall be equipped with temperature indicators as necessary t o operate units in manner recommended by manufacturer. Tailgas incinerator burning chamber temperature shall be maintained at no less than 1 2 O O o F and shall be monitored and recorded. Hydrocarbon emissions from whole-refinery statioryqry source shall not exceed 2 . 4 1 6 . 9 lbm/day without prior District approval.

I. Sulfur processing capacity of Claus plant Texaco Refining & Marketing, Inc. to not exceed 2 0 . 0

. Claus/ATS effluent sulfur recorded. (Rules 108 and

1 2 . Operation shall not result

13. All connectors and piping shall be vapor-tight. (Rule 2 1 0 . 1 )

424 is required. (Rule 424)

4 1 9 )


Sulfur Compounds: 40.00 lbm/hr (as SO2) (Rule 210.1)

.. .~.. . .. . , .. . . . ' 2007027/101/201/301/401/601

Page 2 of

6 Pages

20070278 Continued

EQUIPMENT DESCRIPTION: Modify Existing Claus Sulfur Recovery Unit, including the following equipment and design specifications:

A. 8. C. D. E. P. G. H. I . J . K. L. M. N.

Acid gas K.O. drum 16-D-10A. (existing) Sour water gas K.). drum 16-0-108, (existing) Condensate pump 16-P-101, (existing) Two process air blowers 16-C-101/102. (existing) Muffle furnace 16-P-1. (existing) Sulfur Coaleser 16-V-103, (existing) Waste heat boiler 16-H-101, (existing) Sulfur condenser 16-E-101. (existing) Catalytic Reactor two stage 16-D-101, (existing) Sulfur Condenser 16-E-102, (existing) Sulfur storage pit 16-T-101. (existing) H2S/SO2 ratio analyzer/controller. (existing) Miscellaneous vessels, heat exchangers and pumps, (existing) Tail Gas Treating Unit and Incinerator shared with 2007245. (new)


Pursuant to Rule 209, "con is hereby granted. Please be aware that all conditions in effect for life of project unless modifications are a

DESIGN CONDITIONS:

1. No pressure relief valves shall be designed to relieve hydrocarbons or



4. All vessels, valves, flanges, connections and piping shall be designed and

5. All sampling connections, open-ended valves or lines shall be equipped with

sulfur compounds to refinery fuel gas system. (Rule 209)

concentration monitoring/recording system.




(Rules 209 & 422)


Page 3 Of

6 Pages

20070278 Continued


a. Area 1 fuel gas system sulfur content shall not exceed 0.10 gr/dscf as HP. (Rule 422)

b. Vessels shall be depressurized (during turnaround) as required by Rule 414.3. (Rule 414.3)

c. Sulfur Unit feed gas and gas produced from this emissions unit shall not be disposed of to Plare except during upset breakdown conditions pursuant to Rule 111. (Rule 210.1)

August 21. 1990 shall not exceed 2476.9 lbm/day without prior District approval. (Rule 210.1) Operation shall not result in odors detectable at or beyond property boundary. (Rule 419)

d. Hydrocarbon emissions from all emissions units existing in Area I prior to

e.

f. Operation shall not create a public nuisance. (Rule 419) n

EMISSION SAMPLING LIHITS:

Emissions sampling limits are limits for 2007245 as they are a common emissions point and missions limit.

SPECIAL CONDITIONS:

aa .

bb .

cc.

dd.

ee.

Texaco Refining and Marketing Inc. shall adhere to source testing, monitoring. recordkeeping and notification requirements of Rule 422 at all times. (Rule 422) During upset breakdown conditions pursuant to Rule 111 waste gas shall be disposed of only In manner approved by Dlstrict under Authority to Construct 2007245. (Rule 210.1) Overall refinery sulfur production shall not exceed 81 lt/day unless Authority to Construct 2007248 is fully implemented. (Rule 419) Overall refinery sulfur production shall not exceed 128 lt/day after Authority to Construct 2007248 is fully implemented. (Rule 419) When the tail gas treating unit is off line, total sour gas feed to SRU tl SRU t3 and SRU #4 shall not exceed:

42.00 MMSCP during the first year of operation of 13 SRU. 56.00 MMSCP during the first two years of operation t 3 SRU, 84.12 MMSCP during any consecutive three years of operation.

If any of these limits is exceeded, Texaco Refining and Marketing. Inc. shall construct a second tail gas treating unit (separate Authority to Construct required) (Rule 210.1 BACT Req)

. . _.-__ .._. - .. ..- .

, , . . . 2007027/101/201/301/401/601

Page 4 Of

6 Pages

20070278 Continued

SPECIAL. CONDITIONS CONTINUED:

ff. Texaco Refining and Market

Page . ,+-7 - ,.

E. Inc. shall monitor and recor sour gas rate This to SRU #I. SRU-#3 and SRU C4-when tail gas treating unit is offline.

information shall be submitted quarterly in refinery CEM report and original records be made available for District inspection upon request. (Rule 210.1)

gg. P r i o r to implementation of this Authority to Construct Texaco Refining and Marketing shall establish a computerized emissions monitoring system capable of providing the District with the following on-line emissions monitoring data on a call-up (In District office) basis:



Total sour gas production, n

SO2 concentration and SO2 emiss each tail gas treating unit.

Methods of viewing data and ormation shall be in a form approved by the Control Off

hh. Continuous emisslons monitoring and reporting system (Special Condition gg.) shall contfnuously log and report to District officcall exceedances of applicable sulfur emissions limits.

