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Home My WebLink About20121163 STATE?! Q QLORADO John W.Hickenlooper,Governor <p i I p �" SSIOpdERS Christopher E.Urbina,MD,MPH Executive Director and Chief Medical Officer 1 ? OP �,, $ Dedicated to protecting and improving the health and environment of the people Coo d O P 3' 21 . o , 4300 Cherry Creek Dr.S. Laboratory Services Division * / Denver,Colorado 80246-1530 8100 Lowry Blvd. RECEIVED taus, Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment April 23, 2012 Mr. Steve Moreno Weld County Clerk 1402 N. 17th Ave. Greeley, CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for EOG Resources, Inc. This public notice will be published in the Greeley Tribune on April 28, 2012. Thank you for assisting the Division by making the enclosed package (includes public notice, preliminary analysis, Air Pollutant Emission Notice(s) and draft permit(s)) available for public review and comment. It must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please forward any comment regarding this public notice to the address below. Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Attention: Ellen Evans Regards, Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division �O�1C 1R2utIL CL �L 1-4L - t 1 a, 5 _3_ l a, 2012-1163 NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR CRUDE OIL AND NATURAL GAS PRODUCTION FACILITY BY EOG Resources, Inc. CONTENTS 1 . PUBLIC NOTICE 2. PRELIMINARY ANALYSIS 3. AIR POLLUTANT EMISSION NOTICES 4. DRAFT PERMIT PREPARED BY: JACOB SEBESTA COLORADO DEPARTMENT OF PUBLIC HEALTH & ENVIRONMENT 4300 CHERRY CREEK DRIVE SOUTH, APCD-SS-B1 DENVER, CO 80246-1530 STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina,MD,MPH ,4p? cot94 Executive Director and Chief Medical Officer F� Dedicated to protecting and improving the health and environment of the people of Colorado \\* • a 4300 Cherry Creek Dr.S. Laboratory Services Division \-.18767- Denver,Colorado 80246-1530 8100 Lowry Blvd. ---- Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment Released to: The Greeley Tribune on April 23, 2012; published on April 28, 2012 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT The Colorado Air Pollution Control Division declares the following proposed construction activity warrants public comment. Therefore, the Air Pollution Control Division of the Colorado Department of Public Health and Environment hereby gives NOTICE, pursuant to Section 25-7-114.5(5), C.R.S. of the Colorado Air Quality Control Act that the Division received an application for an air pollution emission permit on the following proposed project and activity: EOG Resources, Inc. proposes to construct and operate three(3) oil and natural gas production facilities known as Randall Creek 6-19H, Critter Creek 7-13H, and Fox Creek 6-33H. These sources are located approximately 9 to 13 miles northwest of Grover, in SESE Sec. 19 of Township 12N, Range 62W, NWNW Sec. 13 of Township 11N, Range 63W, and NWNW Sec. 33 of Township 12N, Range 63W in Weld County. Each of these sources would be considered a major source of air pollutants subject to Prevention of Significant Deterioration (PSD) Title V Operating Permit (OP), and Maximum Achievable Control Technology (MACT) requirements if the operator did not install emissions controls and accept federally enforceable emissions limits in the proposed permit. Since the operator will accept emissions limits less than 100 tons per year for each criteria pollutant and less than 10 tons per year any single hazardous air pollutant (HAP) and 25 tons per year total combined HAP from each facility, these sources will be considered a synthetic minor sources not subject to PSD, OP, or MACT review. As such, each permit is subject to public comment per Regulation 3, Part B, Section III.C.1.d. Copies of the each draft permit and preliminary analysis are available for review in the public comment package. The Division has determined that the proposed sources will comply with all applicable regulations and standards of the Colorado Air Quality Control Commission and has made a preliminary determination of approval of the application. The Division hereby solicits and requests submission of public comment from any interested person concerning the aforesaid proposed projects and activities to comply with the applicable standards and regulations of the Commission for a period of thirty (30) days from the date of this publication. Any such comment must be submitted in writing to the following addressee: Jacob Sebesta Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 Within thirty (30)days following the said thirty(30)-day period for public comment, the Division shall consider comments and, pursuant to Section 25-7-114.5(7)(a), either grant, deny, or grant with conditions,the emission permits. Said public comment is solicited to enable consideration of approval of and objections to the proposed construction of the subject project and activity by affected persons. A copy of the applications for the emission permits,the preliminary analysis of said applications, and accompanying data concerning the proposed project and activity are available for inspection at the office of the Clerk and Recorder of Weld County during regular business hours and at the office of the Air Pollution Control Division, Colorado Department of Public Health and Environment, 4300 Cherry Creek Drive South, Denver, Colorado. Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 12WE1107 Source Name: Randal Creek 6-191-I Source Location: SESE Sec. 19, T12N, R62W, approximately 10 miles northwest of Grover Point 001 -Six (6)400BBL fixed roof crude oil storage tanks Point 002 - One (1)400 BBL fixed roof produced water storage tank Point 003 - One (1) Tornado Flare Point 004 - One (1) 400 BBL emergency tank used for natural gas Equipment Description: blowdowns when the open flare shuts down Point 005 -Generator Engine Point 006 - Crude oil truck loadout Point 007 - Fugitive equipment leaks AIRS ID: 123-9636 Date: March 5, 2012 Review Engineer Jacob Sebesta Control Engineer Chris Laplante Section 2 —Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? • Application received January 23, On what date was this application complete? 2012 • Fugitives APEN received 2/14/2012 Section 4—Source Description AIRS Point Equipment Description 001 Six(6) 400BBL fixed roof crude oil storage tanks 002 One(1) 400 BBL fixed roof produced water storage tank 003 One (1)Tornado Flare Page 1 004 One (1)400 BBL emergency tank used for natural gas blowdowns when the open • flare shuts down 005 Generator Engine 006 Crude oil truck loadout 007 Fugitive equipment leaks Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? If"yes", for what pollutant? PM,') CO Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PMlo CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes" the provisions Yes No of Regulation 7, Sections XII and XVII.C may apply) Section 5— Emission Estimate Information AIRS Point Emission Factor Source Source used E&P Tank model and site specific sampling to develop site-specific emission factors in lb/bbl units. Note: the sampling was completed at the Critter 001 Creek 2-03H site rather than this one. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 0.2740 Ib/bbl 002 State default emission factors for produced water tanks in Weld County Maximum gas vented to atmosphere along with VOC weight fraction to determine a site-specific emission factor. Note: the sampling was completed at the Critter 003 Creek 2-03H site rather than this one. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 33643 lb/MMscf vented Emission Factors for NOx, Sox, CO and PM10 from AP-42 Tables 13.5-1&2 004 VOC emissions are based on a VOC weight-fraction as for Point 002. VOC E.F.= 33643 lb/MMscf vented 005 AP-42, Table 3.2-3 for uncontrolled emissions Manufacturer's data for controlled NOX, CO, and VOC emissions 006 AP-42, Table 5.2-1, equation 1 007 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 131,400 BBL per year (109,500 x 1.2) 002 36,500 BBL/yr produced water throughput 003 96.725 MMscf/yr(0.265 MMscf/d) natural gas venting to flare Page 2 004 393.33 Mscf/yr (10,926 scf/hr x 3 events x 12 hours/event) natural gas venting 005 13.8 MMscf/yr natural gas combusted as fuel 006 146,000 BBUyr crude oil and produced water throughput Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- 2 007 Valves 56 --- 72 24 Other 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% --- Toluene Content(wt%) 0.039% --- 0.075% Ethylbenzene (wt %) 0.002% --- 0.017% -- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content(wt%) 0.336% --- 2.43% --- Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 109,500 BBL per year 002 36,500 BBL/yr produced water throughput 003 96.725 MMscf/yr(0.265 MMscf/d) natural gas venting to flare 004 393.33 Mscf/yr(10,926 scf/hr x 3 events x 12 hours/event) natural gas venting 005 13.8 MMscf/yr natural gas combusted as fuel 006 146,000 BBL/yr crude oil and produced water throughput Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- 007 Valves 56 --- 72 24 Other . 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% Toluene Content(wt%) 0.039% --- 0.075% --- Ethylbenzene (wt %) 0.002% --- 0.017% --- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content(wt%) 0.336% --- 2.43% --- Does this source use a control device? X Yes No % Reduction AIRS Point Process Control Device Description Granted 001 01 Cimarron Smokeless Combustor(vapor combustion unit 95 [VCUJ) 002 01 Cimarron Smokeless Combustor(SN5400413) 95 Page 3 003 of Tornado, 40' Flare Stack, SN 10423-3 95 005 01 NSCR Catalyst with AFRC NOX: 94.3 CO: 87.4 Section 6—Emission Summary (tons per year) Uncontrolled (PTE) Emissions AIRS NOx VOC Fugitive CO Reportable Total Point VOC HAPs HAPs 001 15.0 0.7 0.9 002 4.8 0.1 0.5 003 5.1 1,627.1 27.7 29.8 30.3 004 6.6 0.0 0.1 005 21.6 1.6 36.3 0.6 0.7 006 6.8 0.0 0.2 007 2.4 0.0 0.0 Total 27.1 1,661.9 2.4 64.7 31.2 32.7 Controlled Emissions AIRS Fugitive Reportable Total Point NOx VOC VOC CO HAPs HAPs 001 0.8 0.0 0.0 002 0.2 0.0 0.0 003 5.1 81.4 27.7 1.5 1.5 004 6.6 0.0 0.1 005 2.3 1.6 4.6 006 6.8 0.0 0.2 007 2.4 0.0 0.0 Total 7.7 97.4 2.4 33.0 1.5 1.9 Section 7 - Non-Criteria/ Hazardous Air Pollutants Are the Uncontrolled emissions Controlled AIRS Emission Rate reportable Emission Rate Point Pollutant CAS # BIN (lb/yr) ? (Ib/yr) Benzene 71432 A 188 Yes 9 001 n-Hexane 110543 C 1254 Yes 63 Benzene 71432 A 256 Yes 13 002 n-Hexane 110543 C 803 No 40 003 Benzene 71432 A 7,257 Yes 363 Page 4 Toluene 108883 C 5,480 Yes 274 Ethylbenzene 100414 C 921 No 46 Xylenes 1330207 C 2,276 Yes 114 n-Hexane 110543 C 44,494 Yes 2,225 Benzene 71432 A 30 No 30 004 n-Hexane 110543 C 142 No 142 Formaldehyde 5000 A 1030 Yes 1030 005 Acetaldehyde 75070 A 163 Yes 163 Acrolein 107028 A 100 Yes 100 Benzene 71432 A 46 No 46 006 n-Hexane 110543 C 311 No 311 Benzene 71432 A 5 No 5 007 n-Hexane 110543 C 250 No 250 Section 8 —Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Section 9—Source Classification Is this a new previously un-permitted X Yes No source? What is this facility classification? Synthetic minor source of VOC and HAP for Title V and of VOC for PSD Is this a modification to an existing Yes X No _permit? Synthetic If"yes"what kind of modification? Minor Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Any Comments Received? i Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Page 5 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which 001-006 is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner 001, 002, or operator of a smokeless flare or other flare for the combustion of waste gases shall 003 allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-006 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 -APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in an attainment area with uncontrolled actual emissions of 001-006 two tons per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is attainment. (Applicant is required to file an APEN for these points because uncontrolled emissions exceed 2 tons per year VOC) Part B -Construction Permit Exemptions 001-006 Applicant is required to obtain a permit for points 001-005 since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section Il.D.3.a) Part B, III.D.2- RACT requirements for new or modified minor sources located in ozone 001-006 non-attainment areas This source is not subject to this requirement because it is located in an ozone attainment area. Regulation 6 - New Source Performance Standards 001, 002, NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 004 These tanks are not subject to NSPS Kb because they each have a capacity less than 471 BBL. Res ulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is not subject to the emission control requirements for condensate tanks 001, 002, because this facility is located in an attainment area. 004 XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is not currently subject to this section because these are not condensate storage tanks. Regulation 8- Hazardous Air Pollutants • 001, 002, MACT EEEE: Organic Liquids Distribution 006 This source is not subject to MACT EEEE because it is located at a "production field facility" as defined in 40 CFR 63.761. MACT HH 001, 002, This source is not subject to MACT HH because it is not located at a major source of HAP. 004 These tanks are also not considered "storage vessels with the potential for flash emissions" as defined in Subpart HH. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Factor Pollutant/ Fugitive Emission Control CAS# (Y/N) Factor Source (%) 001 01 E&P Crude Oil 6.5232 lb/1000 V0C Na Site-specific 95 Storage Tanks gallons throughput Page 6 0.0409 lb/1000 Benzene No Site-specific 95 gallons throughput 0.2727 lb/1000 n-Hexane No Site-specific 95 gallons throughput SCC 40400312—Fixed Roof Tank, Crude Oil, working+ breathing +flashing losses Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 6.2381 lb/1000 VOC No State Default 95 E&P Produced gallons throughput EF 0.1667 lb/1000 State Default 01 Water Storage gallons throughput Benzene No 95 EF 002 Tanks 0.5238 lb/1000 State Default gallons throughput n-Hexane No EF 95 SCC 40400315— Fixed Roof Tank, Produced Water,working+breathing+flashing losses Pollutant/ Fugitive Emission Control Process Process Description Emission Factor Point CAS# (Y/N) Factor Source (%) 33642.97 lb/MMscf VOC No Mass Balance 95 vented • 75.0282 lb/MMscf Benzene No Mass Balance 95 vented 56.6516 lb/MMscf Toluene No Mass Balance 95 vented 01 Produced gas 23.5311 lb/MMscf Xylenes No Mass Balance 95 003 vented to flare vented 459.83 lb/MMscf n-Hexane No Mass Balance 95 vented 105.33 lb/MMscf NOx No AP-42 NA vented 573.13 lb/MMscf CO No AP-42 NA vented SCC 31000205—Flares (at gas production facility) Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 33642.97 lb/MMscf VOC No Mass Balance NA 01 Natural gas vented 004 blowdown venting 75.0282 lb/MMscf Benzene No Mass Balance NA vented SCC 31000299— Natural Gas Production: Other not classified Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 3122.73 lb/MMscf NOX No Manufacturer 89 231.978 lb/MMscf VOC No Manufacturer NA 5256.36 lb/MMscf CO No Manufacturer 87 01 NG-fired RICE 74.60641b/MMscf Formaldehyde No AP-42 NA 005 /5000 11.8127 Ib/MMscf Acetaldehyde/ No AP-42 NA 75070 7.2628 lb/MMscf Acrolein/ No AP-42 NA 107028 SCC 20200256—Internal combustion engine, Natural gas, Four stroke-rich burn Page 7 Point Process Process Description Emission Factor Pollutant/ Fugitive Emission Coo trol CAS# (Y/N) Factor Source CA) 2.2285 VOC No AP-42 NA Crude Oil and Produced Ib0 000ga1 01 Water Tank Truck 0.0076 Benzene No AP-42 NA 006 Loadout lb/1000gal 0.0508 n-Hexane No AP-42 NA lb/1000ga1 SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Fugitive Point Process Process Description Emission Factor Pollutant/ Dust Emission Control CAS# (Y/N) Factor Source (0/0 01 Fugitive equipment 4720 lb/yr VOC No EPA-453/R-95- 0 007 leaks017, Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14—Miscellaneous Application Notes AIRS Point 001 Crude Oil Tanks Although these tanks store oil with an API gravity less than 40 degrees, EOG collected a pressurized oil analysis and calculated flash emissions from this tank battery using E&P Tank. Without emission controls and federally enforceable emission limits for this point, this facility would be considered a major source of VOC for Operating Permit applicability. In order to obtain synthetic minor limits and avoid Operating Permit applicability, EOG will not take advantage of the categorical permit exemption in Regulation 3, Part B, Section II.D.1.n for crude oil storage tanks with capacities less than 40,000 gallons. AIRS Point 002 Produced Water Storage Tanks EOG used the state default emission factors to calculate emissions from this produced water storage tank battery. Without emission controls and federally enforceable emission limits for this point, this facility would be considered a major source of VOC for Operating Permit applicability. In order to obtain synthetic minor limits and avoid Operating Permit applicability, EOG will not take advantage of the categorical permit exemption in Regulation 3, Part B, Section II.D.1.m for tanks used to store produced water that is less than 1% oil by volume. AIRS Point 003 Tornado Flare The tornado flare is controlling gas coming off the well since there is no pipeline available in the area at this time. EOG will continue to flare gas until a pipeline is available. AIRS Point 004 Emergency Tank In case of a flare outage (AIRS point 003), produced natural gas from this site will be routed to this Emergency Tank. Entrained liquids settle in the tank and the gas will be vented to atmosphere. EOG based emissions from this activity on a gas flow rate of 8,750 scf/hr and three venting events per year at 12 hours per event. The composition of the vented gas has the same basis as was used to calculate emissions routed to the flare (point 003). • Page 8 AIRS Point 005 Generator Engine Based on a manufacture date of October 1, 2009, this engine is subject to emission standards in NSPS JJJJ. Therefore, this engine is not subject to Regulation 7, Section XVII.E. The construction permit will require stack testing to verify the emission rates stated in the application. The emission rates stated in the certificate of conformity (EPA) are based on an engine with a catalyst for emissions control installed. AIRS Point 006 Truck Loadout of Crude Oil and Produced Water AP-42: Chapter 5.2 Equation 1 L = 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T = temperature of bulk liquid loaded [deg. R] S 0.6 Submerged loading: dedicated normal service P 4.34 psia M 35.99 lb/lb-mole for gasoline with RVP = 11.5 T 524 deg. R (65 deg. F) L 2.231b/10^3 gal Annual requested Throughput 6,132,000gal/yr Annual requested VOC emissions 6.8tpy Page 9 . Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY Current Status(Check 411 that apply) Reason for APEN Submittal(Check all that apply) AIRS ID#1: (23/%Se/0o1 ❑ APEN update only" ® New or previously unreported battery ❑ Modification to existing sources ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GP01 ❑ Synthetic minor facility &cancellation request for individual permit6: ❑ Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no.GP0I - ❑ Administrative permit amendments ❑ Permitted under individual permit: 12WEIID+ ❑ Other. For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division ❑To review a draft of the permit prior to issuance Company Name9: FOG Resources,Inc. OGCC Operator#: 27742 Mailing Address°: 600 17th Street,Suite 1000N curtis_rice@eogresourc City: Denver State: CO Zip: 80202 E-mail: es.com Contact Name: Curtis Rice Phone: 303-262-9946 Fax: 303-262-9449 ),117- S1v2c-Tank Battery Name°: Randall Creek 6-191 Number of tanks: 6 ye-c-4 r �I Location'?(QQ Sec.Twp.Range.): SESE See-fr;I'12N,R62W County: Weld • Total tank capacity[bbl]: 2,400(400 ea) �- L Calendar year for which"Actual"data applies13: 2011 Year(s)tank(s)were placed in service14: 2011 ,\L7 Control Description": Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency16: 95% Condensate Throughput's[bbl/year] Requested": 109,500 Maximum for PTE calculation19: 131,400 Actual2°:. 109,500 While Controls Operational21 109,500 Other equipment at facility22: V CU,flare,heater treater,generator engine,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GP01 coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. E]Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions" Actual Emissions2° Pollutant24 [1b/bl] PTE2s Uncontrolled26 Controlled27 Uncontrolled26 Controlled'-s VOC[tons/year] 0.2740 18.0 N/A N/A 15.0 0.75 NOx[tons/year] N/A 0.05 0.05 0.05 CO[tons/year] N/A 0.25 0.25 0.25 Benzene[lbs/year] 188.0 9.4 n-Hexane[lbs/year] 1,254.0 62.7 Wells serviced by this tank or tank battery's API#: 05-123-31925-00 Name: Randall Creek 6-19H ®Newly Reported Well API#: Name: 0 Newly Reported Well API#: Name: • ❑Newly Reported Well API#: Name: ❑Newly Reported Well ro API#: Name IX1I < ` ❑Newly Reported Well w API#: Name: rs 0 Newly Reported Well 61 API#: Name: --••1: ❑Newly Reported Well w m o The signature below indicates that I ha knowledge of the facts herein set forth slip that the same are true,accurate,and complete to the best of o my knowledge and belief If this• egistration for coverage under general permit GP0I,I further certify that this source is and will be operated N in full compliance with eac lion of gener 't GP0I. ,ci z Signature of L ly Authorized Person(not a vendor or consultant) Date 3.10 Curtis Rice Senior Environmental Specialist N Type or Print Name of Person Signing Above Official Title o Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: N filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-Bl 2 L+U V e r 3 632)6�2-3150 a $250 General Permit fee for each new GP 4300 Cherry Creek Drive South J o registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 EOG RC 6-19H FormAPCD-205-E&PCondensateTankAPEN.docx . N O u 2. ;' ❑ C w O ° E a c o u o CO o a 0 E d .T. . a t.. d h.�i� L co O a T -- E W'm, F? ` m ea, ra, ^0, .. a o o 01 t,' e Al rn rn• . ° c y = ❑ .� �. s ti Y E b NO b n CV 1 0 y O c47 .) ac la ,_ Nis"t 14 tIM 0 en 0 cc \ H L a Q O 4 \ +' W 0.U Y Vl 6.'. O E Al M O ,N �-(1 = F E ❑. No u 0 x "Oa, 6 4 U`E' e o y > E v v �' d K a rFir P. ,>je" I.'.:: o R m F. ❑ T o a 45 8 CV ca S ga c .'A ao T `Y C7 Z ❑ q P. o . ea Y .2 o Wcia 'zZ 2 Y = N ''E Y a d o Le a y '• Y `"a P' C m a Y E o E Y ❑ z 4a un c O o t n Q " z O 0 X u = Z O . Li. . ., - `^ E = y Y v w E.y F.: v u Y o� m 9:2: a 4 a G Y A n = '° E 8 -" a' O Y pp to �E., o 0 'p y N 3 Y Y y y y u Q' ? v U C. a o2 on C I•" c c c °-7 0 o o a o w o . Ga .. 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O aNN o o ' U o a o ° o vE ea PIT .a N. en w br _w _ — _. - .� 0 0. u a o o E r t4 0 q; E o a° aa, c e, E t* a o d .y. .o w Z m 0 u v Tit = v m v u o a.) ,'`,L. I o C o ry V C i s a u c ti To 0 E :9 O m u K _ 61 0 W C W o O N °> C O .N ¢ O _U � G L C.a' N Q N o -,-., = go O x2 CI 0® W U w o w > oLu D "' F u1 ¢} .m .°[° __ Cl) CC TATE OF COLORADO Nei.°p.g°�° COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION r4 p ° TELEPHONE: (303)692-3150 ;+ •..::_<-� 1876 CONSTRUCTION PERMIT PERMIT NO: 12WE1107 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas production facility, known as Randall Creek 6-19H, located at SESE Section 19, Township 12N, Range 62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID 001 Six (6) 400 BBL fixed roof storage tanks used to store crude oil. Emissions from these tanks are controlled by an enclosed flare. One (1) 400 BBL fixed roof storage tank used to store produced PW Tank 002 water. Emissions from this source are routed to an enclosed flare. One (1) Open flame flare (Manufacturer: Tornado, Model No: 40' Flare 003 Flare Stack, Serial No: 10856-21) used to combust produced natural gas vented from a three-phase separator. One (1) 400 BBL well blowdown tank (Manufacturer: Connor Steel, ET#4887 004 Model: EOG #4887, Serial No: 34193) used to catch liquids and vent gas during emergencies when the produced gas cannot be combusted in the flare.(AIRS point 003). AIRS ID: 123/9636/001-007 Page 1 of 19 EOG Resources, Inc. olor- Depa en P li Health and Environment Permit No. 12WE1107 A` it Pollution Control Division Issuance 1 Facility AIRS Equipment Point Description ID One (1) Power Solutions, Inc., Model 8.1L (D081TIC), Serial Number EEPOE902556, natural gas-fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 237 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio Generator control. This emission unit is used to generate power for the RICE 005 facility. Engine This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Power Solutions, Inc. 8.1L (D081TIC) engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Truck 006 Truck loadout of crude oil and produced water. Loadout Fugitive 007 Equipment leaks (fugitive VOCs) from a natural gas production facility. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (di) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) AIRS ID: 123/9636/001-007 Page 2 of 19 • EOG Resources, Inc. olor- Depa en f P •li Health and Environment Permit No. 12WE1107 •Air Pollution Control Division • Issuance 1 • • 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 2.6 tons per year of volatile organic compounds (VOC), -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: • 100 tons per year of volatile organic compounds (VOC), 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Equipment AIRS Tons per Year Emission Type ID Point NO, VOC CO 001 -- 0.8 -- Point PW Tank 002 -- 0.2 -- Point Flare 003 5.1 81.4 27.7 Point ET#4887 004 -- 6.6 -- Point Generator RICE 00$ 2.3 1.6 4.6 Point Engine Truck Loadout 006 -- 6.8 -- Point Fugitive 007 -- 2.4 -- Fugitive See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (12) month total. By the AIRS ID: 123/9636/001-007 Page 3 of 19 EOG Resources, Inc. olor Depa en P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Emissions Point 001: Emissions from this point shall be routed to an enclosed vapor combustion unit (VCU) that reduces uncontrolled emissions of VOC from the crude oil tanks to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. Emissions Point 002: Emissions from this point shall be routed to an enclosed flare that reduces emissions of VOC to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 9. Emissions Point 003: Emissions from this point shall be routed to an open-flame flare that reduces emissions of VOC to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 10. Emissions Point 005: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control that reduces uncontrolled emissions of NOX and CO from the unit to the emission levels listed in Condition 6, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Emissions Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID 001 Crude oil throughput 109,500 BBL/yr PW Tank 002 Produced water throughput 36,500 BBL/yr Flare 003 Natural gas venting to flare 96.725 MMscf/yr ET#4887 004 Natural gas vented to atmosphere via 393,000 scf/yr emergency tank AIRS ID: 123/9636/001-007 Page 4 of 19 EOG Resources, Inc. 0104 Depa en f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 Generator 005 Natural gas combusted as fuel 13.81 MMscf/yr RICE Engine Truck 006 Crude oil and produced water loading 146,000 BBL/yr Loadout Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate each actual monthly process rate and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID number shall be marked on the subject equipment for • ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. &4.) 