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Home My WebLink About20162045.tiff;COLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 June 21, 2016 Dear Sir or Madam: On June 30, 2016, the Air Pollution Control Division will begin a 30 -day public notice period for Noble Energy - LD22-A Econode. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure Pc) (0l vI CD/ 9q Cc v P L i-1 L, w 2016-2045 Qof9C4f1Cs, tJ 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.govicdphe ,; John 'N. Hickenlooper. Governor Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer r Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy - LD22-A Econode - Weld County Notice Period Begins: June 30, 2016 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy Facility: LD22-A Econode Exploration and Production Facility (Econode) SWSE SEC22 T9N R58W Weld County The proposed project or activity is as follows: The applicant proposes to permit a new Econode in Weld County. The permitted pieces of equipment will include condensate storage tanks, produced water storage tanks, loadout operations, separator venting, and 2 RICE engines used for power generation. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section 111.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 16WE0546 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: David V Thompson Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 k� =J '.QA a1�0 16WE0546 Construction Permit Air Pollution Control Division Permit number: Date issued: Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: Noble Energy, Inc. LD22-A Econode 123/9E77 SWSE Section 22 T9N R58W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description LP VOC Flare 004 One Open Flare to control LP Separator Vapors if VRU goes down Open Flare VRT VOC Burners 005 Enclosed flares to control VRT Vapors Enclosed Flares Tank Battery 006 Eight (8) 500 bbl tanks used for the storage of Condensate Enclosed Flares Produced Water 007 Three (3) above ground produced water storage tanks Enclosed Flare Truck Loadout 008 Hydrocarbon Loadout to Tanker Trucks Enclosed Flares GEN1 009 One (1) Doosan, D8.1L, EEPOG301883, Turbo - Charged, 4SRB reciprocating internal combustion engine, site rated at 239 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 and/or peaking power. non -selective catalytic reduction (NSCR) system GEN2 010 One (1) Doosan, D8.1L, EEPOG301546, Turbo - Charged, 4SRB reciprocating internal combustion engine, site rated at 239 horsepower at 1800 RPM. This engine shall be equipped with an oxidation non -selective catalytic reduction (NSCR) 1 ar Page 1 of 18 to !' st and •''_ -fuel ratio control/non-selective y `iredu i n (NSCR) system and air -fuel ratio control/This engine is not equipped with emission controls. 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 and/or peaking power. system Point 009 and 010: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Doosan D8.1L engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific 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 Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. Points 004 and 005: Within one hundred eighty (180) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas flared from the low pressure separators and vapor recovery towers. The operator shall use the gas flow rate listed in the application for actual flow rate, assuming 5% downtime, until the flow meter is installed, not to exceed one hundred and eighty (180) days after issuance of this permit 4. 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. (Regulation Number 3, Part B, Section III.F.4.) 5. 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. (Regulation Number 3, Part B, Section III.E.) COLORADO Pollution Control Division Page 2 of 18 he 6. Th op raf sti ll retainthe perr final authorization letter issued by the Division, after "' tompre idn oteetf-c2tfffftaton, Wtrthe most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOx VOC CO LP VOC Flare 004 1.1 14.4 2.7 Point VRT VOC Burners 005 Point Tank Battery 006 0.0 1.1 9.3 1.8 Point Produced Water 007 2.7 Point Truck Loadout 008 4.3 Point GEN1 009 2.4 1.7 4.7 Point GEN2 010 2.4 1.7 4.7 Point Note: See "Notes to Permit Holder" for information on emission limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 11. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Conttolled LP VOC Flare 004 Open Flare VOC and HAP VRT VOC Burners 005 Enclosed Flares VOC and HAP Tank Battery 006 Enclosed Flares VOC and HAP COLORADO Air Pollution Control Dnizton Page 3 of 18 r�,," Water Enclosed Flares VOC and HAP Truck Loadout 008 Enclosed Flares VOC and HAP GEN1 009 Catalytic Reducer air/fuel ratio controller r CO a NOX GEN2 010 Catalytic Reducer air/fuel ratio controller CO Et NOX PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit LP VOC Flare 004 Total Gas Vented from alt Low- Pressure Separators and Vapor 7.9 MMscf/yr VRT VOC Burners 005 Recovery Towers (VRTs) to flare Tank Battery 006 Condensate Throughput 700,000 barrels Produced Water 007 Produced Water Throughput 400,000 barrels Truck Loadout 008 Oil Loaded 700,000 barrels GEN1 009 Fuel Consumption 9.41 MMscf/yr GEN2 010 Fuel Consumption 9.41 MMscf/yr Compliance with the annua 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 throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. , 13. Points 004 and 005: Upon installation of the flow meter required under Condition 3, the owner or operator shall continuously monitor and record the volumetric flowrate, using flow meters, of gas vented from the low pressure separators to the open flare and gas vented from the VRTs to the enclosed flare. Flow meters shall continuously measure flowrate and record total volumetric flow vented to the flare(s) from the low-pressure separators and from the VRTs. The owner or operator shall use the sum of monthly throughput records for the low pressure separator gas routed to flare and VRT gas routed to flare to demonstrate compliance with the limits specified in Condition 12 and to calculate emissions as described in this permit. 14. Point 008: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) STATE AND FEDERAL REGULATORY REQUIREMENTS 15. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) COLORADO Pollution Control Division Page 4 of 18 F p 16. Thy° pit. fulf�tls t� re��uueme rto hold a valid permit reflecting the storage tank and associa`t`28 t`b�i"tr'bl �dVScrs`u�er thy`"''Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 17. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 18. Point 006, 007: This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate storage tanks; and Ensure that the combustion device controlling emissions from this storage tank 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 combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 19. Points 005, 006, 007: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 20. Point 004: The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must be used as a backup to VRU, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto -igniter according to the following schedule: All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 21. Point 004, 005: The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 22. Point 006: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control COLORADO An Pollution Control Division Page 5 of 18 vice is used, it must have a design destruction efficiency at :r hons =.t where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 23. Point 006, 007: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. 