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Home My WebLink About20161360.tiff + �y p� per A CDPHE COLiORADO O CO , Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado RECEIVED Weld County - Clerk to the Board 1150OSt u 4 2O1 PO Box 758 APR Greeley, CO 80632 WELD COUNTY COMMISSIONERS April 8, 2016 Dear Sir or Madam: On April 13, 2016, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - LC34 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 1 the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Ft Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, --a 1 Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 2016-1360 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe 41 . r7 moo;. John W. Hickentooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ,'- 21,6/1.C..) ?Ltii.6e44) CC; �-1,,�tJ ,& .//S/I , 2D -A- A A CDPHE` Air Pollution Control Division CO s Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - LC34 Econode - Weld County Notice Period Begins: April 13, 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, Inc. Facility: LC34 Econode Oil and gas exploration and production facility NENW Sec 34 T9N R59W Weld County The proposed project or activity is as follows: Source proposes to operate a new oil and gas exploration and production facility The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.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 16WE0159 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: Carissa Money Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us ARROW COLORADO 1 I Zia == ilk CDPHE Construction Permit If Air Pollution Control Division Permit number: 1 6WE01 59 Issuance: 1 Date issued: Issued to: Noble Energy, Inc. Facility Name: LC 34 Econode Plant AIRS ID: 123/9E4F Physical Location: NENW Section 34, Township 9N, Range 59W County: Weld County General Description: Oil and gas exploration and production facility Equipment or activity subject to this permit: Facility AIRS Equipment Point Equipment Description ID Twelve (12) 750 bbl above ground atmospheric fixed roof condensate 4 Tank Battery 006 storage tanks controlled by enclosed flares. Each flare has a minimum control efficiency of 95%. Produced Fourteen (14) 500 bbl above ground fixed roof produced water storage Water 007 tanks controlled by enclosed flares. Each flare has a minimum control efficiency of 95%. Truck Hydrocarbon Loadout to Tanker Trucks. The Loadout is controlled by an Loadout 008 enclosed flare. LP VOC Flare 009 Twenty three low-pressure (LP) separators controlled by an open flare during VRU downtime. The flare has a minimum control efficiency of 95%. VRT VOC 010 Two (2) vapor recovery towers (VRT) controlled by enclosed flares during Burners VRU downtime. Each flare has a minimum control efficiency of 95%. One (1) Doosan (NG), Model D8.1L, Serial Number EEPOG301533, natural gas-fired, turbocharged, 4SRB reciprocating internal combustion engine, GEN1 011 site rated at 239 horsepower at 1800 RPM. This engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power generation. One (1) Doosan (NG), Model D8.1L, Serial Number EEPOG301830, natural gas-fired, turbocharged, 4SRB reciprocating internal combustion engine, GEN2 012 site rated at 239 horsepower at 1800 RPM. This engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for primary power generation. Storage Tank Version Syn Minor 2015-1 Page 1 of 21 AIRS d 2: he en 3 nes ma be replaced with another engine in accordance with the to .• ry en. = r- -me .'• "ion o h another Doosan (NG) 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 the 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. 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.) F.4.) 4. AIRS ID 009 and 010: Within one hundred and eighty (180) days after issuance of this permit, the operator shall install flow meters to monitor and record total volumetric flowrate of gas vented from the low pressure separators to an open flare and to monitor and record total volumetric flowrate of gas vented from the vapor recovery tower(s) to an enclosed flare. The operator shall use the gas flow rates listed in the application for actual flow rate until the flow meters are installed, not to exceed one hundred and eighty (180) days after issuance of this permit. 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.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: COOP HE COLORADO CO z Air Pollution Control Division PPMTIF!1i O, “Palm b E,.ittmment Page 2 of 21 i Tons per Year Emission Equipment ID Point PM2.5 NO. VOC CO Type Tank Battery 006 --- 1.2 12.4 2.6 Point Produced Water 007 --- --- 4.9 --- Point Truck Loadout 008 --- --- 10.5 --- Point LP VOC Flare 009 Point VRT VOC --- 2.4 31.4 5.9 010 Point Burners GEN1 011 --- 2.3 1.6 4.6 Point GEN2 012 --- 2.3 1.6 4.6 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate 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. 8. 