15. Points 001, 002, and 003: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Emissions point 006: The loading of crude oil and produced water into truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Emissions points 001, 003, and 005: Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 19. Emission point 002: a. Flares shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare, or by other convenient means approved by the Division, determine whether the flare is operating properly. b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: AIRS ID: 123/9636/001-007 Page 5 of 19 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a flare include, but are not limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its resolution, the date range the control was inoperable, and the produced water production through the battery during the downtime. During control device downtime, emissions shall be considered to be uncontrolled. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 20. Emissions point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site-specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 21. Emissions points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to AIRS ID: 123/9636/001-007 Page 6 of 19 EOG Resources, Inc olor- Depa ' en P Ii Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: X lb benzene = benzene wt.f rac.* lb.mol. * MWgas r lb 1 * 1e6 scf MMscf 379.3 scf lb mod1MMscf 22. Emissions point 003: The owner or operator shall demonstrate compliance with Condition 15, using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5) 23. A source initial compliance test shall be conducted on emissions point 005 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide 24. Point 007: Within one hundred and eighty days (180) after commencement of operation, the permittee shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 25. Point 007: Within one hundred and eighty days (180) after commencement of operation, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 26. Emissions point 005: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. AIRS ID: 123/9636/001-007 Page 7 of 19 • EOG Resources, Inc. olor- Depa en P li Health and Environment Permit No. 12WE1107 ' A it Pollution Control Division Issuance 1 ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 28. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equals or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 29. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 30. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 31. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction AIRS ID: 123/9636/001-007 Page 8 of 19 EOG Resources, Inc. olor- Depa en = P ...Ii Health and Environment Permit No. 12WE1107 _ it Pollution Control Division Issuance 1 permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 32. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 33. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Jacob Sebesta Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for a new synthetic minor E&P facility. AIRS ID: 123/9636/001-007 Page 9 of 19 EOG Resources, Inc. olor- Depa en P li Health and Environment Permit No. 12WE1107 '' • it Pollution Control Division Issuance 1 Notes to Permit Holder r 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/requlations/airreqs/100102aocccommonprovisionsreq.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Are the Uncontrolled emissions Controlled AIRS Emission Rate reportable Emission Rate Point Pollutant CAS # BIN (lb/yr) ? (lb/yr) Benzene 71432 A 188 Yes 9 001 n-Hexane 110543 C 1254 Yes 63 Benzene 71432 A 256 Yes 13 002 n-Hexane 110543 C 803 No 40 Benzene 71432 A 7,257 Yes 363 Toluene 108883 C 5,480 Yes 274 003 Ethylbenzene 100414 C 921 No 46 Xylenes 1330207 C 2,276 Yes 114 n-Hexane 110543 C 44,494 Yes 2,225 Benzene 71432 A 30 No 30 004 n-Hexane 110543 C 142 No 142 Formaldehyde 5000 A 1030 Yes 1030 005 Acetaldehyde 75070 A 163 Yes 163 Acrolein 107028 A 100 Yes 100 Benzene 71432 A 46 No 46 006 n-Hexane 110543 C 311 No 311 Benzene 71432 A 5 No 5 007 n-Hexane 110543 C 250 No 250 AIRS ID: 123/9636/001-007 Page 10 of 19 .. .EOG Resources, Inc. , , olori Depa en .1 P .Ili 'Health and Environment Permit No. 12WE1107 it % ir Pollution Control Division Issuance 1 Fir' 4) The emission levels contained in this permit are based on the following emission factors: Points 001: CAS# Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.2740 lb/bbl 0.0137 lb/bbl E&P Tank Benzene 1.7 x 10'' lb/bbl 8.6 x le lb/bbl E&P Tank n-Hexane 1.1 x 10-4 lb/bbl 5.7x 10-4 lb/bbl E&P Tank Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. These emission factors were developed using sampling from the Critter Creek 2- 03H well site and the E&P Tank model. Point 002: CAS# Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 Benzene 0.007 lb/bbl 3.5 x 10-41b/bbl PS Memo 09-02 n-Hexane 0.022 lb/bbl 0.0011 lb/bbl PS Memo 09-02 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 003: Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source Ib/MMscf Ib/MMscf natural gas natural gas vented vented NOx 105.33 105.33 AP-42, Table 13.5-1 and 1549 Btu/scf CO 573.13 573.13 AP-42, Table 13.5-1 and 1549 Btu/scf VOC 46.18 33,643 1,682.1 Eng. Calculation 71432 Benzene 0.1029 75.028 3.7514 End. Calculation 108883 Toluene 0.0777 56.6516 2.8326 Eng. Calculation 100414 Ethylbenzene 0.0131 9.5245 0.4762 Eng. Calculation 1330207 Xylenes 0.0323 23.5311 1.1766 Eng. Calculation 110543 n-Hexane 0.6300 459.83 22.992 Eng. Calculation 540841 2,2,4-TMP 0.0001 0.9042 0.0452 Eng. Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 10, 2010 analysis of a gas sample collected from the Critter Creek 2-03-H well (weight percents for VOC and HAP components from this analysis are listed in the table above). The controlled VOC and HAP emissions factors for point 003 are based on the flare control efficiency of 95%. Point 004: Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf natural gas vented AIRS ID: 123/9636/001-007 Page 11 of 19 EOG Resources, Inc. olor. .Depa en f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf natural gas vented VOC 46.18 33,643 -- Eng. Calculation 71432 Benzene 0.1029 75.028 -- Eng. Calculation 110543 n-Hexane 0.6300 459.83 -- Eng. Calculation The emission levels in this permit for this point are based on the use of this tank to blowdown produced natural gas when the flare used to combust the natural gas is down at three (3) events per year and twelve (12) hours of venting through this tank per event at a maximum gas flow rate of 10,926 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well (weight percents for VOC and HAP components from this analysis are listed in the table above). Point 005: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 2.2100 9.4200 0.2345 1.0000 CO 3.7200 15.9000 0.4691 2.0000 VOC 0.1642 0.7000 0.1642 0.7000 5000 Formaldehyde 0.0528 0.2251 0.0528 0.2251 75070 Acetaldehyde 0.0084 0.0356 0.0084 0.0356 107028 Acrolein 0.0051 0.0219 0.0051 0.0219 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site-rated horsepower value of 237, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx AP-42; Table 3.2-3 (7/2000); Manufacturer Data Natural Gas CO AP-42; Table 3.2-3 (7/2000); Manufacturer Data Natural Gas VOC Manufacturer Data Manufacturer Data 5000 Formaldehyde AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-2 (7/2000); No Control Natural Gas Point 006: Note: The emission factor below may be used for both crude oil and produced water loading. Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 0.0936 lb/bbl -- AP-42 AIRS ID: 123/9636/001-007 Page 12 of 19 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source 71432 Benzene 0.0003 lb/bbl -- AP-42 110543 n-Hexane 0.0021 lb/bbl -- AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 4.34 psia M (vapor molecular weight) = 35.99 lb/lb-mol T (temperature of liquid loaded) = 524 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP determined in the pressurized oil analysis by the VOC emission factor. Point 007: Water/Oil Component Gas Service Heavy Oil Light Oil Service Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% --- Toluene Content(wt%) 0.039% --- 0.075% --- Ethylbenzene (wt%) 0.002% --- 0.017% --- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content 0.336% --- 2.'43% --- (wt%) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Water/Oil Component Gas Service Heavy Oil Light Oil Service Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 AIRS ID: 123/9636/001-007 Page 13 of 19 EOG Resources, Inc. ' olorl Depa en f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. 5) Point 005: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on January 23, 2017. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of VOC, Total HAP, and n-Hexane PSD Synthetic Minor Source of VOC Major Source Requirements: Not Applicable (True Minor Source of HAP MALT HH for MACT HH) Area Source Requirements: Not Applicable (Area source requirements only apply to TEG dehydrators) 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources • NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ— Subpart MMMMM MACT 63.8980-End Subpart NNNNN — Subpart XXXXXX 9) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oiloaspermittincthtml AIRS ID: 123/9636/001-007 Page 14 of 19 EOG Resources, Inc. olor Depa en- f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 1,2011 2.Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3.,Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios,Regulation No. 3, Part B,Construction Permits, and Regulation No. 3,Part D,Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS,and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent"is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day,that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement,the manufacturer, date of manufacture,model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer,model number,horsepower, and serial number of the replacement engine. In addition to the log,the permittee shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer,model, and horsepower or a different manufacturer,model, or horsepower as the existing engine without modifying,this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. 2.1.2 The permittee may permanently replace the existing compressor engine with another engine with the same manufacturer,model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any AIRS ID: 123/9636/001-007 Page 15 of 19 EOG Resources, Inc. olor. Depa en sf P .Ii Health and Environment Permit No. 12WE1107 . sir Pollution Control Division Issuance 1 new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice(APEN)that includes the specific manufacturer,model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry,the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances,please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period(i.e. if the permit requires quarterly portable analyzer testing,this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide(NOX)and carbon monoxide(CO)emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol(ver March 2006 or newer). Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual(tons/year)or short term(lbs/unit of time)emission limit,the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760),whichever applies. For comparison with a short-term limit that is either input based(Ib/mmBtu), output based(g/hp-hr)or concentration based(ppmvd @ 15%O2)that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. AIRS ID: 123/9636/001-007 Page 16 of 19 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 If the portable analyzer results indicate compliance with both the NOX and CC)emission limitations, in the absence of credible evidence to the contrary,the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S.25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations,the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3,Part B §II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology(RACT)for the pollutants for which the area is attainment/maintenance or nonattainment.Note that both VOC and NOX are precursors for ozone.RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area,RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS,the following shall be considered RACT for naturalgas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331)and 40 CFR Part 72 (§72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E(State-Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non-selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements AIRS ID: 123/9636/001-007 Page 17 of 19 EOG Resources, Inc olorl Depa en P li Health and Environment Permit No. 12WE1107 it Pollution Control Division Issuance 1 • • Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall subniit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ.An analysis of applicable monitoring,recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2.Any testing required by the NSPS is in addition to that required by this AOS.Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source,subject to the requirements of Regulation No. 6 (i.e.,the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, §1B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine(RICE)MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ.An analysis of the applicable monitoring,recordkeeping,and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS.Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit,not"routine replacement" of an existing unit.The AOS is therefore essentially an advanced AIRS ID: 123/9636/001-007 Page 18 of 19 EOG Resources, Inc. olor- Depa en f P li Health and Environment Permit No. 12WE1107 A,. it Pollution Control Division Issuance 1 construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9636/001-007 Page 19 of 19 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3445 Source Name: Fox Creek 6-33H Source Location: NWNW Sec. 33, T12N, R63W, approximately 13 miles northwest of Grover Point 001 -Six(6)400 BBL fixed roof crude oil storage tanks Point 002 -One (1)400 BBL produced water storage tank Point 003 - One (1)400 BBL emergency tank used for natural gas blowdowns when the open flare shuts down Equipment Description: Point 004 One (1) Tornado Flare Point 005 - One (1) Power Solutions International 237hp generator engine Point 006 - Crude oil and produced water truck loadout Point 007 - Fugitive equipment leaks AIRS ID: 123-9403 Date: December 21, 2011 Review Engineer: Jacob Sebesta Control Engineer: Chris Laplante Section 2 —Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 10/12/2011 Section 4-Source Description AIRS Point Equipment Description 001 Six (6) 400 BBL fixed roof crude oil storage tanks 002 One (1)400 BBL produced water storage tank 003 • One (1)400 BBL emergency tank used for natural gas blowdowns when the open flare shuts down Page 1 004 Point 004 - One (1)Tornado Flare 005 One (1) Power Solutions International 237hp generator engine 006 Crude oil and produced water truck loadout 007 Fugitive equipment leaks Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? If"yes", for what pollutant? PM10 CO Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes" the provisions of Regulation 7, Sections XII and XVII.C may Yes No apply) Section 5—Emission Estimate Information AIRS Point Emission Factor Source Source used E&P Tank model and sampling to develop site-specific emission factors in lb/bbl units. Note: the sampling was completed at the Critter Creek 2- 001 03H site rather than this one. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 0.1407 lb/bbl 002 State default emission factors for produced water tanks in Weld County Emission Factors for NOx, SOx, CO and PM10 from AP-42 Tables 13.5-1&2 003 VOC emissions are based on a VOC weight-fraction as for Point 002. VOC E.F.= 33627 Ib/MMscf vented Maximum gas vented to atmosphere along with VOC weight fraction to determine a site-specific emission factor. Note: the sampling was completed at the Critter 004 Creek 2-03H site rather than this one. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 33627 lb/MMscf vented 005 AP-42, Table 3.2-3 for uncontrolled emissions Manufacturer's data for controlled NOX, CO, and VOC emissions 006 AP-42, Table 5.2-1, equation 1 007 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTEI AIRS Point Process Consumption/Throughput/Production 001 131,400 BBL per year(109,500 x 1.2) 002 73,000 BBL produced water throughput/yr 003 0.375 MMscf/yr (10,416.7 scf/hr x 3 events x 12 hours/event) Page 2 004 91.25 MMscf/yr(0.25 MMscf/d) natural gas venting 005 13.8 MMscf/yr natural gas combusted as fuel 006 182,500 BBL crude oil and produced water throughput/yr Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 576 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 007 Other 35 --- 15 6 VOC Content(wt%) a5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% --- Toluene Content(wt%) 0.039% --- 0.075% --- Ethylbenzene (wt %) 0.002% --- 0.017% Xy/enes Content(wt%) 0.01% --- 0.036% --- n-hexane Content (wt%) 0.336% --- 2.43% --- Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 109,500 BBL Crude oil throughput 2011 Basis for Permitted Emissions (Permit Limits} AIRS Point Process Consumption/Throughput/Production 001 131,400 BBL per year(109,500 x 1.2) 002 73,000 BBL produced water throughput/yr 003 0.375 MMscf/yr(10,416.7 scf/hr x 3 events x 12 hours/event) 004 91.25 MMscf/yr(0.25 MMscf/d) natural gas venting 005 13.8 MMscf/yr natural gas combusted as fuel 006 182,500 BBL crude oil and produced water throughput/yr Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 576 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 007 Other 35 --- 15 6 VOC Content(wt%) _ 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% Toluene Content(wt%) 0.039% 0.075% Ethy/benzene (wt%) 0.002% 0.017% --- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content(wt%) 0.336% --- 2.43% --- Does this source use a control device? X Yes No % Reduction AIRS Point Process Control Device Description Granted 001 01 Cimarron Smokeless Combustor(vapor combustion unit 95 [VCU]) Page 3 002 01 Cimarron Combustor(vapor combustion unit [VCU]) 95 . 004 01 Tornado, 40' Flare Stack, SN: C0CSADA3XS0526059 95 005 01 NSCR Catalyst with AFRC NOX: 94.3 CO: 87.4 Section 6 - Emission Summary Uncontrolled (PTE) Emissions (tons per year) AIRS NOx VOC Fugitive CO Reportable Total Point VOC HAPs HAPs 001 7.7 0.1 0.5 002 9.6 1.1 1.1 003 6.3 0.0 0.1 004 4.8 1,535.0 26.1 28.0 28.5 005 21.6 1.6 36.3 0.6 0.7 006 9.5 0.0 0.1 007 2.4 0.0 0.0 Total 26.4 1,569.6 2.4 62.4 29.8 31.0 Controlled Emissions (tons per year) AIRS NOx VOC Fugitive CO Reportable Total Point VOC HAPs HAPs 001 0.4 0.0 0.0 002 0.5 0.1 0.1 003 6.3 0.0 0.1 004 4.8 76.7 26.1 1.4 1.4 005 2.3 1.6 4.6 0.6 0.7 006 9.5 0.0 0.1 007 2.4 0.0 0.0 Total 7.1 95.0 2.4 30.7 2.1 2.4 Section 7— Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable? Rate(Ib/yr) POINT 001 Benzene 71432 A 100 Yes 5 Toluene 108883 C 88 No 4 n-Hexane 110543 C 666 No 33 POINT 002 Benzene 71432 A 511 Yes 26 Page 4 n-Hexane 110543 C 1606 Yes 80 POINT 003 Benzene 71432 A 28 No 28 Toluene 108883 C 21 No 21 Ethylbenzene 100414 C 4 No 4 Xylenes 1330207 C 9 No 9 n-Hexane 110543 C 172 No 172 POINT 004 Benzene 71432 A 6841 Yes 342 Toluene 108883 C 5165 Yes 258 Ethylbenzene 100414 C 868 No 43 Xylenes 1330207 C 2146 Yes 107 n-Hexane 110543 C 41926 Yes 2096 2,2,4-Trirpethylpentane 540841 C 82 No 4 POINT 005 Formaldehyde 5000 A 1030 Yes 1030 Acetaldehyde 75070 A 163 Yes 163 Acrolein 107028 A 100 Yes 100 POINT 006 Benzene 71432 A 1707 Yes 85 n-Hexane 110543 C 5364 Yes 268 POINT 007 Benzene 71432 A 5 No 5 n-Hexane 110543 C 250 No 250 Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Section 9—Source Classification Is this a new previously un-permitted X Yes No source? What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what X Title V X PSD NA NSR X MACT programs? Is this a modification to an existing Yes X No permit? Synthetic If"yes"what kind of modification? Minor Major Minor Page 5 Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Regulation 1 - Particulate,Smoke Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which 001-007 is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner 001, 002, or operator of a smokeless flare or other flare for the combustion of waste gases shall and 004 allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-007 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3 -APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements 001-007 Applicant is required to file an APEN for these points because uncontrolled emissions exceed 2 tons per year VOC. Part B—Construction Permit Exemptions 001-007 Applicant is required to obtain a permit for points 001-006 since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part B, Section II.D.3.a). Part B, III.D.2 - RACT requirements for new or modified minor sources located in ozone 001-007 non-attainment areas This source is not subject to this requirement because it is located in an ozone attainment area. Regulation 6 New Source Performance Standards 001, 002, NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 003 These tanks are not subject to NSPS Kb because they each have a capacity less than 471 BBL (19,800 gal). Page 6 Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is not subject to the emission control requirements for condensate tanks because this facility is located in an attainment area. 001, 002 XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is not subject to this section because these tanks store crude oil rather than condensate (API Gravity is less than 40). 006 VI. Storage and Transfer of Petroleum Liquid This source is not subject to section VI because it does not store or transfer gasoline. Regulation 8—Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution 001, 002, This source is not subject to MACT EEEE because it is located at a"production field 006 facility" as defined in 40 CFR 63.761 (located upstream of the natural gas processing plant). MACT HH 001 This source is not subject to MACT HH because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Pollutant! Fugitive Emission Control Point Process Process Description Emission Factor CAS# (YIN) Factor Source (%) 3.3494 lb/1000 V0C No E&P Tank 95 gallons throughput Model 01 E&P Crude Oil 0.0217 lb/1000 Benzene No E&P Tank 95 001 Storage Tanks gallons throughput Model 0.1448 lb/1000 n-Hexane No E&P Tank 95 gallons throughput Model SCC 40400312—Fixed Roof Tank, Crude Oil,working+breathing+flashing losses Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 6.2381 lb/1000 V0C No State Default 95 gallons throughput EF E&P Produced 0.1667 lb/1000 State Default 01 Water Storage gallons throughput Benzene No EF 95 002 Tanks 0.5238lb/1000 State Default gallons throughput n-Hexane No 95 EF SCC 40400315—Fixed Roof Tank, Produced Water, working+breathing+flashing Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 01 Natural gas 33642.97 lb/MMscf VOC No Mass Balance NA 003 blowdown venting vented SCC 31000299— Natural Gas Production: Other not classified Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 33642.97 Ib/MMscf V0C No Mass Balance 95 vented 75.0282 Ib/MMscf Benzene No Mass Balance 95 vented 56.6516 Ib/MMscf Toluene No Mass Balance 95 004 01 Produced gas vented vented to flare 23.5311 Ib/MMscf Xylenes No Mass Balance 95 vented 460.006 Ib MMscf n-Hexane No Mass Balance 95 vented 105.331b/MMscf N0x No AP-42 NA vented Page 7 573.13 lb/MMscf CO No AP-42 NA vented SCC 31000205— Flares (at gas production facility) Point Process Process Description Emission Factor Pollutant/ Fugitive Emission Control CAS# (Y/N) Factor Source (%) 3122.73 lb/MMscf NOX No Manufacturer 89 231.978 lb/MMscf VOC No Manufacturer NA 5256.36 lb/MMscf CO No Manufacturer 87 01 NG-fired RICE Formaldehyde 005 74.6064 lb/MMscf /5000 No AP 42 NA 11.8127 lb/MMscf Acetaldehyde/ No AP-42 NA 75070 7.2628 lb/MMscf Acrolein/ No AP-42 NA 107028 SCC 20200256— Internal combustion engine, Natural gas, Four stroke-rich burn Point Process Process Description Emission Factor Pollutant/ Fugitive Emission Control CAS# (YIN) Factor Source (%) 2.47 lb/1000ga1 VOC No AP-42 NA Crude Oil and Produced 0.0167 01 Water Tank Truck lb/1000gal Benzene No AP-42 NA 006 Loadout 0.0976 b/1000ga1 n-Hexane No AP-42 NA SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# ust Factor Source (%) 01 Fugitive equipment 4720 lb/yr VOC No EPA-453/R-95- 0 007 leaks017,Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14— Miscellaneous Application Notes AIRS Point 001 Crude Oil Tanks These tanks store crude oil with an API gravity less than 40 degrees. EOG collected a pressurized oil analysis and calculated flash emissions from this tank battery using E&P Tank. Without emission controls and federally enforceable emission limits for this point, this facility would be considered a major source of VOC for Operating Permit applicability. In order to obtain synthetic minor limits and avoid Operating Permit applicability, EOG will not take advantage of the categorical permit exemption in Regulation 3, Part B, Section II.D.1.n for crude oil storage tanks with capacities less than 40,000 gallons. AIRS Point 002 Produced Water Storage Tanks EOG used the state default emission factors to calculate emissions from this produced water storage tank battery. Without emission controls and federally enforceable emission limits for this point, this facility would be considered a major source of VOC for Operating Permit applicability. In order to obtain synthetic minor limits and avoid Operating Permit applicability, EOG will not take advantage of the categorical permit exemption in Regulation 3, Part B, Section II.D.1.m for tanks used to store produced water that is less than 1% oil by volume. Page 8 AIRS Point 003 Emergency Tank In case of a flare outage (AIRS point 004), produced natural gas from this site will be routed to this Emergency Tank. Entrained liquids settle in the tank and the gas will be vented to atmosphere. EOG based emissions from this activity on a gas flow rate of 10,417 scf/hr and three venting events per year at 12 hours per event. The composition of the vented gas has the same basis as was used to