24. Point 008: The owner or operator shalt follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect onsite loading equipment during loading operations to monitor compliance with above conditions. The inspections shalt occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 25. Point 008: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. OPERATING & MAINTENANCE REQUIREMENTS 26. Upon startup of these points, the owner or operator shall follow the most recent 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) 27. Point 008: The owner or operator of a loadout at which emissions are controlled shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs 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. COLORADO Pollution Control Division Page 6 of 18 an'�Nial spectionA of thief hatch seals and PRD with an indication of status, ion`6fibtil problenirtound, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. Point 004, 005, 006: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) 29. AIRS ID 004 and 005: The operator shall complete initial site specific extended gas analyses of the gas vented from the low pressure separators and of gas vented from the VRTs in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane, and 2,2,4- trimethylpentane content (weight fraction) of these emission streams. Results of testing shall be used to calculate site -specific emission factors for the pollutants referenced above (in units of lb/MMSCF gas vented) using Division approved methods. Results of site -specific sampling and emissions factor analysis shall be submitted to the Division as part of the self -certification and used to determine actual emissions. Periodic Testing Requirements 30. Points 009 and 010: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (OEM) plan as approved by the Division. Revisions to your OEM 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 31. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30`" whenever a significant increase in emissions occurs as follows: For any criteria pollutant: r 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 volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator activity; or COLORADO Au Pollution Control Division whichever is less, above the of any facility, process, or Page 7 of 18 rol equi ent is installed, or whenever a different type of control equi." en rep :ces an exi ing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 32. Federal regulatory program requirements (i.e. PSD, NANSR) 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 Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 33. 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 Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 34. 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 Number 3, Part B, Section M.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. 35. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator 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 owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 36. 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. 37. 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 owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 38. 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. 39. 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 COLORADO Are Pollution Control Division Page 8 of 18 n 5'rceb ern` . acpionsiDndS Sectio 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalf`les7 'fi72a(dieri'at"penaltiei C.R.S. By: David Thompson Permit Engineer rmit Elisto Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. COLORADO Air Pollution Control Entonon Page 9 of 18 No this -.' ,. it issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 12) 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 owner or operator 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 complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator 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: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 004 Benzene 71432 1208 Yes 61 004 n -Hexane 110543 7892 Yes 395 004 Toluene 108883 133 No 7 004 Ethylbenzene 100414 110 No 6 004 Xylenes 1330207 372 Yes 19 005 ; Benzene 71432 403 Yes 21 005 n -Hexane 110543 2548 Yes 128 005 Toluene 108883 40 No 2 005 Ethylbenzene 100414 30 No 2 005 Xylenes 1330207 99 No 5 006 Benzene 71432 939 Yes 47 006 n -Hexane 110543 5839 Yes 292 006 Toluene 108883 88 No 5 006 Ethylbenzene 100414 62 No 4 006 Xylenes 1330207 201 No 11 006 2,2,4-TMP 350 Yes 18 007 Benzene 71432 2800 Yes 140 007 n -Hexane 110543 8800 Yes 440 COLORADO it Pollution Control Division Page 10 of 18 0A# Benue_ 71432lµ.; 426 Yes 21 008 n -Hexane 110543 2647 Yes 132 008 Toluene 108883 40 No 2 008 Xylenes 1330207 91 No 5 008 2,2,4-TMP 308 Yes 15 009 Benzene 71432 22 No 22 009 Formaldehyde 50000 281 Yes 281 010 Benzene 71432 22 No 22 010 Formaldehyde 50000 281 Yes 281 5) The emission levels contained in this permit are based on the following emission factors: Point 004: Pollutant Weight Fraction of Gas (%) Emission Factors Uncontrolled lb/MMscf Emission Factors Controlled lb/MMscf Source NOx (lb/MMBTU) 0.068 0.068 AP -42 CO (lb/MMBTU) 0.37 0.37 AP -42 VOC 68.87 66840.75 3342.0375 Gas Analysis Benzene 0.19 187.56 9.378 Gas Analysis Toluene 0.021 20.61 1.0305 Gas Analysis Ethylbenzene 0.017 16.96 0.848 Gas Analysis Xylenes 0.06 57.71 2.8855 Gas Analysis n -hexane 1.26 1225.64 61.282 Gas Analysis r Point 005: Pollutant Weight Fraction of Gas (%) Emission Factors Uncontrolled lb/MMscf Emission Factors Controlled lb/MMscf Source NOx (lb/MMBTU) 0.068 0.068 AP -42 CO (lb/MMBTU) 0.37 0.37 AP -42 VOC 84.066 100429.09 5021.4545 Gas Analysis Benzene 0.234 280.12 14.006 Gas Analysis Toluene 0.023 27.81 1.3905 Gas Analysis Ethylbenzene 0.017 20.72 1.036 Gas Analysis Xylenes 0.058 68.95 3.4475 Gas Analysis n -hexane 1.486 1775.11 88.7555 Gas Analysis COLORADO An' Pollution Convol Division Page 11 of 18 Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Source V0C 0.5308 Hysis/AP-42 n -Hexane 0.0083 Hysis/AP-42 Benzene 0.0013 Hysis/AP-42 Toluene 0.0001 Hysis/AP-42 Ethylbenzene 0.0001 Hysis/AP-42 Xylenes 0.0003 Hysis/AP-42 Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 007: Pollutant Emission Factors Uncontrolled lb/BBL Produced Water Throughput Source V0C 0.262 CDPHE n -Hexane 0.022 CDPHE Benzene 0.007 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 008: Pollutant Emission Factors Uncontrolled lb/BBL loaded - Source V0C 0.2408 AP -42 Benzene 0.0006 AP -42 n -Hexane 0.0038 AP -42 Toluene 0.0001 AP -42 Xylenes 0.0001 AP -42 The uncontrolled V0C emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 6.14psia M (vapor molecular weight) = 64 lb/lb-mol T (temperature of liquid loaded) = 512.45°R COLORADO Air Pollution Control Division Page 12 of 18 Emission Factors- Uncontrolled Emission Factors — Controlled Source NOx 6.55 g/hp-hr 1.0022 g/hp-hr Manufacturer CO 11.03 g/hp-hr 1.9964 g/hp-hr Manufacturer VOC 0.7 g/hp-hr 0.7 g/hp-hr Manufacturer Formaldehye 0.0205 lb/MMBTU 0.0205 lb/MMBTU AP -42 Acetaldehyde 0.0028 lb/MMBTU 0.0028 lb/MMBTU AP -42 Acrolein 0.0026 lb/MMBTU 0.0026 lb/MMBTU AP -42 Benzene 0.0016 lb/MMBTU 0.0016 lb/MMBTU AP -42 Emission factors are based on a Brake-Specifc Fuel Consumption Factor of 6536 Btu/hp-hr, a site -rated horsepower value of 239, and a fuel heat value of 1454 Btu/scf. Point 010: Emission Factors - Uncontrolled Emission Factors — Controlled Source NOx 6.55 g/hp-hr 1.0022 g/hp-hr Manufacturer CO 11.03 g/hp-hr 1.9964 g/hp-hr Manufacturer VOC 0.7 g/hp-hr 0.7 g/hp-hr Manufacturer Formaldehye 0.0205 lb/MMBTU 0.0205 lb/MMBTU AP -42 Acetaldehyde 0.0028 lb/MMBTU 0.0028 lb/MMBTU AP -42 Acrolein 0.0026 lb/MMBTU 0.0026 lb/MMBTU AP -42 Benzene 0.0016 lb/MMBTU 0.0016 lb/MMBTU AP -42 Emission factors are based on a Brake-Specifc Fuel Consumption Factor of 6536 Btu/hp-hr, a site -rated horsepower value of 239, and a fuel heat value of 1454 Btu/scf. 6) In accordance with C.R.S. 25-7-114.1, each Air Po lutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs, n -Hexane, NOx, CO PSD Synthetic Minor Source of: VOC, HAPs, n -Hexane, NOx, CO MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http:/ /ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I COLORADO ofufion Control Civision Page 13 of 18 3• i. ...., • i dar.m f, 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 616580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN -Subpart XXXXXX COLORADO Air Pollution Control Division Jid Page 14 of 18 "ACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2017 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. T he 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 witFiin 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 owner or operator 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 owner or operator shall maintain a copy of all Applicability Reports required under section 2.1 .2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. COLORADO Air Pollution Control Division Page 15 of 18 An '5i 'o lutan LLmissions o Ice N) tha 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 owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator 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 owner or operator 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 web site at: https://www.colorado.gov/pacific/sites/default/files/AP Portable -Analyzer -Monitoring -Protocol Of Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (Ib/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. 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. COLORADO ution Control Division Page 16 of 18 Subjegt to t4I prgTisttE s or.R.125-T.4123.1 anti in the absence of credible evidence to the contrary, if the portable alyzer anresults"Facto' emonstrat`e co phance tn%itii either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D 2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PMIO 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 S02: Use of natural gas as fuel PNI10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only conditions). Control Requirements: Section XVI a Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: SectionXVILE— 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: COLORADO An Pollution Control Envision Page 17 of 18 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 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section 1.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § LB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources 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. COLORADO Air Pollution Control Division Page 18 of 18 Engineer: David Thompson Control Engineer: Chris Laplante Review Date: 06/07/2016 Application Date: 03/11/2016 Permit No. 16WE0546 AIRS County 123 (Weld Facility # 9E77 Facility Type, exploration and production facility ❑ Located in the 8 -hour non -attainment area? Potentially located in ozone nonattainment area True Minor 0 Synthetic Minor for: 1 VOC r NOx f- CO HPRIInIStldllvc uuvr rua.t,.... Company Name: Noble Energy, Inc Source Name: LD22-A Econode Source Location: SIC: SWSE Sec22 TWP9N R58W 1311 Mailing Address Address 1: Address 2: ty, State Zip: Noble Energy. Inc 1625 Broadway, Suite 2200 Denver, CO 80202 Person To Contact Name: Phone: Fax: Email: Mike Putney 000-000-0000 000-000-0000 mike.putney@nblenergy.com Requested Action Self Certification Required? Issuance Number. Yes 1 Source Description: Oil and gas exploration and production facility known as the LD22-A Econode, located in the SWSE Sec22 TWP9N R58W, Weld County, Colorado. Point Name Type Control Action 004 LP VOC Flare Separator Venting Flare Newly reported source 005 VRT VOC Burners Separator Venting Flare Newly reported source 006 Tank Battery Oil Tanks Flare Newly reported source 007 Produced Water Water Tanks Flare Newly reported source 008 Truck Loadout Loadout Flare Newly reported source 009 Gen 1 Engine Catalytic Reducer Newly reported source 010 Gen 2 Engine Catalytic Reducer Newly reported source 004 Open, back-up flare to control LP Separator Vapors Equipment Description This source vents natural gas from'. Emissions from this source are'. a well head separator routed to a flare 'Natural gas venting from a well head separator. Emissions from this source are routed to a flare, Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication_ Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex =0' MW Xx / C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (0) MW mole % MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 000 4.0026 0.000 0.000 000 0.00 0.00 C02 1.85 44 01 0.814 0 022 1.58 13834 70 6.92 N2 0 26 28.013 0.073 0.002 0.14 1237.60 0.62 methane 31 28 16.041 5.018 0.136 9 73 85259.90 42.63 1848 30.063 5.556 0.151 1078 94401.94 47.20 ethane 27 94 44 092 12.319 0.335 23.90 209330.67 104.67 propane Isobutane 3.19 58.118 1.854 0050 3.60 31502.72 15.75 11.13 58.118 6.469 0.176 12.55 10991387 54.96 n -butane isopentane I 74 72.114 1.255 0.034 243 21321.39 10.66 1.90 72.114 1.370 0037 2.66 23281.98 11.64 n -pentane 70.13 0.000 0.000 0 00 0 00 0.00 cyclopentane 0.54 86.18 0465 0013 0.90 7907.64 3.95 n -Hexane 84.16 0.000 0.000 0.00 0.00 0.00 cyclohexane Other hexanes 86.18 0.000 0.000 0.00 0.00 0.00 heptanes 0.53 100.21 0.531 0014 1.03 9024.72 4.51 072 98.19 0.707 0.019 1.37 12012 86 6.01 methylcyclohexane 224-TMP 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.09 78.12 r 0.070 0.002 0.14 1194.68 0.60 Toluene 0.01 92.15 0.009 0.000 0.02 156.58 0.08 Ethylbenzene 0.01 106.17 0.011 0.000 0.02 180.40 0.09 Xylenes 002 106.17 0.021 0.001 0.04 360.81 0.18 08+Heavies 0.01 2781.35 0.278 0O08 0.54 T,_..a vnr 4726.09 n i..,nnr.nncm 2.36 215.46 6 44 36.82 MMscf/yr Ib/Ib-mol 735 1598174 0017643836 scf/hr MMscf/d Notes Mole %. MW, and mass fractions from Critter Creek 2-03H gas analysis collected XX/XX/XX. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+ based on the average MW on the analysis for the gas. 16W E0546. CP 1. PA.xlsm 004 Open, back-up flare to control LP Separator Vapors Flaring Information Equipment Description Flare to combust low-pressure separator gas during Manufacturer Open Flare Model iustries Open Flare Serial Number TBD Gas Heating Value 2000 Btu/scf Throughput 12880 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales li Make TBD Model TBD Requested Control 100.00% Annual Bypass Tim 50 00% Backup Flare Overall Control 95.00%i Combustion emission factor source: 0.07 lb NOX/MMBtu Emissions Summary Table AP -42: Chapter 13.5 0.37 Ilb CO/MMBtu Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 66912 lb/MMscf 3345.61 lb/MMscf 215.5 tpy 10.8 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 Ib/MMBTU 0.4 tpy 0.4 tpy AP -42 CO 0.37 lb/MMBTU 0.37 Ib/MMBTU 2.4 tpy 2.4 tpy AP -42 Benzene 185.51 lb/MMscf 9.28 lb/MMscf 1195 lb/yr 60 lb/yr Gas Analysis n -Hexane 1227.89 lb/MMscf 61.3947 lb/MMscf 7908 lb/yr 395 lb/yr Gas Analysis Toluene 24.314 lb/MMsd 1.2157 lb/MMscf 157 lb/yr s lb/yr Gas Analysis Xylenes 56.026 lb/MMscf 2.8013 lb/MMscf 361 lb/yr is lb/yr Gas Analysis Ethylbenzene 28.013 lb/MMscf 1.4007 lb/MMscf 180 lb/yr 9lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 1 Section I.A applies to all emission sources. "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 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." AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, Section XVII.B.2 16W E0546. CPI. PA.xlsm 005 Bank of enclosed flares to control VRT Vapors Equipment Description This source vents natural gas from Emissions from this source are a well head separator routed to a flare Natural gas venting from a well head separator. Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication'. Volume II, Chapter 10 - Displacement Equation (10 4-3) Ex = QMW Xx / C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas' MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/Ib-mol) at 60F and 1 atm Throughput (01 MW 1 435 45.33 MMscf/yr Ib/lb-mol 163.8127854 0.003931507 scf/hr MMscf/d mole °/ MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 40026 0.000 0000 000 0.00 0.00 CO2 1.18 44.01 0.519 0.011 022 1966.28 0.98 N2 0.04 28.013 0.011 0.000 0.00 42.43 0.02 methane 9.83 16.041 1.577 0.035 0.68 5970.32 2.99 ethane 17 01 30.063 5.114 0.113 2.21 19361.96 9.68 propane 39.88 44.092 17.584 0.388 7.60 66577.52 33.29 isobutane 5.12 58.118 2.976 0066 1.29 11266.61 5.63 n -butane 1808 58.118 10.508 0232 4.54 39785.22 1989 isopentane 2.79 72.114 2.012 0.044 0.87 7617.92 3.81 n -pentane 2.98 72.114 2.149 0.047 0.93 8136.70 4.07 cyclopentane 000 70.13 0.000 0.000 0.00 0.00 0.00 n -Hexane 078 86.18 0672 0.015 0.29 2545.15 1.27 cyclohexane 0 00 84.16 0 000 0 000 0.00 0.00 0.00 Other hexanes 0.00 86.18 0.000 0000 000 000 0.00 heptanes 0.70 100.21 0701 0015 0.30 2655.96 1.33 methylcyclohexane 106 98.19 1.041 0.023 0.45 3940.81 1.97 224-TMP 007 114.23 0.080 0.002 0.03 302.75 0.15 Benzene t 0.14 78.12 0.109 0O02 0.05 414.10 0.21 Toluene 0.01 92.15 0.009 0000 0.00 34.89 0.02 Ethylbenzene 001 106.17 0.011 0000 0.00 40.20 0.02 Xylenes 0.02 106.17 0.021 0.000 0.01 80.40 0.04 Cs+ Heavies 001 2358 038 0.236 0.005 0.10 892.82 0.45 VOC mass tract 0.841 Total VOC (unoon trolled)I 72. Notes Mole %. MW, and mass fractions from Critter Creek 2-03H gas analysis collected XXIXX/XX. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+ based on the average MW on the analysis for She gas. 16 W E0546. C P1. PA.xlsm 005 Bank of enclosed flares to control VRT Vapors Flaring Information Equipment Description Flare to combust low-pressure separator gas durino VRU downtimr Manufacturer Model 48" Incinerates Serial Number TBD Gas Heating Value 1549 Btu/scf Throughput 2222.815 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales lin Make TBD Model TBD Requested Control 100.00% Annual Bypass Tim 50.00% Backup Flare Overall Control 95.00% Combustion emission factor source - 0 07 Ilb NOX/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 100551 lb/MMscf 5027.56 lb/MMscf 72.1 tpy 3.6 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.1 tpy 0.1 tpy AP -42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 0.4 tpy 0.4 tpy AP -42 Benzene 288.57 lb/MMscf 14.43 lb/MMscf 414 lb/yr 21 lb/yr Gas Analysis n -Hexane 1773.63 lb/MMscf 88.6813 lb/MMscf 2545 lb/yr 127 lb/yr Gas Analysis Toluene 24.314 lb/MMscf 1.2157 lb/MMscf 35 lb/yr 2 lb/yr Gas Analysis Xylenes 56.026 lb/MMscf 2.8013 lb/MMscf 80 lb/yr 4 lb/yr Gas Analysis Ethylbenzene 28.013 lb/MMscf 1.4007 lb/MMscf 40 lb/yr 2 lb/yr Gas Analysis AP -42: Chapter 13.5 0.37 IIb CO/MMBtu Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 Section l.A applies to all emission sources. "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 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." AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, Section XVII.B.2 16W E0546. C P1. PA.xlsm 006 One (1) above ground 300 bbl atmospheric crude oil storage tank Calculations Requsted Throughput 10000 bbl Control Flare Efficiency 95.00% le Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 5 lb/bbl 25.0 tpy 1.3 tpy E&P TANK Benzene 0.5 lb/bbl 5000 lb/yr 250 lb/yr E&P TANK n -Hexane 0.7 lb/bbl 7000 lb/yr 350 lb/yr E&P TANK Regulatory Review 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, 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. (only needed if using flare) 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 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons (471 bbl) NSPS OOOO: for storage vessels in the natural gas production, transmission, and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Regulation 7 — Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of VOC.) 007 Three (3) above ground 500 bbl produced water storage tank Emissions Calculations Requsted Throughput 400000Ibbl Control Flare Efficiency 95.00% ounmaina Jullula Pollutant u.7 i ....... Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 52.4 tpy 2.62 tpy CDPHE Benzene 0.007 lb/bbl 2800 lb/yr 140 lb/yr CDPHE n -Hexane 0 022 lb/bbl 8800 lb/yr 440 lb/yr CDPHE Regulatory Review 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, 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. (only needed if using flare) 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 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. 008 Hydrocarbon Loadout to Tanker Trucks Calculations L = 12.46*S*P*M/T (AP -42: Chapter 5.2, Equation 1) L = loading losses in lb per 1000 gallons loaded The table of inputs below enables you to calculate the loading loss emissions factor "L". If you choose to use a state default emissions factor, you may enter is directly into cell 614 in units lb/1,000 gallons which will overwrite Factor Meaning Value Units Source S Saturation Factor 0.6 AP -42 P True Vapor Pressure 6.14 psia Sales Oil A M Molecular Weight of Vap 64 lb/lb-mole AP -42 T Liquid Temperature 512.45 deg. R Field Data L 5.73 lb/10^3 gal 2.41E-01 lb/bbl Annual requested Throughput Annual requested VOC emissions Control: None Efficiency: 0.00% NCRPs Component Mass Fraction Benzene 0.0020 n -hexane 0.0140 Toluene 0.0000 Xylen es 0.0000 Source: 700000 BBL/yr 29400000 gal/yr 168544 lb/yr 84.27 tpy alysis If the operator provides HAP speciation from a stable "sales oil" analysis, enter the mass fraction from this data. Alternatively, if the operator modeled a pressurized oil to develop a site specific emissions factor, enter the modeled mass fraction for the Pressurized oil or Stable Sales Oil Analysis Emissions Summary Table Pollutant VOC Benzene n -Hexane Toluene Xylenes Emission Factor 0.2408 0.0005 0.0034 0.0000 0.0000 lb/bbl lb/bbl lb/bbl lb/bbl lb/bbl Uncontrolled Emissions 84.3 tpy 426.0 lb/yr 2647 lb/yr 40 lb/yr 91 lb/yr Controlled Emissions Regulatory Review Requiation 3 - APEN and Permitting Requirements Is this site considered an exploration and production location (e.g. well pad)? If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons (238 BBLs) per day of crude oil on an annual average basis? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1 4.2 tpy 21.3 lb/yr 132.4 lb/yr 2.0 lb/yr 4.6 lb/yr No Source AP -42 AP -42 AP -42 AP -42 AP -42 Yes No One (1) Doosan. D8.1 L. EEPOG301883, natural gas -fired. Turbo Charged, 4SRB reciprocating internal combustion engine. site rated at 239 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 Power Genertor. 010 Engine Information Engine date of m Manufacturer: Doosar D8 1L EEPOG301883 1800 1/18/2014 Model Number: Serial Number'. RPM. Site -rated RPM 1800 Engine Function Primary and/or peaking power berating Mfg's Max. Rated Horsepower @ sea level: 229 Horsepower used for calcuations: 239 BSCF @ 100% Load (btu/hp-hr). 653E Site - Rated BSCF @ 100% load (btu/hp-hry. 6536 Other Parameters Engine Type 4SRB Aspiration turbo -charged Electrical Generator Max Site Rating (kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 1074 scf/hr ACTUAL Annual Fuel Consumption 9.41 MMscf/yr MAX YU I tN I IAL Annual Fuel Consumption 9.410 MMscf/yr REQUESTED Annual Fuel Consumption 9 410 MMscf/yr Fuel Heating Value 1454 btu/scf Emission Control Information non -selective catalytic reduction (NSCR) system and air -fuel ratio control ns Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions NOx 6.550 g/hp-hr 1.002 g/hp-hr 15.1 tpy 2.3 tpy CO 11030 q/hp-hr 1.996 q/hp-hr 25.4 tpy 46 tpy VOC 0 700 g/hp-hr 0.700 g/hp-hr 1.6 tpy 1.6 tpy Formaldehyde 0.021 Ib/MMBTU 0.021 Ib/MMBTU 280 lb/yr 280 lb/yr Acetaldehyde 0.003 Ib/MMBTU 0.003 Ib/MMBTU 38 lb/yr 38 lb/yr Acrolein 0.003 Ib/MMBTU 0.003 lb/MMBTU 36 lb/yr 36 lb/yr Benzene 0.002 Ib/MMBTU 0.002 IbIMMBTU 22 lb/yr 22 lb/yr 16W E0546. C P1. P A. xlsm One (1) Doosan, D8,1 L, EEPOG301883, natural gas-fired,Turbo Charged, 4SRB reciprocating internal combustion engine, site rated at 239 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 Power Genertor. 