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 AIRS Pollutants Control Device Equipment ID Point Controlled Tank Battery 006 Enclosed Flare VOC Produced 007 Enclosed Flare VOC Water Truck 008 Enclosed Flare VOC Loadout LP VOC Flare 009 Open Flare VOC VRT V00010 Enclosed Flare VOC Burners GEN1 011 Catalytic Reducer and air/fuel ratio controller NOx, CO GEN2 012 Catalytic Reducer and air/fuel ratio controller NOx, CO ,� CODE COLORADO CO Air Pollution Control Division Depsnment.of P,httc Health H Ewironnnrnt Page 3 of 21 PRO, I TI, S D CO D S 9. 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 AIRS Process Parameter Annual Limit Equipment ID Point Tank Battery 006 Condensate Throughput 1,750,000 BBL Produced 007 Produced Water Throughput 750,000 BBL Water Truck 008 Condensate Loaded 1,750,000 BBL Loadout LP VOC Flare 009 Total Gas Vented from all Low-Pressure VRT VOC Separators and Vapor Recovery Towers 16.1 MMSCF Burners 010 (VRTs) to flare GEN1 011 Consumption of natural gas as a fuel 14.13 MMscf/yr GEN2 012 Consumption of natural gas as a fuel 14.13 MMscf/yr The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual 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. 10. AIRS ID 009 and 010: Upon installation of the flow meter required under Condition 4, 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 9 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. 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) 12. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. a 4.) 13. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. AIRS ID 006: 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 CDPHE COLORADO co Air Pollution Control Division DP,Iartment Pllbtr Health f Ernirmment Page 4 of 21 if .ua obs ati from e outside of the enclosed combustion device, or by other ea- pr. -. . the P .sion, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 15. AIRS ID 006, 007, and 010: The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVII.B.2.b If a 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 combustion device, or by other means approved by the Division, determine whether it is operating properly. XVII.B.2.d Auto-igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto-igniter as follows: XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device. 16. AIRS ID 006 and 007: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve-month total must operate 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. XVII.C.1.b.(i)(a) Control requirements of Section XVII.C.1.b. must be achieved within ninety (90) days of the date that the storage tank commences operation. XVII.C.1.d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks subject to Section XVII.C.1. must conduct audio, visual, olfactory ("AVO") and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; XVII.C.1.d.(iv) Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and CDPH£ COLORADO CO Air Pollution Control Division DPnarmelt RAt)11-Healer6FAvronment Page 5 of 21 .1 ..(v a Imbusti device is used, inspection of the device for the presence •` a - if sm. -. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(a) A storage tank constructed on or after May 1, 2014, must comply with the requirements of Section XVII.C.2.a. by the date the storage tank commences operation. The storage tank must comply with Section XVII.C.2.b. and implement the approved instrument monitoring method inspections within ninety (90) days of the date that the storage tank commences operation. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 - Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency CD" COLORADO CO Air Pollution Control Division Deoa,meat of.ublir};eaitn&ermrorrnertt Page 6 of 21 6 _ Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 XVII.C.2.b.(iii) Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies) are designed to minimize emissions from storage tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. XVII.C.3.f. A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. 17. AIRS ID 008: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 18. AIRS ID 008: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): 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 (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. 4, CDPHE COLORADO CO Air Pollution Control Division DP,parment o₹Pubtir Heai;h ft E-wonment Page 7 of 21 A J .^< h .w r o •pe tor sha` inspect loading equipment and operations on site at the •" e i i-" • to - • e compliance with the conditions (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 19. AIRS ID 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. 20. AIRS ID 008: The owner or operator of a loadout which is being controlled shall: a. Install and operate the vapor collection equipment to collect vapors during loading of tank compartments of outbound transport trucks and route these vapors to the enclosed flare. 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. g. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 21. AIRS ID 009 and 010: The separation equipment, including low pressure separators and vapor recovery towers, 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. AIRS Point 009: The open flare, which receives gas from the low pressure separators during VRU downtime, is approved as an alternative emissions control equipment per Regulation No. 7, Section XVII.B.2.e provided the following conditions are maintained: a. The open flare will not be the primary destination for emissions from the low pressure separators. b. The open flare will 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 (Regulation 7, Section XVII.B.2.b). c. The open flare will be equipped with an operational auto-igniter upon installation of the combustion device (Regulation 7, Section XVII.B.2.d(i)). OPERATING Et MAINTENANCE REQUIREMENTS 23. 