Authority to Construct. (Rule 210.1) ii. Authority to Construct 2007245 shall be implemented concurrently with this

STATE OF CALIFORNIA AIR M X I C S BOT SPOTS REQUIREMENTS:


STATIONARY SOURCE CURTAILMENT PLANS AND TRAFFIC ABATEMENT PLANS:

Facilities expected to emit 100 tons per year or more of carbon monoxide. hydrocarbons, particulate matter or oxides of nitrogen shall comply with KCAPCD Rule 613.

NOTES:

Rule 111 does not provide relief from legal action for volitions resulting from recurrent breakdown of same equipment.

Page 5 of

6 Pages

20070278 Continued


Maximum daily emission rate of each a i r contaminant from these emissions units under permits 20070278, ‘245 and ‘248 shall not exceed the following daily emissions limitation:

Particulate Matter (PM-10): 23.64 lba/day (Rule 210.1)

Sulfur ComDounds: 137.76 lbm/day (of SO,) (Rule 210.1) 20.64 lbm/day (of SO,) (Rule 210.1)

Oxides of Nitrogen: 84.00 lbm/day (as NO2) (Rule 210.1)

Hydrocarbons: 1.68 lbdday (Rule 210.1) stack 51.24 @./day (Rule 210.1) fugitive

Carbon Monoxide: day (Rule 210.1)

Compliance with daily emis ions shall be verified by source operator (with fuel consum , operational data, etc.) on daily basis and written document readily available to District f o r period of three years.


. , . r

. I '

. 2007027/101/201/301/401/601 Page ,+P KERN COUNTY AIR POLLUTION CONlROL DISIWCT


S T R Laation :

27 29s 27E 6451 Rosedale Hwy.. Area 1

2700 "M" Strecr. Suite 275 Flakenfield. CA 9331

(805) 861-3682


slm-up lnrpoction Date :

ISSUE DATE : April 18. 1991 APPUCA'TlON NQ 2007245

EXPIRATIONDATE: April 18, 1993 DATE: May 29, 1990

AUTHORITY TO CONSTRUCT IS HEREBY GRANTED To:

TEXACO REFINING EL MARKETING, INC.

~ ~

AUTHORITY To CONSI'RUCT IS HEREBY GRANTED FOR :

Claus Sul fur Recovery Unit, Tail Gas TreatinR Unit and Waste Gas Incinerator.


Air PoIIulion 580 9149015 (Rev. 6/89)

.. . . . .~. .. . .. . - ~

-*, . , . , a

.. ~ ~ ~ 7 0 2 7 / 1 0 1 / 2 0 1 / 3 0 1 / 4 0 1 / 6 o i

Page 2 of

8 Pages

2007245 Continued

EQUIPMENT DESCRIPTION: Claus Sulfur Recovery Unit, Tail Gas Treatinrr Unit and Waste Gas Incinerator, including the following equipment and design specifications:

SRU t3

A. B. C. D. E.

P. G. H. I. J. K. L. M. N. 0. P. 9. R .' S.

T. U. V.

W. X. Y. 2.

AA. AB. AC . AD. AB.

AF . AG . AH.

Combustion air blower 17-ClOlA 3600 scfm with 250 hp electric motor, Spare combustion air blower 17-Cl01B 3600 scf with 250 hp electric motor, Acid gas K.O. drum 17-D101 2 ft. 6 in. dia x 8 ft. 10 in. long, Two acid gas condensate pumps 17-P1OlA/B with 7.5 hp electric motors. Sour water stripper gas K.O. drum 17-D102 2 ft. 6 in. dia x 6 ft. 10 in. long, Condensate pumps 17-P102A/B with 5 hp electric motors, C l a w combustor 22.5 MMbtu/hr 17-S101. Thermal reactor 17R-101, Primary boller 17-E101. Primary sulfur condenser 17-E102. Catalytic reactor 17-R102 (three-stage), Final sulfur condenser 17-E105. Sulfur day tank 17-T101. Two sulfur transfer pumps 17-P103A/B with 15 hp electric motors,

Spare H2S/S02 and piping,

Tail Gas Treating Unit (all equipment new)

Tail gas reactor 17-R103 9 ft. dia x 11 ft. long, Waste heat steam generator 17-E109, Booster blower suction K.O. drum 17-Dl03 and booster blower discharge K.O. drum 17D-104 stacked over all 3 ft. 6 in. dia x 22 ft. high. Two booster blowers each 4100 scf with 250 hp electric motors, Quench column 17-V101 5 ft. 6 in. dia x 41 ft. tall, Quench water trim cooler 17-Ell1 with bypass valves/piping. Quench water dual bank air fan cooler 17-P101 with two 15 hp electric motors and isolation piping/valves, Two quench water circulation pumps 17-P105A/B with 40 hp electric motors, Two quench water Pilters 17-D105A/B, Absorber 17-V102 4 ft. 6 in. dia x 53 ft. high, Two lean solvent trim coolers 17-E112A/B with isolation valves/piping. Lean solvent dual bank air fan cooler 17-Fl02 with two 15 hp electric motors and isolation valves/piping, Lean oil solvent filter 17-D106A/B. Carbon filter 17-D107. Carbon after filter 17-Dl08.

. . .

.. . . , t

~007027/101/201/301/401/601

Page 3 Of

8 Pages

2007245 Continued

BQUIPMENT DESCRIPTION CONTINUED:

AI. AJ. AK. AL . AM.

