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HomeMy WebLinkAbout1.03 Application• � 6 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Gl Emission Source AIRS ID: s rrlreadti ass?yned a permit 4 & AIRS ID] {Leave Want unless APC Permit Number: nt is referenced within your organization.] [Provide Faciliry Equipment Ii) to identify how this equi Facility Equipment JD: n (Check applicable request boxes) 0 A i L o 0.. .1'- u y E C :s: 4 r k•' . p C C. w - c w r G 'u F E 4 .a E x 'E E C .. 8 : - ? E. d er 7 r TO id e ; e' 4 C '7 L C O u ❑ ❑ N .^ 3 e L. v .3 w E J. I. L. Cm . C ai U C U 'J % C i W :v ueaC :n L v C iz c' C'ETi: d C G .E f C J N X C G in a M '1= V -.7.O.. < iV G C ..r. .. '- C .a V 4 .= I ar Cs a d C C a a 0 E 0 r � k u C El II �e Information Section 01 — Admintstr M OX 5 [iSA NYTP LF Conn Creek Gas Treating Facility 1 County: Garfield w oo� 20 CI l C- B L 7 Mailing Addres 0 C `. C : C C C3 Alonzo llernander Person ro Contac 0 C\ F C C w I C C E-mail Addres for new or rceonstruc N a C OL O Don't know 0 S! E O w. C C H V 0 u 0 C N C r/Y Al E a C. E 9 C Will this equipment be operated in any NIAAQS nonatiainrnent area? [Itttp:/Attttv_cdphe.statc.co us/ap!attainmaintain.html) ■ /i1 Fs. J ��.• r E �+ „ a ` 7,1 Y 3 G V) y.„ 7 V= O C C V rs 6Pry ° C tJ A as C a .6 .,,C C d .j r -8 .f y V q . E. ' c C a ! a E_C u Q. [i C G l9 V E.. © f VU V A 6y n .ac - L °� I— j '= . {, d� ® a '� C l, APEN forms: huft;l/3 a 3 C C C a 0 0 E y O o N r C C ' = C C R IA C u •C I O L u7 O z C, 0 ao v a .o g 7 E e 3 U valet- content: u x C C H z z 0 C u 4' C. C Co .L.a R �C L L C o o 8 u = c- E C C G 4 u m �_ a y 7 =Qy C G E b L' H V n 0. C a. G. C S E d O. es C u L0 N t. ❑F Ur Q +� "r 2 N u U u - F C V 2 OL IO2 -o rq C tel It 0. 0 C C Water Content: N V C r2DchyAPEN_TEG CC(iTF I FormAP('I) C) O t'? 4 u7 G Emission Source AIRS ID: 0) CD CP 0 PIP O Permit Number: 06 —Stack (Source, if no combustion) Location (Datwn & either tC tion (Combustion stacks must be piste Section 05—Stack_infor ft 4 4 ar C c 0 C v. -C 2 a a C C NC C 0 cr, L E C O c i C oi i E R 1 rr ad G. v M Ad w u U a f'leasv use the ANCD Non -Criteria Reportable Air Pollutant Addendum Corm to report pollutants not listed above. k:.titir75alipt hanissiot Non ..+. K ^ v ....7.:. -,Y :.i :] G. a 3 0 o e o o e U H - o G - C V 4.0' Si, .g r- r7 Y I t. LV Yat < 1 Units r .0 V .. r IS c Unconi RI 1112:1 13 sis Identify in Section 07 Ye c. IH X) Icnc n-1 lexanr a° l r C = C C C CCG 11 1 Fu ENSR APEN for Permit No. 06GA1232 -- New 3 -Phase Separator Heater for Existing Tank Battery 05252-005-140 October 2C08 • v C 1 E L GJ ri • • 47 0 Emission Source AIRS ID: a w a7u [l.c.o.c blank unless AI (.I) bar slr. Permit Number: 11.04 tho%equipincirl 1y, 1Ctc'rcries4 N11I1111 •0111 V:1'J11ILatlun I Prmldc l iclllt}' hqul LL n (check applicable request bones) u; L compar.) name Change fuel or eauipmcnt LU ❑❑ ❑L n C U U Q 2754 Compass Drive. Suite 17 4970) 245-2523 Fati Number l'crstxl To Conuict E -Mail ''oldies. Section 03 — C'ener:t Information the pIOIeeled startup date 0 O r. II r+y 7;1 C' C C rV 771 G 7.41 C$ GC J. s 4 c • LLS a E c :2 A I- J ._ I c i D C. Q s Nlanufucturer 0 C c. LA 8 G C- i U r a c c c C tC z `o o a J 4 U 0' c CO U 1 G rd ®YJ 4 i c •'l L if n G y 3 7 ra y ci mould c000dcr poseess rr0ulll u�c twllons Requested i II FormAPCQ2(iimer3IAPi.k 3•Prom. IIralc; dot: FORM APCD-200 • • • AIR POLLUTANT EMISSION NOTICE (ADEN) & Applicatinn fnr CInstruction Permit — General C e. co a,*s FriK7 -0 co yr1yr� c� C 0 U N E J c e N L u U, CI. Q E E cn. C Emission Source AIRS ID: rry oto 2 s 3 ,t E {lihet ( Dew( U v. 7 0 "". N C J C . ❑ 0 0 0— f G 0 U 0 C 7 N N i L£� F. U va Pei w Lti IF" O tot 0 a E G 0 n 06 — Combo ldcnrlification No,: Company t quipn T. 5 13,8 iI IIJturhr 7, e z E Section 47 — Emissions Inventory Information & Emission Control Information iun factordocurncmaunn to this -11'I N 1nm1. -C 7 AP42 '[h1 1-4-2 AP42 ThI 14- I AP42 Thi L4-2 AP42 f7.1 1.4-I FA Vy C a L U i C C E ij G H p 4 6 r' C t G (.1 a d C C a Er 0 E L'] 4 4 w u [moi V 4 Vi J 41. C r - r, x C tr- r 7- C .2 to C.' 0 V ii ems-' so '!I C U C A 0. b C M; C c 000f CNo Q .. N C- C - a Misr 1lcatrr dor 1'1. 11 € onnrlP(-1)-:0J General. • ENSR • • O&M Plan for New RICE 05252-008.140 October 2008 • Furtn APCD-301 Colorado Department of Public I leaIih and hnvironinent Air Pollution Control Division • • Operating and Maintenance Plan Template for Reciprocating internal Combustion Engines Ver. September 10. 200S The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) template for reciprocating internal combustion engines that are permitted at synthetic minor facilities in the State of Colorado. The O&M Pian shall be submitted with the permit application. A single 0&:\•I Plan can be used for all engines at the facility. If the O&M Pan template is completed correctly, the Division will approve the OEM Plan and a construction permit .yell be issued with the requirement to follow the O&M Plan as submitted, if the template is not completed correctly. the Division will work with the facility to make corrections. Once a construction permit is issued, tete facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators arc not required to use this template. Independent case specific O&M Plans may be etcweloped and submitted for approval with the permit application. 1lowever. the Division encourages the use of this template to expedite the permit application approval process. rl �rrr (:.3111r4duI) p irlrlelIt of l'lublkk 1 IEalrll and hivironineitt Submittal Date.: Section 1 - Source li1entificatinn For new permits some of this information (i.c. Facility AIRS ID, Facility t:quipment ID. Permit Number, and AiRS Point ID) tnay not be known at the time of application. Please fall fill out those fields that arc known And leave the others blank. C'onipan) Name: Facility Name: OXY USA `,V1 P LP Conn Creek [las i reating Facility fl Facility Location: S32 11)S 8912, Garfield County Facility AiRS ID (forextsting facilities) Units Covered b this O&M form Facility Equipment ID L9 Cat 3616LE EIO Cat 3616LE El 1 Cat 3616LE E12 Cat 3512LE E'I3 Cat 3512LE E14 Cat 3512LE AIRS Point iD new my., rie`w 11 CIA' flew nes Permit Number new new new new new new Rich Rurn (RB) or Lean Burn (LB) LB LB LB LB LB LB Air Fuel Ratio Controller (YON) t` Y Y Y l Y Catal si Tv e' SCO SCO SCO SC() SCO SCO " Non-selective Catalytic Reduction (NSCR) or Selective Oxidation Catalyst (SCO) Section 2-,7i7aiutenancc Schedules Check one attic following: Facility shall Ibllow manufacturer recommendations for the operation and maintenance of equipment and control 1Z devices. i -hese schedules and practices. as well as any maintenance records showing compliance AA ith these recommendations. shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control d.wices These schedules and practices. as %veil as an mattue lance records showing compliance © with these recommendations. shall be made available to the division upon request and should be consistent with good air pol,u:ion. co ,tra1 practices for minimizing emissions as defined in the New Source Performance Standard (HSPS) general conditions. Page 1 of 4 C'Ct;l l' !! I:ormAt1CD-39 f •RICIsO&t t-V,.:r 9-10-201S dew Colorado Department of Public Health and Environment Air Pollution Control Division Section 3 - Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The operator will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and maintenance plan guidance document fbr firr•ther details and exrunples of emission calculations. Section 4 - General Monitoring Requirements Table I below details the schedule by which fuel consumption and hours of operation must be tracked by the source. The hours of operation must be tracked wi/v if emissions, fuel consumption or maintenance activities are based on hours of operation Table 1 Parameter Fuel Consumption Hours of Operation Monitoring Frequency Monthly Monthly Table 2 outlines fuel use monitoring methods. The source must choose one primary' monitoring method and, optionally, may choose up to two backup methods. Check each box that applies. Table 2 Primary Back-up Fuel Consumption Monitoring Method 0 ❑ Individual engine fuel meter ■ ■ Facility -wide fuel meter attributed to fuel consumptiou rating and hours of operation ❑ Manufacturer -provided fuel consumption ❑ ■ Other (to be approved by the division) - attach explanation and sample calculations Table 3 detai s the portable testing frequency for engines at the facility based on the requested permitted emission totals for the entire facility. Check the appropriate box based on facility -wide NOx and CO permitted emissions. All portable €malv_er rests must be petforrared per Division protocol, which can he found at hito:/•-w\vw.ctlphe.state.co.usjap,downiportanalyzeprotomdf 'liable 3 Control Status Portable Test ng Frequency ►/ Permitted Facility Emissions 0 Permitted Facility Emissions <80tpyNO, orCO Semi-annual; then annual after 2 consecutive passing semi-annual tests. If any of the annual tests fail then the source shall return to semi-annual testing. ?80 toy NO, or CO Quarterly; then semi-annual after 4 consecutive quarterly passing tests. If any of the semi-annual tests tail then the source shall return to quarterly tests. Annual NSCR or SCO No catalyst Annual Section 5 - Emission Control Etsuipment iMonitorinc Requirements —fill out applicable sections only Table 4 details control equipment monitoring frequency for rich burn engines. Check the appropriate box based on facility- wide NOx and CO permitted emissions. See the footnotes following Tables 4 and 5 for details on proper control equipment operating parameter monitoring and compliance requirements. Page 2 of 4 ('CGl F II_ForiuAPC13.301-RICColfvM-Ver 9-11-2(108den: • • Colorado Department of Public Health and Environment Air Pollution Control Division Table 4 Entissions Control Device Non-selective catalytic reduction (NSCR) Air -Fuel Ratio Controller (AFRC) Rich Burn Engine Monitoring Frequency Monitoring Requirement Monitorin Fre uenc Permitted Facility Permitted Facility Emissions Emissions >80 Ipy NO, ur CO < 80 tpy NO, or CO Pre -catalyst Temperature 5' M Daily Catalyst Differential Pressure' Month I:. t AFRC 02 sensor mV reading ` I Weekly weekly Monthly ly Weekly. Pre -catalyst temperature shall stay within she range of 750° F to 1250 F. lythe temperature is outside of this range then appropriate maintenance activities shall be performed. AFRC O_ Sensor Monitoring and Maintenance Requirements • if the engine uses an oxygen sensor then it will he replaced per inantifacturer's recommended schedule. If the replacement is determined by hours of operation then the source will track the hours of operation. • In addilion to the weekly \FRC O, Sensor mV reading. this parameter must be recorded during each portable analyzer test. Table 5 details control equipment monitoring frequency for lean burn engines. ('heck appropriate bots based on facility -wide NON and CO permitted emissions. Sec the footnotes following Table 5 for details on proper control equipment operating parameter monitoring and compliance requirements. Emissions Control Device Selective Oxidation Catalyst (SCOT Table S Lean Burn Fn_ine Monitoring Frequence Monitoring Requirement hlonitorin Permitted Facility Emissions 80 tpy NO, or CO Pre -catalyst Temperature ° Daily Catalyst Differential Pressure Fr wen 11 Permitted Facility Emissions <80tpy NO, orC:O Veel• ly Montnly Monthly ' Pre -catalyst temperature shall stay within the range of 450° E to 1350° F. If the temperature is outside of this range then appropriate maintenance activities shall be performed `Catalyst Differential Pressure Baseline Establishment and Monitoring Requirement_, • The pressure drop shall not exceed 2 inches of water column from the baseline value established by the source when the engine is operating at maximum achievable load This baseline pressure drop shall be established by the source during each initial compliance and portable analyzer test, and as noted below • lfthe pressure is outside this range then the appropriate maintenance shall be performed to bring the pressure back into range In lieu of maintenance the source may choose to perform a portable analyzer test of the engine to establish a new pressure drop value It -the test demonstrates that the engine is in compliance with its emission limits. the pressure drop value at which she engine is tested shall become the new baseline. • The catalyst will be cleaned. reconditioned and replaced per the manufacturer's recommended schedule and a copy of maintenance reports shall he kept. lithe catalyst cleaning. reconditioning and replacement depends on hours of operation then the source shall track the hours of operation for the engine • For new. cleaned or reconditioned catalyst on an existing engine: the new pressure drop baseline must be established by the operator within the first 7 days of engine/catalyst operation and re-established during the next regularly scheduled emission test, • For new cleaned or reconditioned catalyst on a new engine- the new pressure drop baseline must be established within the First ISO days of engine operation. Page 3 of 4 C•CC;TI• Il_ironnnt'C'D.301 •R1Ctn) lower Y -Iii -'L I dc: • Colorado Department of Public Health and Environment Air Pollution Control Division Section 6 — Recorslkeeuine Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2. 3, 4 and 5 fora period of 2 rears. If an applicable Federal NSPS, NESHAP or MACT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 -Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. .'tole: These templates are intended to address operation and nmintenance requirements of Nie Stale of Colorado for equipment operated at .sintltetic minor facilities if the facility or equipment is subject to other state or federal regulations with duplicative requirements, the source shrill follow the most stringent regulatory requirement. Page 4 of 4 CCGTF II FerinAPCD-301-tt!CEO&M-Ver'.1-10-200t Joe • • 06252.009-190 O&M Plan for New TEG & Existing TEG Dehydration Units ENSR October 7000 • • • Form APCD-302 Colorado Department of Public Health and Enviiroo nent Air Pollution Control Division Culuralo i)ep.,rtment ofPubtir I [catch arid En ti Bron 1114'i tt Operating and Maintenance Plan Template for Glycol Dehydration Systems Ver. September 17. 2008 The Air Pollution Control Division (Disision) developed this Operating and Maintenance Plan (O&M Plan) for glycol dehydration systems that arc permitted at synthetic minor facilities in the State of Colorado. An O&M Plan for each type of glycol dehydration system configuration. as described in Section I. shall be submitted with the permit application. One O&M Plan may be used lhr multiple glycol dehydration systems at one facility if each are controlled and monitored in the same manner. It the O&M Plan template is completed correctly, the Division will appros o the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will %york with the facility to make corrections. Once a construction permit is issued. the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators arc not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval ssith the permit application. However. the Division encourages the use of this template to expedite the permit application approval process Submittal Date: Section t - Source Identification For new permits some of this information (Le. Facility AIRS ID, Facility Equipment ID, Permit Number. and AIRS Point ID) ma). not he known at the time of application. Please only. fill out those fields that are known and leave the others blank. Company Name: Facility Name OXY USA WTP LP Conn t. reek Gan Treating Facility lI Facility Location: S321.65 R97W, Garfield County Facility AIRS ID (for existing facilities) Units Covered by this O&M form Facility Equipment In D21VC1U4 DI/VCU I Permit lumber new 05GA0069 _ AIRS Point Ili new 04510831/003 _ Glycol Type Used " TEG TEG _ Glycol types include Ethylene Glycol (EG). Di -Ethylene Glycol (DEG). and Tri -Ethylene Glycol (TEG) Emission Points and Control Status: Check the appropriate boxes rndicaang whether the de h draiian system(s) ore equipped wirlr aJlnsh tank and whether or Prot the flash trunk {rfpreserrlj and still tent rrrriasions are corrrrolled or eecyrletl or willed to air)io.rphere �] Flash Tank ® Controlled/Recycled [] Vented to atmosphere Section 2 - S1ainrenance Schedules Check one of the following: ltl Still Vent Controlled'Recycled 0 Vented to atmosphere Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control devices. These schedules and practices. as well as any maintenance records showing compliance with these recommendations, shall be made available to the Division upon request. Page I of 4 C'CUII. II.I.rn.h.1'li-3ti_"-Ikli.dratoK)&\I-Vvt'.iiJ-2r.rrsdcc • Colorado Department of Public health and Environment Air Pollution Control Division • • Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices. These schedules and practices. as well as any maintenance records showing compliance ❑ with these recommendations, shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (TSPS) general conditions. Section 3 - Monthly Emission Modeline or Calculations The following box must he checked for O&M plan to be considered complete. -the source will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and nruinrenanc' plan guidance document forfurther clekrils and examples of emission calculations. Section 4 — General Moiiitorine Requirements Fable 1 below details the schedule on which the source must monitor each of the listed operating parameters depending on the requested permitted emissions at the facility. Check the appropriate box based on facility wide permitted VOC emissions. Table I ~ Frequency Parameter Monitorin ■ Permitted Facility 1 Permitted Facility Emissions ? 80 tpy VOC Daily Weekly Emissions < 80 tpy VOC Weekly Monthly Monthjy Monthly Lean Glycol Circulation Rate Wet Gas inlet Temperature Wet Gas Inlet Pressure Weekly Monthly Volume of Gas Processed Ch it le rCold Sep ratorJ Press ure (EG units only) Weekly Monthly Chiller (Cold Separator) Temperature (EG units only) Weekly Monthly Tables 2 and 3 outline the methods by which the source may monitor the lean glycol recirculation rate and the volume of gas processed. respectively. In Tables 2 and 3 the source must chose one primary monitoring method and. optionally. up to two backup monitoring methods. Check each box that applies. Table 2 Primary Back-up Lean Glycol Recirculation Rate Monitoring Method ❑ Glycol flow meter(s)- including flow from all injection points or pumps ❑ Record strokes per minute and convert to circulation rate — pump rnakelmodel and stokes per minute! circulation rate relationship must be made available to the division upon request • Assume maximum design rate specifications shall be made available to the division upon request ❑ ❑ 0 Assume maximum design pump rate b — pump make/model and circulation rate specifications must be made available to the division upon request ►Zt 'Note: if you are requesting to permit at a rate lower than the maximum design pump rate then this option should not be used as it will create de facto non-compliance. Table 3 Primary Back-up Volume of Gas Processed Monitorin Method ❑ Metered 0 Inlet • Outlet ❑ Fuel Gas ■ Compressor Discharge ©other: _ ❑ Metered 0 Inlet0 Outletf Fuel Gas /i4 Compressor Discharge ]other: -_ E Assume maximum design rate specifications shall be made available to the division upon request ❑ ❑ Other (to be approved by the division): attach method explanation and sample calculations `Note: if you arc requesting to permit ata rate lower than the maximum contactor design rate then this option should not be used as it will create de facto non-compliance. Page 2 of 4 mrliTF It_FormAPC'D-103-DchylratorO&M -Ver 4-I0-2008 Aux • Colorado Department or Public Health and Environment Air Pollution Control Division Section 5 - Ern issiou Control or Recycling Equipment Monitoring Requirements Table 4 below details the monitoring frequency for control equipment depending on the type of control equipment used and the requested permitted emissions at the facility. Check the appropriate box for "Monitoring Frequency" based on the facility - wide permitted VOC emissions. In addition, indicate still vent and flash tank emissions controls by checking the appropriate boxes. Table I Emissions Control or Recycling Method Still Vent Flash Tank Parameter Monitoring_ Freq eney 0 Permitted Facility Emissions 80 Ipy V©C • Permitted Facility Emissions < SO tpy VOC Condenser ❑ Condenser Outlet Temperature Weekly Monthly Thermal Oxidizer [j 0 Combustion Chamber l'cmrerature' Daily Weekly Combustor or Flare Z ® Pilot Light Monitoring r Daily Weekly Method 22 Readings Daily Weekly Recycled or Closed Loop System (Including Vapor Recovery Units) 0 ❑ To be determined by the source and approved by the division' Re-routed to -rout Burner Reboiie ❑ To be determined by the source and approved by the division Maximum Condenser Outlet Temperature If the equipment is controlled with a secondary control device and no control efficiency is being claimed for the condenser then the condenser outlet temperature does not need to be monitored and there will be no maximum condenser outlet temperature. For all other equipment the maximum condenser outlet temperature shall be: Select ane vjrhe foll©tiring opirons_/rorn Table 5 °F ble 5 (Leon approval from the division) attach supporting documentation if a higher limit is requested Minimum Thermal Oxidizer Combustion Chamber Temperature If the facility uses a thermal oxidizer to control emissions then the minimum combustion chamber temperature shall be: Seleci one of the fallowing uptiors ji om Table d: 1400 ° F E Table 6 Based on manufacturer specifications. Specifications must be submitted with the permit application and made available to the Division u•on re=uest Based on testing performed. The test data shall be submitted and attached to the O&M Plan Page 3 of 4 Ceti tl• !i FunnAPCo-3u'-Ock ralnrn&M-Vyr 9-1f)-20ot floc • • Colorado Department of Public Health and Environment Air Pollution Control Division r Pilot Light Monitoring Options If the facility uses a Combustor or Flare then the source must indicate the method by which the presence of a pilot light will be monitored in Table 7. One primary method For Pilot Light Monitoring must be checked and, optionally, up to two backup methods can be checked. Table 7 Primary Back-up FI Monitoring Method Visual Inspection �] [] ❑ El Q Optical Sensor Auto -Igniter Signal Thermocouple ii Recycled or Closed Loop System Monitoring Plan in the space provided below please provide a brief description of -the emission control or recycling system, including an explanation of how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. r' Reboiler Burlier Control Monitoring Plan in the space provided below please provide a brief description of the emission control system, including an explanation of haw the system design ensures that emissions are being held or rerouted when the reboiler is not firing. Section 6 — Recordkeenintt Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records For the requirements listed in sections 2, s, 4 and 5 for a period of 2 years. If an applicable Federal NSPS, NESHAP or MACE requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance actiitics. Note: These templates are intended to address operdition am! maintenance requirements of the State of Colorado fir equipmeut operated at synthetic minor facilities. if the facility or equipment is subject to other state or federal regulations with duplicative requirements, the source shah follow the most stringent regulatory requirement. Page 4 of 4 CCGTF t 1 l:ormA PC r3-302. Delvit rai Grp& M-Ve r. 7- I 0-20 G S due • • • Appendix B Detailed Emission Calculations 05252.408-14D ENSR October 2008 • • • Appendix B-1 Criteria Pollutant Emission Calculations 05262-008-140 ENSR October 2008 • • • OXY- Conn Creek Gas Treating Facility Il (CCGTF II) Inlet Gas Compression IC Engine Calculations Manufacturer Emission Factors • Caterpillar 03610 LE IC Engine Emission Assumptions Emission Factors gstimateit Emis Table B-1.1 Hours per Year = 8,760 hr/yr Fuel Sulfur Content = 0.05 grains/set Natural Gas Heating Value = 966 Btulscf Conversion = 453.6 glib Conversion = 7,000 grains/lb Number of Engines = 3 Load 100% 76% 64% Horsepower= 4,514 3,385 2,445 HP Fuel Consumption (LHV) = 6,825 7,174 7,678 Btu/bhp-hr Fuel Consumption (LHV) = 31,892 25,139 19,433 sof/hr Fuel Consumption (LHV) = 279 220 170 MMseflyr Exhaust Stack Temperature = 875 916 971 °F Exhaust Gas Flow = 30.226 24,103 18,773 acfm n Manf data - Nameplate rating Mani data Catalyst CE - CO = 93% 93% 93% MACT-required CE Catalyst CE - NMNEHC = 50% 50% 50% Manf-estimated CE Catalyst CE - HCHO = 76% 76% 76% Manf-estimated CE Load 100% 75% 54% NO, 0.70 0.70 0.70 glbhp-hr CO 2.50 2.50 2.51 glbhp-hr NMNEHC 0.50 0.62 0.65 glbhp-hr HCHO 0.41 0.45 0.48 glbhp-hr PM10 0.0100 0.0100 0.0100 IbIMMBtu Manf EF Manf EF Manf EF Manf EF AP -42 EF One Cat G3616 LE IC Engine 100% 75% 54% 100% 75% 54% Iblhr gfs lb/hr I girl lb/hr gls WY Ws WY g/s _ TPY gis NO, 6.97 0.8777 5.22 0.6582 3.77 0.4754 30.51 0.8777 22.88 0.6582 16.53 0.4754 CO 1.74 0.2194 1.31 0.1645 0.95 0.1193 7.63 0.2194 5.72 0.1645 4.16 i 0.1193 NMNEHC 3.96 0.4995 3.12 0.3930 2.37 0.2990 17-37 0.4995 13.66 0.3930 10.39) 0.2990 SO2 0.46 0.0574 0.36 0.0452 0.28 0.0350 2.00 0.0574 1.57 0.0452 1.221 0.0350 PM,2 0.31 0.0388 0.24 0.0306 0.19 0.0236 1.35 0.0388 1.06 0.0306 i 0.82 I 0.0236 Three Cat 03516 LE IC Engine Ib/hr TPY 100% 75% 54% 100% 76% 64% NO, 20.90 15.67 11.32 91.54 68.64 49.58 CO 5.22 3.92 2.84 22.88 17.16 12.44 NMNEHC 11.89 9.36 7.12 52.10 40.99 31.18 SO2 1.37 1.08 0.83 5.99 4.72 3,65 PM17 0.921 0.73 0.56 4.04 3.19 2.46 Notes: Horsepower, fuel consumption and emission factors for NO,, CO, NMNEHC and HCHO from Caterpillar site specific technical data sheet Ref. OM5133-01-002, dated 05Feb2005 SO, emissions based on an estimated pipeline -quality natural gas sulfur content of 5 grains/100 scf. Emission factor for P41, from EPA, AP -42 Chapter 32, Table 3.2-2. including P14, lllterahhe s PM condensable. Formaldehyde is considered a VOC, but it is not included in the NMNEHC g/bhp-hr emission facto . therefore. to Obtain the NMNEHC IW}v emission rate, the NMNEHC and HCHO gibhp-hr emission radar were summed. • • • Table B-1.2 OXY • Conn Creek Gas Treating Facility q (CCGTF II) Power Generator Sets IC Engine Calculations Manufacturer Emission Factors - Caterpillar G3512 LE IC Engine Emission Assumptions Hours per Year = 8,760 hr/yr Fuel Sulfur Content = 0.05 grainslsct Natural Gas Heating Value = 966 Btu/sof Conversion = 453.8 glib Conversion = 7,000 grainsllb Number of Engines = 3 Load 100% 76% 66% Horsepower = 782 586 430 HP Fuel Consumption (LHV) = 7,742 8,099 8,558 Btufbhp-hr Fuel Consumption (LHV) = 6,267 4,913 3,809 scf/hr Fuel Consumption (LHV) = 55 43 33 MMscflyr Exhaust Stack Temperature = 830 819 810 °F Exhaust Gas Flow = 4,589 3,480 2,646 acfm Emission Factors Estimated Emissions Manf data - Nameplate rating Manf data Catalyst CE - CO = 93% 93% 93% MACT-required CE Catalyst CE - NMNEHC = 50% 50% 50% Manf-estimated CE Catalyst CE - HCHO = 76% 76% 76% Manf-estimated CE Load 100% 75% 65% Ni;), 1.50 1 50 1.50 glbhp-hr CO 2.82 2 81 2.82 gfbhp-hr NMNEHC 0.30 0 32 0.36 glbhp-hr HCHO 0.29 0.31 0.33 glbhp-hr 0.01 0.01 0.01 Ib/MMBtu Man! EF Manf EF Manf EF Manf EF AP -42 EF Three Cat 03612 LE One Cat G3512 LE IC Engine Iblhr 100% TPY 76% 66% _ 55% 100% 55% 76% 65% lb/hr 1 gls lb/hr gls lb/hr I gls TPY gls TPY o gls WY r gls NO, 2.59 1 _ 0.3258 1.94 0.2442 1.42 0.1792 11.33 0.3258 8.49 0.2442 6.23 0.1792 CO 0 34 0.0429 0.25 0.0320 0.19 0.0236 1.49 0.0429 1.11 ' 0.0320 0.62 0.0236 NMNEHC 0 38 0.0477 0.30 0.0352 0.25 I, 0.0310 1.66 0.0477 1.33 0.0382 1.08 0.0310 SO2 0.09 0.0113 0.07 0.0088 0.051 0.0069 0.39 0.0113 0.310.0088 0.24 0.0069 PM,0 0.06 0.0076 0.05 0.0060 0.04 I 0.0046 0.26 0.0076 0.21 0.0060 0,16 0.0046 Three Cat 03612 LE IC Engine Iblhr 100% TPY 100% 75% _ 55% 76% 55% NO, 7.76 5.81 4.27 33.98 25.46 18.68 CO 1.02 0.76 0.55 _ 4.47 3.34 _ 2.46 NMNEHC 1.14 0.91 0.74 4.97 3.98 3.23 SO;. 