010 Regulatory Requirements Ambient Air Imps Source is not required to model based on Division Guidelines/No NAAQS violations expected (see details Public Comment Public Comment Required MACT 777Z Facility is an area source of HAPs, so engine is not subject to major source requirements. Engine is new Reg 7 XVII.E.2 Standards (g/hp- hr) The engine is not subject to Reg 7 because it is subject to NSPS JJJJ Req 7 XVII.E.3 The engine is not subject to Reg 7 XVII.E.3 because the engine is rated less than 500 hp Reg 7 XVI.B (Ozone NAA requirements) applies? Not located in NAA so not subject to Reg 7 XVI.B MACT 77ZZ (area source) Is this engine subject to MACT ZZZZ area source requirements? No NSPS JJJJ Is this engine subject to NSPS JJJJ? I Yes Note: JJJJ requriements are not currently included as permit conditions because the req has not been 16W E0546.CPI.PA.xlsm Source Manufacturer Manufacturer Manufacturer AP -42 AP -42 AP -42 AP -42 Control 0.847 0.819 16WE0546.CP1.PA.xlsm One (1) Doosan. D8.1L, EEPOG301546, natural gas-fired,Turbo Charged. 4SRB reciprocating internal combustion engine, site rated at 239 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 Power Genertor. 010 Engine Information Engine date of m Manufacturer: I 1/18/2014 Dcosan D8.1L EEPOG301546 1800 Model Number Serial Number: RPM: Site -rated RPM. 1800 Engine Function Primary and/or peaking power Mfg's Max. Rated Horsepower @ sea level: 239 Oerating Horsepower used for calouations: 239 BSCF @ 100% Load (btu/hp-hr)'. 6536 Site - Rated BSCF @ 100% load (btu/hp-hr): 6536 Other Parameters Engine Type 4SRB Aspiration turbo -charged Electrical Generator Max Site Rating (kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 1074 scf/hr ACTUAL Annual Fuel Consumption 9.41 MMscf/yr MAX FU I EN I IAL Annual W eI Consumption 9.410 MMscf/yr REQUESTED Annual Fuel Consumption 9.410 MMscf/yr Fuel Heating Value 1454 btu/sof Emission Control Information non -selective catalytic reduction (NSCR) system and air -fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions NOx 6.550 gihp-hr 1.002 g/hp-hr 15.1 tpy 2.3 tpy CO 11.030 g/hp-hr 1.996 q/hp-hr 25.4 tpy 4.6 tpy VOC 0.700 g/hp-hr 0.700 g/hp-hr 1.6 tpy 1.6 tpy Formaldehyde 0.021 lb/MMBTU 0.021 IbiMMBTU 280 lb/yr 280 b/yr Acetaldehyde 0.003 lb/MMBTU 0.003 Ib/MMBTU 38 Ib/yr 38 b/yr Acrolein 0.003 lb/MMBTU 0.003 lb/MMBTU 36 lb/yr 36 lb/yr Benzene 0.002 lb/MMBTU 0. C02 Ib/MMBTU 22 lb/yr 22 lb/yr 16W E0546.CP1.PA.xlsm One (1) Doosan, D8.1L, EEP0G301546, natural gas -fired Turbo Charged, 4SRB reciprocating internal combustion engine, site rated at 239 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 Power Genertor. 010 Regulatory Requirements Ambient Air Impz Source is not required to model based on Division Guidelines/No NAAQS violations expected (see details Public Comment Public Comment Required MACT ZZZZ Facility is an area source of HAPs, so engine is not subject to major source requirements. Engine is new Reg 7 XVII.E.2 Standards (g/hp- hr) The engine is not subject to Reg 7 because it is subject to NSPS JJJJ Req 7 XVII.E.3 The engine is not subject to Reg 7 XVII.E.3 because the engine is rated less than 500 hp Reg 7 XVI.B (Ozone NAA requirements) applies? Not located in NAA so not subject to Reg 7 XVI. B MACT 7777 (area Is this engine subject to MACT 7777 area source requirements? No source) NSPS JJJJ Is this engine subject to NSPS JJJJ? I Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been 16W E0546.CP1..PA.xlsm Source Manufacturer Manufacturer Manufacturer AP -42 AP -42 AP -42 AP -42 Control 0.847 0.819 16W E0546.CP1.PA.xlsm N cr- Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] uested Action (check applicable request boxes) Section 02 — Re 6> O y ts FT. E U O H rel o. •• I W o o o ? v r.4 Request for NEW permit or newly reported emission source y 0. a. Ft L 0 0 a? K 0 .0 U 0 C O s u E a) a Ft N O z O w A O O O 0 0 UU z& Source Name: Change company name a. a) O 0 Transfer of ownership ❑ ❑ Change fuel or equipment Change permit limit ❑ ❑ SWSE SEC22 TWP9N R58W Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: Request APEN update only (check the box below that applies) 1625 Broadway, Suite 2200 T 0) C • O C) o P. c 0 c .4- 0 . CU CU LL 0 0 o En eo c c O O N U U;` o •3 E u C',,. W ❑ ❑ O U c 0 i p C A � Person To Contact: 303-228-4362 Fax Number: Section 03 — General Information For new or reconstructed sources, the projected startup date is: For existing sources, operation began on: Normal Hours of Source Operation: Open, back-up flare to control LP Separator Vapors. General description of equipment and purpose: Ii C o 0o v aJ ¢' .�. .�. y E 0 W U U MM cr 0 N O\ ." 01 i S. < a) "9' 40 \O �O �p 0 A b U f — M M en a) W Co) 1 o 0 o Q. 0.. W 0 O C \Ot. 9 ti c c • o: C,o o oo N W z s x ≥ 3 cF. 64 v u A _ o aa > o w. v 0 O T., co a `a 3 aci Y 9 p o a) 9 a� = .0 a� �n 4. 0 ^ o 0. 0J = a) co o o U '� c° a o 0 +• 3 C 3 "c '0 3 `= ° = o o> C E 7 4. ,.. U •3 w L M O Q cC 3g I. a o a a °D °c' .. 7 3 0 N 3 0.0. v �,o o f a)'0 o � ' � .0 0 >F' 0 E or..VoNoo o U 1 0tea La �� En c °'� ``Ac ,O c o.� c O U 0 �' O 0 C p V C'� Z Q U GLi 0 000 Z .0 �, 0. 1••• f o oU. c v �n • a �s aW 0 o Q 0 0 C) a) Ft 0 •N 9 c t Ft 0 0 C U7 ay T C C Ft v 0 44 b U 0 0 b0 �_ o c f •p C. N 3 3� Eauiument Information Section 04 — Processin E m .E. F 04) U Ft a) Ct C O w 0 C) C) O O .k X MMscf/event N C 0 J C w 0 az c 0 0 o F •0 as 0 Iii ° a, 0 O. -c o'C � co0 o 0 0 a: Q C/] b „d O N 0 '2E' t C) O 0x� aco 03c7a.0 as 0 U Ft ?_))0E1000 ❑ x� G 1-4 a, e = a) 0 F- 0 1-4 Na)e. Uo o5 r 00 CC 00 Vented Gas Properties: C) U • O c U_ C • 0. 0 0 0 0 '0 '0 0. 0. 0. o P. ct -o - o 0 0 0 0 0 U cr 0 0 o.0 U U El El Ft N W 0 cd FORM APCD-211 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Ventin Emission Source Li Permit Number: Section 05 —Stack Information (Combustion stacks must be listed here) 9 o O W A ^ O 00 of O 0 bD 0 O 0 C '2 vis ', UC7 00 o v 00 O 00 36 o N O M 00 z Crl cn • y g Width (inches) = ❑ Horizontal ❑ Down 0 Other: Length (inches) = Vertical with obstructing raincap C • ❑ ® i.:, C O " U • s O v dJ N 465 4▪ ) Ct 0 O U h. .5, Ohl C • O C O •U C) Q W Circular: Inner Diameter (inches) = Section 07 — Control Device Information bD C ® Combustion Device used for control of: Manufacturer Guaranteed: N N 0 C4 VOC & HAP Control Efficiency: Waste gas heat content: Pilot burner rating: O z Constant pilot light? Make/Model: O VRU used for control of: O I C O • E _O • r, - co E .0 bn cn 5 C a4 > >' 'i r� \\i • / C U Section 08 — Emissions Inventory Information & Emission Control Information 0 t.C O O • -O u •E .C. Q � C Cep .rt • C O o m E 0 U V O U V L C g • O u C� C U O C • El N b0 u O .O C 0. C L C 0 d .0 cat E C) L L • O C CC CO C cat CUM L CO C Estimation Method or Emission Factor Source HYSYS/AP42 CDPHE CDPHE HYSYS/AP42 HYSYS/AP42 HYSYS/AP42 HYSYS/AP42 HYSYS/AP42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions4 Controlled (Tons/Year) N O0 O O C1 O C;.' O 0 O '.1 O Uncontrolled (Tons/Year) N 2.02 O 0.07 0.055 O M Actual Calendar Year Emissions3 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units Lb/mcf I U O aa Lb/lb-VOC Lb/mcf Lb/mcf u E Lb/mcf Lb/mcf Uncontrolled Basis 00 o 0.0037 7 O O 00 O 1 O O O O O O 1.226 Control Efficiency (% Reduction) 0 a, 0 Q\ 0 a, 0 01 0 01 0 01 Overall Collection Efficiency Control Device Description Secondary CO C E Open Flare Open Flare Open Flare Open Flare Open Flare Open Flare Pollutant VOC XON CO 0 tip Benzene Toulene Ethylbenzene Xylene n -Hexane H U Y CO ✓ O � W C V CO E C Lr C 6 •0. CL O U C O CQ C,. U 5 A O C O CC 8 W .C. AU Q" O c •3 0 CO 0 O V w U co y G V 9 5 V 0 Ca T. 7o 'd ai U x m A • � 5 N F L .w N o N C ai:° 4 U Y CS a3 .. oOy *ea < � U CO C V A U C ,C CO - 1.0 CLoi CO al O .0 O r+ N y C$ • W b w p U O • N C CO U 0 Ctl ? • y Cq Q O\ e C C CJ U C) zID Mike Putne 03/10/2016 C) C. C) C` O O Name of Legally Authorized P C) CS N O N C) FBI FORM APCD-211 5 z w O O w UL_ r 0 Z Z ,V, ^/ _O y! -5,• ;, w .c l— 312 ZE aO U IO M a) J U C J o O O) a CL a; aa) N w J a', Co Q' - a 0 0 w cc NN Lf� w IN�/ LL 9 i 0 Z AIRS ID Number: Permit Number: Noble Energy, Inc. Company Name: LD22-A Econode - LP Sep Burner Plant Location: T a) 7 a a) 2 Person to Contact mike.putney@nblenergy.com E-mail Address: Controlled Actual Emissions Ibs/ ear Co U) Uncontrolled Actual Emissions Ibs/ ear O Emission Factor Source Engineer Calculation Emission Factor (Include Units) 0.164 lb/Mscf Control Equipment / Reduction (%) 0 rn Chemical Name 224 trimethylpentane Chemical Abstract Service (CAS) Number V co 0 Lo 03/10/2016 to Applies: 2016 0 TO 7 Q A a3 L y a1 U -,--: a) E . J O O a) >- O =� `m -o C (6 a) C To co U U) a) c c w co C a) E C a) O_ ca ❑ C W a$ a$ a a a co O a) N O L a) a) C 7 a a) a5 co 0 a a co 0 a) N O L Q To a) a) J C O a) a) a O F - C a a) U) a) a) ET__ co co 0 • a U) O a) N O O Q T a5 a) a) J C O a) a O a) E a5 Z 0 N Form Revision Date: A O Emission Source AIRS Ill: a E [Provide Facility Equipmer C) a z E 6. 