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Home My WebLink About20120599 STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina, MD, MPH �..of cOz � Executive Director and Chief Medical Officer �-AS A) Dedicated to protecting and improving the health and environment of the people of Colorado %tic. *+ 4300 Cherry Creek Dr.S. Laboratory Services Division ,t a'16, 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 February 22, 2012 Mr. Steve Moreno Weld County Clerk 1402 N. 17th Ave. Greeley, CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for EOG Resources, Inc. This public notice will be published in the Greeley Tribune on February 27, 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-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 Attention: Ellen Evans Regards, lc";_"\9 ns L2-- Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division ?wbl, e.vW ) et: PL, rat 3 -5- i s -a 9-/a 2012-0599 NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR NATURAL GAS PRODUCTION FACILITIES 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 -- Christopher E.Urbina,MD, MPH F Cod R Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado °: tl ,,,po 4300 Cherry Creek Dr.S. Laboratory Services Divisionisys' 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 February 22, 2012, to be published on February 27, 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 five oil and natural gas production facilities in Weld County, Colorado. These facilities are: • Randall Creek 1-2811. This source will consist of six (6)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, one (1)-400BBL produced water tank, one (1) reciprocating internal combustion engine and truck loading for the crude oil. This source will be located in the SWSE quarter-quarter of Section 28 of Township 12 North, Range 62 West in Weld County. • Randall Creek 3-3011. This source will consist of six (6)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, one (1)-400BBL produced water tank, one (I) reciprocating internal combustion engine and truck loading for the crude oil. The source will be located in the SESE of Section 30 of Township 12 North, Range 62 West in Weld County. • Fox Creek 3-2611. This source will consist of four (4)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, one (1)-400BBL produced water tank, one (1) reciprocating internal combustion engine and truck loading for the crude oil. This source will be located in the N WNW quarter-quarter of Section 26 of Township 12 North, Range 63 West in Weld County. • Garden Creek 11-18H, This source will consist of four (4)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (1) stack flare, one (1)-400BBL produced water tank and truck loading for the crude oil. This source will be located in the SESE quarter-quarter of Section 18 of Township 11 North, Range 62 West in Weld County. • Fiscus Mesa 9-1011. This source will consist of six (6)-400BBL crude oil storage tanks, one (1) emergency storage tank, one (I) stack flare, one (1)-400BBL produced water tank and truck loading for the crude oil. This source will be located in the NWNW quarter-quarter of Section 10 of Township 9 North, Range 58 West in Weld County. These sources would be considered major sources of air pollutants subject to Prevention of Significant Deterioration (PSD) and Maximum Achievable Control Technology (MACT) requirements if the operator did not install emissions controls and accept Federally enforceable emissions limits in the proposed permit. Since the operator will accept emissions limits less than 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, each source will be considered a synthetic minor source not subject to PSD and MACT review. Each source will have permitted emissions less than 100 tons per year for criteria pollutants and will be considered a new synthetic minor source not subject to Title V Operating Permit requirements. As such, this permit is subject to public comment per Regulation 3, Part B, Sections III.C.I.a and III.C.I.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 80246-1530 Within thirty (30) days following the said thirty (30)-day period for public comment, the Division shall consider comments and, pursuant to Section 25-7-1 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. • Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number 11WE3503 • Source Location: NWNE S26,T12N, R63W,Weld County (Attainment) Point 001: (6)400 BBL above ground atmospheric crude oil storage tanks Point 002: (1)400 BBL above ground atmospheric produced water storage tank. 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: 4SRB internal combustion engine Point 006: Crude oil truck loadout AIRS ID: 123-9465 Date: January 13, 2012 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, when did you mail an Information Request letter to the source? On what date was this application complete? October 27, 2011 Section 4—Source Description AIRS Point Equipment Description Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from • 001 these tanks are controlled by a Cimarron smokeless combustor(vapor combustion unit)with 95% control efficiency. One(1) above ground 400 bbl atmospheric produced water storage tank. 002 Emissions from this tank are controlled by a combustor(VCU)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. One (1)Waukesha, Model F1197GU, Serial Number 102553, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 005 163 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control. This emission unit is used for primary power until electricity can be ran to the location. 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? 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 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 002: Is this source claiming exempt status for this source based on the fraction of oil in the stored X Yes No water(less than 1% by volume crude oil on an average annual basis)? (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 Manufacturer emission factors for NOx,VOC and CO AP-42, Table 3.2-3 for HAPS AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 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) Page 2 • AIRS Point Process Consumption/Throughput/Production 001 175200 BBL per year(146000 x 1.2) 002 87,600 BBL per year(73000 x 1.2) 003 375,000 scf/yr=> 0.375 MMSCF/yr 004 250,000 scf/day a 91,250,000 scf/yr= 91.25 mmscf/yr 005 9.5 MMscf/yr 006 219,000 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 001 146,000 BBL per year 2011 002 73,000 BBL per year 003 375,000 scf/yr=> 0.375 MMSCF/yr 004 250,000 scf/day => 91,250,000 scf/yr= 91.25 mmscf/yr 005 9.5 MMscf/yr 006 219,000 BBL per year crude oil loaded Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 146,000 BBL per year 002 73,000 BBL per year 003 375,000 scf/yr=> 0.375 MMSCF/yr 004 250,000 scf/day => 91,250,000 scf/yr= 91.25 mmscf/yr 005 9.5 MMscf/yr 006 219,000 BBL per year crude oil loaded Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor(VCU) 95 002 of Cimarron smokeless combustor(VCU) 95 004 01 Tornado 40' flare stack 95 005 01 NSCR and AFRC NOx: 93%; CO: 88%; VOC & HAPS: 65% Page 3 Section 6— Emission Summary (tons per year) . Point NO, VOC CO SOx PM10 Single HAP HAP Total 0.5 001 0.03 12.1 0.2 --- --- (n-hexane) 0.7 002 --- 11.5 --- --- --- 1.0 (n-hexane) 1.3 003 --- 6.3 0.09 0.1 PTE: (n-hexane) 210 (n- 004 4.8 1534.1 26.1 0.03 1.2 . 28.5 hexane) 005 21.3 3.2 26.8 --- ___ 0.14 0.2 (formaldehyde) 006 --- 11.4 --- --- --- 0.5 (n-hexane) 1.2 0.4 001 0.03 10.1 0.2 --- --- 0.6 (n-hexane) 002 --- 9.6 --- --- --- 0.8 (n-hexane) 1.1 Uncontrolled point 0.09 source emission rate: 003 --- 6.3 --- --- --- (n-hexane) 0.1 004 4.8 1534.1 26.1 0.03 1.2 21.0 (n- 28.5 hexane) 005 21.3 3.2 26.8 --- --- 0.14 0.2 (formaldehyde) 006 --- 11.4 --- --- --- 0.5 (n-hexane) 1.2 TOTAL(TPY) 26.1 1574.7 52.9 --- --- 22.8 (n 31.7 hexane) 001 0.03 0.5 0.2 --- --- 0.02 0.03 (n-hexane) 002 --- 0.5 --- --- - 0.04 (n- 0.05 hexane) 0.09 Controlled point 003 --- 6.3 --- --- --- 0.1 source emission rate: (n-hexane) 004 4.8 76.7 26.1 0.03 1.2 1.1 (n-hexane) 1.4 0.1 005 1.6 1.1 3.2 --- --- (formaldehyde) 0.1 006 --- 11.4 --- --- -- 0.5 (n-hexane) 1.2 INSIGNIFICANTS 0.5 1.5 0.6 0.14 (n- 0.17 (TPY) hexane) TOTAL PERMITTED 6.4 96.5 29.3 --- --- 1.8 (n-hexane) 2.8 (TPY) Section 7- Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions r Rate(Iblyr)reportable? ( Y ) Point 001 Benzene 71432 A 130 Yes 7 Toluene 108883 C 116 No 6 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 42 No 2 n-Hexane 110543 C 872 No 44 2,2,4-Trimethylpentane 540841 C 72 No 4 Point 002 Page 4 • Benzene 71432 A 511 Yes 26 n-Hexane 110543 C 1606 Yes 80 Point 003 Benzene 71432 A 28 No 28 Toluene 108883 C 21 No 21 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 9 No 9 n-Hexane 110543 C 172 No 172 Point 004 Benzene 71432 A 6845 Yes 342 Toluene 108883 C 5168 Yes 258 Ethylbenzene 100414 C . 869 No 43 Xylenes 1130207 C 2147 Yes 107 n-Hexane 110543 C 41960 Yes 2098 Point 005 Formaldehyde 50000 A 275 Yes 138 Acetaldehyde 75070 A 37 No 19 Acrolein 107028 A 35 No 17 Benzene 71432 A 21 No 11 Point 006 Benzene 71432 A 153 Yes 153 Toluene 108883 C 501 No 501 Ethylbenzene 100414 C 37 No 37 2,2,4-Trimethylpentane 540841 C 194 No 194 Xylenes 1130207 C 666 No 666 n-Hexane 110543 C 912 No 912 Note: Regulation 3, Part A, Section ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001 01 VOC CDPHE PS Memo 05-01 Site-specific sampling 003 01 VOC, State only requirement Site-specific gas HAPS analysis 004 01 NOx CO, Regulation No. 3, Part B., Section III.G.3 Stack test 004 01 Opacity Regulation No. 1, Section II.A.5 Method 9 Page 5 005 01 VOC CO Regulation No. 3, Part B., Section III.G.3 Stack Test 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 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 • 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. 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. • Page 6 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 11.D.3.a) Regulation 6 - New Source Performance Standards 001-003, None 004, 006 NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ when 005 their manufacturer date is on or after July 1, 2008. The operator provided a manufacturer date of 1/1/1961, which is prior to the threshold date. Therefore, this engine is not subject to NSPS JJJJ. 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 001-003, subject to Section XII of this regulation. 004, 006 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. 005 This engine is subject to Regulation 7, Section XVII.E because it was relocated into the State of Colorado on 7/29/11, which is after January 1, 2008. Regulation 8— Hazardous Air Pollutants 001-003, None 004, 006 MACT 7777: Engines subject to area source MACT 7777 are engines with a 005 commencement of construction date on or after June 12, 2006. The operator provided a construction commencement date of 1/31/1961, which is prior to the threshold date, therefore, not subject to area source MACT ZZZZ requirements. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control Factor CAS# (Y/N) Source (%) 3.2873 VOC No E&P Tanks 95 lb/1000 gal 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 0.0212 Benzene No E&P Tanks 95 lb/1000 gal 001 01 Crude oil Storage Tanks 0.0189 Toluene No E&P Tanks 95 lb/1000 gal 0.0003 Ethylbenzene No E&P Tanks 95 lb/1000 gal y 0.0068 Xylenes No E&P Tanks 95 lb/1000 gal y 0.1422 n-hexane No E&P Tanks 95 lb/1000 gal 0.0117 2,2,4-TMP 4-TMP No E&P Tanks 95 lb/1000 gal Page 7 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 Produced water 0.1667 CDPHE PS 01 storage lb/1000 gal Benzene No 95 tanks 002 g throughput Memo 09-02 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 33600 VOC No Engineering 0 lb/MMscf Calculation 74.9333 Engineering Ib/MMscf Benzene No Calculation 0 56.5333 Engineering 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 003 9.60 Ethlybenzene No Engineering 0 lb/MMscf Calculation 23.4667 Engineering lb/MMscf Xylenes No Calculation 0 459.4667 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 33635.0685 VOC No Engineering 95 lb/MMscf Calculation 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42' NA lb/MMBtu Table 13.5-1 75.0082 Benzene No Engineering 95 01 Flare lb/MMscf Calculation 004 56.6367 Toluene No Engineering 95 lb/MMscf Calculation 9.5222 Ethlybenzene No Engineering 95 lb/MMscf Calculation 23.5244 Engineering lb/MMscf Xylenes No Calculation 95 459.8312 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 2.0 g/hp-hr VOC No Manufacturer 65 13.5 g/hp-hr NOx No Manufacturer 93 17.0 g/hp-hr CO No Manufacturer 88 0.0205 Formaldehyde No AP-42 65 01 Reciprocating internal lb/mmbtu 005 combustion engine 0.00279 b/mmbtu Acetaldehyde No AP-42 65 l0.00263 Acrolein No AP-42 65 lb/mmbtu 0.00158 Benzene No AP-42 65 lb/mmbtu SCC 20200253: 4-cycle rich burn 0.104 lb/BBL VOC No AP-42 0 0.0007 Benzene No AP-42 0 lb/BBL 006 01 Truck Crude oil Loadout 0.0023 Toluene No AP-42 0 lb/BBL 0.0002 Ethylhenzene No AP-42 0 lb/BBL Page 8 0.0030 Xylenes No AP-42 0 lb/BBL 0.0042 n-hexane 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 = (10.079 TPY *2000)/ 146000 bbl/yr= 0.1381 lb/bbl *1000/42 = 3.2873 lb/1000 gal Benzene = (0.065 TPY*2000)/ 146000 bbl/yr= 0.0009 lb/bbl * 1000/42 = 0.0212 lb/1000 gal Toluene = (0.058 TPY *2000)/ 146000 bbl/yr= 0.0008 lb/bbl * 0.0189 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 = (0.436 TPY *2000) / 146000 bbl/yr= 0.0060 lb/bbl * 1000/42 = 0.1422 lb/1000 gal 2,2,4-TMP = 0.036 TPY*2000)/ 146000 bbl/yr= 0.0005 lb/bbl * 1000/42 = 0.0117 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 accepts Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. 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. (scf/hr) * (Ib/Ib-mol) * (% fraction from sales gas analysis)/(379.4 scf/lb-mol) = lb/hr* 12 hrs/eyent* 3 events/yr/2000 lb/T) = TPY VOC = (6.3 TPY *2000 lb/T) / (0.375 mmscf/yr) = 33600 lb/mmscf Benzene = (28.1 Ib/yr)/(0.375 mmscf/yr) = 74.9333 lb/mmscf Toluene = (21.2 Ib/yr) / (0.375 mmscf/yr) = 56.5333 lb/mmscf Ethylbenzene = (3.6 Ib/yr)/(0.375 mmscf/yr) = 9.60 lb/mmscf Xylenes = (8.8 Ib/yr)/(0.375 mmscf/yr) = 23.4667 lb/mmscf n-hexane = (172.3 Ib/yr) / (0.375 mmscf/yr) = 459.4667 lb/mmscf AIRS Point 004 l Flare Emissions were calculated using VOC wt fraction. (scf/hr) * (lb/lb-mol) * (% fraction from sales gas analysis) / (379.4 scf/lb-mol) = lb/hr* (hr/yr) /2000 lb/T) = TPY VOC = (1534.6 TPY *2000 lb/T) / (91.25 Ib/mmscf) = 33635.0685 lb/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 (SO2 = 0.00037 Ib/MMBtu) PM10 and PM2.5 based on AP-42 Table 13.5-2 (PM10 and PM2.5=40 ug/I) Benzene = (6844.5 lb/yr)/91.25 mmscf/yr= 75.0082 lb/mmscf Toluene = (5168.1 lb/yr) / 91.25 mmscf/yr= 56.6367 lb/mmscf Ethylbenzene = (868.9 Ib/yr)/91.25 mmscf/yr= 9.5222 lb/mmscf Xylenes= (2146.6 Ib/yr)/91.25 mmscf/yr= 23.5244 lb/mmscf n-hexane = (41959.6 Ib/yr) / 91.25 mmscf/yr=459.8312 lb/mmscf Page 9 AIRS Point 005 RICE This is a permitted source since uncontrolled NOx and CO emissions (each) are greater than 10 TPY. The engine is controlled by a NSCR and AFRC. 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 5.18 psia M 33.43 lb/lb-mole T 524 deg. R L 2.471b/10^3 gal 1.04E-01 lb/bbl Annual requested Throughput 9198000ga1/yr Annual requested VOC emissions 227991b/yr 11.40tpy Benzene = (152.85 Ib/yr) /(219000) = 0.0007 lb/bbl Toluene = (500.53 Ib/yr)/ (219000) = 0.0023 lb/bbl Ethylbenzene = (36.87 Ib/yr)/(219000) = 0.0002 lb/bbl Xylenes = (665.88 Ib/yr)/(219000) = 0.0030 lb/bbl n-hexane = (912.41 Ib/yr)/(219000) = 0.0042 lb/bbl 2,2,4-TMP = (193.51 Ib/yr) / (219000) = 0.0009 lb/bbl Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and is a synthetic minor source for VOC, PSD, n-hexane and total HAPS. Page 10 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY yyee X727 d GL Current Status(Check all that apply) Reason for MEN Submittal(Check all that apply) IZ3 9465/OOt ❑ A-PEN update only° AIRS ID# : O ® New or previously unreported batteryModification to existing sources ❑ Previously grandfathered batter? O Registration for coverage under general permit no.GPOI _ ❑ Synthetic minor facility &cancellation request for individual permit': ❑ Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPOI ]iwtS583 O Administrative permit amendment' ❑ Permitted under individual permit: O 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 17i6 Street,Suite 1000N curtis_rice@eogresourc City: Denver State: CO Zip: 80202 E-mail: es.com Contact Name: Curtis Rice Phone: 303-262-9946 Fax: 303-262-9449 Tank Battery Name": Fox Creek 3-26H Number of tanks: 6 Location'(QQ Sec.Twp.Range.): NWNW Sec 26,T12N,R63W County: Weld Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies': 2011 Year(s)tank(s)were placed in service's: 2011 Control Description1s: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency': 95% Condensate Throughputs'[bbl/year] Requested's: 146,000 Maximum for PTE calculations': 175,200 Actual20: 146,000 While Controls Operational'' 146,000 Other equipment at facility22: VCU,flare,heater treater,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPOI coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use N/A for requested 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's Actual Emission? Pollutant' [lb/bbl] PTE Uncontrolled'-' Controlled2° Uncontrolled26 Controlled'-' VOC[tons/year] 0.1381 12.1 N/A N/A 10.1 0.50 N/A 0.03 0.03 0.03 NOx [tons/year] 0 18 CO[tons/year] N/A 0.18 0.18 • 130.0 6.5 Benzene[lbs/year] 872.0 6.5 n-Hexane[lbs/year] 43.6 Wells serviced by this tank or tank battery 2s API#: 05-123-31417-00 Name: Fox Creek 3-261-I ®Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well m API#: Name: O Newly Reported Well ' Name O Newly Reported Well v_ 1O API#: ❑Newly Reported Wear. m API#: Name: . N Name: 0 Newly Reported Well!' 0 API#: o fhe 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 ny knowledge and belief. If this• registration for coverage under general permit GPOI,1 further certify that this source is and will be"crated ro n full compliance with each ition of gener it GPOI. - =. : z /O —/9 -// d ID ro Date J49 o >ignature of Legally Authorized Person(not a vendor or consultant) 7 Z : n : wills Rice Senior Edvonme p ntal Secialist o Type or Print Name of Person Signing Above Official Title ��For information call: iubmit this form,along with$152.90 for each Colorado Department of Public Health and Envir n information call: I Sling of up to 5 tank battery APENS. 