0.27 0.21 0.16 1.18 0.92 0.72 PM,0 0.18 0.14 0.11 0.79 0.62 0.46 Notes: Horsepower, fuel: consumption and emission factors for NOx. CO, NMNEHC and HCHO From Caterpillar site specific technical data sheet, Ref. DM5554-00-402. dated 3CJan2008 SO, emissions based on an estimated pipeline -quality nature gas sulfur content of 5 grains+1CO sof Emission factor for PM. from EPA, AP -42 Chapter 3.2, Table 3 2-2, including PM,,, filterable 5 PM cerwensade Formaldehyde is considered a VOC, but it is not included in the NMNEHC glbhp-hr emission factor; therefore, to obtain the NMNEHC Ibfhr emission rate, the NMNEHC and HCHO g+bhp-hr emission factor were summed • Table B-1.3 Project: Subject: CALCULATIONS AND COMPUTATIONS OXY - CCGTF II Natural Gas -Fired Heat Medium Heater Calculations Emission Source: Heat Medium Heater Source Type: Natural Gas -Fired Heater Heat Input: 14.00 MMBtulhr Natural Gas Lower Heating Value (LHV): 966 Btulscf Fuel Consumption (LHV): 0.0145 MMscf/hr Fuel Consumption (LHV): 126.96 MMscf/yr Sulfur Content of Fuel: 0.05 grlscf Operating Hours per Year: 8,760 hr/yr Number of Units: 2 Pollutant Emission Factors (a) One Heater Total Short-term Annual Two Heaters lb/hr (bj, (`) g/sec tpy (d) (e} glsec lb/hr tpy NO. 100.0 lb/MMscf 1.45 0.1826 6.35 0.1826 2.90 12.70 CO 84.0lb1MMscf 1.22 0.1534 5.33 0.1534 2.43 10.66 VOC 5.5 lb/MMscf 0.08 0.0100 0.35 0.0100 0.16 0.70 502 0.015 lb/MMBtu 0.21 0.0261 0.91 0.0261 0.41 1.81 PM10 7.6 lb/MMscf 0.11 0,0139 0.48 0.0139 0.22 0.96 Notes: (a) Emission factors (lb/MMscf) based on USEPA AP -42, Section 1.4, Table 1.4-2, dated July 1998, except for Sp Emission factor for 502 (IblMMBtu) based assumed sulfur content of natural gas (b) Hourly Emission Rate (Ib/hr) except for SQ = (Emission Factor, lbfMMsc) * (MMscflhr) (e) Hourly Emission Rate (Ib/hr) for SQ = (Emission Factor, CbIMMBtu) * (Heat Input. MMBtulhr) (d) Annual Emission Rate (tpy) = (Emission Factor, Ib/MMsef) * (MMseflyr) / (2,000 lb/ton) (e) Annual Emission Rate (tpy)for SQ = (Emission Factor, IblMMBtu) * (Heat Input, MMBtulhr) * (hr/yr) l (2,000 lb/ton) Table B-1.4 CALCULATIONS AND COMPUTATIONS Project: OXY - Conn Creek Gas Treating Facility I & II (CCGTF I & Ill) Subject: Vapor Combustion Unit Emission Calculations 4 VCUs - 3 for CCGTF 1 (condensate tanks & TEG Unit) & 1 for CCGTF II TEG Unit Emission Source: Condensate Tanks & TEG Unit Control Source Type: VCU Heat Input: 3.00 MMBtu/hr Flowrate: 1,500.0 scf/hr Flowrate: 13.1 MMscffyr Estimated HHV: 2,000 Btulscf Molecular Weight of Condensate Vapors: 34.3 lb/mole Total VOC Destruction Efficiency: 98.0 % Sulfur Content of Fuel: 0.05 gr/scf Operating Hours per Year: 8,760 hr/yr Number of Units: 4 Pollutant Emission Factors (a) One Vapor Combustion Unit Total Short-term. Annual g/sec Four VCUs lb/hr (b)° (c) g/sec tpy fdj lb/hr tpy NOx 100.0 lb/MMscf 0.15 0.0189 0.66 0.0189 0.60 2.63 CO 84.0 lb/MMscf 0.13 0.0159 0.55 0.0159 0.50 2.21 SO2 0.007 lb/MMBtu 0.021 0.0027 0.09 0.0027 0.09 0.38 PM10 7.6 lb/MMscf 0.01 0.0014 0.05 0.0014 ' 0.05 0.20 Notes: (a) Emission factors are from AP -42 Tables 1.4-1 & 2 (small boilers) except Sp Emission factor for So) (Ib1MMBtu) based assumed sulfur content of natural gas (b) Hourly Emission Rate (lb/hr) (Emission Factor, Ib/MMscf)' (Flowrate, scflhr)(MM! 1,000,000) (c) Hourly Emission Rate (Ib/hr) = (Emission Factor, ib/MMBtuf) " (Heat Input, MMBtulhr) (d) Annual Emission Rate (tpy) = (Hourly Emission Rate, lb/hr) ' (hr/yr) f (2,000 lb/ton) • • Page: 1 GRI-GLYCa1c VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: OXY Conn Creek File Name: U:\My Documents\OXY\GlyCalc\New TEG (with Condenser).ddf Date: September 25, 2008 DESCRIPTION: Description: New TEG System Emissions Estimate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0276 0.663 0.1209 Ethane 0.0245 0.587 0.1072 Propane 0.0281 0.674 0.1230 Isobutane 0.0129 0.309 0.0565 n -Butane 0.0173 0.416 0.0759 Isopentane 0.0085 0.203 0.0371 n -Pentane 0.0068 0.163 0.0298 n -Hexane 0.0114 0.274 0.0500 Heptanes 0.0115 0.276 0.0503 Benzene 0.0218 0.524 0.0957 Toluene 0.0396 0.950 0.1734 Ethylbenzene 0.0011 0.026 0.0048 Xylenes 0.0159 0.382 0.0696 C8+ Heavies 0.0001 0.003 0.0005 Total Emissions 0.2271 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions UNCONTROLLED REGENERATOR EMISSIONS Component 0.2271 0.1750 0.0899 0.0784 5.451 0.9948 5.451 4.201 2.157 1.882 0.9948 0,7666 0.3936 0.3435 lbs/hr lbs/day tons/yr Methane 1.3855 33.252 6.0684 Ethane 1.2447 29.874 5.4520 Propane 1.5298 36.716 6.7007 Isobutane 0.7585 18.203 3.3220 n -Butane 1.0732 25.757 4.7007 Isopentane 0.6897 16.554 3.0211 n -Pentane 0.6247 14.992 2.7361 n-1-Iexane 1.6047 38.513 7.0286 Heptanes 3.3959 81.500 14.8738 Benzene 5.0485 121.163 22.1123 Toluene 22.2282 533.476 97.3593 Ethylbenzene 1.7463 41.912 7.6489 Xylenes 28.7283 689.480 125.8301 C8+ Heavies 10.3188 247.651 45.1963 • • Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH TANK OFF GAS 80.3768 1929.042 80.3768 1929.042 77.7465 1865.917 59.3560 1424.543 57.7513 1386.030 Page: 2 352.0502 352.0502 340.5298 259.9791 252.9506 Component lbs/hr lbs/day tons/yr Methane 13.1778 316.267 57.7187 Ethane 3.4759 83.422 15.2245 Propane 1.9066 45.757 8.3507 Isobutane 0.6359 1.5.261 2.7851 n -Butane 0.6891 16.539 3.0184 Isopentane 0.3860 9.265 1.6908 n -Pentane 0.2836 6.807 1.2422 n -Hexane 0.4097 9.833 1.7945 Heptanes 0.4329 10.390 1.8962 Benzene 0.0465 1.115 0.2035 Toluene 0.1331 3.194 0.5829 Ethylbenzene 0.0061 0.147 0.0268 Xylenes 0.0693 1.663 0.3035 C8+ Heavies 0.1293 3.104 0.5665 Total Emissions 21.7818 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 21.7818 5.1281 0.6647 0.2550 522.763 95.4042 522.763 123.075 15.952 6.119 95.4042 22.4611 2.9112 1.1168 CONDENSER AND COMBUSTION DEVICE Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 15.00 psia Condenser Duty: 4.86e-002 MM BTU/hr Hydrocarbon Recovery: 5.56 bbls/day Produced Water: 20.17 bbls/day Ambient Temperature: 100.00 deg. F Excess Oxygen: 5.00 % Combustion Efficiency: 98.00 % Supplemental Fuel Requirement: 4.86e-002 MM BTU/hr Component Emitted Destroyed Methane 1.99% 98.01% Ethane 1.97% 98.03% Propane 1.84% 98.16% Isobutane 1.70% 98.30% n -Butane 1.61% 98.39% Isopentane 1.23% 98.77% n -Pentane 1.09% 98.91% n -Hexane 0.71% 99.29% Heptanes 0.34% 99.66% • • • Benzene 0.43% 99.57% Toluene Ethylbenzene Xylenes C8+ Heavies ABSORBER 0.18% 0.06% 0.06% 0.00% 99.82% 99.94% 99.94% 100.00% Page: 3 Calculated Absorber Stages: Specified Dry Gas Dew Point: Temperature: Pressure: Dry Gas Flow Rate: Glycol Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content; Specified Lean Glycol Recirc. Ratio: Component Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Heptanes Benzene Toluene Ethylbenzene Xylenes C8+ Heavies FLASH TANK 1.33 7.00 110.0 545.0 60.0000 0.6769 Saturated 124.79 3.00 lbs. H20/MMSCF deg. F psig MMSCF/day lb/hr lbs. H2O/MMSCF gal/lb H20 Remaining Absorbed in Dry Gas in Glycol 5.59% 94.41% 99.80% 0.20% 99.98% 0.02% 99.98% 0.02% 99.95% 0.05% 99.91% 0.09% 99.87% 0.13% 99.82% 0.18% 99.81% 0.19% 99.76% 0.24% 99.59% 0.41% 99.22% 0.78% 86.84% 13.16% 80.89% 19.11% 73.36% 26.64% 64.97% 35.03% 95.17% 4.83% Flash Control: Vented to atmosphere Flash Temperature: 132.0 deg. F Flash Pressure: 55.0 psig Component Left in Removed in Glycol Flash Gas Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane 99.98% 54.77% 9.20% 9.51% 26.37% 44.52% 54.40% 60.90% 64.30% 68.93% 0.02% 45.23% 90.80% 90.49% 73.63% 55.48% 45.60% 39.10% 35.70% 31.07% Page: 4 n -Hexane 79..76% 20.24% Heptanes 88.75% 11.25% Benzene 99.13% 0.87% Toluene 99.45% 0.55% Ethylbenzene 99.69% 0.31% Xylenes 99.79% C8+ Heavies 98.91% REGENERATOR 0.21% 1.09% No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 21.91% 78.09% Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% n -Butane 0.00% 100.00% Isopentane 0.78% 99.22% n -Pentane 0.73% 99.27% n -Hexane 0.63% 99.37% Heptanes 0.56% 99.44% Benzene 5.04% 94.96% Toluene 7.95% 92.05% Ethylbenzene 10.44% 89.56% Xylenes C8+ Heavies STREAM REPORTS: 12.94% 87.06% 12.15% 87.85% WET GAS STREAM Temperature: Pressure: Flow Rate: 110.00 deg. F 559.70 psia 2.51e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 2.63e-001 3.13e+002 Carbon Dioxide 3.79e+000 1.10e+004 Nitrogen 8.98e-002 1.66e+002 Methane 8.91e+001 9.44e+004 Ethane 4.57e+000 9.08e+003 Propane 1.26e+000 3.66e+003 Isobutane 2.69e-001 1.03e+003 n -Butane 2.59e-001 9.96e+002 Isopentane 1.20e-001 5.71e+002 n -Pentane 7.98e-002 3.80e+002 n -Hexane 8.67e-002 4.94e+002 Heptanes Benzene Toluene Ethylbenzene 7.41e-002 4.90e+002 7.50e-003 3.87e+001 1.92e-002 1.17e+002 9.38e-004 6.58e+000 Xylenes 1.17e-002 8.22e+001 C8+ Heavies 1.92e-002 2.16e+002 Total Components 100.00 1.23e+005 DRY GAS STREAM Page: 5 Temperature: Pressure: Flow Rate: 110.00 deg. F 559.70 psia 2.50e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Heptanes Benzene Toluene Ethylbenzene 1.47e-002 3.79e+000 9.00e-002 8.93e+001 4.58e+000 1.26e+000 2.70e-001 2.60e-001 1.20e-001 7.98e-002 1.75e+001 1.10e+004 I.66e+002 9.44e+004 9.07e+003 3.66e+003 1.03e+003 9.94e+002 5.70e+002 3.80e+002 8.66e-002 4.92e+002 7.37e-002 4.87e+002 6.53e-003 3.36e+001 1.56e-002 9.47e+001 6.90e-004 4.83e+000 Xylenes 7.63e-003 5.34e+001 C8+ Heavies 1.83e-002 2.06e+002 Total Components 100.00 1.23e+005 LEAN GLYCOL STREAM Temperature: Flow Rate: 110.00 deg. F 1.47e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Heptanes Benzene 9.89e+001 1.00e+000 2.63e-011 3.26e-014 5.91e-018 2.69e-008 1.69e-009 5.05e-010 5.28e-010 6.53e-005 5.51e-005 1.22e-004 2.32e-004 3.24e-003 8.19e+003 8.29e+001 2.18e-009 2.70e-012 4.89e--016 2.23e-006 1.40e-007 4.18e-008 4.37e-008 5.41e-003 4.56e-003 1.01e-002 1.92e-002 2.68e-001 Page: Toluene 2.32e-002 1.92e+000 Ethylbenzene 2.46e-003 2.04e-001 Xylenes 5.16e-002 4.27e+000 C8+ Heavies 1.72e-002 1.43e+000 Total Components 100.00 8.28e+003 RICH GLYCOL STREAM Temperature: 110.00 deg. F Pressure: 559.70 psia Flow Rate: 1.56e+001 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (1b/hr) TEG 9.41e+001 8.19e+003 Water 4.35e+000 3.78e+002 Carbon Dioxide 2.51e-001 2.18e+001 Nitrogen 3.11e-004 2.70e-002 Methane 1.67e-001 1.46e+001 Ethane 5.43e-002 4.72e+000 Propane 3.95e-002 3.44e+000 Isobutane 1.60e-002 1.39e+000 n -Butane 2.03e-002 1.75e+000 Isopentane 1.24e-002 1.08e+000 n -Pentane 1.05e-002 9.13e-001 n -Hexane 2.33e-002 2.02e+000 Heptanes 4.43e-002 3.85e+000 Benzene 6.17e-002 5.36e+000 Toluene 2.79e-001 2.43e+001 Ethylbenzene 2.25e-002 1.96e+000 Xylenes 3.80e-001 3.31e+001 C8+ Heavies 1.37e-001 1.19e+001 Total Components 100.00 8.70e+003 FLASH TANK OFF GAS STREAM Temperature: Pressure: Flow Rate: 132.00 deg. F 69.70 psia 4.76e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 3.66e-001 8.26e-002 Carbon Dioxide 1.79e+001 9.87e+000 Nitrogen 6.98e-002 2.45e-002 Methane 6.55e+001 1.32e+001 Ethane 9.21e+000 3.48e+000 Propane 3.45e+000 1.91e+000 Isobutane 8.72e-001 6.36e-001 n -Butane 9.45e-001 6.89e-001 Isopentane 4.26e-001 3.86e-001 n -Pentane 3.13e-001 2.84e-001 n -Hexane 3.79e-001 4.10e-001 Heptanes 3.44e-001 4.33e-001 Benzene 4.74e-002 4.65e-002 Page: 7 Toluene 1.15e-001 1.33e-001 Ethylbenzene 4.60e-003 6.13e-003 Xylenes 5.20e-002 6.93e-002 C8+ Heavies 6.05e-002 1.29e-001 Total Components 100.00 3.18e+001 FLASH TANK GLYCOL STREAM Temperature: 132.00 deg. F Flow Rate: 1.55e+001 gpm Component Cone. Loading (wt%) (lb/hr) TEG 9.45e+001 8.19e+003 Water 4.37e+000 3.78e+002 Carbon Dioxide 1.38e-001 1.19e+001 Nitrogen 2,87e-005 2.49e-003 Methane 1.60e-002 1.39e+000 Ethane 1.44e-002 1.24e+000 Propane 1.77e-002 1.53e+000 Isobutane 8.7Se-003 7.58e-001 n -Butane 1.24e-002 1.07e+000 Isapentane 8.02e-003 6.95e-001 n -Pentane 7.26e-003 6.29e-001 n -Hexane 1.86e-002 1.61e+000 Heptanes 3.94e-002 3.42e+000 Benzene 6.14e-002 5.32e+000 Toluene 2.79e-001 2.41e+001 Ethylbenzene 2.25e-002 1.95e+000 Xylenes 3.81e-001 3.30e+001 C8+ Heavies 1.36e-001 1.17e+001 Total Components 100.00 8.66e+003 REGENERATOR OVERHEADS STREAM Temperature: Pressure: Flow Rate: 212.00 deg. F 14.70 psia 6.67e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.32e+001 2.95e+002 Carbon Dioxide 1.54e+000 1.19e+001 Nitrogen 5.05e-004 2.49e-003 Methane 4.91e-001 1.39e+000 Ethane 2.35e-001 1.24e+000 Propane 1.97e-001 1.53e+000 Isobutane 7.42e-002 7.58e-001 n -Butane 1.05e-001 1.07e+000 Isopentane 5.44e-002 6.90e-001 n -Pentane 4.92e-002 6.25e-001 n -Hexane 1.06e-001 1.60e+000 Heptanes 1.93e-001 3.40e+000 Benzene 3.67e-001 5.05e+000 Toluene 1.37e+000 2.22e+001 Ethylbenzene 9.35e-002 1.75e+000 Page: 8 Xylenes 1.54e+000 2.87e+001 C8+ Heavies 3.44e-001 1.03e+001 Total Components 100.00 3.88e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 5.88e-001 gpm Component Conc. Loading (wt%) (1b/hr) (ppm) Water 9.99e+001 2.94e+002 999071. Carbon Dioxide 4.07e-002 1.20e-001 407. Nitrogen 2.24e-007 6.59e-007 0. Methane 2.41e-004 7.10e-004 2. Ethane 2.44e-004 7.17e-004 2. Propane 2.89e-004 8.51e-004 3. Isobutane 7.23e-005 2.13e-004 1. n -Butane 1.29e-004 3.80e-004 1. Isopentane 4.45e-005 1.31e-004 0. n -Pentane 3.83e-005 1.13e-004 0. n -Hexane 5.35e-005 1.57e-004 1. Heptanes 2.98e-005 8.78e-005 0. Benzene 1.62e-002 4.78e-002 162. Toluene 2.42e-002 7.13e-002 242. Ethylbenzene 5.06e-004 1.49e-003 5. Xylenes 1.02e-002 2.99e-002 C8+ Heavies 1.88e-007 5.53e-007 102. 0. Total Components 100.00 2.94e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 1.62e-001 gpm Component Conc. Loading (wt%) (lb/hr) Water 4.98e-002 3.44e-002 Carbon Dioxide 1.67e-001 1.16e-001 Nitrogen 2.23e-005 1.54e-005 Methane 6.O1e-003 4.15e-003 Ethane 2.92e-002 2.02e-002 Propane 1.81e-001 1.25e-001 Isobutane 1.65e-001 1.14e-001 n -Butane 2.99e-001 2.06e-001 Isopentane 3.86e-001 2.66e-001 n -Pentane 4.12e-001 2.85e-001 n -Hexane 1.50e+000 1.03e+000 Heptanes 4.09e+000 2.82e+000 Benzene 5.66e+000 3.91e+000 Toluene 2.92e+001 2.02e+001 Ethylbenzene 2.45e+000 1.69e+000 Xylenes 4.04e+001 2.79e+001 C8+ Heavies 1.49e+001 1.03e+001 Page: 9 Total Components 100.00 6.90e+001 CONDENSER VENT STREAM Temperature: Pressure: Flow Rate: 120.00 deg. F 15.00 psia 2.22e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.14e+001 1.20e+000 Carbon Dioxide 4.56e+001 1.17e+001 Nitrogen 1.51e-002 2.47e-003 Methane 1.47e+001 1.38e+000 Ethane 6.97e+000 1.22e+000 Propane 5.45e+000 1.40e+000 Isobutane 1.90e+000 6.45e-001 n -Butane 2.S5e+000 8.67e-001 Isopentane 1.00e+000 4.23e-001 n -Pentane 8.07e-001 3.40e-001 n -Hexane 1.14e+000 5.71e-001 Heptanes 9.82e-001 5.75e-001 Benzene 2.39e+000 1.09e+000 Toluene 3.68e+000 1.98e+000 Ethylbenzene 8.86e-002 5.49e-002 Xylenes 1.28e+000 7.95e-001 C8+ Heavies 5.74e-003 5.71e-003 Total Components 100.00 2.43e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: Pressure: Flow Rate: 1000.00 deg. F 14.70 psia 1.91e+000 scfh Component Conc. Loading (vol%) (lb/hr) Methane 3.43e+001 2.76e-002 Ethane 1.62e+001 2.45e-002 Propane 1.27e+001 2.81e-002 Isobutane 4.42e+000 1.29e-002 n -Butane 5.94e+000 1.73e-002 Isopentane 2.34e+000 8.46e-003 n -Pentane 1.88e+000 6.80e-003 n -Hexane 2.64e+000 1.14e-002 Heptanes 2.28e+000 1.15e-002 Benzene 5.57e+000 2.18e-002 Toluene 8.56e+000 3.96e-002 Ethylbenzene 2.06e-001 1.10e-003 Xylenes 2.98e+000 1.59e-002 C8+ Heavies 1.34e-002 1.14e-004 Total Components 100.00 2.27e-001 • Page: 1 GRI-GLYCa1c VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: OXY Conn Creek File Name: U:\My Documents\OXY\GlyCalc\Existing TEG (with Condenser).ddf Date: September 25, 2008 DESCRIPTION: Description: New TEG System Emissions Estimate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0196 0.471 0.0859 Ethane 0.0173 0.416 0.0760 Propane 0.0199 0.477 0.0871 Isobutane 0.0091 0.219 0.0399 n -Butane 0.0122 0.293 0.0535 Isopentane 0.0060 0.144 0.0262 n -Pentane 0.0048 0.115 0.0210 n -Hexane 0.0080 0.193 0.0352 Heptanes 0.0081 0.194 0.0354 Benzene 0.0151 0.361 0.0659 Toluene 0.0273 0.656 0.1197 Ethylbenzene 0.0008 0.018 0.0034 Xylenes 0.0111 0.266 0.0485 C8+ Heavies 0.0001 0.002 0.0004 Total Emissions 0.1593 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions UNCONTROLLED REGENERATOR EMISSIONS 0.1593 0.1224 0.0622 0.0542 3.824 0.6979 3.824 2.937 1.494 1.301 0.6979 0.5360 0.2726 0.2374 Component lbs/hr lbs/day tons/yr Methane 0.9846 23.630 4.3124 Ethane 0.8822 21.173 3.8642 Propane 1.0846 26.031 4.7506 Isobutane 0.5377 12.906 2.3553 n -Butane 0.7583 18.200 3.3215 Isopentane 0.4904 11.770 2.1479 n -Pentane 0.4427 10.625 1.9390 n -Hexane 1.1374 27.297 4.9818 Heptanes 2.4133 57.919 10.5703 Benzene 3.5102 84.245 15.3747 Toluene 15.5282 372.676 68.0133 Ethylbenzene 1.2321 29.569 5.3964 Xylenes 20.2049 484.918 88.4976 C8+ Heavies 7.6220 182.929 33.3845 Page: 2 Total Emissions 56.8287 1363.888 248.9095 Total Hydrocarbon Emissions 56.8287 1363.888 Total VOC Emissions 54.9619 1319.085 Total HAP Emissions 41.6127 998.706 Total BTEX Emissions 40.4754 971.408 FLASH TANK OFF GAS 248.9095 240.7329 182.2638 177.2821 Component lbs/hr lbs/day tons/yr Methane 8.6925 208.620 38.0732 Ethane 2.2868 54.883 10.0162 Propane 1.2548 30.115 5.4960 Isobutane 0.4185 10.044 1.8330 n -Butane 0.4520 10.849 1.9799 Isopentane 0.2548 6.114 1.1159 n -Pentane 0.1865 4.477 0.8170 n -Hexane 0.2695 6.469 1.1805 Heptanes 0.2856 6.854 1.2508 Benzene 0.0300 0.720 0.1314 Toluene 0.0863 2.071 0.3780 Ethylbenzene 0.0040 0.096 0.0176 Xylenes 0.0452 1.086 0.1981 C8+ Heavies 0.0887 2.128 0.3883 Total Emissions 14.3553 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 14.3553 3.3759 0.4351 0.1655 344.526 62.8760 344.526 81.023 10.442 3.973 62.8760 14.7866 1.9056 0.7251 CONDENSER AND COMBUSTION DEVICE Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 15.00 psia Condenser Duty: 3.41e-002 MM BTU/hr Hydrocarbon Recovery: 3.94 bbls/day Produced Water: 14.26 bbls/day Ambient Temperature: 100.00 deg. F Excess Oxygen: 5.00 % Combustion Efficiency: 98.00 % Supplemental Fuel Requirement: 3.41e-002 MM BTU/hr Component Emitted Destroyed Methane 1.99% 98.01% Ethane 1.97% 98.03% Propane 1.83% 98.17% Isobutane 1.70% 98.30% n -Butane 1.61% 98.39% Isopentane 1.22% 98.78% n -Pentane 1.08% 98.92% n -Hexane 0.71% 99.29% Heptanes 0.33% 99.67% Benzene 0.43% 99.57% Toluene Ethylbenzene Xylenes C8+ Heavies ABSORBER 0.18% 0.06% 0.05% 0.00% 99.82% 99.94% 99.95% 100.00% Page: Calculated Absorber Stages: Specified Dry Gas Dew Point: Temperature: Pressure: Dry Gas Flow Rate: Glycol Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content: Specified Lean Glycol Recirc. Ratio: Component 1.36 7.00 lbs. H20/MMSCF 110.0 deg. F 510.0 psi% 40.0000 MMSCF/day 0.4316 lb/hr Saturated 131.86 lbs. H20/MMSCF 3.00 gal/lb H2O Remaining Absorbed in Dry Gas in Glycol Water 5.29% 94.71% Carbon Dioxide 99.80% 0.20% Nitrogen 99.98% 0.02% Methane 99.98% 0.02% Ethane 99.95% 0.05% Propane 99.90% 0.10% Isobutane 99.86% 0.14% n -Butane 99.82% 0.18% Isopentane 99.80% 0.20% n -Pentane 99.75% 0.25% n -Hexane 99.57% 0.43% Heptanes 99.17% 0.83% Benzene 86.29% 13.71% Toluene 79.98% 20.02% Ethylbenzene 71.81% 28.19% Xylenes 63.05% 36.95% C8+ Heavies 94.65% 5.35% FLASH TANK Flash Control: Flash Temperature: Flash Pressure: Component Vented to atmosphere 132.0 deg. F 55.0 psi% Left in Removed in Glycol Flash Gas Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane 99.98% 56.61% 9.84% 10.17% 27.84% 46.36% 56.23% 62.65% 65.98% 70.50% 0.02% 43.39% 90.16% 89.83% 72.16% 53.64% 43.77% 37.35% 34.02% 29.50% n -Hexane Heptanes Benzene Toluene Ethylbenzene Xylenes C8+ Heavies REGENERATOR 80.94% 89.47% 99.20% 99.49% 99.71% 99.81% 98.99% Page: 4 19.06% 10.53% 0.80% 0.51% 0.29% 0.19% 1.01% No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Heptanes Benzene Toluene Ethylbenzene Xylenes C8+ Heavies STREAM REPORTS: 21.91% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.76% 0.71% 0.62% 0.56% 5.04% 7.94% 10.44% 12.94% 12.14% 78.09% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 99.24% 99.29% 99.38% 99.44% 94.96% 92.06% 89.56% 87.06% 87.86% WET GAS STREAM Temperature: Pressure: Flow Rate: 110.00 deg. F 524.70 psia 1.67e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane 2.78e-001 3.79e+000 8.98e-002 8.91e+001 4.57e+000 1.26e+000 2.69e-001 2.59e-001 1.20e-001 7.98e-002 2.20e+002 7.35e+003 1.11e+002 6.30e+004 6.05e+003 2.44e+003 6.90e+002 6.64e+002 3.80e+002 2.54e+002 n -Hexane 8.67e-002 3.29e+002 • Heptanes Benzene Toluene Ethylbenzene 7.41e-002 3.27e+002 7.50e-003 2.58e+001 1.92e-002 7.80e+001 9.37e-004 4.39e+000 Xylenes 1.17e-002 5.48e+001 C8+ Heavies 1.92e-002 1.44e+002 Total Components 100.00 8.21e+004 DRY GAS STREAM Page: 5 Temperature: Pressure: Flow Rate: 110.00 deg. F 524.70 psia 1.67e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Heptanes Benzene Toluene Ethylbenzene 1.47e-002 3.79e+000 9.00e-002 8.93e+001 4,58e+000 1.26e+000 2.70e-001 2,60e-001 1.20e-001 7.98e-002 8.66e-002 7.37e-002 6.49e-003 1.54e-002 6.75e-004 1.17e+001 7.33e+003 1.11e+002 6.29e+004 6.05e+003 2.44e+003 6.89e+002 6.63e+002 3.80e+002 2.53e+002 3.28e+002 3.24e+002 2.23e+001 6.24e+001 3.15e+000 Xylenes 7.41e-003 3.46e+001 C8+ Heavies 1.82e-002 1.37e+002 Total Components 100.00 8.18e+004 LEAN GLYCOL STREAM Temperature: Flow Rate: 110.00 deg. F 1.04e+001 gpm Component. Conc. Loading (wt%) (1b/hr) TEG Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Heptanes Benzene 9.89e+001 1.00e+000 2.49e-011 3.05e-014 5.55e-018 2.55e-008 1.63e-009 4.90e-010 5.13e-010 6.40e-005 5.40e-005 1.21e-004 2.32e-004 3.18e-003 5.79e+003 5.86e+001 1.46e-009 1.78e-012 3.25e-016 1.50e-006 9.52e-008 2.87e-008 3.00e-008 3.74e-003 3.16e-003 7.07e-003 1.36e-002 1.86e-001 Toluene 2.29e-002 1.34e+000 Ethylbenzene 2.45e-003 1.44e-001 Xylenes 5.13e-002 3.00e+000 C8+ Heavies 1.80e-002 1.05e+000 Total Components 100.00 5.85e+003 RICH GLYCOL STREAM Page: 6 Temperature: 