6 uested Action (check applicable request boxes) Section 02 — Re Section 01— Administrative Information '�cs, S O O G C. T w 0 ❑ 'O b E a o o. .^CIJ U G G] 0 0 f x c w 0... '" C .V H 2O' T `u C c._ 1.., C C O 7.; 0— c C) y 3 _ o.`" • = o a F O - C 0 C F c Y 0 p '� U V v d C -7. p .E L, m o ` 30 G S y `e u .. 0 F= `o d Cs c c 0 c u d S ;!G _ dG ❑ ❑ T L °L V it". L c _ >, 9 >, x v V C C o C [z. L -o 0 c o m 0 �Vi C •2 L., 4a i = re" .. O Q G 3 0 a c H v _ a, Q _c O. E u z r z q vrn L ) o L 0 c c _ P. c— o c G cn 0.1 u in en c > > 0 ti C. L V C L z' Company Name: SWSE SE SEC22 TWP9N P9N R58 W Ca S O 00 1625 Broadway, Suite 2200 O O c Person To Contact: It 303-228-4362 Fax Number: Section 03 — General Information Y C) 3 T Ca N O T ma V \ 0 .Ni i E 0 c a r C O R. O L. f o O `c o a E A Y L o Q C a L J p 00 to ^ v N rl N N .. P'0._ m CE V -5 0 aci E O C . C O �1 G r, m n O c o a L J V N -, U G G En L Q ‘-0 O L CA > 4 W 1 h0 O = S = F V L a) m 'C w 0 . r 0 a E E 8 3 t° 4 cn F = G O s > 0 c > c c 3 3 ... tip ze O o ,'� ? 3 c e E d 0 T L L N to .< O. W V O U m v eo°' LO o 0 0 E ° 9 hrJ a c .o L = 0 =aO0 O ) L 0 a.. co. i k F C. 00... E c U Qv D a d Cn Q Q 0 0 6 G U a) G G Ca Ca 7 G T T G 0. 0 O 0 0 vi Ca a) c 0 0 = a U. 0 U 0 z ❑ C) Ca F C". t+ G Z F a C 'y( U V O 9 0 0 i- .5. T3 u 3 et uiument Information Section 04 — Processin c_ E. 00 v G 0 _v v -0 '0 5 5 r i 00 G 0 U G G U a) CCr G -0 v. v 3 O a ° O Ci '] G . ' G O G S .c c a -0 T., 3 J ❑ ® ❑ ❑ ❑ ❑ o m Ca Cj G S Process Parameters: a) � e N c O r X 3 Ch 0 0 0 0 Vented Gas Properties: Ca FORM APCD-21 I Permit Number: N C) C) Section 05 — Stack Information (Combu nre 0 v v g -2 -, a " F,57 [i. F N Y O z C6 - Vertical ❑ Vertical with obstructing rain ❑ Circular: Inner Diameter (inches) = ❑ „ O v O Y C?at Y .= 33 O Y U U N ai =n 0 u 11 U o -C C7 Y 00 E wC C) C CoCY U 0 6 5C E L ntrol Device In Section 07 — C E 48" Incinerator Make/Model/Serial Manufacturer Guaran a tr. z 2 0 tu 14 a e N C N CC U .O v 0 . c� .5'.`AF o w `-' C Lq -J O O ca A E v U -0 3.1 0.� G Q � C s r > 0 c T 0 > E > > N ite g- C C y ribe Any Other Section 08 — Emissions Inventory Information & Emission Control Informa Estimation Method or Emission Factor Source HYSYS/AP42 CDPHE CDPHE HYSYSIAP42 HYSYS/AP42 HYSYS/AP42 HYSYS/AP42 HYSYS/AP42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions° Controlled (Tons/Year) 1c Cr; 0 0 0 0 0 0 0 0 0 0 Uncontrolled (Tons/Year) 72.1 N O C0 O 0.20 0.02 We 0 0 O N - Actual Calendar Year Emissions3 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor up C J ILbILb/mcf O a as a 0 s V E a a U E aaa a V E a V E a Lb/mcf Uncontrolled Basis R 0 O M O O O Q O co O 0.2847 O N N O V1 NI O O 'C V. co O N r - Control Efficiency (% Reduction) e It a01 e iInIntin e 01 e C\ e P e Ul P Overall Collection Efficiency Control Device Description C 0 C 0 0 CC vet 0. Enc. Flare Enc. Flare Enc. Flare Enc. Flare Enc. Flare Enc. Flare Pollutant DOA z° o 0 0 C0 C 0 E° v N C a .O m Xylene V C C 0 c 0 u 4 C CC C 0 C1 as E 0 u a O C u .00 0. Ca s CC 0 g E o ao o y O C 0 c o v O R T; a v 7, .E Ay� . r a tCC _ y � 3 o C y A C AFC 9 ‘.ti 72, .1) .0 d C A O G O U `°L F O A O y y m �K8 " O 0 m .E .C CC 9 O R n 3 o E Q 4 y O U T U Y L m n 4 al d mS J: 0 y v C m O 2 C .E u 3w 9 L. v d w'E U c 0 Ey y- m e y U ' N � I a D\ O C O CJ CC CC F CC C C E L F 03/10/2016 0 H 0 FORM APCD-211 N NOTICE ADDENDUM co 0 /� V/ C ~ OI w F d ZE < O U l- O U -J `C J -a O o) CL Ce o a • 0) w < N N LL O a w LL w I- U z O z Permit Number: Noble Energy, Inc. a) 0 0 U a N -o T C O O U LD22-A Econode - VRT Burner a E c6 O Z >+ O C O 0 J 0- E C O N U 0 - CL 0 Person to Contact: mike.putney@nblenergy.com E-mail Address: Controlled Actual Emissions Ibs/ ear In Uncontrolled Actual Emissions Ibs/ ear CO Co Co Emission Factor Source Engineer Calculation Emission Factor (Include Units) 0.218 Ib/Mscf Control Equipment / Reduction (°/0) 0 In CD Chemical Name a) c as C U) a T L 0) E V N N Chemical Abstract Service (CAS) Number a CO O in 03/10/2016 0 0 CV N N Q O_ Q Ca CO a LTT O co d -o C N U U) CO a co co a n O_ 7 U) O N O w J (6 O) 4) J C O N a) d p O c 7 = (0 0- c mCO 2 Environmental Engineer III Title of Person Legally Authorized to Supply Data C Q a) y to Ca co a Q n 7 0) 0 0 N O -C 7 Q co O) a) J C O N N d 4- cz E Z Form Revision Date: A uested Action (Check applicable request boxes) Section 02 — Re Section 01— Administrative Information ❑ ndfathered source v m R 1 .O c Q C .e 0 G dran a a. U 73 EE •c .0 cep V] E❑ ❑ ❑ ❑ c U vc U U U z� 9 3 'C N 00 ° o U U _U W N 1625 Broadway, Suite 2200 y 00 O U v V u L 4 Person To Contact: Section 03 — General Information U T > 0 r ® o Y N C N m c 5 o m c0 9at 3 } ❑ ❑ oT",1 'w O O• F o'SJ "OO 9 d v C L z < 0 O N 0 3 S - v u G L O. O• "- T O a C F c 9 > Z C > O 6 a e`0cjil QI-, •L U 6 U f. It o O 4 L C O.LI ` az9 u ._ _ 'C W 6 C P O �O \ .a C L U U V VI G 9 69 s. N t r— 0. ,.r q . 4 L o Vi 7.3 V .� EO roil 9 4 .c.'2 W G.o I.-. O �_ E 4 x— Z C U U L L V .0 0 oc, CO ai U Z i`. C .N < U + 4 Cg a < 0 00 vt v', t t" --- n en rn N N N ON 0 Z M O a. o O 0 nm v O 0 no c, O. MVD \0 � > 4 O I W O n U C J > V e .o "t c Cv ° GJ L F C t0 E o U 2 C O o. _9 4 L a C./ Q F.. 0 4 E w`b o El r w JO 3 E be L ti,,, ! <U ,,, m..F, EwZ a_iUa oU, = d T U G U f 'n .L LC. G. 0 a cj L U 0 .O ._ F 0 3 ti -zeI' L;_ o s .t,-; m o F t i 0U CC o.7 O T F_y y OUe > h0 L COm LJ 6 �' W e U k C r 1. < h 0 FL < Q r N Q- y U C oc <-5 v o ai E .. 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U 0 EGD u , Q X V] .U. t N T. 9. c • • ca, 9 OL C L rc2 [t -,r1 3.