AN. A0 . AP . AQ . AR. AS. AT. AU . AV . An. AX. AY .

BA . BB . BC . ED.

Two rich solvent pumps 17-P107A/B with 20 hp electric motors, Two lean solvent pumps 17-P107A/B with 20 hp electric motors, Lean rich solvent exchangers 17-E113A/B with isolation valves/piping. Regenerator 17-V103 4 ft. dia x 100 ft. high, Regenerator overhead condenser dual bank with two 15 hp electric motors and isolation valves/plping 17-P103, Two reflux pumps 17-P108A/B with 5 hp electric motors, Solvent sump tank 17-T104 6 Pt. dia x 18 ft. long, Solvent sump pump 17-PI09 with 5 hp electric motor, Solvent sump filter 17-Dlll, Lean solvent storage tank 17-T103 12 ft. dia x 15 ft. high, Solvent circulation pump 17-P110 with 5 hp electric motor, Two condensate pumps 17-PlllA/B with 25 hp electric motors, Two blowdown pumps 17-P112A/B with 25 hp electric motors, Hot oil heater 5 MMbtu/hr (permit exempt), Hot oil surge drum 8 ft. dia x I 8 ft. high. Two hot oil circulation pumps 17-P113A/B with 25 hp electric motors, Miscellaneous small vessels, pumps, heat &changers and piping.

Incinerator

Incinerator with 22 MMbtu/hr burner and Inlet H2S analyzer, In stack SO2 analyzer, In stack 02 analyzer.


Pursuant to Rule 209. "conditional approval" Is hereby aware that all conditions of approval remain in effect unless modifications are approved by District.

DESIGN CONDITIONS:

1.

2 .

3.

4 .

5 .

6. 7.

No pressure relief valves shall be designed to relieve sulfur compounds refinery fuel gas system. (Rule 209) Area 1 refinery fuel gas system shall be equipped with concentration monitorindrecording system. (Rules 209

200 it. stack,

granted. Please be for life of project

hydrocarbons or

hydrogen sulfide k 422) - .

Unit shall be equfpped with temperature indicators as necessary to operate units in manner recommended by manufacturer. (Rule 209) All vessels, valves, flanges, connections and piping shall be designed and maintained In vapor-tight condition. All sampling connections. open-ended valves or lines shall be equipped with two closed valves or be capped with blind flanges or threaded plugs except during actual use. (Rule 422) All new drains shall be equipped with a trap (water seal). Exhaust stack shall be equipped with continuously recording S02. and oxygen monitors. (Rule 108)

(Rule 210.1)

(Rule 422)

.. . .. .~

~ .~ . .

-., ' , ' , 5;

2007027/101/201/301/401/601

Page 4 of

8 Pages

2007245 Continued

DESIGN CONDITIONS CONTINUED:

8. Incinerator inlet shall be equipped with continuously recording H2S monitor on absorber overhead line: (Rules 108 EL 210.1 BACT req.)

9. Air fan coolers 17-P101. 17-P102. 17-Fl03 and exchangers 17-P112A/B and 17- E113A/B shall be sized to allow normal operation with one bank bypassed. (Rule 210.1 BACT req.) Exhaust stack shall be equipped with adequate provisions facilitating the 10. collectlon of samples conslstent with EPA i . e . , capped sample port in accessible location of uniform

OPERATIONAL. CONDITIONS:

a. Area 1 refinery fuel gas system(s)

b. Vessels shall be depressurized (dur gr/dscf as Hp. (Rule 422)

414.3. (Rule 414.3)

pursuant to

at not less than Rule 111. (Rule 210.1)

d. Incinerator firebox 1200%. (Rule 209)

e. Incinerator ased from a PUC carrier or

(Rule 209)

g. During normal and upset operation sour gas shall be balanced between all operating sulfur recovery units in a manner minimizing sulfur emissions. (Rule 209) Operation shall not result in odors detectable at or beyond property boundary. (Rule 419)

h.

1. Operation shall not create a public nuisance. (Rule 419)


Particulates (PM-10): 0.99 lbin/hr (Rule 210.1)

Sulfur ComDounds: 5.74 lbm/hr (of SO,) (Rule 210.1) 0.86 lbm/hr (of SO41 (Rule 210.1)

Oxides of NItro$?en: 3.50 lbm/hr (as NO2) (Rule 210.1)

Hydrocarbons: 0.07 lbin/hr (Rule 210.1) stack 2.14 Ibm/hr (Rule 210.1) fugitive

Carbon Monoxide: 0.88 lbm/hr (Rule 210.1)

..

: . . . 1 ’. . 3

’ . 2007027/10 1 /20 1 /301/401/60 1

Page 5 of

8 Pages

2007245 Continued

COMPLIANCE TESTING REQUIREMENTS:

Compliance with all emissions sampling limits except fugitive hydrocarbons shall be demonstrated by District-witnessed sample collection by independent testing laboratory within 60 days of initial startup, and official test results and field data submitted within 60 days after collection. Compliance with fugitive hydrocarbon emissions shall be demonstrated by emissions testing. maintenance and reporting as required by Rule 414.1 and 414.5. .(Rule 108.1)

SPECIAL CONDITION?

aa.

bb .

cc .

dd.

ee.

f f .

a.