110.00 deg. F Pressure: 524.70 psia Flow Rate: 1.10e+001 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 9.42e+001 5.78e+003 Water 4.35e+000 2.67e+002 Carbon Dioxide 2.37e-001 1.46e+001 Nitrogen 2.91e-004 1.79e-002 Methane 1.58e-001 9.68e+000 Ethane 5.16e-002 3.17e+000 Propane 3.81e-002 2.34e+000 Isobutane 1.56e-002 9.56e-001 n -Butane 1.97e-002 1.21e+000 Isopentane 1.22e-002 7.49e-001 n -Pentane 1.03e-002 6.32e-001 n -Hexane 2.30e-002 1.41e+000 Heptanes 4.42e-002 2.71e+000 Benzene 6.07e-002 3.73e+000 Toluene 2.76e-001 1.70e+001 Ethylbenzene 2.25e-002 1.38e+000 Xylenes 3.79e-001 2.33e+001 C8+ Heavies 1.43e-001 8.76e+000 Total Components 100.00 6.14e+003 FLASH TANK OFF GAS STREAM Temperature: Pressure: Flow Rate: 132.00 deg. F 69.70 psia 3.12e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 3.66e-001 5.42e-002 Carbon Dioxide 1.75e+001 6.32e+000 Nitrogen 6.98e-002 1.61e-002 Methane 6.58e+001 8.69e+000 Ethane 9.24e+000 2.29e+000 Propane 3.46e+000 1.25e+000 Isobutane 8.75e-001 4.18e-001 n -Butane 9.45e-001 4.52e-001 Isopentane 4.29e-001 2.55e-001 n -Pentane 3.14e-001 1.87e-001 n -Hexane 3.80e-001 2.70e-001 Heptanes 3,46e-001 2.86e-001 Benzene 4.67e-002 3.00e-002 • • Page: 7 Toluene 1.14e-001 8.63e-002 Ethylbenzene 4.59e-003 4.O1e-003 Xylenes 5.18e-002 4.52e-002 C8+ Heavies 6.32e-002 8.87e-002 Total Components 100.00 2.07e+001 FLASH TANK GLYCOL STREAM Temperature: 132.00 deg. F Flow Rate: 1,09e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.45e+001 5.78e+003 Water 4.37e+000 2.67e+002 Carbon Dioxide 1.35e-001 8.25e+000 Nitrogen 2.87e-005 1.76e-003 Methane 1.61e-002 9.85e-001. Ethane 1.44e-002 8.82e-001 Propane 1.77e-002 1.08e+000 Isobutane 8.78e-003 5.38e-001 n -Butane 1.24e-002 7.58e-001 Isopentane 8.07e-003 4.94e-001 n -Pentane 7.28e-003 4.46e-001 n -Hexane 1.87e-002 1.14e+000 Heptanes 3.96e-002 2.43e+000 Benzene 6.04e-002 3.70e+000 Toluene 2.76e-001 1.69e+001 Ethylbenzene 2.25e-002 1.38e+000 Xylenes 3.79e-001 2.32e+001 C8+ Heavies 1.42e-001 8.67e+000 Total Components 100.00 6.12e+003 REGENERATOR OVERHEADS STREAM Temperature: Pressure: Flow Rate: 212.00 deg. F 14.70 psia 4.71e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.33e+001 2.09e+002 Carbon Dioxide 1.51e+000 8.25e+000 Nitrogen 5.05e-004 1.76e-003 Methane 4.94e-001 9.85e-001 Ethane 2.36e-001 8.82e-001 Propane 1.98e-001 1.08e+000 Isobutane 7.45e-002 5.38e-001 n -Butane 1.05e-001 7.58e-001 Isopentane 5.47e-002 4.90e-001 n -Pentane 4.94e-002 4.43e-001 n -Hexane 1.06e-001 1.14e+000 Heptanes 1.94e-001 2.41e+000 Benzene 3.62e-001 3.51e+000 Toluene 1.36e+000 1.55e+001 Ethylbenzene 9.34e-002 1.23e+000 • Page: 8 Xylenes 1.53e+000 2.02e+001 C8+ Heavies 3.60e-001 7.62e+000 Total Components 100.00 2.74e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 4.16e-001 gpm Component Conc. Loading (wt%) (lb/hr) ( ppm) Water 9.99e+001 2.08e+002 999080. Carbon Dioxide 4.03e-002 8.38e-002 403. Nitrogen 2.27e-007 4.72e-007 0. Methane 2,46e-004 5.11e-004 2. Ethane 2.47e-004 5.15e-004 2. Propane 2.93e-004 6.10e-004 3. Isobutane 7.33e-005 1.53e-004 1. n -Butane 1.30e-004 2.71e-004 1. Isopentane 4.50e-005 9.37e-005 0. n -Pentane 3.88e-005 8.06e-005 0. n -Hexane 5.38e-005 1.12e-004 1. Heptanes 3.01e-005 6.25e-005 0. Benzene 1.60e-002 3.33e-002 160. Toluene 2.40e-002 4.99e-002 240. Ethylbenzene 5.06e-004 1.O5e-003 5. Xylenes 1.O1e-002 2.11e-002 101. C8+ Heavies 1.97e-007 4.10e-007 0. Total Components 100.00 2.08e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 1.15e-001 gpm Component Conc. Loading (wt%) (lb/hr) Water 4.94e-002 2.42e-002 Carbon Dioxide 1.65e-001 8.08e-002 Nitrogen 2.22e-005 1.08e-005 Methane 6.1.5e-003 3.00e-003 Ethane 2.98e-002 1.45e-002 Propane 1.84e-001 9.O0e-002 Isobutane 1.67e-001 8.17e-002 n -Butane 3.02e-001 1.48e-001 Isopentane 3.92e-001 1.91e-001 n -Pentane 4.15e-001 2.03e-001 n -Hexane 1.51e+000 7.36e-001 Heptanes 4.11e+000 2.O1e+000 Benzene 5.58e+000 2.72e+000 Toluene 2.89e+001 1.41e+0O1 Ethylbenzene 2.44e+000 1.19e+000 Xylenes 4.02e+001 1.96e+001 C8+ Heavies 1.56e+001 7.62e+000 Page: 9 Total Components 100.00 4.89e+001 CONDENSER VENT STREAM Temperature: Pressure: Flow Rate: 120.00 deg. F 15.00 psia 1.55e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.14e+001 8.36e-001 Carbon Dioxide 4.51e+001 8.08e+000 Nitrogen 1.53e-002 1.75e-003 Methane 1.50e+001 9.81e-001 Ethane 7.08e+000 8.67e-001 Propane 5.54e+000 9.94e-001 Isobutane 1.93e+000 4.56e-001 n -Butane 2.58e+000 6.10e-001 Isopentane 1..02e+000 2.99e-001 n -Pentane 8.16e-001 2.40e-001 n -Hexane 1.14e+000 4.01e-001 Heptanes 9.90e-001 4.04e-001 Benzene 2.37e+000 7.53e-001 Toluene 3.64e+000 1.37e+000 Ethylbenzene 8.86e-002 3.83e-002 Xylenes 1.28e+000 5.53e-001 C8+ Heavies 6.03e-003 4.18e-003 Total Components 100.00 1.69e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: Pressure: Flow Rate: 1000.00 deg. F 14.70 psia 1.34e+000 scfh Component Conc. Loading (vol%) (lb/hr) Methane 3.45e+001 1.96e-002 Ethane 1.63e+001 1.73e-002 Propane 1.27e+001 1.99e-002 Isobutane 4.43e+000 9.12e-003 n -Butane 5.93e+000 1.22e-002 Isopentane 2.34e+000 5.98e-003 n -Pentane 1.88e+000 4.79e-003 n -Hexane 2.63e+000 8.03e-003 Heptanes 2.28e+000 8.08e-003 Benzene 5.44e+000 1,51e-002 Toluene 8.37e+000 2.73e-002 Ethylbenzene 2.04e-001 7.66e-004 Xylenes 2.94e+000 1.11e-002 C8+ Heavies 1.39e-002 8.36e-005 Total Components 100.00 1.59e-001 Table B-1.5 CALCULATIONS AND COMPUTATIONS Project: OXY - CCGTF II Subject: Emergency Flare Calculations Emission Source: Emergency Flare Source Type: Open -Flame Air -Assisted Heat Input: 0.50 MMBtu/hr Flare Throughput (Pilot/Purge): 250.0 scf/hr Flare Throughput (Pilot/Purge): 2.19 MMscf/yr Heating Value: 2,000 Btu/sof Sulfur Content of Fuel: 0.05 grfscf Operating Hours per Year: 8,760 hr/yr Pollutant Emission Factors (a) One Heater Short-term Annual lb/hr (b), (C) g/sec tpy (d) glsec NO), 0.068 lb/MMBtu 0.03 0.0043 0.15 , 0.0043 CO 0.370lb/MMBtu 0.19 0.0233 0.81 _ 0.31 0.0233 VOC 0.140 lb/MMBtu 0.07 0.0088 0.0088 SO2 0.007 ib/MMBtu 0.004 0.0004 0.02 0.0004 PM,o 40.0 pg l L s 0.007 0.0008 0.03 0.0008 Notes: (a) Emission factors are from AP -42 Tables 13.5-1 & 2 (Industrial Flares). except so 40 pg I L is for lightly smoking flare (this is conservative as these flares are smokeless in design). Emission factor for 802 (Ib/MMBtu) based assumed sulfur content of natural gas (b) Hourly Emission Rate (lb/hr) except for PM) a (Emission Factor, lbIMMBtuf) * (Heat Input, MMBtu/hr) (c) (MMscf CH4) (10.6 scf Efscf CH4) (0.0283 m /scf E) (40 p PM1 /L E) (1000 Ifm3) (g1106 pg) (lb/453.59 g) , (d) Annual Emission Rate (tpy) _ (Hourly Emission Rate, Ib/hr) * (hrfyr) f (2,000 Ibiton) (hrfyr) = lb PM0I hr Table B-1.6 CALCULATIONS AND COMPUTATIONS Project: OXY USA WTP LP - Conn Creek Gas Treating Facility I (CCGTE I) Subject: 3 -Phase Separator (V-5240) Emission Source: 3-phase separator One Heater Source Type: Heater Iblhr (1*(c) Heat Input: 0.80 MMBtu/hr g/sec Flowrate: 821.4 scf/hr 0.08 Flowrate: 7.2 MMscf/ r Estimated HHV: 974 Btu/scf 0.07 Sulfur Content of Fuel: 0.05 gr./sof 0.0087 Operating Hours per Year: 8,760 hr/yr 0.005 Pollutant Emission Factors (a) One Heater Short-term Annual Iblhr (1*(c) g/sec tpy td} g/sec NO, 100.0Ib/MMscf 0.08 0.0103 0.36 0.0103 CO 84.0IbfMMscf 0.07 0.0087 0.30 0.0087 VOC 5.5 lb/MMscf 0.005 0.0006 0.02 0.0006 502 0.015 Ib/MMBtu 0.012 0.0015 0.05 0.0015 PM10 7.6 Ib1MMscf 0.006 0.0008 0.0 3 0.0008 Notes: (a) Emission factors are from AP -42 Tables 1.4-1 & 2 (small boilers) except SQ Emission factor for 502 (Ib/MMBtu) based assumed sulfur content of natural gas (b) Hourly Emission Rate (lb/hr) = (Emission Factor, lb/MMscf) * (Flowrate, scflhr) * (MM 11,000,000), (c) Hourly Emission Rate (lb/hr) = (Emission Factor, IbIMMBtuf) * (Heat Input, MMBtulhr) (d) Annual Emission Rate (tpy) = (Hourly Emission Rate, Ib/hr) * (hrlyr) / (2.000 lb/ton) Appendix 8-2 Hazardous Air Pollutant Emission Calculations O5252-408-140 ENSR Octch•er 2025 Table B-2.1 Project: Subject: Calculations and Computations HAP Emissions from CCGTF II G3616 LE OXY - CCGTF Il IC Engines Caterpillar G3616 LE Natural Gas -Fired IC Engines Non -Criteria Regulated Pollutant Emissions - Emission Rates Emission Factor One Engine Three Engines Pollutant Type tat (glbh -hr) (Ib1MMBtu) tbl (lbfhr) t`I 1 (lbs/yr) (tpY) td) (Ibfhr) (tpy) 1,1,2,2 -Tetrachloroethane HAP 4.00E-05 0.0006 5.40 0,0027 0.0018 : 0.0081 1,1.2 -Trichloroethane HAP 3.18E-05 0.0005 4.29 0.0021 0.00151 0.0064 1.3 -Butadiene HAP 2.67E-04 0.0041 36.03 0.0180 0.0123 ! 0.0540 1,3-Dichloropropene HAP 2.64E-05 0.0004 3.56 0.0018 0,0012 l 0.0053 2 -Methylnaphthalene HAP 3.32E-05 0.0005 4.48 0.0022 0.0015: 0.0067 2,2,4-Trimethylpentane HAP 2.50E-04 0.0039 33.73 0.0169 0.0116: 0.0506 Acenaphthene HAP 1.25E-06 0.0000 0.17 0.0001 0.0001 i 0.0003 Acenaphthylene HAP 5.53E-06 0.0001 0.75 0.0004 0.00031 0.0011 Acetaldehyde HAP 8.36E-03 0.1288 1,128.09 0.5640 0.39 j 1.69 Acrolein HAP 5.14E-03 0.0792 693.59 0.3468 0.24 ! 1.04 Benzene HAP 4.40E-04 0.0068 59.37 0.0297 0.02031 0.0891 Benzo(b)fluorantherle HAP 1.66E-07 0.0000 0.02 0.0000 0.00001 0.0000 Benzo(e)pyrene HAP 4.15E-07 0.0000 0.06 0.0000 0.00000.0001 Benzo(g,h,i)perylene HAP 4.14E-07 0.0000 0.06 0.0000 0.00001 0.0001 Biphenyl HAP 2.12E-04 0.0033 28.61 0.0143 0.00981 0.0429 Carbon Tetrachloride HAP 3.67E-05 0.0006 4.95 0.0025 0.0017 0.0074 Chlorobenzene HAP 3.04E-05 0.0005 4.10 0.0021 0.0014 0.0062 Chloroform HAP 2.85E-05 0.0004 3.85 0.0019 0.0013 0.0058 Chrysene HAP 6.93E-07 0.0000 0.09 0.0000 0.0000 0.0001 Ethyibenzene HAP 3.97E-05 0.0006 5.36 0.0027 0.0018 0.0080 Ethylene Dibromide HAP 4.43E-05 0.0007 5.98 0.0030 0.0020 0.0090 Fluoranthene HAP 1.11 E-06 0.0000 0.15 0.0001 0.0001 0.0002 Fluorene HAP 5.67E-06 0.0001 0.77 0.0004 0.0003 0.0011 Formaldehyde (e) HAP 0.41 0.98 8,578.03 4.29 2.94 j 12.87 Methanol HAP 2.50E-03 0.0385 337.35 0.1687 0.1155 0.5060 Methylene Chloride HAP 2.00E-05 0.0003 2.70 0.0013 0.0009 ! 0.0040 Hexane HAP 1.11E-03 0.0171 149.78 0.0749 0.0513: 0.2247 Naphthalene HAP 7.44E-05 0.0011 10.04 0.0050 0.0034 1 0.0151 PAH HAP 2.69E-05 0.0004 3.63 0.0018 0.00121 0.0054 Phenanthrene HAP 1.04E-05 0.0002 1.40 0.0007 0.0005 ; 0.0021 Phenol HAP 2.40E-05 0.0004 3.24 0.0016 0.0011 I 0.0049 Pyrene HAP 1.36E-06 0.0000 0.18 0.0001 0.0001 ! 0.0003 Styrene HAP 2.36E-05 0.0004 3.18 0.0016 0.00111 0.0048 Tetrachloroethane HAP 2.48E-06 0.0000 0.33 0.0002 0.00011 0.0005 Toluene HAP 4.08E-04 0.0063 55.06 0.0275 0.0189 I 0.0826 Vinyl Chloride HAP 1.49E-05 0.0002 2.01 0.0010 0.0007 0.0030 Xylene HAP 1.84E-04 0.0028 24.83 0.0124 0,0085 0.0372 1.3 11,195.2 5.6 3.8 : 16.79 Hours o Operatior 8,760 hrlyr Maximum 11dividual HAP. 12.87 Number of IC Engines 3 Horsepower 4,514 HP Fuel Consumption 6,825 Btufbhp-hr Maximum Heat Inputa 30.81 Catalyst CE 4 50% for VOCs Catalyst CE f°r 76% for HCHO Notes: (a) Type = HAP for Hazardous Air Pollutant. (b) Emission factors from AP -42, Section 3.2, Table 3.2-2 (7100). except for formaldehyde yde (c) Hourly Emission Rate (Iblhr) = [Heat Input Rate (MMBtuhlr) ' Emission Factor (Ib7MMBtu)j (d) Annual Emission Rate (tpy). (Average Hourly Emission Rate, Iblhr) * (8760 hr/yr) f (2 000 Iblton) (e) Formaldehyde emission factor from manufacturer's emission factor, Ref. DM5133-01-002, dated 05Feb2008 (f) Maximum heal input rate for the G3616 LE engine is based on fuel consumption rate of 6,825 Btu/bhp-hr for one engine from mar [6,825 Btulbhp-hr] ' [4,514 bhp] 11.000.000 (g) Catalyst control efficiency based on manufacturer -specified percent reduction acturer spec sheet Table B-2.2 Project: Subject: Calculations and Computations HAP Emissions from CCGTF II G3512 LE OXY - CCGTF II IC Engines Caterpillar G3512 LE Natural Gas -Fired IC Engines Non -Criteria Regulated Pollutant Emissions Emission Rates Emission Factor One Engine Three Engines Pollutant Type tal (g/bhp-hr) (lb/MMBtu) tel (lb/hr) M f (Ibs/yr) : (tpyl ld} (Ib/hr) I (tpy) 1,1,2,2 -Tetrachloroethane HAP 4,00E-05 0.0001 1.06 0.0005 0.0004 0.0016 1,1,2 -Trichloroethane HAP 3.18E-05 0.0001 0.84 0.0004 0.0003 , 0.0013 1.3 -Butadiene HAP 2.67E-04 0.0008 7.08 0.0035 0.0024 j 0.0106 1,3-Dichloropropene HAP 2.64E-05 0.0001 0.70 0.0004 0.00021 0.0011 2 -Methylnaphthalene HAP 3.32E-05 0.0001 0.88 0.0004 0.0003 i 0.0013 2,2,4-Trimethylpentane HAP 2.50E-04 0.0008 6.63 0.0033 0.0023 ; 0.0099 Acenaphthene HAP 1.25E-06 0.0000 0.03 0.0000 0.0000 I 0.0000 Acenaphthylene HAP 5.53E-06 0.0000 0.15 0.0001 0.0001 ! 0.0002 Acetaldehyde HAP 8.36E-03 0.0253 221.69 0.1108 0.08 ; 0.33 Acrolein HAP 5.14E-03 0.0156 136.30 0.0682 0.05 0,20 Benzene HAP 4.40E-04 0.0013 11.67 0.0058 0.0040 a 0.0175 Benzo(b)tiuoranthene HAP 1.66E-07 0.0000 0.00 0.0000 0.00oo 1 0.0000 Benzo(e)pyrene HAP 4.15E-07 0-0000 0.01 0.0000 0.0000 1 0.0000 Benzo(g,h,i}perylene HAP 4.14E-07 0.0000 0.01 0.0000 0.0000 0.0000 Biphenyl HAP 2.12E-04 0.0006 5.62 0.0028 0.0019 0.0084 Carbon Tetrachloride HAP 3.67E-05 0.0001 0.97 0.0005 0.0003 0.0015 Chlorobenzene HAP 3.04E-05 0.0001 0.81 0.0004 0.0003 0.0012 Chloroform HAP 2.85E-05 0.0001 0.76 0.0004 0.0003 0.0011 Chrysene HAP 6.93E-07 0.0000 0.02 0.0000 0.0000. 0.0000 Ethylbenzene HAP 3.97E-05 0.0001 1.05 0.0005 0.0004 0.0016 Ethylene Dibromide HAP 4.43E-05 0.0001 1.17 0.0006 0.0004 0.0018 Fluoranthene HAP 1.11E-06 0.0000 0.03 0.0000 0.0000 0.0000 Fluorene HAP 5.67E-06 0.0000 0.15. 0.0001 0.0001 0.0002 Formaldehyde (e) HAP 0.29 0.12 1,051.11 0.53 0.36 t 1.58 Methanol HAP 2.50E-03 0.0076 66.29 0.0331 0.0227 k 0.0994 Methylene Chloride HAP 2.00E-05 0.0001 0.53 0.0003 0.0002 l 0.0008 Hexane HAP 1.11E-03 0.0034 29.43 0.0147 0.0101 t 0.04421 Naphthalene HAP 7.44E-05 0.0002 1.97 0.0010 0.0007 9 0.0030 PAH HAP 2.69E-05 0.0001 0.71 0.0004 0.0002 0.0011 Phenanthrene HAP 1.04E-05 0.0000 0.28 0.0001 0.0001 0.0004 Phenol HAP 2.40E-05 0.0001 0.64 0.0003 0.0002 0.0010 Pyrene HAP 1.36E-06 0.0000 0.04 0.0000 0.0000 0.0001 Styrene HAP 2.36E-05 0.0001 0.63 0.0003 0.0002 0.0009 Tetrachloroethane HAP 2.48E-06 0.0000 0.07 0.0000 0.0000 0.0001 Toluene HAP 4.08E-04 0.0012 10.82 0.0054 0.0037 0.0162 Vinyl Chloride HAP 1.49E-05 0.0000 0.40 0.0002 0.0001 0.0006 Xylene HAP 1.84E-04 0.0006 4.88 0.0024 0.0017 0.0073 0.2 1,565.4 , 0.8 0.5 ; 2.35 Hours o Operatior 8,760 hr/yr Maximum Individual HAP: 1.58 Number of IC Engines 3 Horsepower 782 HP Fuel Consumption 7,742 Btu/bhp-hr Maximum Heat Input* 6.05 Catalyst CE (g' 50% for VOCs Catalyst CE(g) 76% for HCHO , Notes: (a) Type = HAP for Hazardous Air Pollutant (b) Emission factors from AP -42, Section 3.2. Table 3.2-2 (7100), except for formaldehyde (c) Hourly Emission Rate (lb/hr) = [Heat Input Rale (MMBtu/Hr) Emission Factor (Ib/MMBtu)] (d) Annual Emission Rate (tpy) = (Average Hourly Emission Rate. lb/hr) (8760 hr/yr) / (2.000 Ib/ton) (e) Formaldehyde emission factor from manufacturer's emission factor, Ref. ❑M8564.00-002. dated 30Jan2008 (f) Maximum heat input rate for the 03818 LE engine is based on fuel consumption rate of 7,742 Btu/bhp-hr for one engine from ma [7,742 $lulbhp-hr) ` [782 bhp) / 1,000.000 (g) Catalyst control efficiency based on manufacturer -specified percent reduction echoer spec sheet Hea" Maximum I. Table B-2.3 Project: Subject: Calculations and Computations HAP Emissions from CCGTF II Heat Medium Heaters OXY - CCGTF II Natural Gas -Fired Heat Medium Heater Calculations Non -Criteria Regulated Pollutant Emissions Pollutant 2 -Methyl naphthalene Type Ial 3-Methy l c h l a ranthre ne 7,12-Dimethylbenz(a)anthracene Acenaphthene Acenaphthylene Anthracene Benz(a)anthracene Benzene HAP HAP 1.8E-06 HAP 1.6E-05 HAP 1.8E-06 Emission Emission Rates Factor One Heater (Ib/MMscf) tbl (lb/hr) (C) (Ibslyr) l (tpy) {dl 2.4E-05 Benzo(a)pyrene Benzo b fluoranthene Benz�g,hh, i)perylene Ben zo k fluoranthene Ch serve Dibenzo a,h anthracene Dichlorobenzene Fluoranthene Fluorene Formaldehyde Hexane Two Heaters (Iblhr) (tpy) 3.48E-07 3.05E-03 , 1.52E-06 6.96E-07 2.61 E-08 2.29E-04 ' 1.14E-07 5.22E-08 2.32E-07 2.03E-03 1.02E-06 4.64E-07 2.61 E-08 2.29E-04 1.14E-07 5.22E-08 3.05E-06 2.29E-07 2.03E-06 2.29E-07 HAP 1.8E-06 2.61E-08 2.29E-04 1.14E-07 5.22E-08 1 2.29E-07 HAP 2.4E-06 3.48E-08 3.05E-04 1.52E-07 6.96E-08 HAP 1.8E-06 2.61 E-08 2.29E-04 1.14E-07 5.22E-08 HAP 2.1E-03 3.04E-05 2.67E-01 1.33E-04 6.09E-05 HAP 1.2E-06 1.74E-08 1.52E-04 7.62E-08 3.48E-08 2.61 E-08 2.29E-04 1.14E-07 5.22E-08 HAP------._�_ �E�� ...,.., HAP 1.2E-06 1.74E-08 1.52E-04 7.62E-08 3.48E-08 HAP 1.8E-06 261E-08 2.29E-04 1.14E-07 5.22E-08 HAP HAP HAP HAP HAP 1.8E-06 2.61E-08 2.29E-04 1.14E-07 522E-08 1.2E-06 1.74E-08 1.52E-04 7.62E-08 3.48E-08 1.2E-03 1.74E-05 1.52E-01 7.62E-05 3.48E-05 3.0E-06 4.35E-08 3.81 E-04 1.90E-07 8.70E-08 2.8E-06 4.06E-08 3.55E-04 1.78E-07 8.12E-08 HAP 7.5E-02 1.09E-03 9.52E+00 4.76E-03 2.17E-03 HAP 1.8E+00 2.61 E-02 2.29E+02 1.14E-01 5.22E-02 Indeno(1,2,3-cd)py_rene T_---- HAP Naphthalene HAP Phenanathrene HAP Pyrene HAP Toluene 3.05E-07 2.29E-07 2..67E-04 1.52E-07 2.29E-07 1.52E-07' ----...... 2.29E-07 2.29E-07 1.52E-07 1.52E-04 3.81 E-07 3.55E-07 9.52E-03 2.29E-01 1.8E-06 2.61 E-08 2.29E-04 1.14E-07 5.22E-08 ! 2.29E-07 6.1E-04 8.84E-06 7.74E-02 3.87E-05 1.77E-05 ' 7.74E-05 1.7E-05 2.46E-07 2.16E-03 1.08E-06 4.93E-07 2.16E-06 5.0E-06 7.25E-08 6.35E-04 3.17E-07 1.45E-07 6.35E-07 HAP 3.4E-03 4.93E-05 4.32E-01 2.16E-04 9.86E-05 4.32E-04 Natural Gas -Fired Heater Maximum Heat Input Natural Gas Heating Value Fuel Consumption (LHV) Fuel Consumption (LHV) Number of Heaters 8,760 hr/yr 14.00 MMBtu/hr 966 Btu/scf 0.0145 MMscf/hr 126.96 MMscf/yr 2 er Total HAPs Idividual HAP 0.24 tpy 0.23 tpy Notes: (a) Type = HAP for Hazardous Air Pollutant (b) Emission factors from AP -42, Section 1.4, Table 1.4-3 (7/98). (c) Hourly Emission Rate (lb/l r) _ [Heat Input Rate (MMBtu/Ht)Emission Factor (Ib/MMscf)] / (Natural Gas Heating Vale (BTU/scf)] (d) Annual Emission Rate (tpy) _ (Average Hourly Emission Rate, Iblhr) ' (8760 hrfyr)1(2.000 lb/ton) • • • • Table B-2.4 Calculations and Computations HAP Emissions from CCGTF I & II VCUs Project: OXY - Conn Creek Gas Treating Facility I & II (CCGTF I & Ill) Subject: Vapor Combustion Unit Emission Calculations 4 VCUs - 3 for CCGTF 1 (condensate tanks & TEG Unit) & 1 for CCGTF II TEG Unit Non -Criteria Regulated Pollutant Emissions Pollutant Type cal Emission Factor (lb/MMscf) tb) Emission Rases (lb/hr) tzt One VCU (Ibslyr) (tpy) td) Four VCUs {Iblhr) (tpy) 2 -Methylnaphthalene 3-Methylchloranthrene HAP HAP 2.4E-05 3.60E-08 2.70E-09 3.15E-04 2.37E-05 1.58E-07 1.18E-08 1.44E-07 1.08E-08 6.31E-07 4.73E-08 1.8E-06 2.40E-08 2.70E-09 2.10E-04 _ 2.37E-05 1.05E-07 1.18E-08 9.60E-08 1.08E-08 4.20E-07 4.73E-08 7,12-DimethylbenzNanthracene Acenaphthene Acenaphthylene Anthracene Benz(a)anthracene HAP HAP 1.6E-05 1.8E-06 2,70E-09 3.60E-09 2.37E-05 3.15E-05 1.18E-08 1.58E-08 1.08E-08 1,44E-08 4.73E-08 6.31E-08 HAP HAP HAP HAP HAP HAP HAP HAP HAP HAP HAP HAP HAP 1.8E-06 2.4E-06 2.70E-09 3.15E-06 1.80E-09 2.37E-05 2.76E-02 1.58E-05 1,18E-08 1.38E-05 7.88E-09 1.08E-08 1.26E-05 7.20E-09 4.73E-08 5.52E-05 3.15E-08 _ 1.8E-06 2.1E-03 1.2E-06 1.8E-06 1.2E-06 Benzene Benzo(a)pyrene 2.70E-09 1.80E-09 2.37E-05 1.58E-05 1.18E-08 7.88E-09 1.08E-08 7.20E-09 4.73E-08 3.15E-08 Benzo(b)fluoranthene Benzo(g,h,i)peery_lene Benzo(k)fluoranene - Chrysene Dibenzo(a h)anthra cene_ 2.70E-09 2 70E-09 1.80E-09 1.80E-06 4.50E-09 2.37E-05 2.37E-05 1.58E-05 1.58E-02 3..94E-05 1.18E-08 1.18E-08 7.88E09 7.88E-06 1.97E-08 1.08E08 108E-08 720E-09 7.20E-06 1.80E-08 4.73E-08 4.73E-08 3,15E-08 3.15E-05 7.88E-08 _ 3.8E-06 1.8E-06 1.2E-06 1.2E-03 3,0E-06 Dichlorobenzene Fluoranthene 4.20E-09 1,13E-04 2.70E-03 3.68E-05 9.86E-01 2.37E+01 184E-08 4.93E-04 .1.18E-02 168E-08 4.50E-04 1.08E-02 7.36E-08 1.97E_03 0.05 2.8E-06 Fluorene Formaldehyde HAP HAP 7.5E-02 1.8E+00 Hexane Indeno(1,2,3-cd)pyrene Naphthalene Phenanathrene Pyrene Toluene HAP HAP HAP -HAP HAP 1.8E-06 6.1E-04 2.70E-09 9.15E-07 2.37E-05 8.02E-03 1.18E-08 4,01E06 1.08E-08 4.73E-08 3.66E-06__.._ 1.60E-05 2.55E-08 2.23E-04 1.12E-07 1.02E-07 4.47E-07 1.7E-05 5.0E-06 3.4E-03 7.50E-09 5,10E-06 6.57E-05 4.47E-02 3.29E-08 2.23E-05 3.00E-08 1.31E-07 2.04E-05 8.9.4E-05 2.82E-03 24.73 0.01 0.01 0.05 Total Vapor Combustion Unit 8,760 hrlyr VdU Total HAPs 0.05 tpy Maximum Heat Input 3.00 MMBtulhr Maximum Individual HAP 0.05 tpy Higher Heating Value 2,000 Btu/sof Fuel Consumption (HHV) 0.0015 MMscf/hr Fuel Consumption (HHV) 13.14 MMscffyr Number of VCUs 4 Notes: (a) Type = HAP for Hazardous Air Pollutant. (b) Emission factors from AP -42, Section 1.4, Table 1.4-3 (7/98). (c) Hourly Emission Rate (lb/hr) = [Heat Input Rate (MMetu/Hr) ' Emission Factor (Ib/MMscf)] / [Natural Gas Heating Vali. (d) Annual Emission Rate (tpy) _ (Average Hourly Emission Rate, Ib/hr) - (8760 hr/yr)1(2,000 lb/ton) e (BTU/scf)] • • • Table B-2.5 Calculations and Computations HAP Emissions from CCGTF II Flare Project: OXY - CCGTF II Subject: Emergency Flare Non -Criteria Regulated Pollutant Emissions Pollutant Type (a) Emission Factor (Ib/MMscf) (e) Emission Rates One Flare (Ibihr) (` (Ibs/yr) (tpY) (a) Benzene Formaldehyde PAHs 1 Naphthalene Acetaldehyde Acrolein Propylene Toluene Xylenes Ethyl Benzene Hexane HAP 0.159 3.98E-05 _ 3.48E-01 1.74E-04 1.169 2.92E-04 2.56E+00 1.28E-03 HAP HAP 0.014 3.50E-06 3. )7E-02 1.53E-05 HAP 0.011 2.75E-06 2.41 E-02 1.20E-05 HAP 0.043 1.08E-05 9.42E-02 4.71E-05 HAP 0.010 2.50E-06 2.19E-02 1.10E-05 HAP 2.440 6.10E-04 5.4E+00 2.67E-03 HAP 0.058 1.45E-05 1.27E-01 6.35E-05 HAP 0.029 7.25E-06 6.35E-02 3.18E-05 HAP 1.444 3.61E-04 3.16E+00 1.58E-03 HAP 0.029 7.25E-06 6.35E-02 3.18E-05 Flare 8,760 hr/yr Flare Total HAPs 0.006 tpy Maximum Heat Input 0.50 MMBtulhr Max Individual HAP 0.003 tpy Total Purge & Pilot Flow + tanks & EG Vapors 2.19 MMscf/yr Total Purge & Pilot Flow + tanks & EG Vapors 0.0003 MMscf/hr Lower Heating Value 2,000 Btulscf Notes: (a) Type = HAP for Hazardous Air Pollutant (b) Emission factors from Ventura County, CA Air Pollution Control District for Flares, dated May 17, 2001 (c) Hourly Emission Rate (Iblhr) = [Emission Factor (Ib1MMscf) * Throughput of Flare (MMscf/hr) (d) Annual Emission Rate (tpy) = (Average Hourly Emission Rate, lb/hr) * (8760 hr/yr) 1(2,000 lb/ton) • Appendix B-3 Vendor Specifications 05252-008-140 ENSR October 2006 G3616 C11(IAIF SPEEL1 1x +11 COMr11: SIGN TeA710 TTI: ic-Z1•34EF4 WATER rvi.I' r .ACtc>;T WATER OUTLET , St C:4301,04 a Y ST G1 It . 1TiOr'ti SY55EA1 C,r(I tALUST 114/11r-c,%,w C UMBO ST Nog Fll SSlCfti L V'L1 N.,51 -P `ir NJx; GAS ENGINE SITE SPECIFIC TECHNICAL OAI A OXY Enterpl Ise - Conn Creek Corepressor 513;i01 f1 1.; 4CE?JI3 SAY LJ,r E-•-usGri 07 Fj 3. SYSTEM. 1 1* FiE1 Pf1E -$UrIE RAN:::► q1 F & mr7 H:4.E t.'J!JREp Al T:T<�L.r IJAXN1LIL1. INLET A_R TEE3.;P=r-4T_I CITERPIUIIR 1;4Y WITH A'R * UEL EAT NZ CONTROL Corr C1 esscr Sta1Mr 5470 066 5970 100 6 5 {' Com':\'a .00orrol RATING . E TE RATiNGi3 AT h1AXTi)MUM INLET AIR TEIaPEfiA1RE RAT11IO NOTES LOAD 100% 100 N'.1ItiE PO"Jijii 0111l AIR 1-FI41PERA1LIRE r:•*- I 33€:= too ti I C' Rfiftfllt l7lTL .T FUS, C 15 MP ICIN r_HJ, i2- Situ hr &r3• UCLC 14,S,J1.'PTrtjh, 1•41-0 I?, (3•!1'7.1. -►11 74'6 T`;,ST 7939 6437 AIR FLOW fat xylry 541D7 W151 J9osis '29:13 AIR FLOYJ WET t17 •i 11 7 para! 13'1 scfm 1227D 11.117 £17 :.3r, INLET YAt-jI=z1..D PAESUfE 14t r H;;;atiaj 72? i:f.61 5E £ i$L EXHAUST STACfe. 'EMlPEIA1VRE 141 k F4SJ 5 9!: 4.7.71 EXHAUST GAS rI OW 1g s:ackkrrnp :4 Sm i 161 h3,rr•1% 32219 302c6 c4!0.3 1877s EXHAUST GAS USS FLOW rf; •I?r'•' i6 -+t' 5.7t .4,:•23:9 36?04 *. :. EF ISSIONS DATA :. Nr:)r. (es 14021 CO THC i nialrcuiar w1.: ! ' S t1 -I f 1.11.11+C; iron , u1.1t ht r.! I ' t1-11 Nt* E.tC Imo"ect,!ar wi 1,1 $5 114'i 1.1C1-0 IFormarpn- hvae t CO2 cx1-1AUS1 OXYGEN 171 (7•. 7i (7) (7) 171 (SI ;li>.:'r°_ i;. , :MEAT REJECTIot. HEAT REJ TO JACKET WATER HEAT REJ i C ATMOSPHE13L HEAT REJ TO LUSE orL HEAT FILJ TO AFTERCOOLER 13) i9i (9't 10; C 70 50 11r ,1+ C 11 460 •tw P7C• 2 50 t 13 062 1145 Ain X70 251 6u 12:1 Das 0 48 319 10._ 4S8 7186 rr1,W IV'5 741.10 2624 t i53af 205 23466 706.3 - -4 1 IEAT EXCttAl,K31E3t $RING CORIA HEAT RBJ TO JACKET WATER 1101 Blair ru Sti0+1 HEAT RE.1 TO AFTERCC.711 ER1l Ube 011. CIRCU>•r r t otr t t l L I?,1:dRr1r> f3o'?'3i, A ..00!rr9 syver'> s3 eTy lanai r11 0'X, has peen adite0 to Ir $-Ra1 excoar'oer S.2rr C• -IST:: trr10'fr1Gr1A •rar Ott0119 '.p,• Olaf Clue. n, an; , rrr: sad *111--4.46,..* 0160 VIA'1 •L -el r6r r a•. W 4+8.14 >M Solo *w .a +ii`L'e-w LH/* rrr.y S. 4* -141144.4. p+f 6,.4 s s k1r $ L r srr 1r?M .. 11 r !Sr. -41411. U 4( }41'F'c {T7 ,.**44.0., = a 4U 1j *TM" MYT .2.s -I a rare • • L Air' 1.3na•rwoo! so ag psi tl..../07¥•.a.c f+Lrw PIP Rte.. a105,44 c***.; /*Jo 4,06 PREPAIIEC EY :�t.t r, F:p�•ety. Tororrinr; Da -a K frra;c- Dy G"i cn3 re Ra: rig Pro 1`wsrar 3 00 00 F?•• r:aa Ser 131.!513.-01402 P•; r1 `d 05e 200'd Palm I nI4 G3616 Udv;L t}J i_Ii 1.3AS E41W 1NE 5I -r1: SPECIFIC TECHNICAL (MIA ,, ; OXY Enterprise - Conn Creek Compressor Ststlon 5000 5,:800 0600 g 4100 C. 42Ci w 1000 3800 5OOO 45Q0 0.4000 a 3500 3008 `P 25000 2000 2.isao tom SOC 25 zooa 3 Cr - i 5fl Li 1001 .:J 50 750 803 850 0t1C 9 Engrna Speed (run) 1000 1050 1'Nn12 Ar site cnnditicns 01 5970 I; aro 100f inlet air Ierrn., ccrstarai icrque ca 1 be rnprrtalred Jo PP.FPAPED I ' Fta:an Ploncelu. 