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CC F^ = ?C a o ❑ to O C] 01 ❑ ❑ o ® W y ❑ cn co) C En yw i „ k STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT F� AIR POLLUTION CONTROL DIVISION , No) N . TELEPHONE: (303)692-3150 "` .:,,.,. +% leis`-� CONSTRUCTION PERMIT PERMIT NO: 1 1 WE3503 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 Fox Creek 3-26H, located in the NWNW of Section 26, Township 12 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 Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Storage 001 Emissions from these tanks are controlled by a Cimarron Tanks smokeless VCU unit with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water PW Tank 002 storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. One (1) 400 BBL fixed roof storage tank used to store gas in the ET#4659 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. One (1) Waukesha, Model F1197GU, Serial Number 102553, natural gas-fired, naturally aspirated, 4SRB reciprocating internal Generator combustion engine, site rated at 163 horsepower at 1800 RPM. RICE 005 This engine shall be equipped with a non-selective catalytic Engine reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power until electricity can be ran to the location. Truck 006 Truck loadout of crude oil. Loadout Point 005 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha Model F1197GU engine in accordance with the permanent replacement provision of the Alternate Operating Scenario(ADS), included in this permit as Attachment A. AIRS ID: 123/9465/999 Page 1 of 19 Condensate Tank Version 2009-1 1 EOG Resources Inc G olor s ;.Depa en 1 P 1.Ii Health and Environment Permit No. 11WE3503 LA it Pollution Control Division Issuance 1 : r 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 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. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 3.3 per year of volatile organic compounds (VOC), -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: AIRS ID: 123/9465/999 Page 2 of 19 EOG Resources, Inc. olor ' Depa en f I•li 'Health and Environment Permit No. 11WE3503 4` sir Pollution Control Division Issuance 1 • 100 tons per year of volatile orga nic compounds (VOC). 7. 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 PW Tank 002 --- 0.5 — Point ET#4659 003 --- 6.3 --- Point Flare 004 4.8 76.7 26.1 Point Generator 005 1.6 1.1 3.2 Point RICE Engine Truck Loadout 006 -- 11.4 --- 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. 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. 8. 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.) 9. 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.) 10. 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.) 11. Point 005: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. The NSCR shall reduce uncontrolled emissions of NOx, VOC and CO from the unit to the emission levels listed in this section, above. Operating AIRS ID: 123/9465/999 Page 3 of 19 s EOG Resources Inc olors i Depa en` 3f 'all ?Health and Environment Permit No. 11WE3503 ; w ,r A • it Pollution Control Division Issuance 1 parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) PROCESS LIMITATIONS AND RECORDS 12. 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 PW Tank 002 Produced water throughput 73,000 BBL/yr ET#4659 003 Natural gas venting to atmosphere 375,000 SCF/yr Flare 004 Natural gas flaring 91.25 MMSCF/yr Generator 005 Consumption of natural gas as a fuel 9.5 MMscf/yr RICE Engine Truck Loadout 006 Crude oil and produced water loading 219,000 BBL/yr Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly crude oil throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 13. 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 14. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 15. Visible emissions shall not exceed twenty percent(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.) 16. 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.). 17. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/9465/999 Page 4 of 19 EOG Resources, Inc. w olor Depa • en -f 7:•li `Health and Environment Permit No. 11WE3503 ' it Pollution Control Division Issuance 1 18. Point 005: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Note that this condition may not apply if the engine is subject to standards under NSPS or MACTs.(see Reg 7 XVII.B.4). Note that there must be an actual emission standard under NSPS/MACT in order for Reg 7 to not apply. Note also that in most cases, the NSPS/MACT standards will be the same as what would be required for Reg. 7: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 19. Point 006: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 20. 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.) 21. 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: (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. AIRS ID: 123/9465/999 Page 5 of 19 EOG Resources, Inc ll olor + Depa en if 'Ii Health and Environment Permit No. 11WE3503 • it Pollution Control Division Issuance 1 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 22. 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. 23. Points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self- certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: AIRS ID: 123/9465/999 Page 6 of 19 EOG Resources, Inc olor I ., Depa en f a.li `Health and Environment Permit No. 11WE3503 it Pollution Control Division Issuance 1 ib . b m nae.,,. bmo!. .b 1a6 scf x = benzeneWt.frac.* * MW '4 dscf 375.3 scf 8�` L:b mod 1MMscf, 24. Point 004: The owner or operator shall demonstrate compliance with Condition 16 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 25. Point 005: A source initial compliance test shall be conducted on emissions point 004 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide Volatile Organic Compounds Periodic Testing Requirements 26. Point 005: This engine is subject to the periodic testing requirements as specified in the operating and maintenance(O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN)shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. AIRS ID: 123/9465/999 Page 7 of 19 (' EOG Resources, Inc , j olor. ?',. Depa en of i•li Health and Environment Permit No. 11 WE3503 ,'it Pollution Control Division Issuance 1 '' , f. Point 005: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 28. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equal or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 29. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 30. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 31. If this permit specifically states that final authorization has been granted,then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide"final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self-Certify for Final Authorization section of this permit. 32. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 33. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab initio. This permit may be AIRS ID: 123/9465/999 Page 8 of 19 • EOG Resources, Inc olor Depa en' f .li Health and Environment Permit No. 11WE3503 'N ' `: it Pollution Control Division Issuance 1 a. revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for: (6) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank, 4SRB engine and crude oil loadout. New synthetic minor facility. AIRS ID: 123/9465/999 Page 9 of 19 EOG Resources, Inc. olor Depa en f li Health and Environment . Permit No. 11WE3503 Air 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/req u lations/airregs/100102aecccom monprovision sreq.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 130 Yes 7 Toluene 108883 C 116 No 6 Ethylbenzene 100414 C 2 No 0 001 Xylenes 1130207 C 42 No 2 n-Hexane 110543 C 872 No 44 2,2,4- 540841 C 72 No 4 Trimethylpentane Benzene 71432 A 511 Yes 26 002 n-Hexane 110543 C 1606 Yes 80 Benzene 71432 A 28 No 28 Toluene 108883 C 21 No 21 003 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 9 No 9 n-Hexane 110543 C 172 No 172 Benzene 71432 A 6845 Yes 342 Toluene 108883 C 5168 Yes 258 004 Ethylbenzene 100414 C 869 No 43 Xylenes 1130207 C 2147 Yes 107 n-Hexane 110543 C 41960 Yes 2098 Formaldehyde 50000 A 275 Yes 96 005 Methanol 67561 C 41 No 14 AIRS ID: 123/9465/999 Page 10 of 19 EOG Resources, Inc n �. olor Depa en f 'v.li `Health and Environment Permit No. 11WE3503 ` «�I' it Pollution Control Division Issuance 1 ; Acetaldehyde 75070 A 37 No 13 Acrolein 107028 A 35 No 12 Benzene 71432 A 21 No 7 1,3-Butadiene 106990 A 9 No 3 Toluene 108883 C 7 No 3 Benzene 71432 A 153 Yes 153 Toluene 108883 C 501 No 501 Ethylbenzene 100414 C 37 No 37 006 2,2,4- 540841 C 194 No 194 Trimethylpentane Xylenes 1130207 C 666 No 666 n-Hexane 110543 C 912 No 912 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 3.2873 lb/1000 gal 0.1644 lb/1000 gal E&P Tanks 71432 Benzene 0.0212 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 108883 Toluene 0.0189 lb/1000 gal 0.001 lb/1000 qal 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 qal E&P Tanks 110543 n-hexane 0.1422 lb/1000 gal 0.0071 lb/1000 gal E&P Tanks 540841 2,2,4-TMP 0.0117 lb/1000 gal 0.0006 lb/1000 qal 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 002 are based on the combustor control efficiency of 95% AIRS ID: 123/9465/999 Page 11 of 19 EOG Resources Inc olori Depa en" f •liHealth and Environment Permit No. 11WE3503 ' :xk - it Pollution Control Division Issuance 1 Point 003: Emission Factors Weight Fraction of Source CAS# Pollutant Uncontrolled Gas (%) Lb/MMscf Engineering VOC 33600 Ib/MMscf 46.18 Calculation 71432 Benzene 74.9333 lb/MMscf 0.10 Engineering Calculation 108883 Toluene 56.5333 lb/MMscf 0.08 Engineering Calculation 100414 Ethylbenzene 9.60 lb/MMscf 0.01 Engineering Calculation 1330207 Xylenes 23.4667 lb/MMscf 0.03 Engineering Calculation 110543 n-hexane 459.4667 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 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 (0/0) NOx --- 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42 CO --- 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42 VOC 46.18 33635.0685 1681.7534 Engineering lb/MMscf lb/mmscf Calculation PM10 AP-42, Table 40 ug/l 40 ug/I 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf lb/MMBtu lb/MMBtu 71432 Benzene 0.10 75.0082 3.7504 Engineering lb/MMscf lb/mmscf Calculation 108883 Toluene 0.08 56.6367 2.8318 Engineering lb/MMscf lb/mmscf Calculation 100414 Ethylbenzene 0.01 9.5222 lb/MMscf 0.4761 Engineering lb/mmscf Calculation 1330207 Xylenes 0.03 23.5244 1.1762 Engineering lb/MMscf lb/mmscf Calculation 110543 n-hexane 0.63 459.8312 22.9916 Engineering Ib/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 004 are based on the flare control efficiency of 95%. AIRS ID: 123/9465/999 Page 12 of 19 EOG Resources, Inc. , olor Depat en f lic Health and Environment Permit No. 11 WE3503, it Pollution Control Division Issuance 1 {' Point 005: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.1662 13.5 0.2345 1 CO 3.9871 17 0.4691 2 VOC 0.4691 2 0.1642 0.7 50000 Formaldehyde 0.0205 0.0874 0.0072 0.0306 67561 Methanol 0.0031 0.0130 0.0011 0.0046 75070 Acetaldehyde 0.0028 0.0119 0.0010 0.0042 107028 Acrolein 0.0026 0.0112 0.0009 0.0039 71432 Benzene 0.0016 0.0067 0.0006 0.0024 106990 1,3-Butadiene 0.0007 0.0028 0.0002 0.0010 108883 Toluene 0.0006 0.0024 0.0002 0.0008 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site- rated horsepower value of 163, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP-42 AP-42 Point 006: 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 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 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. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on October 26,2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: AIRS ID: 123/9465/999 Page 13 of 19 %la EOG Resources Inc olor a Depa nen �f •li Health and Environment Permit No. 11WE3503 "l tz it Pollution Control Division Issuance 1 Applicable Status Requirement • Operating Permit Synthetic Minor Source VOC, n-hexane, total HAPS 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 Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 8) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oiloaspermittinq html AIRS ID: 123/9465/999 Page 14 of 19 EOG Resources, Inc. ,,, olor Depa en if •li ''Health and Environment Permit No. 11WE3503 s it Pollution Control Division Issuance 1 ' " R � ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES December 10, 2008 The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. A.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90- day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from.the permanent replacement engine comply with 1) the permitted annual emission limitations for the AIRS ID: 123/9465/999 Page 15 of 19 EOG Resources, Inc. olora Depa en f li Health and Environment Permit No. 11 WE3503 Jr Pollution Control Division Issuance 1 existing engine, 2) any permitted short-term emission limitations for the existing permitted engine; and 3) the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissions Notice (APEN) for the replacement engine (see http://www.cdphe.state.co.us/ap/oiloaspermittinq.html for example applicability report formats). Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section A.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermittinq.html. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". . This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. A.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. AIRS ID: 123/9465/999 Page 16 of 19 EOG Resources Inc. . ' olor , Depa ''Health and Environment Permit No. 11WE3503 -< it Pollution Control Division Issuance 1 cr For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. A.3 Applicable Regulations for Permanent Engine Replacements A.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural-gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. A.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State-Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non-selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9465/999 Page 17 of 19 EOG Resources, Inc ;1 , olor , Depa en 1 ;~~.h ``Health and Environment Permit No. 11WE3503 • it Pollution Control Division Issuance 1 ler . :+ Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500≤Flp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject 40 CFR 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of November 1, 2008 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. A.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9465/999 Page 18 of 19 EOG Resources, Inc olor Depa f en .li Health and Environment Permit No. 11WE3503 " it Pollution Control Division Issuance 1 ` r - 111r J. . A.3.4.1 Area Source for HAPs A permanent replacemeht engine located at an area source that commenced construction or reconstruction after June 12, 2006 as defined in § 63.2, will meet the requirements of 40 CFR Part 63, Subpart ZZZZ by meeting the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.4.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 12/19/02) 2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. .The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9465/999 Page 19 of 19 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3526 Source Location: SESE S30, T12N, R62W,Weld County (Attainment) Point 001: (6)400 BBL above ground atmospheric crude oil storage tanks Point 002: (1) 400 BBL above ground atmospheric produced water storage tank. 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: 4SRB internal combustion engine Point 006: Crude oil truck loadout AIRS ID: 123-9468 Date: January 12, 2012 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, when did you mail an Information Request letter to the source? On what date was this application complete? October 13, 2011 Section 4—Source Description AIRS Point Equipment Description Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from 001 these tanks are controlled by a Cimarron smokeless combustor(vapor combustion unit)with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water storage tank. 002 Emissions from this tank are controlled by a combustor(VCU)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. One (1)Waukesha, Model F1197GU, Serial Number 389650, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 005 163 horsepower at 1800 RPM.This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control.This emission unit is used for primary power until electricity can be ran to the location. 