Texaco Refining and adhere to source testing, monitoring, requirements of Rule 422 at all times. (Rule 422) Within one hour of upset recovery unit waste g shall not exceed 12.73 mscfh in each area flare. $ $ 4 1 9 ) In case of any exceedanh of any sulfur compound emission limitation or any condition which results in flaring of sour gas, Texaco Refining and Marketing shall, within 30 minutes of initial exceedance. begin to reduce sour gas production by removing high sulfur feed stocks and reducing unit rates and shall reduce total sour gas to flares to no more than 25.46 Mscf/hr within four hours of initial exceedance. (Rule 209) Whenever sour gas is being flared and odor complaints are received, the District may request further reductions in operations necessary to reduce flaring of sour gas. Overall refinery sulfur production shall not exceed 87 lt/day unless Authority to Construct 2007248 is fully implemented. (Rule 419) Overall refinery sulfur production shall not exceed 128 lt/day after Authority to Construct 2007248 is fully implemented. (Rule 419) When the tail gas treating unit is off line. total sour gas feed to SRU 21. sRU t 3 and SRU :4 shall not exceed:

42.00 MMSCP during the first year of operation of 23 SRU. 56.00 MMSCP during the first two years of operation t 3 SRU. 84.12 MMSCP during any consecutive three years of operation.

If any of these limits is exceeded, Texaco Refining and Marketing, Inc. shall construct a second tail gas treating unit (separate Authority to Construct required).

Rule 111 of any sulfur

(Rule 419)

(Rule 210.1 BACT Req)

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

.si , . 1

' - 2007027/101/201/301/401/601 , '_

2007245 Continued

SPECIAL CONDITIONS CONTINUBD:

Page 6 of

8 Pages

hh.

ii.

jj.

Texaco Refining and Marketing. Inc. sha monitor and record sour gas rate to SRU ~ 1 , SRU t2 and SRU S4 when tail gas treating unit is offline. This information shall be submitted quarterly in refinery CEM report and original records be uade available for District inspection upon request. (Rule 210.1)

Prior to implementation of this Authority to Construct Texaco Refining and Marketing shall establish a computerized emissions monitoring system capable of providing the District with the following on-line emissions monitoring data on a call-up (in District office) basis:



Total sour gas production.

so2 concentration and SO2 from each tail gas treating unit.

Methods of viewing data shall be in a form approved by the Control

Continuous emissions mo (Special Condition ii.) shall continuously all exceedances of applicable sulfur emissions limits. (Rule 209)



STATIONARY SOURCE CURTAILMENT PLANS AND TRAPPIC ABATEMENT PLANS:

Facilities expected to e8it 100 tons per year or more of carbon monoxide, hydrocarbons, particulate matter o r oxides of nitrogen shall comply with KCAPCD Rule 613.

Rule 111 does not provide relief from legal action for violations resulting from recurrent breakdown of same equipment.

. . . . . . . . . . . . . . . . . . . . . . . . . . . . .- . . . . . . . . . . . . . . . - . - ._

. . .. ' . i.

. 2007027/101/201/301/401/601 . . : 9

Page 7 of

8 Pages

2007245 Continued


Maximum daily emission rate of each air contaminant from these emissions units under permits 20070278, '245 and '248 shall not exceed the following daily emissions limitation:

Particulate Matter (PM-IO): 23.64 Ibw/day (Rule 210.1)

Sulfur Compounds: 7 . 7 6 lbm/day (of S0-J (Rule 210.1) 4 64 lbm/day (of Sod) (Rule 210.1)

84.00 Ibm/day (as NO?) (Rule 210.1)

1 .68 lbm/day (Rule 210.1) stack G& 51.24 lbm/day (Rule 210.1) fugitive

Oxides of Nitrogen:

Hydrocarbons:

Carbon Monoxide: 21.00 lbm/day (Rule 210.1)

Com~liance with daily emissions limitations shall be verified by source operator (with fuel consumption data, operational data, etc.) on daily basis and written documentation made readily available to District for period of three years.

RULE 210.1 (NSR) DAILY EMISSIONS LINITATIONS: (See attached.)

. .. . . . . . . . . . . . . ..

.’ ...,

2007027/101/201/301/401/601

ATTACHMENT B

. , !

2007027/101/201/301/401/601

5FHS302 TOTAL OFFGAS TO CLAUS FURNACE TIME MSCFHR 1200 34.16 1300 32.46 1400 33.12 1500 33.84 1600 34.20 1700 34.39 1800 34.03


PARTICULATE 1.02 0.030 SULFATE 0.56 0.017 so2 39.70 1.175 NOX 1.02 0.030 co 3.27 0.097

LBIHR LBIMSCFHR

34.03 1900 I I I

l6FHS302 TOTAL OFFGAS TO CLAUS FURNACE MSCFHR QUARTERLY AVERAGE

1990 1991 1992 MSCFHR JAN 30.82 30.89 1 27.51 FEB 23.26 30.80 2 28.48 MAR 18.82 30.46 3 26.78 APR 22.63 32.68 4 29.59 MAY 26.79 27.33 JUN 28.95 32.50 JUL 27.50 33.23 AUG 28.86 32.22 SEP 28.84 10.01 OCT 30.16 30.52 NOV 24.81 31.63 DEC 27.71 32.71

QUARTERLY EMISSIONS LBlDAY

1 2 3 4

PARTICULATE 19.94 20.64 19.41 21.44 SULFATE 10.95 11.33 10.65 11.77 so2 775.93 803.34 755.29 834.65 NOX 19.94 20.64 19.41 21.44 co 63.91 66.17 62.21 68.75