7_rarrar, Data genera mi ay Gal; Er/1rr.e Rat ta ?fr Veasrr. 310 01 Rn1 Data Sat :WS/23 01 302 Prirtterl0.5ran2CC8 0 J11 RL n tc 800 rpm. c'10i? 2 ca! 1 Engine Power vs. inlet Air Temperature I m■iZ�■■ MEM �� i weamil - WM=m -- ■�■ " NMIMI w�il� ==r 'r~���w� I= --� �r--�ol� I•11111M= IE __11111111�1• ''11111•111•1 I=mo MN 1M 11•11111116.-NIIMIIM =II MINIM m`� INOMMINIMMIM �III'��IIIIIIIIIIIMIIII� ,.../..1. IIIIIII.INIIII .. —F 30 410 se 811 70 81 Air Temperilu+e.'F 40 100 110 120 130 14 LEngine Power vs. Engine Speed 1 ,Nimi.r •— ,,,,, .._ „ '0:>". F+4,414 0f Capabaity FA i p`i Arimeout g Range MIMMII=111 BEM MOM iii 3013aiL1 CS1nda00 alt _ow iQ iJ ater>1a 1 t 7S0 F00 etAJ 930 954 1000 1050 Engine Speed (Ion) 1 Engine Torque vs. Engine Spee )0 i ^t MBA YAj01J8}'S ]0 S.'tee1 GFIMMi1Y Ice Site G lf.01. an Poli C0.0.eirrous °poral ,1i4arge El .. 51Jar1ua+n 1:N, ►x r -Ulm Ladd trrem ,, Il Opuial.oQ R.:r,fv. ti d , 750 803 850 0t1C 9 Engrna Speed (run) 1000 1050 1'Nn12 Ar site cnnditicns 01 5970 I; aro 100f inlet air Ierrn., ccrstarai icrque ca 1 be rnprrtalred Jo PP.FPAPED I ' Fta:an Ploncelu. 7_rarrar, Data genera mi ay Gal; Er/1rr.e Rat ta ?fr Veasrr. 310 01 Rn1 Data Sat :WS/23 01 302 Prirtterl0.5ran2CC8 0 J11 RL n tc 800 rpm. c'10i? 2 ca! 1 G 361 6 AL. -+4.-; ... 4_4'aori GAEI ENGINE : E SPL CIFIC .fFtCI-riLCI L IIT+TA OXY Eriterpti3* • Corm Cru sk Compressor Etollon NOTE1 t Eel NI r.ir M a w.rr, n04 )oi•e triiver• vale. txrr',s ortrarrOr % : ?a, al h.I .Cs1 ▪ Fi*CA+:uript•o+t ::%•• or Ira lox! ora 5 Use goar fvw airemote, value Y1'ato+t^'aTl:*.:r'•5a�. e' TE nPIaAw s It;' rrarer4o0 potlit.r• M a nnrr,rla .an.B war a tLlrer.V'ce vl S • Erato / Cask Wr{VraltrU* % r't.rrnat .#'r:# 41' s`4�•yr„> r-rc3' r•l:4"* 6 Ear. ,W tnw rttr s S Or • *et' Caen row a morneral vahin Aft. a wieraFtd al tt 7 Err'iio eves ROI fincine Et ^ t.141 vas go iv GI ro ally at ”eaiRrtirt Vaivas ore trased or ercine 7zerar a steal), s'a,e corm t•srs. alarsloti Me LW.:,tri d tarlr .; .r .or !r''P. a:.Dt Fut rr•E.,#rt r 4rt.e• :ar".r)r ra'y r p)? 'mar' t 3 Va Lgs irt.t are r,;grwr rr,arr nvrnmar C+Q !0 iaow to. rStrueaentatnl mealur*toeft Pro trr7rrt to engirt t venal Ors Trey .ritit•Vale lo emieeo val..es d Far'a++r�l r r'rrer 4v r i if*'et,a oraei,..Irr(jr►*rtr3n c 41 fitw-a'e al Tse Q^#ez. ed VOr lvel Tuterdret -s U w 9 trret +Ct.rl • e v.a4,e•y art norrvrrst TOe^rarrcai tantCt urs ii ate: watt' we : i0'; tG' I<?t wi'N c'l;LA 5+i'•- 3- rx7.AtiCr :::V t for kat a" �iIC r1 frn = Sok tti. artr_+rCO..r:r ceZrnt 617,Vc.:•©+' uOK or tlrerCCO ” 1 -ear' onset or '3t_'ur !Or re lie *it,. 0,0.• ark/ Tlet a'r^ Y'Stu spat!' id Alter'trO+et twat ;ear tc+3d ate ta• retOrerCOON Oo not Lao pan tcsad aaia tar roar e‹:t•,arc.or s t rxuy 1 ..tok' erct-arn.• _.t ^; c'1%1 s Bra Mat na)r: r, t,T+ IF* __tfR v itr aoprec :O'e±arii; 'r`tEpAREiI $Y Ay , P.nipi,n;t Tgy,prntrit parr. per's,ra:ed Jy G. Cr g re RaI rq Pio Ver y.on 3 Crit L'U Rat gala .at :5L15+33 lit .•n; Pri:lett oir'eu2008 • • G3616 Gmcoup a;S?ii0t,APFor=a , 1 Constituent Wale(' Vas)3 Me:Ra, ^e [Inr�tl1� I'icrotiiane Norbwalrc ts4aenrane No,; re n73r 1� rle•arIA IIe.3ne >•71IroDen Cart>a1 D-ruKie 1• ygi 0 rr' S 41 it t1„ aI L+1]I: Ila:ono( rde **di V?on Oxygen { lemma NeGpent3ne DctOre E1hytleoe Propyere 1'01 Al (Vorur"e `•c; Abbrev H2O C3ri8 .so 4ar1O I1¢• C4FirI;J .r ti e.or C5I412 C61-11-1 r:1II '42 Ia{$ CO -I2 44 ,leu u5rt r7.11.i 111 C 91120 C2-14 CATEAPIWIK� GHS EN3rr,{E SITE SPECIFIC TECHNICAL (ATP. 0 X En(erpirso - Corm Ci ears Compressor S!cllioti Mole 'Vu Norm 0 0140 0.0/ 40 0b 0 85 0870 1020 5 ' C20 1 402(1 + 4C20 0. aocio C 3To9 0.2550 C 2f.50 I) 14413 a.I=t0 0.040 0 "010 0 1$6(} 0 I6 0 0 1580 0.1 Eil1 0 0.8S3 O1.1880 1 0003 4.0;00 0 0000 s o000 U 0000 0.0040 I} 0000 0.0000 3.0000 0.0000 0 0500 0.0000 9 008') 0.0000 0 0230 0.0280 0 0104 0.0100 008-1U C.0840 1) 0030 0.0030 100 o oo 130 0000 r' uyal Woke uU I•,tlrIII p1 7fkJ9 W c : .FlJ41CI# 1 C,':vulltat blelharle Nun-,af. Lovrer Wearing valtre (bt,4,t hagne: re3ung Vague IB:,r`:rcli W0118.2 hide, (alrsttl RPC (%) (To 905 SIbIs i 1•001) Con prossitAny Fal:t a• Sra:cn A F 11:141.4 sv`rl,boI' Stly.cn +SIF I3vv10 0.1ass'11+rals} SPrifIC CaravIty (R,Iarive Slaw 11 : Hem :,,slant (Kr Conn Cr*ea atll ),40....-... IV pro N Am. -A tavalarel Ara {t►11*V.,. 11.y K. 57140PYl D. rMiC wiz, R11. GigioriJ• ikol Ua4pc limes km Wrx r ^•.Y ,1r4 ..e• 11 IKa ISM/Ammo 1M rabg'.f r MI kW' arrrc340J A r wa 4J q# Ca Val b WI' 'WIN s c•Am:•ei 40 toMt 2 rr.b 1 W 1*.M.•11wWA-4 &IV nt.+A RPC ply,' 7 6,44.4 as ry hist,.. 1,40).4 I,F'tlw. irri.f .nG IVirovur!ysi ITA sl la/ ngnwa Orlryw +r *WIT am 1•••• r -.f kr atn�.ltr 41,4is+*d,e�N rfr.a.+�aw P..i41..41141aJ 4*I'.l 71M Ir'\Vli:fr,u`,•F11Pf i',. i 416.0ga, •__ 4 ity'.,}r .,b1,,l }�'fa wog,an 1,44 wM GM6�1 .W %,1.... r„,-,, M,..pp : ++C,Ii4rWM iMsnnardrr,0 Prat y••;,.nr. va W.lar1, -..4.IMx++ of aI Wm 4I14 14.rd6 Pim Ca.l1L3s WG Ari. PO L I• A W4 01 e.zrlr 14 A.kwni pla. r ramm;'+.ar1'Vo1 cetw rlt m ?t'r) Iryr.1,10 a ie0.+r.a. ,•a r4ldfrC r .slctil �dd `i G.14ra.44wtins aM m.m. tt• %mum Mr.aAr Earn*" L...1 i *• As, v sir lid• K -s,. ile. w.91WNAt In »y If.. 1.p 1+m+,r+• ;rtm.arlan arai um*r :Tutt) .M{ WI WI ,ar•.w* *- P11ai1 r* .n'a..04 goal .rNf.+,.+ I7 w,w.m kr mia... a I.!..•30. Nadi I..1 [f'AW,V,.Y+y 51Ir we •uiOrw,lw11o1 War. W. gArtfrpaar 14,01( 94r=i:.n"sio* ,p: OW i101✓4Y e. rC:uKli+v=i ♦.rr' 9,._111 t4'+l." rC..7 tlat.TJ.Ct 7 a .pvaal wow ca,ter.41.r. t Lnv Mr4l'. '][ 41e 71W, 11,1111 Ir Imam),../ a.deGHr ei.d.tnr ,r AIN Iy. q S"1iti N4 L-! ravIRr ..! ION L1CWw j 7,,r1131+151rlrw +r�r PREPARED B' Row Pfcqjrce TC O. 1? H3a:a get rnte0 fl1. Gas i'n;,me a:rn:"Ta Vrrslon 3 00 00 Rel 13= SeI MIS tl'rid}' 00? Pr.,)!et7 05r 200x1 54 k 96E I0`d9 1193 100°x. 0 DP 10.06 15 3S 0.655 ',302 Bae r)• is If4 in pr.. gr ill&.Mfrs. MI] fM.r L1 Y, t,ar"I W 0.•1n.111 Pa•a4 4 00 4 rEMIP T7`CHNQLCG1 5 PREPARED FOR. room -oft : vi ea e'r•+ LVLT"crg 'a.s!-c !T: En Yet 3:801 05 77 AR.. 'JKts 107 t ato..e r CUTE 041:0SOS0TC Eep*'es 741 4 .'Std A dcFOI AT`*N PROVIDED BY ATERPi1,L,AfI Eng a Gbai© DM: S ne tr1Vt5A3 DI at„ 9 C Luc ! DVIt i1t 1000 Ihiceir-Porerr 4715 Fye' vs Yoe al :41 P1rr� %:e 27 Ammo °priory • 1 - S 8760 Ex-au:r F:w. 31".S CFM r7.1.1irt 876 �r.:.Ratyr Enirr i+tr-ryosa+nt 'Z W-' Emrstilon Dares rki• 4''(i 9 org, CC 2 SC tit, 4 Tre: 6 01 {fi1tY n1 !:lJNr= 444 y f' p h' t 70 B P05? TALVS" EMISSIONS TD BE ACHIEVED BY EMISSION CONTROL ECU+PMENT SNGL.E ELEmewr polsoRmAMCF a14. LrrMrearo by tY• doitcr r.ar6 I Gfl •83% r oh7l.rtrt 1 Forntotl.:r yt a ?Ill 'A +educ11301 C CO TR0L EQUIPMENT CATALYTIC.CONV RTERR.iStLENCERUNIT Re -owed F'er Enciirt rt' Fwd.- EAS -6200Z -2022F •S 3 CE E (Ada! oil Pid:JOus gr.Jl,4 ft: 3+War :'lur• /Or ittII'J1<03 rat rrtnr Sae E5' 1: :1 S. C�taisS! Estrri,r4 ) 1124 sl Ar.,ce oie I10i111r+1 �0 4rr rc#uar. 11}i $1n•G1 Sa-ple Pons 614 ; NPT} 114.1ti. Cooriiiour.s Ze llut tate r.onges cutlrrt'wonnrmom 22 !AIM eeIlfny,% C;Ofsf4Jr4i..o. Atiume n310 r End Crul 7.Itrn;.rr into 2r 1111't1 Siierrcet Groor rfglt irpl !mai or. ibA Delivery 1 •, two&s dependone on so on tdsd G3512 LE 0 " • • ENilitNE SPEED trim; iMPRE5.5IOri RAirrti AFTERG'X LER WATER t}s;.Tr.'r' I •FI JACKET WATER OUTLET I'Fr COOLING SYSTEM 4,313'iKINSYSTEM EXRA11$ i MANIPoLo ti OMBU5TTOr; NOk EMS:.6ION LE'JEi. 14.1,np.ht N^O SET Pr)* T imak; i} GAS ENGINE SITE SPECIFIC TECHNICAL DATA ENSR CONN CREEK • Colorado .-A) 130 210 JWtJ{.. Al: ACIEM3 ASWC Low Ema.S,?n 1 2•3.a :J41 SYSIEM CATERPILLAR' HPG IMPCO WITH 4 FUEL RAT ICJCONTROL SITE CONDITIONS! : l▪ J'eL PRES URE RANG:(1.1%41l (OEL MET I NE NUMBER =JE1 L+4V 1:Uhiis ., ALM I,IC h r MAxIM.lM iNLFT AIR lEMPERA'VRs, f I NAMEr7L4T£ trA1 r}k, Gas Analysis 0.40.0 64.a +ta 100 f.:60 LI1pCj 1120C/1:v6 I.E CON5t1MPTION 1t i V1 - MAXJMUM SITE RA!HGAT MAXII iNd INLET AIR • 763," P AT111IG I TEMPERATURE. RAATI71G - w )TE3 . LOAD TCQ% 100% I 70% tai* ` NG1.ME POWER ,1 0)000 3.,0 132 5.86 .130 ,PALET AIR TEMPER41r1f tile5 F 49 " , 1 IDIJ I.E CON5t1MPTION 1t i V1 - :;h� rsr...�G, -nr 763," Ti; , F!.'1K3r'� $5`2 �UEI:U"I:'Jr;IIPTIOFt iFiNV, i=1 Fbh:M'1-hr Y451 S56ii 34-, 7 + AIR FL'_'•'W 13. It4er &301 '"•a`• tile5 4f?! AIR FLOW WEI i77 F :3 ? psio# ::.I, Scl,•1 7941 O.5$ 1.151 1024 +`ILEI MATIIFOLD PRESSURE :41 N, *igiabS) 67.0 e,1 4 Cr P 37 t z..KHALJST 0 ACK TEMP EI T LIRE y51 F 634 Er30 dlir 810 DO.1AOS' r3A5 `tOW le slali+ li>irlt, t4 5 ;.ti3 + ; 6 • FTeAhrrt 5047 415.46 !MO :64E+ cKHAU ; CAS: MA•5$FLOW lc. ItA1r IL`+=e S'67 5232 4772 N(.%r eas rr,):1 - at sethp.re- t;0 t 5+7 , t %C1 s 51) G0 17 44+111-rr : !q. 7 F: 34-, : 3! : 3 ►1C (molti:_lae wl of et-. ;U., !71 rIthp-' 43 15.7 7440 3 1!. 3 56 NNW onoiecular *1 u Tv 8.:1 17i ;Aro .rr O.5$ 0 67 ! 0 60 0.68 110,04E1 -1C .Tnaeafter wI or 1;'_'.6, Or attelip n 029 0 NI 0 22 0 36 1 -ICI -TO r Ftxs*lteh?vhydee k i7 I Il h;-I"r 0:$ J ;- 0 -21 0 3y} CO 171 elRlhp-IT 541 `.4.° s F0t ExHALIST OXYGEN! is 1 %DRY a 2 e. • : n 7 8 HEAT REJECTION HEA? REJ "TO JACKET WATER :7• B4srrmin ' y76+?7 :moil y'•138 T3 -e? MEAT REJ TOATMO$P41ERE ;11 aluecnir 3f43 34-, ;370 :429 +PEATREJ TO LIRE OIL ;1i Rive:Teo 41Z 1rri.: 7440 0941 41E47 RE.1 1'41AFFTE C_,C,?LER i I1 iO . 1u)mIt+ 635$ '?Gem 11 .7:,1E HEAT EXCHANGER SUM CRITERIA HEAT RE,; 1C JACKET WATE91L!I8E ✓iLr=1Rr.u1T HEAT RE.' I0 AFT ERCJOLER 110, '3iu'mrr, 110et1rri 141u/rpm A coolireu syseem salary Noir of VA. has. m:;1 3.T 3011 14 Ire h I rx. nan-oi Si ng ,�11 .}• % NAn e.. s 4 • . • •d1 +l•a . • • •_.11._ ! .d. at, .r a•i . . e.: • .. ... PREPARED BY f3rn' 1 n iIj. n y Erlrxrar, Data wncrare,3 :+y Gas E--ine RashnN Pro Vrollon 1101 O Rer Data Sol DIV 5364-O -O' . Pooled 30JurCTOS a Pico 1 of A G3512 LE 900 V TOO G ROO w150 e 27 A � I 4 111 2 GAS ENGINE SrTE SPECIFIC TECHNICAL DMA ENSR CONN CREEK - Colorado Engine Power vs. Intel. Air TernperauTiiii CATERPILLAR* 30 401 1 1 00 10 40 90 100 /.n 1err,peralurs "F Engine Power vs. Engine Speed 110 35.00 3000 t 2500 3 2000 1500 S'11000 LL 500 0 900 950 1000 1050 1100 $- Timis Scroed rrp+nl 7150 1200 1250 Engine Torque vs. Engine Speed -- ma---- --------� MI In=monnrf =MN 00 0 00 EME 111 IIIMIE ao O0 0 , la 35.00 3000 t 2500 3 2000 1500 S'11000 LL 500 0 900 950 1000 1050 1100 $- Timis Scroed rrp+nl 7150 1200 1250 Engine Torque vs. Engine Speed 900 050 1000 1050 1100 1150 1200 1250 Engine Speed Itprnj 170 130 140 1,Usti internunerl ,t*ral.n; Rioge 44rx Torque. vs ^� 4'te0 Capetii;Iv ir/ Stle Commons Fa Cori rx.104s etal,rg Flange i7 1andar.3 C ur 1 'Gnu Laid Intrrnmen1 wit Ringe Note At amu• a70rtdtttE.970 it arm 10C`F i i i ,r temp tY1r1stare. ;clique an L rrldrnt3•ied Ate to 1100 'poi PR F.PN E 1..) :1Y DrrrtI *n P-bb.grer E a.1Krar, Dwg,genpraTed ay Cas Ern ftgtng Pry Version 3 010: flet ()am Sul DlitIS564-00,00:• rrnrQd 30ruf :'006 eve :al 4 N i , 900 050 1000 1050 1100 1150 1200 1250 Engine Speed Itprnj 170 130 140 1,Usti internunerl ,t*ral.n; Rioge 44rx Torque. vs ^� 4'te0 Capetii;Iv ir/ Stle Commons Fa Cori rx.104s etal,rg Flange i7 1andar.3 C ur 1 'Gnu Laid Intrrnmen1 wit Ringe Note At amu• a70rtdtttE.970 it arm 10C`F i i i ,r temp tY1r1stare. ;clique an L rrldrnt3•ied Ate to 1100 'poi PR F.PN E 1..) :1Y DrrrtI *n P-bb.grer E a.1Krar, Dwg,genpraTed ay Cas Ern ftgtng Pry Version 3 010: flet ()am Sul DlitIS564-00,00:• rrnrQd 30ruf :'006 eve :al 4 G3512 LE • c' GAS ENGINE SITE SPECIFIC TECHNICAL DATA ENSR CONN CREEK - Colorado CATERPILLAR` NOYES 1. Engine rating is with two engine dnven water pumps. Tolerance is ± 3% of full load. 2. Fuel consumption tolerance is ± 3.0% of full load data. 3. Undried air. Flow is a nominal value with a tolerance of ± 5 %. 4. Inlet manifold pressure is a nominal value with a tolerance of ±5 %, 5. Exhaust stack temperature is a nominal value with a tolerance of f+)63 F. i-i54'F. 6. Exhaust flow value is on a 'Wer basis. Flow is a nominal value with a tolerance of ±6 %. 7. Emission levels are at engine exhaust flange prior to any after trealment. Values are based on engine operating at steady state conditions. adjusted to the specified NOx level at 100% load, Fuel methane number cannot vary more than ± 3. NOx tolerances are +111%, -95% of specified value. All other emission values listed are higher than nominal levels to allow for instrumentation. measurement. and engine -to -engine variations. They indicate 'not to exceed values. 8. Exhaust Oxygen level is the result of adjusting the engine to operate at the spedfied NOx level. Tolerance is ± 0.5. 9. Heat rejection values are nominal. Tolerances. based on treated water. are ± I0% for jacket water circuit *50% for radiation, ± 20°ro for lube oil circuit. and ± 5% for aftercooler circuit. 10. Aftercooler heat rejection includes an aftercoder heat rejection factor for the site elevation and inlet air temperature specified. Aftercooler heat rejection values at part load are for reference only. Do not use part load data for heat exchanger sizing. 11. Heat exchanger sizing critena are maximum heat rejection for the site, with applied tolerances. PREPARED BY: Brendan Haigney. Exteran Data generated by Gas Engine Rating Pro Version 3.01.02 Ref Dale Set DM8564-00 002. Panted 30Jun2008 Page 3 of 4 G3512 LE GAS ENGINE SITE SPEC(F)C TEGld 1K AI. DATA ENSR • , CONN GREEK • Colorado Constituent Abbrew Kok % Noun Weir Y rad • 4:'7 0 Cr iQ 0 cr14.6 N41'4'4' CI41 M :A 7... 3!1 CVO r Via 0.4 (Mara.._. r 'CCV r r` Amine C3 e t <CO "rr1 r 'Jaw. ea KJ -lain!. sSd C.4011 C ::o C .050 ling -ss+ W -Clod•) a =SS? C 14`3`5: Cair.i.trit4 F41191 ptga.++. 114Ci 11 :tio-a.P.1I C 4 4s 0 1140 :->o..p^rr mop,4rferLTT.Clw tKrrifrsa-+e rts-P. 1: C *CIAO C 10,60 r‘v rte. G Iy!.3 0 /SW t •,and ^' hie 0 1. C 'old° Low. r a rrIvis:ua la'u"K fist NV` ti: 0 VIVP 0 COG r+ ,or •410111169 V1;#,Eta id ''r3wee $Jtfk ►R 0 01 0 sr4{CtFsi[ �+�do� Mt... -/.:J, ;,41.,(e Vxx-1,.1,41• CO 0 00.. i 0 0000 t*rrt•car. ►C AC(0) 0C400 Oe NV' .74. C COX 0 4[770 •left.•- •°E 0 MX" £ 1XI 1.}:101tC CA1.4M 017+`1430 C 0:10 Iv.iien C1it0 MO G WOG Er.,wr1+ :.1-4 0 Cte.4ri a iii;. =trytrr. Com* C X C 33 TOT lig. jV.Jtry %t !C; DOW Ile Com, =Tv+ -b t 55raa+ 610 r: WarY41 Sste4P AeV pit.. it,4:rnNur: 5cs.os Cra, Fr Cifaatr..lc. Star.". Nag 0114'3111 IP I Cis �.+aT rs a �4+.7a•a u.r .�. •14.. y%Lots Mom mot Ponsiso 'ryw.. • ... if ewes Aar • to ...4 d. M 1..4%.9411.•* gni t Cf.•L r f:A' .r. a.- . ...+y Is w. 1..1 ya+ffi• / Ar.."ryy.&rW f4.rzb •w1. w. 4+ r SOAP;.. El..r .I •: .a•.r .• rrt .FM 0004 w .r. .0.04.111+100,• r,6 4.4 104m6/7r411A . t ! • rte. =We .... N I ..r A. .* rr .M,A. 004 .+.61•+ W •.*4114..+. S. a....c•.. •..t..+..++ 4 /.....�........r t.*.. 1rrr.j t•.. p"4 •" r.t0 w4 f r.+ +.4�. - 7w.w. Ir'f — aw+ .K++. /.•n. ani . — ..011•�•E'•I011.+.1aak.i4l.r.a r..•fa •r.1 II'1 geese /+l.••.• — MR./401 to w 1P.I.9r 4 11.0.4411.4 :000,404.P. Ole a01.1+ ...R..r.. •r •. I....p... .• Mr. a • •.0 46.•.14• f 1a! rltlaittl Mks *mem. me11..P pen m, ..J® wee.•..d y-.. ++•°►..srr. 1001 F1 t. w7 Mfw49. r ••rv70 ..d .. ...r ..I I. ri..r as .Ell. r..000I04 t.. •.l+ 14 wet+... iwrf •.....a.. 4 v W. y� I w .. ••..�+f..t �M r wa.... .1.. '!•**4 4.9 l'.. r 1 r -..}yr. t I. P.wf1.r4. —'tilt./.► ■ h w+Vw 5+ •R+ S. r uv ahI• 0110/.. •w ,. / woo w t+•f Uri 4 411 4.4 a 4Vw.4.! +a..IMN *asp. Oa. PRF"A ED O} rmarlifiliNrwo EAof c_ • I)ftrtatel br tat En.rxr Ra lfN Pro vv —+ .1 C11 141: . ••4•Y •' 11 • •.Ir ►rr....o". 41.114 Mim. Atm. .Aa . per•• fa41r+ 4 +)T i Appendix C Electronic Model File Archive README 05252-008-140 ENSR October 2008 0 0 a U 0 U 73 October 2008 quality impact analysis for the File Contents 0 v U 0 v ,41 0 0 U Z Cy.Y ulemj C7 * * * * 0 'C3 'c":5 0 C.) 0 LL N F U 0 C) v 0 CL � 0 � s U Q 0 N ®2o 2 92 v P U Lu en W es c C] om tt 4.7 C CL at © < Z "a vs a U v r3 . ,a eL "M LA LA 6. IS -0 0 .0 P. _0 173. E w .= 0 0 . 0 < '0 U 0 - 0. ,_,•v 0 to . cl, V .. _ •7, v 0 F.. E H wPS u al - y -1, O r U E Q0 6. .-.I C .3 C E41 3 .) ae d d o 4.t c. = -0 a U - •, = -a �- U C z .2 U C GU Gq 0 o 0cia u�°-0 1-. a' 0. w 0 c u .0 -c -E p F E 0 - cz '+c C p a' . -0. 0 ❑ 0 a U A 0 -Era s W 0 0`"�,U "'th 4 0 W as -- 7 CA.L. C C 0 E' LL 0. 0 cry a' 0 C C 0 4 V C G C C t tl' � 0 tn III � M U 0 v � 0 II z 0. = a' J cz 0 -0 ❑ o ,,r L3! 0 ›-.= - a 0 -- �s C Ls - v O-0 < 0 s 0 0chn " C L V) E.4-.0 cn LA LA � _ N 0. C. - C U 0 .n 0 ,.. t0' - C) Q x I 1 C J "(J II Ca. O C - C Q 7›, 1 C0 0'- of ._ C C 0 0 ' G .a GU3u '� il 'vd Q C G U on V as P r - s II C = cn .. 0 cn v% U a' CZ < DRi T '- jy L2. C 0 -Q L. 0 0 C L}- WI CU +n c/. • •� = g 7.S... . CA 0= 2 II w w C 15. LA 'g D ate' °3 E 0. 'v t,.. C G4. LT- '47.I O En D a2 4© cai C Wt�'cnW W.- LI CL U C C) GC' 0 C} C) E W KP4U .� C. 1. v En -0 Eu d 0 Vt�II c 0 G. .� G •N Q 2. r` u.* *'* C]8 x * * • • 0 0 U 0 rC6 0 U CC LT- tJ 6J EL— col 0 .S$ v 0 U 0 U 0 0 O ^ c3 CJ 0 C .7 cU O 0"C0 0 0 v� "ti a.,) a.) cfl a) EA Po 2 L1.1 tm- Q x 13 -0 LT- E [ ] E v L �n 0 E- t) CrLTj r3 G '- O C4 i.. U f 'L p 4? L eu< err w ug topographic maps covering the project area • -173 • Cil r!Y a▪ ) 0 • Li= 00 CA' o • o C c w 0 CJ C? cu v v C - . 5 CG U v co v Cfy LQ YG • Q 0 4:4 ict2 w rte¢ 0� = E v v ct. ✓ ' v 0 c u v faj LT: t.Q U eJ -16 0 01 as C UI I C] G LCD •:" X O w ar N. v w Cm 0.0 Fd ci.0U ala`, Q 0 7 * * U v 1 • File Contents CC E E ate+ /o , V 0 o 6 ml CQ a5 °J w r -C • C• - •i3 G) .L o -• o a� 4' o 0 o aVi I • c— • ca V C, °C. = U - C N • a.+ ▪ .-C _} • Q. y h -4=1▪ .¢ E �+ 2 ' S• A10 0 -a O Un -edited off-site source inventory file received from CDPHE I I I 00 00 00 C) o c7) cl el 00 0o c o .x c so. a. ) a (-4(-1 O 0 i V o U 0 c E V1 G t.. = U 0 cnP40 on s. rn O z cn C a LL] a) ..0- d 7 S- "a 001 • -, LIZ Uc za zco Appendix D September 19, 2008 CCGTF I Condensate Tank Battery Modification Construction Permit Application Package 05252-008-140 ENSR October 2008 ENSR ENSR 1601 Prospect Parkway, Fort Collins, CO 80525 T (970) 493-8878 F (970) 493-0213 www.ensr.aecom.com September 19, 2008 Mr. Mark McMillan Supervisor, Oil and Gas Team Colorado Air Pollution Control Division Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Dr. S. Denver, CO 80246-1530 Subject: Modification of Existing Condensate Tank Battery Conn Creek Gas Treating Facility, Garfield County, Colorado Dear Mr. McMillan, On behalf of OXY USA WTP LP (OXY), ENSR Corporation (ENSR) submits the attached updated Air Pollutant Emission Notice (APEN), construction permit application and supporting information for a project to modify two existing condensate tanks and install two new condensate tanks at OXY's Conn Creek Gas Treating Facility (CCGTF). The CCGTF (facility) is an existing natural gas processing plant that is operating under several Initial Approval construction permits. The facility is a major source for purposes of Colorado's operating permit (Title V) program. OXY submitted a timely and complete operating permit application to the Division and the operating permit is currently in process. The facility is currently a synthetic minor source (area source) for purposes of National Emission Standards for Hazardous Air Pollutants (NESHAP) for source categories known as Maximum Available Control Technology (MACT), as incorporated by reference in AQCC Reg. 8. AECOM Background OXY owns and operates natural gas production and gathering systems comprising the Grand Valley Field (Field No. 31290) in Garfield County. The Grand Valley Field includes numerous well sites and multiple -well pads that produce natural gas. Gas production and gathering operations include three areas of operation known as: the 'Valley" (Cascade Creek and Conn Creek Drainage); the "Mesa"; and the "Logan Wash' areas. Produced liquids (water and hydrocarbon condensate) removed from the natural gas production stream at each well site or pad by two-phase or three-phase separators may be stored in one mixed liquid (water and condensate) tank or in separate segregated condensate and produced water tanks. The liquids are periodically transported by truck to OXY's Cascade Central Facility Mater Plant") located in the Valley. As part of a strategy to reduce condensate transportation costs and to achieve a substantial reduction in volatile organic compound (VOC) and organic hazardous air pollutant (HAP) emissions from condensate production (flashing, working and standing losses) and truck loading activities, OXY has undertaken a project to centralize condensate handling. Ultimately, OXY plans to transport more produced fluids directly to the CCGTF by pipelines, where the gas, condensate and water can be separated and the vapors flashed from the condensate can be controlled. • • ENSR • Mr. Mark McMillan September 19, 2008 Page 2 The CCGTF (AIRS 045/0831) is currently designed to treat and process up to 40 MMscf per day natural gas gathered from Valley, Mesa and Logan Wash wells. The CCGTF currently operates two 400 -bbl (each) condensate tanks designated TK -415 and TK -416 (AIRS 045/0831/012). The condensate tanks currently receive mixed liquids (condensate and water) from the facility's Inlet Slug Catcher. The hydrocarbons received by the tanks are at elevated pressure and when the condensate enters the atmospheric tanks, flash vaporization occurs that results in emissions of VOC and organic HAP compounds. The tanks are operating under terms and conditions of Initial Approval Permit No. 06GA1232 issued by the Division on October 17, 2007. Effective May 1, 2008, the existing tanks became subject to statewide requirements for condensate tanks set out under Colorado AQCC Regulation 7 XVII.C. OXY installed a closed vent system designed to route tank vapors to the existing flare at the facility and since May 2008 the tanks have operated in compliance with AQCC Reg. 7. Project Description To accommodate expanding field -wide natural gas and condensate production and to achieve strategic objectives for centralizing condensate handling operations at the CCGTF, OXY plans to expand the tank battery at the CCGTF from two tanks to four. OXY will also install a separator/heater treater and a vapor combustion unit (VCU) to control emissions. In addition, a produced water tank will be installed, along with a pump and piping to transport produced water to the Water Plant. Stabilized condensate product will be loaded out by truck. As illustrated in the attached simplified process flow diagram and projected site diagram, one new 400 -bbl "Separator Feed Tank" (TK -5235) and one new 400 -bbl condensate storage tank (TK -417) will be installed. The two existing condensate tanks (TK -415 and TK -416) will be converted from flashing tanks to stabilized condensate storage tanks. In addition, one new 400 -bbl produced water tank will be installed (T-5310). The new Separator Feed Tank will receive mixed liquids from the facility's Inlet Slug Catcher, which receives field gas and produced liquids from the Grand Valley Gathering Systems. The condensate received by Separator Feed Tank will be at Inlet Slug Catcher pressure conditions and will contain solution gas, so flash emissions will occur from the Separator Feed Tank when the pressure is reduced to atmospheric. All four hydrocarbon tanks and the three-phase separator/heater treater will be connected to the new VCU(s) by a closed vent system. Mixed liquids from the Separator Feed Tank will be routed to a new three-phase separator and heater treater to separate water, condensate and any gas still in solution. Water will be routed from the separator/heater treater to the new 400 -bbl produced water surge tank. Stabilized condensate (no solution gas) will be routed from the separator/heater treater to three condensate storage tanks (TK -415/416/417). The condensate received by the three storage tanks will be at near -atmospheric conditions, so no flash emission will occur. Working and standing losses may however occur from vapor displacement during filling operations and from diurnal fluctuations in ambient temperature. Condensate will be piped to a new truck loading station located just east of the CCGTF. Water will be pumped from the Water Surge Tank (T-5310) to the Water Plant. The VCU will be an enclosed combustor that will achieve a 98 percent reduction in VOCs. The make/model of the unit is yet to be determined, but the VCU and the closed vent system will conform to AQCC Reg. 7. The facility may install more than one VCU, as necessary to accommodate vapor throughput. • ENSR Mr. Mark McMillan September 19, 2008 Page 3 The modified tank battery at the CCGTF will include: three 400 -bbl (each) condensate storage tanks: one new tank (TK -417) and two existing tanks (TK -415 and TK -416); • one new 400 -bbl Separator Feed Tank (TK -5235) • one Relief Knockout vessel (V-5115) • one new three-phase separator (V-5240) and one new natural gas-fired heater treater (V- 5245) • one or more natural gas-fired vapor combustion units (VCU -5116) • one new Water Surge Tank (T-5310) • one new separator