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 X Yes No water(less than 1% by volume crude oil on an average 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 Manufacturer emission factors for NOx,VOC and CO AP-42, Table 3.2-3 for HAPS AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T 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) Page 2 AIRS Point Process Consumption/Throughput/Production 001 175200 BBL per year(146000 x 1.2) 002 43,800 BBL per year(36500 x 1.2) 003 427,500 scf/yr=> 0.4275 MMSCF/yr 004 255,000 scf/day a 93,075,000 scf/yr= 93.075 mmscf/yr 005 9.5 MMscf/yr 006 182,500 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 001 146,000 BBL per year 2011 002 36,500 BBL per year 003 427,500 scf/yr a 0.4275 MMSCF/yr 004 255,000 scf/day => 93,075,000 scf/yr= 93.075 mmscf/yr 005 9.5 MMscf/yr 006 182,500 BBL per year crude oil loaded Basis for Permitted Emissions (Permit Limits} AIRS Point Process Consumption/Throughput/Production 001 146,000 BBL per year 002 36,500 BBL per year 003 427,500 scf/yr=> 0.4275 MMSCF/yr 004 255,000 scf/day => 93,075,000 scf/yr= 93.075 mmscf/yr 005 9.5 MMscf/yr 006 182,500 BBL per year crude oil loaded Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor(VCU) 95 002 01 Cimarron smokeless combustor(VCU) 95 004 01 Tornado 40' flare stack 95 NOx: 93%; CO: 88%; 005 01 NSCR and AFRC VOC & HAPS: 65% Page 3 Section 6 - Emission Summa (tons per year) Point NO,, VOC CO SOx PM10 Single HAP Total HAP 0.5 001 0.03 11.8 0.2 --- --- 0.7 (n-hexane) 002 --- 5.7 --- --- --- 0.5 (n-hexane) 0.6 003 --- 7.2 0.10 0.1 PTE: (n-hexane) 004 4.9 1565.2 26.7 0.03 1.2 21.4 (n- 29.1 hexane) 005 21.3 3.2 26.8 --- --- 0.14 0.2 (formaldehyde) 006 --- 9.5 --- --- --- 0.4 (n-hexane) 1.0 001 0.03 9.9 0.2 --- --- 7 (n-hexane) 0. 002 --- 4.8 --- --- --- 0.4 (n-hexane) 0.5 Uncontrolled point 0.10 source emission rate: 003 -- 7.2 --- --- --- 0.1 (n-hexane) 004 4.9 1565.2 26.7 0.03 1.2 21.4 (n- 29.1 hexane) 005 21.3 3.2 26.8 --- --- 0.14 0.2 (formaldehyde) 006 --- 9.5 --- --- --- 0.4 (n-hexane) 1.0 TOTAL (TPY) 26.2 1599.8 53.5 --- --- 22'8 (n 31.6 hexane) 001 0.03 0.5 0.2 --- --- 0.03 0.03 (n-hexane) 002 --- 0.24 --- --- 0.02 (n- 0.03 hexane) Controlled point 003 --- 7.2 --- --- __- 0.10 0.1 source emission rate: (n-hexane) 004 4.9 78.3 26.7 0.03 1.2 1.1 (n-hexane) 1.4 0.1 005 1.6 1.1 3.2 -- 0.1 (formaldehyde) 006 --- 9.5 --- --- --- 0.4 (n-hexane) 1.0 INSIGNIFICANTS 0.14 (n- (TPY) 0.5 1.5 0.6 --- --- hexane) 0.17 TOTAL PERMITTED 6.5 96.8 29.9 --- --- 1.7 (n-hexane) 2.7 (TPY) Section 7 —Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are we Controlled Emission Pollutant CAS # BIN Emission Rate emissions r Rate Ib/ (Iblyr) reportable? ( y ) Point 001 Benzene 71432 A 128 Yes 6 Toluene 108883 C 114 No 6 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 42 No 2 n-Hexane 110543 C 854 No 43 2,2,4-Trimethylpentane 540841 C 70 No 4 Point 002 Page 4 Benzene 71432 A 256 Yes 13 n-Hexane 110543 C 803 No 40 Point 003 Benzene 71432 A 32 No 32 Toluene 108883 C 24 No 24 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 10 No 10 n-Hexane 110543 C 196 No 196 Point 004 Benzene 71432 A 6981 Yes 349 Toluene 108883 C 5272 Yes 264 Ethylbenzene 100414 C 886 No 44 Xylenes 1130207 C 2190 Yes 110 n-Hexane 110543 C 42799 Yes 2140 Point 005 Formaldehyde 50000 A 275 Yes 138 Acetaldehyde 75070 A 37 No 19 Acrolein 107028 A 35 No 17 Benzene 71432 A 21 No 11 Point 006 Benzene 71432 A 127 Yes 127 Toluene 108883 C 416 No 416 Ethylbenzene 100414 C 31 No 31 2,2,4-Trimethylpentane 540841 C 161 No 161 Xylenes 1130207 C 553 No 553 n-Hexane 110543 C 758 No 758 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 Site-specific 001 01 VOC CDPHE PS Memo 05-01 sampling 003 01 VOC, State only requirement Site-specific gas HAPS analysis 004 01 NOx CO Regulation No. 3, Part B., Section III.G.3 Stack test 004 01 Opacity Regulation No. 1, Section II.A.5 Method 9 Page 5 005 01 VOC CO Regulation No. 3, Part B., Section III.G.3 Stack Test 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 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 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. Page 6 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 001-003, None 004, 006 NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ when 005 their manufacturer date is on or after July 1, 2008. The operator provided a manufacturer date of 10/27/1985, which is prior to the threshold date. Therefore, this engine is not subject to NSPS JJJJ. 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 001-003, subject to Section XII of this regulation. 004, 006 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. 005 This engine is subject to Regulation 7, Section XVII.E because it was relocated into the State of Colorado on 10/7/10,which is after January 1, 2008. Regulation 8— Hazardous Air Pollutants 001-003, None 004, 006 MACT 7777: Engines subject to area source MACT 7777 are engines with a 005 commencement of construction date on or after June 12, 2006. The operator provided a construction commencement date of 10/27/1985, which is prior to the threshold date, therefore, not subject to area source MACT ZZZZ requirements. Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 3.2169 VOC No E&P Tanks 95 lb/1000 gal 0.068 AP-42, Ib/MMBtu NOx No Table 13.5-1 NA 0.37 CO No AP-42, NA Ib/MMBtu Table 13.5-1 0.0209 Benzene No E&P Tanks 95 lb/1000 gal 001 01 Crude oil Storage Tanks 0.0186 Toluene No E&P Tanks 95 lb/1000 gal 0.0003 Ethylbenzene No E&P Tanks 95 lb/1000 gal 0.0068 Xylenes No E&P Tanks 95 lb/1000 gal 0.1393 n-hexane No E&P Tanks 95 lb/1000 gal 0.0114 2,2,4-TMP 4-TMP No E&P Tanks 95 lb/1000 gal Page 7 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 Produced water storage 0.1667 CDPHE PS 01 tanks lb/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 33684.2105 VOC No Engineering 0 lb/MMscf Calculation 74.8538 Engineering lb/MMscf Benzene No Calculation 0 56.6082 Engineering 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 003 9.5906 Ethlybenzene No Engineering 0 lb/MMscf Calculation 23.6257 X lenes No Engineering y 0 lb/MMscf Calculation 459.4152 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 33633.0916 Engineering VOC No 95 lb/MMscf Calculation 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 75.0083 Benzene No - Engineering 95 01 Flare lb/MMscf Calculation 004 56.6371 Toluene No Engineering 95 lb/MMscf Calculation • 9.5224 Ethlybenzene Na Engineering 95 lb/MMscf Calculation 23.5251 Engineering lb/MMscf Xylenes No Calculation 95 459.8313 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 2.0 g/hp-hr VOC No Manufacturer 65 13.5 g/hp-hr NOx No Manufacturer 93 17.0 g/hp-hr CO No Manufacturer 88 0.0205 Formaldehyde No AP-42 65 01 Reciprocating internal lb/mmbtu 005 combustion engine 0.00279 b/mmbtu Acetaldehyde No AP-42 65 l0.00263 Acrolein No AP-42 65 lb/mmbtu 0.00158 Benzene No AP-42 65 lb/mmbtu SCC 20200253: 4-cycle rich burn • 0.104 lb/BBL VOC No AP-42 0 0.0007 Benzene No AP-42 0 lb/BBL 006 01 Truck Crude oil Loadout 0.0023 b/BBL Toluene No AP-42 0 l0.0002 Ethylbenzene No AP-42 0 lb/BBL Page 8 0.0030 lb/BBL Xylenes No AP-42 0 0.0042 n-hexane 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 = (9.863 TPY *2000) / 146000 bbl/yr= 0.1351 lb/bbl *1000/42 = 3.2169 lb/1000 gal Benzene = (0.064 TPY *2000) / 146000 bbl/yr= 0.0009 lb/bbl * 1000/42 = 0.0209 lb/1000 gal Toluene = (0.057 TPY* 2000)/ 146000 bbl/yr= 0.0008 lb/bbl * 0.0186 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 = (0.427 TPY *2000)/ 146000 bbl/yr= 0.0058 lb/bbl * 1000/42 = 0.1393 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 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 accepts Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. 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. (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 = (7.2 TPY *2000 lb/T)/(0.4275 mmscf/yr) = 33684.2105 lb/mmscf Benzene = (32.0 Ib/yr)/(0.4275 mmscf/yr) = 74.8538 lb/mmscf Toluene = (24.2 Ib/yr)/(0.4275 mmscf/yr) = 56.6082 lb/mmscf Ethylbenzene = (4.1 Ib/yr)/ (0.4275 mmscf/yr) = 9.5906 lb/mmscf Xylenes = (10.1 lb/yr)/(0.4275 mmscf/yr) = 23.6257 lb/mmscf n-hexane = (196.4 lb/ r) / (0.4275 mmscf/yr) = 459.4152 lb/mmscf AIRS Point 004 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 = (1565.2 TPY * 2000 Ib/T)/(93.075 lb/mmscf) = 33633.0916 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/l) Benzene = (6981.4 Ib/yr) / 93.075 mmscf/yr= 75.0083 lb/mmscf Toluene = (5271.5 Ib/yr) /93.075 mmscf/yr= 56.6371 lb/mmscf Ethylbenzene = (886.3 Ib/yr) / 93.075 mmscf/yr= 9.5224 lb/mmscf Xylenes= (2189.6 Ib/yr)/93.075 mmscf/yr= 23.5251 lb/mmscf n-hexane = (42798.8 Ib/yr) /93.075 mmscf/yr=459.8313 lb/mmscf Page 9 AIRS Point 005 RICE This is a permitted source since uncontrolled NOx and CO emissions (each) are greater than 10 TPY. The engine is controlled by a NSCR and AFRC. 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 5.18 psia M 33.43 lb/lb-mole T 524 deg. R L 2.471b/10^3 gal 1.04E-01 lb/bbl Annual requested Throughput 7665000ga1/yr • Annual requested VOC emissions 189371b/yr 9.47tpy Benzene = (126.96 lb/yr)/(182500) = 0.0007 lb/bbl Toluene = (415.74 Ib/yr) / (182500) = 0.0023 lb/bbl Ethylbenzene = (30.63 lb/yr)/ (182500) = 0.0002 lb/bbl Xylenes = (553.08 Ib/yr) /(182500) = 0.0030 lb/bbl n-hexane = (757.84 Ib/yr)/ (182500) = 0.0042 lb/bbl 2,2,4-TMP = (160.73 Ib/yr) /(182500) = 0.0009 lb/bbl Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and is a synthetic minor source for VOC, PSD, n-hexane and total HAPS. Page 10 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit • . - OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERX,"---- ""'.- Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) , ,E C:El'' '�' AIRS ID#1: C3 gl&s(ee; 0 APEN update only° 0 ® . New or previously unreported battery Modification to existing source' ?i!V—2 201 ❑ Previously grandfathered battery'' ❑ Registration for coverage under general permit.no.GPOI ❑ Synthetic minor facility &cancellation request for individual permits: O Located in the 8-hr Ozone Control Area' 0 Application for or Modification of an individual permit ❑ Registered under general permit no.GPOI Ill , ,,i 1L 0 Administrative permit amendment' ID Permitted under individual permit: 0 Other: For individual permit applications,check if you wants: 0 A copy of the preliminary analysis conducted by the Division ❑To review a draft of the permit prior to issuance Company Name': EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 17's Street,Suite IOOON . 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': Randall Creek 3-30H Number of tanks: 6 Location"-(QQ Sec.Twp.Range.): SESE Sec 30.T12N,R62W County: Weld Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies°: 2011 Year(s)tanks)were placed in service's: 2011 Control Description': Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency's: 95% Condensate Throughput'[bbl/year] Requested's: 146,000 Maximum for PTE calculation'''. 175,200 Actual': 146,000 While Controls Operational" 146,000 Other equipment at facility": VCU,flare,heater treater,generator engine,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GP01 coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use NM for requested throughput/emission values unless requesting an individual permit ❑ Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emission's Actual Emissions20 Pollutant's [lb/bbl] PTE'' Uncontrolled26 Controlled' Uncontrolled26 Controlled' VOC[tons/year] 0.1351 11.8 N/A N/A 9.9 0.49 NOx[tons/year] N/A 0.03 0.03 0.03 CO[tons/year] N/A 0.18 0.18 0.18 128.0 6.4 Benzene[lbs/year] 854.0 42.7 n-Hexane[lbs/year] Wells serviced by this tank or tank battery28 API#: 05-123-31339-00 Name: Randall Creek 3-3014 ®Newly Reported Well API#: Name: 0 Newly Reported Well API#: Name: ❑Newly Reported Well Hi 0 Newly Reported Well w API#: Name: so API if: Name 0 Newly Reported Welk`,,, rn API#: Name: 0 Newly Reported Weill_:. m 0 Newly Reported WellIi Ap]#: Name: 0 Ciii �' Tire signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of y my knowledge and ief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated zN in full compli each c 'on of general permit GPOI. : o Sign re of Legally Authorized Person(not a vendor or consultant) Date N Senior Environmental Specialist d"° Curtis Rice Official Title N Type or Print Name of Person Signing Above O Submit this form,along with$152.90 for each Colorado Department of Public Health and Envirorunent For information call: N y call� filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI f��n`L,-� G of $250 General Permit fee for each new GP 4300 Cherry Creek Drive South (, l t ��' }:�� registration to: Denver,CO 80246-1530 ".. FORM APCD-205 Page 1 of 2 EOG RC 3-30H FormAPCD-205-E&PCondensateTankAPEN.docx N • • N , - a .- -Cib 'a 0 ° o °o a I. o m >. Is cy .L. i s Ln _ in E E i m O o c W ao 8 z ` L• .. f�) en t it r y I U ..0 O a. 0 ° W O:'u ••.. i.,,'` N N N ° > > > d 3 Q s d 0. 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C IF v .°�.. > ❑ E a c o u U ,O„ u a A d ti eJ-_J. O F fill ° 'ter z p W 2 y u W ❑ Eu du v m c� mL �0 7 u O R Q 0 C .E' C u.- C N E am a m E u W v O N O e 'C y a J .. E '_' y H i u y o O E.I 7 Q y N a � L m o N M U _m O 'G - Z C - s o .u. .C. 5 c c. o ., u A v7 C a E O +,.' O y!4 a O C ti Q a15 S a W N u r- 0. .ta O i O 0 u w L O ti P. .au., - w .. Q O m •Ci o A m c'!. E' S 0.' ° A m c CO a P. u G 5eki m c .. O E y u-1 00 x y V o coo o a � _u c 4 O D. m M O > O U T m m O _ 'u " m R O m w ter Y e0 O u > m 0 e E — _ ... d L4 v « .C V N ' r� N W 0 r C tn 0 . 0 as o o` o o m � v E .. �' 0 O W 7 O O O N o c m m ¢� o.w ^g. L > n n' Q > F A c a z > U m F T X c u u O ❑ I❑ u CE u •b4 u D CU v W V) V) V] ' I V] zol STATE OF COLORADO f f tali .0v.cozo COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT ;1 AIR POLLUTION CONTROL DIVISION i TELEPHONE: (303) 692-3150 + .:, .: �+ •8876* CONSTRUCTION PERMIT PERMIT NO: 1 1 WE3526 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 Randall Creek 3-30H, located in the SESE of Section 30, Township 12 North, Range 62 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Crude Oil Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Storage 001 Emissions from these tanks are controlled by a Cimarron Tanks smokeless VCU unit with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water PW Tank 002 storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. One (1) 400 BBL fixed roof storage tank used to store gas in the ET#4707 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. One (1) Waukesha, Model F1197GU, Serial Number 389650, natural gas-fired, naturally aspirated, 4SRB reciprocating internal Generator combustion engine, site rated at 163 horsepower at 1800 RPM. RICE 005 This engine shall be equipped with a non-selective catalytic Engine reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power until electricity can be ran to the location. Truck 006 Truck loadout of crude oil. Loadout Point 005 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha Model F1197GU engine in accordance with the permanent replacement provision of the Alternate Operating Scenario(AOS), included in this permit as Attachment A. AIRS ID: 123/9468/999 Page 1 of 19 Condensate Tank Version 2009-1 EOG Resources, Inc. olora Depar en f P li Health and Environment Permit No. 11WE3526 it Pollution Control Division Issuance 1 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 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. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment,which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 3.2 per year of volatile organic compounds (VOC), -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: AIRS ID: 123/9468/999 Page 2 of 19 EOG Resources, Inc . olor Depa en f P bli Health and Environment Permit No. 11 WE3526, it Pollution Control Division Issuance 1 • TMy 4 • 100 tons per year of volatile organic compounds (VOC). 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO Crude Oil 001 --- 0.5 --- Point Storage Tanks PW Tank 002 --- 0.24 --- Point ET#4707 003 --- 7.2 -- Point Flare 004 4.9 78.3 26.7 Point Generator 005 1.6 1.1 3.2 Point RICE Engine Truck Loadout 006 --- 9.5 --- 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. 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. 8. 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.) 9. 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.) 10. 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.) 11. Point 005: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. The NSCR shall reduce uncontrolled emissions of NOx, VOC and CO from the unit to the emission levels listed in this section, above. Operating AIRS ID: 123/9468/999 Page 3 of 19 EOG Resources, Inc. olor Depar" en f i.licHealth and Environment Permit No. 11WE3526 F ` {` 'ir Pollution Control Division Issuance 1 parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) PROCESS LIMITATIONS AND RECORDS 12. 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 PW Tank 002 Produced water throughput 36,500 BBL/yr ET#4707 003 Natural gas venting to atmosphere 427,500 SCF/yr Flare 004 Natural gas flaring 93.075 MMSCF/yr Generator 005 Consumption of natural gas as a fuel 9.5 MMscf/yr RICE Engine Truck Loadout 006 Crude oil and produced water loading 182,500 BBL/yr Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly crude oil throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 13. 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 14. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 15. Visible emissions shall not exceed twenty percent(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.) 16. 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.). 17. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/9468/999 Page 4 of 19 EOG Resources, Inc. olor Depa nen of li Health and Environment Permit No. 11 WE3526 Jr Pollution Control Division Issuance 1 18. Point 005: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Note that this condition may not apply if the engine is subject to standards under NSPS or MACTs (see Reg 7 XVII.B.4). Note that there must be an actual emission standard under NSPS/MACT in order for Reg 7 to not apply. Note also that in most cases, the NSPS/MACT standards will be the same as what would be required for Reg. 7: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 19. Point 006: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 20. 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.) 21. 