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Home My WebLink About20121268.tiff STATE OF COLORADO John W.Hickenlooper,Governor oc cod Christopher E. Urbina,MD,MPH ti • --_0 Executive Director and Chief Medical Officer fc 0 Dedicated to protecting and improving the health and environment of the people of Colorado .* *, 4300 Cherry Creek Dr.S. Laboratory Services Division r lave' 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 May 9, 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 May 13, 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-B I 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 P au u t U h G/3 - 2012-1268 5- al-ra c5-‘5 :(ta. NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR 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: LAURA STROHKIRCH 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 RF'oF cot c145Executive Director and Chief Medical Officer Q ?,� Dedicated to protecting and improving the health and environment of the people of Colorado * 4300 Cherry Creek Dr.S. Laboratory Services Division • Denver,Colorado 80246-1530 8100 Lowry Blvd. I 1876 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 May 9, 2012, published May 13, 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 the following natural gas exploration and production facilities in Weld County, Colorado. • Garden Creek 02-0611. This source will consist of six (6) 400BBL crude oil storage tanks, truck loadout of crude oil and produced water, fugitive leak emissions, one (I) Tornado flare stack, one(1) emergency blowdown tank, and one (1) 400BBL produced water storage tank. 'This source will be located in the SESE quarter-quarter of Section 6,Township 11 North, Range 62 West in Weld County, Colorado. • Red Poll 10-16H. This source will consist of one (1) 400BBL produced water storage tank, four(4) 400BBL crude oil storage tanks, one (1) emergency blowdown tank, one (I) Tornado flare stack, loadout of crude oil and produced water, and fugitive leak emissions. This source will be located in the SESE quarter-quarter of Section 16, Township I 1 North, Range 63 West in Weld County, Colorado. • Garden Creek 6-11H. This source will consist of one (1) 400BBL produced water storage tank, four(4) 400BBL crude oil storage tanks, one (1) emergency blowdown tank, one (I) reciprocating internal combustion engine, one (1) Tornado flare stack, loadout of crude oil and produced water, and fugitive leak emissions. This source will be located in the SESE quarter-quarter of Section 11, Township I I North, Range 62 West in Weld County, Colorado. These emission points would be considered major sources of air pollutants subject to Prevention of Significant Deterioration (PSD) 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 250 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, each source will be considered a synthetic minor source not subject to PSD and MACT review. Each source will have permitted emissions less than 100 tons per year for criteria pollutants and will be considered a new synthetic minor source not subject to Title V Operating Permit requirements. As such, this permit is subject to public comment per Regulation 3, Part B, Section III.C.l.d. Copies of the draft permit and preliminary analysis are available for review in the public comment package. The Division has determined that the,Proposed source 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 concerning the aforesaid proposed project and activities 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: Laura Strohkirch 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: 10WE2243 Source Location: SESE Sec 11, T11N, R62W Source Name: Garden Creek 6-11H Equipment Description: Point 001- One (1) 400 BBL fixed roof produced water storage tank Point 002- Four(4) 400BBL storage tanks for crude oil Point 003-One (1)400 BBL emergency tank Point 004-One (1) Tornado Flare Point 005- One (1)Waukesha Reciprocating Internal Combustion Engine Point 006- Crude oil and produced water truck loadout Point 007- Fugitive emissions AIRS ID: 123-8762 Date: March 29, 2011 Review Engineer: Laura Strohkirch 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 On May 23, 2011 Jake, who is also Information Request letter to the source? working on some EOG sites, e- mailed David Long about the flare calculations. The mole fraction VOC had been used instead of mass fraction VOC. This caused the emissions to be underestimated and with the correct calculations facility status could change. New calculations for this facility were submitted August 23, 2011 September 24, 2010 original On what date was this application complete? application was received. Revised calcs received August 23, 2011 Page 1 Section 4—Source Description AIRS Point Equipment Description One (1) above ground 400 bbl atmospheric produced water storage tank. Emissions 001 from this tank are controlled by a smokeless Cimarron Energy Combustor(SN: 4848)with a destruction efficiency of 95%. Four(4) above ground 400 bbl atmospheric crude oil storage tank. Emissions from 002 these tanks are controlled with a Cimarron Smokeless Combustor(VCU)with 95% control efficiency. One (1) above ground 400 bbl atmospheric emergency tank. This tank is used when 003 there is a need to vent the natural gas from blowdowns of the flare rather than put it into the pipeline.There are no controls for this tank. 004 One (1) Tornado Flare that is controlling a separator. This is a 40' candlestick flare that is not enclosed and has been granted 95% destruction efficiency. One (1)Waukesha, Model F1197GU, Serial Number 32697, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine, design-rated at 005 162 horsepower at 1200 RPM.This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power. 006 Crude oil and produced water truck loadout. 007 Fugitive emission 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 X No apply) Point 001: Is this source claiming exempt status for this source based on the fraction of oil in the stored X Yes No water (less than 1% by volume crude oil on an average annual basis)? Point 001: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 001: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? If so, submit Form APCD-105 Section 5— Emission Estimate Information AIRS Point Emission Factor Source 001 CDPHE Emission Factors (PS Memo 09-02) Source used E&P Tanks along with site-specific sampling to calculate a site- 002 specific emission factor Page 2 VOC E.F.= 0.1349 lb/bbl Used maximum gas vented to atmosphere along with VOC weight fraction to 003 determine a site-specific emission factor. VOC E.F.= 33,420 lb/MMscf Emission Factors for NOx, Sox, CO and PM10 came from AP-42 Tables 13.5-1&2 004 VOC emissions are based on a VOC weight-fraction VOC E.F.= 33,624.06 lb/MMscf 005 Manufacturer Data and AP-42 Table 3-2-3 006 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 43,800 BBL/yr(36,500 x 1.2) 002 175,200 BBL per year(146,000 x 1.2) 003 382,500 scf/yr or 0.383 MMscf/yr 004 255,000 scf/day or 93,075,000scf/yr or 93.1 MMscf/yr 005 8.7 MMscf/yr 006 182,500 BBL/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- 2 Valves 56 --- 72 24 Other 35 --- 15 6 Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 36,500 BBL/yr 2011 002 146,000 BBL per year while controls are in operation 2011 003 382,500 scf/yr or 0.38 MMscf/yr 2011 004 93.1 MMscf/yr 2011 005 8.7 MMscf/yr 006 182,500 BBL/yr 2011 Page 3 Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy ,(or Light Liquid) Liquid) Connectors 576 --- 520 51 Flanges 8 --- 24 4 007 Open-Ended 9 --- 7 5 2011 Lines Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 36,500 BBLJyr 002 146,000 BBL 003 382,500 scf/yr or 0.38 MMscf/yr 004 93.1 MMscf/yr 005 8.7 MMscf/yr 006 182,500 BBL/yr — Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) — Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 _ Other 35 --- 15 6 Does this source use a control device? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron Smokeless Combustor, SN 4848 95 002 01 Cimarron Smokeless Combustor(VCU) 95 004 01 Tornado, 40' Flare Stack, SN 08CSADA4X510129 95 NOx: 85%; 005 of NSCR and AFRC CO: 76%; VOC: 50% HAPS: 50% Section 6— Emission Summa (tons per year) _ Point NO, VOC CO Single HAP Total HAP 001 - 5.74 - 0.48 (n-hexane) 0.63 002 0.03 11.8 0.18 003 - 6.4 - 0.09 (n-hexane) 0.1 PTE: 004 4.9 1,565.2 26.7 21.40 (n-hexane) 28.8 005 17.73 2.63 22.33 0.13 0.17 (Formaldehyde) 006 - 9.5 - 0.4 (n-hexane) 0.9 007 - 2.4 - 0.1 (n-hexane) 0.1 Page 4 Total (TPY) PTE: 22.66 03.67 49.21 30.7 001 - 4.8 - 0.4 (n-hexane) 0.53 002 0.03 9.9 0.18 003 - 6.4 - 0.09 (n-hexane) 0.1 Uncontrolled point 004 4.9 1,565.2 26.7 21.40 (n-hexane) 28.8 source emission rate: 005 17.73 2.63 22.33 0.13 0.17 (Formaldehyde) 006 - 9.5 - 0.4 (n-hexane) 0.9 007 - 2.4 - 0.1 (n-hexane) 0.1 001 - 0.24 - 0.02 (n-hexane) 0.03 002 0.03 0.48 0.18 003 - 6.4 - 0.09 (n-hexane) 0.1 Controlled point 004 4.9 78.3 26.7 1.07 (n-hexane) 1.43 source emission rate: 005 2.63 1.31 5.25 0.06 0.09 (Formaldehyde) 006 - 9.5 - 0.4 (n-hexane) 0.9 007 - 2.4 - 0.1 (n-hexane) 0.1 Total APEN Reported 7.56 98.63 27.37 1.6 (n-hexane) 2.49 emissions: Section 7—Non-Criteria / Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions Ibl r (lb/yr) reportable? Rate( Y ) POINT 001 Benzene 71432 A 255.5 Yes 12.78 n-Hexane 110543 C 803 No 40.15 POINT 002 Benzene 71432 A 131.4 Yes 8.76 POINT 003 Benzene 71432 A 28.7 No NA n-Hexane 110543 C 175.8 No NA POINT 004 Benzene 71432 A 6,981.4 Yes . 349.1 Toluene 108883 C 5,271.5 Yes 263.6 Ethylbenzene 100414 C 886.3 No 43.3 Xylenes 1330207 C 2,189.6 Yes 109.5 n-Hexane 110543 C 42,798.8 Yes 2,139.9 Page 5 POINT 005 Formaldehyde 50000 A 53.8 Yes 26.9 Acetaldehyde 75070 A 31.2 No 15.6 POINT 006 Benzene 71432 A 127 Yes 127 Toluene 108883 C 416 No 416 Ethylbenzene 100414 C 31 No 31 Xylenes 1130207 C 553 No 553 n-Hexane 110543 C 758 No 758 Note: Regulation 3, Part A, Section ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? • If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 002 01 VOC CDPHE PS Memo 05-01 Site-specific sampling 003 01 VOC, State-only requirement Site-specific gas HAP's analysis 004 01 VOC, State-only requirement Site-specific gas HAP's analysis 005 01 VOC, Regulation No. 3, Part B., Section III.G.3 Stack test NOx, CO g 007 01 VOC, State only requirement Site-specific gas HAPS analysis 007 01 VOC, State only requirement Hard component HAPS count Section 9-Source Classification Is this a new previously un-permitted X Yes No source? (Points 001-005) What is this point classification? True Minor Synthetic Minor Major Point 001: One (1)400 BBL fixed roof X produced water storage tank Point 002: Four(4) above ground 400 bbl atmospheric crude oil storage X tank Point 003: One (1) above ground 400 X bbl atmospheric emergency tank Point 004: One (1)Tornado Flare X Point 005: X Point 006: Crude oil and produced X water truck loadout Page 6 Point 007: Fugitive VOC emissions X 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? If"yes"what kind of modification? Minor Synthetic 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 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 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, 001-007 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 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. 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 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 001-007 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 points 001-007 since emissions exceed 2 tons per year VOC) Part B —Construction Permit Exemptions 001-007 Applicant is required to obtain a permit for points 001-007 since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section 11.D.3.a) Page 7 Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in 006 nonattainment or attainment/maintenance areas. This source is located in the attainment area, therefore, not subject to RACT. However, operator is using 0.6 (submerged, dedicated normal service) for its saturation factor. Regulation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 001,002,003 Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ when 005 their manufacturer date is on or after July 1, 2008. The operator provided a manufacturer date of 11/6/1978, which is prior to the threshold date. Therefore, this engine is not subject to NSPS JJJJ. 004, 006, None 007 Re•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 001,002,003 since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since these are not condensate storage tanks 005 This engine is subject to Regulation 7, Section XVII.E because it was relocated into the State of Colorado 6/28/2010,which is after January 1, 2008. 