feed pump (P-5234) • one new water pump (P-5311) and piping to the Water Plant • one new Condensate Unloading Pump (P-5234) • new truck loading station The current Initial Approval Permit No. 06GA1232, which was issued prior to promulgation of statewide requirements for condensate tanks set out in AQCC Reg. 7, includes terms and conditions limiting condensate throughput to 7.300 bbls per rolling 12 -months and VOC emissions to 55.3 tons per rolling 12 -months. The attached APEN requests a substantial increase in condensate throughput from the current permit limit, but with the 98 percent reduction that will be achieved by the VCU(s), VOC emissions will decrease substantially from the current permit limitation. In addition, as discussed above, field -wide VOC emissions from the well sites/pads will decrease as a result of the centralized condensate handling strategy and the reduction in emissions at the well sites from flashing and truck loading. Also, the reduced truck traffic will result in a reduction in vehicle miles traveled on unpaved roads, which will reduce PM 10 emissions and truck exhaust emissions. The tanks are not affected by federal New Source Performance Standards (HSPS) set out at 40 CFR Part 60 Subpart Kb and incorporated by AQCC Reg. 6 because the tanks each have a design capacity less than or equal to 1,589.874 m3 (40,000 gallons) and they are each used for petroleum or condensate stored, processed, or treated prior to custody transfer [40 CFR §60.110b(d)(4)]. The tanks are not "storage vessel with the potential for flash emissions" as defined in the Oil and Natural Gas Production MACT rule set out at 40 CFR Part 63 Subpart HH. The oil and natural gas production MACT regulates "storage vessel with the potential for flash emissions" located at major sources of HAP. Subpart HH defines "storage vessel with the potential for flash emissions" to mean (emphasis added): "any storage vessel that contains a hydrocarbon liquid with a stock tank GOR equal to or greater than 0.31 cubic meters per liter 11,750 cflbbl] and an API gravity equal to or greater than 40 degrees and an actual annual average hydrocarbon liquid throughput equal to or greater than 79,500 liters per day [500 BOPD]. The Separator Feed Tank will have flash emissions, as discussed above, and the API gravity of the condensate will exceed 40, but the actual annual average and the requested allowable annual total condensate production rate for the tank battery, requested in the attached APEN (96,360 bblslyear and 264 BOPD) will be less than the 500 BOPD threshold. As a consequence, the condensate tanks would not be affected facilities under Subpart HH even if the facility were to become a major source, ENSR Mr. Mark McMillan September 19, 2008 Page 4 We have combined the tank battery into a single APEN form. Separate APEN forms are provided for the heater treater burners (0.5 MMBtulhr) and condensate loadout operations. The APENs are attached, along with supporting emission calculations. Additionally, the Division's new Operating and Maintenance Plan Template for Condensate and Mixed Liquid Storage Tanks (Ver. September 10, 2008) has been completed and is attached. The APEN fees ($152.90 each APEN, for a total of $458.70) will be paid separately by credit card. Since the facility's operating permit is still in process, OXY requests that upon issue of the Initial Approval permit for this project, the Division incorporate the applicable requirements set out in terms and conditions of the modified permit and AQCC Reg. 7 into the forthcoming operating permit. if you or the Division have any questions or concerns, please contact me at (970) 530-3458 or Alonzo Hernandez, OXY HES Superintendent at (970) 263-3609. We look forward to working with you and the Division on this and future projects. Sincerely yours, Kenneth A. Malmquist Senior Air Quality Engineer km almquist@ensr. aecom.com attachment cc: Alonzo Hernandez, OXY • • • OXY USA WTP LP Corm Creek Gas Treating Facility SIMPLIFIED PROCESS FLOW DIAGRAM a a U l} N Condensate To Water Plant r. To Truck I.oadout September 19, 2008 9702436868 OXY USA GRANO JUNG 06.53:19 a m 09-17-2008 1 11 KNEE PHASE • /REIM x-5244 fs Cl. I-' air F 'mat 3-5277 1.-5238 VAPOR ll1:14 VCLF-SIIi- MAT 15tG5li 1913 -. 1K-415/414/417. } to11E11mr1 PIMP P4511 /45t6001412K 11411 - ./ • ION nd S p1•t 1.. .� D tgp{11 twl Aid w wwr t 1 • I • AIRS ID.: 045108311012 PERMIT No.: C riz 0 U, U) 2 W z J 0 a. d 9V 0 U R En 8 O } VI Cp e TITLE HES Su F to x Q 6 6 a w " i e §f r 0 Cis — l Y 0� N o w V-- giUDZ C vi cc rt n aa r Q 2 pwo 2Lu$ O a. Q W6 Jrw, os5oa OXY USA WTP LP ADDITIONAL INFORMATION OR REMARKS. 'Tins APEN Is far the expansion of an existing tendon:are tank battery. Including two new 400 -bbl (each) tanks and a new 3•phase sepaiantr!heater treater, all controlled by a vapor combustor conforming to ADCC Rel. 7 F n.stir,.l l'roilot:l•Ai:rmal c utrlu: t. a CHECK ALL liO%1: S t HAI APPLY 2 New of previously unmoor':ex source M❑rtrqurst�ng madihcalxln of epstu+g Penna J Cnanpo Ali evnea'ona. t rougaputa or etu:pmcnl Transfer of ownersfvt+' 0 No Menge, APEN update aro ID Omer (Specify; C! Omer ISneolIo Kota Far Meister at brews -nyi rr anipariy nano cmrnge or a panni{ you ni uit alw sutrril a Consiruchpn Ptronit Ao 4a9ItNr ?Um YEAR FOR WHICH THE ACTUAL DATA APPLIES Date source began or wrrl begin ppete:ton October 1. 2008 Colorado Dean at pubic Health & Enraonwent APEN A I of I Aa Polo/ion Central Divison 4300 ChMri'y Geek Cairo Scoff., APCD-SE-131 Fdr rnfOtmeiion. Call Denier. Cckuado 80245-1530 (30.3) 02-31SO r .15 � ca ca v+ wi r" N L. Stabilized Condensate qszi C� ESTIMATION --� METHOD CIE it m tib.. c c p Ci _ M q V r p C d m aint Q CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. en It c -I [f! I© A $152.90 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send com kited Iorrr.swith fees to 1 M "in Ssgriature of Perscm Legally Aulnonzed to Supply Data: A i r Typed Name and Tote Alonzo Hernandez - HES Superintendent C lY "9 nor0: (plot to attached sketch of + = I I. Velocity Moisture It/sec Annual Fuel Consumption Actual Data ire iesteu ir,.ni (Data :.ar level Raw Cnnsum.liI un C e ACTUAL F MISSION I-. m e + N ESTIMATED EMISSIONS (TONS/YEAR) AT THI CIUGHPUITS REQUESTED ABOVE [ CONTROLLED j UNCONTROLLED !S 6 A us !'! 'THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall he filed prior to this expiration date, whenever a permit limitation must be modified. whenever control equipment !is changed, and annually whenever a significant emission change occurs. For specific details ,tee Regulation 3, Part A, C E cc m a 0 tY Natural Gas i C:1 C COrr!- / C asc Z Z A p D G r 9 id 4E'H O Cr . S cas m id N .ptiy N ° SE ® 1 r, cam c u ill PLEASE USE APCD NON -CRITERIA REPORTABLE AIR' POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. D. PROCESS INFORMATION Descnptlorr of Processing Unit Four Condensate Storage Tanks 1400 -bbl ea.) Frtake/Model rm Vapor Combustion Unit (VCU) ro S IE. POLLUTION CONTROL EQUIPMENT 1 Typo of Conitol Equipment C5 A GENERAL INFORMATION Condensate Tank Battery and Separator/Heater Treater wIVCU Control � t a VCU a ro Tana,.AI N PERMIT No.: Lw r 0 z W o. WV) E <i) E W z as J {] ri<D ✓ w O 2 } 8 Q Z it rd~ O 2 S a N li C b V )i • 2 Q F PERSON TO CONTACT REGARDING THIS INFOR 2 0 H z Q LLa 0 a a U W 0 a LU W 2 W C7 ADDITIONAL INFORMATION OR REMARKS; i wa .c •a v N M ti E c 4 s M x ill 2 IIB STACK OP VENT INFORMATION_JIde itify beSowwhich stack If plant has two or more; refer to attached sketch of plant layout) V i u 0. 6 rC :S S� CHECK ALL BOXES THAT APPLY rtiYrr rw prewtou$iy unrefgrtee SOurrM O Rei, +suns, froli Crkan co ',ming perm., ❑"r Cbahoir in emissions, Cveugipij17 n• equipment O TramsPel or ay rrefSNP' ▪ No crRinge APEN opiate wry O other rSper'yt O Dew (Spey) NOW rpr Irensfer et ownerseii or cerwa ny non* erunpe o a pelma yuu must also sytero a Coro/rm.! ton Perm.' Arphathrm loan YEAR FOR WHICH THE ACTUAL DATA APPLIES E 49 v eV O L 8 ttr a ❑ Colorado Dept of Public HQefnr. Q Eeveore nem APEN rr 1 of 1 Ar Pd ulit14 Cnnhd D+v,Sn e 1300 Chewy Creek, Drive Soule APCD•SS-B I For rniormabon. Ca! Denver Cdrxado 60246-1530 (303) 692-3150 a '.L r* 6 L -' :iiti V1 b m LL y� 61jI Ca N fV c v 4,.G Z ti:° g Q t 4 Signature of Person Legarly Authorized to Supply Data ./A/92 DApTE 'Typed Name and Tutee / } Alonzo Hernandez - HES Superintendent ESTIMATION METHOD 2 al p4, 4 sulfur content of fuel ; '" r CM 4f 4 AP42 Table 1.4.2 K m Al r C 4 CI CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE -EMISSION ESTIMATES` INSTRUCTIONS ON BACK. °�.ta r ti 2. (, F Fuel Heating Val -le (HIurlb, Bturgal. or Btuuscr) aa * CG A S152.90 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to O 0 W 4773 T Z at r,./ a 1i41 U > xm `i ti E 5 HSSION CTUAL us re 0. C G C S v t^ ESTIMATED EMISSIONS riONSfYEARi AT THROUGHPUTS REQUESTED AROVE UNCON I ROLLED 0.02 tpy 0.02 toy 4 O A cel, p' B, a 7;. w 13 THIS NOTICE IS VALID FOR FIVE YEARS. A rsvlsed notice shall bs filed prior to this expiration date, whenever a permit Hmitatton must be modified, whenever control equipment Is changed. and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, II.C.1. �py tl Cl cu 4. U Q a LL 1 a LS7 X oy En bl 2ho e m M 11 IM A. CONTROLLED Normal Opara toI This Source I Raw Matenaes Used Oescnplaxr Design Input Rate (i0 BTUfl-IR) m 2 H F W Ty E — m a __ , td � .Y' Dow PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. D. PROCESS INFORMATION Dcscnplron of Processing Una ii 6 -ie CO C7 t o C c 0 Z 0 z c 0 U a lihealer Treater Burner Ca i IE. POLLUTION CONTROL EQUIPMENT I Type of Control Egllrprnent 21O 0 L.. m E = m I E 1 �'a x 15 aa.. ab Z y° IGr firmer Aper • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM AIRS ID Nurnb° Permit Number 5 O Zip Code 81506 G 0 V Section 32.755. R97W C a c c 0 E 0 4 0 E•mait Address Controlk.d Ac:u.-1 Emissions fibs/year}1 r, rs t7 4L7 CV I I I_ HR 41• co Emission Facto, Source M w V - a Q E Reparting Control Equipment/ Bin Efficiency O l Ts g Ci Benzene Chemical wserati Service Number 71432 CaImndar Year for which Acleral Data Apple N ano(1.2or3is Reporting Sce f a a a fi Y 21 C CC 0 CL CO CO o CO1 to Supply Data (Please print) n Legally Autho Name of Pe S 3 ri • ti n N en LU z 8 c 05 0 19 J h u 0 C.1 4-0 a. R a 4 re i 0 5- } 4 Lu 4 4 z 0 U a 0 a S NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM 045/0831/012 AIRS ID Number \ § Fermi! Number .11 0 f ) a \ Zip Code 81506 2 970-263.3608 cc w « §4.7 ■ 2 E - • • / / Plant Location 9 Alonzo hornande E-mail Address Controlled Actual ,1I Emissions 4ibstyearj % ©q - m \ — k ¥ .4 $' $] . co 6 6.745.17 in d 2 ' E E8P Tank 2.0 & TANKS 4.09d E&P Tank 2.0 & TANKS 4.09d E8P Tank 2.0 & TANKS 4.0911 , ,. .w 2 $ / . . £ k u $ \. ' } & « u , ! . 2 . �. u \ Benzene Cu . I- } ƒ � Chemical Abstract Service Number rq Q E 108883 k } Calendar Year for which Actual Data Applies ;enano (1. 2 or 3) § 7 I 2 ■ s C k z ( 0 « � % $ • • Air Pollution Control Division (APCD) - Construction Permit Application PLEASE READ INSTRUCTIONS ON REVERSE SIDE. I. Permit to be issued to: OXY USA WTP LP 2. Mailing Address: 2754 Compass Drive, Suite 170 Grand Junction, CO 3. General Nature of Business: Natural Gas Compression, Processing, and Treating SIC code (if known) 1321 4. Air Pollution Source Description: Modified Tank Battery Controlled by Vapor Combustor Unit (see attached project description) (List permit numbers if existing source, 06GA1232 attach additional pages if needed) Is this a Portable Unit? NO 5. Source Location Address (Include Location Map) If portable, include the initial location and home base location Conn Creek Gas Treating Facility I SW/SW Section 32, T6S, R97W Garfield County, Colorado 6. Reason for Application: (Check all that apply) W New or Previously Unreported Source Administrative Permit Amendments Modification of Existing Source ❑ Transfer of Ownership (Complete Section 9 & 10 below) Request for Synthetic Minor Permit ❑ Company Name Change (Complete Section 9 below) 9 Other: 9 other: 7. Projected Startup Date: October 2008 Signature of Legally Authorized Person of Company listed in Section I Date Signed Alonzo Hernandez— HES Superintendent Phone: 970-263-3609 Type or Print Name and Official Title of Person Signing Above Fax: 970-243-2525 8. Check appropriate box if you want: ill Copy of preliminary analysis conducted by Division /1 To review a draft of the permit prior to issuance These sections are to be completed only if a company name change or transfer of ownership has occurred. c). Permit previously issued to: 10. Transfer of Ownership Information Effective Date of Permit Transfer: As responsible party for the emission source(s) listed above, I certify that the business associated with this source has been sold, and agree to transfer the permit to said party. Signature of Legally Authorized Person of Company listed in Section 9 Date Signed Phone: Type or Print Name and Official Title of Person Signing Above Fax: Mail completed application, APENs, and filing fee to: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B I Denver, Colorado 80246-1530 http:Ir'www.cdphe.state.co.us.!aolstationarv.htm l Phone: (303) 692-3150 Revised August 2004 INSTRUCTIONS FOR THE COMPLETION OF THE APPLICATION FOR CONSTRUCTION PERMIT OR PERMIT MODIFICATION FORM The following instructions for the completion of this form are titled, lettered, and numbered the same as the applicable sections of the form on the other side If a section does not apply, write "NIA": DO NOT LEAVE BLANK. NOTE: All information submitted as pan of this permit application and all data generated by the Division as part of processing this permit will be considered open to the public unless confidential treatment is requested in writing. All such materials MUST be (I) clearly marked "CONFIDENTIAL" and (2) enclosed in a separate sealed envelope marked "CONFIDENTIAL INFORMATION" to ensure against accidental release. Confidentiality is granted only if the release of such information would result in economic disadvantage to the applicant. If confidentiality is requested, the Division will notify you of its decision and, if denied, allow time for you to present additional evidence justifying the need for confidentiality. In general, confidentiality requests will increase permit processing time. Under no circumstances can emissions data be held confidential. 1. PERMIT ISSUED TO: List the name of the company (e.g., corporation, partnership, association, individual owner, or governmental agency) to whom the permit is to be issued and who will therefore be responsible for the operation of the source. This company name will be listed on the permit. 2 MAILING ADDRESS: This is the address for all correspondence relating to this permit. 3. GENERAL NATURE OF BUSINESS: List the business activity (dry cleaner, saw mill, furniture manufacturer, commercial printing, etc.). Also, list the Standard Industrial Classification (S.I.C.) for this type of business activity, if known. 4 AIR POLLUTION SOURCE DESCRIPTION: Provide a brief description of the equipment being permitted and the associated emission controls (e.g., concrete batch plant with baghouses, paint booth with particulate filters). If this source has an existing APCD permit(s), please list all applicable permit numbers. 5. SOURCE ADDRESS: Do not give a P.O. Box. This is for the physical location of the source. Please include a map that indicates the exact location and shows major topographic features. if the source is portable, include the home base and initial location 6. REASON FOR APPLICATION: Modification of Permitted Source - A permit modification may be required for changes in emissions, throughput, equipment, etc. Request for Synthetic Minor -A source that is voluntarily applying for a permit to create federally enforceable permit conditions to limit the potential to emit criteria or hazardous air pollutants in order to avoid other requirements. Public comment must be conducted prior to the issuance of any synthetic minor emission permit. Administrative Permit Amendments Transfer of Ownership - A transfer of ownership is required if equipment previously permitted by another company has been purchased. A merger is considered to be a transfer of ownership. Complete sections 9 & 10 of this form. Name Change - A name change is appropriate if only the name on the permit is to be changed, and there is no transfer of ownership. Complete section 9 of this form. Other - Any other administrative change as defined in Regulation No. 3, Part A, Section IB I. 7. PROJECTED START-UP DATE: Construction, operation, or modifications prior to receipt of a permit is prohibited by Colorado Statute. 8. DRAFT REVIEW REQUEST: Review requests will usually add to both processing costs and processing time. Any additional time and charges incurred by the Division in providing a draft and correspondence with the applicant will be billed to the applicant. The Division will consider the request an official extension of the processing deadlines specified by the Act. The extension will consist of the number of days elapsed between Division mailing of the draft permit to the applicant and receipt of the applicant's comments by the Division, not to exceed 15 days. However, the Division is not bound to consider any comments received after the 15 day time period lapses, unless both the Division and the applicant agree to a further extension of the processing deadlines. 9. PERMIT PREVIOUSLY ISSUED TO: List the name of the company on the most recently issued permit. This section should be completed only if a company name change or transfer of ownership has occurred. 10. TRANSFER OF OWNERSHP: This section should be completed by the former owner of the permit. Transfer of the permits) conveys to the new owner all responsibility, coverage and liability associated with the permit(s). Submission of a transfer of ownership application without a request for permit modification implies that no change is contemplated which would constitute a new or modified air pollution source. A written agreement containing a specific date for transfer of ownership permit will be accepted in lieu of completion of this section of this form. Submit completed application, APENs, and Fling fee to the address below: APENS: More than one Air Pollutant Emission Notice (APEN) may be needed with this application. Only one application form needs to be completed. Multiple sources An APEN is required for each source unless they may be grouped as specified in Regulation No. 3, Part A, Section ll.B.4. Transfer of Ownership - An APEN must be submitted for each individual emission source to be transferred. Name Change - If a company is changing its name only, and all other procedures and information as stated in the last submitted APEN remains unchanged, then only one APEN for each facility is required. FEES: Filing Fee: Permittee must submit $152.90 per APEN with the application. Permit Processing Fee: Permittee will be invoiced at the rate of $59.98 per hour based on the amount of time spent reviewing the application and issuing the permit. Invoices for APE N fees and permit processing fees must be paid before permit will be issued. Once an application is received, all processing time will be charged regardless of whether a permit is issued or riot. If a project is cancelled, the division should be notified in writing immediately. Annual Fees: Annual fees will be billed for each source requiring an APEN to cover the costs of periodic inspections and administration. Annual fees are based on the quantity and type of pollutants emitted. For specific information related to fees see Regulation No. 3, Part A, Section VI. Mail completed application, APENs, and filing fee to: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, Colorado 80246-1530 http://www.cdphe.state_co.us/ap/stationarv.html Phone: (303) 692-3150 Revised August 2004 OXY USA WTP LP - Conn Creek Gas Treating Facility I (CCGTF I) Condensate Throughput 264 [bbl/day] Control Device E&P Tank Results Emission Summary Component Total HAPs Total HC VOCs, C2+ VOCs, C3+ Vapor HC Vapor GOR No Component 1 H2S 2 02 3 CO2 4 N2 5 Cl 6 C2 7 C3 8 i -C4 9 n -C4 10 i-05 11 n-05 12 C6 13 C7 14 C8 15 C9 18 C10+ 17 Benzene 18 Toluene 19 E -Benzene 20 Xylenes 21 n -C6 22 224Trimethylp Total VCU Uncontrolled Uncontrolled Controlled Controlled [ton/yr] [Ibfhr][tonfyr] (lb/hr] 18.8 4.292 0.38 0.09 1,071.0 244.53 21.42 4.89 776.6 177.30 15.53 3.55 121.35 10.63 2.43 531.5 77.43 [MSCFD] 74.31 [MSCFD] 293.3 [SCF/bbl] Uncontrolled Uncontrolled Controlled Controlled (ton/yr] [ibihr] [to nfyr] bin r] 0 0 0.00 0 0.00 64.265 1.159 294.487 245.044 187.846 73.023 81.285 44.486 38.620 65.718 14.536 5.459 1.354 0.395 2 789 3 315 0.083 0 995 11621 0 000 1,136.460 14.672 0.265 67.230 55.946 42.887 16.672 18.558 10.157 8.817 15.004 3.319 1.246 0.309 0.090 0.637 0.757 0.019 0.227 2.653 0.000 259.466 1.29 0.02 5.89 4.90 3.76 1.46 1.63 0.89 0.77 1.31 0.29 0.11 0.03 0.01 0.08 0.07 0.002 0.02 0.23 0 0.00 0.00 0.29 0.01 1.34 1.12 0.86 0.33 0.37 0.20 0.18 0.30 0.07 0.02 0.01 0.00 0.01 0.02 0.0004 0.005 0.05 0 No. Component MW LP Oil Flash Oil Sale Oil Flash Gas W&S Gas mol % mol % mol % moi % mol % 1 H2S 34.8 0 0 0 0 0 2 02 32 0 0 0 0 0 3 CO2 44.01 0.921 0.0668 0.0047 3.8421 6.0314 4 N2 28.01 0.026 0.0002 0 0.1144 0.0153 5 Cl 16.04 11.532 0.276 0.0004 50.0217 26.7609 6 C2 30.07 5.441 0.8314 0 4194 21.2034 40.4157 7 C3 44.1 4.002 1.8454 1.7312 11.3764 12.8166 8 l -C4 58.12 1.975 1.5687 1.5484 3.3644 3.5189 9 n -C4 58.12 2.88 2.6267 2.6136 3.7461 3.8886 10 i-05 72.15 2.923 3.2947 3.3113 1.652 1.7034 11 n-05 72.15 3.472 4.068 4.0949 1.4341 1.4799 12 C6 86.16 14.834 18.5592 18.7297 2.0959 2.1696 13 C7 100.2 9.436 12.0781 12.1995 0.4014 0.4178 14 C8 114.23 11.066 14.2637 14.4107 0.1317 0.138 15 C9 128.28 8.064 10.4137 10.5217 0.0294 0.0332 16 C10+ 154 10.622 13.7263 13.8691 0.0069 0.0073 17 Benzene 78.11 0.982 1.2412 1.2531 0.0956 0.0994 18 Toluene 92.13 3.989 5.1274 5.1797 0.0963 0.1008 19 E -Benzene 108.17 0.294 0.3794 0.3833 0.0021 0.0022 20 Xylenes 106 17 4.161 5.3705 5.4261 0.0251 0.0264 21 n -C6 86.18 3.38 4.2628 4.3033 0.3612 0.3745 22 224Trimethylp 114.24 0 0 0 0 0 MW 85.36 101.45 102.14 30.35 34.32 Stream Mole Ratio 1 0.7737 07658 0.2263 0.008 Heating Value [BTU/SCF] 1677.18 1838.1 Gas Gravity [Gas/Air] 1.05 1.18 Bubble Pt. @ 100F [psia] 423.29 22.74 11.29 RVP @ 100F [psia] 102.95 12.37 9.32 Spec. Gravity @ 100F 0.652 0.678 0.679 Total Emissions mal 1/0 0 0 3.9165 0.111 49.2303 21.8571 11.4254 3.3696 3.7509 1.6537 1.4356 2.0984 0.4019 0.1319 0.0295 0.0069 00958 0.0965 0.0021 0.0251 0.3617 0 30.48 0.2342 1682.65 1.05 Emission factor source Reportable Yes/No CO cl) y- COI )_ a Z o Z Yes 1 0 Z r No I a Z v Z o Z oN nN No No I v Z v Z ON oN De Minimis Level 7 v) N 0 Ll 2,500 2,500 Z500 Emissions tpy N- C) r C ) (C) LO CO 0 Nt 0 CD CJ N N 6 6 O v O r Controlled .0 0 (U(D N cO 00 f C)0) ,--szt- IUncontrolled Emissions > C7 N Z h. CO CO 0 D aj N M 6 r Is CO CD c0 r ice- N v/ Ni CO6a tiaz) d N Scenario Number NNNNN N N L. N N N N N N N N N N Ie < U U U 0 CAS Number 0 0 Q 1. POLLUTANTS CD C a+ N NC N @ .0C 1p 0 2 >' N X -_.s CO E-- W X I • C- TANKS 4.0.9d E E \2\o e z 0060 0 §§ \6 ✓ 2 - O .2 -_ k P. u _ R3 '« ° n @ ■ ..0 = �2 )/77\ % \ 7- 5 a 06 a - ¥- . .a) 4) 0) .�� fw §74 \ F\) 2.10.4) ®:�#e f £F 6m =.,eeV ',-,4,7, is . « ■Eo {gid\E/ (k\9`�rm 2222fa &\� �7® o�� 02:#»�\-» u22G° -c ,^..••• )§§ 73eeoEc ��o�<>-z. £ _� �In 2>EL 40w $ a. re & f1e://C:1Pragram riles\Tanks4O9d\summarydisplay.htm TANKS 4.0.9d Y � O I u. a w: y• EE W a co 'Ly ▪ 5w L YI C- W C G C} W 5 Y H 0 0 0 CX -� .O CO 01 O K 0 G ams i • r F H • 8 0. H ja ga= 72 _ mn C. 3�F 3b L9 Option 2i A=7.009, B=1462.265 C=215.11 O ▪ o V. CO n 6 4 0 0 D O o a o G 0 0 0 a© o 88888 R.8 A n s m m � s ID 0 en N O 0 6 A A O +A N 8 O o r tj p. (N N 0 0 m tom) a) 10 .4 N e+a n 6 R O m C a m • TANKS 4.0.9d n Cakaulalions } no - cc )\ \§§ §§§) 2SE ) 2 �In ,-/ . ( ,;ci N0.-00 § \ - Le %§ (/\(§§§§ct - }a ®am ,„_,_ zrzr E - % ? 2 7 t } . l kƒ\\ k ¥ TANKS 4.0.9d {ti E 8 75 LL Qi �+ 0) 'C W o s2 = 47 cu CeN C z -a U, .� 'E 'C3 W - Emissions Report for: Annual Total Emissions 4 J c ca m L h n Di yO N M N M r3) ca ea' Conn Creek Condensate a, n N N ci a) a) C a) CO Li) N aa)) o' H m .b 0 ci cD Ci m C a) e W co co N h t() IN - 0 ti LO CID ri rt) 771 w tri Unidentified Components • file://C:\Program Files\Tanks4O9d\summarydisplay.htrn TANKS 4.0.9d v LL CU a "S 0 r%1 0 09 (1) E LU Ol C t 006acry0p 0 O c 0 LO IC 0 Z ociniascc; oz d N r t- N CO -ch y N 0 Y C C6 07 CI I- r rl .° C -1 ° tf O N C CCc 11 7• 3 -an C x • ° • Q - - CQ a 00 - a E 87A y fl x 4 0 2 0 CO qo 0 0 E E N z co (.70 c� o S) c'7 00 0 4 o m C a 0 V1 N c -a .- 0) '0° � ,0 3 rnL g= V o c D 4.-, •m mi mS•- ° Vt-c .-000r} il 5 E E £=E -°I -m r-=aw is Baa w O �0 6� a ar k V t t a C U a° 'a> ae CO .< >- a 4 -2t! [+7o C0900 CCC ! ;>rk m I- 0. 0. 