_ r

2007027/101/201/301/401/601 Page , 8 - 3 ~

TABLE 3-1. SUMMARY OF SOURCE EMISSION TEST DATA ( 6 O O F )

Unit Tested: Texaco R & M SRU Incinerator


Barometric Pressure (in. Hg) Stack Pressure (in. Hg) Stack Area (ft') Elapsed Sampling Time (min.) Volume Gas Sampled (dscf)

GAS DATA

Average Gas Velocity (fps) Average Gas Temperature ( O F )

Gas Flowrate (dscfm) Gas Analysis . (Volume %)

Carbon Dioxide,. dry Oxygen, dry Water

1 Offset

29.90 29.88 4.91

120.00 90.541

44.75 957.17 4,460

5.00 5.23 7.66


Filterable Particulate (gr/dscf) Total Particulate (gr/dscf) Total Sulfate (gr/dscf) co .(PPm) 131.50

36.75 (PPm) so*

NO, (PPm)

EMISSION RATE - 1 b/hr

Filterable Particulate Total Particulate Total Sulfate co 2.60

1.19 so* NO,


2 Offset

29.90 29.88 4.91

120.00 90.541

44.75 957.17 4,460

4.98 5.08 7.66

0.0353 0.0485 0.0176 157.54 839.63

32.73

1.35 -1.85 0.67 3.11

37.94 1.06

3 Offset .

29.88 29.86

4.91 120.00 89.299

44.88 959.08

4,536

4.97 5.36 6.14

0.0180 0.0300 0;0115 204.77 902.30

24.68

0.70 1.17 0.45 4.11

41.46 0.81

Average

29.89 29.87 4.91

120.00 90.127

44.80 957.81 4,485

4.98 5.22 7.16

0.0267 0.0392 0.0146 164.60 870.97

31.39

1.02 1.51 0.56 3.27

39.70 1.02

3-2

. . I

2007027/101/201/301/401/601

ATTACHMENT C

. , .I

2007027/101/201/301/401/601

MONTH



JAN '92 FEE '92 MAR '92 (1 Not us

8 c a l e

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


Mscf/Hr Mscf/Mnth __________-----___________ _________---------________ 0.00 0.00

(18.82) (583.42) 22.63 16293.60 26.79 19931.76 28.95 20844.00 27.50 20460.00 28.86 21 474.07 28.84 20764.80 30.16 22439.04 24.81 17863.20 27.71 2061 6.24

--- ---

30.82 23.26 30.46 32.68 27.33 32.50 33.23 32.22 10.01 30.52 31.63 32.71

22930.08 15630.72 22662.24 23529.60 20333.52 23400.00 24723.12 23971.68

7207.20 22706.88 22773.60 24336.24

QUARTER


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

Page

.~ , , . a

2007027/101/201/301/401/601

QUARTER


--------- ____--_-_

QUARTER


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

PM10 1 SO4 I SO2 I NO2 I CO ............................................. ............................................. 1425.63 0.00 55479.23 1425.41 4569.70 1689.68 0.00 65754.88 1689.42 5416.08 1611.79 0.00 62723.64 1611.54 5166.41 1776.69 0.00 69141.04 1776.42 5694.99

QUARTER


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

QUARTER

JAN-MAR APR-JUN JUL-SEP OCT-OEC

-_-______ _-_____--

ACTUAL HISTORICAL EMISSIONS

PM10 I SO4 I SO2 I NO2 I CO ............................................. ............................................. 15.84 0.00 616.44 15.84 50.77 18.57 0.00 722.58 18.57 59.52 17.52 0.00 681.78 17.52 56.16 19.31 0.00 751.53 19.31 61.90

Lb/Qtr PHI0 I SO4 I SO2 I NO2 I CO


PMlO I SO4 I SO2 I NO2 I CO

158.40 , 0.00 6164.36 158.38 507.74 187.74 0.00 7306.10 187.71 601.79 179.09 0.00 6969.29 179.06 574.05 197.41 0.00 7682.34 197.38 632.78

Lb/Qtr

............................................. .............................................

Page

.. _ I _,

2O07027/101/201/30 1 /40 I /60 1

ATTACHMENT D

., : .>

2007027/10 1 /20 1 /30 1 /40 1 /601 Page

1991 AIR QUALJTYATTAJNMENTPLAN ?e.-+.

EXTERNAL COMBUSTION DEVICES BOILERS, STEAM GENERATORS, PROCESS HEATERS, DRIERS

SOURCES AFFECTED: All existing boilers, steam generators, process heaters and driers subject to permitting may be affected. This control measure does not apply to boilers used to generate electricity. SCC and CES codes are shown below.




DESCRIPTION OF CONTROL MEASURE: The District will reduce NOx emissions by implementing several rules that establish emission standards for different categories of existing external combustion devices. Each separate rule will control NOx emissions from a distinct category with subcategories based upon size range andlor type of combustion device, e.g. large steam generators, refinery process heaters, small package boilers. These rules and the requirements therein will be based on energy, environmental and economic factors specific t o the SJVAB at the time of rule development, and specific emission limits, exemptions and applicability criteria will be developed for each subcategory in each rule development process, after consideration of e ~ i s s i o n limits achieved in practice and cost effectiveness.

This control measure will be implemented in four phases based on source type and control type; several rules, or sets of requirements within rules, may result from each phase of the control measure. Each type of external combustion device operating in the SJVAB will be addressed in the control measure: equipment types not addressed during one phase of the control measure will be addressed in another phase.