calculate emissions routed to the flare (point 004). AIRS Point 004 Tornado Flare The tornado flare controls gas coming off the three-phase separator at this site since there is no pipeline available in the area at this time. EOG will continue to flare gas until a pipeline is available. AIRS Point 005 Generator Engine Based on a manufacture date of January 3, 2011, this engine is subject to emission standards in NSPS JJJJ. Therefore, this engine is not subject to Regulation 7, Section XVII.E. The construction permit will require stack testing to verify the emission rates stated in the application. The emission rates stated in the certificate of conformity (EPA) are based on an engine with a catalyst for emissions control installed. AIRS Point 006 Truck Loadout of Crude Oil and Produced Water AP-42: Chapter 5.2 Equation 1 L = 12.46*S*P*M/T L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors[lb/lb-mole] T = temperature of bulk liquid loaded [deg. R] S 0.6 Submerged loading: dedicated normal service P 5.18 psia M 33.54 lb/lb-mole for gasoline with RVP = 11.5 524 deg. R (64 deg. F) L 2.481b/10^3 gal nnual requested Throughput 7,665,000gal/yr nnual requested VOC emissions 9.5tpy Page 9 - Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit r. , OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERYy ` e Current Status(Chet all that apply) . Reason for APEN Submittal(Check all that apply) 0CT 12 1 AIRS in#': i231g403e&, ❑ APEN update only4 ❑ New or previously unreported battery O Modification to existing sources r ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GPOI. .. ❑ Synthetic minor facility &cancellation request for individual permit: ❑ Located in the 8-hr Ozone Control Area' 0 Application for or Modification of an individual permit ❑ Registered under general permit no.GPOI O Administrative permit amendment' I[ ❑ Permitted under individual permit: , .,, , 5 O Other: For individual permit applications,check if you wants: O A copy of the preliminary analysis conducted by the Division ❑To review-a draft of the permit prior to issuance Company Names: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address1s: 600 l7`"Street,Suite 1000N david_long@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303-262-9448 _ Fax: 303-262-9449 Tank Battery Name": Fox Creek 6-33H _ Number of tanks: 6 Location12(QQ Sec.Twp.Range.): NWNW Sec 33,TI2N,R63W County: Weld _ Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies"3: 2011 Year(s)tank(s)were placed in service°: 2011 Control Descriptions: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency'6: 95% Condensate Throughput"[bbl/year] Requested's: 109,500 Maximum for PTE calculation1°: 131,400 Actual20: 109,500 While Controls Operational" 109,500 Other equipment at facility": VCU,flare,heater treater,generator engine, line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPOI coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use N/A for requested thraughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions'-3. Emission Factor Battery Requested Emission's Actual Emissions'° Pollutant'° [lb/bbl] PTE's Uncontrolled" Controlled" Uncontrolled'6 Controlled2° VOC[tons/year] 0.1407 9.2 N/A N/A 7.7 0.39 NOx[tons/year] N/A 0.03 0.03 0.03 CO [tons/year] N/A 0.15 0.15 0.15 Benzene[lbs/year] 100.0 5.0 n-Hexane[lbs/year] - 666.0 33.3 Wells serviced by this tank or tank battery's APT#: 05-123-31558-00 Name: Fox Creek 6-33H 0 Newly Reported Well •API#: Name: ❑Newly Reported Well 9#: Name: O Newly Reported Well "' I#: Name: O Newly Reported Well w 10 I#: Name O Newly Reported Well ';; a w I#: Name: O Newly Reported Well o I#: Name: ❑Newly Reported Wels,,"l O b :signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of „y knowledge and belief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated to lig compliance�� }r with eac a9ndition of general permit GPOI. H nature`oftegally Authorized Person(not a vendor or consultant) Date I � F, a-" vid Long Division Environmental Manager o pe or Print Name of Person Signing Above Official Title Ht n 3mit this form,along with$152.90 for each Colorado Department of Public Health and Envi onment ` For information call: o r-T 303 692-3150 F, rig of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 ' ( ) i0 General Permit fee for each new GP 4300 Cherry Creek Drive South - pe0 Th( 262321 istration to: Denver,CO 80246-1530 L.--, v �_ N 'ORNI APCD-205 Page 1 of 2 EOG FC 6-33H FormAPCD-205-E&PCondensateTankAPEN.docx N N 40) 0 .a asp 44 61 « o f - o. O 6. c m a• `o s. A o°`f. 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O T X Sc O O cc rn x z ® W o m a o m �, •� a W F W c ¢T' v m v U w O a > 0 - v m _ V] Cl) (%� ': STATE OF COLORADO pF co, COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT a�e AIR POLLUTION CONTROL DIVISION ° TELEPHONE: (303)692-3150 « • *1876* CONSTRUCTION PERMIT PERMIT NO: 11WE3445 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas production facility, known as Fox Creek 6-33H, located at NWNW Section 33, Township 12N, Range 63W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID 001 Six (6) 400 BBL fixed roof storage tanks used to store crude oil. Emissions from these tanks are controlled by an enclosed flare. PW Tank 002 One (1) 400 BBL fixed roof storage tank used to store produced water. Emissions from this source are routed to an enclosed flare. One (1) 400 BBL well blowdown tank (Manufacturer: JTM Equip, ET #4619 003 Model: EOG #4619, Serial No: 11-056) used to catch liquids and vent gas during emergencies when the produced gas cannot be combusted in the flare (AIRS point 004). One (1) Open flame flare (Manufacturer: Tornado, Model No: 40' Flare 004 Flare Stack, Serial No: 10856-11) used to combust produced natural gas vented from a three-phase separator. One (1) Power Solutions, Inc., Model 8.1L (D081TIC), Serial Number EEPOG 006758, natural gas-fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 237 horsepower at 1800 RPM. This engine shall be equipped with a . non-selective catalytic reduction (NSCR) system and air-fuel ratio Generator control.This emission unit is used to generate power for the facility. RICE 005 Engine This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Power Solutions, Inc. 8.1 L (D081TIC) engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. AIRS ID: 123/9403/001-007 Page 1 of 20 EOG Resources, Inc. olor- Depa en P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 • Facility AIRS Equipment Point Description ID Truck 006 Truck loadout of crude oil and produced water. Loadout Fugitive 007 Equipment leaks (fugitive VOCs) from a natural gas production facility. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (H) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 5.0 tons per year of volatile organic compounds (VOC), -OR- AIRS ID: 123/9403/001-007 Page 2 of 20 EOG Resources, Inc. olor- Depa en f P li Health and Environment Permit No. 11WE3445 A it Pollution Control Division Issuance 1 Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: • 100 tons per year of volatile organic compounds (VOC), 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Equipment AIRS Tons per Year Emission Type ID Point NO, V0C CO 001 -- 0.4 -- Point PW Tank 002 -- 0.5 -- Point ET#4619 003 -- 6.3 -- Point Flare 004 4.8 76.7 26.1 Point Generator RICE 005 2.3 1.6 4.6 Point Engine Truck Loadout 006 -- 9.5 -- Point Fugitives 007 -- 2.4 -- Fugitive See "Notes to Permit Holder #4" for information on emission factors and methods, used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Emissions Point 001: Emissions from this point shall be routed to an enclosed vapor combustion unit (VCU) that reduces uncontrolled emissions of V0C from the crude oil tanks to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. Emissions Point 004: Emissions from this point shall be routed to an open-flame flare that reduces emissions of VOC to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) AIRS ID: 123/9403/001-007 Page 3 of 20 EOG Resources, Inc. olor Depa en P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 9. Emissions Point 002: Emissions from this point shall be routed to an enclosed flare that reduces emissions of VOC to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan: (Reference: Regulation No.3, Part B, Section III.E.) 10. Emissions Point 005: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control that reduces uncontrolled emissions of NOX and CO from the unit to the emission levels listed in Condition 6, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Emissions Point 007: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID 001 Crude oil throughput 109,500 BBL/yr PW Tank 002 Produced water throughput . 73,000 BBL/yr ET#4619 003 Natural gas vented to atmosphere via 375,000 scf/yr emergency tank Flare 004 Natural gas venting to flare 91.25 MMscf/yr Generator 005 Consumption of natural gas as a fuel 13.81 MMscf/yr RICE Engine Truck 006 Crude oil and produced water loading 182,500 BBUyr Loadout Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate each actual monthly process rate and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) AIRS ID: 123/9403/001-007 Page 4 of 20 • EOG Resources, Inc. olorl Depa en f P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section H A.1. &4.) 15. Points 001, 002, and 004: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Emissions point 006: The loading of crude oil and produced water into truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Emissions points 001, 004, 005: Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 19. Emission point 002: a. Flares shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare, or by other convenient means approved by the Division, determine whether the flare is operating properly. b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable AIRS ID: 123/9403/001-007 Page 5 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a flare include, but are not limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its resolution, the date range the control was inoperable, and the produced water production through the battery during the downtime. During control device downtime, emissions shall be considered to be uncontrolled. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 20. Emissions point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site-specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 21. Emissions points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: X lb benzene = benzene wt.f rac.* lb.mol. * 11'/W f lb 1 * le6 scf MMscf 379.3 scf gas lb?nod1MMscf. 22. Emissions point 004: The owner or operator shall demonstrate compliance with Condition 15, using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5) 23. Emissions point 005: A source initial compliance test shall be conducted on emissions point 005 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and AIRS ID: 123/9403/001-007 Page 6 of 20 EOG Resources, Inc. olor- Depa en .f P •Ii Health' and Environment Permit No. 11WE3445 �. it Pollution Control Division Issuance 1 approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide 24. Point 007: Within one hundred and eighty days (180) after commencement of operation, the permittee shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 25. Point 007: Within one hundred and eighty days (180) after commencement of operation, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 26. Emissions point 005: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or AIRS ID: 123/9403/001-007 Page 7 of 20 EOG Resources, Inc. olor Depa en P li Health and Environment Permit No. 11 WE3445 it Pollution Control Division Issuance 1 d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 28. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equals or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 29. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 30. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 31. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 32. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 33. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. AIRS ID: 123/9403/001-007 Page 8 of 20 EOG Resources, Inc. olor- Depa en f P li Health and Environment Permit No. 11WE3445 A it Pollution Control Division Issuance 1 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Jacob Sebesta Permit Engineer Permit History Issuance • Date Description Issuance 1 This Issuance Facility-wide permit for a new synthetic minor E&P facility. AIRS ID: 123/9403/001-007 Page 9 of 20 EOG Resources, Inc. , olor- ik Depa en f P li Health and Environment Permit No. 11WE3445 �_ it Pollution Control Division Issuance 1 Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are • based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/requlations/airreqs/100102agcccommonprovisionsreq.