6 ion, Colorado (Avg Atmospheric Pressure = 12.37 psia) C C C Meterologics; Data used in Emissions Catculatio • 0 Cl eC • TANKS 4.0.9d TK -416 - Vertical Fixed Roof Tank Grand Junction, Colorado O L � ym } li e 7� LL a A as e 0 -tom 0. M �g Option 2t A=7.005. 6=1462.266, C=2155.11 V r hi� bhpp M m rN p n N W 8 0 A 8 h 2 88§828 in CD p0�pryry �ID h ] F 4 V C C 2C a Z O d a o d o 8888828 n �mNt!fM F G hll P� N V N_ 0el3 N C C CO © N 6 C 6 aCN- Ct�p FN- a N O 4] 6 6 — O0 6 S' 1 C 4 C C nh oa ao MixturefComponent o VI TANKS 4.0.9d N L 41 N 4 i Q . Wce GJ 0 a— y � E Ui TK -016 - Vertical Fixed Roof Tank Grand Junction, Colorado Annual Emission Calcaulalio LCt04000 NOVO C, NOW+- pW4C50 N N � 40 8 P—$288 N d O N N O o fvH 0444 (N LE 7;288 m N Ipso popp Ldmp tai Qi 6a 6gi e0 Cl t� T • 1�! R?T S aDfONbO ti «AGOG K1 [uW N ,- In o c4 4 0( 0 0 I.- N i. tri O f` W1 40 file:!/C:\Program FilestTanks409d1summarydisplay. I Vapor Space 0 °.288E § /2288( § `%`§" °° k uri A - file://C:1Program Files\Tanks409d\sumrnarydisplay.htm • TANKS 4.0.9d CO E 70- 8 — c 'cc o Q7 N c E t o o. co ct VI o �E c w — Emissions Report for: Annual TK -416 - Vertical Fixed Roof Tank Grand Junction, Colorado a N 0 O J Working Loss Breathing Loss Total Emissions Conn Creek Condensate 2,978.93 2,432.53 5,411.46 IL Benzene 15.20 12.41 27.61 Toluene 21.13 17.25 38.39 Ethylbenzene - — 0.60 0.49 1.09 Xylenes (mixed isomers) 7.07 5.77 12.84 170.12 1 5,161.42 N ti N 2.320.13 ino) K7 K7 QI N o CO N Components Hexane (-n) Unidentified Components file://C:\Program Files\Tanks4O9d\summarydisplay.htm • ae esi • cc c E 0. file://C:\Program Files\Tanks409d1summa TANKS 4.O.9d E § k ) $]$2 » z dA§A 3 E k $2 / o re ./ a / —k o—; § \ 7:k\ 0 .- § &/ .-. k 7i-/ - _/§\\\)§k£2000ec 57m7 {e„ ,,Enou«4wz_a� )CO 00 da 90 Meterological Data used in Emissions Calculations: Grand Junction, Colorado (Avg Atmospheric Pressure = 1237 psia) file:11C:1Program Files\Tanks4O9d\summarydisplay.htm • N ots TANKS 4.0.9d TK -417 - Vertical Fixed Roof Tank Grand Junction, Colorado a E r2" t� m U z L » J . LL s.� a Oplion 2. A=7.009, 8=1462.266, C=215.11 N. �p m N.Ip (N N. N. aO m O T 0 p'f {+ O Y fO ppm pN Q 8 8 d666666 00 0 N - SS Q = Qu 0 000000 0 0 = O O O 8 8 6 8 8 n 8 vi 1.4 CN A O o C> r ea ris EV cv S: 2 oD G+ d N vp v) w DR 8 co 30 `� ui o6 6 6 o da CO CO CO (N V-0029 E -. N LL A t. 7Lt r,,.. E 3 E c o E To a l o ( T3 t° ® V Cr. 01 L M eks Q H O 0 W E C m to E C S a m 2 c g a Q m C U k EU U p& ` 17 . _ '.7", , ty ; TANKS 4.0.9d c L'I — a '�s 4 • c I Q c a z ar Ce is tov c— a '� a Ch E TK -417 - Vertical Fixed Roof Tank Grand Junction, Colorado C +Wu - • g a C C S E .. g a 0 -Am cm- aE cmJa sa a to m�7d0 c 0 4 cmmoum 03]77 0 rq O+ K 0 N 9 Eli 1 It a m 9 d 4 E a. *E-Eci r.a'mu$ nate m -vw`w g rnT � et mn`m�-..o�aa vW yr � np � R � m � "S C � I.onat; iEm Wm`w c y. p, m S L N } m R W W O O{po7 .4❑{17o.L�jaaF7G'r '866RNa sada 4��4} x777 A3 3 Ji -H al tin co 6aiNo MEE N '0 r r O r file://C:IProgram Files\Tanks4O9d1summarydisplay.htm • n dpi F6NI � YY N N S � SO v. I-O0ON CG �G O N Q of tri `n A gr- C:1Program Files\Tanks4O9d\summarydisplay.htm • TANKS 4.O.9d E 0 o ▪ 1 - co 0 CD .71 c E t 0. = m ea Et 1— Q • .� y Emissions Report for: Annual TK -417 - Vertical Fixed Roof Tank Grand Junction, Colorado Losses(lbs) Components Working Loss Breathing Loss Total Emissions Benzene 15.20 12.41 27.61 Toluene 21.13 17.25 38.39' Ethylbenzene 0.60 0.49 1.09 Xylenes (mixed isomers) 7.07 5.77 12.84 incm 1-- (0. a) F a) w alx x 0 I Unidentified Components 2,841.29 2,320.13 5,161A21 Conn Creek Condensate 2,978.93 2,432.53 5,411.46 file://C:\Program Files\Tanks409d\summarydispia� • en C file:/IC:\Program Files\Tanks409d1summarydisplay lhtm • • • ESP TANK V2.0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2008.09.17 ******************************************************************* *********************** * Project Setup Information ****************************************************************************************** Project File W:\OXY USA\Conn Creek\Permits 6 APENs1CCGTF I Tanks\CCGTF I Separator Feed Tank.ept Flowsheet Selection : Oil Tank with Separator Calculation Method : RVP Distillation Control Efficiency : 100.0% Known Separator Stream : Low Pressure Oil Entering Air Composition : No Filed Name : Cascade Creek Well Name : CCGTF I Well ID : Condensate (from inlet slug catcher) Permit Number : 06GA1232 - Separator Feed Tank T-5235 Date : 2008.09.17 ****************************************************************************************** * Data Input ****************************************************************************************** Separator Pressure Separator Temperature Ambient Pressure Ambient Temperature C10+ SG C10+ MW 300.00[psig] : 95.00(F] 12.73(psia] : 60.00(F] 0.7400 : 154.00 Low Pressure Oil No. Component mol % 1 R2S 0.0000 2 02 0.0000 3 CO2 0.9210 4 N2 0.0260 5 Cl 11.5320 6 C2 5.4410 7 C3 4.0020 8 i -C4 1.9750 9 n -C4 2.8800 10 i-05 2.9230 11 n-05 3.4720 12 C6 14.8340 13 C7 9.4360 14 C8 11.0660 15 C9 8.0640 16 C10+ 10.6220 17 Benzene 0.9820 18 Toluene 3.9890 19 E -Benzene 0.2940 20 Xylenes 4.1610 21 n -C6 3.3800 22 224Trimethylp 0.0000 -- Sales Oil Production Rate : 264[bbl/day] Days of Annual Operation : 365 [days/year] API Gravity : 54.0 Reid Vapor Pressure : 9.00[psia] ****************************************************************************************** * Calculation Results * ****************************************************************************************** -- Emission Summary Item Uncontrolled Uncontrolled page 1 • • • E&P TANK V2.0 Calculation Report--- Developed by DB Robinson & Associates Ltd. 2008.09.17 Total HAPS Total HC VOCs, C2+ VOCs, C3+ [ton/yr] [Th/hr] 18.800 4.292 1071.032 244.528 776.565 177.298 531.521 121.352 Uncontrolled Recovery Info. Vapor 77.4300 [MSCFD] HC Vapor 74.3100 [MSCFD] GOR 293.30 [SCF/bbl] Emission Composition No Component Uncontrolled Uncontrolled [ton/yr] (Ib/hr] 1 H28 0.000 0.000 2 02 0.000 0.000 3 CO2 64.265 14.672 4 N2 1.159 0.265 5 Cl 294.467 67.230 6 C2 245..044 55.946 7 C3 187.846 42.887 8 i -C4 73.023 16.672 9 n -C4 81.285 18.558 10 i-05 44.486 10.157 11 n-05 38.620 8.817 12 C6 65.718 15.004 13 C7 14.536 3.319 14 C8 5.459 1.246 15 C9 1.354 0.309 16 C10+ 0.395 0.090 17 Benzene 2.789 0.637 18 Toluene 3.315 0.757 19 E -Benzene 0.083 0.019 20 Xylenes 0.995 0.227 21 n -C6 11.621 2.653 22 224Trimethylp 0.000 0.000 Total 1136.460 259.466 -- Stream Data. No. Component 1 H2S 2 02 3 CO2 4 N2 5 Cl 6 C2 7 C3 8 i -C4 9 n -C4 10 i-05 11 n-05 12 C6 13 C7 14 CB 15 C9 16 C10+ 17 Benzene 18 Toluene 19 E -Benzene 20 Xylenes 21 n -C6 22 224Trimethylp MW LP Oil Flash Oil Sale Oil Flash Gas W&S Gas Total Emissions mol % mol % mol % mol % mol % mol % 34.80 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 32.00 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 44.01 0.9210 0.0668 0.0047 3.8421 6.0314 3.9165 28.01 0.0260 0.0002 0.0000 0.1144 0.0153 0.1110 16.04 11.5320 0.2760 0.0004 50.0217 26.7609 49.2303 30.07 5.4410 0.8314 0.4194 21.2034 40.4157 21.8571 44.10 4.0020 1.8454 1.7312 11.3764 12.8166 11.4254 58.12 1.9750 1.5687 1.5484 3.3644 3.5189 3.3696 58.12 2.8800 2.6267 2.6136 3.7461 3.6886 3.7509 72.15 2.9230 3.2947 3.3113 1.6520 1.7034 1.6537 72.15 3.4720 4.0680 4.0949 1.4341 1.4799 1.4356 86.16 14.8340 18.5592 18.7297 2.0959 2.1696 2.0984 100.20 9.4360 12.0781 12.1995 0.4014 0.4178 0.4019 114.23 11.0660 14.2637 14.4107 0.1317 0.1380 0.1319 128.28 8.0640 10,4137 10.5217 0.0294 0.0332 0.0295 154.00 10.6220 13.7263 13.8691 0.0069 0.0073 0.0069 78.11 0.9820 1.2412 1.2531 0.0956 0.0994 0.0958 92.13 3.9890 5.1274 5.1797 0.0963 0.1008 0.0965 106.17 0.2940 0.3794 0.3833 0.0021 0.0022 0.0021 106.17 4.1610 5.3705 5.4261 0.0251 0.0264 0.0251 86.18 3.3800 4.2628 4.3033 0.3612 0.3745 0.3617 114.24 0.0000 0.0000 0.0000 0.0000 0.0000 0.0000 MW 85.36 101.45 102.14 30.35 34.32 30.48 Stream Mole Ratio 1.0000 0.7737 0.7658 0,2263 0.0080 0.2342 Heating Value [BTU/SCF] 1677.18 1838.10 1682.65 Gas Gravity [Gas/Air] 1.05 1.18 1.05 page 2 BSI. TANK V2.0 Calculation Report--- Developed by DB Robinson 6 Associates Ltd. 2008.09.17 Bubble Ft. @ 100F [psis] RVF @ 100F [psis] Spec. Gravity @ 100F 423.29 102.95 0.652 22.74 12.37 0.678 page 3 11.29 9.32 0.679 • • • CALCULATIONS AND COMPUTATIONS Project: OXY USA VVTP LP - Conn Creek Gas Treating Facility I (CCGTF I) Subject: Vapor Combustion Unit Emission Calculations Emission Source: Condensate Tanks Control , Source Type: VCU Heat Input: 8.00 MMBtulhr Flowrate: 4,000.0 scf/hr Flowrate: 35.0 MMscflyr Estimated HHV: 2,000 Btulscf Molecular Weight of Condensate Vapors: 34.3 lb/mole Total VOC Destruction Efficiency: 98.0 % Sulfur Content of Fuel: 0.05 gr/scf Operating Hours per Year: 8,760 hr/yr Pollutant Emission Factors (a) One Heater Short-term Annual Iblhr thl° (c) glsec tpy (d) gfsec NO,, 100.Olb/MMscf _ 0.40 0.0504 1.75 0.0504 CO 84.0 lb/MMscf 0.34 0.0423 1.47 0.0423 SO2 0.0071b/MMBtu 0.057 0.0072 - 0.25 0.0072 PM10 7.6 lb/MMscf 0.03 0.0038 0.13 I 0.0038 Notes: (a) Emission factors are from AP -42 Tables 1.4-1 & 2 (small boilers) except Sc) Emission factor for SO2 (1b/MMBtu) based assumed sulfur content of natural gas (b) Hourly Emission Rate 013/hr) = (Emission Factor, Ib/MMscf) " (Flowrate, scflhr) " (MM 1 1,000,000) (c) Hourly Emission Rate (Ib/hr) = (Emission Factor, Ib/MMBtuf)' (Heat Input, MMBtulhr) (d) Annual Emission Rate (tpy) _ (Hourly Emission Rate, lblhr)' (hr/yr) / (2,000 lb/ton) VOC Emissions from Truck Loading [AP -42 Chapter 5.2 (1/95)] r 2§/ / g o Lu CD 2 A ) 2 i7) 0 § -42 Table 5,2-1 {1 § AP -42 Chapter 5.2, Table 5.2-1 (1/95) { § CCGTFI Separator Feed Tank Emissions 09-17-2008.xls k § k 0 I w Reportable lYes/No CD 2 k 2 No ! k oN oN oN ON ON k. No No No 2 k 2 I De Minimis Level 0 § L & 2,500 2,500 2,500 I Controlled Emissions \ 3 / / 0 . 3, % m 0 0 0 0 0 » G ? g p G §/dk\k Uncontrolled Emissions g 2 / 7 g CO Q$ g 0 6 6 6 6 0 % \ \ G / G 0 83 0 \ 0 CO/ ¥ w Scenario Number CNICNCNCNCN• NOINNNNCINNNNN < 0 0 0 0 CAS Number w Cr) / / / \ POLLUTANTS N ( r k @ E @ § % S ) 2 \ w x ƒ | Form APCD-304 Colorado Department of Public Health and Environment Air Pollution Control Division Operating and Maintenance Plan Template for Condensate and Mixed Liquid Storage Tanks Ver. September 10, 2008 The Mr Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for condensate and mixed liquid storage tanks permitted at synthetic minor facilities in the State of Colorado. An O&M Plan shall be submitted with the permit application. One O&M Plan may be used for multiple tanks at one facility if each are controlled and monitored in the same manner. If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the facility to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However, the Division encourages the use of this template to expedite the permit application approval process. Colorado Depa anent of Public I lealth and Environment Submittal Date: September 21, 2008 Section 1 - Source Identification For new permits some of this information (i.e. Facility AIRS ID, Facility Equipment ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill out those fields that are known and leave the others blank. Company Name: Facility Name: OXY USA WTP LP Conn Creek Gas Treating Facility Facility Location: S32 T6S R97W, Garfield County Facility AIRS ID (for existing facilities) 045/0831 Units Covered b Facility Equipment ID TK -5235 3 -Phase Separator V -5240 Heater Treater V- 5245 TK -415/416 TK -417 Permit Number new new new 06GA1232 new AIRS Point ID _ 045/083/012 Tank Type a 11L ML ML C C Controlled (YIN) Y Y S' }' Y Tank types include condensate (C) and mixed liquid (ML) Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control 0 devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices. These schedules and practices, as well as any maintenance records showing compliance with these recommendations, shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Page 1 of 4 O&MFarrnAPCD-304,doc Colorado Department of Public Health and Environment Air Pollution Control Division Section 3 - Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The source will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division, as reflected in the construction permit. Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4 — General Monitoring Requirements All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. Table I below details the schedule on which the source must monitor each of the listed operating parameters depending on the requested permitted emissions at the facility. Check the appropriate box based on the facility wide permitted VOC emissions. Table 1 Parameter Monitorin Fre uency a Permitted Facility LI Permitted Facility Emissions < 80 t VOC Emissions 80 t+ VOC Condensate Throughput Monthly Monthly Separator Temperature (if present) Weekly Monthly Separator Pressure (if present) Weekly Monthly Table 2 outlines condensate and mixed liquid throughput monitoring methods. The source must chose one primary monitoring method and, optionally, may chose up to two backup methods. Check each box that applies. Table 2 Primary Back-up Condensate or Mixed Liquid Throughput Monitoring Method I I Inlet meter(s) • LJ Tank level measurements which take into account all additions and loadout activity 1{ ❑ Sales or haul tickets Other (to be approved by the division): attach method explanation and sample calculations ❑ Section 5 - Emission Control or Recycling Equipment Monitoring Requirements If a control device is used then leakage of VOCs to the atmosphere must be minimized as follows: • Thief hatch seals shall be inspected for integrity annually and replaced as necessary; • Thief hatch covers shall be weighted and properly seated; • Pressure relief valves (PRV) shall be inspected annually for proper operation and replaced as necessary; • PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses (as applicable) are routed to the control device under normal operating conditions; • Annual inspections shall be documented with an indication of status, a description of any problems found, and their resolution. Page 2 of 4 O&MFormAPCD-304.doe Colorado Department of Public Health and Environment Air Pollution Control Division Table 3 below details the monitoring frequency for control equipment depending on the type of control equipment used and the requested permitted emissions at the facility. Check the appropriate box for "Monitoring Frequency" based on the facility -wide permitted VOC emissions. In addition, indicate storage tank emissions controls by checking the appropriate boxes. Table 3 Emissions Control Or Recycling Method Parameter Monitoring Frequency 12 Permitted Facility Emissions > SO tpy VOC ■ Permitted Facility Emissions < SO tjy VOC Thermal Oxidizer ❑ Combustion Chamber Temperature b Daily Weekly Combustor or Flare Pilot Light Monitoring" Daily Weekly ❑ Miir Method 22 Readings Daily Weekly Recycled or Closed Loop System (Including Vapor Recovery Units) ❑ To be determined by the source and approved by the division d Re-routed to Reboiler Burner ❑ To be determined by the source and approved by the division b Minimum Thermal Oxidizer Combustion Chamber Temperature If the facility uses a thermal oxidizer to control emissions then the minimum combustion chamber temperature shall be: Select one of the following options from Table 4: Table 4 Primary 1400°F II 0 F Based on manufacturer specifications. Specifications must be submitted with the permit application and made available to the Division upon request ❑ Based on testing performed. The test data shall be submitted and attached to the O&M Plan " Pilot Light Monitoring Options If the facility uses a Combustor or Flare then the source must indicate the method by which the presence of a pilot light will be monitored in Table 5. One primary method for Pilot Light Monitoring must be checked and, optionally, up to two backup methods may be checked, Table 5 Primary Back-up Monitoring Method �� ❑ Visual Inspection ❑ Optical Sensor ❑ _❑ Auto -Igniter Signal Thermocouple ❑ Miir d Recycled or Closed Loop System Monitoring Plan In the space provided below please provide a brief description of the emission control or recycling system, including an explanation of how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Page 3 of 4 0&MFomiAPCD-304.doc Colorado Department of Public Health and Environment Air Pollution Control Division Reboiler Burner Control Monitoring Plan In the space provided below please provide a brief description of the emission control system, including an explanation of how the system design ensures that emissions are being held or rerouted when the reboiler is not firing. Section 6 — Recordkeeping Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2, 3, 4 and 5 for a period of 2 years. If an applicable Federal NSPS, NESHAP or MACT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. Note: These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities. If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the source shall follow the most stringent regulatory requirement. Page 4 of 4 O&MFormAPCP304.doc DXY 14111./ Project: OXY Conn Creek II Compressor Station Submittal Item Number: 11.1.8.2 Dust Control All excavation work shall be conducted in a manner that preserves soil and allows for the segregation of soil types in order to facilitate land reclamation in the future. Measures shall be taken to prevent excessive soil erosion by wind or water including the Best Management Practices as detailed in the Storm water Management Plan for the site. All excavated surfaces shall be maintained with adequate moisture to reduce wind erosion. During operation of the facility, care will be taken to review site conditions daily. Wet conditions will require maintenance of surfaces to keep mud from tracking onto County Road 213. Dry conditions will require maintenance of surfaces, either through application of water or a dust suppressant. These measures are noted within the Storm water Management Plan in tab 11.1.A. Page 1 of 1 DXY Project: OXY Conn Creek II Compressor Station Submittal Item. Number: 11.1.8.4 Noise Abatement Please find attached the following documents: A. Computer Noise Modeling dated 9/12/08 prepared by Hankard Environmental, Inc. B. COGCC regulation 802- Noise Abatement This noise analysis indicates that the existing compressors and the proposed two compressors will comply with the Colorado Oil and Gas Conservation Commission regulation 802 regarding noise abatement. OXY USA WTP LP will comply with all of the recommendations presented by the Hankard Environmental, Inc. report. Page 1 of 1 HANKARD ENVIRONMENTAL ACOII9TICi +'1) V!1ART,ON CORS_ 7. September 12, 2008 Phil Vaughan Phil Vaughan Construction Management, Inc. Construction Manager 1038 County Road 323 Rifle, CO 81650 Re: Anal sis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station Dear Mr. Vaughan, This letter described the results of Hankard Environmental's analysis of noise from Oxy's Conn Creek Compressor Station Expansion Project, which is located in Garfield County, Colorado. Noise levels from the existing Conn Creek Compressor Station were measured, and this data was used to predict the noise levels that will exist when the expanded station is operational. The noise Ievels predicted from the combined operation of the existing and expanded facilities are below the limits promulgated in applicable Garfield County and State of Colorado regulations. The following describes the project site, applicable noise regulations, the results of our noise level measurements, and the noise levels we predict from the combined operation of the existing and proposed compressor stations. PROJECT AND SITE DESCRIPTION The proposed Conn Creek Compressor Station Expansion Project is located in Garfield County, approximately 11 miles north of De Beque, Colorado. The existing and expansion compressor station sites are located in a deep valley off of Conn Creek Road, as shown in Figure 1. The land to the north of the site is owned by Oxy USA Inc., out to a distance of approximately five miles. Two -thousand foot high ridges are located to the east and west. The land over the eastern ridge is owned by the Puckett Land Company, and is currently being explored for gas development potential. The land over the western ride is owned by the Shell Frontier Oil and Gas Company, and is also being explored for gas development potential. The Iand to the south of the site is owned by the Bureau of Land Management and the Savage Limited Partnership. A three-dimensional map of the site is show in Figure 2. The primary noise generating components of the existing station include the Generator Building and the Compressor Building. The Generator Building contains three Caterpillar 3512 Generator Sets with exterior cooling towers. Only two of these engines run at any one time per on site management. The existing Compressor Building houses five Caterpillar 3516 units with exterior cooling towers. The primary noise source at the expansion compressor station will be a Compressor Building that will house two Caterpillar 3616 units with exterior cooling units. COLORADO • WfSCONSIN • MAINE phone: (303) 666-0617 • www,hankardinc.com • fax (303) 600-0282 jjHANKARD JJ ENVIRONMENTAL Az^usl £s Al: V:iix'-pN Co4$4,itM6 FIGURE 1: SITE LOCATOR MAP Analysis of Noise from Proposed Expansion of Oxy's Cann Creek Compressor Station September 12, 2008 page HANKARD ENVIRONMENTAL - — Ac,ZUST Cf NY] V1112... (.