004, 006, None 007 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 003 field facility" as defined in 40 CFR 63.761 (located upstream of the natural gas processing plant). MACT HH 002,003 • This source is not subject to MACT HH because it is not located at a major source of HAP. 004-007 none Section 13—Aerometric Information Retrieval System Coding Information Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor o CAS# (YIN) Factor Source (/o) 6.2381 lb/1000 gal V0C No CDPHE PS 95 E&P Produced throughput Memo 09-02 0 01 Water Storage .1667 lb/1000 gal Benzene No CDPHE PS 95 001 Tanks throughput Memo 09-02 0.5238 lb/1000 gal n-Hexane No CDPHE PS 9 throughput Memo 09-02 SCC 40400315— Fixed Roof Tank, Produced Water,working+breathing+flashing losses Page 8 Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 3.21 lb/1000 gal VOC No Site-specific 95 01 E&P Crude Oil throughput 002 Storage Tanks 0.02 lb/1000 gal Benzene No Site-specific 95 throughput SCC 40400312— Fixed Roof Tank, Crude Oil,working+ breathing + flashing losses Process Process Description Emission Factor Pollutant/ Fugitive Emission Control Point CAS# (Y/N) Factor Source (%) 32,420 lb/MMscf VOC No Mass Balance NA 01 Emergency Tank 74.9 lb/MMscf Benzene No Mass Balance NA 003 459 lb/MMscf n-Hexane No Mass Balance NA SCC 31000299- Natural Gas Production: other, not classified Process Process Description Emission Factor Pollutant/ Fugitive Emission Control Point CAS# (Y/N) Factor Source (/°) 33,624.061b/MMscf VOC No Mass Balance 95 105.3 lb/MMscf NOx No AP-42 NA 573.6 lb/MMscf CO No AP-42 NA 0.64 lb/MMscf SOx No AP-42 NA 01 Tornado Flare 004 75 lb/MMscf Benzene No Mass Balance 95 56.6 lb/MMscf Toluene No Mass Balance 95 23.5 lb/MMscf Xylenes No Mass Balance 95 459.7 lb/MMscf n-Hexane No Mass Balance 95 SCC 31000205— Flares (at gas production facility) Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (YIN) Factor Source (%) 2.0 g/hp-hr VOC No Manufacturer 65 Reciprocating Internal 13.5 g/hp-hr NOx No Manufacturer 93 01 Combustion Engine 005 17.0 g/hp-hr CO No Manufacturer 88 0.0205 lb/mmbtu Formaldehyde No AP-42 76 SCC 20200253: 4-cycle rich burn Pollutant/ Fugitive Emission Control Point Process Process Description Emission Factor CAS# (Y/N) Factor Source (%) 2.47 lb/1000gal VOC No AP-42 NA Crude Oil and Produced 01 Water Tank Truck 0.016 lb/1000 gal Benzene No AP-42 NA 006 Loadout 0.098 lb/1000 gal n-Hexane No AP-42 NA SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Page 9 Pollutant/ Fugitive Control Point Process Process Description CAS# ty/Nl Emission Factor Source (%) 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017,Table 2-4 NA 007 Emission SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14—Miscellaneous Application Notes AIRS Point 001 Produced Water Storage Tanks Operator originally requested this point to be a General Permit; however, having the general permit emission limit of 39TPY for VOC would have made them a major source so operator requested that the point be added to the facility-wide construction permit so actual, controlled emissions would be accounted for instead of the general permit limit. State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson, Larimer and Weld The APEN states that the tanks contain less than 1% by volume crude oil on an annual average basis which qualifies the source for the categorical exemption (Regulation 3, Part B, Section II.D.1.m). However, this source will be permitted because if it was not controlled, the overall permitted VOC emissions would be greater than 100 TPY and become a major facility. The operator has requested synthetic minor status and accepted Federally enforceable controls, so this point will be included to ensure synthetic minor eligibility. AIRS Point 002 Crude Oil Tanks These tanks contain oil with an API gravity less than 40 degrees. EOG used E&P Tank to estimate the flash emissions off this tank battery. From E&P Tank- uncontrolled ton/year= 9.592 TPY VOC VOC=(9.851 TPY)*(20001b/ton)/(146,000bbl/yr)= 0.1349 lb/bbl VOC or 3.2130 lb/1000 gallons AIRS Point 003 Emergency Tank Gas going to the flare would be routed to this tank in case of a flare outage. The gas is vented to atmosphere from this tank. The APEN was submitted with worse-case scenario calculations. This consists of 3 upset conditions in a 12 month period. Each instance of upset conditions was estimated to be 12 hours in length. Max gas vented to atmosphere= 10,625 scf/hr Molecular wt. of gas= 27.6 lb/lb-mole VOC fraction= 0.4618 379.4 scf/lb-mole VOC= 10,625 scf/hr*( 27.6 lb/lb-mole)/(379.4 scf/Ib-mole)*0.4618= 356.9 lb/hr VOC Using the 3 upset conditions at 12 hrs per condition: 365.9 lb/hr*(12 hr/event)* (3 events/yr)/ (2,000lb/ton)= 6.4 tpy VOC VOC E.F.: 6.4 ton/yr*( 2,000lb/ton)/(0.383 MMscf/yr)= 33,420 Ib/MMscf Page 10 AIRS Point 007 Fugitive VOC emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (APEN threshold) and the total facility is greater than 5 TPY (permit threshold). When reviewing calculations for a similar facility in non-attainment, another engineer working on these sites noticed the fugitive emissions were calculated incorrectly. These errors triggered fugitives in attainment facilities to be permit-required (increase from 1.5 TPY to 2.4 TPY). EOG submitted APENS for the fugitive emissions on 2/14/12. Points 001-006: No monthly limits will be put in the permit even though this is a synthetic minor source. After discussing this source with Chris Laplante 3-8-2011 it was decided that since production at an E&P site is not steady enough to impose those kinds of limits. Compliance on a monthly limit may not be possible, while a yearly limit could be. Page 12 AIRS Point 004 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. Emissions were calculated using VOC wt fraction. (scf/hr) * (Ib/Ib-mol) * (% fraction from sales gas analysis)/(379.4 scf/lb-mol) = lb/hr* (hr/yr)/2000 IbiT) = TPY Emission factors for NOx, CO, and PM10 came from AP-42, table 13.5-1 Emission factor for SOx also came from AP-42 and is based on 100% conversion of sulfur to SO2 at 2000 grains/MMscf VOC E.F. = (1565.2 TPY* 2000 Ib/T)/(93.1 mmscf/yr) = 33,624.06 lb/MMscf HAP's Emission Factors: Benzene = (6981.4 Ib/yr)/93.1 MMscf/yr= 75 lb/MMscf Toluene = (5271.58 lb/yr)/ 93.1 MMscf/yr= 56.6 lb/MMscf Ethylbenzene= (886.3 Ib/yr)/93.1 MMscf/yr= 9.5 lb/MMscf Xylenes= (2189.6 lb/yr)/93.1 MMscf/yr= 23.5 lb/MMscf n-hexane = (42798.8 Ib/yr) / 93.1 MMscf/yr= 459.7 lb/MMscf AIRS Point 005 Waukesha RICE This is a permitted source since uncontrolled NOx and CO emissions (each) are greater than 10 TPY. Engine not subject to federal requirements, and since it was relocated into Colorado on 2/18/2011, it is subject to Regulation 7 requirements. The engine is controlled by a NSCR and AFRC. 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 33.43 lb/lb-mole for gasoline with RVP = 11.5 T 523 deg. R (64 deg. F) L 2.481b/10^3 gal Annual requested Throughput 7665000ga1/yr Annual requested VOC emissions 189731b/yr 9.49tpy Page 11 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTER `- \, Current Status(Check al that apply) Reason for ADEN Submittal(Check all that apply) ( S p 2 4 VEEP��I AIRS ID#1: )Q•4/ 76°T/GO?- ❑ APEN update only4 s 4, .4/� ® New or previously unr&ported battery ❑ Modification to existing source ,SIr4if n ❑ Previously grandfathered battery2 0 Registration for coverage under general permit no.GPOI C ""ark ❑ Synthetic minor facility &cancellation request for individual permit6: ` , ac's ❑ Located in the 8-hr Ozone Control Area3 0 Application for or Modification of an individual permit) ,,1 ;•t/.._ , RRegistered under general permit no.GPO _ O Administrative permit amendment' 4 -£ w7 ` Permitted under individual permit: ci 0 Other: For individual permit applications,check if you wants: 0 A copy of the preliminary analysis conducted by the Division 0 To review a draft of the permit prior to issuance Company Name9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address°: 600 17t°Street,Suite l000N 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": Garden Creek 6-11H Number of tanks: 4 Location12(QQ Sec.Twp.Range.): SESE Sec 11,TI IN,R62W County: Weld Total tank capacity[bbl]: 1,600(400 ea) Calendar year for which"Actual"data applies3: 2010 Year(s)tank(s)were placed in service14: 2010 Control Description': Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency16: 95% n 's Maximum for PTE calculation 9: 294,700 i-L ,,o0 C'mrdermn[e-Throughput [bbl/year] Requested 237,250 j y l0,f'l�i� eftk,6e_, 0' 1 Actual20: 239,250 1 i-1 tv:Cal While Controls Operational21 ?39-,250 I'4/ 000 Other equipment at facility22: 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 GPO! 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 emissions23. Emission Factor Battery Requested Emission's Actual Emissions20 Pollutant24 [lb/bbl] PTE23 Uncontrolled26 Controlled27 Uncontrolledr6 Controlled"' VOC[tons/year] 0.13`4' 03085— j 1.S 43-9- N/A N/A 9 Pci 36.6. J,t4 5 d-8' . NOx[tons/year] C.0;.'YJ-4 NNt- 0,02; .068- 0_.330:08- 1i),,-1j0O8- CO[tons/year] o.-1 Nifi n. ri,s '0&3— O.1°S 0:43 n.l./ Od3 Benzene[lbs/year] 0. ' ,1 Y-1(21 0 32S (1.0 (n O.JU-I n-Hexane[lbs/year] p_ Wells serviced by this tank or tank batter? . API#: 05-123-31221 Name: Garden Creek 6-11H ®Newly Reported Well API#: Name: 0 Newly Reported Well API#: Name: ❑Newly Reported Well ti-iLi API#: Name: ❑Newly Reported Well Li Name El Newly Reported Welk.,.,, co API#: m API#: Name: ❑Newly Reported Well ND API#: Name: 0 Newly Reported Welljh Ii - 0 N The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,andcpmplete to the bestto,. my knowledge and belief. If this is a r-_'station uie for coverage under general permit GPOI,I further certify that this soe[is ahl Iwill be'iferated b in full co •• ' . wt e. , •nil 'd'�of general permit GPOI. PP, to - 7"y'' ' I = Z//r N �- Date o Sigma' ega y-• .,• . ed Perso• of a vendor or consultant) 1 -.,, o Division Environmental Nlanager �avid-Eon ,..„ a e �,.F i.--1 Lo Type or Print Name of Person Signing Above Official Title ti.- Submit this form,along with$152.90 for each Colorado Department of Public Health and Enviro ent For information call: 303 692-3150 filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI � (303) ro $250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver,CO 80246-1530 I _ -- I V lDM APrnL9.115 I x't C.-?,,C -.1:11 1,--,e. Page 1 of 2 EOG GC 6-11H FomrAPCD-205-E&PCondensateTankA.PEN.docx o H _ a,w Z p O m u Z co CC "°' .� o v °' " '' w � co a �/�ry `'�' = `eo 2 8O `er ,� � , E. Nc "' y . �4 .0 a fi cr w E O -11 iL. E E ✓ ' uC7 Q Q W J S O p a L c ao ,-- as m c w W i V s. F C .V.. `A "c0 S+ L'. O V ea p C aQ --es q O O J ad+ 'y y U. .� m II .. 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O E E A .n,4. v) W a a` LT.E t r fi e 0 U ti E LO i c a. w Z o �.=] E y o v N W wc-, 1° .C .a E � � C LS A v-, > a C Fa E 4 A B r. E v 0 o u v . C .R O '� ." E C AT; E C a 0 h c CC u_ eo. — u S F _. C d u O ,c C I� d �.' o o` CL " c o y t= e\ h e i-r a d s v y T. O p" C N ry c = o U - O e O m -2 , �L.) W Pe C. O u — O ❑ ,, 3" O d E �., E c a •,, 2 " u o a y d c n y T F E u,, U C , '_ Oo .7 Z C] W n _ F .-1 W e q ¢ m I c .a n n 'v Q m. VD Z�' o °J o 'o m o a n u O c d u c E A r 0 O cos°a C U .? a 0 W 'V) t c e4 a O N = u o x m E .d. .0 O` 4 a c U e - CO v 0. ° a`, = o o > v o ≥, k c CO o a Cr) z — c. a® W U 'W O coc. a > O -c' v ❑ a a7 F w ¢ >. tr. m v, d Ct (n L STATE OF COLORADO .c.CO/-0 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT � Ne AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 '1876% CONSTRUCTION PERMIT PERMIT NO: 1 UWE2243 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 Garden Creek 6-11 H, located at SESE Section 11, Township 11N, Range 62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID One (1) 400 BBL fixed roof storage tank used to store produced PW Tank 001 water. Emissions from this tank are controlled by a smokeless #1 Cimarron Energy Combustor with 95% efficiency. Four (4) 400 BBL fixed roof storage tanks used to store crude oil. Crude Oil 002 Emissions from these tanks are controlled by a Cimarron Tanks smokeless vapor combustion unit with 95% efficiency. One (1) 400 BBL well blowdown tank, Manufacturer: Frontier, ET#3614 003 Model: EOG #3614, SN: 5422 used when the produced gas cannot be combusted in the flare. One (1) Tornado flare (Manufacturer: Tornado, Model No: 40' Flare Flare 004 Stack, Serial No: 08CSADA4X510129) used to combust produced gas vented from a three-phase separator. One (1) Waukesha, Model F1197GU, Serial Number 32697, natural gas-fired, naturally aspirated, 4SRB reciprocating internal Generator combustion engine, design-rated at 162 horsepower at 1200 RPM. RICE 005 Engine This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power. Truck 006 Truck loading of crude oil and produced water. Loadout Equipment leaks (fugitive VOCs) from a natural gas production Fugitive 007 facility. AIRS ID: 123/8762/999 Page 1 of 21 Condensate Tank Version 2009-1 i.EOG Resources Inc. '" olor. ' Depa en f 1•li Health and Environment Permit No. 10WE2243 sir Pollution Control Division Issuance 1 a. Point 005 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha Model F1197GU engine in accordance with the permanent replacement provision of the Alternate Operating Scenario(AOS), included in this permit as Attachment A. 