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: (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. AIRS ID: 123/9468/999 Page 5 of 19 EOG Resources, Inc. olor Depa en gfjir IicHealth and Environment Permit No. 11WE3526 q Pollution Control Division Issuance 1 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 22. 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. 23. Points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self- certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: AIRS ID: 123/9468/999 Page 6 of 19 EOG Resources, Inc. h r (9. epa > en•l5f k'.li Health and Environment Permit No. 11WE3526 . .44ir Pollution Control Division Issuance 1 banana tb.mot, i222 1 1a6scf = ben::ene Wt.frac.M » M1,111.7�M!dscf 37'5.3 sc./ 5 ra' ibmad 1.I.N.scf, 24. Point 004: The owner or operator shall demonstrate compliance with Condition 16 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 25. Point 005: A source initial compliance test shall be conducted on emissions point 004 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide • Volatile Organic Compounds Periodic Testing Requirements 26. Point 005: This engine is subject to the periodic testing requirements as specified in the operating and maintenance(O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. AIRS ID: 123/9468/999 Page 7 of 19 EOG Resources, Inc. olor Depai ent ilf_PaiIic Health and Environment Permit No. 11 WE3526ykir Pollution Control Division Issuance 1 f ` • f. Point 005: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 28. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equal or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 29. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 30. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 31. If this permit specifically states that final authorization has been granted,then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide"final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self-Certify for Final Authorization section of this permit. 32. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 33. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab initio. This permit may be AIRS ID: 123/9468/999 Page 8 of 19 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11WE3526 it Pollution Control Division Issuance 1 revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for: (6) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank, 4SRB engine and crude oil loadout. New synthetic minor facility. AIRS ID: 123/9468/999 Page 9 of 19 ' m : 1 _w EOG Resources, Inc ., „ olor tDepar entof P IicHealth and Environment ) Permit No. 11WE3526 l _ 4ir Pollution Control Division Issuance 1 I - k_ 4, li ._, Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cd phe.state.co.us/req u lation s/airregs/100102agcccom mon 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 128 Yes 6 Toluene 108883 C 114 No 6 Ethylbenzene 100414 C 2 No 0 001 Xylenes 1130207 C 42 No 2 n-Hexane 110543 C 854 No 43 2,2,4- 540841 C 70 No 4 Trimethylpentane Benzene 71432 A 256 Yes 13 002 n-Hexane 110543 C 803 Yes 40 Benzene 71432 A 32 No 32 Toluene 108883 C 24 No 24 003 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 10 No 10 n-Hexane 110543 C 196 No 196 Benzene 71432 A 6981 Yes 349 Toluene 108883 C 5272 Yes 264 004 Ethylbenzene 100414 C 886 No 44 Xylenes 1130207 C 2190 Yes 110 n-Hexane 110543 C 42799 Yes 2140 Formaldehyde 50000 A 275 Yes 96 005 Methanol 67561 C 41 No 14 AIRS ID: 123/9468/999 Page 10 of 19 EOG Resources, Inc. olor Depat en f li Health and Environment Permit No. 11WE3526 it Pollution Control Division Issuance 1 Acetaldehyde 75070 A 37 No 13 Acrolein 107028 A 35 No 12 Benzene 71432 A 21 No 7 1,3-Butadiene 106990 A 9 No 3 Toluene 108883 C 7 No 3 Benzene 71432 A 127 Yes 127 Toluene 108883 C 416 No 416 Ethylbenzene 100414 C 31 No 31 006 2,2,4- 540841 C 161 No 161 Trimethylpentane Xylenes 1130207 C 553 No 553 n-Hexane 110543 C 758 No 758 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 3.2165 lb/1000 gal 0.1564 lb/1000 gal E&P Tanks 71432 Benzene 0.0209 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 108883 Toluene 0.0186 lb/1000 qal 0.001 lb/1000 gal E&P Tanks 100414 Ethylbenzene 0.0003 lb/1000 qal 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 0.1393 lb/1000 gal 0.0070 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 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 002 are based on the combustor control efficiency of 95% AIRS ID: 123/9468/999 Page 11 of 19 EOG Resources, Inc L olor r > Depar en of P �lii Health and Environment Permit No. 11 WE3526 x Air Pollution Control Division Issuance 1 Point 003: Emission Factors Weight Fraction of Source CAS# Pollutant Uncontrolled Gas (%) Lb/MMscf VOC 33684.2105 lb/MMscf 46.18 Engineering Calculation 71432 Benzene 74.8538 lb/MMscf 0.10 Engineering Calculation 108883 Toluene 56.6082 lb/MMscf 0.08 Engineering Calculation 100414 Ethylbenzene 9.5906 lb/MMscf 0.01 Engineering Calculation 1330207 Xylenes 23.6257 lb/MMscf 0.03 Engineering Calculation 110543 n-hexane 459.4152 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 11,875 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 (%) NOx --- 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42 VOC 46.18 33633.0916 1681.6546 Engineering lb/MMscf lb/mmscf Calculation PM10 AP-42, Table 40 ug/I 40 ug/l 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf lb/MMBtu lb/MMBtu 71432 Benzene 0.10 75.0083 3.7504 Engineering lb/MMscf lb/mmscf Calculation 108883 Toluene 0.08 56.6371 2.8316 Engineering lb/MMscf lb/mmscf Calculation 100414 Ethylbenzene 0.01 9.5224 lb/MMscf 0.4761 Engineering lb/mmscf Calculation 1330207 Xylenes 0.03 23.5251 1.1763 Engineering lb/MMscf lb/mmscf Calculation 110543 n-hexane 0.63 459.8313 22.9916 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 004 are based on the flare control efficiency of 95% • AIRS ID: 123/9468/999 Page 12 of 19 EOG Resources, Inc. olora Depa err ' f li Health and Environment Permit No. 11WE3526 ' it Pollution Control Division Issuance 1 Point 005: Emission Factors - Emission Factors- Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.1662 13.5 0.2345 1 CO 3.9871 17 0.4691 2 VOC 0.4691 2 0.1642 0.7 50000 Formaldehyde 0.0205 0.0874 0.0072 0.0306 67561 Methanol 0.0031 0.0130 0.0011 0.0046 75070 Acetaldehyde 0.0028 0.0119 0.0010 0.0042 107028 Acrolein 0.0026 0.0112 0.0009 0.0039 71432 Benzene 0.0016 0.0067 0.0006 0.0024 106990 1,3-Butadiene 0.0007 0.0028 0.0002 0.0010 108883 Toluene 0.0006 0.0024 0.0002 0.0008 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site- rated horsepower value of 163, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP-42 AP-42 Point 006: 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 i AP-42 540841 2,2,4-IMP 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 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. 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 November 1,2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. AIRS ID: 123/9468/999 Page 13 of 19 • YS'6�. ^sL�il EOG Resources, Inc a4 olora Depa: en! f P �jlid Health and Environment Permit No. 11WE3526 • e it Pollution Control Division Issuance 1 6) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source • VOC, n-hexane, total HAPS 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 Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY • MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 8) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilgaspermittinq.html AIRS ID: 123/9468/999 Page 14 of 19 EOG Resources Inc t` olor .,Depa en f y1i `Health and Environment Permit No. 11WE3526 'it Pollution Control Division Issuance 1 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES December 10, 2008 The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. A.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90- day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from the permanent replacement engine comply with 1) the permitted annual emission limitations for the AIRS ID: 123/9468/999 Page 15 of 19 EOG Resources, Inc h olor rf� Depar en i1f Health and Environment Permit No. 11WE3526 x Air Pollution Control Division Issuance 1 . 111, existing engine, 2) any permitted short-term emission limitations for the existing permitted engine, and 3) the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissions Notice (APEN) for the replacement engine (see http://www.cdphe.state.co.us/ap/oilgaspermittinq.html for example applicability report formats). Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section A.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermittinq.html. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. A.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9468/999 Page 16 of 19 • EOG Resources, Inc. olora, Depa, 'nen rblicHealth and Environment Permit No. 11 WE3526' Air Pollution Control Division Issuance 1 For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. A.3 Applicable Regulations for Permanent Engine Replacements A.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology(RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural-gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. A.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State-Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non-selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9468/999 Page 17 of 19 ”.j7," ,.f. . EOG Resources Inc. Depar.4 en'df - lic Health and Environment Permit No. 11WE3526 `I� Air Pollution Control Division i. Issuance 1 ; b nni ki Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject 40 CFR 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of November 1, 2008 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, §I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. A.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9468/999 Page 18 of 19 EOG Resources, Inc. a It ; e.olor Depar en, of P• .lic'Health and Environment Permit No. 11 WE3526 h11 4 Air Pollution Control Division Issuance 1 • A.3.4.1 Area Source for HAPs A permanent replacement engine located at an area source that commenced construction or reconstruction after June 12, 2006 as defined in §63.2, will meet the requirements of 40 CFR Part 63, Subpart ZZZZ by meeting the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.4.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 12/19/02) 2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. • New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9468/999 Page 19 of 19 Construction Permit Application Preliminary Analysis Summary Section 1 -Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3458 Source Location: SWSE S28,T12N, R62W,Weld County(Attainment) Point 001: (6)400 BBL above ground atmospheric crude oil storage tanks Point 002: (1) 400 BBL above ground atmospheric produced water storage tank. 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: 4SRB internal combustion engine Point 006: Crude oil truck loadout AIRS ID: 123-9406 Date: January 12, 2012 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, when did you mail an Information Request letter to the source? On what date was this application complete? October 13, 2011 Section 4— Source Description AIRS Point Equipment Description Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from 001 • these tanks are controlled by a Cimarron smokeless combustor (vapor combustion unit)with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water storage tank. 002 Emissions from this tank are controlled by a combustor(VCU) 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. One (1) International, Model NG466TA, Serial Number 674774-20, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine, site rated at 005 134 horsepower at 1800 RPM.This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control. This emission unit is used for primary power until electricity can be ran to the location. 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 X Yes No water(less than 1% by volume crude oil on an average 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 AP-42, Table 3.2-3 AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 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 [Ib/Ib-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 Page 2 001 131400 BBL per year(109500 x 1.2) 002 65,700 BBL per year(54750 x 1.2) 003 390,000 scf/yr a 0.39 MMSCF/yr 004 260,000 scf/day => 94,900,000 scf/yr= 94.9 mmscf/yr 005 7.8 MMscf/yr 006 164,250 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 001 109,500 BBL per year 2011 002 54,750 BBL per year 003 390,000 scf/yr=> 0.39 MMSCF/yr 004 260,000 scf/day=> 94,900,000 scf/yr= 94.9 mmscf/yr 005 7.8 MMscf/yr 006 164,250 BBL per year crude oil loaded Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 109,500 BBL per year 002 54,750 BBL per year 003 390,000 scf/yr=> 0.39 MMSCF/yr 004 260,000 scf/day => 94,900,000 scf/yr= 94.9 mmscf/yr 005 7.8 MMscf/yr 006 164,250 BBL per year crude oil loaded Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor(VCU) 95 002 01 Cimarron smokeless combustor(VCU) 95 004 01 Tornado 40' flare stack 95 005 01 NSCR and AFRC NOx: 89%; CO: 87%; VOC: 57% & HAPS: 50% Page 3 Section 6 —Emission Summary (tons per year) Point NO, VOC CO SOx PM10 Single HAP Total HAP 001 0.03 9.0 0.2 --- 0.4 (n-hexane) 0.52 002 --- 8.6 --- --- --- 0.7 (n-hexane) 1.0 003 --- 6.6 --- --- --- 0.09 0.1 PTE: (n-hexane) 004 5.0 1595.9 27.2 0.03 1.3 21'8 (n 29.6 . hexane) 005 12.2 2.1 20.5 ( 0.1 formaldehyde) 0.2 006 --- 8.5 --- --- --- 0.3 (n-hexane) 0.9 0.3 001 0.03 7.5 0.2 --- (n-hexane) 0.43 002 --- 7.2 --- --- --- 0.6 (n-hexane) 0.8 Uncontrolled point source emission rate: 003 --- 6.6 --- --- --- 0'09 0.1 (n-hexane) 004 5.0 1595.9 27.2 0.03 1.3 21'8 (n 29.6 hexane) 005 12.2 2.1 20.5 ( 0.1 formaldehyde) 0.2 006 --- 8.5 --- --- --- 0.3 (n-hexane) 0.9 TOTAL (TPY) 17.2 1627.8 47.7 --- --- 23.0 (n- 32.0 hexane) 001 0.03 0.4 0.2 --- --- 0.02 (n- 0.02 hexane) 002 --- 0.4 --- --- --- 0.03 (n- 0.04 hexane) Controlled point 003 --- 6.6 --- ___ --- 0.09 0.1 source emission rate: (n-hexane) 004 5.0 79.8 27.2 0.03 1.2 1.1 (n-hexane) 1.5 005 1.3 0.9 2.6 0.1 (formaldehyde) 0.1 006 --- 8.5 --- --- 0.3 (n-hexane) 0.9 INSIGNIFICANTS 0.5 1.5 0.6 0.14 (n- 0.17 (TPY) hexane) TOTAL PERMUTED 6.3 96.6 29.8 --- --- 1.5 (n-hexane) 2.7 (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 99 Yes 5 Toluene 108883 C 88 No 4 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 33 No 2 n-Hexane 110543 C 606 No 32 2,2,4-Trimethylpentane 540841 C 55 No 3 Point 002 Page 4 Benzene 71432 A 383 Yes 19 n-Hexane 110543 C 1205 Yes 60 Point 003 • Benzene 71432 A 29 No 29 Toluene 108883 C 22 No 22 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 9 No 9 n-Hexarie 110543 C 179 No 179 Point 004 Benzene 71432 A 7118 Yes 356 Toluene 108883 C 5375 Yes 269 Ethylbenzene 100414 C 904 No 45 Xylenes 1130207 C 2233 Yes 112 n-Hexane 110543 C 43638 Yes 2182 Point 005 Formaldehyde 50000 A 226 Yes 113 Acetaldehyde 75070 A 34 No 17 Acrolein 107028 A 31 No 16 Benzene 71432 A 17 No 9 Point 006 Benzene 71432 A 114 Yes 114 Toluene 108883 C 374 No 374 Ethylbenzene 100414 C 28 No 28 2,2,4-Trimethylpentane 540841 C 145 No 145 Xylenes 1130207 C 498 No 498 n-Hexane 110543 C 682 No 682 Note: Regulation 3, Part A, Section Il.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 Site-specific 001 01 VOC CDPHE PS Memo 05-01 sampling 003 01 VOC, State only requirement Site-specific gas HAPS analysis 004 01 NOx CO Regulation No. 3, Part B., Section III.G.3 Stack test 004 01 Opacity Regulation No. 1, Section II.A.5 Method 9 Page 5 005 01 VOC CO Regulation No. 3, Part B., Section III.G.3 Stack Test 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 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:! Particulate,Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 001-006 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2-Odor Section LA- 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. Page 6 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£0 TPY threshold(Reg. 3, Part B, Section ll.D.3.a) Regulation 6 - New Source Performance Standards 001-003, None 004, 006 NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ when 005 their manufacturer date is on or after July 1, 2008. The operator provided a manufacturer date of November 14, 2006, which is prior to the threshold date. Therefore, this engine is not subject to NSPS JJJJ. 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 001-003, subject to Section X11 of this regulation. 004, 006 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. 005 This engine is subject to Regulation 7, Section XVII.E because it was relocated into the State of Colorado on 4/17/11, which is after January 1, 2008. Regulation 8— Hazardous Air Pollutants 001-003, None 004, 006 MACT 7777: Engines subject to area source MACT 7777 are engines with a commencement of construction date on or after June 12, 2006. The operator provided 005 a construction commencement date of 7/8/2010, which is after the threshold date, therefore, subject to area source MACT ZZZZ requirements. Requirements are to follow NSPS JJJJ requirements. Section 13.—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 3.2603 VOC No E&P Tanks 95 lb/1000 gal 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA Ib/MMBtu Table 13.5-1 0.0209 Benzene No E&P Tanks 95 001 01 Crude oil Storage Tanks lb/1000 gal 0.0187 Toluene No E&P Tanks 95 lb/1000 gal • 0.0004 Ethylbenzene No E&P Tanks 95 lb/1000 gal 0.0070 Xylenes No E&P Tanks 95 lb/1000 gal y 0.1409 n-hexane No E&P Tanks 95 lb/1000 gal Page 7 0.0117 2,2,4-TMP 4-TMP No E&P Tanks 95 lb/1000 qal . 