{ FIGURE 2: THREE•DINIENSIQNAL MAP OF SITE APPLICABLE REGULATIONS Section 5.03.08(1) of the Garfield County Zoning and Subdivision Regulations (Industrial Performance Standards for Conditional and Special Uses) states that the "Volume of sound generated shall comply with the standards set forth in the Colorado Revised Statutes at the time any new application is made. (A. 93-061)". This refers to the Colorado Revised Statutes (C.R. S.) §25-12-101 et seq. noise regulation. A second noise regulation that is applicable to this project is the Colorado Oil and Gas Conservation Commission's (COGCC) Rule 802 (updated November 2006). The noise limits contained in these two regulations are identical, and their maximum permissible noise levels are shown in Table 1. The noise limits shown in Table 1 vary depending on time of day and surrounding land use. The permit being applied for will allow 24 hour per day operation, thus the maximum noise level will be defined by the nighttime (quietest) limit for each Iand use zone. COGCC Rule 802 states that "In remote locations, where there is no reasonably proximate occupied structure or designated outside activity area, the light industrial standard may be applicable". There are no occupied structures (residences) located within at least two miles of the proposed project. In terms of Iand use, almost all of the land surrounding the site is being developed for gas Analysis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station page 3 September 12, 2008 IFIENVIRONMENTAL AzouS, CS Ay: VII.,-Pop CONi0.lpI.i extraction. There is some BLM land to the south, but there are no designated outdoor activity areas associated with that property. Given all of this, we feel that the nighttime "light industrial" limit of 65 dBA is the defining limit for this project. TABLE 1 STATE OF COLORADO MAXIMUM PERMISSIBLE NOISE LEVELS - dBA Zane Daytime {1). P) Nighttime (2y (7:00am to 7:00pm) (7:00pm to 7:00am) Residential 55 50 Commercial 60 55 Light Industrial 70 65 Industrial 80 75 (I) During the daytime, the noise level can be increased by 10 dBA for 15 minutes in any one-hour period Ili Noise level limit decreased by 5 dBA for impulsive type sounds. NOISE MEASUREMENTS Noise levels from the existing operations (compressor station and generators) were measured on August 26, 2008 at the eleven locations around the site shown in Figure 3. A Larson Davis Model 824 Sound Level Meter (ANSI Type 1) was used for all measurements. The meter was calibrated within the past year by the manufacturer, and field calibrations were also conducted. All of the noise level measurements were taken with the microphone mounted five feet above the ground on a tripod, and with the microphone fitted with a windscreen. The equivalent sound level (Leq) for each location was measured for one to five minutes and paused when vehicular or other non -facility noise was present. The measured noise levels are shown in Figure 3 (Leq, dBA). The Ievels range from 58 to 73 dBA. During the noise level measurements the existing compressor station was operating at 90% of capacity (typical), two of the three generator engines were running (standard procedure), and all garage doors and doorways were completely open (worst-case). The winds were blowing between 3 to 10 miles per hour from the south. All of the noise measurements were taken downwind or cross -wind from the site. Overall, these measurements represent "worst-case" (loudest) conditions. The measured noise Ievels, which include one-third octave band sound levels, were used to calculate the sound power level for the existing generator building, existing compressor station building, and future compressor station building (discussed below). Analysis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station page 4 September 12, 2008 • HANKARD FN VIRONMENTAL h'10 Vu{ZA-!OH COM3clfl♦G o Measurement Location Property Line FIGURE 3: MEASUREMENT LOCATIONS Analysis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station September 12, 2008 page 5 HNINENTAL Ar OUSI,CS /.M: vii ht DW Cortise 1r14s NOISE ANALYSIS RESULTS Noise levels from the combined operation of the existing and expansion compressor stations at Conn Creek were predicted using an acoustical computer model (SoundPlan v6.5). SoundPlan is an internationally recognized sound propagation software model which utilizes 150-9613 outdoor sound propagation algorithms. Parameters input into this model included terrain type, terrain elevation, the locations of buildings that act as barriers, and the sound power level of the major compressor station noise sources (existing generator building, existing compressor station building, and proposed compressor station building). The terrain information was derived from 15 meter elevation contours. The locations of buildings were approximated from a combination of digital aerial mapping and design drawings of the proposed compressor station. The sound power levels for the existing generator building and existing compressor station building were calculated from the measurements conducted for this project (described above). This same sound power level was assumed for the proposed compressor station, as the number and type of equipment is identical. First, a noise model of the existing compressor station was generated and used to predict noise levels at the measurement locations. The model was validated by comparing measured and predicted results. The measured and predicted noise levels agreed within approximately ±3 dBA for locations within 500 feet of the existing station. This is within the expected accuracy of the model. Next, the proposed compressor station was added to the noise model and the model was used to predict how noise will propagate from the compressor station toward adjacent properties. Figure 4 shows the results of this analysis in the form of noise level contours overlaid onto an aerial photograph of the project site. From the figure it can be seen that 65 dBA (project limit) is not exceeded outside of Oxy USA's property. Note that these noise level predictions assume that all of the doors in the generator building and both compressor buildings are completely open. Thus, lower levels would be expected with all or some doors closed. In summary, noise levels from the combined operation of the existing Conn Creek Compressor Station and the Conn Creek Compressor Station Expansion Project are predicted to be Iower than the 65 dBA limit specified by the State of Colorado when measured at any point along the project's property boundary. Analysis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station page 6 September 12, 2008 s's HANKARD ENVIRONMENTAL _ AOUST CI 0,1n VIIPA •.DPi COMItLItNa o 250 500 Feet Noise Level Contour Property Line FIGURE 4: NOISE LEVEL CONTOURS Analysis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station page 7 September 12, 2008 HANK/till) ENVIRONMENTAL _ A t..s, C AND Vi12*.,no. Co,r1L:lisG Please call if you have any questions or we may be of any further assistance. Sincerely, Jeff M. Cerjan Senior Engineer Analysis of Noise from Proposed Expansion of Oxy's Conn Creek Compressor Station page 8 September 12, 2008 �XII" 11116.001 Project: OXY Conn Creek II Compressor Station Submittal Item Number: 11.1.B.5 Glare Abatement Paint Colors: Exposed piping and equipment will be painted as per COGCC Rule #804 and "Desert Tan" in color. Visual Impact Mitigation which states "Production Facilities constructed or substantially repainted after May 30, 1992 which are observable from any public highway shall be painted with uniform, non -contrasting, non -reflective color tones, (similar to Munsell Soil Color Coding System) and with colors matched to but slightly darker than the surrounding landscape." Page 1 of I • (2) Sound level meters shall be equipped with wind screens, and readings taken when the wind velocity at the time and place of measurement is not more than five (5) miles per hour. (3) Sound level measurements shall be taken four (4) feet above ground level. (4) Sound levels shall be determined by averaging minute -by -minute measurements made over a minimum fifteen (15) minute sample duration if practicable. The sample shall be taken under conditions that are representative of the noise experienced by the complainant (e.g., at night, morning, evening, or during special weather conditions). (5) In all sound level measurements, the existing ambient noise level from all other sources in the encompassing environment at the time and place of such sound level measurement shall be considered to determine the contribution to the sound level by the oil and gas operation(s). d. In situations where the complaint or Commission onsite inspection indicates that low frequency noise is a component of the problem, the Commission shall obtain a sound level measurement twenty-five (25) feet from the exterior wall of the residence or occupied structure nearest to the noise source, using a noise meter calibrated to the db(C) scale. If this reading exceeds 65 db(C), the Commission shall require the operator to obtain a low frequency noise impact analysis by a qualified sound expert, including identification of any reasonable control measures available to mitigate such low frequency noise impact. Such study shall be provided to the Commission for consideration and possible action. e. Exhaust from all engines, motors, coolers and other mechanized equipment shall be vented in a direction away from all occupied buildings. f. All facilities within four hundred (400) feet of occupied buildings with engines or motors which are not electrically operated shall be equipped with quiet design mufflers or equivalent. All mufflers shall be properly installed and maintained in proper working order. 803, LIGHTING To the extent practicable, site lighting shall be directed downward and internally so as to avoid glare on public roads and occupied buildings within seven hundred (700) feet. 804. VISUAL IMPACT MITIGATION Production facilities constructed or substantially repainted after May 30, 1992 which are observable from any public highway shall be painted with uniform, non -contrasting, non -reflective color tones, (similar to the Munsell Soil Color Coding System) and with colors matched to but slightly darker than the surrounding landscape. 800-2 as of November 30, 2006 DXY Project: OXY Conn Creek II Compressor Station Submittal Item Number: 11.1.8.6 Vibration Abatement Vibrations produced by rotating equipment such as the produced gas compressors will be minimized through concrete foundation design and geotechnical reports. Minimization of vibration is also important to prolong equipment life and is a goal of foundation design. The geotechnical investigation has been completed by Kumar and Associates, Inc. The foundation design has been conducted by Kumar and Associates, Inc. We feel that the expertise of this company in design will ensure the minimization of vibrations. The installation will meet the requirements set forth in code by Garfield County that require ground vibration to not be perceptible, without instruments, at the boundary line of the property. Page 1 of 1 Kumar & Am:dales, int. S20.Fctei.al rd Wends Eu; ipeLs cit EraigYikraSCir:; 1q3 Prepared By: Wade Gilbert, P.E. ACEC 3gt1 5au:n Limn St;aa: Dnrr+_s, CO $4223 phone: (343) 74-2-9704 fez: (303)742-5665 e -snail: lade re.'orglcum a.ros«-com wv,•,.v. uioanisa.wro CrhrrCtr,See l a(:=`tuns. Cels ado and 'Gvu tes ParktFraRer, Colorado GEOTECHNICAL ENGINEERING STUDY PROPOSED EXPANSION OF EXISTING COMPRESSOR FACILITY OCCIDENTAL OIL & GAS'S CONN CREEK FACILITY COUNTY ROAD 213 NORTH OF DEBEQUE GARFIELD COUNTY, OLORAO Reviewed By; r-- Alan F. CIaybourn, P.E. Prep red Fon Nolte Engineering, Inc. 8000 South Chester Street, Suite 200 Centennial, Colorado 30112 Attention: Rick Rome, P.E. Project No. 00-1-577A March 17, 2008 TABLE OF CONTENTS SUMMARY PURPOSE AND SCOPE OF WORK PROPOSED CONSTRUCTION .................. •414 ...... 2 SITE CONDITIONS 3 SUBSURFACE CONDITIONS ........ 3 l_ABORATORY TESTING ... SITE DEVELOPMENT CONSIDERATIONS 5 FOUNDATION RECOMMENDATIONS 6 SEISMICITY 11 FLOOR SLABS . 11 WATER SOLUBLE SULFATES 12 BURIED METAL CORROSION 12 s IjR FACE DRAINAGE 13 EXCAVATION AND GRADING 14 DESIGN AND CONSTRUCTION SUPPORT SERVICES .. . .... 16 LIMITATIONS 17 FIG. 1 - LOCATIONS OF EXPLORATORY BORINGS FIG. 2- LOGS OF EXPLORATORY BORINGS FIG. 3 - LEGEND AND NOTES FIGS. 4 throuch 7 - SWELL -CONSOLIDATION TEST RESULTS FIG. 8 — LABORATORY RESISTIVITY RESULTS FIG. 9 - MOISTURE -DENSITY RELATIONSHIP TABLE I - SUMMARY OF LABORATORY TEST RESULTS Kumar Is ASSOUlateS, Inc. SUMMARY ;. Subsurface conditions encountered in the borings generally consisted of relatively dense silty to clayey sands containing varying amounts of gravel and zones of clayey sand, silty to clayey gravel with sand, and lean clay with varying amounts of sand. Ground water was not encountered in the borings during drilling or when measured one day after drilling. Seasonal ground water due to changes in creek flows and up -gradient infiltration should be anticipated. 3 In general, the planned buildings and equipment can be supported on shallow spread foundations or mats, provided the foundations or mats are underlain by properly prepared, non -moisture -sensitive natural soils or compacted structural fill extending to suitable natural soils, Shallow foundations should have a minirru.srn dimension of 13 inches for continuous footings and 2 feet for isolated pad footings. Shallow spread foundations and mats should be designed for an allowable bearing pressure of 2,500 psi. To limit potential excessive differential settlements due to variable soil conditions, we recommend supporting the compressors or other settlement sensitive facilities on mats, which would distribuin the equipment load over a broad area and result in relatively low foundation contact pressures- Allowable bearing pressures may be increased by 1f3 for transient load conditi❑ns. 3. Floor slabs should be supported on properly prepared, non -moisture -Sensitive natural soils or compacted structural fill extending to suitable natural soils. 4. Potentially collapsible soils may be present at the site. Proper surface drainage will be very important for acceptable performance of site structures and facilities. Site finished grades should be designed and constructed to promote drainage and reduce ponding of water, and site development plans should include control of up -gradient storm water runoff and site drainage in order is limit site and embankment erosion and ponding of water adjacent to structures. 5. The existing natural soils should be suitable for use as site grading fill and structural fill beneath foundations and floor slabs The geotechnical engine& should evaluate the suitability o: proposed Fill materials prior to placement, Kumar & Assaciales, Inc. • • 2 - PURPOSE AND SCOPE OF WORK This report presents the results of a geotechnical engineering study for the proposed expansion of the existing aas compressor facility at Occidental Oil & Gas's Conn Creek facilities westGaside County, Colorado. The project site is located about 13 miles north of DeBeque on th of the extension of County Road 213 as shown on Fig- 1. The study was conducted for the purpose of obtaining data and developing geotechnical recommendations for the design and construction of the proposed expansion. The study was conducted in general accordance with the scope of work presented in an addendum to our Proposal No. P-08-132 to Nolte Associates, Inc. dated January 21, 2008 A field exploration program consisting of exploratory borings was conducted to obtain information on subsurface conditions. Samples of the soils obtained during the field exploration program were tested in the laboratory to determine their classification and engineering characteristics. The results of the field exploration and laboratory testing programs were analyzed to develop geotechnical recommendations for use in design and construction of the proposed gas nandlirig facilities. The results of the field exploration and laboratory testing are presented herein. This report has been prepared to summarize the data obtained during this study and to present our conclusions and recommendations based on the proposed Construction and the subsurface conditions encountered. Design parameters and a discussion of geotechnical engineering considerations reated to construction of the proposed facility are included in the report. PROPOSED CONSTRUCTION We understand the existing Conn Creeks compressor facility will be expanded to the north and be generally similar in size to the existing facility. Based on information provided by ForeRunner Corporation, the expansion area willhave overall dimensions of between 200 and 225 feet in the east -west direction and between 400 and 450 feet in the north -south direction. The layout of the expansion was not established at the time of our study. Based on our knowledge of the existing facility and our experience with similar compressor faciltities, we assume the expansion will include a compressor building with room for four or more Kumar & Associates. inc.. • -3- compressors, miscellaneous process and auxiliary buildings, various vertical and horizontal process and storage vessels and tanks, other miscellaneous equipment and facilities, and various pipelines. We assume that building column loads will range from about 50 to 120 Kips, and that r-;quipment weights will range from about 200 to 400 kips for the reciprocating compressors and from about 200 to 400 kips for various storage. and processing vessels. We assume site development will include improvement of existing access roads and construction of aggregate -surfaced yard areas Although planned site grades were not provided, we anticipate construction cuts and fills for the project site will vaiy from minor to significant if overall facility grades are to be relatively level, Improvement of the site access road may require moderate to possibly extensive cuts within the western portion of the site and moderate to extensive embankment fills within the eastern portion of the site. If the proposed construction varies significantly from that described above Or depicted in this report, we should be notified to reevaluate the recommendations presented in this report. SITE CONDITIONS The site is immediately north of the existing facility, which is located west of County Road 213 on the west side of Conn Creek. The site is currently undeveloped, generally undisturbed land covered primarily with sparse grasses and weeds and moderately -thick low brush. The site is situated on the west side of a relatively narrow valley floor between Conn Creek to the east and Graded facilities to the west and south associated with existing gas facilities, including the existing compressor facility. Topographically, the site has a moderate overall downward slope to the south-southeast, with an overall grade change estimated to range from about 20 to 30 feet based on USGS topographic data. With the exception of the banks of Conn Creek, there are no apparent sharp oracle changes across r.e adjacent to the site. SUBSURFACE CONDITIONS The subsurface conditions were explored by drilling six widely -spaced exploratory borings to depths ranging from 40 to 45 feet below ground surface_ The boring locations were determined and staked by ForeRunner Corporation, and the approximate locations are shown on Fig. 1, r41i71.., Komar & Associates, Inc. • -4- T ha logs of the exploratory borings are presented on Fig. 2, along with a legend and associated explanatory notes on Fig. 3, The borings generally encountered natural silty to clayey sands containing occasional to frequent travel, and zones of silty to clayey gravel with sand and lean clay containing varying amounts of sand. The soils encountered in the borings contained occasional to frequent gravel - to cobble -sized shale fragments, and were slightly moist to moist and brown -gray to gray -brown. Based on sampler penetration resistance, the sands and gravels were generally medium dense to dense with isolated loose and very dense zones, and the clay zones were generally vary stiff to hard. Based on the results of laboratory swell -consolidation testing on eight soil samples, which are shown graphically on Fias. 4 through 7, seven of the samples, including two samples of sandy lean clay, exhibited additional compression upon wetting. The additional compression exhibited by those samples was relatively low, generally less than 2 percent. Based on our experience, drive sampling of the types of soils that were tested generally results in varying degrees of sample disturbance, and roost of the additional compression exhibited by the tested samples may be the result of that sample disturbance. However, based on our knowledge of soil conditions in the general area, it is also possible that lenses or layers of salt with low density and a potential for collapse upon wetting may be present on site. Ground water was not encountered in the borings during drilling, Three of the borings were left open in order to obtain ground water level measurements; however, the bore holes were dry to the full depths drilled of 40 to 45 feet when measured one day after drilling was completed. The borings were backfilled immediately after either driling or ground water measurement was completed. Water was not observed in Conn Creek at the time of drilling, and ground water conditions at the site could be affected by seasonal flows in the creek andlor up -gradient infiltration, LABORATORY TEs riNG Laboratory testing was perarmed on selected soil samples obtained from the borings to determine in situ soil moisture content and dry density, Atterberg limits, swell -consolidation characteristics gradation. concer. ration of water soluble sulfates, chloride content, pH, .'. 1 i'TAS Kumar & Assnciales, Inc. -5 - electrical resistivity, and moisture -density relationships (standard Proctor). The results of the laboratory tests are shown to the right of the logs on Fig. 2 and summarized in Table I. The results of specific tests are graphically plotted on Figs. 4 through 9. The testing was conducted in general accordance with recngnized test procedures, primarily those of the American Society for Teeing of Materials (ASTM . Swell Gonsotidatiere Swell -consolidation tests were conducted on eight samples of the soils encountered in the bcrings in order to determine their compressibility and swell characteristics ander loading and when submerged in water, Each sample was prepared and placed in a confining ring between porous discs, subjected to a surcharge pressure of 200. 500 or 1.000 psf, and allowed to consolidate before being submerged. The sample height was monitored until deformation practically ceased under each load increment. Results of the swell -consolidation tests are presented on Figs. 4 through 7 as plots of the curve of the final strain at each increment of pressure against the log of the pressure. Based on the results of the laboratory swell -consolidation testing, none of the samples exhibited swell behavior upon wetting, and seven samples exhibited about 1/2 to 2 percent additional compression upon wetting under surcharge loads of 600 and 1,000 psf. Index Properties: Samples were classified into categories of similar engineering properties in general accordance with the Unified Soil Classification System. This system is based on index properties, including liquid limit and plasticity index, and grain size distribution, Values for moisture content, dry density, liquid limit, plasticity index, and the percent of soil passing the U S. No. 200 sieve are presented in Table f and adjacent to the corresponding sample on the boring logs. SITE DEVELOPMENT CONSIDERAi IONS Lased on conditions encountered in the borings, subsurface conditions across the site are generally conducive to construction of the proposed compressor facility. The site is generally underlain to depths of 40 to =5 feet or amore by natural relatively dense, predominantly granular soils with zones of relatively st'ff lean clay. Several samples of the soils exhibited relatively low adct tional compression during swell -consolidation testing upon wetting. which can be indicative of a collapsible soil condition However, based or the in situ dry densities of those soils, we v Kumar & Associates, Inc. believe most of the additional compression exhibited by the tested samples is probably the result of sample disturbance. Based on our Knowledge of soil conditions in the general area, it is possible that lenses or layers of soil with low density and a potential for collapse may be present on site. Generally, soils expected to exhibit significant collapse potential are those with relatively low moisture contents and in situ densities_ Collapsible soils, is present, could adversely affect site facilities supported on those soils. The risk of adverse movement due to possible moisture -related collapse can be reduced by proper surface drainage, including measures to control storm water runoff and limit surface ponding. which would reduce the potential for water to infiltrate the site roils. The risk of potential collapse -related movement can also be reduced by performing additional, structure - specific subsurface explorations and laboratory testing to determine if those locations are underlain by moisture -sensitive sols. Shallow spread footing and/or mat foundations and slab -on -grade construction should be feasible across the site with proper subgrade preparation and site drainage measures, and with the understanding that there may be some risk of movement due moisture -related collapse of site soils. FOUNDATION RECOMMENDATIONS We assume the working loads that will be exerted by the planned structures and other facilities will be light to moderate. We understand that the critical structures and equipment will include the compressor building and compressors, and possibly taller gas processing equipment. We assume these facilities can tolerate relatively little differential settlement, although we have not been provided with settlement tolerances. In general, the planned structures and facilities, and miscellaneous equipment. can be supported on shallow spread footing or mat foundations, provided the spread footings or mats are underlain by undisturbed, non -moisture -sensitive, natural soils or compacted structural fill extending to natural soils. While it would be feasible to support the compressors on isolated or continuous footings, subsurface soils across the building location are expected to be variable arid could lead to excessive differential settlements between individual foundation elements. To limit potential excessive differential settlements due to variable soil conditions. we recommend Ku= r & Associates, Inc., -7 - supporting the corepressors and other settlement -sensitive facilities on mats, which would distribute the equipment loads over a broader area and result in relatively tow foundation contact pressures, Spread Footings; The design and construction criteria presented below should be observed for a spread footing foundation system. The construction details should be considered when preparing protect documents. 1. Footings should be established directly on properly prepared. tion -moisture -sensitive natural soils or on properly compacted structural fill extending to natural soils. Footings established as recommended should be designed for ari allowable soil bearing pressure of 2,500 psf. Higher allowable bearing pressures could be used, if necessary, for heavier structures; however, structure specific exploration would be required, and it is likely that a layer of structural fill would be required. Allowable bearing pressures may be increased by 1/3 for transient load conditions. 2. Spread footings should have a minimum footing width of 18 inches for continuous footings and 24 inches for isolated pads. 3 Based on experience and assuming soils with significant collapse potential do not influence foundation performance, we estimate total settlement for footings designed and constructed as discussed in this section will be approximately 1 inch or less. Differential settlements between adjacent foundation elements are estimated to be approximately '/2 to '.i of the total settlement. Settlements should be substantially complete shortly after construction is finished. 