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Home My WebLink About20120879.tiff STATE OF COLORADO John W.Hickenlooper,Governor Christopher D.Urbina,MD, MPH - Rop co Executive Directt or andd C Chief M Medical Officer TS Ham" Dedicated to protecting and improving the health and environment of the people of Colorado }`` , * 4300 Cherry Creek Dr.S. Laboratory Services Division "/876 • 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 March 26, 2012 Mr. Steve Moreno Weld County Clerk 1402 N. 1711, Ave. Greeley, CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for EOG Resources, In. This public notice will be published in the Greeley Tribune on March 29, 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 1 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 i Sc. KC ifuJ ec, : i-/ L PL i' 2012-0879 - LI-I .3 .30-12. STATE OF COLORADO John W.Hickenlooper,Governor Christopher E. Urbina,MD, MPH oF coto,� Executive Director and Chief Medical Officer /IIr.� Dedicated to protecting and improving the health and environment of the people of Colorado \ ta 4300 Cherry Creek Dr. S. Laboratory Services Division Denver,Colorado 80246-1530 8100 Lowry Blvd. \_!aye' 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 March 26, 2012, published on March 29, 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 two oil and natural gas production facilities in Weld County, Colorado. The facilities are: • Critter Creek 17-21H: This source will consist of four (4)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, one (I)-400BBL produced water tank and truck loading for the crude oil and associated fugitive emissions. This source will be located in the SESE quarter-quarter of Section 21 of Township 11 North, Range 63 West in Weld County. • Critter Creek 21-26H & 30-26H. This source will consist of twelve (12)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, two (2)-400 BBL produced water tanks, truck loading for the crude oil and associated fugitive emissions. This source will be located in the SESE quarter-quarter of Section 26 of Township II North, Range 63 West in Weld County. Theses sources would be considered major sources of air pollutants subject to Prevention of Significant Deterioration (PSD) 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, each source will be considered synthetic minor sources not subject to PSD review. Each source will have permitted emissions greater than 100 tons per year for criteria pollutants and will be considered new major sources subject to Title V Operating Permit requirements. As such, this permit is subject to public comment per Regulation 3, Part B, Section III.C.1.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: Stephanie Chaousy, PE Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B I Denver, Colorado 80246-1 53 0 Within thirty(30)days following the said thirty(30)-day period for public comment,the Division shall consider comments and, pursuant to Section 25-7-1 14.5(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. NOTICE OF REQUEST FOR MAJOR 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: STEPHANIE CHAOUSY COLORADO DEPARTMENT OF PUBLIC HEALTH & ENVIRONMENT 4300 CHERRY CREEK DRIVE SOUTH, APCD-SS-B1 DENVER, CO 80246-1530 • Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE1998 • Source Location: SESE 526, T11N, R63W,Weld County (Attainment) Point 001: (12)400 BBL above ground atmospheric crude oil storage tanks Point 002: (2)400 BBL above ground atmospheric produced water storage tanks. Point 003: (1)400 BBL above ground atmospheric emergency storage Equipment Description: tank for vented gas. Point 004: Plant flare with a minimum combustion efficiency of 95%. Point 005: Fugitive emissions Point 006: Crude oil truck loadout AIRS ID: 123-9277 Date: October 7, 2011 Review Engineer: Stephanie Chaousy, P.E. Control Engineer Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt *If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" 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? Yes X No Did the applicant submit all required paperwork? Yes X 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 Please refer to Section 14 for Information Request letter to the source? questions relating to specific points. On what date was this application complete? July 8, 2011 Section 4—Source Description AIRS Point Equipment Description Twelve (12) above ground 400 bbl atmospheric crude oil storage tanks. Emissions 001 from these tanks are controlled by a Cimarron smokeless combustor(vapor recovery unit)with 95% control efficiency. Two (2) above ground 400 bbl atmospheric produced water storage tanks. 002 Emissions from these tanks are controlled by a combustor(VRU)with a minimum destruction efficiency of 95%. Page 1 One (1)400 BBL fixed roof storage tank used to store gas in the event that there is 003 a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. 004 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 005 Equipment leaks (fugitive V0Cs)from an exploration and production site. 006 Truck loadout of crude oil. 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 Yes X No Regulation 7, Sections XII and XVII.C may apply) Point 002: 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)? (Section 3 on APEN) Point 002: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? (Section 3 on APEN) Point 002: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? (Section 3 on APEN) If so, submit Form APCD-105 Section 5— Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific using E&P Tanks (Refer to Section 14 for calculations) 002 CDPHE Emission Factors (PS Memo 09-02) 003 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 004 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 005 EPA-453/R-95-017, Table 2-4 AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*MR 006 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] 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 001 141,912 BBL per year(118260 x 1.2) 002 9636 BBL per year(8030 x 1.2) Page 2 003 753,900 scf/yr= 0.7539 mmscf/yr 004 502.6 MSCF/day=> 183449 mscf/yr= 183.449 MMScf/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 864 --- 780 77 Flanges 8 --- 48 8 005 Open-Ended Lines 18 --- 14 10 Pump Seals --- --- --- --- Valves 84 --- 108 36 Other 52 --- 23 9 006 125,925 BBL per year crude oil loaded Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 118,260 BBL per year 2011 002 8030 BBL per year 003 753,900 scf/yr= 0.7539 mmscf/yr 004 502.6 MSCF/day=> 183449 mscf/yr= 183.449 MMScf/yr Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 864 --- 780 77 Flanges 8 --- 48 8 005 Open-Ended 18 --- 14 10 Lines Pump Seals --- --- --- --- Valves 84 --- 108 36 Other 52 --- 23 9 006 125,925 BBL per year crude oil loaded Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 118,260 BBL per year 002 8030 BBL per year 003 753,900 scf/yr= 0.7539 mmscf/yr 004 502.6 MSCF/day=> 183449 mscf/yr= 183.449 MMScf/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 864 --- 780 77 Flanges 8 --- 48 8 005 Open-Ended Lines 18 --- 14 10 Pump Seals --- --- --- --- Valves 84 --- 108 36 Other 52 --- 23 9 006 125,925 BBL per year crude oil loaded Does this facility use control devices? X Yes No Reduction AIRS Point Process Control Device Description Granted 001 01 Cimarron smokeless combustor(VCU) 95 Page 3 002 01 Cimarron smokeless combustor(VCU) 95 004 01 Tornado 40' flare stack 95 Section 6— Emission Summary (tons per year) Point NO,t VOC CO SOx PM10 Single HAP Tl HAotaP 0.5 001 0.02 11.6 0.1 --- --- (n-hexane) 0.6 002 --- 1.1 --- --- --- 0.09 0.1 (n-hexane) PTE: 003 --- 13.4 --- --- --- 0.18 0.24 (n-hexane) 004 9.5 3249.1 51.7 --- --- 6.1 (n-hexane) 6.4 005 --- 12.4 --- --- --- 0.3 (n-hexane) 0.7 006 --- 4.4 --- --- --- 0.02 (benzene) 0.05 0.4 001 0.02 9.6 0.1 (n-hexane) 0.5 002 --- 1.1 --- --- --- 0.09 0.1 Uncontrolled point(n-hexane) source emission rate: 003 13.4 ___ 0.18 0.24 --- --- -- (n-hexane) 004 9.5 3249.1 51.7 --- ___ 121.1 (n- 128.5 hexane) 005 --- 12.4 --- --- --- 0.3 (n-hexane) 0.7 006 --- 4.4 --- --- --- 0.02 (benzene) 0.05 TOTAL (TPY) 9.5 3284.2 51.8 --- ___ 122.1 (n- 130.1 hexane) 001 0.02 0.5 0.1 --- ___ 0.02 (n- 0.03 hexane) 002 --- 0.1 --- 0.004 0.01 (n-hexane) Controlled point 003 --- 13.4 --- --- ___ 0.18 0.24 source emission rate: (n-hexane) 004 9.5 162.5 51.7 --- --- 6.1 (n-hexane) 6.4 005 --- 12.4 --- --- --- 0.3 (n-hexane) 0.7 006 --- 4.4 --- --- --- 0.02 (benzene) 0.05 INSIGNIFICANTS 0.8 0.6 -- (TPY) --- --- --- TOTAL PERMITTED 9.5 193.3 51.8 --- --- 6.6 (n-hexane) 7.4 (TPY) Section 7- Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable? Rate(Ib/yr) Point 001 Benzene 71432 A 108 Yes 5 Toluene 108883 C 96 No 5 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 34 No 2 Page 4 n-Hexane 110543 C 798 No 40 2,2,4-Trimethylpentane 540841 C 68 No 3 Point 002 Benzene 71432 A 56 Yes 3 n-Hexane 110543 C 177 No 9 Point 003 Benzene 71432 A 28 No 28 Toluene 108883 C 21 No 21 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 9 No 9 n-Hexane 110543 C 169 No 169 Point 004 Benzene 71432 A 6687 Yes 334 Toluene 108883 C 5049 Yes 253 Ethylbenzene 100414 C 851 No 43 Xylenes 1130207 C 2099 Yes 105 n-Hexane 110543 C 41,003 Yes 2050 Point 005 Benzene 71432 A 104 Yes 104 Toluene 108883 C 283 No 283 Ethylbenzene 100414 C 22 No 22 Xylenes 1130207 C 362 No 362 n-Hexane 110543 C 633 No 633 Point 006 Benzene 71432 A 49 No 49 Toluene 108883 C 44 No 44 Ethylbenzene 100414 C 1 No 1 Xylenes 1130207 C 16 No 16 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 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 001 01 VOC CDPHE PS Memo 05-01 Site-specific sampling 003 01 VOC, State only requirement Site-specific gas HAPS analysis Page 5 004 p� VOC, State only requirement Site-specific gas HAPS analysis 005 p� VOC, State only requirement Extended gas and HAPS liquids analysis 005 al VOC, State only requirement Hard component HAPS count Section 9—Source Classification Is this a new previously un-permitted source? 001 002 003 004 005 006 YES X X X X X X NO • What is this point classification? True Minor X X X X X Synthetic Minor Major X What is this facility classification? True Synthetic X Major Minor Minor Classification relates to what programs? X Title V PSD NA NSR X MACT Is this a modification to an existing permit? Yes X No 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? VOC 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)? X Yes 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? NOx emissions are less than 40 TPY. AIRS Point Section 12— Regulatory Review . . Requlation 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. Requlation 2—Odor Page 6 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 since emissions from production exceed 2 tons per year VOC) 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 8-hour ozone attainment area, therefore, not subject to RACT. However, operator is using 0.6 (submerged, dedicated normal service) for its saturation factor. Part B— Construction Permit Exemptions 001-006 Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) Regulation 6 - New Source Performance Standards 001-004, None 006 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). 005 Is this source at a "natural gas processing plant?" No Is this source subject to NSPS KKK? No WHY? This source is not defined as a "natural gas processing plant" (it is a wellhead E&P site, therefore, a production field facility). Therefore, this source is not subject to KKK. Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is not located in the 8-hr ozone control area; therefore, this facility is not 001-006 subject to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... This facility is an oil and gas operation that does not operate any equipment subject to Section XVII of this regulation. Section XII.G: If facility is a natural gas processing plant located in non-attainment 005 area, then subject to Section XII.G. Since this facility is NOT a gas processing plant, and not in the non-attainment area, this facility is not subject to this section. Regulation 8— Hazardous Air Pollutants 001-004, None 006 MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators and fugitives), then fugitive emissions are subject to MACT HH. 005 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? Area source MACT HH only applies to TEG dehydrators (while Major MACT HH is applicable to TEG dehydrators, tanks and fugitives). Therefore, this source is not subject to MACT HH. Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 001 01 Crude oil Storage Tanks 3.8837 lb/1000 gal VOC No E&P Tanks 95 Page 7 0.068 AP-42, lb/MMBtu NOx No Table 13.5-1 NA 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 0.0217 Benzene No E&P Tanks 95 lb/1000 gal 0.0193 Toluene No E&P Tanks 95 lb/1000 gal 0.0004 Ethylbenzene No E&P Tanks 95 lb/1000 gal y 0.0068 Xylenes No E&P Tanks 95 lb/1000 gal y 0.1607 n-hexane No E&P Tanks 95 b/1000 gal • 0.0137 2,2,4-TMP 4-TMP No E&P Tanks 95 lb/1000 gal SCC 40400301 — Fixed Roof Tank, Oil field storage of crude, breathing losses 6.2381 CDPHE PS lb/1000 gal VOC No Memo 09-02 95 throughput 0.1667 Produced Water Storage CDPHE PS 01 Tanks b/1000 gal Benzene No Memo 09-02 95 002 throughput 0.5238 CDPHE PS lb/1000 gal n-Hexane No Memo 09-02 95 throughput SCC 40400315— Fixed Roof Tank, Produced Water, working+breathing+flashing losses 35426.9797 VOC No Engineering 0 lb/mmscf Calculation 36.477 Benzene No Engineering 0 lb/mmscf Calculation 27.59 Toluene No Engineering 0 01 Gas Storage Tank lb/mmscf Calculation 003 4.6425 Ethlybenzene No Engineering 0 lb/mmscf Calculation 11.4073 Engineering lb/mmscf Xylenes No Calculation 0 223.5044 n-hexane No Engineering 0 lb/mmscf Calculation SCC 40400152-Vapor collection losses 35421.9429 VOC No VOC Wt Fraction 95 lb/mmscf 0.068 AP-42, lb/MMBtu NOx No Table 13.5-1 NA 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 36.4494 Benzene No Engineering 95 01 Flare lb/MMscf Calculation 004 27.5226 Toluene No Engineering 95 lb/MMscf Calculation 4.6405 Ethlybenzene No Engineering 95 lb/MMscf Calculation 11.4413 Engineering lb/MMscf Xylenes No Calculation 95 223.5128 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 005 01 Fugitives VOC Yes EPA-453/R-95- NA 017, Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) 006 01 Truck Crude oil Loadout 0.0697 VOC No AP-42 0 lb/BBL Page 8 0.0004 Benzene No AP-42 0 lb/BBL 0.0003 Toluene No AP-42 0 lb/BBL 0.00001 Ethylbenzene No AP-42 0 Ib/BBL 0.0001 Xylenes No AP-42 0 lb/BBL SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Section 14— Miscellaneous Application Notes AIRS Point 001 Crude Oil Storage Tanks Site-specific emission factor using E&P Tanks: VOC = (9.645 TPY *2000) / 118260 bbl/yr= 0.1631 lb/bbl *1000/42 = 3.8837 lb/1000 gal Benzene = (0.054 TPY*2000)/ 118260 bbl/yr= 0.0009 lb/bbl * 1000/42 = 0.0217 lb/1000 gal Toluene = (0.048'TPY*2000) / 118260 bbl/yr= 0.0008 lb/bbl * 0.0193 lb/1000 gal Ethylbenzene = (0.001 TPY *2000)/ 118260 bbl/yr= 0.00002 lb/bbl * 1000/42 = 0.0004 lb/1000 gal Xylenes = (0.017 TPY *2000)/ 118260 bbl/yr= 0.0003 lb/bbl * 1000/42 = 0.0068 lb/1000 gal n-hexane = (0.399 TPY*2000)/ 118260 bbl/yr= 0.0067 lb/bbl * 1000/42 = 0.1607 lb/1000 gal 2,2,4-TMP = ,0.034TPY*2000) / 118260 bbl/yr = 0.0006 lb/bbl * 1000/42 = 0.0137 lb/1000 gal AIRS Point 002 Produced Water Storage Tanks 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 operator stated on the APEN that the tanks contain less than 1% by volume crude oil on an annual average basis. There is a categorical exemption for such source (Regulation 3, Part B, Section II.D.1.m). However, this source will be permitted because if the source was not controlled, the overall permitted VOC emissions would be greater than 100 TPY, and therefore a major source facility. The operator has requested synthetic minor status and accept Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. I emailed EOG on 10/11/11: The application indicates that the produced water tanks are APEN-exempt (APCD Form 102). However, the uncontrolled benzene is greater than 50 lb/yr, therefore, is APEN- required (Regulation 3, Part A, Section II.D.1.b). This source, therefore, will require a permit. Don Gray called me with CRA on 10/12/11 and agreed that the produced water tanks will require a permit and that the facility inventory form is incorrect. Page 9 AIRS Point 003 Emergency Storage Tank Emissions were calculated using VOC wt fraction using a sales gas analysis from the facility dated August 9, 2010. I emailed the Operator/consultant regarding the emission factors. These factors should be very similar to Point 004. I received an email on 11/21/11 from Don Gray (consultant): The differences in emissions for flaring and emergency vent were making a couple of adjustments in the calculations for consistency and included using 48.72 VOC weight percent and a consistent factor of 379.7. One difference with your emergency tank calculations was the value of 0.75mmscf/yr which represents 36 hours per year and my original calculations were for 24 hours per year which is 0.5027 mmscf/yr. When I corrected the VOC weight percent to 48.72 and 379.7 value, the VOC emissions worked out to be nearly identical for flaring and the emergency tank, see the attached sheet(35,409 lb/mmscf and 35,412 lb/mmscf). Also please check the n-hexane emissions, it should have a weight% of 0.631. Curtis told me he would like to change the emergency tank vent to be for 3 events per year, 12 hours each for a total of 36 hours. This represents 753,900 scf of gas vented and 13.354 tpy of VOCs. I have attached an excel spreadsheet to show the change in emissions in blue text I also added a cell showing uncontrolled VOC emissions from the flare at 3,249.06 tpy in blue text. Controlled VOC emissions from the flare are 162.45 tpy, no change. I included uncontrolled HAP emissions from the flare see the blue text. Changes to the excel table are on Table 1, Table 7 and Table 10 rev in blue text VOC = (13.3542 TPY*2000 lb/T)/(0.7539 MMscf/yr) = 35426.9797 lb/mmscf Benzene = (27.5 Ib/yr)/ (0.7539 MMscf/yr) = 36.4770 lb/mmscf Toluene = (20.8 Ib/yr)/(0.7539 MMscf/yr) = 27.5900 lb/mmscf Ethylbenzene = (3.5 Ib/yr) / (0.7539 MMscf/yr) = 4.6425 lb/mmscf Xylenes = (8.6 Ib/yr)/(0.7539 MMscf/yr) = 11.4073 lb/mmscf n-hexane = (168.5 Ib/yr) / (0.7539 MMscf/yr) = 223.5044 lb/mmscf AIRS Point 004 1 Flare Emissions were calculated using VOC wt fraction. VOC = (3249.06 TPY*2000 lb/T)/ (183.449 mmscf/yr) = 35421.9429 lb/mmscf NOx and CO (from AP-42, Chapter 13, Table 13.5-1 (NOx= 0.068 lb/mmbtu; CO = 0.37 lb/mmbtu) SO2 emissions based on AP-42 Table 1.4-2 (SO2 = 0.00037 Ib/MMBtu) PM10 and PM2.5 based on AP-42 Table 13.5-2 (PM10 and PM2.5=40 ug/l) Benzene =(6686.6 Ib/yr)/ 183.449 mmscf/yr= 36.4494 lb/mmscf Toluene = (5049 Ib/yr) / 183.449 mmscf/yr= 27.5226 lb/mmscf Ethylbenzene = (851.3 Ib/yr)/ 183.449 mmscf/yr= 4.6405 lb/mmscf Xylenes= (2098.9 Ib/yr) / 183.449 mmscf/yr= 11.4413 lb/mmscf n-hexane = (41003.2 Ib/yr) / 183.449 mmscf/yr= 223.5128 lb/mmscf I emailed EOG on 10/11/11: For the flare, the APEN is showing no controlled emission limits. Wouldn't the VOC be controlled at 95%? So, the controlled VOC would be 8.14 TPY? And the HAPs as well? Don Gray called me with CRA on 10/12/11 and noticed that the uncontrolled VOC was not on the APEN and the controlled VOC was in the wrong column. So, he gave me the uncontrolled VOC and HAP emissions over the phone and I redlined the APEN accordingly. AIRS Point 005 Fugitive emissions Fugitive emissions from this facility are greater than 2 TPY (APEN-required) and 5 TPY (permit-required) and therefore, require a permit. I emailed EOG on 10/11/11 with a question regarding the fugitive emissions. My calculations were not matching the application, and I could not find the discrepancy. I was hoping he could help me with this. Don Gray called me with CRA on 10/12/11 and agreed with my calculations. He was missing a VOC wt% in one of his components. I redlined the APEN accordingly. Page 10 AIRS Point 006 Truck crude oil Loadout 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 3.5 psia M 33.24 lb/lb-mole T 524 deg. R L 1.661b/10^3 gal 6.97E-021b/bbl Annual requested Throughput 5288850ga1/yr Annual requested VOC emissions 87791b/yr 4.39tpy Benzene = (49.2 Ib/yr) / (125925) = 0.0004 lb/bbl Toluene = (43.7 Ib/yr)/ (125925) = 0.0003 lb/bbl Ethylbenzene = (0.91 Ib/yr) / (125925) = 0.00001 lb/bbl Xylenes = (15.5 Ib/yr) / (125925) = 0.0001 lb/bbl I emailed EOG on 10/11/11: For the condensate loadout: the APEN is showing 0.6 saturation factor, but the calculation sheet is showing 1.0 for submerged loading. The calculation sheet is also showing 520degR, where I think it would be 524degR. I believe the emissions from the loadout are actually 4.39 TPY, not 7.37 TPY. If you agree, I can just redline the APEN. Don Gray called me with CRA on 10/12/11 and agreed that the saturation factor should be 0.6 (not 1.0) and the temperature 524R (not 520R). I corrected the calculation sheet and redlined the APEN accordingly. Facility-wide Operator Comments Page 11 Operator provided comments on the DRAFT permit on 10/19/11. The comments are: 1. p1, Facility Equipment ID 001 -please rename "Crude oil storage tanks" . I revised the permit accordingly. 2. Remove the"VRU"-as we spoke ...VCU, everywhere. I revised the permit accordingly. 3. p3. section 11 -the emergency tank venting, 003 ... 91 million cubic feet is incorrect(thats 250K/day, 365 days..?) This should be-3 events at 12 hours per event (I believe this is the standard for all sites for the emergency calc) at 20,942 cubic feet/hr—or 753,900 SCF/yr (per the application, 502.6 MCFD) . I called Curtis Rice with EOG and we did this calculation over the phone together. The throughput for the emergency tank is small since its worst-case scenario would be 36 hours/year. I agreed with his calculation of 753,900 SCF/yr, or 0.75 mmscf/yr. Revised permit and PA accordingly. 4. p4. Flare 004-should be -20,942 cubic feet/hr-or 502.6 CF/day, or 183.5 million/YR. /revisited the throughput and agreed with his calculation. Revised permit and PA accordingly. 5. p4. reference method 22- and a time frame. Email dated 9-27-11 from Jacob Sebesta (I'll forward it to you if needed) This is a common thread for all the permits. During our phone conversation on 10/20/11, we discussed an email sent to EOG from Jake Sebesta providing information on what an inspector expects for a Method 22 reading. 6. p4 table, Truck loading 006-this should read"Crude oil and Produced water" -it's both volumes combined.. I revised the permit accordingly. 7. p4. section 18-a. Flares shall be enclosed The flares are NOT enclosed . /modified the condition to reflect "VCU"rather than "flare." 8. p5. section 21 and p6. section 24- The initial testing will provide accurate composition-may we request analyzing for extended comp every two years? it's not likely to change and provide substantially different calc's...? During our phone call on 10/20/11, I explained to him that several conditions would be satisfied with the one extended gas analysis, and that the Division feels that testing once a year is not a burden on an operator. 9. p8. Permit history-table add the combustor VCU...? /revised the permit accordingly. 10. p9 section 3 table 004 N-Hexane is 41,014 Lb/YR not 242,235. During our phone call on 10/20/11, I explained to Curtis that I got the HAP emission limits from the consultant directly and when calculating backwards from what was provided on the APEN, the uncontrolled n-hexane is 242,235 lb/yr. He agreed. 11. p9. table - I can't see where some of these numbers came from . 005 uncontrolled N-Hexane? I provided him a copy of my fugitive emissions calculation sheet He agreed. 12. p11. POINT 004- N-Hexane... weight percent of 0.63 should be controlled, 1.12 Ib/MMSCF and uncontrolled 22.36 lb/MMSCF..During our phone call on 10/20/11, we discussed how the emission factors for the produced water tank and flare should be the same because the same material would be either going to the flare or emergency tank if the flare breaks down. I did a mass balance, and I did not get the same emission factors. I believe that the emission limits are incorrect, but not sure for which source. I emailed Curtis my calculations on 10/20/11. Page 12 • • Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION eltitrilir STORAGE TANK BATTERY g ` Current Status(Check all t¢pat apply) Reason for APEN Submittal(Check all that apply) y+, YV 0� AIRS ID#': 123/9277/001 ❑ APEN update only° •_ S 2 M New or previo ly unrepp�rorted battery ❑ Modification to existing source` Oa' ❑ Previously grandfathered battery ❑ Registration for coverage under general permit no..GPOI ��a - ❑ Synthetic minor facility &cancellation request for individual permit 6: S� ❑ Located in the 8-hr Ozone Control Areas M Application for or Modification of an individual permit -S01.C ❑ Registered under general permit no.GPOI ❑ Administrative permit amendment? ❑ . Permitted under individual permit: IUWE 199$ ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division M To review a draft of the permit prior to issuance Company Name: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address°: 600 17th Street,Suite 1000N davidlong@eogresour 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 1: Critter Creek 21-26H&30-26H Number of tanks: 12 Location 12(QQ Sec.Twp.Range.): SE/SE Sec26,TI IN,R63W County: Weld Total tank capacity[bbl]: 4,800 Calendar year for which"Actual"data applies3: 2011 Year(s)tank(s)were placed in service": 201I Control Description's: Cimarron smokeless combustor vapor combustion unit(VCU) Control Efficiency 6: 95 Throughputs'[bbl/year] Requested's: 118,260 Maximum for PTE calculation 9: 1487364 191;ill. ,'.w. G cV pG Actual2°: While Controls Opera[iona12s Other equipment at facility22: Flare, heater treaters,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. M Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions 18 Actual Emissions20 Pollutant" [lb/bbl] PTE226 Uncontrolled26 Controlled" Uncontrolled26 Controlled" VOC[tons/year] 0.16312 97645 11,C44freu 9.645 0.48 • NOx[tons/year] 0.02 0.02 0.02 CO[tons/year] 0.11 0.11 0.11 Benzene fibs/year] , n-Hexane[lbs/year] Wells serviced by this tank or tank battery2a API#: 05-123-31796 Name: Critter Creek 21-26H M Newly Reported Well API#: 05-123-32328 Name: Critter Creek 30-26H ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well w API#: Name O Newly Reported Well 'o API#: Name: ❑Newly Reported Well y -) API#: Name: ❑Newly Reported Well:!6,1 o The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the bjst of o my knowledge and belief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated in 11 con . ce wit each co .ition of general permit GPOI. Cl Signature of Lega y Aut orize+ Person(not a vendor or c.0 ultant) Date 1 1 N t'f; o David Long Division Environmental Manager k'^ i' Type or Print Name of Person Signing Above Official Title O Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: o filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI (303)692-3150 m $250 General Permit fee for each new GP 4300 Cherry Creek Drive South o registration to: Denver,CO 80246-1530 FORM APCD-205 Page I oft FormAPCD-205-E&PCondensateTankAPEN-Ver.9-28-2009 N 06 258806 N N z ti c o y E `o_ E e c L ° ,='- a• 'ti 8 O o. ., 4 - n � v - E o G T R ❑ ° ` a m L o Si <0.