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: • 3.77 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), AIRS ID: 123/8762/999 Page 2 of 21 EOG Resources, Inc olor Depa en -f iii Health and Environment Permit No. 10WE2243 it Pollution Control Division Issuance 1 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 AIRS Tons per Year Equipment ID Point NO, VOC CO Emission Type PW Tank#1 001 - 0.24 - Point Crude Oil 002 - 0.48 - Point Tanks ET#3614 003 - 6.4 - Point Flare 004 4.9 78.3 26.7 Point Generator 005 2.63 1.31 5.25 Point RICE Engine Truck Loadout 006 - 9.5 - 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 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 flare that reduces emissions of VOC to the emission levels listed in this section, 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 002: 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 this section, above. 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 004: This emissions point is a separator controlled by a 40' flare stack. The flare shall reduce emissions of VOC to the emission levels listed in this section, above. AIRS ID: 123/8762/999 Page 3 of 21 • EOG Resources Inc olor- Depa en -f ' .li `Health and Environment Permit No. 10WE2243 = '_ •it Pollution Control Division Issuance 1 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. The NSCR shall reduce uncontrolled emissions of NOx, VOC and CO from the unit to the emission levels listed in this section, 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. 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 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 PW Tank#1 001 Produced water throughput 36,500 BBL/yr Crude Oil 002 Crude oil throughput 146,000 BBL/yr Tanks ET#3614 003 Natural gas vented to atmosphere via 0.38 MMscf/yr emergency tank Flare 004 Natural gas flaring 93.1 MMscf/yr Generator 005 Consumption of natural gas as a fuel 8.7 MMscf/yr RICE Engine Truck 006 Crude oil and produced water loading 182,500 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. 13. Point 001: Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained for a consecutive period of three years. AIRS ID: 123/8762/999 Page 4 of 21 ''„ olor s Depa en 4 ••li Health and Environment EOG Resources, Inc. it Pollution Control Division Permit No. 10WE2243 �'< Issuan ce 1 <"` A STATE AND FEDERAL REGULATORY REQUIREMENTS 14. 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) 15. Visible emissions shall not exceed twenty percent modification,opacity dur adjuring normal operation control l the source. During periods of startup, process 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.)e ustion of waste 16. No shall allow operator allow or causeemissions into the atmosphere h ofany air bpollutant 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.). 17. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 18 Point 005: This equipment is subject control internal combustion under Regula ion No.requirements, reciprocating operator Section XVII E (State anyng internal l engine that is or either constructed orr gas-fired the state rec)of Coll combustion 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 ant maincticable tenance and consistent with technological limitations and good engineering practices over the entire life of the engine so that it achieves) ftee miissio is stubjandards required in the table below: Note that this condition may not apply actual standards under NSPS or MACTs (see Reg 7 XVI1.B.4). Note that there Note be an that in emission standard under NSPS/MACT in order for Reg 7 to not apply. pp y most cases, the NSPS/MACT standards will be the same as what would be required for Reg. 7: Emission Standard in g/hp-hr Maximum Engine Construction or CO VOC HP Relocation Date NOx ma s<100HPNMI N/A 2.0 4.0 1.0 ≥100HP and January 1, 2008 1 0 2 0 0.7 <500HP January 1, 2011 1.0 Jul 1, 2007 2.0 4.0 ≥500HP July 1, 2010 1.0 2.0 0.7 19. conductedpoint submerrged fill. (Reference: Regulation 3, Part B water into truck tanks shall be by OPERATING & MAINTENANCE REQUIREMENTS licant shall 20. Emissions points 002, 004 and 005: Upon startup of these points, the app follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoingbject to Divisionhere quire it oentss of this permit. Revisions to your O&M plan are simplementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) Page 5 of 21 AIRS ID: 123/8762/999 EOG Resources Inc. olor-1 Depa en f '.li Health and Environment Permit No. 10WE2243 II s it Pollution Control Division Issuance 1 w 21. Emission point 001: a. VCU's 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 VCU, or by other convenient means approved by the Division, determine whether the\/CU 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 and 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 VCU 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 22. Emissions point 002: 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- AIRS ID: 123/8762/999 Page 6 of 21 EOG Resources, Inc. olor Depa en f P li Health and Environment Permit No. 10WE2243 it Pollution Control Division Issuance 1 certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 23. 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: ib ben�ne tmoi. :b Sa6 HI_ benzene wt.frac.• * kfy't'3cs [.b mv� L'.i.',fsc x .',rMscf 379.3 scf f. 24. Point 004: The owner or operator shall demonstrate compliance with Condition 16 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 25. 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 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 26. Point 007: Within one hundred and eighty days(180) after issuance of permit,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. 27. Point 007: Within one hundred and eighty days(180) after issuance of permit,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. Page 7 of 21 AIRS ID: 123/8762/999 EOG Resources, Inc olor-, Depa en .f .li Health and Environment Permit No. 10WE2243 ! `' ' , it Pollution Control Division Issuance 1 • • Periodic Testing Requirements 28. 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 29. 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 sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; 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. 1. Point 005: 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 enginek. 30. 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. 31. 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 AIRS ID: 123/8762/999 Page 8 of 21 EOG Resources, Inc. olor Depa en f li Health and Environment ir.Pollution Control Division Permit No. 10WE2243 Issuance 1 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 32. 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. 33. 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. 34. 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. 35. 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. 36. 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. • 37. 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. 38. 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. Page 9 of 21 AIRS ID: 123/8762/999 EOG Resources Inc olor Depa en' .f .li 'Health and Environment Permit No. 10WE2243 �; it Pollution Control Division Issuance 1 By: Laura Strohkirch Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for a new E&P facility issued to EOG Resources, Inc. This permit encompasses points 001-007. This facility is synthetic minor for Title V and PSD. AIRS ID: 123/8762/999 Page 10 of 21 EOG Resources, Inc. � olor.�Depa en -f •li `Health and Environment , Permit No. 10WE2243 it Pollution Control Division Issuance 1 SI t. ' St IV 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.cd he state co.us/re ulations/airre s/100102a cccommon rovisionsre . df. 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 Emission Are the Controlled Rate emissions Emission AIRS Point Pollutant CAS# BIN Ibl r re�Y s 78tile? Ra 12s r Benzene 71432 A 255.5 001 803 No 40.15 n-Hexane 110543 C Benzene 71432 A 131.4 Yes 8.76 Toluene 108883 C 113.88 No 8.76 002 Xylenes 1330207 C 43.8 No 2.19 n-Hexane 110543 C 849.7 No 42.49 2,2,4 540841 C 70.08 No 3.5 Trimeth I•entane No n/a Benzene 71432 A 28.7 Toluene 108883 C 21.6 No n/a 3.6 No n/a Ethylbenzene 100414 C 003 1330207 C 9.0 No n/a Xylenes n-Hexane 110543 C 175.8 No n/a 2,2,4 540841 C 0.3 No n/a Trimeth I•entane 71432 A 6,981.4 Yes 349.1 Benzene 263.6 108883 C 5,271.5 Yes Toluene 43.3 886.3 No 004 Ethylbenzene 100414 C 109.5 1330207 C 2,189.6 Yes Xylenes 2,139.9 n-Hexane 110543 C 42,798.8 Yes 005 Formaldehyde 50000 A 53.8 Yes 26.9 Page 11 of 21 AIRS ID: 123/8762/999 EOG Resources Inc 3 olor �: Depa en` -f 1.li "Health and Environment Permit No. 10WE2243 �' it Pollution Control Division Issuance 1 Acetaldehyde 75070 A 31.2 No 15.6 Benzene 71432 A 127 Yes n/a Toluene 108883 C 416 No n/a 006 Ethylbenzene 100414 C 30.6 No n/a Xylenes 1330207 C 533 No n/a n-Hexane 110543 C 757.8 No n/a Benzene 71432 A 7.5 No 7.5 Toluene 108883 C 12.2 No 12.2 007 Ethylbenzene 100414 C 1.7 No 1.7 Xylenes 1130207 C 4.5 No 4.5 n-Hexane 110543 C 252 No 252 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 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 71432 Benzene 0.007 lb/bbl 0.0004 lb/bbl PS Memo 09-02 110543 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 002: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.1349 lb/bbl 0.0067 lb/bbl E&P Tank 71432 Benzene 9.0 x 10' lb/bbl 4.5 x 10'° lb/bbl E&P Tank 110543 n-Hexane 0.0058 lb/bbl 2.9 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 Critter Creek 2-03H well site and E&P Tank. Point 003: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 32,420 lb/MMscf Eng. Calculation natural gas vented - 71432 Benzene 74.91b/MMscf natural gas vented Eng. Calculation 108883 Toluene 56.4 lb/MMscf __ Engineering Calculation 100414 Ethylbenzene 9.4 lb/MMscf -- Engineering Calculation AIRS ID: 123/8762/999 Page 12 of 21 EOG Resources, Inc. . olor- y Depa en` -f •Ii 'Health and Environment Permit No. 10WE2243 - • r Pollution Control Division Issuance 1 Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source Engineering 1330207 Xylenes 23.5 lb/MMscf Calculation 459 lb/MMscf -- Eng. Calculation 110543 n-Hexane natural gas vented 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 10,625.0 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 Composition Factors Factors (Weight%) Uncontrolled Controlled CAS# Pollutant Source lb/MMscf Ib/MMscf natural gas natural gas vented vented NOx AP-42, Table -- 105.33 105.33 13.5-1, 1549 Btu/scf CO AP-42, Table -- 573.13 573.13 13.5-1, 1549 Btu/scf VOC Eng. 46.18 33,624 1,681.2 Calculation 71432 Benzene Eng. 0.1029 75 3.75 Calculation 108883 Toluene Eng. 0.0777 56.6 2.84 Calculation 100414 Ethylbenzene 0.0131 9.52 0.47 Eng. Calculation 1330207 Xylenes Eng. 0.0323 23.52 1.17 Calculation 110543 n-Hexane Eng. 0.6300 459.7 23 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. The controlled VOC and HAP emissions factors for point 004 are based on the flare control efficiency of 95%. Point 005: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.1662 13.5 0.475 2.025 CO 3.9871 17 0.957 4.080 VOC 0.4691 2 0.235 1.000 AIRS ID: 123/8762/999 Page 13 of 21 • EOG Resources Inc. olori Depa it en f i.li 'Health and Environment Permit No. 10WE2243 sir Pollution Control Division Issuance 1 Emission Factors - Emission Factors — Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr 50000 Formaldehyde 0.0048 0.0205 0.0024 0.01025 75070 Acetaldehyde 0.00279 0.0119 0.00279 0.0119 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a design-rated horsepower value of 162, and a fuel heat value of 1286 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP-42 AP-42 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 0.104 lb/bbl -- AP-42 71432 Benzene 0.00071b/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 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% --- AIRS ID: 123/8762/999 Page 14 of 21 "" • .li Health and Environment EOG Resources, Inc ' olor Depa en •f , it Pollution Control Division Permit No. 10WE2243 • Issuance 1 r L '. ali ' ® 0.075% Toluene Content % 0.039% 0 017% illallill Eth (benzene wt% 0.. 02% ® 0.036% IIINISI n MKS X lenes Content wt% 0.33% MIS-�® n-hexane Content wt% 0.336% *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 ® Heavy Oil Light Oil Service Component 1.1E-04 2.0E-04 7.5E-06 2.1E-04 Connectors 1.1E-04 2.9E-06 3.9E-04 3.9E-07 Ranges 1.4E-03 2.5E-04 2.0E-03 1.4E-04 Pumpend is Lines 1.3E-02 2.4E-05 Pump Seals 2.4E-03MEM g.6E-05 CIS 8.4E-06 2.5E-03 4.5E-03 1.4E-02 Other 8.8E-03 3.2E-05 7.5E-03 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. utant on 5) In accordance h this permit is valid for la term of five years. The fie- )year term for his f Notice APEN xpireson September wit 23,2015. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: Applicable Requirement Synthetic Minor Source of VOC Operating Permit S nthetic Minor Source of HAP PSD Synthetic Minor Source of VOC Major Source Requirements: Not Applicable Area Source Requirements: Not A•plicable 7) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: htto //ecfr eyoaccess eov/ Part 60: Standards of Performance for New Stationary Sources Ca 60.1-End Subpart A—Subpart KKKK Ca Part 60, Appendixes Appendix A—Appendix I Page 15 of 21 AIRS ID: 123/8762/999 � T I EOG Resources Inc olor Depar en f .li -Health and Environment Permit No. 10WE2243 •it Pollution Control Division Issuance 1 ' 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 M—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/oilgaspermitting.html AIRS ID: 123/8762/999 Page 16 of 21 EOG Resources, Inc. ' olor- Depa en .f - ''Ii Health and Environment Permit No. 10WE2243 r�j •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 AIRS ID: 123/8762/999 Page 17 of 21 EOG Resources Inc olor Depa en of P •.li Health and Environment Permit No. 10WE2243 it Pollution Control Division Issuance 1 tr. r yy P' 4 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. 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: 123/8762/999 Page 18 of 21 olor. Depa' en •f 1•li `Health and Environment EOG Resources, Inc. • r Pollution Control Division Permit No. 10WE2243 .:� Issuance 1 r . >� , e X and emission limitations, in the absence If the portable analyzer to resultsindicate he source may certify that theOe engine is iiOn compliance with both the NOX and of credible evidence to the contrary, 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 § I1.D.2 sified as attainment/maintenance or nonattainment o permanent must t Reasonably ag nabl ines that re ailable Control Technology(ed in an area that is RACT)for the pollutants for which the area is attain n t/ma must apply c Y 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 PM 10 attainment/maintenance area,RACT applies to PM I0 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 PM 10: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. Page 19 of 21 AIRS ID: 123/8762/999 EOG Resources, Inc . olor Depa'' en' f •li `Health and Environment Permit No. 10WE2243 �; it Pollution Control Division Issuance 1 Emission Standards:Section XVILE—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: Max Engine HP Construction or Emission Standards in G/hp-hr Relocation Date NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 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 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 AIRS ID: 123/8762/999 Page 20 of 21 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 10WE2243 it Pollution Control Division Issuance 1 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: 123/8762/999 Page 21 of 21 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number 10WE2175 Source Location: SESE Section 16, Township 11N, Range 63W Point 001-One (1)400BBL storage tank for produced water Point 002- Four(4) 400BBL storage tanks for crude oil Point 003-One (1)400 BBL emergency tank Equipment Description: Point 004-One (1)Tornado Flare Point 005-Crude oil and produced water truck loadout Point 007- Fugitive emissions AIRS ID: 123-8752 Initial review: March 16, 2011, Second review: September 20, 2011, Date: revised application received 1-30-2012 Review Engineer Laura Strohkirch 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 On May 23, 2011 Jake e-mailed Information Request letter to the source? David Long about the flare calculations. The mole fraction VOC had been used instead of mass fraction VOC. The caused the emissions to be underestimated and with the correct calculations facility status could change. New calculations for this facility were submitted 1-30-2012 September 15, 2010 original application was received. Revised On what date was this application complete? calculations were received 1-30- 2012 and the fugitive emissions were added 2-14-2012 Page 1 Section 4—Source Description AIRS Point Equipment Description 001 One (1) above ground 400 bbl atmospheric produced water storage tank. Emissions from this tank are controlled by a combustor with a destruction efficiency of 95%. Four(4) above ground 400 bbl atmospheric crude oil storage tank. Emissions from 002 these tanks are controlled with a J.W. 24" smokeless combustor(VCU) with 95% control efficiency. One (1) above ground 400 bbl atmospheric emergency tank.This tank is used when 003 there is a need to vent the gas rather than put it into the pipeline. There are no controls for this tank. 004 One (1) Tornado Flare that is controlling a separator. This is a 40' candlestick flare that is not enclosed and has been granted 95% destruction efficiency. 005 Crude oil and produced water truck loadout. 007 Fugitive emission 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 PM,o 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 Yes No Regulation 7, Sections XII and XVII.C may apply) Point 001: Is this source claiming exempt status for this source based on the fraction of oil in the stored water(less than 1% by volume crude oil on an average X Yes No annual basis)? Point 001: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 001: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? If so, submit Form APCD-105 Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 The source used CDPHE emission factors for the produced water tanks (PS Memo 09-02). Source used E&P Tanks along with site-specific sampling to calculate a site- 002 specific emission factor VOC E.F.= 0.2126 lb/bbl Used maximum gas vented to atmosphere along with VOC weight fraction to — 003 determine a site-specific emission factor. VOC E.F.= 32,484.8 Emission Factors for NOx, SOx, CO and PM10 came from AP-42 Tables 13.5- 004 1&2 Page 2 VOC emissions are based on a VOC weight-fraction VOC E.F.= 32,638 lb/MMscf 005 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(PTE} AIRS Point Process Consumption/Throughput/Production 001 43,800 bbl/yr(36,500 x 1.2) 002 109,500 bbl per year(91,500 x 1.2) 003 412,500 scf/yr= 0.4125 MMscf/yr 004 275,000 scf/day or 100,375,000 scf/yr or 100.4 MMscf/yr 005 127,750 bbl/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventorvi AIRS Point Process Consumption/Throughput/Production Data Year 001 36,500 bbl 2010 002 91,250 bbl per year while controls are in operation 2010 003 412,500 scf/yr= 0.4125 MMscf/yr 2010 004 275,000 scf/day or 100,375,000 scf/yr or 100.4 MMscf/yr 2010 005 127,750 bbl/yr 2010 Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 2011 Open-Ended 9 --- 7 5 Lines Pump Seals --- -- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 36,500 bbl 002 91,250 bbl 003 412,500 scf/yr= 0.4125 MMscf/yr 004 275,000 scf/day or 100,375,000 scf/yr or 100.4 MMscf/yr 005 127,750 bbl/yr Page 3 Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals -- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Does this source use a control device? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 J.W. 24" Smokeless Combustor(VCU), SN 24183-13 95 002 01 J.W. 24" Smokeless Combustor(VCU) 95 004 01 Tornado,40' Flare Stack, SN 07CSADA4X507243 95 — Section 6— Emission Summa (tons per year) Point NO, VOC CO Single HAP Total HAP PTE: 001 5.7 0.48 (n-hexane) 0.64 002 0.03 11.6 0.18 0.07 (benzene) 003 6.7 004 5.3 1638.1 28.6 24.3 (n-hexane) 32.3 005 6.5 0.26 (n-hexane) 0.71 007 2.4 0.1 (n-hexame) 0.1 Uncontrolled point 001 4.8 0.4 (n-hexane) 0.43 source emission rate: 002 .03 9.7 0.18 003 6.7 004 5.3 1638.1 28.6 24.3 (n-hexane) 32.3 005 6.5 0.26 (n-hexane) 0.71 007 2.4 0.1 (n-hexame) 0.1 Controlled point 001 0.24 0.13 (n-hexane) 0.03 source emission rate: 002 .03 0.48 0.18 003 6.7 004 5.3 81.9 28.6 1.2 (n-hexane) 1.6 005 6.5 0.26 (n-hexane) 0.71 007 2.4 0.1 (n-hexame) 0.1 Total APEN Reported 8.18 98.22 28.78 2.41 emissions: Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions (Iblyr) reportable? Rate(Ib/yr) Page 4 POINT 001 Benzene 71432 A 255.5 Yes 12.8 n-Hexane 110543 C 803 No 40.2 POINT 002 Benzene 71432 A 122.64 Yes 6.13 Toluene 108883 C 113.88 No 5.69 Xylenes 1330207 C 43.8 No 2.19 n-Hexane 110543 C 832.2 No 41.61 2,2,4 Trimethylpentane 540841 C 70.08 No 3.5 POINT 003 Benzene 71432 A 34.7 - No NA n-Hexane 110543 C 199.5 No NA POINT 004 Benzene 71432 A 8,459.7 Yes 423 108883 C 5782.5 Yes 289.1 Toluene 40.8 Ethylbenzene 100414 C 815.2 No Xylenes 1330207 C 1,771 Yes 88.5 n-Hexane 110543 C 48,574 Yes 2,428.7 POINT 005 Benzene 71432 A 87.68 No NA Toluene 108883 C 287.11 No NA Ethylbenzene 100414 C 21.15 No NA Xylenes 1330207 C 381.96 No NA n-Hexane 110543 C 523.37 No NA POINT 007 Benzene 71432 A 8 No 8 C 12 No 12 Toluene 108883 Ethylbenzene 100414 C 2 No 2 Xylenes 1130207 C 4 No 4 n Hexane 110543 C 252 No 252 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used b the o erator. Section 8—Testin Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below Test Method AIRS Point Process Pollutant Regulatory Basis Site-specific 002 01 VOC CDPHE PS Memo 05-01 sam lin Page 5 003 01 VOC & State-only requirement Site-specific gas HAP's analysis 004 01 VOC & State-only requirement Site-specific gas HAP's analysis 007 at VOC, State only requirement Site-specific gas HAPS analysis 007 01 VOC, State only requirement Hard component HAPS count Section 9—Source Classification Is this a new previously un-permitted X Yes No source? What is this point classification? True Minor Synthetic Minor Major Point 001: One (1)400 BBL fixed roof X produced water storage tank Point 002: Four(4) above ground 400 bbl atmospheric crude oil storage X tank Point 003: One (1) above ground 400 X bbl atmospheric emergency tank Point 004: One (1) Tornado Flare X Point 005: Crude oil and produced X water truck loadout Point 007: Fugitive emissions X 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? If"yes" what kind of modification? Minor Synthetic 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 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? • Page 6 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 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, 001-007 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 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. 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 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 001-007 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 points 001-007 since emissions exceed 2 tons per year VOC) Part B—Construction Permit Exemptions Applicant is required to obtain a permit for points 001-007 since uncontrolled VOC 001-007 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 This section of Regulation 3 requires RACT for new or modified minor sources located in 005 nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone attainment area, therefore, not subject to RACT. However, operator is using 0.6 (submerged, dedicated normal service) for its saturation factor. Regulation 6- New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 001,002,003 Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No 004,005 none NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities (any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids (NGLs) or both). 