- o ct UH H Actual While Control External Floating Ro O <o F V] Date Of First Production (Month/Year) =' o Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Newly Reported Well e�EE:. _� N N Name of Well Grade LD22-720 Gracie LD22-730 Gracie LD22-740 Grade LD22-750 Kidd LD22-770 Installation Date of most recent storage vessel in storage tank (Month/Year) on N Total Volume of Storage Tank (bbl) C C # of Liquid Manifold Storage Vessels in Storage Tank or API Number 05-123-41561 05-123-41562 05-123-41563 05-123-41564 0 tn en U1 o W Ou y= 0 - 4 V APEN Tank Battery Mar 2016 N 0 0 0- FORM APCD-205 CI) Y CC d Pri 0 0 ee O, Q Cr E ct z 0-4 04 i7 O Q4 0 cr- M Emission Source AIRS ID: Permit Number: 2 0 I. 0 0 0 a r ci E C 0 w O C C .0 E C 1/40 C ai 0 0 C 0 U r O Es Q o O 000 .0 o„ °a zo o 3 G m r C co co oec v.; ly o O• O O ft Fw E- N ❑ GI 3 tre > V W J Circular: Inner Diameter (inches) = E&P Sites Onl 00 In Y 0 P. .. O Y -5, N h o m O o R O 0 9 oo O 3 C • O V c c N a 0 0 c. 0 c R N N v • m 0 0 0 .0 cal 3 a C 0 ci O o O w C O U 0 y E 0 O E ca H L 0 C a C O 0 O en CC .0 C C .0 C C C i L m C t1 c 2 L' G C 0 c E CO' 0 E Emission Factor Data Source CDPHE HYSYS/AP-42 CDPHE HYSYS/AP-42 HYSYS/AP-42 N a Q L-.7) CA } S HYSYS/AP-42 HYSYS/AP-42 HYSYS/AP-42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report ollutants not listed above. I Requested Permitted Emissions IControlled (Tons/Year) N 04 co000-0 000000 Uncontrolled (Tons/Year) 0 185.79 1.77 0.47 0 O 0 O o O 2.92 m O e Actual Calendar Year Emission Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor U 0 a a a c� a .0 a a a a a a Uncontrolled Basis N t0 co O 0 00 O Fe) V1 0 e on 0 0 0 e O 0 0 0 O 0 0 0 O 0 0 0 N O 0 0 0 'O N 0 0 0 N O 0 0 0 C 3 o n, 0 z> 0° o N d- m y 0 F- Ethylbenzene W ° T X o C O x c N w Y a N 0 •�c L O 'O C ci E O U CM C 0 R U a a c s i E .0 y 0 0 E 0.1 W 'O C L s C G 0 tic O E L C A s v U .0 u .ci a U n ao CC 0 to ? b H O N O 0 O • J H a Y a o CO O C 5 V • a. d N ❑ • F, o 0 Q o � ^ 0 0 Ado • N co a 0 c 0 0 o 0 F w zF O 'y c w LU y OU iC .C 0 d w z O y c 0 s O T m 0. c: TEI N C O C N y 0 0 ci 6 O Fri 0 C 0. Q F 0 O m F 0 0 c 0 H CU w 0 .0 0 00 3 0 O 0 F V O F V c A c 0 F Y Q a s 0 W E a 0 Ca a < APEN Tank Battery Mar 2016 N O N V ci 0, FORM APCD-705 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Noble Energy, Inc. Addendum Form Page 1 Source Name: LD22-A Econode Emissions Source AIRS ID2: N/A / / I Z3 !9ET7 l6 DG Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41589 Kidd LD22-780 0 - - ❑ - - ❑ - - ■ - ❑ ❑ - ■ - ❑ _ - ❑ - - ❑ ❑ - ■ _ - ❑ - ❑ - - ❑ - ❑ ❑ - - 111 ❑ Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 APEN-Addendum Forml Tanks Mar 2016 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Stora cs- Emission Source AIRS II): [Leave blank unless APCD has already assigned a permit # & AIRS ID] Permit Number: 0 .CO 0 0 T 0 C) U N C) G 0. a) Cr CO -CO O C) 0. CO T cC ) .C Produced Water Facility Equipment IQ: O C) Yq O d 0 o' C) 00 L r © C) V c▪ o CO • W Pw ❑ CO E g 0. W .0 • d W�r•, u C A v o > 0 C u A 7 4 CD ea P. aa W c a) z u O L L Lo W • ,o O C' • 0 co ❑ PG C Section 02 — Re Section 01— Administrative Information ® ❑ Change company name Change process or equipment C) 0 O O C) O ❑ Transfer of ownership ❑ Change permit limit Co APEN Submittal for Permit Exempt/Grandfathered source 0 L a) > C aJ z Section 03 — General Information 3 Tzzzzz ❑ZDZZ T CO y 3 01 0 .0 '0 CO C (▪ .4 a) C) CO CO a) co 0. C) 0 CO .o .S W En O C C .O 01 a) 0 o ecs 0 v z 3 0 rl CO 0 C CO 0 C 0 rcl (1) O v) C.) 0 cn 0 0 Normal Hours of Source Operation: um cli I.0 • - • 00 ° d L a• .,)c L a a c. U L 4^. 'O W `' C CO 0 01 o o C. 0 la E L •a) y y N s CO C > .� d i Wo • 0, a) "> C ,O tO. O L L CO 700 a4 -a'. ca, N H „° W O F O Oo • L N y' A t-. c�C 769 at+ wU.° • y C o x d o..C u CO i- cy = LZ bO N C) Cl .0 0 cCC ti u I. i .N 6 0 • 00 0 00 I.0. . a�i 3 4' O rn R a) • 0 a O a+A j U C O 67) i C C ,c C W E 5 O C CO a) 0 OC O w CCO O- •m S O CO v1 CCCC U ca �. CO c 0. a) 0 C a) U L L W +" C) A °vp,.c _$,op oA o 0 3 :La.)H d �, o CO0cC0 . n COO a' >, p ._— .4 o C L 0 a O > O U't Fr, Wc� °L'U 4 C-. 0 o�N M M O 0 00n en c° z �• 2 •O cip E �a UO > U O .5 C@ 3 75 O c z O d o U o (I) CO • a al.to . 70 w° ¢rv) APEN forms: htt a) CO > O ://www.colorado Application status: htt •C o 8 5 O„ O a) so. a 0 D . 5 o O 0 O CO O T O CL • O .0 O • G ro 0 Cyo<'C) y�� roV d C �U ¢�zx ,L4 cc y > C COo C a) O ® y 0 CO 0 3x P. Al o cz C to 0 C C CO tall o '0 a) cop *.E.0. YO 0.6' 0 O u 0Cl) r Ci a a) N 0 O 2- C 0. CO a) o. CO. ce a) a) C 0 0 0 .0. • U 0 CO N Information C CO Section 04 — Stora C a) O O O 7 ell a. cn CO 0 CO C) O CO C O U CO C C C U External Floating Roof: Internal Floating Roof: Fixed Roof: C) ▪ CO CO • • N taD Q aH F- C O U CO o4 fs, 4 CO Total Volume of O .. C, L O r 0 0 .0 ' 0 a, cid 00 3 'b i C. C a a z izl Name of Well Grade LD22-720 Gracie LD22-730 Grade LD22-740 Gracie LD22-750 Kidd LD22-770 L .0 E 0 z 11) N .c O O\ 1• f�1 N 0. O O O N O 0 Produced WaterTank APEN Mar 2016 N w 0 a0 CO QI aem V'I r C a N Emission Source AIRS ID: Permit Number: COc. C o 5 00 r d o 00 yto .5 0 WI?o P 00 00 'et 00 O 7. O N C) CO v CC E C) u CO V V 0� C) CO -'. U N O O o Q w E, H " O Other (Describe): Width (inches) _ Horizontal ❑ Down O Other: Length (inches) = Vertical ❑ Vertical with obstructing raincap O Circular: Inner Diameter (inches) = Direction of stack outlet (check one): Exhaust Opening Shape & Size (check one): Information Cv 0 Section 07 — C OO CO of of the Storage Tank(s) ® Combustion Device used for con 8" VOC Burners Make/Model Enclosed Flare .r= VOC & HAP Control Efficiency: Waste gas heat content: Pilot burner rating: O oz CO CO CO ❑U -CO C) Cl) U y t) U R O y 7 U b0 O C O 4- O sed for contro Make/Model: C C 0 C N 0 Requested VOC & HAP Control Efficiency: O sed (emissions Annual time that VRU is byp 00 CO C O s o u -c U 0 C] CO C N b0 co CO m C w CO O C O C.) O CO E d y o. � O o N Q E&P Sites On Information aration Technolo Section 08 — Gas/Li b0 What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? .y. c CO C) 00 CO C CO CJ O L O n. co ae �P. Please describe the separation process between the well and the storage tanks: iN O CO E CJ 4 O U h 0 CO Ce E 0 7 O ii 1�1 0 CO o, U V 0© b[ u CO 01 _ iC. C 0 .0 CO C C7 CO CO U R u Ca C C Ca i A Estimation Method or Emission Factor Source APCD Ca C n. d • Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. �I Requested Permitted Emissions Controlled (Tons/Year) 2.62 0.07 0.22 Uncontrolled (Tons/Year) 0.2 52.4 0 1.4 4.4 Actual Calendar Year Emission2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units Lb/lb-VOC Lb/lb-VOC .CO.0 L Uncontrolled Basis 0.0037 0.262 O O O C 0.022 Pollutant XONI VOC CO Benzene Toluene Ethylbenzene Xylenes C) CO R 0 xi U CO CO CO N CO. T ._ C) P H v N N V v O u CQ C) C) C+ O u 0 CO a CO V .10 0 CO E d u ^C) 0.1 CO O V O CO E CC CO V FIZ C.) C: C.) 11 Environmental En CU rl rl a) 01 C) CO CO C) 0 Lei N N o QF z Q o E CO CO O o ti O V u z�) c p 3 a o w CO y CO •U C 1) 2 c°, y O Q o w U rr . 7^ Oo COQ:. o CC m z� W 01 ¢ CO 0 P VD . U o C w N Z R 0 U O R CO � R ›, CO CO b. vs v �w O h0 C U y 4� = v o •3 C) CO O L"+ �— ry C; U R rn CO O CO a P -CO CO T O O Cr CO �CO C.) U N O a. CO O Q P 0. d.. •O O O C) CO C) CO x 0 p U C. V 0 c O R C) U O o N o F F C) - v) 0. o C CO U c CO R 00 7 N . CO • to C X "O CO Lo ti U A T O C w R y ?' o •y F p o U 2w 0. C y 0 bn E. CO itr O Produced WaterTank APEN Mar 2016 N w 0 N 0 b0 Ca a FORM APC11-207 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Source Name: Emissions Source AIRS ID2: Noble Energy, Inc. Addendum Form Page 1 LD22-A Econode N/A/ 23f9=717fic'7 Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41589 Kidd LD22-780 VA - - - - - ❑ - - ❑ - - ❑ - - ❑ ❑ - - • ❑ - - • - - ❑ - - ❑ - - ❑ - - ❑ - ❑ ❑ - - - - ❑ Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 APEN-Addendum Form1 Tanks Mar 2016 Section 02 — R General Permit GP07 Individual Permit 0 v Ca O N O CO Noble Energy, Inc LD22-A Econode Source Name: L a SWSE SEC22 TWP9N R58W Source Location: CD O G d. Blank APENs 0 U N Fax Number: 303-228-4280 0 U Er' Cl C N C T m v C C J J a d �E o -E Ea c E Phone Number: 303-228-4385 Addl. Info. & Notes: Y C) 3 A 9 0 Y O r O 'z z z z z ❑ o 000 < < < } ?u >- Y 0 ❑ ❑❑❑ O N 2.0. O e7 0 c .b. E'. cv_ a y 4 M M E Z O V c < m Ti. 4.N N N4. 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P d r a0 - o o m 0 •,, o. .`y. a, 0 . .o] o a F -E b' E v s,.. c : v a, m rn 1.2> I 0. .. y t - O m 0 ._ c- Oy - E C O G O 7 .- > , < T O - p ,, L °i 'O `� m C © o. ti- r- o .v o._= c•- F E c y m m o .F-. o 00 •m o o♦ ♦♦♦< r G ♦ Q F .. CO Cr) in �Cr)` m T 0 a s J 0 0 C J 2 _ 7 J E O 3 O 2-N F E -0, E - O G Va '-2 m 6 O a F a n v C N m c O C) c - O O O c.41 C O N U O c:, 2 a c. 0 C Do CO R O '- O a a -- L_ '0 tu ice 7 ` ,1 E Ci © O oL N c . —1a O C' xyq =a ca V EG 0 C L ` u b o u co .w L C C> o O Vi a, V .° = L A . O y y 0 h Y o d W m V E its n. o M 0 E I c� C L. o 0 o y o O1 o Ca V e CA o . 