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 ,r, c0OPHE COLORADO CO It Air Pollution Control Division Def.-meltd,,,blic 7'.eaith 9,=rnirorment Page 8 of 21 • • p a su ct Divisi. approval prior to implementation. (Regulation Number 3, •art , ctl .G. �..,:.. ,.,.. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 24. AIRS ID 006, 007 and 010: 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 XVII.B.2. and XVII.A.16) 25. AIRS ID 009: 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 XVII.B.2. and XVII.A.16) 26. AIRS ID 009 and 010: 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 demonstrate the emissions factors established through this initial testing are less than or equal to, the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this sampling and analysis is greater than the emissions factors established in the permit application and "Notes to Permit Holder" the operator shall submit to the Division within 60 days, a request for permit modification to update emissions factors and emissions limits specified in this permit. Periodic Testing Requirements 27. AIRS ID 011 and 012: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (OftM) 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 28. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) 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 * CDPH£ COLORADO CO -% Air Pollution Control Division DeP=nmeni o₹r,.btic 3;ealF'n b,3-w.onnwnt Page 9 of 21 i cZ .r • `>Y"`on-" repo e pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 29. 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 30. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation 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. 31. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self-Certify for Final Authorization section of this permit. 32. This permit is issued in reliance upon the accuracy and completeness of information supplied by the 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. 33. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 34. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the 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. #, CDPHE COLORADO CO Air Pollution Control Division - D)<-., e,t of„,nrc f;d n&E-vronmomt Page 10 of 21 • • A 35. o :x 2 -11.7(2; ), .R.S. r uires that all sources required to file an Air Pollution miss ."` N:" - (A' ' "1st pa n annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 36. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122:1 (criminal penalties), C.R.S. By: Carissa Money Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. 40, CDPHE COLORADO Co 1 Air Pollution Control Division Ce smrwot of fi,hiic??eaitn&F.wlronment Page 11 of 21 No - "_-- =r • __..: th- n . ....•a 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.) 2) 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. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (lb/yr) reportable? (lb/yr) Benzene 71432 1,351 Yes 68 n-Hexane 110543 9,711 Yes 486 Toluene 108883 1,059 Yes 53 006 Ethylbenzene 100414 146 No 7 Xylenes 1330207 379 Yes 19 2,2,4- 540841 812 Yes 41 trimethylpentane Benzene 71432 5,250 Yes 263 007 n-Hexane 110543 16,500 Yes 825 Benzene 71432 1,133 Yes 57 n-Hexane 110543 8,244 Yes 412 Toluene 108883 876 Yes 44 008 Ethylbenzene 100414 103 No 5 Xylenes 1330207 309 Yes 15 2,2,4- 540841 670 Yes 33 trimethylpentane Benzene 71432 3,087 Yes 154 009 n-Hexane 110543 22,418 Yes 1,121 Toluene 108883 2,731 Yes 137 * CDPHE COLORADO CO 9 Air Pollution Control Division Department of n,brc xeaich a rni.onment Page 12 of 21 s ii x E t �,.,•F,,.l a 100' , 350 Yes 17 Xylenes 1330207 1,398 Yes 70 2,2,4- 540841 2,257 Yes 113 trimethylpentane Benzene 71432 1,192 Yes 60 n-Hexane 110543 8,549 Yes 427 Toluene 108883 967 Yes 48 010 Ethylbenzene 100414 203 No 10 Xylenes 1330207 405 Yes 20 2,2,4- 540841 763 Yes 38 trimethylpentane Benzene 71432 31 - No 31 011 Formaldehyde 50000 395 Yes 395 Benzene 71432 31 No 31 012 Formaldehyde 50000 395 Yes 395 Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr)are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 006: Uncontrolled Controlled Emission Factors Emission Factors CAS# Pollutant lb/bbl lb/bbl Source NOx 0.0014 0.0014 CDPHE CO 0.0030 0.0030 CDPHE VOC 0.2834 0.0142 HYSYS n-Hexane 0.0055 2.8 x 10"4 HYSYS 71432 Benzene 0.0008 3.9 x 10"5 HYSYS 108883 Toluene 0.0006 3.0 x 10-5 HYSYS 100414 Ethylbenzene 0.0001 4.2 x 10-6 HYSYS 1330207 Xylenes 0.0002 1.1 x 10- HYSYS 540841 Trime2,2,4-ntane 0.0005 2.3 x 10-5 HYSYS Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 007: Uncontrolled Controlled lb/BBL Produced lb/BBL Produced Pollutant Water Throughput Water Throughput Source VOC 0.262 0.0131 CDPHE n-Hexane 0.022 0.0011 CDPHE Benzene 0.007 0.0004 