007 Is this source at a "natural gas processing plant?" No Is this source subject to NSPS KKK? No WHY? Facility not defined as a natural gas processing plant, therefore, does not meet the criteria of NSPS KKK. Page 7 Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS 001-007 (Facility is not located in the 8-hr ozone control area; therefore, it is not subject to section XII of this regulation.) XVILC STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Facility does not operate any equipment subject to section XVII of this regulation.) Regulation 8— Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution • This source is not subject to MACT EEEE because it is located at a "production 002, 003 field facility" as defined in 40 CFR 63.761 (located upstream of the natural gas processing plant). MACT HH 002,003 • This source is not subject to MACT HH because it is not located at a major source of HAP. 004-005, none 007 I Section 13—Aerometric Information Retrieval System Coding Information Process Process Description Emission Factor Pollutant/ Fugitive Emission Control Point CAS# (Y/N) Factor Source (/o) 6.2381 lb/1000 gal V0C No CDPHE PS 95 throughput Memo 09-02 01 Produced Water 0.1667 lb/1000 gal Benzene No CDPHE PS 95 001 Storage Tanks throughput Memo 09-02 0.5238 lb/1000 gal n-Hexane No CDPHE PS 95 throughput Memo 09-02 SCC 40400315— Fixed Roof Tank, Produced Water,working+breathing+flashing losses Pollutant/ Fugitive Emission Point Process Process Description Emission Factor Control CAS# (Y/N) Factor Source (%) 5.06 lb/1000 gal V0C No Site-specific 95 01 Crude Oil Storage throughput 002 Tanks 0.02 lb/1000 gal Benzene No Site-specific 95 throughput SCC 40400312—Fixed Roof Tank, Crude Oil, working+ breathing + flashing losses Process Process Description Emission Factor Pollutant/ Fugitive Emission Control p Point CAS# (Y/N) Factor Source (%) 32,484.8 lb/MMscf V0C No Mass Balance NA 01 Emergency Tank 84.12 lb/MMscf Benzene No Mass Balance NA 003 483.6 lb/MMscf n-Hexane No Mass Balance NA SCC 31000299-Natural Gas Production: other, not classified Process Process Description Emission Factor Pollutant/ Fugitive Emission Conntrol A) 32,638 lb/MMscf V0C No Mass Balance 95 004 01 Tornado Flare 105.3 lb/MMscf N0x No AP-42 NA 573.1 lb/MMscf CO No AP-42 NA Page 8 0.57 lb/MMscf SOx No AP-42 NA 84.3 lb/MMscf Benzene No Mass Balance 95 57.6 lb/MMscf Toluene No Mass Balance 95 17.6 lb/MMscf Xylenes No Mass Balance 95 484 lb/MMscf n-Hexane No Mass Balance 95 SCC 31000205—Flares (at gas production facility) Pollutant/ Fugitive Factor Source Emission Control Point Process Process Description Emission Factor CAS# IN Crude Oil and Produced No AP-42 NA 01 Water Tank Truck 2.44 lb/1000gal VOC 005 Loadout SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Control Pollutant/ Fugitive Emission Factor Source °APoint Process Process Description CAS# EPA-453/R-95-017, NA 01 Fugitive VOC Emissions VOC Yes Table 2-4 007 Leak Fu itives (Valves, flanges, connections,seals, drains) SCC 31000220: All Equip. 9 Section 14— Miscellaneous A. •lication Notes AIRS Point 001 Operator originally requested this point to be a General Permit; however, having the general permit emission limit of 39TPY for VOC would have made them a major source so operator requested that the point be added to the facility-wide construction permit so actual, controlled emissions would be accounted for instead of the general permit limit. State-Develo•ed Emission factors in Ib11000 •al are: Produced Water Tank Default Emission Factors lb/1000 .al VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Dou•las, Jefferson, Larimer and Weld The APEN states that the tanks contain less than 1% by volume crude oil on an annual average basis which qualifies the source for the categorical exemption (Regulation 3, Part B, Section II.D.1.m). However, this source will be permitted because if it was not controlled, the overall permitted VOC emissions would b ty. The ator hs synthetic minor s at greater 100 major ili and accepted Federally enforceable controls, so this point rwi l be included to d ensures nthetic minor eli•ibilit . AIRS Point 002 Crude Oil Tanks These tanks contain oil with an API gravity less than 40 degrees. EOG used E&P Tank to estimate the flash emissions off this tank battery. From E&P Tank- uncontrolled ton/year= 9.698 TPY VOC VOC=(9.698 TPY)*(2000lb/ton)/(91,250 bbl/yr)= 0.2126 Iblbbl VOC or 5.06 lb/1000 gallons Page 9 AIRS Point 003 Emergency Tank Gas going to the flare would be routed to this tank in case of a flare outage. The gas is vented to atmosphere from this tank. The APEN was submitted with worse-case scenario calculations. This consists of 3 upset conditions in a 12 month period. Each instance of upset conditions was estimated to be 12 hours in length. Max gas vented to atmosphere= 11,458.3 scf/hr Molecular wt. of gas= 27.3 lb/lb-mole VOC fraction= 0.4525 379.4 scf/lb-mole VOC= 11,458.3 scf/hr*( 27.3 lb/lb-mole)/(379.4 scf/Ib-mole)*0.4525= 373.8 lb/hr VOC Using the 3 upset conditions at 12 hrs per condition: 373.8 lb/hr*(12 hr/event)* (3 events/yr)/(2,000lb/ton)= 6.7 tpy VOC VOC E.F.: 6.7 ton/yr*( 2,0001b/ton)/(0.4125 MMscf/yr)= 32,484.8 lb/MMscf AIRS Point 004 Tornado Flare The tornado flare is controlling gas coming off the 3-phase separator since there is no pipeline available in the area at this time. This is a 40' candlestick type flare that is not enclosed and has been granted 95% destruction efficiency as is Division policy for this type of source since no testing can be done to verify great efficiency. EOG will continue to flare gas until a pipeline is available. Emissions were calculated using VOC wt fraction. (scf/hr) * (Ib/Ib-mol) * (% fraction from sales gas analysis)/(379.4 scf/lb-mol) = lb/hr* (hr/yr)/2000 Ib/T) = TPY Emission factors for NOx, CO, and PM10 came from AP-42, table 13.5-1 Emission factor for SOx also came from AP-42 and is based on 100% conversion of sulfur to SO2 at 2000 grains/MMscf VOC E.F. = (1638.1 TPY* 2000 lb/T)/ (100.38 mmscf/yr) = 32,638 lb/MMscf HAP's Emission Factors: Benzene = (8,459.7 lb/yr) / 100.38 MMscf/yr= 84.3 lb/MMscf Toluene = (5,782.5 Ib/yr)/ 100.38 MMscf/yr= 57.6 lb/MMscf Ethylbenzene= (815.2 lb/yr) / 100.38 MMscf/yr= 8.1 lb/MMscf Xylenes= (1,771 Ib/yr) / 100.38 MMscf/yr= 17.6 lb/MMscf n-hexane = (48,574 Ib/yr) / 100.38 MMscf/yr= 484 lb/MMscf Page 10 AIRS Point 005 Truck Loadout of Crude Oil and Produced Water Converting the Ib/1000gallon factor to lb/bbl: 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 4.89 psia M 34.91 lb/lb-mole for gasoline with RVP = 11.5 T 523 deg. R (64 deg. F) L 2.441b/10^3 gal Annual requested Throughput 5,365,500ga1/yr Annual requested VOC emissions 13,000lb/yr 6.5tpy AIRS Point 007 Fugitive VOC Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (APEN threshold) and the total facility is greater than 5 TPY (permit threshold). When another engineer working on EOG sites reviewed calculations for a similar facility, they noticed that the fugitive emissions were calculated wrong. These errors triggered fugitives in attainment facilities to be permit-required (increase from 1.5 TPY to 2.4 TPY VOC). EOG submitted APENS for the fugitive emissions on 2/14/12. Points 001-005, 007: No monthly limits will be put in the permit even though this is a synthetic minor source. After discussing this source with Chris Laplante 3-8-2011 it was decided that production at an E&P site is not steady enough to impose those kinds of limits. Compliance with monthly limits may not be possible, while a yearly limit is. Page 11 N 2 . C 2 tl d c ° E C�a't .G E ° a w O CO vl ^ G rl aC '1' T O. en O L o• r .:1' r- -. ... o i f S'4 7 G W m y Z y N N N C C N �_ u .0 Q. .� 1. Q X ti 0.Wia °°i Z. ,0 VD �a y I rib I. 3 '�'` 2 on. 00�' 0 G U a d ,�n. �° E n m m o N Cr, 3. 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A c, = r'tci t3 ,, o U u U - w .. = C e y R \ O i.y 1 W .. 3 rci ° O O .�, U 6. y u 0 , W ._ a '° -o E o o o. .. oo o o a E °v '� N c 7 O p 0 ° °_' x a o o @se 2 o n o U F E a �n 0.' 6 0 `� o Z > U o " T Z =o •b am a ❑ W ❑ O ❑ W . . ,� w -- m ti rn • Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit j_ OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY' )L_ Current Status(Check a l that app y) Reason for MEN Submittal(Check all that apply) !1 5 VAC AIRS ID#': IaiIfl5a�coa ❑ MEN update only° ® New or previously un eported battery ❑ Modification to existing sources APC D ❑ Previously grandfathered battery ❑ Registration for coverage under general permit no.GPO1 Static): r ❑ Synthetic minor facility &cancellation request for individual permit6: Sit:-, ❑ Located in the 8-br Ozone Control Area3 ® Application for or Modification of an individual permit _.. ❑ Registered under general permit no.GP01 ❑ Administrative permit amendment° Permitted under individual permit:4101..J a 911 S ❑ Other: R.Cr. For individual permit applications,check if you want8: ❑A copy of the preliminary analysis conducted by the Division k ti - -.) ❑To review a draft of the permit prior to issuance Company Name9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 17th Street,Suite 1000N david_long@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.comlb Contact Name: David Long Phone: 303-262-9448 Fax: 303-262-9449 cp Tank Battery Name I: Red Poll 10-16H Number of tanks: 4 c ,� Location l2(QQ Sec.Twp.Range.): SESE Sec 16,Tl1N,R63W County: Weld Total tank capacity[bbl]: 1,600(400 ea) S ,3 Calendar year for which"Actual"data applies13: 2010 - µl71 l Year(s)tank(s)were placed in service": 2010 £ Control Descriptions: 7.W.24"Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency6: 95% - Id Condensate Throughput"[bbl/year] Requested1s: 455;500 61 1 4 a SO Maximum for PTE calculation": 996;808 lo 1 530 1. Cn.kil? u�1 Actual": -235300_ 41, 5p While Controls Operational"t 255500- (7) 0 Other equipment at facility32: VCU,flare,heater treater(I),line beater(1),produced H2O tank(1),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 NM for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. 0 Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emissions1s Actual Emissions20 Pollutant24 [lb/bbl] PTE25 Uncontrolled26 Controlled" Uncontrolled26 Controlled" VOC[tons/year] O.al l.la 0.3139 it,la 481 N/A N/A ,c[,'7,0d 0,i4Sf 28 NOx[tons/year] N/A u.0:i -0,08— n.137, 0:08 . . ,, 0708 . CO[tons/year] N/A D. t Or41- o.t g- 9A2 D.w, 9342 Benzene[lbs/year] 0,330S c)-02 (I,(10 0. 003 n-Hexane[lbs/year] Wells serviced by this tank or tank battery2s API#: 05-123-30749 Name: Red Poll 10-16H ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well '—' API#: Name: 0 Newly Reported Well N CO API#: Name 0 Newly Reported Well so API#: Name: ❑Newly Reported Well Cr ND API#: Name: ❑Newly Reported Well 0 :ND N 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 my knowledge and belief. If this is a regis.tion for coverage under general permit GPO I,I further certify that this source is and will be operated roin full c‘stptl-ance with each c. tio. : general permit GPOI. el Z i /p 9— ,p o Siy.: . e eg- . t.o. Perso. .ot a vendor or consultant) Date o Davi. ong Division Environmental Manager Li-'i o Type or Print Name of Person Signing Above - Official Title r Submit this form along with$152.90 for each Colorado Department of Public Health and Environment '+. '7 For information call: u-: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B1 - (303)692-3150 o $250 General Permit fee for each new GP 4300 Cherry Creek Drive South r istration to: Denver,CO 80246-1530 FORM APCD-205 I Page 1 of 2EOG Red Poll 10-16H ForrnAPCD-205-E&PCondensateTankAPEN.docx N F .2v _ I.. w - ♦ 4 13 I a O T m °. E vl era— B t ai 0 as F W ❑ •� C W b°y - N eV N G' G N 'U O \ O e G. C _ a as-0, O O y ? 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O 4 > O V N O Lc y 00 x. r e -,_ STATE OF COLORADO p sT�h�. :' ' .'.. /V.OF•cOZON COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT 4 e AIR POLLUTION CONTROL DIVISION a TELEPHONE: (303)692-3150 A+i *1876 4a CONSTRUCTION PERMIT PERMIT NO: 1 0WE2175 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 the Red Poll 10-16H, located at SESE Section 16, 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 PW Tank One (1) above ground 400 bbl atmospheric produced water storage 001 tank. Emissions from this tank are controlled by a J.W. 24" #1 smokeless combustor with a destruction efficiency of 95%. Crude Oil Four (4) above ground 400 bbl atmospheric crude oil storage tank. 002 Emissions from these tanks are controlled with a J.W. 24" Tanks smokeless combustor with 95% control efficiency. One (1) 400 BBL well blowdown tank (Manufacturer: Conner, ET#3372 003 Model: EOG #3372, Serial No: 25395). This tank is only used when the produced gas cannot be combusted in the flare. There are no controls for this tank. One (1) Tornado flare (Manufacturer: Tornado, Model No: 40' Flare Flare 004 Stack, Serial No:07CSADA4X507243) used to combust produced gas vented from a three-phase separator. Truck 005 Truck loadout of crude oil and produced water. Loadout Fugitive 007 Equipment leaks (fugitive VOC) 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: AIRS ID: 123/8752/999 Page 1 of 14 Condensate Tank Version 2009-1 • E0G Resources Inc olor Depa en r 1 °.li `Health and Environment Permit No. 10WE2175 ` ?r. •it Pollution Control Division Issuance 1 2 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: • 4.2 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 (V0C), 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) AIRS ID: 123/8752/999 Page 2 of 14 EOG Resources, Inc i' olor Depa en .f P A.li 'Health and Environment Permit No. 10WE2175 v 'it Pollution Control Division Issuance 1 Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO PW Tank#1 001 - 0.24 - Point Crude Oil 002 - 0.48 - Point Tanks ET#3372 003 - 6.7 - Point Flare 004 5.3 81.9 28.6 Point Truck Loadout 005 - 6.5 - Point Fugitive 007 - 2.4 - Fugitive Annual Limits: 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, 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 a J.W. 24" smokeless flare that reduces emissions of VOC to the emission levels listed in this section, 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 002: Emissions from this point shall be routed to a J.W. 24" smokeless combustor vapor combustion unit (VCU). The combustor shall be capable of reducing uncontrolled emissions of VOC from the crude oil tanks to the emission levels listed in this section, above. 