„'" N .0 ° 0 03 p 0 C \ L.` i T v 3 .J 0 6 4Q N 0 Y -b ,O \ r > o > v o a S° W U o !' 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MI F '-' X nm v a 0 d o o w °u ❑ ❑ d ® w v; v� I _ _, c. \ ( \ 3 ce et / \% } ] tt , \ \\ -E. \ � k \ = ) f ° ± Z: a. 6,2 « ) 7 0. 0g •E -OO 7. )• § f jkk O \ . / \/ - - ril j j \ Q » \(� f\f ° � � LI # ��- /) \� ._: k�\�\ ° (k C 2 : a \\ j \\ \ b 4 le e / ! f . § dam\ / e � 9 j� E 4 / \ \ \ �; (§ • 4„. erairri, ' I H r STATE OF COLORADO „' ISLESIS tidYtd.I pCO(p COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT NQ� �b AIR POLLUTION CONTROL DIVISION o TELEPHONE: (303)692-3150 R76 CONSTRUCTION PERMIT PERMIT NO: 11WE1998 WE1 998 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas production facility, known as Critter Creek 21-26H and 30-26H, located in the SESE of Section 26, Township 11 North, Range 63 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 Twelve (12) 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. Produced Two (2) above ground 400 bbl atmospheric produced water Water Tank 002 storage tanks. Emissions from these tanks are controlled by a combustor 0/CU) with a minimum destruction efficiency of 95%. Emergency One (1) 400 BBL fixed roof storage tank used to store gas in the Tank 003 event that there is a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. Flare 004 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Fugitives 005 Equipment leaks (fugitive VOCs) from an exploration and production site. Truck 006 Truck loadout of crude oil. Loading 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. YOU MUST notify the APCD no later than fifteen days after issuance of this permit or activity by submitting a Notice of Startup (NOS) form to the APCD. The Notice of Startup (NOS) form may be downloaded online at AIRS ID: 123/9277/999 Page 1 of 13 Condensate Tank Version 2009-1 EOG Resources, Inc. olor Depar en f P: li Health and Environment Permit No. 11 WE1998 1r_Pollution Control Division Issuance 1 • www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. 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). 3. 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.) 4. 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.) 5. 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 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 Crude Oil 001 --- 0.5 --- Point Storage Tanks Produced 002 --- --- --- Point Water Tank Emergency 003 --- 13.4 --- Point Tank Flare 004 9.5 162.5 57.1 Point Fugitives 005 --- 12.4 --- Fugitives Truck Loading 006 --- 4.4 --- Point 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. AIRS ID: 123/9277/999 Page 2 of 13 fl 4 EOG Resources Inc z olori Depa en `f "Health and Environment Permit No. 11WE1998 r it Pollution Control Division Issuance 1 ) y 1 ` ., K1 ' c r, . .; 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. Point 001: This emissions point shall be configured with a combustor. The combustor shall reduce the uncontrolled 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. Point 002: 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 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. 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. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 10. Point 005: 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 11. 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 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 118,260 BBL/yr Storage Tanks Produced 002 Produced water throughput 8,030 BBL/yr Water Tank Emergency 003 Natural gas venting to atmosphere 1,130,850 SCF/yr Tank Flare 004 Natural gas flaring 183.5 MMSCF/yr AIRS ID: 123/9277/999 Page 3 of 13 EOG Resources, Inc - olor DepaF& err f P li Health and Environment Permit No. 11WE1998 . a r Pollution Control Division Issuance 1 _ ?` + t Truck Loading 006 Crude oil and produced water loading 125,925 BBL1yr 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 crude oil throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 12. Point 002: 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) 17. Point 006: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Points 001, 004 and 005: Upon startup of these points, the applicant shall follow the operating and maintenance(O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 19. Point 002: 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: CO Leakage of VOCs to the atmosphere must be minimized as follows: AIRS ID: 123/9277/999 Page 4 of 13 EOG Resources, Inc. a olor- Depa en f li Health and Environment Permit No. 11 WE1998 4 it Pollution Control Division Issuance 1 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a 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 20. Point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site- specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 21. 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 AIRS ID: 123/9277/999 Page 5 of 13 EOG Resources, Inc. olor.. Depa en f li Health and Environment Permit No. 11WE1998 A it Pollution Control Division Issuance 1 equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: lb banana lb mo 1. lb l 186 scf x = benzene wt.frac.* *�1 Was bb * MMscf 374.3 scf gb mod L41.blscf, 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 II.A.5). 23. Point 005: 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) 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 005: 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: 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. This source is subject to the provisions of Regulation number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The application for the Operating Permit is due within one year of becoming major. AIRS ID: 123/9277/999 Page 6 of 13 EOG Resources, Inc. olor. - Depa en f ' ,•li Health" and Environment Permit No. 11WE1998 A it Pollution Control Division Issuance 1 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 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. AIRS ID: 123/9277/999 Page 7 of 13 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1998 it Pollution Control Division Issuance 1 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: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for (12) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (2) produced water tanks, fugitive emissions and crude oil loadout. New Major facility. AIRS ID: 123/9277/999 Page 8 of 13 • EOG Resources Inc , , olor.! Depa , en .f •li Health' and Environment t. Permit No. 11WE1998 = j �' it Pollution Control Division zt Issuance 1ik 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/req u lations/airreqs/100102aocccom monprovisionsreq.odf. 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 (Ib/yr) Benzene 71432 A 108 Yes 5 Toluene 108883 C 96 No 5 Ethylbenzene 100414 C 2 No 0 001 Xylenes 1130207 C 34 No 2 n-Hexane 110543 C 798 No 40 2,2,4- 540841 C 68 No 3 Trimethylpentane Benzene 71432 A 56 Yes 3 002 n-Hexane 110543 C 177 No 9 Benzene 71432 A 28 No 28 Toluene 108883 C 21 No 21 003 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 9 No 9 n-Hexane 110543 C 169 No 169 Benzene 71432 A 6687 Yes 334 Toluene 108883 C 5049 Yes 253 004 Ethylbenzene 100414 C 851 No 43 Xylenes 1130207 C 2099 Yes 105 n-Hexane 110543 C 41,003 Yes 2050 Benzene 71432 A 104 Yes 104 005 Toluene 108883 C 283 No 283 AIRS ID: 123/9277/999 Page 9 of 13 EOG Resources, Inc. olor Depar en rf P lid Health and Environment Permit No. 11WE1998 4ir Pollution Control Division Issuance 1 - Ethylbenzene 100414 C 22 No 22 Xylenes 1130207 C 362 No 362 n-Hexane 110543 C 633 No 633 Benzene 71432 A 49 No 49 Toluene 108883 C 44 No 44 006 Ethylbenzene 100414 C 1 No 1 Xylenes 1130207 C 16 No 16 4) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42, Table 13.5-1 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42, Table 13.5-1 VOC 3.8837 lb/1000 qal 0.1942 lb/1000 gal E&P Tanks 71432 Benzene 0.0217 lb/1000 gal 0.0011 lb/1000 gal E&P Tanks 108883 Toluene 0.0193 lb/1000 gal 0.0010 lb/1000 qal E&P Tanks 100414 Ethylbenzene 0.0004 lb/1000 gal 0.00002 lb/1000 gal E&P Tanks 1330207 Xylenes 0.0068 lb/1000 gal 0.0003 lb/1000 qal E&P Tanks 110543 n-hexane 0.1607 lb/1000 gal 0.00807 lb/1000 gal E&P Tanks 540841 2,2,4-TMP 0.0137 lb/1000 gal 0.00076 lb/1000 gal 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: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 PS Memo 09-02 110543 n-Hexane 0.022 0.0011 PS Memo 09-02 71432 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions factors for point 005 are based on the combustor control efficiency of 95%. Point 003: Emission Factors Weight Fraction Source CAS# Pollutant Uncontrolled of Gas (°/o) Lb/mmscf VOC 35426.9797 lb/mmscf 46.18 Engineering Calculation AIRS ID: 123/9277/999 Page 10 of 13 - EOG Resources Inc , olor ` Depat en f li Health and Environment Permit No. 11WE1998 c_____ .. : it Pollution Control Division Issuance 1 Emission Factors Weight Fraction Source CAS # Pollutant Uncontrolled of Gas (%) Lb/mmscf 71432 Benzene 36.477 0.10 Engineering Calculation 108883 Toluene 27.59 0.08 Engineering Calculation 100414 Ethylbenzene 4.6425 0.01 Engineering Calculation Engineering 1330207 Xylenes 11.4073 0.03 Calculation Engineering 110543 n-hexane 223.5044 0.63 Calculation The emission levels in this permit for this point are based on the use of this tank to blowdown produced natural gas when the flare used to combust the natural gas is down at three (3) events per year and twelve(12) hours of venting through this tank per event at a maximum gas flow rate of 10,416.7 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: Weight Emission Emission Fraction Factors Factors CAS # Pollutant of Gas Uncontrolled Controlled Source (°/O) NOx 0.068 0.068 AP-42 lb/MMBtu lb/MMBtu CO --- 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42 VOC 46.18 35421.9429 1771.0971 Engineering lb/mmscf lb/mmscf Calculation PM10 --- 40 ug/I 40 ug/I AP-42, Table 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf lb/MMBtu lb/MMBtu 71432 Benzene 0.10 36.4494 1.8225 Engineering lb/MMscf lb/mmscf Calculation 108883 Toluene 0.08 27.5226 1.3761 Engineering lb/MMscf lb/mmscf Calculation • 100414 Ethylbenzene 0.01 4.6405 0.2320 Engineering lb/MMscf lb/mmscf Calculation 1330207 Xylenes 0.03 11.4413 0.5721 Engineering lb/MMscf lb/mmscf Calculation 110543 n-hexane 0.63 223.5128 11.1756 Engineering lb/MMscf lb/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 003 are based on the flare control efficiency of 95%. Point 005: Component I Gas Service I Heavy Oil .1 Light Oil I Water/Oil AIRS ID: 123/9277/999 Page 11 of 13 EOG Resources, Inc. olor A.Depai ern f P lic•Health and Environment Permit No. 11WE1998 Air Pollution Control Division Issuance 1 Service Connectors 864 --- 780 77 Flanges 8 --- 48 8 Open-Ended Lines 18 --- 14 10 Pump Seals Valves 84 --- 108 36 Other 52 --- 23 9 VOC Content(wt%) 48.72% 100% 99.86% 100% *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 006: Emission Factors - Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.0697 AP-42 71432 Benzene 0.0004 AP-42 108883 Toluene 0.0003 AP-42 100414 Ethylbenzene 0.00001 AP-42 1330207 Xylenes 0.0001 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) = 3.5 psia M (vapor molecular weight) = 33.24 Ib/Ib-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 in the vapors the VOC emission factor. AIRS ID: 123/9277/999 Page 12 of 13 EOG Resources, Inc .r olori Depar en �f P •li '`Health and Environment Permit No. 11WE1998 � it Pollution Control Division �a Issuance 1 11411W,!