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. CDPHE COLORADO T i Co i Air Pollution Control Division Deparment or P,nnr MPal;h 8 Frwironment Page 13 of 21 11 A 18: Uncontrolled Controlled Pollutant lb/BBL loaded lb/BBL loaded Source VOC 0.2408 0.0120 AP-42 Benzene 0.0006 3.2 x 10"' AP-42 n-Hexane 0.0047 2.4 x 10-4 AP-42 Toluene 0.0005 2.5 x 10"' AP-42 Ethylbenzene 0.0001 2.9 x 10-6 AP-42 Xylenes 0.0002 8.8 x 10"6 AP-42 2,2,4- 0.0004 1.9 x 10 5 AP 42 Trimethylpentane The uncontrolled VOC 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) = 6.137 psia M (vapor molecular weight) =64 lb/lb-mot T (temperature of liquid loaded) = 512 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the flash stream vapors by the VOC emission factor. Point 009: Weight Emission Emission Fraction Factors Factors Source Pollutant of Gas (%) Uncontrolled Controlled lb/MMscf lb/MMscf NOx (lb NOx/lb --- 0.0037 0.0037 CDPHE Memo VOC) CO (lb CO/lb --- 0.0094 0.0094 CDPHE Memo VOC) VOC 70.6 71,373 3,568.6 HYSYS Model Benzene 0.24 247.35 12.367 HYSYS Model Toluene 0.22 218.83 10.941 HYSYS Model Ethylbenzene 0.03 28.013 1.4007 HYSYS Model Xylenes 0.11 112.05 5.6026 HYSYS Model n-hexane 1.78 1,796.4 89.818 HYSYS Model 2,2,4- 0.18 180.84 9.0420 HYSYS Model Trimethylpentane Note: The uncontrolled VOC and HAP emissions were calculated based on a HYSYS model to estimate the VOC and HAP content of each stream and stream flow. The controlled emissions for this point are based on a flare control efficiency of 95%. Point 010: Weight Emission Emission Fraction Factors Factors Source Pollutant of Gas (%) Uncontrolled Controlled lb/MMscf lb/MMscf ,A CDPH£ COLORADO CO Air Pollution Control Division ' Denamrent of nuhQ-Neaun&Emrormenr Page 14 of 21 Ill ry. ei t mission Emission Pollutant rac ion actors Factors Source of Gas (%) Uncontrolled Controlled lb/MMscf lb/MMscf N0x (lb N0x/lb ___ 0.0037 0.0037 CDPHE Memo V0C) CO (lb CO/lb --- 0.0094 0.0094 CDPHE Memo V0C) V0C 83.2 100,295 5,014.7 HYSYS Model Benzene 0.27 329.79 16.490 HYSYS Model Toluene 0.22 267.45 13.373 HYSYS Model Ethylbenzene 0.05 56.026 2.8013 HYSYS Model Xylenes 0.09 112.05 5.6026 HYSYS Model n-hexane 1.96 2,364.8 118.24 HYSYS Model 2,2,4- 0.18 210.98 10.549 HYSYS Model Trimethylpentane Note: The uncontrolled V0C and HAP emissions were calculated based on a HYSYS model to estimate the V0C and HAP content of each stream and stream flow. The controlled emissions for this point are based on a flare control efficiency of 95%. Points 011 and 012: Emission Factors - Emission Factors- Controlled Uncontrolled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr N0x 2.2100 9.22 0.2396 1.00 CO 3.7200 15.50 0.4792 2.00 V0C 0.1677 0.70 0.1677 0.70 50000 Formaldehyde 0.0205 0.09 0.0205 0.09 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 4 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9,202 Btu/hp-hr, a il site-rated horsepower value of 239, and a fuel heat value of 1,363 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source N0x AP-42; Table 3.2-3 (7/2000); NSPS JJJJ, Reg 7 Natural Gas CO AP-42; Table 3.2-3 (7/2000); NSPS JJJJ, Reg 7 Natural Gas V0C NSPS JJJJ NSPS JJJJ, Reg 7 50000 Formaldehyde AP-42; Table 3.2-3 (7/2000); No control Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 4, CDPHE COLORADO CO CD.Z1 Pollution Control Division PhTm�,t of cofh c HPalto ft.^,rorrofmt Page 15 of 21 A llu t U controlled EFSource Controlled EF Source 143 cenzene AP- able 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant 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) AIRS ID 011 and 012: Each engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr181a08.pdf 8) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, NOx, CO, HAPs (total and n-hexane) NANSR Synthetic Minor Source of: VOC and NOx MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A- Subpart KKKK NSPS Part 60, Appendixes Appendix A- Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A- Subpart Z MACT 63.600-63.1199 Subpart AA- Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980-End Subpart NNNNN - Subpart XXXXXX * CDPHE COLORADO CO Air Pollution Control Division f:e; menFo;PIblic'r:esirt =rnnrenment Page 16 of 21 • A CHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 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. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The 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. CDPHE COLORADO 14 i CO If Air Pollution Control Division Deontrnent or a,nrf-Healio Eoyfroornent Page 17 of 21 11 III A 2.1. n o •p: ato a ,•erman tly replace the existing compressor engine with another en• - r th t - . - . u . mod- , .nd horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial il 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). III 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: http://www.colorado.gov/cs/Satellite/CDPHE-AP/CBON/1251596520270. 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. GDPHE COLORADO Co Air Pollution Control Division `f DXpan'nFn>o₹Publr Hpaith o E^vnonrnent Page 18 of 21 �.