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 Produced water storage 0.1667 CDPHE PS 01 tanks lb/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 33846.1539 Engineering lb/MMscf VOC No Calculation 0 74.8718 Engineering lb/MMscf Benzene No Calculation 0 56.6667 Engineering 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 003 9.4872 Ethlybenzene No Engineering 0 lb/MMscf Calculation 23.5897 Engineering lb/MMscf Xylenes No Calculation 0 459.4872 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 33633.2982 Engineering lb/MMscf VOC No Calculation 95 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 75.0084 Benzene No Engineering 95 01 Flare lb/MMscf Calculation 004 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 0.385 VOC No AP-42 57 lb/mmbtu 2.21 NOx No AP-42 89 lb/mmbtu 3.72 CO No AP-42 87 lb/mmbtu 01 Reciprocating internal 0.0205 Formaldehyde No AP-42 50 005 combustion engine lb/mmbtu 0.00279 Acetaldehyde No AP-42 50 lb/mmbtu 0.00263 Acrolein No AP-42 50 lb/mmbtu 0.00158 Benzene No AP-42 50 lb/mmbtu SCC 20200253: 4-cycle rich burn 0.104 lb/BBL VOC No AP-42 0 006 01 Truck Crude oil Loadout 0.0007 b/BBL Benzene No AP-42 0 lPage 8 0.0023 Toluene No AP-42 0 lb/BBL 0.0002 Ethylbenzene No AP-42 0 lb/BBL 0.0030 Xylenes No AP-42 0 lb/BBL 0.0042 n-hexane 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 = (7.497 TPY*2000) / 109500 bbl/yr= 0.1369 lb/bbl *1000/42 = 3.2603 lb/1000 gal Benzene = (0.048 TPY*2000)/ 109500 bbl/yr= 0.0009 lb/bbl * 1000/42 = 0.0209 lb/1000 gal Toluene = (0.043 TPY*2000) / 109500 bbl/yr = 0.0008 lb/bbl * 0.0187 lb/1000 gal Ethylbenzene = (0.001 TPY *2000) / 109500 bbl/yr= 0.00002 lb/bbl * 1000/42 = 0.0004 lb/1000 gal Xylenes = (0.016 TPY *2000)/ 109500 bbl/yr= 0.0003 lb/bbl * 1000/42 = 0.0070 lb/1000 gal n-hexane = (0.324 TPY*2000) / 109500 bbl/yr = 0.0059 lb/bbl * 1000/42 = 0.1409 lb/1000 gal 2,2,4-TMP = 0.027 TPY *2000)! 109500 bbl/yr= 0.0005 lb/bbl * 1000/42 = 0.0117 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 accepts Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. 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. (scf/hr) * (lb/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 = (6.6 TPY* 2000 lb/T)/(0.39 mmscf/yr) = 33846.1539 lb/mmscf Benzene = (29.2 Ib/yr)/ (0.39 mmscf/yr) = 74.8718 lb/mmscf Toluene = (22.1 Ib/yr) /(0.39 mmscf/yr) = 56.6667 lb/mmscf Ethylbenzene = (3.7 Ib/yr) / (0.39 mmscf/yr) = 9.4872 lb/mmscf Xylenes = (9.2 Ib/yr) / (0.39 mmscf/yr) = 23.5897 lb/mmscf n-hexane = (179.2 Ib/yr)/ (0.39 mmscf/yr) = 459.4872 lb/mmscf Page 9 AIRS Point 004 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 lb/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/l) Benzene = (7118.3 lb/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 005 RICE This is a permitted source since uncontrolled NOx and CO emissions (each) are greater than 10 TPY. Engine subject to MACT requirements, but not subject to NSPS JJJJ, so since it was relocated into Colorado on 4/17/10, it is subject to Regulation 7 requirements. The engine is controlled by a NSCR and AFRC. 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 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 6898500ga1/yr Annual requested VOC emissions 170441b/yr 8.52tpy Benzene = (114.26 Ib/yr)/ (164250) = 0.0007 lb/bbl Toluene = (374.17 Ib/yr) / (164250) = 0.0023 lb/bbl Ethylbenzene = (27.56 Ib/yr) /(164250) = 0.0002 lb/bbl Xylenes = (497.77 Ib/yr) /(164250) = 0.0030 lb/bbl n-hexane = (682.06 Ib/yr)/ (164250) = 0.0042 lb/bbl 2,2,4-TMP = (144.66 Ib/yr) / (164250) = 0.0009 lb/bbl Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and is a synthetic minor source for VOC, PSD, n-hexane and total HAPS. Page 10 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY OIL . Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) . , AIRS ID#': 123194%1 e&l ❑ APEN update only° ❑ New or previously unreported battery ❑ Modification to existing sources ' s 0CT { 3 2011 ❑ Previously grandfathered battery'- O Registration for coverage under general permit no.GPOI ❑ Synthetic minor facility &cancellation request for individual permits: ry'ipi!irj' ❑ Located in the 8-hr Ozone Control Areas ® Application for or Modification of an individual permit `�,� j0Ur1✓s ❑ Registered under general permit no.GPOI ❑ Administrative permit amendments ❑ Permitted under individual permit: I IWE3µ58 ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division O To review a draft of the permit prior to issuance Company Names: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address1s: 600 17°'Street,Suite 1000N david_long@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303-262-9448 Fax: 303-262-9449 Tank Battery Name'': Randall Creek 1-281-I Number of tanks: 6 Location's(QQ Sec.Twp.Range.): SWSE Sec 28,T12N,R62W County: Weld Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies's: 2011 Year(s)tank(s)were placed in service's: 2011 Control Description's: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency's: 95% C.endhixeaK Throughput's[bbl/year] Requested's: 109,500 Maximum for PTE calculation1s: 131,400 C12WtE Olt-- Actual''°: 109,500 While Controls Operational2' 109,500 Other equipment at facility22: VCU,flare,heater treater,generator engine,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPOI 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. 0 Check if site-specific emission factors provided to calculate emissions'-s. Emission Factor. Battery Requested Emissions's Actual Emissions29 Pollutant24 [lb/bbl] PTE-5 Uncontrolledss Controlled'-r Uncontrolled26 Controlled2r VOC[tons/year] 0.1369 . 9.0 N/A N/A 7.5 0.37 NOx[tons/year] N/A 0.03 0.03 0.03 CO[tons/year] N/A 0.15 0.15 0.15 Benzene[lbs/year] 95.0 4.8 n-Hexane[lbs/year] 648.0 32.4 Wells serviced by this tank or tank battery? API#: 05-123-31357-00 Name: Randall Creek 1-2811 • ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: O Newly Reported Well Is' API#: ni Name: El Newly Reported Well tV w API#: Name _ ❑Newly Reported Well a API#: Name: ❑Newly Reported Well fey' o°s API#: Name: O Newly Reported Well :1i- oici ro 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 this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated roin full complianc ith each con ' ' n of general permit GPOI. p Ps Z I /12 —!/ —// . o Signa e of Legally Authorized Person(not a vendor or consultant) Date is')IC) E' Curtis Rice Senior Environmental Specialist 3 Type or Print Name of Person Signing Above Official Title 0 Hi Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment' For information call: `s filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 t-1 /1 5—?'-' rN" (303)692-3150 o $250 General Permit fee for each new GP 4300 Cherry Creek Drive South I��1j Q ' 5 registration to: Denver,CO 80246-1530 v FORM APCD-205 Page 1 of 2 EOG RC 1-28H FormAPCD-205-E&PCondensateTankAPEN.docx Ni N O N G ° r al 0 ° —4O o f c o `u ° E rl ao T e $ h O a CD v ^ = o n g z y o 3.4 W en en m c W ❑ O O M G V W ayi N N N O co N ` u u > �' Q F G P. 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Y °� 0 E `a o -T4:,40) ,�+-",s at;^a` u m o O En( v a d ^ `o a u E A E m>v e m .o �`"-. •°�'• c ° c, • .o s 'd " Ca Ain?, n om a, c y b ;CIr�E U .-55 Fo u Y E y W 0 h — O m o $"".Tk� xY '`S.S S w e G ,N F-i C. Q F q:W C .C N" J O W N L u ° N a\-t,-;P- a '/T �/J+t, r' j S]y O o o m m o o • •-• G 0 T. v +o' u Gay W • : y u I� 'ecms n u.E - Y u 0.i F C y a. -8M _ t 5 a G R yS° - u N u C. Ph aay QE tici, .G. aGa tSi- U '-Cao 'c y • , .: .3�• a a Y<4 u Rl m m ° Vl +L' > O « T O y d O a. 4,-."r ,'` 3a 9 Yr- 'E u . C al n vNi v m o u > o C .E L� U ra.4 �1•,...m -rsiz.;. --Cif, 4: E, y w h .a u v E Q, c a v� y E U R' u .� O u W o E ' Q P. c ° o ea a N u G c d m o E >< U0 N o c v K ¢ o v z o.w z .F m > in a: a > E- Ga W a^a. .. z > U 9 o >' >, x o X m co x • STATE OF COLORADO jur 0f.co�o .p COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION e/ TELEPHONE: (303)692-3150 + ♦1876• CONSTRUCTION PERMIT PERMIT NO: 1 1 WE3458 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 Randall Creek 1-28H, located in the SWSE of Section 28, Township 12 North, Range 62 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Crude Oil Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Storage 001 Emissions from these tanks are controlled by a Cimarron Tanks smokeless VCU unit with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water PW Tank 002 storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. One (1) 400 BBL fixed roof storage tank used to store gas in the ET #4619 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. Separator controlled by a 40' flare stack. Flare has a minimum Flare 004 combustion efficiency of 95%. The flare is not enclosed. One (1) International, Model NG466TA, Serial Number 674774-20, natural gas-fired, naturally aspirated, 4SRB reciprocating internal Generator combustion engine, site rated at 134 horsepower at 1800 RPM. RICE 005 This engine shall be equipped with a non-selective catalytic Engine reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power until electricity can be ran to the location. Truck 006 Truck loadout of crude oil. Loadout Point 005 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha Model F1197GU engine in accordance with the permanent replacement provision of the Alternate Operating Scenario(AOS), included in this permit as Attachment A. AIRS ID: 123/9406/999 Page 1 of 19 Condensate Tank Version 2009-1 EOG Resources, Inc. Oolora Depa ' en f :aealth and Environment Permit No. 11 WE3458 it Pollution Control Division Issuance 1 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 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. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment,which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 3.3 per year of volatile organic compounds (VOC), -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: AIRS ID: 123/9406/999 Page 2 of 19 EOG Resources, Inc. h 'blor Depa en f lic Health and Environment Permit No. 11WE3458 Air Pollution Control Division Issuance 1 • 100 tons per year of volatile organic compounds (VOC). 7. 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, V0C CO Emission Type Crude Oil 001 --- 0.4 --- Point Storage Tanks PW Tank 002 --- 0.4 --- Point ET#4619 003 --- 6.6 --- Point Flare 004 5.0 79.8 27.2 Point Generator 005 1.3 0.9 2.6 Point RICE Engine Truck Loadout 006 8.5 --- 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. 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. 8. 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.) 9. 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.) 10. 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.) 11. Point 005: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. The NSCR shall reduce uncontrolled emissions of NOx, VOC and CO from the unit to the emission levels listed in this section, above. Operating AIRS ID: 123/9406/999 Page 3 of 19 EOG Resources Inc ` olor. % Depar en f P slic Health and Environment Permit No. 11WE3458 it Pollution Control Division Issuance 1 'kt. parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) PROCESS LIMITATIONS AND RECORDS 12. 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 109,500 BBL/yr Storage Tanks PW Tank 002 Produced water throughput 54,750 BBL/yr ET#4619 003 Natural gas venting to atmosphere 390,000 SCF/yr Flare 004 Natural gas flaring 94.9 MMSCF/yr Generator 005 Consumption of natural gas as a fuel 7.8 MMscf/yr RICE Engine Truck Loadout 006 Crude oil and produced water loading 164,250 BBL/yr Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly crude oil throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 13. 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 14. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 15. Visible emissions shall not exceed twenty percent(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.) 16. 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.). 17. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/9406/999 Page 4 of 19 EOG Resources Inc olor " Depa en f •li `Health and Environment Permit No. 11WE3458 A it Pollution Control Division Issuance 1 rs �: 18. Point 005: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Note that this condition may not apply if the engine is subject to standards under NSPS or MACTs (see Reg 7 XVII.B.4). Note that there must be an actual emission standard under NSPS/MACT in order for Reg 7 to not apply. Note also that in most cases, the NSPS/MACT standards will be the same as what would be required for Reg. 7: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 19. Point 006: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 20. 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.) 21. 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: (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. AIRS ID: 123/9406/999 Page 5 of 19 EOG Resources Inc z olor Depa em of 'Ii 'Health and Environment Permit No. 11 WE3458 frt a Pollution Control Division Issuance 1 . 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 22. 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. 23. Points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self- certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: AIRS ID: 123/9406/999 Page 6 of 19 $'. 8 EOG Resources, Inc. olor Depa en f P blic Health and Environment • Permit No. 11WE3458 Jr Pollution Control Division Issuance 1 :b banzano lb'no:. ;b 1 196 scj x = benzene wt.frac.* * MW MM_-cf o. o3 scf .ga' [NI maLi immscf 24. Point 004: The owner or operator shall demonstrate compliance with Condition 16 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 25. Point 005: A source initial compliance test shall be conducted on emissions point 004 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide Volatile Organic Compounds Periodic Testing Requirements 26. Point 005: This engine is subject to the periodic testing requirements as specified in the operating and maintenance(O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 27. A revised Air Pollutant Emission Notice(APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. AIRS ID: 123/9406/999 Page 7 of 19 n:.:y rx tx • EOG Resources, Inc j olor Depa r en if P 'Ii Health and Environment Permit No. 11WE3458 ;4ir Pollution Control Division Issuance 1 ,,\._ f. Point 005: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 28. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equal or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 29. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 30. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 31. If this permit specifically states that final authorization has been granted,then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide"final"authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self-Certify for Final Authorization section of this permit. 32. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 33. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be AIRS ID: 123/9406/999 Page 8 of 19 EOG Resources, Inc , olor Depa en dif bli Health and Environment • Permit No. 11WE3458"" Jr _ir Pollution Control Division Issuance 1 Ey '- revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for: (6) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank, 4SRB engine and crude oil loadout. New synthetic minor facility. AIRS ID: 123/9406/999 Page 9 of 19 EOG Resources, Inc. -olor Depart' end' f P li Health and Environment Permit No. 11WE3458 Air Pollution Control Division Issuance 1 4 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.c0.us/req ulations/a i rreas/100102aocccom mon provisionsrea.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 99 Yes 5 Toluene 108883 C 88 No 4 Ethylbenzene 100414 C 2 No 0 001 Xylenes 1130207 C 33 No 2 n-Hexane 110543 C 606 No 32 2,2,4- 540841 C 55 No 3 Trimethylpentane Benzene 71432 A 383 Yes 19 002 n-Hexane 110543 C 1205 Yes 60 Benzene 71432 A 29 No 29 Toluene 108883 C 22 No 22 003 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 9 No 9 n-Hexane 110543 C 179 No 179 Benzene 71432 A 7118 Yes 356 Toluene 108883 C 5375 Yes 269 004 Xylenes 1130207 C 2233 Yes 112 n-Hexane 110543 C 43638 Yes 2182 Formaldehyde 50000 A 226 Yes 113 005 Methanol 67561 C 34 No 17 Acetaldehyde 75070 A 31 No 15 AIRS ID: 123/9406/999 Page 10 of 19 EOG Resources, Inc >1 s': olor ' Depa' en, xf P,1.Ii 'Health and Environment • Permit No. 11 WE3458 v "{ 1 , A it Pollution Control Division Issuance 1 ., Point 003: Emission Factors Weight Fraction of Source CAS# Pollutant Uncontrolled Gas (%) Lb/MMscf VOC 33846.1539 lb/MMscf 46.18 Engineering Calculation Engineering 71432 Benzene 74.8718 lb/MMscf 0.10 Calculation Engineering 108883 Toluene 56.6667 lb/MMscf 0.08 Calculation Engineering 100414 Ethylbenzene 9.4872 lb/MMscf 0.01 Calculation Engineering 1330207 Xylenes 23.5897 lb/MMscf 0.03 Calculation Engineering 110543 n-hexane 459.4872 Ib/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 10,833.3 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well(weight percents for VOC and HAP components from this analysis are listed in the table above). Point 004: Weight Emission Emission Fraction Factors Factors CAS# Pollutant of Gas Uncontrolled Controlled Source (%) NOx --- 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42 CO --- 0.37 Ib/MMBtu 0.37 Ib/MMBtu AP-42 VOC 46.18 33633.2982 1681.6649 Engineering lb/MMscf lb/mmscf Calculation PM10 AP-42, Table 40 ug/l 40 ugh 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf lb/MMBtu lb/MMBtu 75.0084 3.7504 Engineering 71432 Benzene 0.10 lb/MMscf lb/mmscf Calculation • 108883 Toluene 0.08 56.6365 2.8318 Engineering lb/MMscf lb/mmscf Calculation 0.4761 Engineering 100414 Ethylbenzene 0.01 9.5216 lb/MMscf lb/mmscf Calculation 23.5248 1.1762 Engineering 1330207 Xylenes 0.03 lb/MMscf lb/mmscf Calculation 110543 n-hexane 0.63 459.8314 22.9916 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 004 are based on the flare control efficiency of 95%. AIRS ID: 123/9406/999 Page 12 of 19 antisl EOG Resources, Inc. olor Depa nen f P li Health and Environment Permit No. 11 WE3458 it Pollution Control Division Issuance 1 Acrolein 107028 A 29 No 15 Benzene 71432 A 17 No 9 1,3-Butadiene 106990 A 7 No 4 Toluene 108883 C 6 No 3 Benzene 71432 A 114 Yes 114 Toluene 108883 C 374 No 374 Ethylbenzene 100414 C 28 No 28 006 2 2 q_ 540841 C 145 No 145 Trimethylpentane Xylenes 1130207 C 498 No 498 n-Hexane 110543 C 682 No 682 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 3.2603 lb/1000 gal 0.1564 lb/1000 gal E&P Tanks 71432 Benzene 0.0209 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 108883 Toluene 0.0187 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 100414 Ethylbenzene 0.0004 lb/1000 gal 0.00002 lb/1000 gal E&P Tanks 1330207 Xylenes 0.0070 lb/1000 gal 0.0004 lb/1000 gal E&P Tanks 110543 n-hexane 0.1409 lb/1000 gal 0.0070 lb/1000 gal E&P Tanks 540841 2,2,4-TM'P 0.0117 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 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 002 are based on the combustor control efficiency of 95% AIRS ID: 123/9406/999 Page 11 of 19 EOG Resources, Inc. olora Depa nen of li Health and Environment • Permit No. 11WE3458 it Pollution Control Division Issuance 1 Point 005: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 2.21 9.4229 0.2345 1 CO 3.72 15.8612 0.4691 2 VOC 0.385 1.6416 0.1642 0.7 50000 Formaldehyde 0.0205 0.0874 0.0103 0.0437 67561 Methanol 0.0031 0.0130 0.0015 0.0065 75070 Acetaldehyde 0.0028 0.0119 0.0014 0.0059 107028 Acrolein 0.0026 0.0112 0.0013 0.0056 71432 Benzene 0.0016 0.0067 0.0008 0.0034 106990 1,3-Butadiene 0.0007 0.0028 0.0003 0.0014 108883 Toluene 0.0006 0.0024 0.0003 0.0012 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site- rated horsepower value of 134, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx AP-42 AP-42 CO AP-42 AP-42 VOC AP-42 AP-42 50000 Formaldehyde AP-42 AP-42 Point 006: 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 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 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. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on October 12,2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: AIRS ID: 123/9406/999 Page 13 of 19 e EOG Resources, Inc. olor Depa. nen' f - li Health and Environment Permit No. 11WE3458 Air Pollution Control Division Issuance 1 , , F Applicable Status Requirement Operating Permit Synthetic Minor Source VOC, n-hexane, total HAPS 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.woaccess.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/oileaspermittino.html • AIRS ID: 123/9406/999 Page 14 of 19 EOG Resources, Inc. ,olor Depa. en f P li Health and Environment Permit No. 11WE3458 it Pollution Control Division Issuance 1 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES December 10, 2008 The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. A.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90- day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from the permanent replacement engine comply with 1) the permitted annual emission limitations for the AIRS ID: 123/9406/999 Page 15 of 19 Krnawsii EOG Resources, Inc k; olor i Depai 'nen?8f fblicl lealth and Environment Permit No. 11WE3458 1. it Pollution Control Division Issuance 1 k existing engine, 2) any permitted short-term emission limitations for the existing permitted engine, and 3) the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissions Notice (APEN) for the replacement engine (see http://www.cdphe.state.co.us/ap/oilgaspermittinq.html for example applicability report formats). Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section A.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermittinq.html. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. A.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9406/999 Page 16 of 19 • EOG Resources, Inc g •olor 4,Depa en, cf 2•li `Health and Environment Permit No. 11WE3458 : �, = it Pollution Control Division Issuance 1 For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. A.3 Applicable Regulations for Permanent Engine Replacements A.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology(RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural-gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. A.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State-Only conditions). Control Requirements. Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non-selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9406/999 Page 17 of 19 EOG Resources, Inc a olora } Depa ern Of lic Health and Environment Permit No. 11WE3458 u it Pollution Control Division • Issuance 1 Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine • so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject 40 CFR 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required • by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition • A.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of November 1, 2008 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. A.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9406/999 Page 18 of 19 EOG Resources, Inc. ` olor Depari, en) f P li Health and Environment Permit No. 11 WE3458 it Pollution Control Division Issuance 1 A.3.4.1 Area Source for HAPs A permanent replacement engine located at an area source that commenced construction or reconstruction after June 12, 2006 as defined in § 63.2, will meet the requirements of 40 CFR Part 63, Subpart ZZZZ by meeting the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.4.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 12/19/02) 2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9406/999 Page 19 of 19 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3457 Source Location: SESE S18, T11N, R62W,Weld County (Attainment) Point 001: (4) 400 BBL above ground atmospheric crude oil storage tanks Point 002: (1)400 BBL above ground atmospheric produced water storage tank. Equipment Description: Point 003: (1)400 BBL above ground atmospheric emergency storage tank for vented gas. Point 004: Plant flare with a minimum combustion efficiency of 95%. Point 005: Crude oil truck loadout AIRS ID: 123-9405 Date: January 17, 2012 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, when did you mail an Information Request letter to the source? On what date was this application complete? October 12, 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 combustion unit)with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water storage tank. 002 Emissions from this tank are controlled by a combustor(VCU) with a minimum destruction efficiency of 95%. 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. Page 1 004 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 005 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 X Yes No water(less than 1% by volume crude oil on an average 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 ESP 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) AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 005 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 131400 BBL per year(109500 x 1.2) 002 87,600 BBL per year(73000 x 1.2) 003 414,000 scf/yr=> 0.414 MMSCF/yr 004 276,000 scf/day a 100,740,000 scf/yr= 100.74 mmscf/yr 005 182,500 BBL per year crude oil loaded Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) Page 2 AIRS Point Process Consumption/Throughput/Production Data Year 001 109,500 BBL per year 2011 002 73,000 BBL per year 003 414,000 scf/yr=> 0.414 MMSCF/yr 004 276,000 scf/day => 100,740,000 scf/yr= 100.74 mmscf/yr 005 182,500 BBL per year crude oil loaded Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 109,500 BBL per year 002 73,000 BBL per year 003 414,000 scf/yr=> 0.414 MMSCF/yr 004 276,000 scf/day => 100,740,000 scf/yr= 100.74 mmscf/yr 005 182,500 BBL per year crude oil loaded Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor(VCU) 95 002 01 Cimarron smokeless combustor(VCU) 95 004 01 Tornado 40' flare stack 95 Page 3 Section 6— Emission Summary (tons per year) Point NO. VOC CO SOx PM10 Single HAP Total HAP 001 0.1 64.2 0.6 3.3 (n-hexane) 4.0 002 --- 11.5 --- --- --- 1.0 (n-hexane) 1.3 0.1 PTE: 003 5.5 --- (n-hexane) 0.15 004 4.8 1336.2 26.3 0.03 1.3 26.2 (n 37.3 hexane) 005 --- 16.8 --- --- --- 0.7 (n-hexane) 2.2 2.8 001 0.1 53.5 0.6 (n-hexane) 4.3 Uncontrolled point 002 --- 9.6 --- --- --- 0.8 (n-hexane) 1.1 source emission rate: 003 -- 5.5 0.1 (n-hexane) 0.15 004 4.8 1336.2 26.3 0.03 1.3 26.2 (n 37.3 hexane) 005 --- 16.8 --- --- --- 0.7 (n-hexane) 2.2 TOTAL (TPY) 4.9 1421.6 26.9 --- --- 30.6 (n- 45.1 hexane) 001 0.1 2.7 0.6 --- ___ 0.14 (n- 0 2 hexane) 002 --- 0.5 --- -_- 0.04 (n- 0.05 Controlled point hexane) 0.1 source emission rate: 003 --- 5.5 --- --- --- (n-hexane) 0.15 004 4.8 66.8 26.3 0.03 1.2 1.3 (n-hexane) 1.9 005 --- 16.8 --- --= --- 0.7 (n-hexane) 2.2 , INSIGNIFICANTS 0.4 1.5 0.8 0.14 (n- 0.17 (TPY) hexane) TOTAL PERMITTED 4.9 92.3 26.9 0.03 1.2 2.3 (n-hexane) 4.5 (TPY) 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 Benzene 71432 A 1090 Yes 55 Toluene 108883 C 1044 Yes 52 Ethylbenzene 100414 C 166 No 8 Xylenes 1130207 C 370 No 19 n-Hexane 110543 C 5522 No 276 2,2,4-Trimethylpentane 540841 C 364 No 18 Point 002 Benzene 71432 A 511 Yes 26 n-Hexane 110543 C 1606 Yes 80 Point 003 Page 4 Benzene 71432 A 45 No 45 Toluene 108883 C 32 No 32 Ethylbenzene 100414 C 5 No 5 Xylenes 1130207 C 10 No 10 n-Hexane 110543 C 215 No 215 Point 004 Benzene 71432 A 10857 Yes 543 Toluene 108883 C 7714 Yes 386 Ethylbenzene 100414 C 1157 Yes 58 Xylenes 1130207 C 2539 Yes 127 n-Hexane 110543 C 52346 Yes 2617 Point 005 Benzene 71432 A 316 Yes 316 Toluene 108883 C 955 No 955 Ethylbenzene 100414 C 414 No 414 2,2,4-Trimethylpentane 540841 C 214 No 214 Xylenes 1130207 C 1040 Yes 1040 n-Hexane 110543 C 1407 Yes 1407 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 Site-specific 001 01 VOC CDPHE PS Memo 05-01 sampling 003 01 VOC, State only requirement Site-specific gas HAPS analysis 004 01 NOx CO Regulation No. 3, Part B., Section III.G.3 Stack test 004 01 Opacity Regulation No. 1, Section II.A.5 Method 9 Section 9—Source Classification Is this a new previously un-permitted source? 001 002 003 004 005 YES X X X X X NO What is this point classification? True Minor X X X X Synthetic Minor X Page 5 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 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, 001-005 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 001-005 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. Page 6 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 001-005 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 005 nonattainment or attainment/maintenance areas. This source is not 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 001-005 Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section 11.D.3.a) Regulation 6 - New Source Performance Standards 001-005 None 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. Regulation 8-Hazardous Air Pollutants 001-005 None Section 13 —Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (°/a) 23.2524 VOC No E&P Tanks 95 lb/1000 gal 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA • lb/MMBtu Table 13.5-1 0.2370 Benzene No E&P Tanks 95 lb/1000 gal 01 Crude oil Storage Tanks 02270 Toluene No E&P Tanks 95 001 lb/1000 gal 0.0361 Ethylbenzene No E&P Tanks 95 lb/1000 gal y 0.0805 Xylenes No E&P Tanks 95 lb/1000 gal 1.2007 n-hexane No E&P Tanks 95 lb/1000 gal 0.0791 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 95 Memo 09-02 throughput 0.1667 Produced water storage CDPHE PS 01 tanks lb/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 Page 7 26570.0483 Engineering lb/MMscf VOC No Calculation 0 - 107.7295 Engineering lb/MMscf Benzene No Calculation 0 76.5700 Engineering 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 003 11.5942 Ethlybenzene No Engineering 0 lb/MMscf Calculation 25.1208 Engineering lb/MMscf Xylenes No Calculation 0 519.3237 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 26527.6951 Engineering lb/MMscf VOC No Calculation 95 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 AP-42, lb/MMBtu CO No Table 13.5-1 NA 107.7735 Benzene No Engineering 95 01 Flare lb/MMscf Calculation 004 76.5684 Toluene No Engineering 95 lb/MMscf Calculation 11.4820 Ethlybenzene No Engineering 95 Ib/MMscf Calculation 25.0548 Engineering lb/MMscf Xylenes No Calculation 95 519.6109 n-hexane No Engineering 95 lb/MMscf Calculation SCC 31000205-Flares 0.164 lb/BBL VOC No AP-42 0 0.0017 Benzene No AP-42 0 lb/BBL 0.0052 Toluene No AP-42 0 lb/BBL 01 Truck Crude oil Loadout 0.0023 005 lb/BBL Ethylbenzene No AP-42 0 0.0057 Xylenes No AP-42 0 lb/BBL 0.0077 n-hexane No AP-42 0 Ib/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 = (53.433 TPY *2000) / 109500 bbl/yr = 0.9759 lb/bbl *1000/42 = 23.2368 lb/1000 gal Operator showed an emission factor of 0.9766 lb/bbl (which is higher). Will use that: 23.2524 lb/1000 gal Benzene = (0.545 TPY* 2000)/ 109500 bbl/yr= 0.0010 lb/bbl * 1000/42 = 0.2370 lb/1000 gal Toluene = (0.522 TPY*2000)/ 109500 bbl/yr= 0.0010 lb/bbl * 0.2270 lb/1000 gal Ethylbenzene= (0.083 TPY *2000) / 109500 bbl/yr= 0.0015 lb/bbl * 1000/42 = 0.0361 lb/1000 gal Xylenes = (0.185 TPY*2000)/ 109500 bbl/yr= 0.0034 lb/bbl * 1000/42 = 0.0805 lb/1000 gal ' n-hexane = (2.761 TPY*2000)/ 109500 bbl/yr= 0.0504 lb/bbl * 1000/42 = 1.2007 lb/1000 gal 2,2,4-TMP = (0.182 TPY *2000)/ 109500 bbl/yr= 0.0033 lb/bbl * 1000/42 = 0.0791 lb/1000 gal Page 8 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 accepts Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. 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. (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 = (5.5 TPY *2000 lb/T)/(0.414 mmscf/yr) = 26570.0483 lb/mmscf Benzene = (44.6 Ib/yr)/ (0.414 mmscf/yr) = 107.7295 lb/mmscf Toluene = (31.7 Ib/yr) /(0.414 mmscf/yr) = 76.5700 lb/mmscf Ethylbenzene = (4.8 Ib/yr) / (0.414 mmscf/yr) = 11.5942 lb/mmscf Xylenes = (10.4 Ib/yr)/ (0.414 mmscf/yr) = 25.1208 lb/mmscf n-hexane = 215.0 lb/ r) / (0.414 mmscf/yr) = 519.3237 lb/mmscf AIRS Point 004 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 = (1336.2 TPY * 2000 lb/T)/(100.74 lb/mmscf) = 26527.6951 lb/mmscf NOx and CO (from AP-42, Chapter 13, Table 13.5-1 (NOx = 0.068 lb/mmbtu; CO = 0.37 Ib/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/l) Benzene = (10857.1 Ib/yr)/ 100.74 mmscf/yr= 107.7735 lb/mmscf Toluene = (7713.5 Ib/yr)/ 100.74 mmscf/yr= 76.5684 lb/mmscf Ethylbenzene = (1156.7 Ib/yr)/ 100.74 mmscf/yr= 11.4820 lb/mmscf Xylenes= (2539.2 Ib/yr)/ 100.74 mmscf/yr= 25.0548 lb/mmscf n-hexane = (52345.6 Ib/yr) / 100.74 mmscf/yr= 519.6109 lb/mmscf Page 9 AIRS Point 005 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 5.96 psia M 51.42 lb/lb-mole T 524 deg. R L 4.371b/10^3 gal 1.84E-01 lb/bbl Annual requested Throughput 7665000gal/yr Annual requested VOC emissions 335141b/yr 16.76tpy Benzene = (316.41 Ib/yr)/(182500) = 0.0017 lb/bbl Toluene = (954.60 lb/yr)/ (182500) = 0.0052 lb/bbl Ethylbenzene= (413.67 Ib/yr)/(182500) = 0.0023 lb/bbl Xylenes = (1039.79 Ib/yr) / (182500) = 0.0057 lb/bbl n-hexane = (1406.64 Ib/yr) /(182500) = 0.0077 lb/bbl 2,2,4-TMP = (214.12 lb/yr)/ (182500) = 0.0012 lb/bbl Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and is a synthetic minor source for VOC, PSD, n-hexane and total HAPS. Page 10 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit/' OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTaERk- :y Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) I ► \2Lus AIRS ID#1: JZ3N#cf oei O APEN update only° ® New or previously unreported battery O Modification to existing sources .; ❑ Previously grandfathered battery O Registration for coverage under general permit no.GPOI O Synthetic minor facility &cancellation request for individual permit6: ... ❑ Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPOI II2tir� ❑ Administrative permit amendment.) ❑ Permitted under individual permit: �D9C77 O 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 Name9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 17th Street,Suite I000N david_Iong@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303-262-9448 Fax: 303-262-9449 Tank Battery Name11: Garden Creek I1-18H Number of tanks: 4 Location12(QQ Sec.Twp.Range.): SESE Sec 18,T11N,R62W County: Weld Total tank capacity[bbl]: 1,600(400 ea) Calendar year for which"Actual"data applies13: 2011 Year(s)tank(s)were placed in service14: 2011 Control Description's: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency": 95% Condensate Throughputs'[bbl/year] Requested1s: 109,500 Maximum for PTE calculation1D: 131,400 Actual20: 109,500 While Controls Operational21 109,500 Other equipment at facility": VCU,flare,heater treater,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 ❑;Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions 18 Actual Emissions'-° Pollutant" [lb/bbl] - PTE�5 Uncontrolled26 Controlled'.) Uncontrolled26 Controlled" VOC[tons/year] 0.9766 64.2 N/A N/A 53.5 2.67•NOx[tons/year] N/A 0.10 0.10 0.10 CO [tons/year] N/A 0.55 - 0.55 . 0.55 Benzene[lbs/year] 1,090.0 54.5 n-Hexane[lbs/year] 5,528.0 276.4 Wells serviced by this tank or tank battery28 API#: 05-123-31331-00 Name: Garden Creek 11-19H ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well N API#: Name: • ❑Newly Reported Well w 1 API#: Name ❑Newly Reported WellCD e; .n o API#: Name: O Newly Reported Well 1� O5 I API#: • Name: O Newly Reported Well :5:: • O Q'rl 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 m :- and belief. If this is a registration for coverage undergeneral permit GPOI,I further certify that this source is and will be operated ro y .,.. -•- 8i 8 P in •y'lion -ach condition of eneral permit GPOI.tn te /� N.) ��)I / DV- e t/C 7d/ PJ//F o SI_ . I e-o _ y Authorize. Persil(not a vendor or consultant) Date t ' t;` I-' 9_a N 1 David Long • Division Environmental Manager t_ o Type or Print Name of Person Signing Above Official Title 1 N Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: •= I filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI �� (-t 1 (303)692-3150 off $250 General Permit fee for each new GP 4300 Cherry Creek Drive South - , ( n p r? p c r registration to: Denver,CO 80246-1530 '"� �" ` J, U 2 O 6 r ) FORM APCD-205 Page 1 of 2 EOG GC 11-18H FormAPCD-205-E&PCondensateTankAPEN.docx el N O U o !' N N v t o f oe E. E _ ti ❑ Z o e en nn W O o a 0 N W O N N N N CO rl V wt. •- L> 6 0 ti QI °` m E o b b a L U 0 .