- 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 July 7, 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: Applicable Status Requirement Operating Permit Major Source VOC PSD Synthetic Minor Source VOC MACT HH Area Source Requirements: Not Applicable MACT ZZZZ 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 Pad 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 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/oilqaspermittinq html AIRS ID: 123/9277/999 Page 13 of 13 r Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number 11WE1367 Source Location: SESE S21, T11N, R63W, Weld County (Attainment) Point 001: (4)400 BBL above ground atmospheric crude oil storage tanks Point 002: (1)400 BBL above ground atmospheric emergency storage tank for vented gas. Point 003: Plant flare with a minimum combustion efficiency of 95%. Equipment Description: Point 004: Crude oil truck loadout Point 005: (1)400 BBL above ground atmospheric produced water storage tank. Point 006: Fugitive emissions AIRS ID: 123-8958 Date: September 15, 2011 Review Engineer Stephanie Chaousy, P.E. Control Engineer: Chris Laplante Section 2 —Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt "If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" 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, May 23, 2011: Jake emailed David Long regarding the flare when did you mail an Information calculations. It appeared that the consultant used the mole Request letter to the source? fraction VOC instead of the mass fraction VOC. The change in VOC could change the status of the facility. Jamie Christopher submitted new calculations for this facility on 9/19/11. This source is now at a major status facility. On what date was this application February 11, 2011. Received revised calculations on complete? August 25, 2011. Section 4-Source Description AIRS Point Equipment Description Four(4) above ground 400 bbl atmospheric crude oil storage tanks. Emissions 001 from these tanks are controlled by a Cimarron smokeless combustor(vapor recovery unit)with 95% control efficiency. Page 1 One (1)400 BBL fixed roof storage tank used to store gas in the event that there is 002 a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. 003 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 004 Truck loadout of crude oil. One (1) above ground 400 bbl atmospheric produced water storage tank. 005 Emissions from this tank are controlled by a combustor(VRU)with a minimum destruction efficiency of 95%. 006 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? PM,o 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 X No Regulation 7, Sections XII and XVII.C may apply) Point 005: 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)? (Section 3 on APEN) Point 005: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? (Section 3 on APEN) Point 005: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? (Section 3 on APEN) If so, submit Form APCD-105 Section 5— Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific using E&P Tanks(Refer to Section 14 for calculations) 002 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 003 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 004 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] 005 CDPHE Emission Factors (PS Memo 09-02) 006 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 Page 2 001 175,200 BBL per year(146000 x 1.2) 002 600,000 scf/yr=> 0.60 MMSCF/yr 003 400,000 scf/day => 146,000,000 scf/yr= 146 mmscf/yr 004 229,950 BBL per year crude oil loaded 005 100,740 BBL per year(83,950 x 1.2) Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 006 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 001 146,000 BBL per year 2010 002 600,000 scf/yr=> 0.60 MMSCF/yr 003 400,000 scf/day => 146,000,000 scf/yr= 146 mmscf/yr 004 229,950 BBL per year crude oil loaded 005 83,950 BBL per year Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 576 --- 520 51 006 Flanges 8 --- 24 4 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 001 146,000 BBL per year 002 600,000 scf/yr=> 0.60 MMSCF/yr 003 400,000 scf/day => 146,000,000 scf/yr= 146 mmscf/yr 004 229,950 BBL per year crude oil loaded 005 83,950 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 006 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Does this facility use control devices? X Yes No Page 3 AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor(VCU) 95 003 01 Tornado 40'flare stack 95 005 01 Cimarron smokeless combustor(VCU) 95 Section 6— Emission Summary (tons •er year) Point NO, VOC CO SOx PM10 Single Total HAP HAP 001 0.03 11.7 0.2 0.5 (n-hexane) 0.60 002 --- 10.1 0.1 0.2 (n-hexane) 003 7.7 2455.3 41.8 0.04 1.9 33.6 (n- 45.6 PTE: hexane) 004 --- 11.9 --- -- 0.5 (n- 1 2 hexane) 005 --- 13.2 -- -- 1.1 (n- 1 5 hexane) 006 --- 2.4 --- - --- 0.1 (n- 0.1 hexane) 001 0.03 9.7 0.2 - 0.4 (n-hexane) 0.50 0.1 002 10.1 (n-hexane) 0.2 Uncontrolled point 33.6 (n- source emission rate: 003 7.7 2455.3 41.8 0.04 1.9 hexane) 45.6 004 --- 11.9 --- --- -__ 0.5 (n- 1 2 hexane) 005 -- 11.0 -- --- --- 0.9 (n- 1.2 hexane) 006 --- 2.4 -- --- -- 0.1 (n- 0.1 hexane) TOTAL(TPY) 7.7 2500.4 42.0 -- --- 35.6 (n- 48 8 hexane) 001 0.04 0.5 0.2 --- -- 0.02 (n- 0.02 hexane) 0.1 002 10.1 (n-hexane) 0.2 003 7.7 122.8 41.8 0.04 1.9 1.7 (n 2.3 Controlled point hexane) source emission rate: 00411.9 0.5 (n- 1.2 --- --- -- hexane) 005 --- 0.6 -- -- - 0.1 (n- 0.1 hexane) 006 --- 2.4 --- -- 0.1 (n- 0 1 hexane) INSIGNIFICANTS 0.3 1.5 0.4 -- -- 0.13 (n- 0.17 (TPY) hexane) TOTAL PERMITTED 7,7 148.3 42.0 2.6 (n- 3.9 (TPY) hexane) Section 7-Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions Ib/ r (Ib/yr) reportable? Rate( Y ) Point 001 Page 4 Benzene 71432 A 126 Yes 6 Toluene 108883 C 122 No 6 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 42 No 2 n-Hexane 110543 C 844 No 42 2,2,4-Trimethylpentane 540841 C 70 No 4 Point 002 Benzene 71432 A 45 No 45 Toluene 108883 C 34 No 34 Ethylbenzene 100414 C 6 No 6 Xylenes 1130207 C 14 No 14 n-Hexane 110543 C 276 No 276 Point 003 Benzene 71432 A 10951 Yes 548 Toluene 108883 C 8269 Yes 413 Ethylbenzene 100414 C 1390 Yes 70 Xylenes 1130207 C 3435 Yes 172 n-Hexane 110543 C 67135 Yes 3357 Point 004 Benzene 71432 A 160 Yes 160 Toluene 108883 C 524 No 524 Ethylbenzene 100414 C 39 No 39 2,2,4-Trimethylpentane 540841 C 203 No 203 Xylenes 1130207 C 697 No 697 n-Hexane 110543 C 955 No 955 Point 005 Benzene 71432 A 588 Yes 29 n-Hexane 110543 C 1847 Yes 92 Point 006 Benzene 71432 A 8 No 8 Toluene 108883 C 12 No 12 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 by the operator. Page 5 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 001 01 VOC CDPHE PS Memo 05-01 Site-specific sampling 002 01 VOC, State only requirement Site-specific gas HAPS analysis 003 01 VOC, State only requirement • Site-specific gas HAPS analysis Section 9 —Source Classification Is this a new previously un-permitted source? 001 002 003 004 005 006 YES X X X X X X NO What is this point classification? True Minor X X X X X Synthetic Minor Major X What is this facility classification? True Synthetic X Major Minor Minor Classification relates to what programs? X Title V PSD NA NSR X MACT Is this a modification to an existing permit? Yes X No 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? VOC 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)? X Yes 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? NOx emissions are less than 40 TPY. AIRS Point Section 12—Regulatory Review Requlation:l=Particulate",Smoke, Carbon Monoxide and Sulfur Dioxide Page 6 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-APENe,,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 since emissions from production exceed 2 tons per year VOC) 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 004 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. Part B —Construction Permit Exemptions 001-006 Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section/I.D.3.a) Regulation 6-- New Source Performance Standards 001-005 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). 006 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. Regulation 7"—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is not located in the 8-hr ozone control area; therefore, this facility is not 001-005 subject to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... This facility is an oil and gas operation that does not operate any equipment subject to Section XVII of this regulation. Section XII.G: If facility is a natural gas processing plant located in non-attainment 006 area,then subject to Section XII.G. Facility is not a natural gas processing plant, therefore, not subject to Section XII.G. " =Re•ulation 8'— Hazardous Air:Pollutants '":r, r E '' 001-005 None Page 7 MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators and fugitives), then fugitive emissions are subject to MACT HH. 006 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? Facility is area source for MACT HH, therefore, only TEG dehydrators are subject to MACT HH. This facility has no TEG dehydrators, so facility not subject to MACT HH. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control Factor CAS# (Y/N) Source (%) 3.1787 V0C No E&P Tanks 95 lb/1000 gal _ 0.068 AP-42, lb/MMBtu N0x No Table 13.5-1 NA 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 0.0205 Benzene No E&P Tanks 95 lb/1000 gal 01 Crude oil Storage Tanks 0.0183 Toluene No E&P Tanks 95 001 b/1000 gal 0.0003 lb/1000 gal Ethylbenzene No E&P Tanks 95 0.0068 Xylenes No E&P Tanks 95 lb/1000 gal _ 0.1376 n-hexane No E&P Tanks 95 lb/1000 gal 0.0114 2,2,4-TMP No E&P Tanks 95 lb/1000 qal SCC 40400301 — Fixed Roof Tank, Oil field storage of crude, breathing losses 33666.6667 V0C No Engineering 0 ' lb/MMscf Calculation 75.0 lb/MMscf Benzene No Engineering 0 Calculation 56.6667 Engineering 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 002 9.5 lb/MMscf Ethlybenzene No Engineering 0 Calculation 23.5 lb/MMscf Xylenes No Engineering 0 Calculation 459.5 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 33634.2466 V0C No Engineering 95 lb/MMscf Calculation 0.068 AP-42, lb/MMBtu N0x No Table 13.5-1 NA 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 75.0068 Benzene No Engineering 95 01 Flare lb/MMscf Calculation 003 56.6438 Toluene No Engineering 95 lb/MMscf Calculation 9.5205 Ethlybenzene No Engineering 95 lb/MMscf Calculation 23.5274 Engineering lb/MMscf Xylenes No Calculation 95 459.8288 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 004 01 Truck Crude oil Loadout 2.47 Iga11000 V0C No AP-42 0 Page 8 • 0.0007 lb/BBL Benzene No AP-42 0 0.0023 lb/BBL Toluene No AP-42 0 0.0002 lb/BBL Ethylbenzene No AP-42 0 0.0030 lb/BBL Xylenes No AP-42 0 0.0042 lb/BBL n-hexane No AP-42 0 0.0009 Ib/BBL 2,2,4-TMP No AP-42 0 SCC 4060132: Crude Oil: Submerged Loading (Normal Service) 6.2381 CDPHE PS lb/1000 gal VOC No Memo 09-02 95 throughput Produced Water 0.1667 CDPHE PS 01 Storage Tanks lb/1000 gal Benzene No Memo 09-02 95 005 throughput 0.5238 CDPHE PS lb/1000 gal n-Hexane No Memo 09-02 95 throughput SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, NA 006 Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections,seals, drains) Section 14— Miscellaneous Application Notes . AIRS Point 001 Crude Oil Storage Tanks Site-specific emission factor using E&P Tanks: VOC = (9.746 TPY *2000) / 146000 bbl/yr= 0.1335 lb/bbl *1000/42 = 3.1787 lb/1000 gal Benzene = (0.063 TPY*2000)/ 146000 bbl/yr= 0.0008 lb/bbl * 1000/42 = 0.0205 lb/1000 gal Toluene = (0.056 TPY*2000) / 146000 bbl/yr= 0.0008 lb/bbl *0.0183 lb/1000 gal Ethylbenzene = (0.001 TPY *2000) / 146000 bbl/yr= 0.00001 lb/bbl * 1000/42 = 0.0003 lb/1000 gal Xylenes = (0.021 TPY * 2000)/ 146000 bbl/yr= 0.0003 lb/bbl * 1000/42 = 0.0068 lb/1000 gal n-hexane = (0.422 TPY *2000)/ 146000 bbl/yr= 0.0058 lb/bbl * 1000/42 = 0.1376 lb/1000 gal 2,2,4-TMP= ;0.035 TPY* 2000)/ 146000 bbl/yr= 0.0005 lb/bbl * 1000/42 = 0.0114 lb/1000 gal AIRS Point 002 Emergency Storage Tank Emissions were calculated using VOC wt fraction using a sales gas analysis from the facility dated August 9, 2010. (scf/hr) * (Ib/lb-mol) * (% fraction from sales gas analysis)/ (379.4 scf/lb-mol) = lb/hr* 12 hrs/event * 3 events/yr/2000 lb/T) =TPY VOC = (10.1 TPY*2000 lb/T)/ (0.6 mmscf/yr) = 33666.6667 lb/mmscf Benzene = (45 Ib/yr)/ (0.6 mmscf/yr= 75.0 lb/mmscf Toluene = (34 Ib/yr)/(0.6 mmscf/yr) = 56.6667 lb/mmscf Ethylbenzene = (5.7 Ib/yr)/(0.6 mmscf/yr) = 9.5 lb/mmscf Xylenes = (14.1 Ib/yr) /(0.6 mmscf/yr) =23.5 lb/mmscf n-hexane = (275.7 lb/yr)/ (0.6 mmscf/yr) =459.5 lb/mmscf Page 9 AIRS Point 003 Flare 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 lb/T) = TPY VOC = (2455.3 TPY*2000 lb/T)/ (146 mmscf/yr) = 33634.2466 Ib/mmscf NOx and CO (from AP-42, Chapter 13, Table 13.5-1 (NOx= 0.068 Ib/mmbtu; CO = 0.37 lb/mmbtu) SO2 emissions based on AP-42 Table 1.4-2 (5O2 = 0.00037 lb/MMBtu) PM10 and PM2.5 based on AP-42 Table 13.5-2 (PM10 and PM2.5= 40 ug/l) Benzene = (10951 Ib/yr) / 146 mmscf/yr= 75.0068 lb/mmscf Toluene = (8270 Ib/yr)/ 146 mmscf/yr= 56.6438 lb/mmscf Ethylbenzene = (1390 Ib/yr) / 146 mmscf/yr= 9.5205 lb/mmscf Xylenes= (3435 Ib/yr)/ 146 mmscf/yr= 23.5274 lb/mmscf n-hexane = (67135 lb/ r)/ 146 mmscf/yr=459.8288 lb/mmscf AIRS Point 004 Truck crude oil Loadout 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 524 deg. R L 2.471b/10^3 gal 1.04E-01 lb/bbl Annual requested Throughput 9657900ga1/yr Annual requested VOC emissions 238611b/yr 11.93tpy Benzene =(159.97 Ib/yr)/(229950) = 0.0007 lb/bbl Toluene = (523.84 Ib/yr)/(229950) = 0.0023 lb/bbl Ethylbenzene= (38.59 Ib/yr)/(229950) = 0.0002 lb/bbl Xylenes= (696.88 Ib/yr)/(229950) = 0.0030 lb/bbl n-hexane=(954.88 Ib/yr)/(229950) = 0.0042 lb/bbl 2,2,4-TMP = (202.52 Ib/yr)/ (229950) = 0.0009 lb/bbl Page 10 AIRS Point 005 Produced Water Storage Tanks 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 operator stated on the APEN that the tanks contain less than 1% by volume crude oil on an annual average basis. There is a categorical exemption for such source (Regulation 3, Part B, Section II.D.1.m). However, this source will be permitted because the source is at a major source facility, accepting Federally enforceable controls for PSD, and therefore, this source needs to be included in the overall facility AIRS Point 006 Fugitive emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(APEN threshold) and TOTAL FACILITY is greater than 5 TPY (permit threshold). When reviewing calculations for a similar facility in non-attainment, 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). EOG submitted APENS for the fugitive emissions on 2/14/12. Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY(permit threshold) and is a major source for VOC, and synthetic minor for PSD, n-hexane and total HAPS. The original package did not calculate the emissions correctly. Operator used mass fraction VOC % instead of the mole fraction VOC %. Because of this change, the source could be a major source due to different input. This was brought to the operator's attention in June 2011. I received revised calculations on August 25, 2011. This facility's status in now Major Source for Title V. Facility-wide Operator Comments Operator provided comments on the DRAFT permit on 10/19/11. The comments are: 1. p1, Facility Equipment ID 001 -please rename"Crude oil storage tanks" . I revised the permit accordingly. 2. Remove the"VRU"-as we spoke ...VCU, everywhere. I revised the permit accordingly. 3. P3. reference method 22- and a time frame. Email dated 9-27-11 from Jacob Sebesta (I'll forward it to you if needed) This is a common thread for all the permits. During our phone conversation on 10/20/11, we discussed an email sent to EOG from Jake Sebesta providing information on what an inspector expects for a Method 22 reading. 4. P3 table,Truck loading 006-this should read"Crude oil and Produced water" -it's both volumes combined.. / revised the permit accordingly. 5. p4. section 17-a. Flares shall be enclosed The flares are NOT enclosed . I modified the condition to reflect "VCU"rather than "flare.° 6. p5. section 19 and section 20- The initial testing will provide accurate composition-may we request analyzing for extended comp every two years? it's not likely to change and provide substantially different calc's...? During our phone call on 10/20/11, 1 explained to him that several conditions would be satisfied with the one extended gas analysis, and that the Division feels that testing once a year is not a burden on an operator. 7. P7. Permit history-table add the combustor VCU...? /revised the permit accordingly. 8. P9. POINT 004-N-Hexane... weight percent of 0.63 should be controlled, 1.12 Ib/MMSCF and uncontrolled 22.36 lb/MMSCF..During our phone call on 10/20/11, we discussed how the emission factors for the produced water tank and flare should be the same because the same material would be either going to the flare or emergency tank if the flare breaks down. I did a mass balance, and I got very similar emission factors. Page 11 N " O O c 0. L aE c a c o a O T u o m .n F a' a_ y o ti c n - E z m - re, n ' E i c c Vl , Q 0 W M" C N �i s ❑ > O a c O G T P V 'OJ' p 0 O >i >L. v L QF d u b .O V Z N a 0 O 6 > ^' .a O �... vi o d (N Vii yo ^, u ° d W d y � W V n - C 0 0 0 = n O O ,-i y m M c 0. 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O q N �a c o o o °o a ca N -a mu °. v, C W - c el o a ,� o V V o N „ J R Ee a° d - c a w ; — 4 c c A u °o tu ei Z 7 •E O E 4 E E . C G .e°- v v :C „ •:R s Q z w - 6 __ a E O `s u h C v. 4 7 F W N C b b u CPr- E y L N G W E O VI O A1:1 q a_E" 70 en 0 4 G joa C o ° U C G o 'p a L 0 0 `o o b E „"€ o.- AM .„RI q m� u N P o a w _c u co F4 u I - ;I s I g yry „ u C w o Q¢z N e 0 a E o c N o .E N V o �' G C .V A O L C c N e C �i s v u w . C 4� _ O NN o ©© X 1O E = o S 5.q 3 . o ,Z.•U 'e E c u E ?rd .uc ' 5 a > 0 -87x F — X . 00 5 a u x z d ° W U w O w J O " d ❑ P. W c >' W V] V1 v® V1 C cc Air Pollutant Emission Notice (APEN)— and—Application for Construction Permit - OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTE*_..:::' "-. - Current Status(Check all thatta�appply) Reason for APEN Submittal(Check all that apply) 4O6 25 241 AIRS ID#': [Q3- '0 S96--LSO] ❑ APEN update only4 ❑ New or previously unreported battery ❑ Modification to existing sources .. ❑ Previously grandfathered battery- ID for coverage under general permit no.GPsp�1 sp b ❑ Synthetic minor facility &cancellation request for individual permits: '^2----".' ❑ Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPOI �7 ❑ Administrative permit amendment? /c Permitted under individual permit: (Dice 13kalt ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division ❑To review a draft of the permit.prior to issuance Company Name9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address1°: 600 l7`h Street,Suite 1000N day id_long@ eogreso ur 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 l: Critter Creek 17-21H Number of tanks: 4 Location's(QQ Sec.Twp.Range.): SESE Sec 21,T11N,R63 W County: Weld Total tank capacity[bbl]: 1,600(400 ea) Calendar year for which"Actual"data applies 3: 2010 Year(s)tank(s)were placed in service14: 2010 Control Description's: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency's: 95% Condensate Throughput'?[bbl/year] Requested's: 146,000 Maximum for PTE calculation's: 175,200 Actual'-°: 146,000 While Controls Operational2I 146,000 Other equipment at facility22: VCU,flare,heater treater(1),line heater(1),produced 1120 tank(I),emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPO I 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 Emissions1s Actual Emissions'° Pollutant24 [lb/bbl] PTE2' Uncontrolled26 Controlled27 Uncontrolled26 Controlled' VOC[tons/year] 0.1335 11.7 N/A N/A 9.7 0.49 NOx[tons/year] N/A 0.03 0.03 0.03 CO[tons/year] N/A 0.17 0.17 0.17 Benzene[lbs/year] 126.0 6.3 n-Hexane[lbs/year] 844.0 42.2 Wells serviced by this tank or tank battery API#: 05-123-31505-00 Name: Critter Creek 17-2111 Ei Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑ Newly Reported Well i—, API#: Name: ❑Newly Reported Well N ''i API#: Name • ❑ Newly Reported Well ko API#: Name: ❑ Newly Reported Well cn m API#: Name: ❑ Newly Reported Well i 0 o The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of : my knowledge and belief. If this is a registration for coverage under general permit GPO1,I further certify that this source is and will be operated ro �in ful(comp with each condition of general permit GPOI. N.) Signature of Legally Authorizecyerson(not a vendor or consultant) Date o 11 David Long Division Environmental Manager I Type or Print Name of Person Signing Above Official Title w N Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: u' filing of up to S tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI (303)692-3150 o $250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2EOG CC 17-2111 FormAPCD-205-E&PCondensateTankAPEN-update.docx No N L 0 YO 8 0. o f o0o E O .74 a ❑ E z v m en �n F L c u - > a, 4 m e a w vt w o , a s N t =. Y �.1. a y a N 0 0 0, e G '$ " E 0 0 IA ca. d V 0. 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Pr Io vn I v v v c;) v n c v v N U m Q a Q o c 0 0 'c a t acs u E- a co R x u 0 u u g . x o `o y a ? e >. v v C4 ,N v c W 5 O O ? y v o ,- ,°, Z 5 A o U F- F- C > - d Q c 0 2 > u e ≥, X �' ? - CYi Q`� O x uu c0 c U▪ on b0C v Q fA v ❑ 0 u u km r/� — V] V] V1 v Vl D FT STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT e AIR POLLUTION CONTROL DIVISION y TELEPHONE: (303)692-3150 *� G7 �+ •4176* CONSTRUCTION PERMIT PERMIT NO: 11WE1367 WE1 367 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas production facility, known as Critter Creek 17-21H., located in the SESE of Section 21, Township 11 North, Range 63 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 Four (4) 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. One (1) 400 BBL fixed roof storage tank used to store gas in the ET#4025 002 event that there is a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. Separator controlled by a 40' flare stack. Flare has a minimum Flare 003 combustion efficiency of 95%. The flare is not enclosed. Truck 004 Truck loadout of crude oil. Loadout PW Tank One (1) above ground 400 bbl atmospheric produced water #1 005 storage tank. Emissions from this tank are controlled by a combustor(VCU) with a minimum destruction efficiency of 95%. Fugitive 006 Equipment leaks (fugitive VOCs) from a natural gas production facility. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the APCD no later than fifteen days after issuance of this permit or activity bV submitting a Notice of Startup (NOS) form to the APCD. The Notice of Startup (NOS) form may be downloaded online at AIRS ID: 123/8958/999 Page 1 of 12 Condensate Tank Version 2009-1 EOG Resources, Inc. olor Depa en f Ii Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. 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). 3. 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 fora 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.) 4. 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.) 5. 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 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 Crude Oil 001 --- 0.5 -- Point Storage Tanks ET#4025 002 --- 10.1 --- Point Flare 003 7.7 122.8 41.8 Point Truck Loadout 004 --- 11.9 -- Point PW Tank#1 005 0.6 --- Point Fugitive 006 --- 2.4 --- Fugitive See ?Votes 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. AIRS ID: 123/8958/999 Page 2 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 7. Point 001: This emissions point shall be configured with a combustor. The combustor shall reduce the uncontrolled 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. Point 003: 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. 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 005: 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 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. Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liequids 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 11. 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 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 146,000 BBL/yr Storage Tanks ET#4025 002 Natural gas venting to atmosphere 600,000 SCF/yr Flare 003 Natural gas flaring 146 MMSCF/yr Truck Loadout 004 Crude oil and produced water loading 229,950 BBL/yr PW Tank#1 005 Produced water throughput 83,950 BBUyr 12. Point 005: 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 AIRS ID: 123/8958/999 Page 3 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 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) 17. Point 004: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Points 001 and 003: 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. Point 005: 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. 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. (H) 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 AIRS ID: 123/8958/999 Page 4 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 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 20. Point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site- specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 21. Points 002 and 003: 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 banana lb mot. r lb 1 Sa6 scf x =benzene wt.frac.**MWgas MMscf 379.3 scf lb,no 124Mscf. 22. Point 003: The owner or operator shall demonstrate compliance with Condition 14 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 23. Point 006: 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 006: 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 AIRS ID: 123/8958/999 Page 5 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 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: 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. This source is subject to the provisions of Regulation number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The application for the Operating Permit is due within one year of becoming major. 