> 3 For i • o a ort- rm mit tha °is either input based (lb/mmBtu), output based (g/hp-hr) ll or : -ntra b (pp • `'15% • that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B S II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and 5O2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. ` CDPHE COLORADO CO G Air Pollution Control Division Department ofP:ablir',Palm&Emnonment Page 19 of 21 --. -- II A The '. i o on of e ip -nt shall ;,e appropriately sized for the engine and shall be operated an. - & aine• . c. to" r" ture .-cifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XV!I.E- State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, I and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 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 * CDHE COLORADO Co Air Pollution Control Division I [,enar:ment.ofa,t>Iic,fain&E•nirrament Page 20 of 21 Appl .bi .R o re ire nd Condit n 2.1.2. Any testing required by the MACT is in addition to tha = fired y th " t the ial 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. • , CDPHE COLORADO co / Air Pollution Control Division Deparmen 5^.,renrent Page 21 of 21 Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 02/16/2016 Application Date: 11/12/2015 Facility Identifiers Permit No. 16WE0159 Potentially located in ozone nonattainment area AIRs County# 123 (Weld Facility# 9E4F Facility Type: exploration and production facility Q Located in the 8-hour non-attainment area? 0 True Minor 0 Synthetic Minor for: F VOC 17 NOx F CO Administrative Information Company Name: Noble Energy Inc. Source Name: LC34 Econode Source Location: NENW Section 34, Township 9N, Range 59W SIC: 1311 Address 1: Noble Energy Inc. Mailing Address 2: 1625 Broadway,Suite 2200 Address ty,State Zip: Denver,CO 80202 Name: Mike Putney Person To Phone: 303-228-4385 Contact Fax: 303-228-4280 Email: mike.putnev@nblenergv.com 'Requested Action Self Certification Required? Yes 11 1 Number: 1 Source Description:Issuance Oil and gas exploration and production facility known as the LC34 Econode,located in the NENW Section 34, Township 9N,Range 59W,Weld County,Colorado. Point Name Type Control Action 006 Tank Battery Condensate Tanks Flare Newly reported source 007 Produced Water Tanks Flare Newly reported source Water 008 Truck Loadout Flare Newly reported source Loadout LP VOC Separator Venting Flare Newly reported source- Emissions from LP 009 Flare Separator during VRU downtime VRT VOC Separator Venting Flare Newly reported source-Emissions from VRT 010 Burners during VRU downtime 011 GEN1 Engine Catalytic Newly reported source Reducer 012 GEN2 Engine Catalytic Newly reported source Reducer 'Pts 001 -005 are engines covered by GP02. Technical Notes: The source submitted the application stating the site was located outside the nonattainment area(NM). I reviewed the site location and wellhead location based on COGCC's online GIS map. Using this map,the site is within the NAA boundary(the northern most well was located at 40.712786 latitude which is below the boundary at 40.71308). Moreover, an existing permitted facility directly to the west of this new facility is Noble AIRS ID 123-9621 and it is listed as within the NAA. I discussed with Mike Putney and he agreed to classify the site as within the NAA. Twelve(12)750 bbl above ground atmospheric fixed roof condensate storage tanks 006 controlled by enclosed flares. Each flare has a minimum control efficiency of 95%. Requsted Throughput 1750000 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2834 lb/bbl 247.9 tpy 12.4 tpy HYSYS Benzene 0.0008 lb/bbl 1351 lb/yr 68 lb/yr HYSYS n-Hexane 0.0055 lb/bbl 9711 lb/yr 486 lb/yr HYSYS Toluene 0.0006 lb/bbl 1,059 lb/yr 53 lb/yr HYSYS Ethylbenze 0.0001 lb/bbl 146 lb/yr 7 lb/yr HYSYS Xylenes 0.0002 lb/bbl 379 lb/yr 19 lb/yr HYSYS 224-TMP 0.0005 lb/bbl 812 lb/yr 41 lb/yr HYSYS Nox 0.0037 lb/lb VOC 1.2 tpy 1.2 tpy CDPHE Memc CO 0.0094 lb/lb VOC 2.6 tpy 2.6 tpy CDPHE Memo 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. 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 420,000 gallons(10,000 bbl) and is located prior to custody transfer. 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 subject to the emission control requirements for condensate tanks since the facility is located in the nonattainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS Applicant is currently subject to this requirement since actual uncontrolled emissions are greater than 20 tpy of VOC and actual uncontrolled emissions are greater than 6 tpy. The tank battery is considered a new tank since it was constructed after 5/1/2014. 16WE0159.CP1.xlsm 123/9E4F Fourteen (14) 500 bbl above ground fixed roof produced water storage tanks 007 controlled by enclosed flares. Each flare has a minimum control efficiency of 95%. Emissions Calculations Requsted Throughput 750000 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 98.3 tpy 4.9 tpy CDPHE Benzene 0.007 lb/bbl 5250 lb/yr 263 lb/yr CDPHE n-Hexane 0.022 lb/bbl 16500 lb/yr 825 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. 