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 004: This emissions point is a separator controlled by a 40' open flare stack. The flare shall be capable of reducing emissions of VOC to the emission levels listed in this section, above. 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 007: 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 AIRS ID: 123/8752/999 Page 3 of 14 EOG Resources Inc. olor-.i Depa en f lili 'Health and Environment Permit No. 10WE2175 4` it Pollution Control Division Issuance 1 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 11. This source shall be limited to the following maximum processing rates as listed below. Annual 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 PW Tank 001 Produced water throughput 36,500 BBL/yr #1 Crude Oil 002 Crude oil throughput 91,250 BBL/yr Tanks ET#3372 003 Natural gas vented to atmosphere via 0.413 MMscf/yr emergency tank Flare 004 Natural gas flaring 100.4 MMscf/yr Truck 005 Crude oil and produced water loading 127,750 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 monthly condensate throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 12. Point 001: Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained for a consecutive period of three years. 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. 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. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/8752/999 Page 4 of 14 EOG Resources, Inc olor Depa en" .f 'Ii 'Health and Environment Permit No. 10WE21755aAir Pollution Control Division Issuance 1 17. Emissions point 005: the loading of crude oil and condensate into truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Emissions points 002 and 004: 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 001: a. VCU's 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 VCU, or by other convenient means approved by the Division, determine whether the VCU 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 and 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 VCU 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. AIRS ID: 123/8752/999 Page 5 of 14 EOG Resources, Inc. olor + r Depa en .f , .li Health and Environment Permit No. 10WE2175 '. ' it Pollution Control Division Issuance 1 COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 20. Emissions point 002: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude 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. 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: Pb benzene lb rno:. !b 106 scf x ,r,Hsc = benzene wt.frac.* 3;s.3 scj*�t1 WVWas {lb mod 1ht,xscJ, 22. 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 I I.A.5). 23. Point 007: Within one hundred and eighty days(180) after issuance of permit,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. 24. Point 007: Within one hundred and eighty days (180) after issuance of permit, 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. ADDITIONAL REQUIREMENTS 25. 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: AIRS ID: 123/8752/999 Page 6 of 14 EOG Resources Inc olor Depat?. en f P •li `Health and Environment Permit No. 10WE2175 �' it Pollution Control Division Issuance 1 `' 4, 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. 26. 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. 27. 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 28. 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. 29. 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. 30. 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 AIRS ID: 123/8752/999 Page 7 of 14 EOG Resources Inc olor- a' Depa en -f i•li 'Health and Environment Permit No. 10WE2175 = it Pollution Control Division • Issuance 1 • 11111 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. 31. 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. 32. 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. 33. 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. 34. 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: �� C WNI,a. Laura Strohkirch Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for a new E&P new synthetic minor facility issued to EOG Resources. This permit encompasses points 001-005 and 007. This facility is synthetic minor for Title V and PSD. AIRS ID: 123/8752/999 Page 8 of 14 EOG Resources, Inc. ' • olor ��'t. Depa en'` .f li i. -Health and Environment Permit No. 10WE2175 �' it Pollution Control Division Issuance 1 ; w 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.cd phe.state.co.us/req u lations/ai rregs/100102agcccom m on provision sreq.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 Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (lb/yr) reportable? Rate (lb/yr) Benzene 71432 A 255.5 Yes 12.8 001 Hexane 110543 C 803 No 40.2 Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission _ Point Pollutant CAS# BIN (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 122.64 Yes 6.13 Toluene 108883 C 113.88 No 5.69 002 Xylenes 1330207 C 43.8 No 2.19 n-Hexane 110543 C 832.2 No 41.61 2'2,4 540841 C 70.08 No 3.5 Trimethylpentane Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (Ib/yr) reportable? Rate (Ib/yr) Benzene 71432 A 34.7 No NA 003 n-Hexane 110543 C 199.5 No NA AIRS ID: 123/8752/999 Page 9 of 14 EOG Resources, Inc olor D .li Health' and Environment Permit No. 10WE2175 � �'` epa en f it Pollution Control Division Issuance 1 l' k a II Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (Ib/yr) reportable? Rate (Ib/yr) Benzene 71432 A 8,459.7 Yes 423 Toluene 108883 C 5782.5 Yes 289.1 004 Ethylbenzene 100414 C 815.2 No 40.8 Xylenes 1330207 C 1,771 Yes 88.5 n-Hexane 110543 C 48,574 Yes 2,428,7 Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 87.68 Yes NA Toluene 108883 C 287.11 No NA 005 Ethylbenzene 100414 C 21.15 No NA Xylenes 1330207 C 381.96 No NA n-Hexane 110543 C 523.37 No NA Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 8 No 8 Toluene 108883 C 12 No 12 007 Ethylbenzene 100414 C 2 No 2 Xylenes 1130207 C 4 No 4 n-Hexane 110543 C 252 No 252 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 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 71432 Benzene 0.007 lb/bbl 0.0004 lb/bbl PS Memo 09-02 110543 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: 123/8752/999 Page 10 of 14 • EOG Resources Inc II olor ? _. Depa , en sf P i.li Health and Environment Permit No. 10WE2175 .y '•. '•a Pollution Control Division Issuance 1 �;: 1 Point 002: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.2126 lb/bbl 0.01 lb/bbl E&P Tank 71432 Benzene 8.0 x 10-° lb/bbl 4.0 x 10-' lb/bbl E&P Tank 110543 n-Hexane 0.0091 lb/bbl 4.5 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 Critter Creek 2-03H well site and E&P Tank. Point 003: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 32,484.8 lb/MMscf -- Eng. Calculation 71432 Benzene 84.12 lb/MMscf -- Eng. Calculation 108883 Toluene 57.5 lb/MMscf -- Eng. Calculation 100414 Ethylbenzene 8.0 lb/MMscf -- Eng. Calculation 1330207 Xylenes 17.7 lb/MMscf -- Eng. Calculation 110543 n-Hexane 483.6 lb/MMscf -- Eng. Calculation natural gas vented 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 11,458.3 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 Composition Factors Factors CAS# Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf lb/MMscf natural gas natural gas vented vented NOx AP-42, Table -- 105.33 105.33 13.5-1, 1549 Btu/scf CO AP-42, Table -- 573.13 573.13 13.5-1, 1549 Btu/scf VOC Eng. 45.25 32,638 1,631.9 Calculation 71432 Benzene 0.12 84.3 4.22 Eng. Calculation 108883 Toluene 0.08 57.6 2.88 Eng. Calculation 100414 Ethylbenzene 0.01 8.1 0.41 Eng. Calculation 1330207 Xylenes 0.02 17.6 0.88 Eng. Calculation AIRS ID: 123/8752/999 Page 11 of 14 • EOG Resources, Inc A olor. Depa en f P .li `Health and Environment Permit No. 10WE2175 > it Pollution Control Division Issuance 1 Natural Gas Emission Emission Composition Factors Factors CAS# Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf lb/MMscf natural gas natural gas vented vented 110543 n-Hexane 0.67 484 24.2 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. The controlled VOC and HAP emissions factors for point 004 are based on the flare control efficiency of 95%. Point 005: 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 0.102 lb/bbl -- AP-42 71432 Benzene 0.0007 lb/bbl -- AP-42 108883 -Toluene 0.0022 lb/bbl -- AP-42 1330207 Xylenes 0.0030 lb/bbl -- AP-42 110543 n-Hexane 0.0041 Ib/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) = 4.89 psia M (vapor molecular weight) = 34.91 Ib/Ib-mol T (temperature of liquid loaded) = 523 °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: 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(wt%) 0.336% --- 2.43% --- AIRS ID: 123/8752/999 Page 12 of 14 EOG Resources Inc olor Depa en' +f f•li ' Health and Environment Permit No. 10WE2175 ' it Pollution Control Division Issuance 1 t 11IF `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 September 14,2015. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: Applicable Status Requirement Synthetic Minor Source VOC Operating Permit Synthetic Minor Source of HAP PSD Synthetic Minor Source VOC MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 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 AIRS ID: 123/8752/999 Page 13 of 14 • EOG Resources Inc { olor , Depa en` .1 ''Ii "Health and Environment Permit No. 10WE2175 �` r Pollution Control Division Issuance 1 �' 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/oilgaspermitting.html • AIRS ID: 123/8752/999 Page 14 of 14 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3133 Source Name: Garden Creek 02-06H Source Location: SESE Sec. 6,T11 N, R62W, Northern Weld County inside Attainment Area. Point 001 -Six (6)400BBL fixed roof crude oil storage tanks Point 002—Crude oil truck Loadout Point 003—Fugitive Emissions Equipment Description: Point 004 - One (1)Tornado 40' Flare Stack Point 005— One (1) 400 BBL Conner emergency tank, model #4466, Serial number 30798 used for natural gas blow-downs when the flare shuts down Point 006 One (1)400 BBL produced water tank AIRS ID: 123/9321/001-006 Date: December 20, 2011 Review Engineer: Laura Strohkirch 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? Yes X No If you answered "no"to any of the above, when did you mail an January 3, 2012 Information Request letter to the source? On what date was this application complete? August 9, 2011 Section 4—Source Description AIRS Point Equipment Description Point 001 — Point 001 -Six (6)400BBL fixed roof crude oil storage tanks Point 002 Point 002-Crude oil truck Loadout Point 003 Point 003—Fugitive Emissions Point 004 Point 004 -One (1) Tornado 40' Flare Stack 123/9321/001-006 Page 1 11WE3133 Point 005 Point 005—One(1)400 BBL Conner emergency tank, model #4466, Serial number 30798 used for natural gas blow-downs when the flare shuts down Point 006 Point 006—One (1) 400 BBL produced water tank Is this a portable source Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? Is this location in an attainment maintenance area for Yes X No any criteria pollutant? Is this source located in the 8-hour ozone non- attainment region? Yes X No 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. 001 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. 002 AP-42, Table 5.2-1, equation 1 003 Fugitive emissions calculated using connection hard count and EPA-453/R-95- 017 emission factors. Emission Factors for NOR, CO and PM10 are from AP-42 Tables 13.5-1&2. VOC emissions are based on a VOC weight-fraction from gas analysis. Emissions controlled by Tornado 40' Flare Stack at 95% efficiency. 004 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 emissions are based on a VOC weight-fraction from gas analysis. Permit will include a 0.13695 MMscf yearly venting limit. 005 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. 