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 AIRS ID: 123/8958/999 Page 6 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 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 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: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for: (5) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank and crude oil loadout and associated fugitives. New major source facility. AIRS ID: 123/8958/999 Page 7 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/reou lations/airreqs/100102aocccommon provisionsreq.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 (Ib/yr) reportable? Rate (Ib/yr) Benzene 71432 A 126 Yes 6 Toluene 108883 C 122 No 6 Ethylbenzene 100414 C 2 No 0 001 Xylenes 1130207 C 42 No 2 n-Hexane 110543 C 844 No 42 2,2,4- 540841 C 70 No 4 Trimethylpentane Benzene 71432 A 45 No 45 Toluene 108883 C 34 No 34 002 Ethylbenzene 100414 C 6 No 6 Xylenes 1130207 C 14 No 14 n-Hexane 110543 C 276 No 276 Benzene 71432 A 10951 Yes 548 Toluene 108883 C 8269 Yes 413 003 Ethylbenzene 100414 C 1390 Yes 70 Xylenes 1130207 C 3435 Yes 172 n-Hexane 110543 C 67135 Yes 3357 Benzene 71432 A 160 Yes 160 004 Toluene 108883 C 524 No 524 Ethylbenzene 100414 C 39 No •39 AIRS ID: 123/8958/999 Page 8 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 2,2,4 540841 C 203 No 203 Trimethylpentane Xylenes 1130207 C 697 No 697 n-Hexane 110543 C 955 No 955 • Benzene 71432 A 588 Yes 29 005 n-Hexane 110543 C 1847 Yes 92 Benzene 71432 A 8 No 8 Toluene 108883 C 12 No 12 006 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: Point 001: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42, Table 13.5-1 CO • 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42, Table 13.5-1 VOC 3.1787 lb/1000 gal 0.1589 lb/1000 gal E&P Tanks 71432 Benzene 0.0205 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 108883 Toluene 0.0183 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 100414 Ethylbenzene 0.0003 lb/1000 gal 0.00002 lb/1000 gal E&P Tanks 1330207 Xylenes 0.0068 lb/1000 gal 0.0003 lb/1000 gal E&P Tanks 110543 n-hexane 0.1376 lb/1000 qal 0.0069 lb/1000 gal E&P Tanks 540841 2,2,4-TMP 0.0114 lb/1000 gal 0.0006 lb/1000 gal 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: Emission Factors Weight Fraction Source CAS# Pollutant Uncontrolled of Gas (%) Lb/MMscf Engineering VOC 33666.6667 lb/MMscf 46.18 Calculation Engineering 71432 Benzene 75.0 lb/MMscf 0.10 Calculation Engineering 108883 Toluene 56.6667 lb/MMscf 0.08 Calculation 100414 Ethylbenzene 9.5 lb/MMscf 0.01 Engineering Calculation 1330207 Xylenes 23.5 Ib/MMscf 0.03 Engineering Calculation AIRS ID: 123/8958/999 Page 9 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 Emission Factors Weight Fraction Source CAS# Pollutant Uncontrolled of Gas (%) Lb/MMscf 110543 n-hexane 459.5 lb/MMscf 0.63 Engineering 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 16,666.7 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 003: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled NOx 0.068 0.068 AP-42 lb/MMBtu Ib/MMBtu CO 0.37 AP-42 0.37 lb/MMBtu lb/MMBtu VOC 46.18 33634.2466 1681.7123 Engineering lb/mmscf lb/mmscf Calculation PMio -- 40 ug/I 40 ug/l AP-42, Table 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf Ib/MMBtu Ib/MMBtu 71432 Benzene 0.10 75.0068 3.7503 Engineering lb/mmscf lb/mmscf Calculation 108883 Toluene 0.08 56.6438 2.8322 Engineering lb/mmscf lb/mmscf Calculation 100414 Ethylbenzene 0.01 9.5205 0.4760 Engineering lb/mmscf lb/mmscf Calculation 1330207 Xylenes 0.03 23.5274 1.1764 Engineering lb/mmscf lb/mmscf Calculation 110543 n-hexane 0.63 459.8288 22.9914 Engineering lb/mmscf lb/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 2-03H well. The controlled VOC and HAP emissions factors for point 003 are based on the flare control efficiency of 95%. Point 004: Emission Factors -Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.104 AP-42 71432 Benzene 0.0007 AP-42 108883 Toluene 0.0023 AP-42 100414 Ethylbenzene 0.0002 AP-42 1330207 Xylenes 0.0030 AP-42 110543 n-hexane 0.0042 AP-42 AIRS ID: 123/8958/999 Page 10 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 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 Ib/Ib-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 in the vapors the VOC emission factor. Point 005: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 PS Memo 09-02 110543 n-Hexane 0.022 0.0011 PS Memo 09-02 71432 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions factors for point 005 are based on the combustor control efficiency of 95%. Point 006: 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% -- *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 AIRS ID: 123/8958/999 Page 11 of 12 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE1367 it Pollution Control Division Issuance 1 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 February 10,2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: Applicable Status Requirement O Major Source: VOC Operating Permit Synthetic minor source: n-hexane and total HAPS PSD• Synthetic Minor Source VOC 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.cdohe.state.co.us/ap/oilqaspermittinghtml AIRS ID: 123/8958/999 Page 12 of 12 STATE OF COLORADO John W.Hickenlooper,Governor p co Christopher E.Urbina,MD,MPH Afrir% Executive Director and Chief Medical Officer r,Q Dedicated to protecting and improving the health and environment of the people of Colorado * i 4300 Cherry Creek Dr.S. Laboratory Services Division •rare•* 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 March 23, 2012 Mr. Steve Moreno Weld Countys Clerk 1402 N. 17t Ave. Greeley, CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for EOG Resources, In. This public notice will be published in the Greeley Tribune on March 29, 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 1 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 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: STEPHANIE CHAOUSY 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 oF.001 Christopher E. Urbina,MD, MPH . =4,\ Executive Director and Chief Medical Officer Fe N r4 o Dedicated to protecting and improving the health and environment of the people of Colorado . x 4300 Cherry Creek Dr. S. Laboratory Services Division *W418:7-6 "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 Released to: The Greeley Tribune on March 26, 2012, published March 29, 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 an oil and natural gas production facility in Weld County, Colorado called Jersey 12-25H. This source will consist of four (4)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, one (l)-400BBL produced water tank, truck loading for the crude oil and associated fugitive emissions. This source will be located in the NWNW quarter-quarter of Section 25 of Township 11 North, Range 63 West in Weld County. This source would be considered a major source 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 100 tons per year for each criteria pollutant and less than 10 tons per year any single hazardous air pollutant (HAP) and 25 tons per year total combined HAP, the source will be considered a synthetic minor source not subject to PSD and MACT review. The source will also have permitted emissions less than 250 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 I1I.C.1.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: Stephanie Chaousy, PE 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: 11WE1579 Source Location: NWNW S25, T11N, R63W, Weld County(Attainment) Point 001: (4)400 BBL above ground atmospheric crude oil storage tanks Point 002: (1)400 BBL above ground atmospheric emergency storage tank for vented gas. Point 003: Plant flare with a minimum combustion efficiency of 95%. Equipment Description: Point 004: Crude oil truck loadout Point 005: (1) 400 BBL above ground atmospheric produced water storage tank. Point 006: Fugitive emissions AIRS ID: 123-9044 Date: September 22, 2011; Revised application received 12/31/11 (began working on it 2/9/12) Review Engineer: Stephanie Chaousy, P.E. Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt *If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" 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, May 23, 2011: Jake emailed David Long regarding the flare when did you mail an Information calculations. It appeared that the consultant used the mole Request letter to the source? fraction VOC instead of the mass fraction VOC. The change in VOC could change the status of the facility. Jamie Christopher submitted new calculations for this facility on 9/19/11. The facility is now a major source. On what date was this application February 11, 2011. Received revised calculations on complete? August 25, 2011. Revised application received 12/30/11 Section 4—Source Description AIRS Point Equipment Description Four(4) above ground 400 bbl atmospheric crude oil storage tanks. Emissions 001 from these tanks are controlled by a Cimarron smokeless combustor(vapor recovery unit)with 95% control efficiency. Page 1 One (1)400 BBL fixed roof storage tank used to store gas in the event that there is 002 a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. 003 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 004 Truck loadout of crude oil. One (1) above ground 400 bbl atmospheric produced water storage tank. 005 Emissions from this tank are controlled by a combustor(VRU)with a minimum destruction efficiency of 95%. 006 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? PMio 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 PMio 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 X No Regulation 7, Sections XII and XVII.C may apply) Point 005: 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)? (Section 3 on APEN) Point 005: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? (Section 3 on APEN) Point 005: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? (Section 3 on APEN) If so, submit Form APCD-105 Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific using E&P Tanks (Refer to Section 14 for calculations) 002 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 003 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 004 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] 005 CDPHE Emission Factors (PS Memo 09-02) 006 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? X I Yes No Basis for Potential to Emit(PTEI AIRS Point Process Consumption/Throughput/Production Page 2 001 109,500 BBL per year(91250 x 1.2) 002 600,000 scf/yr= >0.6 MMSCF/yr 003 260,000 scf/day => 94,900,000 scf/yr= 94.9 mmscf/yr 004 127,750 BBL per year crude oil loaded 005 43800 BBL per year(36500 x 1.2) Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 006 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 91,250 BBL per year 2011 002 600,000 scf/yr= >0.6 MMSCF/yr 003 260,000 scf/day=> 94,900,000 scf/yr= 94.9 mmscf/yr 004 127,750 BBL per year crude oil loaded 005 36500 BBL per year Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 576 --- 520 51 006 Flanges 8 --- 24 4 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 91,250 BBL per year 002 600,000 scf/yr= >0.6 MMSCF/yr 003 260,000 scf/day a 94,900,000 scf/yr= 94.9 mmscf/yr 004 127,750 BBL per year crude oil loaded 005 36500 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 006 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Does this facility use control devices? X I Yes No Page 3 AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor(VCU) 95 003 01 Tornado 40' flare stack 95 005 01 Cimarron smokeless combustor(VCU) 95 Section 6 —Emission Summa (tons per year) Point NO, VOC CO SOx PM10 Single Total HAP HAP 001 0.02 7.3 0.13 0.3 (n-hexane) 0.42 002 --- 10.1 --- --- --- 0.14 0.2 (n-hexane) 003 5.0 1595.9 27.2 0.03 1.3 21.8 (n 29.6 PTE: hexane)' 004 --- 6.6 --- --- - 0.3 (n- 0 7 hexane) 005 --- 5.7 --- --- 0.5 (n- 0 6 hexane) 006 --- 2.4 --- --- 0.1 (n- 0 1 hexane) 001 0.02 6.1 0.13 0.3 (n-hexane) 0.4 002 - 10.1 --- --- 0.14 Uncontrolled point (n-hexane) 0.2 source emission rate: 003 5.0 1595.9 27.2 0.03 1.3 21.8 (n- 29.6 hexane) 004 --- 6.6 --- ___ 0.3 (n- 0 7 hexane) 005 --- 4.8 --- --- -__ 0.4 (n- 0 5 hexane) 006 --- 2.4 --- ___ 0.1 (n- 0 1 hexane) TOTAL (TPY) 5.02 1625.9 27.3 0.03 1.3 23.0 (n- 31.5 hexane) 001 0.02 0.3 0.13 --- --- 0.01 (n- 0.02 hexane) 002 --- 10.1 --- __- ___ 0.14 0.2 (n-hexane) 003 5.0 79.8 27.2 0.03 1.3 1'1 (n 1.5 Controlled point hexane) source emission rate: 004 6.6 - 0.3 (n- 0.7 hexane) 005 --- 0.3 --- ___ 0.1 (n- 0 03 hexane) 006 --- 2.4 --- --- -__ 0.1 (n- 0.1 hexane) INSIGNIFICANTS 1.4 1.5 0.6 0.13 (n- 0.2 (TPY) hexane) TOTAL PERMITTED 5.0 99.5 27.3 0.03 1.3 1.8 (n- 2.5 (TPY) hexane) Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (lb/yr) reportable? Rate(lb/yr) Point 001 Page 4 Benzene 71432 A 78 Yes 4 Toluene 108883 C 70 No 4 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 26 No 1 n-Hexane 110543 C 524 No 26 2,2,4-Trimethylpentane 540841 C 44 No 2 Point 002 Benzene 71432 A 45.0 No 45.0 Toluene 108883 C 34.0 No 34.0 Ethylbenzene 100414 C 5.7 No 5.7 Xylenes 1130207 ' C 14.1 No 14.1 n-Hexane 110543 C 275.7 No 275.7 Point 003 Benzene • 71432 A 7118 Yes 356 Toluene 108883 C 5375 Yes 269 Ethylbenzene 100414 C 904 Yes 45 Xylenes 1130207 C 2233 Yes 112 n-Hexane 110543 C 43638 Yes 2182 Point 004 Benzene 71432 A 89 Yes 89 Toluene 108883 C 291 No 291 Ethylbenzene 100414 C 21 No 21 2,2,4-Trimethylpentane 540841 C 113 No 113 Xylenes 1130207 C 387 No 387 n-Hexane 110543 C 531 Yes 531 Point 005 Benzene 71432 A 256 Yes 13 n-Hexane 110543 C 803 No 40 Point 006 Benzene 71432 A 8 No 8 Toluene 108883 C 12 No 12 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 lI.