° U d Q N be N O a 0 0. o c P. 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O V B O O G N N N Cr'. y L N C W "'j OX OU O °° Z 0 N X �^ q 1N 0 oOz: Fm o > V] a� ¢ > FQ o o Z > Ufo4 >,z o`er w W z V1 A it 4 1y �_ STATE OF COLORADO r S etid.„ciao . COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION I�+ i TELEPHONE: (303)692-3150 A � CONSTRUCTION PERMIT PERMIT NO: 1 1 WE34557 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 Garden Creek 11-18H, located in the SESE of Section 18, Township 11 North, Range 62 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Crude Oil Four (4) above ground 400 bbl atmospheric crude oil storage Storage 001 tanks. Emissions from these tanks are controlled by a Cimarron Tanks smokeless VCU unit with 95% control efficiency. One (1) above ground 400 bbl atmospheric produced water PW Tank 002 storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. One (1) 400 BBL fixed roof storage tank used to store gas in the ET #4234 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. Separator controlled by a 40' flare stack. Flare has a minimum Flare 004 combustion efficiency of 95%. The flare is not enclosed. Truck 005 Truck loadout of crude oil. Loadout 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 www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the AIRS ID: 123/9405/999 Page 1 of 13 Condensate Tank Version 2009-1 EOG Resources Inc ` olor ;' Depa en. if x .li Health and Environment Permit No. 11WE3457 _ i it Pollution Control Division Issuance 1 ' 2. 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. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 7.8 per year of volatile organic compounds (VOC), -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: • 100 tons per year of volatile organic compounds (VOC). 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) • AIRS ID: 123/9405/999 Page 2 of 13 s• k. •v hts •qD EOG Resources Inc r olora ,Depa en f Health and Environment Permit No. 11WE3457 * r Pollution Control Division -74 Issuance 1 t. Annual Limits: Facility AIRS Tons per Year Equipment ID Point NOx VOC CO Emission Type Crude Oil 001 --- 2.7 --- Point Storage Tanks PW Tank 002 --- 0.5 --- Point ET#4234 003 --- 5.5 --- Point Flare 004 4.8 66.8 26.3 Point Truck Loadout 005 --- 16.8 --- 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. 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. 8. 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.) 9, 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.) 10. 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.) 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) AIRS ID: 123/9405/999 Page 3 of 13 EOG Resources, Inc. olor Depa en rf li Health and Environment Permit No. 11WE3457 it Pollution Control Division Issuance 1 Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Crude Oil 001 Crude oil throughput 109,500 BBL/yr Storage Tanks PW Tank 002 Produced water throughput 73,000 BBL/yr ET#4234 003 Natural gas venting to atmosphere 414,000 SCF/yr Flare 004 Natural gas flaring 100.74 MMSCF/yr Truck Loadout 005 Crude oil and produced water loading 182,500 BBL/yr Compliance with the yearly throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate 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 005: 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: 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: AIRS ID: 123/9405/999 Page 4 of 13 EOG Resources, Inc. t '„< olo .O'., Depa err if t.li Health and Environment Permit No. 11WE3457 ° it Pollution Control Division Issuance 1 `< ' 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. 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. AIRS ID: 123/9405/999 Page 5 of 13 , SRtf N �' EOG Resources, Inc z olor 5'ir '1/4 $ Depar�r ern of P Ii&Health and Environment Permit No. 11WE3457 Air Pollution Control Division • Issuance 1 `` 21. Points 003 and 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self- certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: Ib benzene y, :b 7no.. al 1e6 se/ x' = benzene vit.1 rac.* k MW « MNsc; 375.3 sof 3 ib mod t4111scf. 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). ADDITIONAL REQUIREMENTS 23. 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. 24. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equal or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 25. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD AIRS ID: 123/9405/999 Page 6 of 13 EOG Resources, Inc $ olor Depa en .1 L.li .Health and Environment Permit No. 11WE3457 % ✓ 'it Pollution Control Division Issuance 1 threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 26. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 27. If this permit specifically states that final authorization has been granted,then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide"final"authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self-Certify for Final Authorization section of this permit. 28. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 29. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 30. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab inifio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 31. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 32. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal AIRS ID: 123/9405/999 Page 7 of 13 EOG Resources, Inc. oloR4kE f lic°Health and Environment Permit No. 11WE3457 it Pollution Control Division Issuance 1 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: (4) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank and crude oil loadout. New synthetic minor facility. AIRS ID: 123/9405/999 Page 8 of 13 EOG Resources, Inc. olor Depar en f li Health and Environment ' Permit No. 11WE3457 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/reo ulations/airreq s/100102agcccom mon 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 (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 1090 Yes 55 Toluene 108883 C 1044 Yes 52 Ethylbenzene 100414 C 166 No 8 001 Xylenes 1130207 C 370 No 19 n-Hexane 110543 C 5522 No 276 2,2,4- 540841 C 364 No 18 Trimethylpentane Benzene 71432 A 511 Yes 26 002 n-Hexane 110543 C 1606 Yes 80 Benzene 71432 A 45 No 45 Toluene 108883 C 32 No 32 003 Ethylbenzene 100414 C 5 No 5 Xylenes 1130207 C 10 No 10 n-Hexane 110543 C 215 No 215 Benzene 71432 A 10857 Yes 543 Toluene 108883 C 7714 Yes 386 004 Ethylbenzene 100414 C 1157 Yes 58 Xylenes 1130207 C 2539 Yes 127 n-Hexane 110543 C 52346 Yes 2617 Benzene 71432 A 316 Yes 316 005 Toluene 108883 C 955 No 955 AIRS ID: 123/9405/999 Page 9 of 13 w,e x e a $, .x•r .F .1 EOG Resources, Inc .tL, V , olor R Depai .' en f P •li 'Health and Environment Permit No. 11WE3457 r t 1 it Pollution Control Division • Issuance 1 • ti z, is , s 4 Ethylbenzene 100414 C 414 No 414 2,2,4- 540841 C 214 No 214 Trimethylpentane Xylenes 1130207 C 1040 Yes 1040 n-Hexane 110543 C 1407 Yes 1407 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 23.2524 1.1626 lb/1000 gal E&P Tanks lb/1000 gal 71432 Benzene 0.2370 lb/1000 gal 0.0119 lb/1000 gal E&P Tanks 108883 Toluene 0.2270 lb/1000 gal 0.0114 lb/1000 gal E&P Tanks 100414 Ethylbenzene 0.0361 lb/1000 gal 0.0018 lb/1000 qal E&P Tanks 1330207 Xylenes 0.0805 lb/1000 gal 0.0040 lb/1000 gal E&P Tanks 110543 n-hexane 1.2007 lb/1000 gal 0.0600 lb/1000 gal E&P Tanks 540841 2,2,4-TMP 0.0791 lb/1000 gal 0.0040 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 Garden Creek 6-11 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 002 are based on the combustor control efficiency of 95% Point 003: Emission Factors Weight Fraction of Source CAS# Pollutant Uncontrolled Gas (%) Lb/MMscf VOC 26570.0483 lb/MMscf 39.17 Engineering Calculation 71432 Benzene 107.7295 lb/MMscf 0.16 Engineering Calculation 108883 Toluene 76.5700 lb/MMscf 0.11 Engineering Calculation AIRS ID: 123/9405/999 Page 10 of 13 ti EOG Resources, Inc. olor Depa en f P li Health and Environment ' Permit No. 11WE3457 . • it Pollution Control Division - Issuance 1 ,n i Emission Factors Weight Fraction of Source CAS # Pollutant Uncontrolled Gas (%) Lb/MMscf Engineering 100414 Ethylbenzene 11.5942 lb/MMscf 0.02 Calculation Engineering 1330207 Xylenes 25.1208 lb/MMscf 0.04 a Calculation Engineering 110543 n-hexane 519.3237 lb/MMscf 0.77 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 11,500 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Garden Creek 6-11 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 (%) NOx --- 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42 CO --- 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42 VOC 39.17 26527.6951 1326.3848 Engineering lb/MMscf lb/mmscf Calculation PM10 AP-42, Table 40 ug/l 40 ug/l 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf lb/MMBtu lb/MMBtu 107.7735 5.3887 Engineering 71432 Benzene 0.16 lb/MMscf lb/mmscf Calculation 108883 Toluene 0.11 76.5684 3.8284 Engineering lb/MMscf lb/mmscf Calculation 100414 Ethylbenzene 0.02 11.4820 0.5741 Engineering lb/MMscf lb/mmscf Calculation 1330207 Xylenes 0.04 25.0548 1.2527 Engineering lb/MMscf lb/mmscf Calculation 519.6109 25.9805 Engineering 110543 n-hexane 0.77 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 Garden Creek 6-11 well. The controlled VOC and HAP emissions factors for point 004 are based on the flare control efficiency of 95%. Point 005: Emission Factors - Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.184 lb/BBL AP-42 71432 Benzene 0.0017 lb/BBL AP-42 108883 Toluene 0.0052 lb/BBL AP-42 AIRS ID: 123/9405/999 Page 11 of 13 ‘scEOG Resources, Inc �� k, °,olor Depa k' enf f ��,tt,licAHealth and Environment Permit No. 11WE3457 s„ ° it Pollution Control Division • Issuance 1 Emission Factors - Uncontrolled CAS Pollutant lb/BBL loaded Source 100414 Ethylbenzene 0.0023 lb/BBL AP-42 1330207 Xylenes 0.0057 lb/BBL AP-42 110543 n-hexane 0.0077 lb/BBL AP-42 540841 2,2,4-TMP 0.0012 lb/BBL AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.96 psia M (vapor molecular weight) = 51.42 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. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on October 11,2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source VOC, n-hexane, total HAPS 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 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 AIRS ID: 123/9405/999 Page 12 of 13 EOG Resources, Inc. olor Depai en f P lic Health and Environment Permit No. 11 WE3457 it Pollution Control Division Issuance 1 `' 1 saeta 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/oilqaspermittind.html AIRS ID: 123/9405/999 Page 13 of 13 • Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3433 Source Location: NWNW S10, T9N, R58W, Weld County (Attainment) Point 001: Crude oil truck loadout Point 002: Plant flare with a minimum combustion efficiency of 95%. Point 003: (1)400 BBL above ground atmospheric emergency storage Equipment Description: tank for vented gas. Point 004: (1) 400 BBL above ground atmospheric produced water storage tank. Point 005: (6)400 BBL above ground atmospheric crude oil storage tanks AIRS ID: 123-9392 Date: January 17, 2012 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, when did you mail an Information Request letter to the source? On what date was this application complete? September 28, 2011 Section 4—Source Description AIRS Point Equipment Description 001 Truck loadout of crude oil. Separator controlled by a 40' flare stack. Flare has a minimum combustion 002 efficiency of 95%. The flare is not enclosed. 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. One (1) above ground 400 bbl atmospheric produced water storage tank. 004 Emissions from this tank are controlled by a combustor(VCU)with a minimum destruction efficiency of 95%. Page 1 Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from 005 these tanks are controlled by a Cimarron smokeless combustor(vapor combustion unit)with 95% control efficiency. 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 004: 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 004: 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 004: 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 AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 001 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] 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) 004 CDPHE Emission Factors (PS Memo 09-02) 005 Site-specific using E&P Tanks (Refer to Section 14 for calculations) 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 001 171,500 BBL per year crude oil loaded 002 255,000 scf/day => 93,075,000 scf/yr= 93.075 mmscf/yr 003 525,000 scf/yr=> 0.525 MMSCF/yr 004 74,460 BBL per year(62050 x 1.2) 005 131400 BBL per year(109500 x 1.2) Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) Page 2 AIRS Point Process Consumption/Throughput/Production Data Year 001 171,500 BBL per year crude oil loaded 002 255,000 scf/day => 93,075,000 scf/yr= 93.075 mmscf/yr 003 525,000 scf/yr=> 0.525 MMSCF/yr 004 62,050 BBL per year(62050 x 1.2) 005 109,500 BBL per year 2011 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 171,500 BBL per year crude oil loaded 002 255,000 scf/day => 93,075,000 scf/yr= 93.075 mmscf/yr 003 525,000 scf/yr=> 0.525 MMSCF/yr 004 62,050 BBL per year(62050 x 1.2) 005 109,500 BBL per year Does this facility use control devices? X Yes No AIRS Point Process Control Device Description °/0 Reduction Granted 002 01 Tornado 40' flare stack 95 004 01 Cimarron smokeless combustor(VCU) 95 005 01 Cimarron smokeless combustor(VCU) 95 Page 3 Section 6—Emission Summary (tons per year) ' Point NO, VOC CO SOx PM10 Single HAP HAP Total 0.4 001 --- 8.9 --- --- -- (n-hexane) 1.0 002 4.9 1565.2 26.7 0.03 1.2 21.4 (n- 29.1 hexane) PTE: --- --- -- 0.1 0038.8 - (n-hexane) 0.2 004 --- 9.8 --- --- 0.8 (n-hexane) 1.1 005 -- 8.6 --- --- 0.4 (n-hexane) 0.5 0.4 001 8.9 (n-hexane) 1.0 Uncontrolled point 002 4.9 1565.2 26.7 0:03 1.2 21.4 (n- 29 1 source emission rate: hexane) 0.1 003 --- 8.8 --- -- --- (n-hexane) 0.2 004 --- 8.1 --- --- --- 0.7 (n-hexane) 0.9 005 --- 7.1 --- --- 0.3 (n-hexane) 0.4 TOTAL (TPY) 4.9 1598.1 26.7 --- --- 22.9 (n- 31.6 hexane) 0.4 001 --- --- -- 8.9 (n-hexane) 1.0 002 4.9 78.3 26.7 0.03 1.2 1.1 (n-hexane) 1.5 Controlled point 003 --- 8.8 --- --- 0.1 0.2 source emission rate: (n-hexane) 004 --- 0.4 --- --- 0.03 (n- 0.4 hexane) 005 --- 0.4 --- --_ 0.02 (n- 0.02 hexane) INSIGNIFICANTS 0.14 (n- (TPY) 0.3 1.5 0.4 --- --- hexane) 0.17 TOTAL PERMITTED 4.9 96.8 26.9 0.03 1.2 1.8 (n-hexane) 3.1 (TPY) Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable? Rate(Iblyr) Point 001 Benzene 71432 A 119 Yes 119 Toluene 108883 C 391 No 391 Ethylbenzene 100414 C 29 No 29 Xylenes 1130207 C 520 No 520 n-Hexane 110543 C 712 No 712 2,2,4-Trimethylpentane 540841 C 151 No 151 Point 002 Benzene 71432 A 6981 Yes 349 Toluene 108883 C 5272 Yes 264 Ethylbenzene 100414 C 886 No 44 Page 4 . Xylenes 1130207 C 2190 Yes 110 n-Hexane 110543 C 42799 Yes 2140 Point 003 Benzene 71432 A 39 No 39 Toluene 108883 C 30 No 30 Ethylbenzene 100414 C 5 No 5 Xylenes 1130207 C 12 No 12 n-Hexane 110543 C 241 No 241 Point 004 Benzene 71432 A 434 Yes 22 n-Hexane 110543 C 1365 Yes 68 Point 005 Benzene 71432 A 92 Yes 5 Toluene 108883 C 82 No 4 Ethylbenzene 100414 C 2 No 0 2,2,4-Trimethylpentane 540841 C 52 No 3 Xylenes 1130207 C 30 No 2 n-Hexane 110543 C 618 No 31 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 002 01 NOx CO Regulation No. 3, Part B., Section III.G.3 Stack test 002 01 Opacity Regulation No. 1, Section II.A.5 Method 9 003 01 VOC, State only requirement Site-specific gas HAPS analysis Site-specific 005 01 VOC CDPHE PS Memo 05-01 sampling Section 9 —Source Classification Is this a new previously un-permitted source? 