Phase 1 of the external combustion NOx control measure will target larger combustion devices such as process heaters, boilers and steam generators, over a certain MMBtulhr heat input capacity. MMBtu/hr "cut-offs", used to define

7 - 26 . .-

I . . . . , - .. %%3

.. . 1 _. 2007027/101/201/301/401/601

l%L.. T:: 1991 AIR QUALITYATTAINMENTPLAN

applicability of the rules, may vary for different equipment types; these cut-off values will be determined during rule development.

Recognizing that many SJVAB external combustion devices burn crude or fuel oil, Phase 2 of the control measure will address encouraging the use of "clean fuel" as a NOx. reduction technique. The lowest NOx emissions for any type of combustion. device are achievable through combustion of natural gas in place of other fuels; it is anticipated that the District will encourage (or require) switching to natural gas, where such a switch is feasible and cost effective.


Phase 4 will address driers used in food processing and other industrial processes.

Operators will be able to achieve the emission standards by applying available control technology such as oxygen trim, low-NOx burners, flue-gas recirculation (FGRJ, selective catalytic reduction (SCR), selective non-catalytic reduction (SNCR), or radiant burners.

The suggested standards below are from the ARB Draft Determination of BARCT for boilers, steam generators and process heaters. In the ARB Draft Determination, less stringent requirements are suggested for devices wi th fuel input less than 90,000 therms annually. The ARB BARCT determination will be the starting point for development of the external combustion NOx strategy, but as stated above, District rules and the requirements therein will be based on energy, environmental and economic factors specific t o the SJVAB and different source categories at the time of rule development.

Gaseous Fuel Liquid Fuel

pDm NOx @3% 0, -2 Ib NO /MMBtu 30 0.036 40 0.048

EMISSIONS ESTIMATES: NOx - TonslDay

Baseline Inventory: 89.16 85.89 87.67 88.49 Anticipated Reduction: 65.13 66.41 66.98 Remaining Emissions: 20.76 21.26 21.51

- 1987 1994 1997 2ooo

. . . . . . . .. .?.". . :-.., . .. 7 - 27

. .I _,

2007027/101/201/301/401/601

./i.. 1991 AIR QUALITYATTAINMENTPLAN - The emissions reductions shown are based on the ARB Draft BARCT Determination for Boilers. Steam Generators and Process Heaters.

COST EFFECTIVENESS: For retrofit applications, technological feasibility and costs of control are dependent on energy availability, equipment location, type of control, operating capacity modes, and physical size of the heaterlboiler. Thus, some control techniques that are feasible for larger devices may not be practical for smaller devices because of cost or effect on efficiency. 'Burner replacement may be the most cost effective control technique for smaller boilers. ARB estimates the cost effectiveness of several typical control technologies as shown below. In general, cost effectiveness improves with size of the unit and annual usage rate.

Unit Size Range Cost Effectiveness Control Techniaue JMMBtulhrl 1-1 Low-NOx Burners 25 - 150 $300 - $27,000 Flue Gas Recirculation 10 - 350 $1,000 - $29,000 Selective Noncatalytic Reduction 50 - 375 $1,300 - $20,000 Selective Catalytic Reduction 50 - 350 $4,000 - $66,000

:-*. :...*:::.

. .-., .~ .. .-. - Santa Barbara County APCD estimates cost effectiveness for control of NOx -;>+

emissions from smaller boilers using radiant burner technology as shown below:

Boiler Size Total Cost Effectiveness JMMBtulhrl EauiDment Cost $/ton NOx reduced

1 $18,000 10,000 5 $25,000 3,000 10 $30,000 2,000

Mobil Oil Company has identified the cost of retrofit of flue gas recirculation technology for their steam generators to be approximately $36,000 per year per large (62.5 MMBtu/hr) steam generator. This retrofit reduces NOx from a single natural gas-fired generator by about 28 tons per year, for a cost effectiveness o f $1,300 per ton of NOx reduced. Mobil Oil's steam generators using flue gas recirculation currently have limits of 0.04 IblMMBtu.

As of June 6, 1991, Kern River steam generator fuels cost $1 2 per barrel ($1 .9O/MMBtu) for produced oil and $2.75/mcf ($2.6O/MMBtu) for produced natural gas. Assuming fuel costs remain constant, switching fuels from crude oil t o natural gas to reduce NOx emissions would cost approximately $5,800 per ton of NOx reduced. However, with increased availability, local natural gas prices are

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- 7 - 28

f-5---, 199 1 AIR QUALITY A TTAINMENT PLAN

expected to decrease. Additionally, flue gas sulfur scrubber operational costs, and maintenance costs associated with burning crude would be almost eliminated.



Phase 1 Phase 2 Phase 3 Phase 4 Draft Rule: 10192 10193 10194 1 0195 Workshop Rule: 20192 20193 20194 20195 Adopt Rule: 40192 40193 40194 40195 Full Implementation: 40194 4Q195 40196 40197

ENFORCEABILITY: Compliance is dependent on initial and annual emissions tests, annual inspections. Requirements for continuous emission monitors on large sources, and maintenance of operating logs will enhance the District's ability to enforce any proposed regulation.

p"ri -7

TECHNICAL FEASIBILITY AND PUBLIC ACCEPTABILITY: Technology for certain combustion devices is currently in use that can achieve the NOx emission standards suggested in the ARB BARCT Determination. Implementation of this measure will be affected by the availability of clean fuels to meet fuel conversion demands. Pipeline capacity increases are expected to meet the increase in demand for natural gas. The MojaveIKern River Pipeline project, which is expected to be completed in 1992, could provide an additional 1.1 billion scf of natural (equivalent t o approximately 200,000 barrels of oil) gas per day. Public acceptability is expected to be neutral.