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. Page 5 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 001 01 VOC CDPHE PS Memo 05-01 Site-specific sampling 002 01 VOC, State only requirement Site-specific gas HAPS analysis 003 01 VOC, State only requirement Site-specific gas HAPS analysis 006 01 VOC, State only requirement Site-specific gas HAPS analysis 006 01 VOC, State only requirement Hard component HAPS count Section 9—Source Classification Is this a new previously un-permitted source? 001 002 003 004 005 006 YES X X X X X X NO What is this point classification? True Minor X X X X Synthetic Minor X Major What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? Yes X No 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? VOC 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)? X Yes 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? NOx emissions are less than 40 TPY. AIRS Point Section 12— Regulatory Review 'Regulation 1' Particulate, Smoke;Carbon.Monoxide and Sulfur Dioxide Page 6 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 since emissions from production exceed 2 tons per year VOC) 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 004 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. Part B —Construction Permit Exemptions 001-006 Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section ll.D.3.a) Regulation 6- New Source Performance Standards 001-005 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). 006 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. Regulation'7-Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is not located in the 8-hr ozone control area; therefore, this facility is not 001-005 subject to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... This facility is an oil and gas operation that does not operate any equipment subject to Section XVII of this regulation. Section XII.G: If facility is a natural gas processing plant located in non-attainment 006 area, then subject to Section XII.G. Facility is not a natural gas processing plant, therefore, not subject to Section XII.G. Regulation 8-Hazardous Air Pollutants 001-005 None Page 7 MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators . and fugitives), then fugitive emissions are subject to MACT HH. 006 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? Facility is area source for MACT HH, therefore, only TEG dehydrators are subject to MACT HH. This facility has no TEG dehydrators, so facility not subject to MACT HH. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control Factor CAS# (Y/N) Source (%) 3.1635 VOC No E&P Tanks 95 lb/1000 gal 0.068 AP-42, Ib/MMBtu NOx No Table 13.5-1 NA 0.37 AP-42, Ib/MMBtu CO No Table 13.5-1 NA 0.02 lb/1000 Benzene No E&P Tanks 95 01 Crude oil Storage Tanks gal 001 0.018 Toluene No E&P Tanks 95 lb/1000 gal 0.0005 Ethylbenzene No E&P Tanks 95 lb/1000 gal y 0.0068 Xylenes No E&P Tanks 95 lb/1000 gal y 0.1367 n-hexane No E&P Tanks 95 lb/1000 gal SCC 40400301 —Fixed Roof Tank, Oil field storage of crude, breathing losses 33666.6667 Engineering lb/MMscf VOC No Calculation 0 75.0 lb/MMscf Benzene No Engineering 0 Calculation 56.6667 Engineering 002 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 9.5 lb/MMscf Ethlybenzene No Engineering 0 Calculation 23.5 lb/MMscf Xylenes No Engineering 0 Calculation 459.5 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 33633.2982 I Engineering lb/MMscf VOC No Calculation 95 0.068 AP-42, lb/MMBtu NOx No Table 13.5-1 NA 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 75.0084 Benzene No Engineering 95 01 Flare No Calculation 003 56.6365 Toluene No Engineering 95 lb/MMscf Calculation 9.5216 Ethlybenzene No Engineering 95 lb/MMscf Calculation 23.5248 Engineering lb/MMscf Xylenes No Calculation 95 459.8314 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 0.104 lb/BBL VOC No AP-42 0 004 01 Truck Crude oil Loadout 0.0007 lb/BBL Benzene No AP-42 0 Page 8 0.0023 lb/BBL Toluene No AP-42 0 0.0002 Ib/BBL Ethylbenzene No AP-42 0 0.0030 Ib/BBL Xylenes No AP-42 0 0.0042 lb/BBL n-hexane No AP-42 0 0.0009 lb/BBL 2,2,4-TMP No AP-42 0 SCC 4060132: Crude Oil: Submerged Loading (Normal Service) 6.2381 CDPHE PS lb/1000 gal VOC No Memo 09-02 95 throughput Produced Water 0.1667 CDPHE PS 01 Storage Tanks lb/1000 gal Benzene No Memo 09-02 95 005 throughput 0.5238 CDPHE PS lb/1000 gal n-Hexane No Memo 09-02 95 throughput SCC 40400315—Fixed Roof Tank, Produced Water, working+breathing+flashing losses 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, NA 006 Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14— Miscellaneous Application Notes AIRS Point 001 Crude Oil Storage Tanks Site-specific emission factor using E&P Tanks: VOC = (6.062 TPY *2000) / 91250 bbl/yr= 0.1329 lb/bbl *1000/42 = 3.1635 lb/1000 gal Benzene = (0.039 TPY *2000)/ 91250 bbl/yr= 0.0009 lb/bbl * 1000/42 = 0.02 lb/1000 gal Toluene = (0.035 TPY* 2000) /91250 bbl/yr= 0.0008 lb/bbl * 1000/42 = 0.018 lb/1000 gal Ethylbenzene = (0.001 TPY *2000)/91250 bbl/yr= 0.00002 lb/bbl * 1000/42 = 0.0005 lb/1000 gal Xylenes = (0.013 TPY *2000) /91250 bbl/yr= 0.0003 lb/bbl * 1000/42 = 0.0068 lb/1000 gal n-hexane = (0.262TPY *2000)/ 91250 bbl/yr= 0.0057 lb/bbl * 1000/42 = 0.1367 lb/1000 gal AIRS Point 002 Emergency Storage Tank Emissions were calculated using VOC wt fraction using a sales gas analysis from the facility dated August 9, 2010. (scf/hr) * (Ib/Ib-mol) * (% fraction from sales gas analysis) / (379.4 scf/lb-mol) = lb/hr* 12 hrs/event * 3 events/yr/2000 lb/T) = TPY VOC = (10.1 TPY*2000 lb/T) /(0.6 mmscf/yr) = 33666.6667 lb/mmscf Benzene = (45 Ib/yr) / (0.6 mmscf/yr) = 75.0 lb/mmscf Toluene = (34 Ib/yr)/(0.6 mmscf/yr) = 56.6667 lb/mmscf Ethylbenzene = (5.7 Ib/yr) / (0.6 mmscf/yr) = 9.5 lb/mmscf Xylenes = (14.1 Ib/yr) /(0.6 mmscf/yr) = 23.5 lb/mmscf n-hexane = (275.7 Ib/yr) / (0.6 mmscf/yr) =459.5 lb/mmscf Page 9 AIRS Point 003 Flare 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 lb/T) = TPY VOC = (1595.9 TPY*2000 lb/T) / (94.9 Ib/mmscf) = 33633.2982 lb/mmscf NOx and CO (from AP-42, Chapter 13, Table 13.5-1 (NOx = 0.068 lb/mmbtu; CO = 0.37 lb/mmbtu) SO2 emissions based on AP-42 Table 1.4-2 (SO2 = 0.00037 lb/MMBtu) PM10 and PM2.5 based on AP-42 Table 13.5-2 (PM10 and PM2.5=40 ug/I) Benzene = (7118.3 Ib/yr)/94.9 mmscf/yr= 75.0084 lb/mmscf Toluene = (5374.8 Ib/yr)/94.9 mmscf/yr= 56.6365 lb/mmscf Ethylbenzene = (903.6 Ib/yr)/94.9 mmscf/yr= 9.5216 lb/mmscf Xylenes= (2232.5 Ib/yr)/94.9 mmscf/yr= 23.5248 lb/mmscf n-hexane = (43638 lb//r)/94.9 mmscf/yr= 459.8314 lb/mmscf AIRS Point 004 Truck crude oil Loadout 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 524 deg. R L 2.471b/10^3 gal 1.04E-01 lb/bbl Annual requested Throughput 5365500ga1/yr Annual requested VOC emissions 132401b/yr 6.62tpy Benzene = (88.87 Ib/yr) /(127750) = 0.0007 lb/bbl Toluene = (291.02 Ib/yr)/(127750) = 0.0023 lb/bbl Ethylbenzene= (21.44 lb/yr)/ (127750) = 0.0002 lb/bbl Xylenes = (387.16 Ib/yr)/(127750) = 0.0030 lb/bbl n-hexane = (530.49 lb/yr) /(127750) = 0.0042 lb/bbl 2,2,4-TMP = (112.51 Ib/yr)/ (127750) = 0.0009 lb/bbl Page 10 AIRS Point 005 Produced Water Storage Tanks 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 operator stated on the APEN that the tanks contain less than 1% by volume crude oil on an annual average basis. There is a categorical exemption for such source (Regulation 3, Part B, Section II.D.1.m). However, this source will be permitted because the source is at a major source facility, accepting Federally enforceable controls for PSD, and therefore, this source needs to be included in the overall facility. AIRS Point 006 Fugitive emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (APEN threshold) and TOTAL FACILITY is greater than 5 TPY (permit threshold). When reviewing calculations for a similar facility in non-attainment, 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). EOG submitted APENS for the fugitive emissions on 2/14/12. Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY(permit threshold) and is a major source for VOC, and synthetic minor for PSD, n-hexane and total HAPS. The original package did not calculate the emissions correctly. Operator used mass fraction VOC % instead of the mole fraction VOC %. Because of this change, the source could be a major source due to different input. This was brought to the operator's attention in June 2011. I received revised calculations on August 25, 2011. This facility changed to Major source status. Facility-wide Operator Comments Operator provided comments on the DRAFT permit on 10/19/11. The comments are: 1. p1, Facility Equipment ID 001 -please rename"Crude oil storage tanks" . I revised the permit accordingly. 2. Remove the"VRU"-as we spoke ...VCU, everywhere. I revised the permit accordingly. 3. P3. reference method 22- and a time frame. Email dated 9-27-11 from Jacob Sebesta (I'll forward it to you if needed) This is a common thread for all the permits. During our phone conversation on 10/20/11, we discussed an email sent to EOG from Jake Sebesta providing information on what an inspector expects for a Method 22 reading. 4. P3 table, Truck loading 006-this should read"Crude oil and Produced water" -it's both volumes combined.. I revised the permit accordingly. 5. p4. section 17-a. Flares shall be enclosed The flares are NOT enclosed . I modified the condition to reflect "VCU"rather than "flare." 6. p5. section 19 and section 20- The initial testing will provide accurate composition-may we request analyzing for extended comp every two years? it's not likely to change and provide substantially different calc's...? During our phone call on 10/20/11, I explained to him that several conditions would be satisfied with the one extended gas analysis, and that the Division feels that testing once a year is not a burden on an operator. 7. P7. Permit history-table add the combustor VCU...? I revised the permit accordingly. 8. P9. POINT 004-N-Hexane... weight percent of 0.63 should be controlled, 1.12 Ib/MMSCF and uncontrolled 22.36 lb/MMSCF..During our phone call on 10/20/11, we discussed how the emission factors for the produced water tank and flare should be the same because the same material would be either going to the flare or emergency tank if the flare breaks down. I did a mass balance, and I got very similar emission factors. Page 11 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY / Current Status(Check a.,ll that apply) Reason for APEN Submittal(Check all that apply) r r :I .�� AIRS ID#': ;Z3/900/001 O APEN update only 3 a 20t1 ® New or previously unreported battery O Modification to existing sources ( ❑ Previously grandfathered battery'' ❑ Registration for coverage under general permit no.GPO I !=" ❑ Synthetic minor facility &cancellation request for individual permit': - - ❑ Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit _ O Registered under general permit no.GPOI O Administrative permit amendment" O Permitted under individual permit: I1h1E;1S19 ❑ Other: For individual permit applications,check if you wants: O A copy of the preliminary analysis conducted by the Division O To review a draft of the permit prior to issuance Company Name': EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 17th Street,Suite l000N curtis_rice@eogresourc City: Denver State: CO Zip: 80202 E-mail: es.com Contact Name: Curtis Rice Phone: 303-262-9946 Fax: 303-262-9449 Tank Battery Name": Jersey 12-25H Number of tanks: 4 Location'(QQ Sec.Twp.Range.): NWNW Sec 25,TI IN,R63W County: Weld Total tank capacity[bbl]: 1,600(400 ea) Calendar year for which"Actual"data applies'3: 2011 Year(s)tank(s)were placed in service": 2011 Control Descriptions: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency's: 95% Condensate Throughput"[bbl/year] Requested's: 91,250 Maximum for PTE calculation19: 109,500 Actual": 91,250 While Controls Operational" 91,250 Other equipment at facility: VCU,flare,heater treater,generator engne,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPOI coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use NM for requested throughput/emission values unless requesting an individual permit o Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emissions" Actual Emissions30 Pollutant" [lb/6bl] PTE" Uncontrolled26 Controlled" Uncontrolled's Controlled" VOC[tons/year] 0.1329 7.3 N/A N/A 6.1 0.30 NOx[tons/year] N/A 0.02 0.02 0.02 CO[tons/year] N/A 0.13 0.13 0.13 Benzene[Ibs/year] 78.0 3.9 n-Hexane[lbs/year] 524.0 26.2 Wells serviced by this tank or tank battery' API#: 05-123-30994 Name: Jersey I2-25H ®Newly Reported Well API#: Name: ®Newly Reported Well '.