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS# BIN (Ib/yr) reportable? (Ib/yr) Benzene 71432 A 100 Yes 5 • 001 Toluene 108883 C 88 No 4 n-Hexane 110543 C 666 No 33 Benzene 71432 A 511 Yes 26 002 n-Hexane 110543 C 1606 Yes 80 Benzene 71432 A 28 No 28 Toluene 108883 C 21 No 21 003 Ethylbenzene 100414 C 4 No 4 Xylenes 1330207 C 9 No 9 n-Hexane 110543 C 172 No 172 Benzene 71432 A 6841 Yes 342 Toluene 108883 C 5165 Yes 258 Ethylbenzene 100414 C 868 No 43 004 Xylenes 1330207 C 2146 Yes 107 n-Hexane 110543 C 41926 Yes 2096 2,2,4- 540841 C 82 No 4 Trimethylpentane Formaldehyde 5000 A 1030 Yes 1030 005 Acetaldehyde 75070 A 163 Yes 163 Acrolein 107028 A 100 Yes 100 AIRS ID: 123/9403/001-007 Page 10 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11 WE3445 it Pollution Control Division Issuance 1 Benzene 71432 A 1707 Yes 85 006 n-Hexane 110543 C 5364 Yes 268 Benzene 71432 A 5 No 5 007 n-Hexane 110543 C 250 No 250 4) The emission levels contained in this permit are based on the following emission factors: Points 001: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.1407 lb/bbl 0.0070 lb/bbl E&P Tank Benzene 9.1 x 10' lb/bbl 4.6 x 10-' lb/bbl E&P Tank _ n-Hexane 0.0061 lb/bbl 3.0 x 10-° lb/bbl E&P Tank Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. These emission factors were developed using sampling from the Critter Creek 2- 03H well site and the E&P Tank model. Point 002: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 Benzene 0.007 lb/bbl 3.5 x 10-4 lb/bbl PS Memo 09-02 n-Hexane 0.022 lb/bbl 0.0011 lb/bbl PS Memo 09-02 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 003: Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf natural gas vented VOC 46.18 33,642 -- Eng. Calculation 71432 Benzene 0.1030 75.028 -- Eng. Calculation 110543 n-Hexane 0.6315 460.006 -- Eng. Calculation The emission levels in this permit for this point are based on the use of this tank to blowdown produced natural gas when the flare used to combust the natural gas is down at three (3) events per year and twelve (12) hours of venting through this tank per event at a maximum gas flow rate of 10,419 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well (weight percents for VOC and HAP components from this analysis are listed in the table above). Point 004: Natural Gas Emission Emission CAS# Pollutant Composition Factors Factors Source (Weight%) Uncontrolled Controlled AIRS ID: 123/9403/001-007 Page 11 of 20 EOG Resources, Inc. olor Depa en P li Health and Environment • Permit No. 11WE3445 it Pollution Control Division Issuance 1 lb/MMscf lb/MMscf • • natural gas natural gas vented vented NOx -- 105.33 105.33 AP-42, Table 13.5-1 and 1549 Btu/scf CO ' -- 573.13 573.13 AP-42, Table 13.5-1 and 1549 Btu/scf VOC 46.18 33,642 1,682.1 Eng. Calculation 71432 Benzene 0.1030 75.028 3.7514 Eng. Calculation 108883 Toluene 0.0778 56.6516 2.8326 Enq. Calculation 100414 Ethylbenzene 0.0131 9.5245 0.4762 Eng. Calculation 1330207 Xylenes 0.0323 23.5311 1.1766 Enq. Calculation 110543 n-Hexane 0.6315 460.006 23.000 Eng. Calculation 540841 2,2,4-TMP 0.0012 0.9042 0.0452 Eng. Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 10, 2010 analysis of a gas sample collected from the Critter Creek 2-03-H well (weight percents for VOC and HAP components from this analysis are listed in the table above). The controlled VOC and HAP emissions factors for point 003 are based on the flare control efficiency of 95%. Point 005: Emission Factors - Emission Factors— Uncontrol led Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 2.2100 9.4200 0.2345 1.0000 CO 3.7200 15.9000 0.4691 2.0000 VOC 0.1642 0.7000 0.1642 0.7000 5000 Formaldehyde 0.0528 0.2251 0.0528 0.2251 75070 Acetaldehyde 0.0084 0.0356 0.0084 0.0356 107028 Acrolein 0.0051 0.0219 0.0051 0.0219 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site-rated horsepower value of 237, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx AP-42; Table 3.2-3 (7/2000); Manufacturer Data Natural Gas CO AP-42; Table 3.2-3 (7/2000); Manufacturer Data Natural Gas VOC Manufacturer's Data Manufacturer Data 5000 Formaldehyde AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-2 (7/2000); No Control Natural Gas Point 006: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 0.104 lb/bbl -- AP-42 AIRS ID: 123/9403/001-007 Page 12 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source 71432 Benzene 0.0007 lb/bbl - AP-42 108883 Toluene 0.0023 lb/bbl - AP-42 1330207 Xylenes 0.0030 lb/bbl - AP-42 110543 n-Hexane 0.0041 lb/bbl ••- AP-42 Note: The emission factor below may be used for both crude oil and produced water loading. The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.18 psia M (vapor molecular weight) = 33.43 lb/lb-mol T (temperature of liquid loaded) = 524 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP determined in the pressurized oil analysis by the VOC emission factor. Point 007: Water/Oll Component Gas Service Heavy Oil Light Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% --- Toluene Content(wt%) 0.039% --- 0.075% -- Ethylbenzene (wt%) 0.002% --- 0.017% -- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content 0.336% --- 2.43% --- (wt%) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8,4E-06 2.5E-03 9.8E-05 AIRS ID: 123/9403/001-007 Page 13 of 20 EOG Resources, Inc. olor. Depa en f P li Health and Environment Permit No. 11WE3445 A it Pollution Control Division Issuance 1 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission • factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on October 11, 2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) Point 005: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.qov/ttn/atw/area/fr18ia08.pdf 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of VOC and n-Hexane PSD Synthetic Minor Source of VOC Major Source Requirements: Not Applicable (True Minor Source of HAP MACT HH for MACT HH) Area Source Requirements: Not Applicable (Area source requirements only apply to TEG dehydrators) Major Source Requirements: Not Applicable (True Minor Source of HAP MACT Z777 for MACT Z777) Area Source Requirements: Apply 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End SubpartA— SubpartKKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 - Subpart A— Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE— Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX AIRS ID: 123/9403/001-007 Page 14 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 9) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdohe.state.co.us/apioilbaspermittinghtml • AIRS ID: 123/9403/001-007 Page 15 of 20 EOG Resources, Inc. olor- Depa en P li Health and Environment Permit No. 11WE3445 A, it Pollution Control Division Issuance 1 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 1, 2011 2.Alternative Operating Scenarios The following Alternative Operating Scenario (AOS)for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9403/001-007 Page 16 of 20 EOG Resources, Inc. ' olor-r Depa en f P Ii Health and Environment Permit No. 11WE3445 it Pollution Control Division • Issuance 1 2.1.2 The permittee may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine.Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer). Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9403/001-007 Page 17 of 20 EOG Resources, Inc. olor- Depa en .1 P •li Health and Environment • Permit No. 11WE3445 • •it Pollution Control Division Issuance 1 For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for naturalgas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9403/001-007 Page 18 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11WE3445 it Pollution Control Division Issuance 1 Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: - Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500cHp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § LB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9403/001-007 Page 19 of 20 EOG Resources, Inc. olor- Depa en f P li Health and Environment • Permit No. 11WE3445 ' it Pollution Control Division Issuance 1 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9403/001-007 Page 20 of 20 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number 11WE3414 Source Name: Critter Creek 7-13H Source Location: NWNW Sec. 13,T11N, R63W, approximately 9 miles northwest of Grover Point 001 - Crude oil and produced water truck loadout Point 002 -One (1) Waukesha 163 hp generator engine Point 003 -One (1)Tornado Flare used to combust produced natural gas Point 004 -One (1)400 BBL emergency tank used for natural gas Equipment Description: blowdowns when the open flare shuts down Point 005 - One (1)400 BBL produced water storage tank Point 006 -Six(6) 400 BBL fixed roof crude oil storage tanks Point 007 - Fugitive equipment leaks AIRS ID: 123/9389 Date: December 28, 2011 Review Engineer: Jacob Sebesta Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3 —Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 9/23/2011 Section 4—Source Description AIRS Point Equipment Description 001 Crude oil and produced water truck loadout 002 One (1)Waukesha 163 hp generator engine 003 One (1) Tornado Flare used to combust produced natural gas 004 One (1) 400 BBL emergency tank used for natural gas blowdowns when the open flare shuts down Page 1 005 One (1)400 BBL produced water storage tank 006 Six (6)400 BBL fixed roof crude oil storage tanks 007 Fugitive equipment leaks Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? If"yes", for what pollutant? PM10 CO Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes" the provisions of Regulation 7, Sections XII and XVII.C may Yes No apply) Section 5— Emission Estimate Information AIRS Point Emission Factor Source 001 AP-42, Table 5.2-1, equation 1 002 Manufacturer's Data for NOX, CO, and VOC AP-42 for HAP Emission Factors for NOx, SOx, CO and PM10 from AP-42 Tables 13,5-1&2 Maximum gas vented to atmosphere along with VOC weight fraction to determine 003 a site-specific emission factor. Note: the sampling was completed at the Critter Creek 2-03H site rather than this one. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 33627 Ib/MMscf vented 004 VOC emissions are based on a VOC weight-fraction as for Point 002. VOC E.F.= 33627 Ib/MMscf vented 005 State default emission factors for produced water tanks in Weld County Source used E&P Tank model and sampling to develop site-specific emission factors in lb/bbl units. Note: the sampling was completed at the Critter Creek 2- 006 03H site rather than this one. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 0.1407 lb/bbl 007 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 182,500 BBL crude oil and produced water throughput/yr 002 9.5 MMscf/yr natural gas combusted as fuel 003 91.25 MMscf/yr(0.25 MMscf/d) natural gas venting 004 0.569 MMscf/yr(15,791.7 scf/hr x 3 events x 12 hours/event) Page 2 005 73,000 BBL produced water throughput/yr 006 131,400 BBL per year(109,500 x 1.2) Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 007 Other 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% -- 0.027% -- Toluene Content(wt%) 0.039% --- 0.075% --- Ethylbenzene (wt%) 0.002% --- 0.017% --- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content(wt%) 0.336% --- 2.43% --- Basis for Actual Emissions Reported During this'APEN Filing (Reported to Inventory) , AIRS Point Process Consumption/Throughput/Production Data Year 001 109,500 BBL Crude oil throughput 2011 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 182,500 BBL crude oil and produced water throughput/yr 002 9.5 MMscf/yr natural gas combusted as fuel 003 91.25 MMscf/yr(0.25 MMscf/d) natural gas venting 004 0.569 MMscf/yr(15,791.7 scf/hr x 3 events x 12 hours/event) 005 73,000 BBL produced water throughput/yr 006 131,400 BBL per year(109,500 x 1.2) Water/Oil Component Gas Service Heavy Oil Light Oil Service Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 -- Valves 56 --- 72 24 007 Other 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% --- Toluene Content(wt%) 0.039% --- 0.075% --- Ethylbenzene (wt %) 0.002% --- 0.017% --- Xylenes Content(wt%) 0.01% --- 0.036% -- n-hexane Content(wt%) 0.336% --- 2.43% - - Does this source use a control device? X Yes No % Reduction AIRS Point Process Control Device Description Granted Page 3 NOX: 93 002 01 NSCR(Catalyst)with AFRC CO: 88 VOC: 65 HCHO: 65 003 01 Tornado,40' Flare Stack, SN: 10856-16 VOC& HAP: 95 005 01 Cimarron Combustor(vapor combustion unit NM]) VOC & HAP: 95 006 at Cimarron Combustor(vapor combustion unit [VCU]) VOC & HAP: 95 Section 6— Emission Summary(tons per year) Uncontrolled (PTE) Emissions AIRS NOx VOC Fugitive CO Reportable Total Point VOC HAPs HAPs 001 9.5 0.0 0.1 002 21.3 3.1 26.8 0.1 0.2 003 4.8 1,535.0 26.1 28.0 28.5 004 9.6 0.0 0.2 005 9.6 1.1 1.1 006 7.4 0.1 0.5 007 2.4 0.0 0.0 Total 26.1 1,574.2 2.4 52.9 29.3 30.6 Controlled Emissions AIRS NOx VOC Fugitive CO Reportable Total Point VOC HAPs HAPs 001 9.5 0.0 0.0 002 1.6 1.1 3.1 0.0 0.1 003 4.8 76.7 26.1 1.4 1.4 004 9.6 0.0 0.2 005 0.5 0.1 0.1 006 0.4 0.0 0.0 007 2.4 0.0 0.0 Total 6.4 97.8' 2.4 29.3 1.5 1.8 Section 7— Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable? Rate(Iblyr) POINT 001 Benzene 71432 A 30 No 1 Page 4 Toluene 108883 C 22 No 1 n-Hexane 110543 C 179 No 9 POINT 002 .., Formaldehyde 5000 A 275 Yes 96 Acetaldehyde 75070 A 37 No 13 Acrolein 107028 A 35 No 12 POINT 003 Benzene 71432 A 6841 Yes 342 Toluene 108883 C 5165 Yes 258 Ethylbenzene 100414 C 868 No 43 Xylenes 1330207 C 2146 Yes 107 n-Hexane 110543 C 41926 Yes 2096 2,2,4-Trimethylpentane 540841 C 82 No 4 POINT 004 Benzene 71432 A 43 No 43 n-Hexane 110543 C 262 No 262 POINT 005 Benzene 71432 A 511 Yes 26 n-Hexane 110543 C 1606 Yes 80 POINT 006 Benzene 71432 A 100 Yes 5 n-Hexane 110543 C 666 No 33 POINT 007 . Benzene 71432 A 5 No 5 n-Hexane 110543 C 250 No 250 Section 8-Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Section 9—Source Classification Is this a new previously un-permitted X Yes No source? True Synthetic What is this facility classification? Minor X Minor Major Classification relates to what X Title V X PSD NA NSR X MACT programs? Is this a modification to an existing Yes X No permit? Synthetic If"yes" what kind of modification? Minor Major Minor Page 5 Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which 001-007 is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner 003, 005, or operator of a smokeless flare or other flare for the combustion of waste gases shall 006 allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Requlation 2— Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-007 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Requlation 3 -APENs Construction Permits, Operating Permits, PSD Part A-APEN Requirements 001-007 Applicant is required to file an APEN for these points because uncontrolled emissions exceed 2 tons per year VOC. Part B — Construction Permit Exemptions 001-007 Applicant is required to obtain a permit for points 001-006 since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part B, Section II.D.3.a). Part B, III.D.2 - RACT requirements for new or modified minor sources located in ozone 001-007 non-attainment areas This source is not subject to this requirement because it is located in an ozone attainment area. Requlation 6 - New Source Performance Standards 004, 005, NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 006 These tanks are not subject to NSPS Kb because they each have a capacity less than 471 BBL (19,800 gal). Page 6 Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is not subject to the emission control requirements for condensate tanks 004, 006 because this facility is located in an attainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is not subject to this section because these tanks store crude oil rather than condensate (API Gravity is less than 40). 