0 v C. o z qY a ° z 0 a,v,',, c FTa c -c U - O) b F .L o u o �y cn a W o F..CO -, = '- a z o i CO E La o ^ ^6 a. O lai Y V 0 I 0 CO O u CA -"E O 415 6 ° E bv Lkm moo° 0o0 -2o • 7 a * 0 MN - O N ro co 0 o o` y CO G O < v. E a F u .` CO 0 II C .0 O 3 u` ro E a O U > ❑ ❑C b = C .O e Y E V Y0 U r Y u N (;5' b .0 C o N m a O CO p .0 L Y „co U 0 a I - o O .. O h C 5 .9 x 0 W 00 CO N c 0 e 0 u e o C/5 O 0 'tip 0 0 •a O O 2 O ..z F O o• c m i CCI C7 Cq a a 0 cc 0 C C 0 cc cu K ,-4 .4 O1 a a 0 O C b N wo 00 0 O 0 E L O. CO.71 Pa O 22 73 0 0 :CO L w CO 0 ,Dra en V ON- . 0 0 n c, U O. 0 0 L u CO L a d 0 b U Cb _ e m - Y E o a. 64U U err 0 ea Ct a C e0 L 0 v .0 0 E L e L CO •0 C V CO C) n L L T C 0 C) 2 0 0 4 C) a b c .0 0 V C, CO c O O C b L O C) e E w ❑ oO CO o Ez Ca Actual Calendar Year Emissions Emission Factor v acsi o c 0 O F N U co 0 m C w O 0 U 0 m C w N- 0 O 0 N of 0 o 0 p v en ca of o O o v N 03 N O N Co: 0v d O O O Co Uncontrolled Basis c • C Ca N Ca 0 O U O W N 0 0 U1 E 0. zz U O .0 N O Identify in Section 07 0 ° c O O 0 0 O co M O O O c.) CO 0 0 -, ae - a d CO c of > c w s m 1, c 0 C c u c O o L `_ p L 0 C F 'O V w o C a 0 N ..1 m o c b 0 o c, aL CS o Co d O )vc ., 0.a i. a 0 e n u o y b GUcanS E Ll . a Q V C 0 ton a F t) n9 a CO C O O Y N V N Z I. C b O V 3 y d 'a T C 00 a 0 u y ' .a 6 T W E 0 0 O CO Ca c E •a w E C.C. m m o Y E Z N C .0 Y E • u m 0 CO C. CO a Z C 'f y u 0 im < a b .0 a u •- N V ^ O Le E ^° o L �+ d ` y- V a d 0 c. w L ` 6 R ht,' L < •a .� a u s Ca Ea E `c o t y m. a aLi b r` N 7.g 6 I V 10 E^'0 CO xa `o o E9 < 0 d ,, W L C a T 0. °1 b \ O L u ' 3 " 4Li CO m; d 0 b c c C L ^ O b0 r ^ L C. E .0. � 9 a ; 0 c O e o CO QYetTa b aci CD Li C C V U e u ❑V L V F an 0 O an m 2 C W O W U H O z z 'O 5 E co t 0 __ f" ZE QO U O J " J O o C Q � W� J a Ca QS) N r O a. cc N Lf� O Permit Number: Noble Energy, Inc. Company Name: 303-228-4385 `E.) C or E U z a) c 0 L a LD22-A Econode - Truck Loadouts Plant Location: Person to Contact mike.putney@nblenergy.com E-mail Address: Controlled Actual Emissions Ibs/ ear In Uncontrolled Actual Emissions Ibs/ ear 0 r) Emission Factor Source Engineer Calculation Emission Factor (Include Units) O O 0 0 O Control Equipment / Reduction (%) 0 a) Chemical Name 224 trimethylpentane Chemical Abstract Service (CAS) Number v co 0 U' up co 0 a) a) a a a Ct N ❑ a) 7 a) co ❑ co co T a a J O a a) N 0 w 7 U A \ To O ) U (1) a 3 o 1O a ZL =�S m C C) Calendar Year Environmental Engineer III 7 n a) Title of Person Legally Authorized to Supply Data C •a N N co a) os CO a a 7 0 a) N .` O L S Q C C) a) J 0 O a) a 0 a) E N z 0 N V Form Revision Date: A rocatin>r Internal Combustion Er M ti C p o - =< _6 = Q L C _ Ct 2 © U 0) O 6 L w r:? on C o o .R S — E c C , 6 < -9G m ok ° z E a W O < O Z J1 < Section 02 — R 0 A • , LI L X j E d C O y O C V m = Ca i C " y L G ! CL • ❑ ❑ 3 Z d U _ o i Z E C E e a L Ca < 0 _ c C V O V V 3 a c. z C on on z m s s C C C U 0- c cc` z ❑ ❑ Change company name Transfer of ownership Noble Energy, Inc. C U LD22-A Econode Source Name: -o C U SWSE SEC22 T9N R58W C C) s 15 ai i. N y Y yi Y C O e ..V ti i E `' N c J. N w- C W v e C. C C C 2 7 . C N O cc U N 1625 Broadway, Suite 2200 Mailing Address: O U 0 ` V 0 303-228-4280 C z S mike.putney@nblenergy.com Section 03 — General Information L C L V C 2 ) 0 O C C o0• .tN o w (--:rnen _ Ni N N V T P G ^ .0 ,.O it, r.. r. a= v ` O 0N z vC N 4 G APEN fonns: lit //www.colorado Power Generator C C o _ C oJ onstrucnon co o c C_ 0 nstruction/mo C Date the engine was ordered: Date the engine was relocated into Colorado: z } c- a) • E C r v d u >00 C ti L L > 6 > v 9 O c I G O E. 0 Et 0 0 C C L c C O 0 3 ❑ ❑ 0 0 C z 0 O J G G o ra N c0 M N M C D❑ ❑ ❑ o C 0 40 .77 C 0 L FORM APCD-201 Ca Internal Combustion En (311 7 L 1 ,,� O W O 1- _ ,-7 M d u N o 1 • Lcp a VD _ F 9 + E+Q a L C •-; 6O y = 6 O u p G a c u y 6 m L .2 h C o w U o a G cc O L S .- ..- c V la 4 O G cc; -5 C z G W > 40 Utai. N ° O t41 ca z 3 a v C co co V] cc V1 i. 5 !V Y Od IV 4C1 t W 7 ¢ F z o F E E L14 E , a a Y C al et) a �, 0 _ s Ct O o N C O `° • 6 `2 0 2. o d m E w 2 00 V w U O 0 a ❑ 0 S: i co O DD E o C 00 oCa V 2 9 E n a co 0 5v .(7) a O Q N v. E F= 0 ro tion Information Section 06 — Fuel Consum T 0- O z 6 cc N m Q C, N a, N L p N C 1454 Blu/SCF Requested Permit Lim U 0D 7r. 1074 SCF/hr m m z a. a.4 o _ A Li C = ° .o n a E w c O v°i = `o cn O 0 ro CC en t — N O CC. O U '' U a- t a i �Q a) 0 Ca 6 O O O O C) C) C C) C W l0 C m C C C W o = C n = O o N U U ro y m ., C ca = r U t i 3.Q E U 'VCo w c • .a, ° 0 'Lf T C E N E '8' C d w o 4. a c v m E C_ z C c C 040 c D 2cC _- U ro c 3 •= _ O y 9 ° t N y ` 02 C c O' G O C O h Ero SAC° ° O` F v - U o t 9 ro o C T a Z 2 ° = C d o v E V] ¢'m t y O a = •y= Z O ° - L m R ° 1v`. -y ¢ o I o- O 9 ao O N O M 0 0 m APCD-201-RICEAPEN-Ver.02.10.2014.docx 0 00 Sol E C S J O C? v E Cei V I N N 0 0- V4 vied emission source i Is o O J C C O v a a C s Z o v N ' C O • X U E ▪ 6 ° (0 0 t t L v F 3 L > L'2, E v g i Z e n O V E q c. 2 o o C L —4.. m (11Y C. ty U H ,. C. C G C W v u:. y i z •x W e r O a) y y % IZ at Z,F i. c O0 F '� o _ a ':=-. L 6isa C 7. N E < -- Z y 0 m m t W o • °. L C L .. Q £ .- UU ✓ ClV J J t ra R C CG' C C ❑❑ C C E C) Noble Energy, Inc. LD22-A Econode E z z > E E °0 U SWSE SEG22 T9N R58W Source Location: O 0 N CN 00 'UO N s: 1625 Broadway, Suite 2200 'O on C C U 0 303-228-4280 Fax Number: mike.putney@nblenergy.com Section 03 — General Information c a. a) N s a c v 9. C 0 a) O N C 0 N U] 3 a 'C 'O t N C V 'J - C C C le 0 E r. e 6 x Z Occ in, Cr 't a s_ z M M e C iL C ) G ^ ^ N C V t C F C C U V a G C • flr-.n'O V .-Ca c a ooc Z, ii Li ' C M M ll P-. > b ° t W= O G C - y= ''.0. V o j ° = ]0 U C E 'v pL r ° ps] iY O 11. y p < o ' C W R S' L ..� C .-,-..a- O v Y .1 < • O r L p m L ��` W00 S 0 .)' O t v m z L s a E 'E ° ° EE. = a °° e o " E c z v t y z E �°-, C- ca E _ 4. U m it en ° _ _ t c O m . `° rc a s,o 3 T., 4,,-,' °�' _ 7 v .E m ou E tr.... ; o a 0▪ < E e u cc.; ▪ m a `a m r o ..o, z.. p C 8 F E € C C O r O 0.0 ▪ C aCi _ 'CO • tj U 0 C 'D .;—_, C) LC Ca 'ag .or oF. (,' o E a v ,7"v, c...) aQO =. <rt. < < O O EV € C 0. O. C C 2.0 'o 0c c c O o N v Q Y X X s >° Y Y O ❑❑ Power Generator CC C `c c � X z ` E 0 .1.-} u i. Z O O a c O ~ ro C7 O d W w CI O C E v C W 0 0 C C) 3clz O m z m O CO Y N • C G O G ❑ O z C r 2 O O C F E E v I O es -.E, O 00 a) '3 Oa N 0 U on E C S S.2 E O C a) T 0 O co co O on 0C. O In U, t4 M FORM APCD-201 0 0 I-, u L 9 •u A E a, '> E 0 o /C O Co C O G A C., a c r. ▪ a. z w a C E U o L a = N O s CtCtC.I c C O o 4-'O W > v a z O • L,i . O Z z Z a O h H CC F r - A W e Q • z • o W PI O ,— I-7 Y v Pr m 7d e0 e a v r M N 1. 1. O 00 c 0 CO .0 C o o` N ry a O 0 0 m co co E 00 co 0, t -- or'' 3 s< Z !0o C V IT:) 3 0 -- 11' a 00 v CO O > y 4•, G 2 o S s ci 0_ a au UC L W -CO 0 0 0 a C01 CO •CO 00 CO II v 0-= U m v > Q ❑ C `m U > ❑ C 0 •• E 0 o `O V d el CO t o " a° V V N s E . • a C — O 6 no u c o .OCO a cO co • 0 O CO 0 O s G G v C 00 Q 0 a rte% O CO 0 CO z C U, 00 N N CO 10 N w C G N 1454 Btu/SCF Requested Permit Li U 0D S 5 Cr. C LL U to 0 CO CO 2 z w "0 y0 a P Actual Calendar Year Emissions Emission Factor N 0 O F N d 0 N a C N c. C f'I 0 N C O 0 AP-42/NSPS JJJJ ry Conservative/JJJJ AP-42/NSPS JJJJ C O 0. N a a O O N O d O a O S C S 1- 0 0 0 N en O N C O O O 0 O O O Uncontrolled Basis C U O O C U g O v W � CO 0 a C G U G 0 CO U CO a CO 9 CO 0 ti E a H O m S S a 0 O 0 a S S a a m S S n a O 0 U, m S S n m O O 0 U N Z 0 z n co N b L a L m co z U N Z O a m 0 cc 0 U to Z O U > Fv C co S a 0 N co) 3 S S a m 0 O L 0 C c C O Q co co S a m N O O C N 00 2 S a co co 0 C; 0 CO a, 0 0 0 e V U CO d v ic e y Ctl CO e 3 o o _ ° v c a a O 3 N 0 C. 0 E o P C O a E ss �.O ,o y g w Q s T 00 v i,..:,:•), m C. c .a IN! . H 5 w d P w o a 0 < I- o C v N E O O Y CO _ 5 z g,. 3 0 " E c • y 0 CO a .5 va W r U C CS 00 N o n o C c O O U 'i.. Y a T V) 0 0 O z w a o Q F yUy 0 0 U a C Q $ E m CL' C 0 N 00 N a Hello