001 002 003 004 005 YES X X X X X NO What is this point classification? True Minor X X X X Synthetic Minor X Page 5 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 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, 001-005 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 001-005 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. Page 6 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 001-005 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 001 nonattainment or attainment/maintenance areas. This source is not 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 001-005 Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section 11.D.3.a) Re ulation 6 - New Source Performance Standards 001-005 pre 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. Regulation 8— Hazardous Air Pollutants 001-005 None Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 0.104 lb/BBL V0C No AP-42 0 0.0007 Benzene No AP-42 0 lb/BBL 0.0023 Toluene No AP-42 0 lb/BBL 01 Truck Crude oil Loadout 0.0002 001 lb/BBL Ethylbenzene No AP-42 0 0.0030 Xylenes No AP-42 0 lb/BBL 0.0042 n-hexane No AP-42 0 lb/BBL SCC 4060132: Crude Oil: Submerged Loading (Normal Service) 33633.0916 V0C No Engineering 95 lb/MMscf Calculation 0.068 N0x No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 75.0083 Benzene No Engineering 95 lb/MMscf Calculation 01 Flare 002 56.6371 Toluene No Engineering 95 Ib/MMscf Calculation 9.5224 Ethlybenzene No Engineering 95 Ib/MMscf Calculation 23.5251 X lenes No Engineering y 95 Ib/MMscf Calculation 459.8313 n-hexane No Engineering 95 Ib/MMscf Calculation SCC 31000205-Flares Page 7 33523.8095 Engineering Ib/MMscf VOC No Calculation 0 75.0476 Engineering lb/MMscf Benzene No Calculation 0 56.5714 Engineering 01 Gas Storage Tank lb/MMscf Toluene No Calculation 0 003 9.5238 Ethlybenzene No Engineering 0 lb/MMscf Calculation 23.4286 Engineering lb/MMscf Xylenes No Calculation 0 459.4286 n-hexane No Engineering 0 lb/MMscf Calculation SCC 40400152-Vapor collection losses 6.2381 CDPHE PS lb/1000 gal VOC No Memo 09-02 95 throughput Produced water 0.1667 CDPHE PS 01 lb/1000 gal Benzene No 95 004 storage tanks throughput Memo 09-02 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 3.1050 VOC No E&P Tanks 95 lb/1000 gal 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 0.0200 Benzene No E&P Tanks 95 lb/1000 gal 01 Crude oil Storage Tanks 0.0178 Toluene No E&P Tanks 95 005 lb/1000 gal • 0.0004 Ethylbenzene No E&P Tanks 95 lb/1000 gal 0.0065 Xylenes No E&P Tanks 95 lb/1000 gal 0.1344 n-hexane No E&P Tanks 95 lb/1000 gal 0.0113 2 2,4-TMP No E&P Tanks 95 lb/1000 gal SCC 40400301 —Fixed Roof Tank, Oil field storage of crude, breathing losses • Page 8 Section 14— Miscellaneous Application Notes AIRS Point 001 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 T 524 deg. R L 2.471b/10^3 gal 1.04E-01 lb/bbl Annual requested Throughput 7203000ga1/yr Annual requested VOC emissions 177961b/yr 8.90tpy Benzene = (119.34 Ib/yr) / (171500) = 0.0007 lb/bbl Toluene = (390.80 Ib/yr) / (171500) = 0.0023 lb/bbl Ethylbenzene = (28.79 Ib/yr) / (171500) = 0.0002 lb/bbl Xylenes = (519.89 Ib/yr) / (171500) = 0.0030 lb/bbl n-hexane = (712.37 Ib/yr)/ (171500) = 0.0042 lb/bbl 2,2,4-TMP = 151.08 lb/yr) / (171500) = 0.0009 lb/bbl AIRS Point 002 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 = (1565.2 TPY *2000 lb/T)/(93.075 lb/mmscf) = 33633.0916 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/l) Benzene = (6981.4 Ib/yr) / 93.075 mmscf/yr= 75.0083 lb/mmscf Toluene = (5271.5 Ib/yr) / 93.075 mmscf/yr= 56.6371 lb/mmscf Ethylbenzene = (886.3 Ib/yr) /93.075 mmscf/yr= 9.5224 lb/mmscf Xylenes= (2189.6 Ib/yr) / 93.075 mmscf/yr= 23.5251 lb/mmscf n-hexane = (42798.8 Ib/yr) / 93.075 mmscf/yr= 459.8313 lb/mmscf 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. (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 = (8.8 TPY *2000 lb/T)/(0.525 mmscf/yr) = 33523.8095 lb/mmscf Benzene = (39.4 Ib/yr)/(0.525 mmscf/yr) = 75.0476 lb/mmscf Toluene = (29.7 Ib/yr)/ (0.525 mmscf/yr) = 56.5714 lb/mmscf Ethylbenzene = (5.0 Ib/yr) / (0.525 mmscf/yr) = 9.5238 lb/mmscf Xylenes = (12.3 Ib/yr) / (0.525 mmscf/yr) = 23.4286 lb/mmscf n-hexane = (241.2 Ib/yr) / (0.525 mmscf/yr) =459.4286 lb/mmscf Page 9 AIRS Point 004 Produced water 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 accepts Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. AIRS Point 005 Crude oil storage tanks Site-specific emission factor using E&P Tanks: VOC = (7.140 TPY*2000) / 109500 bbl/yr= 0.1304 lb/bbl *1000/42 = 3.1050 lb/1000 gal Benzene = (0.046 TPY * 2000) / 109500 bbl/yr= 0.0008 lb/bbl * 1000/42 = 0.0200 lb/1000 gal Toluene = (0.041 TPY*2000) / 109500 bbl/yr= 0.0007 lb/bbl * 0.0178 lb/1000 gal Ethylbenzene = (0.001 TPY "2000)/ 109500 bbl/yr= 0.00002 lb/bbl " 1000/42 = 0.0004 lb/1000 gal Xylenes = (0.015 TPY *2000) / 109500 bbl/yr= 0.0003 lb/bbl * 1000/42 = 0.0065 lb/1000 gal n-hexane = (0.309 TPY*2000)/ 109500 bbl/yr= 0.0056 lb/bbl * 1000/42 = 0.1344 lb/1000 gal 2,2,4-TMP = (0.026 TPY *2000) / 109500 bbl/yr= 0.0005 lb/bbl * 1000/42 = 0.0113 lb/1000 gal Facility-wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and is a synthetic minor source for VOC, PSD, n-hexane and total HAPS. Page 10 N O d L. 3 3 3 3 3 L. 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O '� :�. e 4. a u N d u UCee, H ^ v m A w e 8 c o ._. 2 > .R > 0 E w' , & 4.,fl u("e 41 elite; ._, 0 A Vi rn U e A v m w v o' m U 4r -tt o a I v v n I . = - Ay o t. 6 o O ell; 1 o >a, v 0 U N 0. c o f ._`°. x U u 0 c c o ¢ , 0 0 �:z u g o U F F ;ad `n w' Q C W O O g c : 5, axi "' q / arn8 6 _ G t a�0, z > wv T X $ o "" Any ki o I t5 W` ❑ ❑ ) 0 . =pa u .m o vl W 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 l that a ply) - ^ Reason for APEN Submittal(Check all that apply) AIRS ID#': 11�j 9392 s.1c-2 ❑ APEN update only° ® New or previously unreported b : 44 r O Modification to existing source` O Previously grandfathered batter . - O, O Registration for coverage under general permit no.GPOI O Synthetic minor facility ��g$. t� &cancellation request for individual permits: ❑ Located in the 8-hr-Ozone Cont ol:At`?A"J�r c:t' l[I,Ji3 ® Application for or Modification of an individual permit ❑ Registered under general permit no GPOI,' O Administrative permit amendment' ❑ Permitted under individual permit: b:�_,,.r O Other: For individual permit applications,check if you wane O A copy of the preliminary analysis conducted by the Division O To review a draft of the permit prior to issuance Company Name9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address1s: 600 17°i Street,Suite 1000N david_long@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303-262-9448 Fax: 303-262-9449 Tank Battery Name'': Fiscus Mesa 9-I0H - Number of tanks: 6 • Location'(QQ Sec.Twp.Range.): NWNW Sec 10,T9N,R58W County: Weld Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies": 2011 Year(s)tank(s)were placed in service": 2011 Control Description': Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency's: 95% Condensate Throughput°[bbl/year] Requested'": 109,500 Maximum for PTE calculation'': 131,400 Actual2s: 109,500 While Controls Operational'' 109,500 Other equipment at facility'-: VCU,flare,heater treater,generator engine,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GP01 coverage. Therefore,an individual permit is being requested. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit O Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions's. Emission Factor Battery Requested Emissions's Actual Emissions'-° Pollutant's • [lb/bbl] PTE Uncontrolled's Controlled'' Uncontrolled's Controlled'? VOC[tons/year] 0.1304 8.6 N/A N/A 7.1 0.36 NOx[tons/year] N/A 0.03 0.03 0.03 CO[tons/year] N/A 0.14 - 0.14 0.14 Benzene[lbs/year] 96.0 4.8 n-Hexane[lbs/year] 644.0 32.2 Wells serviced by this tank or tank battery's API#: 05-123-33065-00 Name: Fiscus Mesa 9-I0H ®Newly Reported Well • API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well l— API#: Name: O Newly Reported Well iv j' API#: Name O Newly Reported Well wti- API#: Name: O Newly Reported Well rr n�i API#: Name: , O Newly Reported Well 1 co 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 Ymy knowledge and belief. If this is a registr n for coverage under general permit GPOI,I further certify that this source is and will be operated ro in full complianc ondition gf eral permit GPOI. NSignature of Legal] ied a vendor or consultant) Date 1" r David I Division Environmental Manager n- 1 to pc_or-RI:int:4 n Signing Above Official Title to tv Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: m filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 S 77.-s„, (303)692-3150 o $250 General Permit fee for each new GP 4300 Cherry Creek Drive South rr triQ� 1J registration to: Denver,CO 80246-1530 F - ) FORM APCD-205 263420 Page 1 of 2 EOG FM 9-10H FormAPCD-205-E&PCondensateTankAPEN.docx N • T g k M7. STATE OF COLORADO Inata of•ao COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT •Pi AIR POLLUTION CONTROL DIVISION R � � TELEPHONE: (303)692-3150 * '>• ^'�* '18764- C ONSTRUC TION PERMIT PERMIT NO: 11 WE3433 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 Fiscus Mesa 9-10H, located in the NWNW of Section 10, Township 9 North, Range 65 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Truck 001 Truck loadout of crude oil. Loadout Separator controlled by a 40' flare stack. Flare has a minimum Flare 002 combustion efficiency of 95%. The flare is not enclosed. One (1) 400 BBL fixed roof storage tank used to store gas in the ET #4609 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. One (1) above ground 400 bbl atmospheric produced water PW Tank 004 storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. Crude Oil Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Storage 005 Emissions from these tanks are controlled by a Cimarron Tanks smokeless VCU unit with 95% control efficiency. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. 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 www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the AIRS ID: 123/9392/999 Page 1 of 13 Condensate Tank Version 2009-1 EOG Resources, Inc 't 00 olor 01 Depar, ens if lic Health and Environment Permit No. 11WE3433 j it Pollution Control Division Issuance 1 rP x! h ,„P,.. 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. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment,which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 3.2 per year of volatile organic compounds (VOC), _OR_ Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: • 100 tons per year of volatile organic compounds (VOC). 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) AIRS ID: 123/9392/999 Page 2 of 13 za +p a N �o-a a.y ua3�t'15EOG Resources, Inc. ) ',olor s `,Depaiµ en f P3bli `Health and Environment Permit No. 11WE3433 ,� h a,� 'Air Pollution Control Division Issuance 1 is Is f µ Annual Limits: Facility AIRS Tons per Year Equipment ID Point NO„ VOC CO Emission Type Truck Loadout 001 --- 8.9 --- Point Flare 002 4.9 78.3 26.7 Point ET#4609 003 --- 8.8 --- Point PW Tank 004 --- 0.4 --- Point Crude Oil 005 --- 0.4 --- Point Storage Tanks See "Notes to Permit Holder#4"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 8. Point 002: 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 004: 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 005: 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.) 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) AIRS ID: 123/9392/999 Page 3 of 13 441 EOG Resources, Inc. • E "olora Depar nen of P lic Health and Environment Permit No. 11 WE3433 r Pollution Control Division Issuance 1 Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Truck Loadout 001 Crude oil and produced water loading 171,500 BBL/yr Flare 002 Natural gas flaring 93.075 MMSCF/yr ET#4609 003 Natural gas venting to atmosphere 525,000 SCF/yr PW Tank 004 Produced water throughput 62,050 BBL/yr Crude Oil 005 Crude oil throughput 109,500 BBLJyr Storage Tanks 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 004: 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 001: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Points 002, 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 004: AIRS ID: 123/9392/999 Page 4 of 13 r rag, EOG Resources, Inc olor 3�� Depa 4 en( ‘f P).lic'Health and Environment Permit No. 11WE3433 a � 1 k it Pollution Control Division Issuance 1 aisz 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. (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. 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 AIRS ID: 123/9392/999 Page 5 of 13 EOG Resources, Inc. olora, Depa en, f P Iic Health and Environment Permit No. 11WE3433 Air Pollution Control Division Issuance 1 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 nn-ins :b mot. lb leb scr bax = benzene wt.frac.,, Llll' :.r5lscf 379.3 scf jes tb mot. l:dht Sic" . 21. Point 002: 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). 22. Point 005: 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. ADDITIONAL REQUIREMENTS 23. 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. 24. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equal or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 25. Prevention of Significant Deterioration (PSD) requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet AIRS ID: 123/9392/999 Page 6 of 13 x . EOG Resources, Inc. olora Depa; en r li Health and Environment Permit No. 11 WE3433 it Pollution Control Division Issuance 1 commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS 26. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 27. If this permit specifically states that final authorization has been granted,then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide"final"authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self-Certify for Final Authorization section of this permit. 28. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 29. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 30. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 31. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 32. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, 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: 123/9392/999 Page 7 of 13 3t r EOG Resources, Inc A olora' Depai' en f li Health and Environment Permit No. 11 WE3433 g .€" F q Air Pollution Control Division Issuance 1 x `3 tat �r'l '1TtOF! .m� I .rvp:h By: Stephanie Chaousy, PE Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for: (6) crude oil tanks and VCU, (1) emergency tank, (1) tornado flare, (1) produced water tank and crude oil loadout. New synthetic minor facility. AIRS ID: 123/9392/999 Page 8 of 13 EOG Resources, Inc. ki r4 olora: Depa . en 3f P bli Health and Environment Permit No. 11WE3433 t.: it Pollution Control Division Issuance 1 ; .: ass: ;e Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/requlations/airregs/100102agcccommonprovisionsreq.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (Ib/yr) reportable? Rate (lb/yr) Benzene 71432 A 119 Yes 119 Toluene 108883 C 391 No 391 Ethylbenzene 100414 C 29 No 29 001 Xylenes 1130207 C 520 No 520 n-Hexane 110543 C 712 No 712 2'2'4 540841 C 151 No 151 Trimethylpentane Benzene 71432 A 6981 Yes 349 Toluene 108883 C 5272 Yes 264 002 Ethylbenzene 100414 C 886 No 44 Xylenes 1130207 C 2190 Yes 110 • n-Hexane 110543 C 42799 Yes 2140 Benzene 71432 A 39 No 39 Toluene 108883 C 30 No 30 003 Ethylbenzene 100414 C 5 No 5 Xylenes 1130207 C 12 No 12 n-Hexane 110543 C 241 No 241 Benzene 71432 A 434 Yes 22 004 n-Hexane 110543 C 1365 Yes 68 Benzene 71432 A 92 Yes 5 005 Toluene 108883 C 82 No 4 AIRS ID: 123/9392/999 • Page 9 of 13 EOG Resources, Inc. olor Depar en f P id Health and Environment Permit No. 11WE3433 Jr Pollution Control Division Issuance 1 Ethylbenzene 100414 C 2 No 0 2,2,4- 540841 C 52 No 3 Trimethylpentane Xylenes 1130207 C 30 No 2 n-Hexane 110543 C 618 No 31 4) The emission levels contained in this permit are based on the following emission factors: Point 001: 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 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 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 002: Weight Emission Emission Fraction Factors Factors CAS # Pollutant of Gas Uncontrolled Controlled Source (°/0) NOx --- 0.068 Ib/MMBtu 0.068 lb/MMBtu AP-42 CO --- 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42 VOC 46.18 33633.0916 1681.6546 Engineering lb/MMscf lb/mmscf Calculation PM o AP-42, Table 40 ug/l 40 uq/l 13.5-1 SOx 0.00036 0.00036 0.002 gr/scf lb/MMBtu lb/MMBtu 71432 Benzene 0.10 75.0083 3.7504 Engineering lb/MMscf lb/mmscf Calculation 108883 Toluene 0.08 56.6371 2.8319 Engineering lb/MMscf lb/mmscf Calculation AIRS ID: 123/9392/999 Page 10 of 13 EOG Resources, Inc. olj_J0raDeP] n 3fJir Health and Environment Permit No. 11WE3433 i. Pollution Control Division Issuance 1 Weight Emission Emission Fraction Factors ,Factors CAS# Pollutant of Gas Uncontrolled Controlled Source (%) 100414 Ethylbenzene 0.01 9.5224 lb/MMscf 0.4761 Engineering lb/mmscf Calculation 23.5251 1.1763 Engineering 1330207 Xylenes 0.03 lb/MMscf lb/mmscf Calculation 110543 n-hexane 0.63 459.8313 22.9916 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 002 are based on the flare control efficiency of 95%. Point 003: Emission Factors Weight Fraction of Source CAS # Pollutant Uncontrolled Gas (%) Lb/MMscf Engineering VOC 33523.8095 lb/MMscf 46.18 Calculation Engineering 71432 Benzene 75.0476 lb/MMscf 0.10 Calculation Engineering 108883 Toluene 56.5714 lb/MMscf 0.08 Calculation Engineering 100414 Ethylbenzene 9.5238 lb/MMscf 0.01 Calculation 1330207 Xylenes 23.4286 lb/MMscf 0.03 Engineering Calculation 110543 n-hexane 459.4286 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 14,583.3 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well (weight percents for VOC and HAP components from this analysis are listed in the table above). Point 004: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source Ib/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 004 are based on the combustor control efficiency of 95% AIRS ID: 123/9392/999 Page 11 of 13 EOG Resources, Inc <, olor- Depar ent of fr i Health and Environment Permit No. 11WE3433 fK, Pollution Control Division • Issuance 1 � rPoint 005: 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 3.1050 lb/1000 gal 0.1553 lb/1000 gal E&P Tanks 71432 Benzene 0.0200 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 108883 Toluene 0.0178 lb/1000 gal 0.001 lb/1000 gal E&P Tanks 100414 Ethylbenzene 0.0004 lb/1000 gal 0.00002 lb/1000 gal E&P Tanks 1330207 Xylenes 0.0065 lb/1000 gal 0.0003 lb/1000 gal E&P Tanks 110543 n-hexane 0.1344 lb/1000 gal 0.0067 lb/1000 gal E&P Tanks 540841 2,2,4-TMP 0.0113 lb/1000 gal 0.0006 lb/1000 gal E&P Tanks Note: The controlled emissions factors for point 005 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 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on September 27,2016. 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 Synthetic Minor Source VOC, n-hexane, total HAPS 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: hap://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 SubpartA—SubpartZ MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP AIRS ID: 123/9392/999 Page 12 of 13 EOG Resources Inc tt i° 2Color4 _jEi.__Jr Jt Deprent of P blic'Health and Environment Permit No. 11 WE3433 * Pollution Control Division acs 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 XXXX(X 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/oiloaspermittinghtml AIRS ID: 123/9392/999 Page 13 of 13 Hello