001 VI. Storage and Transfer of Petroleum Liquid This source is not subject to section VI because it does not store or transfer gasoline. Regulation 8—Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution 001, 005, This source is not subject to MACT EEEE because it is located at a"production field 006 facility" as defined in 40 CFR 63.761 (located upstream of the natural gas processing plant). 006 MACT HH This source is not subject to MACT HH because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (YIN) Factor Source (%) 2.47 lb/1000gal VOC No AP-42 NA Crude Oil and Produced 0.0167 01 Water Tank Truck lb/1000gal Benzene No AP-42 NA 001 Loadout 0.0976 n-Hexane No AP-42 NA lb/1000ga1 SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (YIN) Factor Source (%) 4473.85 lb/MMscf NOX No Manufacturer 93 662.793 lb/MMscf VOC No Manufacturer 65 01 NG-fired RICE 002 5633.74 lb/MMscf CO No Manufacturer 88 28.9665 lb/MMscf Formaldehyde No AP-42 65 !5000 SCC 20200256— Internal combustion engine, Natural gas, Four stroke-rich burn Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 33642.97 lb/MMscf VOC No Mass Balance 95 vented 75.0282 lb/MMscf Benzene No Mass Balance 95 vented 56.6516 lb/MMscf Toluene No Mass Balance 95 vented 01 Produced gas 23.5311 lb/MMscf Xylenes No Mass Balance 95 003 vented to flare vented 460.006 lb/MMscf n-Hexane No Mass Balance 95 vented 105.33 lb/MMscf NOx No AP-42 NA vented 573.13 lb/MMscf CO No AP-42 NA vented SCC 31000205—Flares (at gas production facility) Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source r/o) Page 7 01 Natural gas 33642.97 lb/MMscf V0C No Mass Balance NA 004 blowdown venting vented SCC 31000299— Natural Gas Production: Other not classified Point Process Process Description Emission Factor Pollutant/ Fugitive Emission Control CAS# (YIN) Factor Source (%) 6.2381 lb/1000 State Default E&P Produced gallons throughput V0C No EF 95 01 Water Storage 0.1667 lb/1000 Benzene No State Default 95 005 Tanks gallons throughput EF 0.5238 lb/1000 n-Hexane No State Default 95 gallons throughput EF SCC 40400315— Fixed Roof Tank, Produced Water, working+breathing+flashing Point Process Process Description Emission Factor Pollutant/ Fugitive Emission Control CAS# (Y/N) Factor Source (%) 3.2346 lb/1000 E&P Tank gallons throughput V0C No Model 95 01 E&P Crude Oil 0.0210 lb/1000 Benzene No E&P Tank 95 006 Storage Tanks gallons throughput Model 0.1410 lb/1000 n-Hexane No E&P Tank 95 gallons throughput Model SCC 40400312— Fixed Roof Tank, Crude Oil,working+breathing+flashing losses Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# Dust bus) Factor Source (%) 01 Fugitive equipment 4720 lb/yr V0C No EPA-453/R-95- 0 007 leaks017, Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14— Miscellaneous Application Notes AIRS Point 001 Truck Loadout of Crude Oil and Produced Water AP-42: Chapter 5.2 Equation 1 L = 12.46*S*P*M/T L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T = temperature of bulk liquid loaded [deg. R] S 0.6 Submerged loading: dedicated normal service P 5.18 psia M 33.54 lb/lb-mole for gasoline with RVP = 11.5 T 524 deg. R (64 deg. F) L 2.481b/10^3 gal Annual requested Throughput 7,665,000gal/yr Annual requested VOC emissions 9.5tpy Page 8 AIRS Point 002 Generator Engine This engine was manufactured in 1975 and is therefore not subject to NSPS JJJJ. This engine is subject to Regulation 7, Section XVII.E based on a relocation (into Colorado) date of 6/28/2011. Emission standards of 1.0/2.0/0.7 (NOX/CONOC) apply to this source. The construction permit will require stack testing to verify the emission rates stated in the application. AIRS Point 003 Tornado Flare The tornado flare controls gas coming off the three-phase separator at this site since there is no pipeline available in the area at this time. AIRS Point 004 Emergency Tank In case of a flare outage (AIRS point 003), produced natural gas from this site will be routed to this Emergency Tank. Entrained liquids settle in the tank and the gas will be vented to atmosphere. EOG based emissions from this activity on a gas flow rate of 10,417 scf/hr and three venting events per year at 12 hours per event. The composition of the vented gas has the same basis as was used to calculate emissions routed to the flare (point 003). AIRS Point 005 Produced Water Storage Tanks EOG used the state default emission factors to calculate emissions from this produced water storage tank battery. Without emission controls and federally enforceable emission limits for this point, this facility would be considered a major source of VOC for Operating Permit applicability. In order to obtain synthetic minor limits and avoid Operating Permit applicability, EOG will not take advantage of the categorical permit exemption in Regulation 3, Part B, Section II.D.1.m for tanks used to store produced water that is less than 1% oil by volume. AIRS Point 006 Crude Oil Tanks These tanks store crude oil with an API gravity less than 40 degrees. EOG collected a pressurized oil analysis and calculated flash emissions from this tank battery using E&P Tank. Without emission controls and federally enforceable emission limits for this point, this facility would be considered a major source of VOC for Operating Permit applicability. 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L �'b O Mr Pollutant Emission Notice(APEN)—and—Application for Construction Permit ;" T OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY .-)7:F/0 2 '. -1_,;\'4 '1 gibCurrent Status(Check all at apply < Reason for APEN Submittal(Check all that apply) , AIRS ID#': IZ3 93897bob ❑ APEN update only4 ❑ New or previously unreported battery ❑ Modification to existing source' ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GP0I -- ❑ Synthetic minor facility &cancellation request for individual permit6: ❑ Located in the 8-hr Ozone Control Area3 • Z1 Application for or Modification of an individual permit ❑ Registered under general permit no.GPO I ❑ Administrative permit amendment ❑ Permitted under individual permit:— Il WE 34 I' ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division ❑To review a draft of the permit prior to issuance Company Name 9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 It Street,Suite I000N david_Iong@leogresour City: Denver • State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303-262-9448 Fax: 303-262-9449 Tank Battery Namel r: Critter Creek 7-13H _ Number of tanks: 6 Location''-(QQ Sec.Twp.Range.): NWNW Sec 13,TI IN,R63W County: Weld _ Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies13: 2011 Year(s)tank(s)were placed in servicer°: 2011 Control Description rs: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency'6: 95% Condensate Throughput'? [bbl/year] Requested's: 109,500 Maximum for PTE calculation1°: 131,400 Actual'°: 109,500 While Controls Operational" 109,500 Other equipment at facility": VCU,flare,heater treater,generator engine,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GP01 coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions'3. Emission Factor Battery Requested Emissions's Actual Etnissions2U Pollutant24 [lb/bbl] PTE25 Uncontrolled'6 Controlled:" Uncontrolled'° Controlled'' VOC[tons/year] 0.1359 8.9 N/A N/A 7.4 0.37 NOx[tons/year] N/A 0.03 0.03 0.03 CO[tons/year] N/A 0.14 0.14 0.14 Benzene[lbs/year] 96.0 4.8 • n-Hexane[lbs/year] 644.0 322 Wells serviced by this tank or tank battery28 API#: 05-123-31325-00 Name: Critter Creek 7-13H ® Newly Reported Well API#: Name: ❑ Newly Reported Well API#: Name: ❑ Newly Reported Well F, API#: Name: ❑Newly Reported Well N w API#: Name ❑ Newly Reported Well u" API it: Name: ❑Newly Reported Well 'i`, co API#: Name: Y p Z. ❑ Newl Re orted Well `1 o The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best'of O1 my knowled a and belief. If this is a•registration for coverage under general permit GP0I,I further certify that this source is and will be operated ly in-full com/'' tiance,withyeach,coonndition cif-general permit GPO I. (' „ '.. z �. • i-.. (/1 I ,�V ,'' • — . ((\ .0_V' \ cC`� C1 ) I J 1 td Signatur`€of Legally Authorized ze Person(not a vendor or consultant) Date ril v o V David Long Division Environmental Manager :•,,,,rI Type or Print Name of Person Signing Above Official Title 0 co Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: w filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI 1_s' 'e.77-...,,,. c—^ (303)692-3150 to $250 General Permit fee for each new GP 4300 Cherry Creek Drive South dp , '� r v, registration to: Denver,CO 80246-1530 V( Z • `I d_S r v`? sZ_`.,:—t" FORM APCD-205 Page 1 of 2 EOG CC 7-131-I FormAPCD-205-E&PCondensateTankAPEN.docx N 261661. 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X x co o o u ° u c C o m a o o ..-.. 0. a F t c Q T ❑ Y x Z Y 'W V k, 0 4 > O U 0 ❑ W U °q FT STATE OF COLORADO • ry O4'CO(O COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 . *Ian• CONSTRUCTION PERMIT PERMIT NO: 11 WE3414 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas production facility, known as Critter Creek 7-13H, located at NWNW Section 13, Township 11N, Range 63W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Truck 001 Truck loadout of crude oil and produced water. Loadout One (1) Waukesha, Model F1197GU, Serial Number 289188, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 136 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic Generator reduction (NSCR) system and air-fuel ratio control. This emission RICE 002 unit is used to generate power for the facility. Engine This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha F1197GU engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. One (1) Open flame flare (Manufacturer: Tornado, Model No: 40' Flare 003 Flare Stack, Serial No: 10856-16) used to combust produced natural gas vented from a three-phase separator. One (1) 400 BBL well blowdown tank (Manufacturer: Conner, ET#4590 004 Model: EOG #4590, Serial No: 11-056) used to catch liquids and vent gas during emergencies when the produced gas cannot be combusted in the flare (AIRS point 003). PW Tank 005 One (1) 400 BBL fixed roof storage tank used to store produced water. Emissions from this source are routed to an enclosed flare. AIRS ID: 123/9389/001-007 Page 1 of 20 EOG Resources Inc. '. olor-�Depa en f P li Health and Environment • Permit No. 11WE3414 it Pollution Control Division Issuance 1 Facility AIRS Equipment Point Description ID 006 Six (6) 400 BBL fixed roof storage tanks used to store crude oil. Emissions from these tanks are controlled by an enclosed flare. Fugitive 007 Equipment leaks (fugitive VOCs) from a natural gas production facility. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either; the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 4. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 5. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 2.2 tons per year of volatile organic compounds (VOC), AIRS ID: 123/9389/001-007 Page 2 of 20 EOG Resources, Inc. olor- Depa en f P li Health and Environment Permit No. 11WE3414 A it Pollution Control Division Issuance 1 -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: • 100 tons per year of volatile organic compounds (VOC), 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Equipment AIRS Tons per Year Emission Type ID Point NO, VOC CO Truck Loadout 001 -- 9.5 -- Point Generator RICE 002 1.6 1.1 3.2 Point Engine Flare 003 4.8 76.7 26.1 Point ET#4590 004 -- 9.6 -- Point PW Tank 005 -- 0.5 -- Point 006 -- 0.4 -- Point Fugitives 007 -- 2.4 -- Fugitive See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Emissions Point 002: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control that reduces uncontrolled emissions of NOX and CO from the unit to the emission levels listed in Condition 6, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. Emissions Point 003: Emissions from this point shall be routed to an open-flame flare that reduces emissions of VOC to the emission levels listed in Condition 6. Operating AIRS ID: 123/9389/001-007 Page 3 of 20 • EOG Resources, Inc. olor- . Depa en f P li Health and Environment Permit No. 11WE3414 A it Pollution Control Division Issuance 1 parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 9. Emissions Point 005: Emissions from this point shall be routed to an enclosed flare that reduces emissions of VOC to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 10. Emissions Point 006: Emissions from this point shall be routed to an enclosed vapor combustion unit (VCU) that reduces uncontrolled emissions of VOC from the crude oil tanks to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Emissions Point 007: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. . The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Truck Loadout 001 Crude oil and produced water loading 182,500 BBL/yr Generator RICE 002 Consumption of natural gas as a fuel 9.50 MMscf/yr Engine Flare 003 Natural gas venting to flare 91.25 MMscf/yr ET#4590 004 Natural gas vented to atmosphere via 0.569 MMscf/yr emergency tank PW Tank 005 Produced water throughput 73,000 BBL/yr 006 Crude oil throughput 109,500 BBL/yr Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate each actual monthly process rate and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) AIRS ID: 123/9389/001-007 Page 4 of 20 EOG Resources, Inc. olor Depa en P li Health and Environment Permit No. 11WE3414 it Pollution Control Division Issuance 1 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in . any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. & 4.) 15. Points 003, 005, and 006: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Emissions point 001: The loading of crude oil and produced water into truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 18. Emissions point 002: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC ≥100HP and January 1, 2011 1.0 2.0 0.7 <500HP OPERATING & MAINTENANCE REQUIREMENTS 19. Emissions points 002, 003 and 006: Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 20. Emission point 005: a. Flares shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare, or by other convenient means approved by the Division, determine whether the flare is operating properly. b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: AIRS ID: 123/9389/001-007 Page 5 of 20 EOG Resources, Inc. olor- Depa en . P .Ii Health and Environment Permit No. 11WE3414 ,it Pollution Control Division Issuance 1 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. • (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (Hi) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a flare include, but are not limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its resolution, the date range the control was inoperable, and the produced water production through the battery during the downtime. During control device downtime, emissions shall be considered to be uncontrolled. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 21. Emissions point 006: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site-specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 22. Emissions points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to AIRS ID: 123/9389/001-007 Page 6 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11WE3414 it Pollution Control Division Issuance 1 the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. • For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: x lb benzene = benzene wt. rac.a lb.mol. * MW ( lb 1 * le6scf MMscf f 379.3 Sc! gas Llb mod1MMscf. 23. Emissions point 003: The owner or operator shall demonstrate compliance with Condition 15, using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5) 24. Emissions point 002: A source initial compliance test shall be conducted on emissions point 002 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide Volatile Organic Compounds 25. Point 007: Within one hundred and eighty days (180) after commencement of operation, the permittee shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 26. Point 007: Within one hundred and eighty days (180) after commencement of operation, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 27. Emissions point 002: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. AIRS ID: 123/9389/001-007 Page 7 of 20 EOG Resources, Inc. olor- , Depa en .f P 'Ii Health and Environment Permit No. 11WE3414 �' 'it Pollution Control Division Issuance 1 ADDITIONAL REQUIREMENTS 28. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 29. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equals or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 30. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 31. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 32. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction AIRS ID: 123/9389/001-007 Page 8 of 20 EOG Resources, Inc. olor- ,Depa en f P li Health and Environment Permit No. 11WE3414 it Pollution Control Division Issuance 1 permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 33. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 34. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 35. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 36. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 37. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Jacob Sebesta Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for a new synthetic minor AIRS ID: 123/9389/001-007 Page 9 of 20 EOG Resources, Inc. ' olor. Depa '- en 4 P'-.li Health and Environment Permit No. 11WE3414 �`, Air Pollution Control Division Issuance 1 E&P facility. AIRS ID: 123/9389/001-007 Page 10 of 20 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 11WE3414 it Pollution Control Division Issuance 1 Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/regulations/airregs/100102agcccommonprovisionsreq.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS# BIN (Ib/yr) reportable? (Ib/yr) Benzene 71432 A 30 No 1 001 Toluene 108883 C 22 No 1 n-Hexane 110543 C 179 No 9 Formaldehyde 5000 A 275 Yes 96 002 Acetaldehyde 75070 A 37 No 13 Acrolein 107028 A 35 No 12 Benzene 71432 A 6841 Yes 342 Toluene 108883 C 5165 Yes 258 Ethylbenzene 100414 C 868 No 43 003 Xylenes 1330207 C 2146 Yes 107 n-Hexane 110543 C 41926 Yes 2096 2,2,4- 540841 C 82 No 4 Trimethylpentane - Benzene 71432 A 43 No 43 004 n-Hexane 110543 C 262 No 262 Benzene 71432 A 511 Yes 26 005 n-Hexane 110543 C 1606 Yes 80 Benzene 71432 A 100 Yes 5 006 n-Hexane 110543 C 666 No 33 007 Benzene 71432 A 5 No 5 AIRS ID: 123/9389/001-007 Page 11 of 20 EOG Resources Inc. — olor Depa en f P: •li Health and Environment Permit No. 11WE3414y �_ it Pollution Control Division • Issuance 1 k S 1111, n-Hexane 110543 C 250 No 250 4) The emission levels contained in this permit are based on the following emission factors: Points 001: Note: The emission factor below may be used for both crude oil and produced water loading. Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 0.104 lb/bbl -- AP-42 71432 Benzene 0.0007 lb/bbl -- AP-42 108883 Toluene 0.0023 lb/bbl -- AP-42 1330207 Xylenes 0.0030 lb/bbl -- AP-42 110543 n-Hexane 0.0041 lb/bbl -- AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.18 psia M (vapor molecular weight) = 33.43 lb/lb-mol T (temperature of liquid loaded) = 524 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP determined in the pressurized oil analysis by the VOC emission factor. Point 002: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.1662 13.5000 0.2345 1.0000 CO 3.9871 17.0000 0.4691 2.0000 VOC 0.4691 2.0000 0.1642 0.7000 5000 Formaldehyde 0.0205 0.0874 0.0072 0.0306 75070 Acetaldehyde 0.0028 0.0119 0.0010 0.0042 107028 Acrolein 0.0026 0.0112 0.0009 0.0039 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site-rated horsepower value of 136, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer's Data Manufacturer's Data CO Manufacturer's Data Manufacturer's Data VOC Manufacturer's Data Manufacturer's Data 5000 Formaldehyde AP-42; Table 3.2-3 (7/2000); Manufacturer's Data Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); Engineering Estimate Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); Engineering Estimate Natural Gas AIRS ID: 123/9389/001-007 Page 12 of 20 EOG Resources, Inc. olor Depa en P li Health and Environment Permit No. 11WE3414 it Pollution Control Division Issuance 1 Point 003: Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf IbIMMscf natural gas natural gas vented vented NOx 105.33 105.33 AP-42, Table 13.5-1 and 1549 Btu/scf CO 573.13 573.13 AP-42, Table 13.5-1 and 1549 Btu/scf VOC 46.18 33,643 1,682.1 Eng. Calculation 71432 Benzene 0.1030 75.028 3.7514 Eng. Calculation 108883 Toluene 0.0778 56.6516 2.8326 Eng. Calculation 100414 Ethylbenzene 0.0131 9.5245 0.4762 Eng. Calculation 1330207 Xylenes 0.0323 23.5311 1.1766 Eng. Calculation 110543 n-Hexane 0.6315 460.006 23.000 Eng. Calculation 540841 2,2,4-TMP 0.0012 0.9042 0.0452 Eng. Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 10, 2010 analysis of a gas sample collected from the Critter Creek 2-03-H well (weight percents for VOC and HAP components from this analysis are listed in the table above). The controlled VOC and HAP emissions factors for point 003 are based on the flare control efficiency of 95%. Point 004: Natural Gas Emission Emission Composition Factors Factors CAS# Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf natural gas vented VOC 46.18 33,643 -- Eng. Calculation 71432 Benzene 0.1030 75.028 __ Eng. Calculation 110543 n-Hexane 0.6315 460.006 -_ Eng. Calculation The emission levels in this permit for this point are based on the use of this tank to blowdown produced natural gas when the flare used to combust the natural gas is down at three (3) events per year and twelve (12) hours of venting through this tank per event at a maximum gas flow rate of 15,792 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well (weight percents for VOC and HAP components from this analysis are listed in the table above). Point 005: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 Benzene 0.007 lb/bbl 3.5 x 10'lb/bbl PS Memo 09-02 n-Hexane 0.022 lb/bbl 0.0011 lb/bbl PS Memo 09-02 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. AIRS ID: 123/9389/001-007 Page 13 of 20 EOG Resources, Inc. olor. i Depa en f P li Health and Environment Permit No. 11WE3414 , it Pollution Control Division Issuance 1 Point 006: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.1359 lb/bbl 0.0068 lb/bbl E&P Tank Benzene 9.1 x 10' lb/bbl 4.6 x 10-' lb/bbl E&P Tank n-Hexane 0.0061 lb/bbl 3.0 x 10-° lb/bbl E&P Tank Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. These emission factors were developed using sampling from the Critter Creek 2- 03H well site and the E&P Tank model. Point 007: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 Valves 56 --- 72 24 Other 35 --- 15 6 VOC Content(wt%) 3.5% 100% 29.2% 100% Benzene Content(wt%) 0.023% -- 0.027% --- Toluene Content(wt%) 0.039% --- 0.075% Ethylbenzene (wt %) 0.002% --- 0.017% --- Xylenes Content(wt%) 0.01% --- 0.036% --- n-hexane Content 0.336% °(wt%) 2.43% --- *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on October 11, 2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: AIRS ID: 123/9389/001-007 Page 14 of 20 EOG Resources, Inc. • ; olor- Depa en f P li Health and Environment Permit No. 11WE3414 A' it Pollution Control Division Issuance 1 Applicable Status Requirement Operating Permit Synthetic Minor Source of VOC and n-Hexane PSD Synthetic Minor Source of VOC Major Source Requirements: Not Applicable (True Minor Source of HAP MACT HH for MACT HH) Area Source Requirements: Not Applicable (Area source requirements only apply to TEG dehydrators) Major Source Requirements: Not Applicable (True Minor Source of HAP MACT ZZZZ for MACT ZZZZ) Area Source Requirements: Apply 7) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 8) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilqaspermittinci.html s $ AIRS ID: 123/9389/001-007 • Page 15 of 20 • EOG Resources, Inc. olor.1 Depa en f P li Health and Environment Permit No. 11WE3414 ' it Pollution Control Division Issuance 1 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 1, 2011 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. •2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is •in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9389/001-007 Page 16 of 20 EOG Resources, Inc. olor- Depa en f P li Health and Environment Permit No. 11WE3414 A it Pollution Control Division Issuance 1 2.1.2 The permittee may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer). Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9389/001-007 Page 17 of 20 EOG Resources, Inc. A. olor. Depa en f P li Health and Environment Permit No. 11WE3414 , A : it Pollution Control Division Issuance 1 For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for naturalgas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9389/001-007 Page 18 of 20 • EOG Resources, Inc. olor- Depa en P li Health and Environment Permit No. 11WE3414 A it Pollution Control Division Issuance 1 Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9389/001-007 Page 19 of 20 • EOG Resources, Inc µ olor- Depa en f P li Health and Environment Permit No. 11WE3414 a� it Pollution Control Division Issuance 1 • A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9389/001-007 Page 20 of 20 Hello