HEALTH, ENVIRONMENTAL, ENERGY, AND SOCIAL IMPACTS: Spent catalyst materials, including vanadium pentoxide, are considered hazardous materials and would have to be deposited in a Class I landfill; the only operational Class I disposal site in California is in Kings County. Ammonia emissions may occur if SCR or SNCR is used. Combustion of natural gas in place of residual, distillate or crude oil will result in lower toxic, carbon dioxide, particulate and SO2 emissions. Additional electrical energy will be required to operate all control systems. The control measure will encourage natural gas fuel use over fuel or crude oil.

7 - 29

1991 AIR QUALITYATTAINMENTPLAN

Switching from crude or fuel oil combustion to combustion of natural gas will reduce emissions of polycyclic aromatic hydrocarbons and toxic metals, some of which are known carcinogens. Minor increases in emissions of benzene and formaldehyde may result from the increased use of natural gas.


Air Resources Board. Draft ProDosed Determination of Reasonablv Available Control Technoloav and Best Available Retrofit Technoloov for Industrial, Institutional and Commercial Boilers, Steam Generators and Process Heaters. 1991.

Air Resources Board. 1989. Emissions Inventory Criteria and Guidelines Regulation Pursuant to the Air Toxics "Hot Spots" Information and Assessment Act of 1987. Sacramento, California.


Brinkman, P. E., Mobil Exploration and Production Company. 1990.. Letter to Scott Nester, Kern County APCD. June 20, 1990.



Pease, Robert R., Martin L. Kay, Andrew Y. Lee. "Industrial Boilers: Status of Oxides of Nitrogen Regulations and Control Technology in the South Coast Air Quality Management District", 1989, Annual Meeting and Exhibition, Air and Waste Management Association, June 1989.


South Coast Air Quality Management District. Best Available Control Technoloay Guideline. October 1988.

... ;>. ?~ . .. .... . &As

7 - 30

...

. -

,-A\. 199 1 AIR QUALITY ATTAINMENT PLAN - South Coast Air Quality Management District. Rule 1109 - Emissions of Oxides of Nitrogen from Boilers and Process Heaters in Petroleum Refineries. August 5, 1988.


South Coast Air Quality Management District. Draft Rule 1 1 77 - Best Available Fuel Standard. 1991

South Coast Air Quality Management District. p, "Appendix IV-A: Tier I, Tier I I and Contingency Control Measures". March 1989.


US Environmental Protection Agency. 1985. Comoilation of Air Pollutant Emission m, Fourth Edition. Research Triangle Park, North Carolina. ~&* &;& ...... . . ...... -w


SCC

10200401 10200402 10200403 10200501 10200502 10200503 10200601 10200602 10200603 10200701 10200799 10200902 10201002 10201201 10300401 10300402 10300501 10300502 10300503 10300601 10300602 10300603 30290003 30600101 306001 03 306001 04 306001 05 306001 06 31 000402 31 000403 31000404 31000411 31000412 31000414 39000499 39000599 39000603 39000689 39000699 39000889 39001099

CES

47142 471 59 471 67 58727 66795 66803 82073 82081 83071

7 - 31

SAN JOAQUIN VALLEY UNIFIED AIR POLLUTION CONTROL DISTRICT EMISSION REDUCTIONS FOR DEPOSIT IN COMMUNITY BANK

RE: EMISSIONS REDUCTIONS FOR DEPOSIT IN THE COMMUNITY BANK:

Emission credits are to be added to the Community Bank because they are:

d o n s i t e actual emissions reductions. - exces,s offsets required and obtained pursuant to cffset ratios

__ returned from a so not engaged in a continuous program

- Other (Description

unclaimed actual emissions reductlons.

of construction wi of ATC issuance.

Permit No:

Describe Action Generating Credits: @,h,4 , . u o ~ y z j & &&.;e/

AVERAGE DAILY EMISSIONS REDUCTION CREDITS (lbs/day)

SJVUAPCD Form EN4

. . .. .~. .. .: .... 'L .i-.==.. . . . .. '..

FINAL CHECKLIST -_._ - -

I Eng ineer ing ana lys is inc ludes a l l i t e m s d e s c r i b e d . i n u i d e l i n e s . a l l i tems appear i n c o r r e c t o rder , and a l l p a r t s o f a n a l y s i s read l o g i c a l y and are l e g i b l e . 9 -

flKRu1 210.1 C e r t i f i c a t e of compliance, i f requi red, has been rece ived and i s o f - &r c o n t e n t and form. - VPackage i s d i v i d e d i n t o sec t ions (each one i n a f o l d e r ) as descr ibed i n guide l ines

each f o l d e r has a c o r r e c t l y prepared l a b e l .

Rough d r a f t A's t o C have been prepared i n accordance w i th g u i d e l i n e s and i n c o r r e c t fo rmat wi th c o r r e c t punctuat ion. D r a f t s read l o g i c a l 1 and a r e l e g i b l e . Each Design p . . Opera t iona l c o n d i t i o n i s . f o l l o w e d by number o f ru 7 e r e q u i r i n g t h e c o n d i t i o n o r

r o v i d i n g b a s i s f o r t h e cond i t ion .