006 State emission factors for produced water tanks in Weld County, PS memo 09-02 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Limits 001 63,247 bbl/yr (52,706 x 1.2) crude oil throughput 002 89,425 bbl/yr truck Loadout Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 432 0 390 39 003 Flanges 4 0 24 4 Open-Ended Lines 9 0 7 5 Pump Seals 0 0 0 0 Valves 42 0 54 18 Other 26 0 12 4 123/9321/001-006 Page 12 11WE3133 004 33.32 MMscf/yr(91,300 scf/d) natural gas venting to flare 005 0.13695 MMscf/yr (3,804.16 scf/hr vent rate x 3 events x 12 hours per event) emergency venting through blow down tank. 006 36,610 bbl/yr produced water throughout Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) -- All Points Newly Constructed -- Basis for Permitted Emissions (Permit Limits) AIRS Point Process Limits 001 52,706 bbl/yr crude oil throughput 002 89,425 bbl/yr truck loadout Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 432 0 390 39 003 Flanges 4 0 24 4 Open-Ended Lines 9 0 7 5 Pump Seals 0 0 - 0 0 Valves 42 0 54 18 Other 26 0 12 4 004 33.32 MMscf/yr(91,300 scf/d) natural gas venting to flare 005 0.13695 MMscf/yr (3,804.16 scf/hr vent rate x 3 events x 12 hours per event) emergency venting through blow down tank. 006 36,610 bbl/yr produced water throughput Does this facility use control devices? X Yes No AIRS Point Control Device Description Reduction Granted 001 Cimarron Smokeless Combustor (vapor combustion unit [VCU]) 950/ Serial Number 1331258 004 Tornado, 40' Flare Stack 95% 006 Cimarron Smokeless Combustor (vapor combustion unit [VCU]) 95% Serial Number 1331258 Section 6—Emission Summary (tons per year) Point NO, VOC CO Single HAP Total HAP 001 --- 8.1 --- 0.3 n-Hexane 0.5 002 --- 5.2 --- 0.2 n-Hexane 0.3 003 -- 6.2 --- 0.3 n-Hexane 0.5 PTE: 004 --- 560.5 -- 7.6 n-Hexane 10.4 005 --- 2.3 --- --- -- 006 --- 4.8 --- 0.4 n-Hexane 0.5 Total --- 587.1 --- 8.8 12.2 001 --- 6.8 --- 0.3 n-Hexane 0.4 Uncontrolled point 002 --- 5.2 --- 0.2 n-Hexane 0.3 source emission rate: 003 --- 6.2 --- 0.3 n-Hexane 0.5 004 --- 560.5 --- 7.6 n-Hexane 10.4 • 123/9321/001-006 Page 13 11WE3133 005 --- 2.3 --- --- --- 006 --- 4.8 --- 0.4 n-Hexane 0.5 Total --- 585.8 --- 8.8 12.1 001 --- 0.3 --- --- 002 --- 5.2 --- 0.2 n-Hexane 0.3 Controlled point 003 --- 6.2 --- 0.3 n-Hexane 0.5 source emission 004 1.7 28.0 9.4 0.4 n-Hexane 0.5 rate: 005 --- 2.3 --- --- --- 006 --- 0.2 --- --- --- Total 9.4 42.2 1.7 0.9 1.3 Non-Criteria Reportable Pollutants Uncontrolled Are the Controlled Pollutant CAS # BIN Emission Rate emissions Emission Rate (lb/yr) reportable? (Ib/yr) Point 001 Benzene 71432 A 105 Yes 5 Toluene 108883 C 53 No 3 n-Hexane 110543 C 578 No 29 2,2,4-TMP 540841 C 53 No 3 Point 002 Benzene 71432 A 71 Yes --- Toluene 108883 C 62 No --- Xylenes 1330207 C 23 No --- n-Hexane 110543 C 478 No --- 2,2,4-TMP 540841 C 39 No --- Point 003 Benzene 71432 A 83 Yes --- Toluene 108883 C 189 No --- E-Benzene 100414 C 12 No --- Xylenes 1330207 C 224 No --- n-Hexane 110543 C 516 No --- Point 004 Benzene 71432 A 2,497 Yes 125 Toluene 108883 C 1,885 Yes 94 . E-Benzene 100414 C 317 No 16 Xylenes 1330207 C 783 No 39 n-Hexane 110543 C 15,294 Yes 765 123/9321/001-006 Page 14 11WE3133 Point 005 Benzene 71432 A 10 No --- Toluene 108883 C 8 No -- n-Hexane 110543 C 63 No --- Point 006 Benzene 71432 A 256 Yes 13 n-Hexane 110543 C 805 No 40 Note: Reg. 3, Part A, II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Is testing required to show compliance with any emission rate or regulatory X Yes No standard? AIRS Point Process Pollutant Regulatory Basis Test Method Site-specific gas 001 01 VOC CDPHE PS Memo 05-01 sampling Site-specific gas 004, 005 01 VOC, HAPs State only requirement analysis Section 9-Source Classification Is this a new previously 001 002 003 004 005 006 un-permitted source? Yes Yes Yes Yes Yes Yes Point classification True Minor X X X --- X X Synthetic Minor --- --- --- X --- --- Major --- --- --- --- --- -- Facility Classification Synthetic Minor Classification related to Title V, PSD Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No Reason For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? Yes X 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)? 123/9321/001-006 Page 15 11WE3133 • 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 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, 001-006 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 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. 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 in an attainment area. Part B -Construction Permit Exemptions 001-006 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 VOC threshold(Reg. 3, Part B, Section 11.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, 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. • Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS 001, 005, Applicant is not subject to the emission control requirements for condensate tanks 006 because this facility is located in an attainment area. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... This facility does not operate any equipment subject to section XVII of this regulation. Regulation 8—Hazardous Air Pollutants 001-006 None 123/9321/001-006 Page 16 11WE3133 Section 13—Aerometric Information Retrieval System Coding Information Process Pollutant/ Fugitive Emission Control Point Process Description Emission Factor CAS# (Y/N) Factor Source Eff. 6.1094 lb/1000 gal. V0C 0.0475 lb/1000 gal. Benzene 01 E&P Crude Oil 0.0237 lb/1000 gal. Toluene No E&P Tanks 95% 001 Storage Tanks 0.2612 lb/1000 gal. n-Hexane 0.0237 lb/1000 gal. 2,2,4 TMP SCC 40400311 — Fixed Roof Tank, Oil field storage of crude, breathing losses Process Emission Factor Pollutant/ Fugitive Emission Control Point Process Description CAS# (YIN) Factor Source Eff. 2.7877 lb/1000 gal. V0C 0.0190 lb/1000 gal. Benzene Crude Oil and 0.0166 lb/1000 gal. Toluene 01 Produced Water No AP-42 NA 002 Tank Truck , 0.0061 lb/1000 gal. Xylenes Loadout 0.1273 lb/1000 gal. n-Hexane 0.0104 lb/1000 gal. 2,2,4-TMP SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Process Pollutant/ Fugitive Emission Factor Control Point Process Description CAS# (Y/N) Source Eff. 01 Fugitive V0C Yes EPA-453/R-95-017 NA 003 Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Process Pollutant/ Fugitive Emission Control Point Process Description Emission Factor CAS# (Y/N) Factor Source Eff. 33633.7106 lb/MMscf V0C 74.9096 lb/MMscf Benzene 56.5620 lb/MMscf Toluene Mass Balance 95% Produced gas 9.5094 Ib/MMscf Ethylbenzene 01 vented to flare No 004 23.4939 lb/MMscf Xylenes 458.8522 lb/MMscf n-Hexane 0.0680 lb/MMBtu N0x AP-42 NA , 0.3700 lb/MMBtu CO SCC 31000205—Flares (at gas production facility) 123/9321/001-006 Page 17 11WE3133 Process Pollutant/ Fugitive Emission Factor Control Point Process Emission Factor Description CAS# (YIN) Source Eff. 33633.7106 lb/MMscf VOC 74.9096 lb/MMscf Benzene 01 Natural gas blow 56.5620 Ib/MMscf Toluene down venting No Mass Balance NA 005 - 9.5094 lb/MMscf Ethylbenzene 23.4939 lb/MMscf Xylenes 458.85221b/MMscf n-Hexane SCC 31000299— Natural Gas Production: Other not classified Process Pollutant/ Fugitive Emission Factor Control Point Process Description Emission Factor CAS#p (Y/N) Source Eff. 6.2381 lb/1000 gal. VOC E&P Produced 01 Water Storage 0.1667 lb/1000 gal. Benzene No State EF 95% 006 Tanks 0.5238 lb/1000 gal. n-Hexane SCC 40400315— Fixed Roof Tank, Produced Water, working+breathing+flashing Section 14—Miscellaneous Application Notes AIRS Point 001 Crude Oil Tanks Tank emissions controlled by Cimarron smokeless combustor unit with 95% reduction. Site-specific emission factor using E&P Tanks: VOC = (6.762 TPY*2000) /52,706 bbl/yr= 0.2566 lb/bbl *1000/42 = 6.1094 lb/1000 gal Benzene = 105.12 lb/52,706 bbl/yr= 0.00199 lb/bbl * 1000/42 = 0.0475 lb/1000 gal Toluene = 52.56 lb/ 52,706 bbl/yr = 0.000997 lb/bbl * 1000/42 = 0.0237 lb/1000 gal n-Hexane = 578.16 lb/ 52,706 bbl/yr= 0.01097 lb/bbl * 1000/42 = 0.2612 lb/1000 gal 2,2,4 TMP = 52.56 lb/52,706 bbl/yr= 0.000997 lb/bbl * 1000/42 = 0.0237 lb/1000 gal AIRS Point 002 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 1.0 Submerged loading: dedicated vapor balance service P 3.5 psia M 33.24 lb/lb-mole for gasoline with RVP = 11.5 T 520 °R (60 °F) L 2.79 lb/10"3 gal nnual requested Throughput 3,755,850 gal/yr nnual requested VOC emissions 10,470 lb/yr 5.24 tpy VOC = 10,470 lb/yr/ 89,425 bbl/yr= 0.117080 lb/bbl * 1000/42 = 2.7877 lb/1000 gal. Benzene = 71.35 lb/yr/ 89,425 bbl/yr= 0.000798 lb/bbl * 1000/42 = 0.0190 lb/1000 gal. Toluene = 62.39 lb/yr/89,425 bbl/yr= 0.000698 lb/bbl * 1000/42 = 0.0166 lb/1000 gal. Xylenes =22.74 lb/yr/89,425 bbl = 0.000254 lb/bbl * 1000/42 = 0.0061 lb/1000 gal. n-Hexane =478.03 lb/yr/ 89,425 bbl = 0.005350 lb/bbl * 1000/42 = 0.1273 lb/1000 gal. 2,2,4-TMP = 39.22 lb/yr/ 89,425 bbl = 0.000439 lb/bbl * 1000/42 = 0.0104 lb/1000 gal. 123/9321/001-006 Page 18 11WE3133 AIRS Point 003 Fugitive Emissions Stream VOC/HAP Weight Fractions Gas Light Oil Heavy Oil Water/Oil VOC 0.4872 1.0000 0.0000 1.0000 Benzene 0.0068 0.0066 0.0000 0.0066 Toluene 0.0060 0.0216 0.0000 0.0216 Ethylbenzene 0.0001 0.0016 0.0000 0.0016 Xylene 0.0022 0.0288 0.0000 0.0288 n-Hexane 0.0456 0.0394 0.0000 0.0394 AIRS Point 004 Tornado 40' Flare Stack Emissions calculated using VOC / HAP weight fractions from analysis dated August 9, 2010 from Critter Creek 2-03H. Site specific sampling will be required as part of self certification to verify emission estimates used to set permit limits. Emissions controlled at 95% efficiency. The tornado flare is controlling gas coming off the well since there is no midstream pipeline available in the area at this time. EOG will continue to flare produced gas until a pipeline is available. AIRS Point 005 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 3,804.16 scf/hr and three venting events per year lasting 12 hours per event. The composition of the vented gas is the same as was used to calculate emissions routed to the flare (point 004). AIRS Point 006 Produced Water Storage Tanks EOG used the state default emission factors to calculate emissions from this produced water storage tank battery. Produced water contains less than 1% oil, emissions controlled by Cimarron smokeless combustor. 123/9321/001-006 Page 19 11WE3133 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit �( OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY ".9 Current Status(Check all that apply) Reason for APEN Submittal (Check all that apply) ea f/ IIWE3133 4 dP • AIRS ID# : [23I43ZII�91 ❑ APEN update onlyl� c„ ® New or previously unreported battery ❑ Modification to existing source- ❑ 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 ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPO' ❑ Administrative permit amendment ❑ Permitted under individual permit: • ❑ 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': EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address1', 600 f 7°i Street,Suite 1000N david_l ong@eo gresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303 262-9448 Fax: 303 262-9882 Tank Battery Name'': Garden Creek 02-06H Number of tanks: 6 Location"-(QQ Sec.Twp.Range.): SE/SE Sec 06 TI IN,R62W County: Weld Total tank capacity[bbl]: 2,400 ' Calendar year for which"Actual"data applies'': 2011 Year(s)tank(s)were placed in service14: 201 I Control Descriptions: Cimarron smokeless combustor vapor combustion unit(VCU) Control Efficiency": 95 Condensate Throughput'[bbl/year] Requested's: 52,706 Maximum for PTE calculation19: 52,706 63,Zl(7 Actual'°: While Controls Operational21 Other equipment at facility'', Flare,combustor,treater,line heater,produced water tanks,emergency tank, Comments: 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. Z Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions" Actual Emissions2° Pollutant2" [lb/bbl] PTE" Uncontrolled'-° Controlled"' Uncontrolled' Controlled" VOC[tons/year] 0.2566 6-16 8.i 6.76 0.34 NOx[tons/year] 0.02 0.02 0.02 CO[tons/year] —8:&Y U,08 0.07 0.07 Benzene[lbs/year] n-Hexane[lbs/year] Wells serviced by this tank or tank battery's API#: 05-123-31264 Name: Garden Creek 02-06H ® Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑ Newly Reported Well N API#: Name: ❑ Newly Reported Well co API#: Name ❑ Newly Reported Well__ w API#: Name: ❑Newly Reported Well' :,, ro ' I API#: Name: ❑Newly Reported Well,._, o . o The signature below indicates that 1 have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of Ymy knowledge and belief If this is a registration for coverage under general permit GPO I,I further certify that this source is and will be operated rd in full c pliance-with each condition general permit GPOI. cl,I Z tJ /.- J` -/t� 1 tf ro Signature of L d person(n 1 a vendor or consultant) Date r l; �� .., r Long / / Division Environmental Manager ..' o Type or Print Naiit oe f Person Signing Above - Official Title m o Submit this form, along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. 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S`t S,_; `isI C. ii- w .. 0' C > CCIpr r.:,; c' e▪ 3.� ic -� C relitrn c t v o u a U o v, 2 0 0. r d a R N .Tr 4 s V.` o y rel. a c p O D., O s car, o . ▪ -r _ p d 0 d' a ° w •• in A 5 o - E .v a > �' E m '� _ �+- 4--b-,--,-- s . _ :� A vi w m U e m .8 y m a W % a d o a tn — o a °x " c m I n a 0 a a c Q °° o r- a P, G p. .7 ti o E p 'E m KC.) v y C - m 4� K T r ' �I V o. o o a a 6$ w a o-G ,,4E . 