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 7—Volatile Organic Compounds XVII.C.1.b Applicant is subject since actual uncontrolled emissions are greater than 6 tpy. The storage tank is considered new since it was constructed after 5/1/2014. I 16WE0159.CP1.xlsm 123/9E4F 008 Hydrocarbon Loadout to Tanker Trucks.The loadout is controlled by an enclosed flare. Calculations L=12.46*S*P*M/T(AP-42:Chapter 5.2, Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source S Saturation Factor 0.6 AP-42 P True Vapor Pressure 6.1374401 psia Based on AP-42, EPA Tanks 4.0.9 output M Molecular Weight of VaF 64 lb/lb-mole Based on AP-42, EPA Tanks 4.0.9 output T Liquid Temperature 512.1225 deg.R Based on AP-42, EPA Tanks 4.0.9 output L 5.73 lb/10^3 gal 2.41E-01 lb/bbl Annual requested Throughput 1750000 BBL/yr 73500000 gal/yr Annual requested VOC emissions 421454 lb/yr 210.73 tpy Control: Flare Efficiency: 95.00% NCRPs Component Mass Fraction Benzene 0.0022 VOC fractioi 0.8180 n-hexane 0.0160 Toluene 0.0017 Ethylbenzeni 0.0002 Xylenes 0.0006 224-TMP 0.0013 Source: HAP mass fraction based on flash emission speciation from condensate tank in Promax run Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2408 lb/bbl 210.7 tpy 10.5 tpy AP-42 Benzene 0.0006 lb/bbl 1133 lb/yr 57 lb/yr AP-42 n-Hexane 0.0047 lb/bbl 8244 lb/yr 412 lb/yr AP-42 Toluene 0.0005 lb/bbl 876 lb/yr 44 lb/yr AP-42 Ethylbenzenl 0.0001 lb/bbl 103 lb/yr 5 lb/yr AP-42 Xylenes 0.0002 lb/bbl 309 lb/yr 15 lb/yr AP-42 224-TMP 0.0004 lb/bbl 670 lb/yr 33 lb/yr AP-42 Regulatory Review Regulation 3 APEN and Permitting Requirements Is this site considered an exploration and production location(e.g.well pad)? Yes 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? No 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? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 16WE0159.CP1.xlsm 123/9E4F . _ __ _ _ . Twenty three low-pressure(LP)separators controlled by an open flare during VRU downtime.The flare has 009 a minimum control efficiency of 95%. Equipment Description This source vents natural gas from: a low pressure separator during VRU downtime Emissions from this source are: routed to a flare 'Natural gas venting from a low pressure separator during VRU downtime.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=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed 156.147 MW=Molecular weight of gas=SG of gas*MW of air 12.49176 Xx=mass fraction of x in gas 0.079908676 C=molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Throughput(Q) 12.4795 MMscf/yr 1424.605213 scf/hr MW 38.32 Ib/Ib-mol 0.034190525 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.12 44.01 0.933 0.024 3.51 30721.80 15.36 N2 0.19 28.013 0.053 0.001 0.20 1752.56 0.88 methane 29.23 16.041 4.689 0.122 17.62 154390.18 77.20 ethane 18.61 30.063 5.595 0.146 21.03 184220.57 92.11 propane 26.71 44.092 11.777 0.307 44.27 387786.88 193.89 isobutane 3.47 58.118 2.017 0.053 7.58 66404.81 33.20 n-butane 12.20 58.118 7.090 0.185 26.65 233469.37 116.73 isopentane 2.07 72.114 1.493 0.039 5.61 49152.92 24.58 n-pentane 2.33 72.114 1.680 0.044 6.32 55326.72 27.66 cyclopentane 0.81 70.13 0.568 0.015 2.14 18704.59 9.35 n-Hexane 0.79 86.18 0.681 0.0178 2.56 22417.80 11.21 cyclohexane 84.16 0.000 0.000 0.00 0.00 0.00 Other hexanes 86.18 0.000 0.000 0.00 0.00 0.00 heptanes 0.61 100.21 0.611 0.016 2.30 20127.99 10.06 methylcyclohexane 98.19 0.000 0.000 0.00 0.00 0.00 224-TMP 0.06 114.23 0.069 0.0018 0.26 2256.79 1.13 Benzene 0.12 78.12 0.094 0.0024 0.35 3086.76 1.54 Toluene 0.09 92.15 0.083 0.0022 0.31 2730.85 1.37 Ethylbenzene 0.01 106.17 0.011 0.0003 0.04 349.59 0.17 Xylenes 0.04 106.17 0.042 0.0011 0.16 1398.37 0.70 C8+Heavies 0.54 154.5772037 0.835 0.022 3.14 27485.18 13.74 VOC mass fraci 0.706 Total VOC(Uncontrolled) 445.35 Notes Mole%and MW of gas are based on stream values for stream labeled"Vapors to VRU/Comb"predicted in HYSYS model Emissions are based on assuming 8%downtime for the VRU I calculated the average MW of C8+based on the average MW on the analysis for the gas. I 16W E0159.CP 1.xlsm 123/9E4F Twenty three low-pressure(LP)separators controlled by an open flare during VRU downtime. The flare has 009 a minimum control efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure separator gas during VRU downtime. Manufacturer Flare Industries Model 4"tip Serial Number Gas Heating Value 2138 Btu/scf Throughput 26681.26008 MMBtu/yr VRU Information -NOT APPLICABLE.VRU IS PART OF THE PROCESS Equipment Description Make Model Requested Control Efficiency Annual B ass Time Backup I Flare Overall Control 95.00% Combustion emission factor source: CDPHE Memo 0.0037 Ilb NOX/Ib VOC 0.0094 IIb CO/lb VOC Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions VOC 71373 lb/MMscf 3568.6 lb/MMscf 445.3 tpy 22.3 tpy Nox 0.0037 lb Nox/lb VOC 0.0037 lb Nox/lb VOC 1.7 tpy 1.7 tpy CO 0.0094 lb CO/lb VOC 0.0094 lb CO/lb VOC 4.2 tpy 4.2 tpy Benzene 247.35 lb/MMscf 12.367 lb/MMscf 3087 lb/yr 154 lb/yr n-Hexane 1796.4 lb/MMscf 89.818 lb/MMscf 22418 lb/yr 1121 lb/yr Toluene 218.83 lb/MMscf 10.941 lb/MMscf 2731 lb/yr 137 lb/yr Ethylbenzene 28.013 lb/MMscf 1.4007 lb/MMscf 350 lb/yr 17 lb/yr Xylenes 112.05 lb/MMscf 5.6026 Ib/MMscf 1398 lb/yr 70 lb/yr 224-TMP 180.84 lb/MMscf 9.0420 Ib/MMscf 2257 lb/yr 113 lb/yr 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 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 • One(1)vapor recovery towers(VRTs)controlled by enclosed flares during VRU downtime. Each flare has a 010 minimum control efficiency of 95%. Equipment Description This source vents natural gas from: vapor recovery towers(VRTS)during VRU downtime Emissions from this source are: routed to a flare 'Natural gas venting from vapor recovery towers(VRTS)during VRU downtime. 