&Applicant has been n o t i f i e d by te lephone o f a l l c o n d i t i o n s appear ing i n A's t o C b u t n o t proposed i n a p p l i c a t i o n .

- ' Emissions summary sheets (one. for ,whole p r o j e c t and one System 36 p r i n t o u t f o r each A t o C1 have been DreDared i n c l u d i n g n e t emissions change f o r whole s t a t i o n a r y - I

I source; NSPS s t a t u s has been marked;

emiss ion r a t e has been se t , and compl iance (on a moving" y e a r l y average) has been requ i red .

/&NSPS/NESHAPS, BACT/LAER, and/or NSR r e p o r t has been prepared, with t h r e e copies o f each.

- d&miss ion p r o f i l e s have been prepared accord ing t o - g u i d e l i n e s . a maximum d a i l y

t'& KCAPCO Grant Ob jec t ives r e p o r t has be,en prepared .for approval o f source e m i t t i n g over 82 lbm/dav PH., and f o r sources n e t t i n g o u t o f NSR requirements f o r any c r i t e r i a a i r contah7nant.

j u s t mark " i n l e t " , " o u t l e t ,

p r o j e c t , even i f t h e r e is no fee due f o r one o r more A 's t o C.

(understandably and c l e a r l y descr ibed) which r e s u l t e d i n unnecessary expenditure o f t ime; unnecessar meaning t h a t t h e t i m e would n o t have been spent i f t h e a p p l i c a t i o n

& Source t e s t requirements s p m a r y has been repared ( d o n ' t s p e c i f y emission l i m i t s ,

W e r m i t f e e b i l l i n g e d i t has been prepared which inc ludes a l l A ' S t o C Involved i n

A o b l e m s encountered summary sheet has 'been prepared which inc ludes a l l items

u n i t s " , e tc .7 , and one copy has been made.

had been c o r r e c t r y submit ted, t h e d a t a was a l l c o r r e c t , no changes were made ' in e tc .

e v a l u a t i o n t ime sheet has been Drepared which incudes a l l t ime spent i n - - processing- the , a p p l i c a t i o n s . This i n c l u d e s t ime spent d iscuss ing t h e a p p l i c a t i o n w i t h o t h e r s , t ime spent r e v i s i n g , e t c .

gned: , P r o j e c t E v a l u a t i o n Engineer

, i t i a l e d : , Reviewing Engineer

r APPROVAL BLOCK I WrrL4J-w I DATE L ,

A. Preliminary Review - Application Deemed Incomplete

2. Permit Senices

DISTRICT MANAGER REVIEW: [ ] NOT REQUIRED [&QUlRED [ ] Engineering Evaluation E n c l o d [ ] Draft Imminent Denial Letter Enclosed [ 1 Draft ATC(s) Enclosed [ ] PRELlMIN.PN Enclosed

H. District Manager of Permit Services Approval

PROJECTS REQUIRING PUBLIC NOTIFICATION

[ ] PELMINARY DISPOSITION [ ] Dcliver Ad to the Ncwrpapu NOT LATER THAN [ 1 Mail copies of Cover b c r M d Engineering Evduation to Diruibution.

[ 1 Ddivsr Ad to rho Newspaper NOT LATER THAN [ ] Mail copicr of Cover L u c r M d Authoriry(icr) to Connrvct to Disiribution.

[ ] Dcliver Ad u) rhc Newrpapsr NOT LATER THAN [ ] Mail copies of Cover Lmu to Diruibution.

[ ] FINAL DISPOSITION - APPROVAL.

[ 1 FINAL DISPOSITION - DENW:

PROJECTS NOT REQUIRING PUBLIC NOTIFICATION

[ ] PRELMINARY DISPOSITION - DENIAL:

[ ] FINAL DISPOSITION - APPROVAL:

[ ] FINAL DISPOSITION - DENIAL

[ ] Msil Imminent E n i d h c r to the Applicant

[ 1 Mail Aurhoriry(ier) u) Construn to ahc Applisant

[ ] Mail Denial Lsner to rhc Applicant.

..-. OF - -. .r'

Company Name: ?eA/etd &,LN,uc 1 h p t ~ w SJL,

Company Number: >e)? - Project Description: p&, , c ?v 5-L?$&,7,, d/ I /Nffk-w&

Project Numb/er: q$l)7/6

Processing Dates, Including Preliminaries: 8//7/7&9 (@//'7/?- ' 1

PAOCESSING:

Initial Contact: - telephone - in person Project Entry into System 36:

Preliminary Review:

Organization/Familiarizacion:

Project Description/Schematic/Equipmenc Listing:

Listing of Applicable Rules:

Design Review of Air Pollution Control Equipment:

Calculation of Expected Emissions:

Air Quality Impact Assessment Review (Modeling):

Preparation of Emission Profiles:

CEQA Review:

Health Risk Assessment Review:

Reworking of Applicarion Due to Changes:

Preparation of Rough Draft A's to C:

Preparation of Written Requests for Information:

Telephone and Verbal Requests for Information:

General Meetings with Applicant:

System 36 Data Entry (Including Emissions):

TOTAL TIME SPENT ON EVALUATION:

-: JNITAL:

h

0

111 111 111 111 111 111

.. h

m

I I

Documents

Emission Reduction Credit Certifdate s-0002-2Proiect 2007 92071 6 The District has issued an Emission Reduction Credit (ERC) certificates for project #2007 920716 to Texaco Refining