4. Exterior footings and footings beneath unheated areas should be provided with adequate soil cover above their bearing elevation for frost protection. Placement of foundations at least 38 inches below the exterior grade is typically used in the site vicinity. 5 The lateral resistance of a spread footing placed on properly -prepared natural soils andior properly compacted structural till material will be a combination of the sliding Kumar & Associates, Inc. _ 3 - resistance of the footing on the foundation materials and passive earth pressure against the side of the footing. Resistance to sliding at the bottoms of the footings can be calculated based on an allowable coefficient of friction of 0.30. Passive pressure against the sides of the footings can be calculated using an equivalent fluid pressure of 175 pcf. The above values are working values. e. Structural fill placed against the sides of the footings to resist lateral loads should conform to the general material and compaction criteria provided in the Excavation and Grading section of this report. 7 Soft or excessively loose natural soils, or soils exhibiting characteristics indicative of moistuic sensitivity, encountered within the foundation excavation should be removed and the footings extended to suitable undisturbed natural soil. As an alternate. unsuitable subgrade materials may be removed and replaced. where necessary to achieve required footing subgrade elevation, with structural fill. 8. Structural fill beneath spread footing foundations should conform to the general material and compaction criteria provided in the Excavation and Grading section of this report with the exception that structural till placed beneath footing foundations should be compacted to at least 98% of the maximum standard Proctor density (ASTM D698). Prior to placing structural fill, the subgrade soils should be scarified to a depth of 8 inches. adjusted to a moisture content near optimum, and re -compacted to at least 95% of the standard Proctor (ASTM 0 698) maximum dry density to provide a firm, uniform base for subsequent fill placement. 9. A representative of the project geotechnical engineer should observe all footing excavations and observe and test structural fills prior to concrete placement. Mats: the design and construction criteria presented below should be observed for a mat foundation system Construction details should be considered when preparing project documents. ,n.aamY+m Kumar & Associates, Inc. - g_ 1. A gnat foundation placed on oroperly prepared, non -moisture -sensitive, natural soils or properly compacted structural fill extending to suitable natural granular soils may be designed for an allowable contact pressure of 2,500 psf. This contact pressure may he increased by 1,4 for transient loadings. 7_ Settlements under static load were computed for a relatively large, rigid mat with a uniforn-ly distributed working load based on the combined weight of the heaviest planned compressor and mat. It should he noted that the estimated working contact pressure was signif�iu ntty less than the allowable contact pressure. Settlement due to compression of the predominantly non -cohesive foundation soil was calculated based on elastic theory. The settlement is assumed to occur immediately after the application of loads. Based on the above. we estimate total settlements beneath a rigid mat will be on the order of 1 inch. Differential settlements across the mat are estimated to be'/4 to Y4 of the total settlement, Non-uniformity of the subsurface conditions and deviation from the rigid mat assumption Will contribute to total and differential settlements. Rigidity of the mat is dependent on the mat dimensions, load distribution, and the modulus of subgrade reaction of the supporting soils. We recommend the mat foundation be analyzed to determine if the rigidity assumption is valid. If the mat cannot be considered rigid, the soil pressure distribution should be computed using a method which models tea soil -structure interaction, such as the beam on an elastic foundation procedure. A modulus of vertical subgrade reaction equal to 175 ter may be used for predominantly granular sails and 125 tot for predominantly fine --grained soils. 1 he Modulus value given is for a 1 -foot square plate and must he corrected for mat shape and size. When the soil pressure distribution has been determined, we should be contacted to reanalyze the settlement pattern of the foundation. The process of evaluating soil pressure distribution beneath the foundation may require several iterations for a foundation which classifies between rigid and flexible. Kumar & Associates, Inc. -10- 3. The iateral resistance of a mat foundation placed on properly prepared natural soil or properly compacted structural fill material will be a combination of the sliding resistance of the nit on the foundation mateenais and passive earth pressure against the Side of the footing. Resistance to sliding at the bottoms of the footings can be calculated based on a coefficient of friction of 0.30. Passive pressure against the sides of the mat foundations can be calculated using an equivalent fluid density of 175 pcf. The above values are vaorking values. 4. Structural fill placed against the sides of the footings to resist lateral loads should conform to the general material and compaction criteria provided in the Excavation and Grading section of this report. 5. For dynamic analysis, we recommend using a low -strain, dynamic shear modulus of 1503 kst and a Po sson's ratio of 0.4, These values are for non -cohesive silty sands similar to those encountered at the site and are based on empirical relationships between soil type and density. 6. Areas of soft or excessively loose natural soils, or soils exhibiting characteristics indicative of moisture sensitivity, encountered vi ithin the foundation excavation should be removed and the mats extended to suitable undisturbed natural soil. As an alternate, unsuitable subgrade materials may be removed and replaced, vwhere necessary to achieve the required mat subgrade elevalion, with structural fill. 7. Structural fall beneath mat foundations should conform to the general material and compaction criteria prov;deet in the Excavation and Grading section of this report with the exception that structural fill placed beneath mat foundations should be compacted to at least 93Yc of the maximum standard Proctor density (ASTM Dna). Prior to placing sub - slab structural fill, the subgrade soils should be scarified to a depth of B inches, adjusted to a moisture content near optimum, and re -compacted to at least D5% of the standard Proctor (ASTM D 60) maximum dry density to provide a firm, uniform base for subsequent fill placement. Ktiinar & Associates, Inc. ItLiIPlat 114440 VV1411r V, i•rV -13 - The pH tests indicated the tested soils are mildly alkaline, which should have a negligible affect on corrosion, and have chloride contents of 0.03 percent. The results of the electrical resistivity tests are presented on 'Fig. a The test resuits for the samples indicate minimum laboratory electrical resistivity values of about 4,140 and 5,410 ohm -cm at moisture contents of about 35 and 48 percent. respectively. and estimated resistivity values of more than 15,600 ohm -cm at insitu moisture contents of less than about 15 percent. Based on the resistivity test results, the natural clay soils would generally be classified as slightly corrosive at in situ moisture contents below about 16 percent and mildly to moderately corrosive at moisture contents above about 16 percent. The corrosion classificaticn is based on a range of slightly, mildly, moderately, to very corrosive as presented by the U.S. Bureau ot Reclamation. Based on laboratory test resu'ts, the moisture contents of the natural clays encountered to the full depths explored of 40 to 45 feet were generally less than 16 percent. The natural soils are expected to exhibit poor to fair drainage characteristics Corrosion of buried metal is a complex process and requires an understanding of the combined affects of pH, ion content, electrical resistivity, soil moisture, and other Conditions not evaluated as part of this study. We recommend a qualified corrosion engineer review the information presented herein to determine the need for and appropriate level of corrosion protection for buried metals at the site. SURFACE DRAINAGE Proper surface drainage is very important for acceptable performance of site structures and facilities during construction and alter the construction has been completed. The sive may be subject to storm water runoff from higher elevation areas to the north and west. The site soils are expected to be moderately susceptible to erosion from storm water flows. Although the site soils are expected to be moderately impervious, there is the possibility That potentially collapsible soils may be present, which could be affected by iinfiltration of surface water. Accordingly, site finished grades should be designed and constructed to promote drainage and reduce ponding ot water. Site development plans should include control of up -gradient storm seater runoff and site drainage in order to limit site and emibankment erosion and ponding of water adjacent to structures. GG: ., .PZ II,.I•J Kumar & Associates, Inc • • - 14 - Drainage recommendations provided by local, state and rational entities should be followed based on the Intended use of the facility. The following recommendations should be used as guidelines and charges should be made only after consultation with the geotechnical engineer: Excessive wetting or drying of the foundation and slab subgrades should be avoided during construction. 2, Construct appropriate surface drainage measures to collect and remove runon and runoff, and to reduce ponding, infiltration, and flow over fill slopes. We recommend grading the site to promote orad direct runoff, installing collection and diversion measures such as ditches and berms where appropriate, and constructing discharge points designed to reduce potential erosion EXCAVATION AND GRADING Site Preparation: Site- preparation should include stripping andlor grubbing existing vegetation and removal of topsoil, where present, from beneath structures and other site facilities and from beneath roadway and yard areas, Prior to placing compacted fills or roadway and yard area surfacing, the natural subgrade soils should be scarified to a minimum depth of 8 inches, adjusted to a moisture content near optimum, and compacted to at least 95 % of the standard Proctor (ASTM 0 698) maximum dry density. Fills should be benched into existing natural slopes exceeding 41-1:1V (horizontal to vertical), with vertical bench heights between 2 and 4 feet. Prior to placement of concrete, foundation and floor slab areas should be proof -robed with a large vibratory 4:.cmpactor to identify any areas of soft or excessively Coosa subgrade soils, and to density possible low-density natural soils, if present near subgrade, and reduce the potential for moisture -related collapse of those soils. Soft or low-density soils that cannot be properly densiifled during proof -rolling should ba over -excavated to suitable undisturbed natural soils and replaced with compacted structural fill. Undisturbed natural soils identified during site grading as potentially collapsible should be removed and replaced with compacted structural fill: however, this condition, if encountered, should be addressed on a site-specific basis to determine the appropriate amount and extent of over -excavation and becktifiing. Kumar &i ssociates, Inc. Tc.moorary Excavation Slops: Ali excavations should be oanstmcted in accordance with OSHA requirements, as well as state, local and other applicable requirements, For temporary excavations that occur during site grading, the natural, predominantly granular soils generally classify as OSHA Type C soils. If unstable soil conditions or ground water are encountered, the geotechnical engineer should be notified so that additional recommendations can be provided, if necessary/. Permanent Cut and Fill Sloues: Based on our experience with soils similar to those encountered on the site, we recommend that unr_rnforced embankment fills and permanent cut slopes be constructed ria steeper than 211:1V based on stability requirements and 31-4:1V for reducng erosion susceptibility. No fo'rnal stability analyses were performed to evaluate the slope recommended above. Published literature and our experience vdth similar cuts and fills indicate the reeonimindEod slopes should have adequate factors of safety. if a d tailed stability analysis is required, we should be notified. We do not anticipate seepage will be encountered in permanent Excavation slopes. However, the risk of slopes instability will be significantly increased if seepage is encountered in cuts, and 2 stebiiity investigation should be conducted to determine if the seepage will adversely affect the cut. Slaps. of 21-I:1V (horizontal: vert.c l) consl+ucted of or excavated in on-site natural soils are expected to be moderately to highly sus ptib10 to surface erosion under moderate Sheet flows end highly suss: ptibie to erosion under concentrated flows. Susceptibility to erosion can be limited by constructing the slopes at flatter inclinations, as recommended above, or by establishing en appropriate vegetative cover, which may be difficult at the site. Fi.l Materials and Cornpactton Criteria: We anticipate tr!at the primary source of structural fill Materiel will be on-site natural soils, and that materials will he imported as necessary where additional vo urne is required or for specific purpos+=s such as road and yard area sarfacincr, Ba ed on subsurface ccr-rditiws encountered in the explorations, on-site borrow will consist primarily of natural silty to clayey granular :sells, with possible minor volumes of lean clays, Irnpn> aed fit material, if required, should be non expansive and free of vegetation, brush. sod Kumar & Associates, Inc. and other deleterious substances and should not contain rocks or lumps larger than 6 inches in greatest dimension. Rocks or lumps should be dispersed throughout the fill and "nesting" of these materials should be avoided. The yeatechnicel engineer should evaluate the suitability of proposed fill materials prior to placement. Unless recommended otherwise in this report, structural fill should be compacted to at least 95:6 of the standard Proctor (ASTM 11 693) maxirnurfi dry density. Fine-grained structural fill materials (more than 50% passing the No. 200 sieve) should be compacted at a moisture content betwen 0 to 3 percentage points above optimum moisture content. Granular structural fill materials (less than 50% passing the No. 200 sieve) should be compacted at a moisture content within 2 percentage points of the optimum moisture content. Based on the laboratory test data and our experience with similar sails, the in-situ moisture contents of the natural soils are expected to be somewhat to significantly below the optimum moisture content for those materials. Achieving the required moisture content for compaction of the finer -grained on-site natural soils will require the addition of moderate to significant amounts of water. The contractor should he aware that on-site fine-grained soils, as well as granular soils with moderate to significant amounts of material passing the No. 200 sieve, may become somewhat unstable and deform under wheel loads if placed near the upper end of the moisture range, This is generally not a concern in structural fills beneath buildings and other structures, but could be problematic in drive areas. A representative of the geotechnical engineer should observe and test structural and embankment fill placement. DESIGN AND CONSTRUCTION SUPPOR r SERVICES Kumar & Associates, Inc. should be retained to review the protect plans and specifications for conformance with the recommendations provided in our report. We are also available to assist the design team in preparing specifications for geotechnical aspects of the project, and to perform additional studies, if necessary, to accommodate possible changes in the proposed construction. Kumar & Associates, Inc. - 17 - Vide recommend that Kumar & Associates, Inc. be retained to provide observation and testing services to document that the intent of this report and the requirements of the plans and specifications are being followed during construction, and to identify possible variations in subsurface conditions from those encountered in this study so that we can re-evaluate our recommendations, if needed. LIMITATIONS This study has been conducted in accordance with generaily accepted geotechnical engineering practices in this area for exclusive use by the client for planning and design purposes. The conclusions and recommendations submitted in this report are based upon data obtained from the exploratory borings drilled at the locations indicated on Fig. 1, and upon the proposed construction. This report may not reflect subsurface variations that occur between the explorations or across the remainder of the site, and the nature and extent of variations across the site may not become evident until site grading and excavations are performed If during construction, fill. soil, rock or water conditions appear to be different from those described herein, Kumar P. Associates, Inc. should be advised at once so that a re-evaluation of the recommendations presented in this report can be made. Kumar & Associates, Inc. is not responsible for liability associated with interpretation of subsurface data by others. The scope of services for this project does not include any environmental assessment of he site or identification of contaminated or hazardous materials or conditions. If the Occidental Oil & Gas is concerned about the potential for such contamination, other studies should be undertaken. JWG rnj cc: book, file Kumar i Associates, Inc. 1 7, • - ; s •r• ,* b_cl•Pir • • e:LrAl _4 It 1 c..i. • • -,11Mtle _47 4, %.1 , . • . • 7.4;A: .1,, .r" .! • • „. ...:` , • • , i'-7'.7,' -0 -,-, .. : • . _.. 4' „..._-1.-•;'...et;-T- 4,:' j- • ,,-1.- r'..-* - • -7: 1 .. • ..- 1 .4- "' 40:- i , r:4°^"' ; L'S•1 .. i44 • - 4 GUT; 61 e- ci A t Pt rt • k me,...14. • i • 11A—j-t! : en LEGEND SILTY C;;LAY'EY SAND ($14 -In) WITH OCCASIONA TO FRE,;IJENI GRAVEL Aro TONES (it* .i EA f CLAY WITH (CL), SANDY LEAN 'CLAY (CL), AND SILLY CLAYEY GRAVEL :4IT�1 L��SMV. (CM -GC). 14EDiLM DENSE TO DENSE W17H ISOLATED LOOSE AND VERY CENSE ZONES, SLIGHTLY HOIST TO 1.10157, ?ROW'N-GRA"{ TO GRAY -BROWN, OCCASIONAL TO FREQUENT SHALE FRAGMENTS FROM GRAVEL- TO COBBLE -SIZED UDRIVE sAkdPI F, 2 IPTG rl ,.D. DALFORFI;.A LINER SAMPLE. -11 DRIVE 3AMF :., 1 3/3 -INCH I.C. s"L:T SPOON SAMPLE, STANDARD PENEiR.4T1AN TEST. 15/12 DRIVE SAMPLE BLOW C:O1;NT. INDICATES THAI 15 SLOWS CF A 140 -POUND HAYMER :.AI LING 30 INCHES *ERE REQUIRED TO DRIVE THE SAMPLER 12 INCHES. DISTLR; EO RULIC SAMPLE. NOTES_ 1. THE EX'PLORA1ORY BORINGS WERE DRILLED ON FEBRUARY G. 2008 WITH A 4 -!NCH DIAMETER CONTINUOUS FI_ CHI POWER AJGER. 2. THE LOCATIONS GE THE EXPLO:CATORY SORIN"WS 'S•�FRE MEASURED BY GLOBAL POSITIONING SYSTEM BY FORERUNNER CORE::RATION. 5. THE ELEVATIONS OF THE 'EXPLORATORY RCRINrGS WERE NOT MEASURED AND THE LOGS DT THE EXPLORATORY BORIHG5 ARE PLOTTED TO DEPTH. 4. 1HE EXFI.OP.A10R'f BORING LOCATIONS SHOULD BE CONSIDERED ACCURATE ONLY 70 THE DEGREE IMPLIED EY THE METHOD USED. 5. THE LINES FETWELN !.(ATERIALS SHOWN ON TH.. ' XFLQRATORY BORING LOGS REPRESEN1 THE ArROXII.IATF '3OxUNDARIES BETWEEN MATERIAL TYPES AND THL TRANSITIONS MAY BE GRADUAL 6. GROUND WATER WAS NOT EN OUNTERED IN TOE BORINGS AT THE TIME OF DRILLING OR WHEN CHECKED I DAY LATLN. 7. LABORATORY TEST RESULTS: WC = 'NATER CONTENT (T) ;ASTM D 2216); EG = DRY DENSITY (pci (ASTM 0 2215); +4 PERCENTAGE RETAINED ON NU. 4 SIEVE -20C - PERCENTAGE PASSING NO. 200 SIEVE LL = LIGUID LIMIT (ASTi,1 D 4313); P6 = PLASTIG11TY INDEX (ASTM A =313); RES - MINIMUM LARORATCR?Y RESISTIVITY (e,r - W'SS = WATER ''301 LEGE SJR.RTES (X) (AASHIC p1: = HYDROGEN ION CG14CEN1RA-ION (ASTM E OMC a OPTIMUM MOISTL-E CONTENT (f) (ASTM MUD = MAXIMUM DU CEI.SITY { d) (A51M C ASTM b 1140): )6--'1 —577t\.7 e:-..) (ASTLI G 57); T 25O); IU): 0 1 ,537) or (ASTI.1 J 557) er (AS -M D AS.5), LEC EN ] AMID NOTE. �'q. 3 1 0 -5 I I I I SAMPLE OF: 'a and+ F PO Eiay; rg % d2. } I I I WC - 12.3h. 30 -7003 =. 44%, LL 1, 11111 —I—I I , [ I 1 1 L 6 1, 1 Leg n Clsy (CL) .- ;7.2 pcj 44. PI = 15 • i i I I I I II��I ADDITIONAL COMPRESSICN JiJOER, CONSTANT PRESSURE :sPJ" TO 'WETTING dli APPLIED PRESSURE - KSf 1D - 3. 1143,3ry1041 ea! A, t 1 SAMPLE OF: Clayey Scn1 with :gavel (511 -SC) FROM: Boring 3 4' WC _ 4.4:«. DO - 103.6 ecf -200 = 281, LL = 27. Fi = 5 N LH 1 I I I ADial 01.1AL 0.01.1=RESS ON UNDER CONSTANT FRESS"JRE DUE TO % ETTING TT 11 ?RrSSURF - liS 17 OE— I—577A.2 Kumar e AhSCdci0Les. 3WE.LL • C.ONSQLIDAT 0`d I EST Rf :;'JI_I Fig. 4 CONSOLICATOt8 _2 —4 0 ti 1 y crifa5ULIDATPOr4 — 2 —3 — 4 — 5 —5 I I ° III I wI 1 ll I f II I I I -200 = 33r:, LL = 11WW1 I IIS P I 11 I II,I i dpi+ I I I I--- I NO MOVEMEW: LI?Coi,I ;YEiING I 1 1 IIP I I 1-1-1 I ISI SAMFLr Cr: SiI y Cfayey Clr;.vex.1h "Sand D1.: ?,ring 4 103.0 pcf 2e, PI = 7- -r--1j,']" 1 1-1 I I I Ifl pi rl,1p � HLH' LLL •w APPLIED PRZSSU F — KSE 10 1CC SAMPLE 0r: C1 yey Send w:#I Grzvel [SC) FROM: Bering r+ IA' WC — 9.6%, OA = 94.9 Rd —200 = 329:, LL = 32, P1 9 ADDLTI0k L C01.1PRZSSI0N UNDER CONS' ANT NK`_S ilrie DUE TO 'W_fTI'IG 112,1149. ralvd a1 ne, D. Pv IA . yaeCla i'4•' 06- -577A,'i KJro r APPLIED RESSLIPE — KSr Iv il SWELL—CONSOLIDATION IFSi Ri IJL S • • • 10r-1 — ';tilCd.L LI i CkSOLI DAT IO?t —4 —4 AMPLE OF: Sano, Leon Clay (CO FROM: Bating 5 1? '• hlC A 6.7 00 = 114.7 pcf -200 _ 55::, I1. = jam, PI = 13 I f1 I ll, II I_I1 �'-1 1 �JA'7ulliONAL COMPRESSION I 1 _[' �I 1 UN01 CONSTANT rRE° J GU= 70 W 1 1NC .1 ' I N 11 II III w 1 1I ill I I N---- to #Fl LIED PRESSI.URE xsr 10 SIN LE 01: SIII Clayey Send wl1h Gtsrel (SM—SC) FROM: 'aaring E 9 s' tidC = 7.3/, DO = 100-2 p•_1 —2400 34:, LL = 251 'I = 6 %rxe trfi nw.a .nJ 0./ : w•.. .4..4 dei Mkt �f n••e•d, w.'• 4 1,l, .:r'..J L.• •1L4s. 44G'^-1 a u� ...I A.0.4.1n. +t. 1,/•.n Lhw:..fsm•d I. •m4..,• .L. I.1,1 Y -.s.. If n a -p LS EI F ti'SSU - KSF 1G AOD.TI0IiAL COY ?RE 'S ION UNDER r,ONSTAF7T FRS SSIUR€ DUE TO V.'LTT.KG J ,CC —1 —577A.") Kuriar ASE.I:,c:lafa5 SWrF.LL—C'OkSOLIDA dON TEST KES1ULT S Fig. 5 r 1II 17` II 1 SAMPLE OF: :i19� Clayey Sdnd sviEh Drovel (SM -S.6,11 N f I IFROM: Boring 6 4D 9' r I we= 6.75:. Drs 1C0. pvf I I I I I-2tia'] - 27°%, LL 26 PI 6 � ! -o � { I 11 i ,III I I 1 11 I I "� Ii 1 1 IL' II I 1 1, I J I f I ITT ' AGG".Tio1 L COM RESSION --�- LINDER CONSTMa PRESSURE DUE TO 1.CTT.N Li LJ -4 :OI45OLIDATID:4 - SWELL 141 * �IIII.r--�- � 1 111 I III I I II rl 1 11 L U➢ AFFLIED PRFSSUR_ - KSF 10 1' 4 SAMPLE OF: Clayey Scnd vr:ih Gtcvel (SC) FROM Boring 6 19' �C = 5.7%. DO = 108.2 pcf -201)-3I2. tL=26, Pl=8 AD7i 7IONAL Ca'?EdFRESSII0N UNDER CONSTANT PRESSURE 1 I GLIT. TO WETTING H 1 rut. •i U....Pp, .v'. ,,..:.:. YA "i 4.•2.17.,.. ' g. . l . 401.2. n., Lawszaten, q i..^ APPLIED PRESSURF. - KSF s'r';ET_L-COI'seLIN-11DN TEST RE _PLTS Kt.:rZ2r.dc Assocate.i Fig. 7 • • 10 LL 30 40 50 E0 I 7 I 1 14_41 1 I 1-P 1, 1 Loci 0 30 ?.AOISTIPiE CV.) 40 53 t I GO UDE SYIADOL SAMPLE :IGNIXI:A10N SOI ":..R P.,EDROCK n'n 1/INFLIJM kr SISTATI/ (nb°71-crn) RESISTIVITY A PI SJU IdOLOURE Ce NEN r (rthri-crr.) 0 DURING' 2 0, 4 FT. Silty Cra?ey S,S :On Crowd •M -c) 4,1 40 ? 5,500. 'CRIN,17., C tt 4 Fr. Siity Ctoylry a'4$'odIrn nrivel SM -Si) 5.4 10 > 10.000 0;3-1-577A,2 Kumar A.VsT.,W:iii':ES LABORATORY RESISTIVITY REStLTS FiD. 8 C_. DRY DENSITY 145 13 1 I ! _SII 1 I I SPECIFIC i 1 I 125 •15 SI. ME i ZERO AIR ',..010 GIMES , 1aa III 1 I , 1- I 117 110 105 I0 c rII I I I ~�G^st15±II'f 7.20 SPECIFIC �GR.A'J9�f 2.70 SPECIFIC --GRAVITY = 2.eu TEST WETHOD AST'r.1: M SS-1TQ L' 152A -00A DATE SAMPLED: 42 -2a—"15 DATE RECEIVED: 52 DATE TES Lb: — 53-03-03 OVERSIZE CORRECTION — (ASTM D 471x) BULK SPECT IC GRAVITY ADSORPTION % _ I 1 I i1 1 H- H i I JI f— JIII J 11 ili \ 5 ' 0 15 20 25 .!C' I.+GIS+URE CDN TENT - FERCN' or DRY WEIGHT N/A 1k.1. hod ...Ma :SNR geld Thr amp•ei .11".* rep;r1 +:II i,iepl 'F. VI. .s^nul Ihr .0411, r.-prwvr r.t eu5r ,;.y Aur.Iehls. erlgilie-a•¢s 'r0141' aera-d.Rr. .IIII £ri'11 Iasi. 5I3S1. I.:Ip.b.rq ,06.10.1 tt.11'I 11.,r :a1 YSIA rc!0.,10 -i ::i-rJer•._r .Ilh e7h1 Ctsj. CIr.4. MAXIMUM DRY [,:ENSIT`t: 1109.0 S'::L TYPE: SAPIP_E NO.: ;:Ids Clcyey 5a i 1 Gr;'aVA' (EM —SC) P7I ID.PTNILP,1 MOISTURE CONTE.N f: 15.0 % --C�aATifli,: Cxr 'Coli:.pr 9r f rc 1 f GF!AVEL: A\1.0; is 1511: ANC PLASTICITY 'IDE); I BORING NO.: 2-3 0[P111: 0' --'IS' LIO!JID r'ull: 06-1-5774_2 I K11rrar Asstsrintr':3 J MOISTURE -DENSITY Rra_AT'C)NSL111' Fill. S J