0 0 0 N c a. x E — a z — m c U F= H C > rn n: 6 c Z > U u o °' C 're m O En Q W m ❑ ❑ v CIp.i 0] E' W = ': cd '.b9 STATE OF COLORADO 0 Cp�p COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT a� M AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 *1876* CONSTRUCTION PERMIT PERMIT NO: 11 WE3133 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil gas production facility, known as Garden Creek 02-06H, located in the SE'/SE'/ of Section 6, Township 11 North, Range 62 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Crude Oil Six (6) above ground 400 bbl atmospheric crude oil storage Storage 001 tanks. Emissions from these tanks are controlled by a Cimarron Tanks smokeless combustor (VCU) unit with 95% control efficiency. Truck 002 Truck Loadout of crude oil and produced water. Loading Fugitives 003 Equipment leaks (fugitive VOCs). Separator controlled by a 40' flare stack. Flare has a minimum Flare 004 combustion efficiency of 95%. The flare is not enclosed. One (1) 400 BBL fixed roof storage tank (Manufacturer: Conner, Model: EOG Tank #4466, Serial Number: 30798) used to vent Emergancy Tank 005 gas to the atmosphere in the event that the Flare (Point 004) is shut down during an emergancy. Emissions from this tank are not controlled. One (1) above ground 400 bbl atmospheric produced water Produced storage tank. Emissions from these tanks are controlled by a Water Tank 006 Cimarron smokeless combustor (VCU) unit with 95% control efficiency. 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 AIRS ID: 123/9321/999 Page 1 of 13 Condensate Tank Version 2009-1 EOG Resources Inc. 2. olorl Depa en P..'Ii 'Health and Environment Permit No. 11WE3133 °it Pollution Control Division Issuance 1 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; (Hi) 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. 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 AIRS Tons per Year Emission Type VOC CO Equipment ID Point NO. Crude Oil 001 --- 0.3 Point Storage Tanks Truck Loading 002 --- 5.2 --- Point Fugitives 003 6.2 --- Fugitive Flare 004 -- 28.0 9.4 Point Emergency 005 --- 2.3 --- Point Tank Produced 006 0.2 Point Water Tank See "Notes to Permit Holder#4"for information on emission factors and methods used to calculate limits. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, 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. AIRS ID: 123/9321/999 Page 2 of 13 EOG Resources, Inc olor Depa en- ..f P`.li Health' and Environment Permit No. 11WE3133 , �( ' it Pollution Control Division Issuance 1 6. Point 001: This emissions point shall be configured with a combustor (VCU). The VCU shall reduce the uncontrolled 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.) 7. Point 003: 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. 8. Point 004: This emissions point is a separator controlled by a 40' flare stack. The flare shall reduce 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. Point 006: This emissions point shall be configured such that vapors are routed to a combustor (VCU). The VCU shall reduce uncontrolled 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.) PROCESS LIMITATIONS AND RECORDS 10. This source shall be limited to the following maximum consumption, processing and/or operational rates as listed below. Monthly records of the actual crude oil and natural gas throughput 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 Crude Oil 001 Crude oil throughput 52,706 bbl/yr Storage Tanks Truck Loading 002 Crude oil and produced water loadout 89,425 bbl/yr Fugitives 003 Fugitive VOC Leaks -- Flare 004 Natural gas flaring 33.32 MMscf/yr Emergancy 005 Natural gas venting to atmosphere 136,950 scf/yr Tank Produced 006 Produced water throughput 36,610 bbl/yr Water Tank Compliance with the yearly consumption, processing and/or operational rate 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 monthly consumption, processing and/or operational rate and keep AIRS ID: 123/9321/999 Page 3 of 13 EOG Resources, Inc s olora ' Depa en .f P .'Ii Health and Environment Permit No. 11WE3133 • '' .: it Pollution Control Division Issuance 1 • a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. 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) 12. 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.) 13. 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.). 14. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 15. Point 002: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 16. Points 001 and 004: 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.). 17. Point 006: a. VCUs 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 VCU, or by other convenient means approved by the Division, determine whether the VCU 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. AIRS ID: 123/9321/999 Page 4 of 13 EOG Resources Inc. olor- = Depa en' f P .li *'Health and Environment Permit No. 11WE3133 , it Pollution Control Division Issuance 1 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 VCU 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 18. 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. 19. Point 003: Within one hundred and eighty days (180) after issuance of this permit, 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. 20. Point 003: Within one hundred and eighty days (180) after issuance of this permit, 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. AIRS ID: 123/9321/999 Page 5 of 13 • EOG Resources Inc ti olor Depa en .f P i•li 'Health and Environment Permit No. 11WE3133 A it Pollution Control Division Issuance 1 21. Point 004: The owner or operator shall demonstrate compliance with Condition 13 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section I I.A.5). 22. Points 004 and 005: 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: • lb benzene lb mol. lb 1E6 scf X = benzene wt.frac.* * MWyas = MMscf 379.3 scf Llb.mol 1MMscf ADDITIONAL REQUIREMENTS 23. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, ll.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. 24. 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. 25. 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 AIRS ID: 123/9321/999 Page 6 of 13 EOG Resources, Inc : olor ; Depa , en f PIA 'Health and Environment Permit No. 11WE3133 it Pollution Control Division Issuance 1 _` `r , `w 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 26. 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. 27. 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. 28. 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. 29. 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. 30. 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. 31. 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. 32. 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, AIRS ID: 123/9321/999 Page 7 of 13 EOG Resources Inc olor. Depa .nen .f P 'Ii Health and Environment Permit No. 11WE3133 A it Pollution Control Division Issuance 1 11 civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: �7��iriiLL1(�. Laura Strohkirch Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Facility-wide permit issued to EOG Resources for: six (6) crude oil storage tanks controlled by a VCU, crude oil loadout, associated fugitive Issuance 1 This Issuance emissions, one (1) Tornado 40' Flare, one (1) emergency blowdown tank and one (1) produced water tank controlled by VCU. This is a new, synthetic minor facility. AIRS ID: 123/9321/999 Page 8 of 13 EOG Resources Inc olor ' Depa ' en .f Pc.li 'Health and Environment Permit No. 11WE3133 , �. it Pollution Control Division Issuance 1 ;h ` ; 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/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. AIRS Uncontrolled Are the Controlled Point Pollutant CAS # BIN Emission emissions Emission Rate (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 105 Yes 5 Toluene 108883 C 53 No 3 001 n-Hexane 110543 C 578 No 29 2,2,4-Trimethylpentane 540841 C 53 No 3 Benzene 71432 A 71 Yes -- Toluene 108883 C 62 No --- 002 Xylenes 1130207 C 23 No --- n-Hexane 110543 C 478 No --- 2,2,4-Trimethylpentane 540841 C 39 No -- Benzene 71432 A 83 Yes --- Toluene 108883 C 189 No -- 003 Ethylbenzene 100414 C 12 No --- Xylenes 1130207 C 224 No --- n-Hexane 110543 C 516 No --- Benzene 71432 A 2,497 Yes 125 Toluene 108883 C 1,885 Yes 94 004 Ethylbenzene 100414 C 317 No 16 Xylenes 1130207 C 783 No 39 AIRS ID: 123/9321/999 Page 9 of 13 • EOG Resources, Inc : olor' ` .li }Health and Environment Permit No. 11WE3133 3: �'. Depa enf P `ir Pollution Control Division Issuance 1 :it-, fl : n-Hexane 110543 C 15,294 Yes 765 Benzene 71432 A 10 No --- 005 Toluene 108883 C 8 No --- n-Hexane 110543 C 63 No --- Benzene 71432 A 256 Yes 13 006 n-Hexane 110543 C 804 No 40 4) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.2566 lb/bbl 0.0128 lb/bbl E&P Tanks 71432 Benzene 1.990E-3 lb/bbl 9.972E-51b/bbl E&P Tanks 108883 Toluene 9.972E-4 lb/bbl 4.986E-5 lb/bbl E&P Tanks 110543 n-hexane 0.0110 lb/bbl 5.485E-4 lb/bbl E&P Tanks 540841 2,2,4-TMP 9.972E-4 lb/bbl 4.986E-4 lb/bbl E&P Tanks Note: The controlled emissions factors for point 001 are based on the combustor control efficiency of 95%. These emission factors were developed using a pressurized liquids analysis from the Critter Creek 2-03H well. Point 002: CAS# Pollutant Emission Factors Source Uncontrolled VOC 0.1171 lb/bbl AP-42 71432 Benzene 7.979 x 10-" lb/bbl AP-42 108883 Toluene 6.977 x 10-4 lb/bbl AP-42 1330207 Xylenes 2.543 x 10-4 lb/bbl AP-42 110543 n-Hexane 5.350 x 10-' lb/bbl AP-42 540841 2,2,4-TMP 4.386 x 10' 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 = 1.0 (Submerged loading: dedicated vapor balance service) P (true vapor pressure) = 3.5 psia M (vapor molecular weight) = 33.24 Ib/Ib-mol T (temperature of liquid loaded) = 520 °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. • AIRS ID: 123/9321/999 Page 10 of 13 EOG Resources, Inc olor � Depa en'" f P �•Ii `Health and Environment Permit No. 11WE3133 � , r *it Pollution Control Division Issuance 1 � ' Point 003: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 432 --- 390 39 Flanges 4 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals 0 --- 0 0 Valves 42 --- 54 18 Other 26 --- 12 4 VOC Content(wt%) 48.72% 100% 99.86% 100% Benzene Content(wt%) 0.11% --- 0.68% -- Toluene Content(wt%) 0.08% --- 2.24% -- Ethylbenzene (wt%) 0.01% --- 0.16% -- Xylenes Content(wt%) 0.03% -- 2.97% -- n-hexane Content(wt%) 0.67% --- 4.08% -- *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. Point 004: Weight Emission Emission Factors CAS # Pollutant Fraction of Factors Controlled Source Gas (%) Uncontrolled NOx --- 0.068 0.068 lb/MMBtu AP-42 Ib/MMBtu CO --_ 0.37 lb/MMBtu AP-42 lb/MMBtu VOC 46.18 33633.7106 1681.6649 Engineering lb/MMscf lb/MMscf Calculation 71432 Benzene 0.10 74.9096 3.7504 lb/MMscf Engineering lb/MMscf Calculation 108883 Toluene 0.08 56.5620 2.8318 lb/MMscf Engineering lb/MMscf Calculation 100414 Ethylbenzene 0.01 95094 0.4761 lb/MMscf Engineering lb/MMscf Calculation AIRS ID: 123/9321/999 Page 11 of 13 • EOG Resources, Inc ' olor- Depa en` .f P •li 'Health and Environment Permit No. 11WE3133 �' �;, r Pollution Control Division Issuance 1 • Weight Emission Emission Factors CAS # Pollutant Fraction of Factors Source Controlled Gas (%) Uncontrolled 1330207 Xylenes 0.03 23.4939 1.1761 lb/MMscf Engineering lb/MMscf Calculation 110543 n-hexane 0.63 458.8522 22.9916 lb/MMscf Engineering Ib/MMscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 9, 2010 analysis of a gas sample collected from the Critter Creek 2-03-H well The controlled VOC and HAP emissions factors for point 004 are based on the flare control efficiency of 95%. Point 005: Weight Emission Factors CAS # Pollutant Fraction Source Uncontrolled of Gas r/o) Engineering VOC 46.18 33633.7106 lb/MMscf Calculation Engineering 71432 Benzene 0.10 74.9096 lb/MMscf Calculation • Engineering 108883 Toluene 0.08 56.5620 lb/MMscf Calculation 100414 Ethylbenzene 0.01 9.5094 lb/MMscf Engineering Calculation Engineering 1330207 Xylenes 0.03 23.4939 lb/MMscf Calculation Engineering 110543 n-hexane 0.63 458.8522 lb/MMscf 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 3,804.2 scf per hour. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well. Point 006: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 110543 n-Hexane 0.022 lb/bbl 0.0011 lb/bbl PS Memo 09-02 71432 Benzene 0.007 lb/bbl 0.0004 lb/bbl PS Memo 09-02 Note: The controlled emissions factors for point 006 are based on the combustor control efficiency of 95%. 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 August 8th, 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: 123/9321/999 Page 12 of 13 EOG Resources, Inc. olora.) :Depa enY 1 P :Ali Health and Environment Permit No. 11WE3133 �_ °it Pollution Control Division Issuance 1 Applicable Status Requirement Operating Permit Synthetic minor source for VOC emissions PSD Synthetic Minor Source for VOC emissions MACT HH Area Source Requirements: Not Applicable 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/oiloaspermfitinq html AIRS ID: 123/9321/999 Page 13 of 13 Hello