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=Q*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(Q) 3.615 MMscf/yr 412.6617199 scf/hr MW 45.68 Ib/Ib-mol 0.009903881 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 1.37 44.01 0.603 0.013 0.66 5750.84 2.88 N2 0.03 28.013 0.008 0.000 0.01 80.16 0.04 methane 10.39 16.041 1.667 0.036 1.81 15896.67 7.95 ethane 17.93 30.063 5.390 0.118 5.87 51412.85 25.71 propane 36.73 44.092 16.195 0.355 17.63 154468.46 77.23 isobutane 5.18 58.118 3.011 0.066 3.28 28714.38 14.36 n-butane 18.23 58.118 10.595 0.232 11.54 101054.67 50.53 isopentane 3.02 72.114 2.178 0.048 2.37 20772.35, 10.39 n-pentane 3.34 72.114 2.409 0.053 2.62 22973.39 11.49 cyclopentane 1.09 70.13 0.764 0.017 0.83 7291.04 3.65 n-Hexane 1.04 86.18 0.896 0.0196 0.98 8548.68 4.27 cyclohexane 84.16 0.000 0.000 0.00 0.00 0.00 Other hexanes 86.18 0.000 0.000 0.00 0.00 0.00 heptanes 0.73 100.21 0.732 0.016 0.80 6977.39 3.49 methylcyclohexane 98.19 0.000 0.000 0.00 0.00 0.00 224-TMP 0.07 114.23 0.080 0.0018 0.09 762.67 0.38 Benzene 0.16 78.12 0.125 0.0027 0.14 1192.18 0.60 Toluene 0.11 92.15 0.101 0.0022 0.11 966.82 0.48 Ethylbenzene 0.02 106.17 0.021 0.0005 0.02, 202.53 0.10 Xylenes 0.04 106.17 0.042 0.0009 0.05 405.06 0.20 C8+Heavies 0.54 159.7399074 0.863 0.019 0.94 8227.47 4.11 VOC mass fracl 0.832 Total VOC(Uncontrolled) 181.28 Notes Mole%and MW of gas are based on stream values for stream labeled"Vaports to VRTVRU/Comb"predicted in HYSYS model Emissions are based on assuming 8%downtime for the VRU I calculated the average MW of C8+based on the average MW on the analysis for the gas. One(1)vapor recovery towers(VRTs)controlled by enclosed flares during VRU downtime. Each flare has a 010 minimum control efficiency of 95%. Flaring Information Equipment Description Flare to combust VRT gas during VRU downtime. Manufacturer LEED Model 48" Serial Number _ Gas Heating Value 2551.7 Btu/scf Throughput 9224.182858 MMBtu/yr VRU Information -NOT APPLICABLE.VRU IS PART OF THE PROCESS Equipment Description Make Model Requested Control Efficiency Annual Bypass Time Backup I Flare Overall Control 95.00% Combustion emission factor source: CDPHE Memo 0.0037 llb NOX/Ib VOC 0.0094 llb CO/lb VOC Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions VOC 100295 lb/MMscf 5014.7 Ib/MMscf 181.3 tpy 9.1 tpy Nox 0.0037 lb Nox/lb VOC 0.0037 lb Nox/lb VOC 0.7 tpy 0.7 tpy CO 0.0094 lb CO/lb VOC 0.0094 lb CO/lb VOC 1.7 tpy 1.7 tpy Benzene 329.79 lb/MMscf 16.490 lb/MMscf 1192 lb/yr 60 lb/yr n-Hexane 2364.8 lb/MMscf 118.24 lb/MMscf 8549 lb/yr 427 lb/yr Toluene 267.45 lb/MMscf 13.373 lb/MMscf 967 lb/yr 48 lb/yr Ethylbenzene 56.026 lb/MMscf 2.8013 lb/MMscf 203 lb/yr 10 lb/yr Xylenes 112.05 lb/MMscf 5.6026 lb/MMscf 405 lb/yr 20 lb/yr 224-TMP 210.98 lb/MMscf 10.549 lb/MMscf 763 lb/yr 38 lb/yr 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 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 One(1)Doosan(NG),Model D8.1L,Serial Number EEPOG301533,natural gas-fired,turbocharged, 4SRB reciprocating internal combustion engine,site rated at 239 horsepower at 1800 RPM.This engine shall be equipped with non-selective catalytic reduction(NSCR)system and air-fuel ratio control.This emission unit is used for primary power generation. 011 Engine Information Engine date of m 7/29/2013 Manufacturer:Doosan(NG) Model Number: D8.1L Serial Number: EEPOG301533 RPM: 1800 Site-rated RPM: 1800 Engine Function Primary and/or peaking power berating Mfg's Max.Rated Horsepower @ sea level: 239 Horsepower used for calcuations: 239 BSCF @ 100%Load(btu/hp-hr): 9202 Site-Rated BSCF @ 100%load(btu/hp-hr): 9202 Engine Type 4SRB Other Parameters Aspiration turbo-charged Electrical Generator Max Site Rating(kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100%Load 1613.55686 scf/hr ACTUAL Annual Fuel Consumption 0 MMscf/yr MAR HU I tiv i IAL Annuali-uei Consumption 14.135 MMscf/yr REQUESTED Annual Fuel Consumption 14.135 MMscf/yr Fuel Heating Value 1363 btu/scf Emission Control Information This engine shall be equipped with 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 2.210 Ib/MMBTU 0.240 Ib/MMBTU 21.3 tpy 2.3 tpy CO 3.720 Ib/MMBTU 0.479 Ib/MMBTU 35.8 tpy 4.6 tpy VOC 0.168 Ib/MMBTU 0.168 Ib/MMBTU 1.6 tpy 1.6 tpy Formaldehyde 0.021 Ib/MMBTU 0.021 Ib/MMBTU 395 lb/yr 395 lb/yr Acetaldehyde 0.003 lb/MMBTU 0.003 lb/MMBTU 54 lb/yr 54 lb/yr Acrolein 0.003 Ib/MMBTU 0.003 lb/MMBTU 50 lb/yr 50 lb/yr Benzene 0.002 Ib/MMBTU 0.002 Ib/MMBTU 31 lb/yr 31 lb/yr 16WE0159.CP1.xlsm One(1)Doosan(NG),Model D8.1L,Serial Number EEPOG301533,natural gas-fired,turbocharged, 4SRB reciprocating internal combustion engine,site rated at 239 horsepower at 1800 RPM.This engine shall be equipped with non-selective catalytic reduction(NSCR)system and air-fuel ratio control.This emission unit is used for primary power generation. 