--:&111#: Name: - O Newly Reported Well - .API#: Name: O Newly Reported Well N (.4 Al'I#: Name ❑Newly Reported Well o API#: Name: i•: O Newly Reported Well a, API#: Name: : O Newly Reported Well o The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of "i' my knowledge and belief. If ' is a registration for coverage under general permitGPOI,I further certify that this source is and will be operated roin fall compliance with ondition of eral permit GPOl. to a r JZ- 29— /t N Signature of Le ly Authorized Person(not a vendor or consultant) a Date 0 : Curtis Rice Senior Environmental Specialist r, Type or Print Name of Person Signing Above Official Title N w Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: • 0 filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B I 2 6 6 2 411303)692-3150 o $250 General Permit fee for each new GP 4300 Cherry Creek Drive South :-' registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2EOG Jersey 12-25H FormAPCD-205-E&PCondensateTankAPEN-update.docx N N L 0 4 f r" ' .11 ci pN 2' 0 Is o f �',1 o E u J _a _ • ❑ fi z u o man ri 0 u I w O PWi C a O N N N Si O o m p .' as• a'u k o a W _cat.) m u �` :::.gym O o —c y o o cl O 0 O. 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J O -`� d O ..1 m 00 STATE OF COLORADO 0F:C% COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT r� �� AIR POLLUTION CONTROL DIVISION * p a o} TELEPHONE: (303)692-3150 t!s76*_ CONSTRUCTION PERMIT PERMIT NO: 11WE1579 WE1 579 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas production facility, known as Jersey 12-25H., located in the NWNW of Section 25, Township 11 North, Range 63 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 Four (4) 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. One (1) 400 BBL fixed roof storage tank used to store gas in the ET#4205 002 event that there is a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. Flare 003 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Truck 004 Truck loadout of crude oil. Loadout One (1) above ground 400 bbl atmospheric produced water PW Tank 005 storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. Fugitive 006 Equipment leaks (fugitive VOCs) from a natural gas production facility. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the APCD no later than fifteen days after issuance of this permit or activity by submitting a Notice of Startup (NOS) form to the APCD. The Notice of Startup (NOS) form may be downloaded online at AIRS ID: 123/9044/999 Page 1 of 14 Condensate Tank Version 2009-1 EOG Resources Inc. '' olor DepaF en .f .li "Health and Environment Permit No. 11 WE1579 •it Pollution Control Division Issuance 1 www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. 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). 3. 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 fora 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.) 4. 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.) 5. 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 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 Crude Oil 001 --- 0.3` --- Point Storage Tanks ET#4205 002 --- 10.1 --- Point Flare 003 5.0 79.8 27.2 Point Truck Loadout 004 --- 6.6 --- Point PW Tank 005 --- 0.3 --- Point Fugitive 006 --- 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. AIRS ID: 123/9044/999 Page 2 of 14 EOG Resources, Inc. olor- 5 De , en' f :ell `Health and Environment Permit No. 11WE1579 ` � pa ' it Pollution Control Division Issuance 1 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. Point 001: This emissions point shall be configured with a combustor. The combustor shall reduce the uncontrolled 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. Point 003: 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. 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 005: 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 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. Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liequids 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 11. 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 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 91,250 BBL/yr Storage Tanks ET#4205 002 Natural gas venting to atmosphere 260,000 SCF/yr Flare 003 Natural gas flaring 146 MMSCF/yr Truck Loadout 004 Crude oil and produced water loading 127,750 BBLJyr PW Tank#1 005 Produced water throughput 36,500 BBL/yr Compliance with the yearly natural gas 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 AIRS ID: 123/9044/999 Page 3 of 14 EOG Resources, Inc olor Depa en f Ii Health and Environment Permit No. 11WE1579 ? A it Pollution Control Division Issuance 1 based on the previous twelve months' data. The permit holder shall calculate monthly natural gas throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 12. Point 005: 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) 17. Point 004: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Points 001 and 003: 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. Point 005: 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 AIRS ID: 123/9044/999 Page 4 of 14 EOG Resources, Inc olor. Depa en f '.li 'Health and Environment Permit No. 11WE1579 ; it Pollution Control Division Issuance 1 release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a 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 20. Point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site- specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 21. Points 002 and 003: 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 banana ibmoi. lb 196 sc.( r = benzene wt.frac.* * KYV MMscf 379.3 scf gcs ib?no 1MMscf, AIRS ID: 123/9044/999 Page 5 of 14 EOG Resources, Inc. olor- . Depa en f li Health and Environment Permit No. 11WE1579 A it Pollution Control Division Issuance 1 22. Point 003: The owner or operator shall demonstrate compliance with Condition 14 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 23. Point 006: 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 006: 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, 'LC) 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. 26. This source is subject to the provisions of Regulation number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The application for the Operating Permit is due within one year of becoming major. 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) AIRS ID: 123/9044/999 Page 6 of 14 EOG Resources, Inc. olor Depa en f 'Ii Health and Environment Permit No. 11WE1579 , it Pollution Control Division Issuance 1 • 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 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. AIRS ID: 123/9044/999 Page 7 of 14 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE1579 it Pollution Control Division Issuance 1 By: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for: (5) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank, crude oil loadout and associated fugitives. New synthetic minor source facility. AIRS ID: 123/9044/999 Page 8 of 14 . EOG Resources, Inc. " olor--'I..:. . Depa en .f •li °Health and Environment Permit No. 11WE1579 •i ,° �;, it Pollution Control Division Issuance 1 Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdph e.state.co.us/req u lation s/ai rregs/100102agcccom monprovis ionsreq.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 ID: 123/9044/999 Page 9 of 14 EOG Resources, Inc. olor- li Health and Environment Permit No. 11WE1579 D . A Depa en f it Pollution Control Division Issuance 1 Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (lb/yr) reportable? Rate(Ib/yr) Benzene 71432 A 78 • Yes 4 Toluene 108883 C 70 No 4 001 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 26 No 1 n-Hexane 110543 C 524 No 26 Benzene 71432 A 45 No 45 Toluene 108883 C 34 No 34 002 Ethylbenzene 100414 C 6 No 6 Xylenes 1130207 C 14 No 14 n-Hexane 110543 C 276 No 276 Benzene 71432 A 7118 Yes 356 Toluene 108883 C 5375 Yes 269 003 Ethylbenzene 100414 C 904 Yes 45 Xylenes 1130207 C 2233 Yes 112 n-Hexane 110543 C 43638 Yes 2182 Benzene 71432 A 89 Yes 89 Toluene 108883 C 291 No 291 Ethylbenzene 100414 C 21 No 21 004 y 2 q_ 540841 C 113 No 113 Trimethylpentane Xylenes 1130207 C 387 No 387 n-Hexane 110543 C 531 Yes 531 Benzene 71432 A 256 Yes 13 005 n-Hexane 110543 C 803 No 40 Benzene 71432 A 8 No 8 Toluene 108883 C 12 No 12 006 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: Point 001: AIRS ID: 123/9044/999 Page 10 of 14 EOG Resources, Inc. olor--- Depa en f 'Ii Health and Environment Permit No. 11WE1579 it Pollution Control Division Issuance 1 Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42, Table 13.5-1 CO 0.37 Ib/MMBtu 0.37 lb/MMBtu AP-42, Table 13.5-1 VOC 3.1635 lb/1000 gal 0.1582 lb/1000 gal E&P Tanks 71432 Benzene 0.02 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 108883 Toluene 0.018 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 100414 Ethylbenzene 0.0005 lb/1000 gal 0.00003 lb/1000 gal E&P Tanks 1330207 Xylenes 0.0068 lb/1000 gal 0.0003 lb/1000 gal E&P Tanks 110543 n-hexane 0.1367 lb/1000 gal 0.0068 lb/1000 gal 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: Emission Factors Source CAS# Pollutant Uncontrolled Weight Fraction of Lb/MMscf Gas (/o) Engineering VOC 33666.6667 lb/MMscf 46.18 Calculation 71432 Benzene 75.0 lb/MMscf 0.10 Engineering Calculation 108883 Toluene 56.6667 lb/MMscf 0.08 Engineering Calculation 100414 Ethylbenzene 9.5 lb/MMscf 0.01 Engineering Calculation Engineering 1330207 Xylenes 23.5 lb/MMscf 0.03 Calculation Engineering 110543 n-hexane 459.5 lb/MMscf 0.63 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 16,666.7 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 003: Weight Emission Emission Factors CAS# Pollutant Fraction of Factors Controlled Source Gas (%) Uncontrolled NOx 0.068 AP-42 lb/MMBtu 0.068 lb/MMBtu CO --- 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42 VOC 46.18 33633.2982 1681.6649 Engineering Ib/MMscf Ib/mmscf Calculation PM10 AP-42, Table 40 ug/l 40 ug/l 13.5-1 AIRS ID: 123/9O44/999 Page 11 of 14 EOG Resources, Inc. olor. Depa en f li Health and Environment Permit No. 11 WE1579 A it Pollution Control Division Issuance 1 Weight Emission Emission Factors CAS# Pollutant Fraction of Factors Controlled Source Gas (%) Uncontrolled SOx 0.00036 0.002 gr/scf lb/MMBtu 0.00036 lb/MMBtu 71432 Benzene 0.10 75.0084 3.7504 lb/mmscf Engineering lb/MMscf Calculation 108883 Toluene 0.08 56.6365 2.8318 lb/mmscf Engineering lb/MMscf Calculation 100414 Ethylbenzene 0.01 9'5216 0.4761 lb/mmscf Engineering lb/MMscf Calculation 1330207 Xylenes 0.03 23.5248 1.1761 lb/mmscf Engineering lb/MMscf Calculation 110543 n-hexane 0.63 459.8314 22.9916 lb/mmscf Engineering lb/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 003 are based on the flare control efficiency of 95%. Point 004: Emission Factors -Uncontrolled CAS Pollutant lb/1000 gal loaded Source VOC 2.468 AP-42 71432 Benzene 0.0007 AP-42 108883 Toluene 0.0023 AP-42 100414 Ethylbenzene 0.0002 AP-42 1330207 Xylenes 0.0030 AP-42 110543 n-hexane 0.0042 AP-42 540841 2,2,4-TMP 0.0009 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 005: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 PS Memo 09-02 AIRS ID: 123/9044/999 Page 12 of 14 EOG Resources, Inc. olor. . Depa en •f .li "Health and Environment Permit No. 11WE1579 it Pollution Control Division Issuance 1 ,� w .• W . Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source Ib/BBL Produced lb/BBL Produced Water Throughput Water Throughput 110543 n-Hexane 0.022 0.0011 PS Memo 09-02 71432 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions factors for point 005 are based on the combustor control efficiency of 95%. Point 006: Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 -- Valves 56 --- 72 24 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% --- *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 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 April 17, 2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. AIRS ID: 123/9044/999 Page 13 of 14 EOG Resources, Inc olor- - Depa en f 'Ii `Health and Environment Permit No. 11WE1579 �; it Pollution Control Division Issuance 1 6) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic minor Source: VOC Synthetic minor source; n-hexane and total HAPS PSD Synthetic Minor Source VOC 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: htto://www.cdphe.state.co.us/ap/oilqaspermittino.html AIRS ID: 123/9044/999 Page 14 of 14 Hello