011 Regulatory Requirements Ambient Air Imps Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 7777 Facility is an area source of HAPs,so engine is not subject to major source requirements.Engine is new Reg 7 XVII.E.2 The engine is not subject to Reg 7 because even though the max engine rating is greater than 100 hp and h�)ndards(g/hp- it was constructed after 1/1/2008,the engine is subject to NSPS JJJJ Reg 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 Engine is not subject to Reg 7 XVI.B because rated less than 500 hp requirements) applies? MACT ZZZZ(area Is this engine subject to MACT 7777 area source requirements? No Per 63.6590(c)(1),a new RICE at an area source) 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 Source 1 AP-42,Table 3.2-3 AP-42,Table 3.2-3 NSPS JJJJ/Reg 7(which is higher than AP-42) AP-42,Table 3.2-3 AP-42,Table 3.2-3 AP-42,Table 3.2-3 AP-42,Table 3.2-3 source must follow NSPS JJJJ to meet MACT 7777 One(1)Doosan(NG),Model D8.1L,Serial Number EEPOG301830,natural gas-fired,turbocharged, 4SRB reciprocating internal combustion engine,site rated at 239 horsepower at 1800 RPM.This engine shall be equipped with non-selective catalytic reduction(NSCR)system and air-fuel ratio control.This emission unit is used for primary power generation. 012 Engine Information Engine date of m 12/3/2013 Manufacturer: Doosan(NG) Model Number: D8.1L Serial Number: EEPOG301830 RPM: 1800 Site-rated RPM: 1800 Engine Function Primary and/or peaking power berating Mfg's Max.Rated Horsepower @ sea level: 239 Horsepower used for calcuations: 239 BSCF @ 100%Load(btu/hp-hr): 9202 Site-Rated BSCF @ 100%load(btu/hp-hr): 9202 Engine Type 4SRB Other Parameters Aspiration turbo-charged Electrical Generator Max Site Rating(kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100%Load 1613.55686 scf/hr ACTUAL Annual Fuel Consumption 0 MMscf/yr MAX NV I tN I IAL Annual ruel Consumption 14.135 MMscf/yr REQUESTED Annual Fuel Consumption 14.135 MMscf/yr Fuel Heating Value 1363 btu/scf Emission Control Information This engine shall be equipped with 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 2.210 lb/MMBTU 0.240 lb/MMBTU 21.3 tpy 2.3 tpy CO 3.720 Ib/MMBTU 0.479 Ib/MMBTU 35.8 tpy 4.6 tpy VOC 0.168 lb/MMBTU 0.168 lb/MMBTU 1.6 tpy 1.6 tpy Formaldehyde 0.021 Ib/MMBTU 0.021 Ib/MMBTU 395 lb/yr 395 lb/yr Acetaldehyde 0.003 lb/MMBTU 0.003 _ lb/MMBTU 54 lb/yr 54 lb/yr Acrolein 0.003 lb/MMBTU 0.003 Ib/MMBTU 50 lb/yr 50:lb/yr Benzene 0.002 lb/MMBTU 0.002 lb/MMBTU 31 lb/yr 31 lb/yr One(1)Doosan(NG),Model D8.1L,Serial Number EEPOG301830,natural gas-fired,turbocharged, 4SRB reciprocating intemal combustion engine,site rated at 239 horsepower at 1800 RPM.This engine shall be equipped with non-selective catalytic reduction(NSCR)system and air-fuel ratio control.This emission unit is used for primary power generation. 012 Regulatory Requirements Ambient Air Impa Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 7777 Facility is an area source of HAPs,so engine is not subject to major source requirements.Engine is new Reg 7 XVII.E.2 The engine is not subject to Reg 7 because even though the max engine rating is greater than 100 hp and Standards(g/hp-it was constructed after 1/1/2008,the engine is subject to NSPS JJJJ hr) 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 Engine is not subject to Reg 7 XVI.B because rated less than 500 hp requirements) applies? MACT 7772(area Is this engine subject to MACT 7777 area source requirements? No Per 63.6590(c)(1),a new RICE at an area 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 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Noble Energy,Inc. Addendum Form Page 1 Source Name: LC34 Econode Emissions Source AIRS ID2: N/A/ / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05-123-40601 Haley LC27-745 05-123—40640 Jessica LC27-775 05-123-40642 Jessica LC27-785 TBD- - Ann LC34-755 TBD- - Ann LC34-765 TBD- - Douglas LC35-770 TBD- - Douglas LC35-780 TBD- - Faith LC34-775 TBD- Faith LC34-785 TBD- - JD LC26-770 TBD- - JD LC26-780 TBD- - Kerri LC26-760 TBD- - Lynn LC35-750 TBD- - Lynn LC35-760 TBD- - Remora LC34-715 TBD- - Remora LC34-725 TBD- - Remora LC34-735 TBD- - Remora LC34-745 - - ❑ - - ❑ Footnotes: 1 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 4:?E.,_ ftiLlY.12 Form APCD-212 APEN-Addendum_Forml Tanks Nov 2015 kin cn •o a) co izzzzz > a) o E o o Cf. V W ?' 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Addendum Form Page 1 Source Name: LC34 Econode Emissions Source AIRS ID2: N/A/ / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05- 123-40601 Haley LC27-745 05-123—40640 Jessica LC27-775 05-123-40642 Jessica LC27-785 El TBD- - Ann LC34-755 El TBD- - Ann LC34-765 TBD- - Douglas LC35-770 TBD- - Douglas LC35-780 El TBD - - Faith LC34-775 TBD- - Faith LC34-785 TBD - - JD LC26-770 P TBD- - JD LC26-780 El TBD - - Kerri LC26-760 TBD- - Lynn LC35-750 TBD - - Lynn LC35-760 TBD- - Remora LC34-715 TBD- - Remora LC34-725 TBD- - Remora LC34-735 TBD - - Remora LC34-745 ID Footnotes: 1 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 Nov 2015 I o b .. O .0 oo ❑0 ❑0 0 0 �, ° O - O. 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