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Home My WebLink About20143507.tiff• CDPHE COLORADO CO A Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 November 10, 2014 Dear Sir or Madam: On November 12, 2014, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - Rohn LD09 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 date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health 8 Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, f, ! ' fa.eL t. ftkty Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure • • • JF CO 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe ``+ DE l'E 1Ex John W. Hickentooper, Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ,, ; o' �a� 1. TUJOLCC/ 11•10.0<A))1-17- I 20P-1 -5C07 �{ CC • PL,�W, L1��13 CDPHE Public Notice Of A Proposed Project t ► Or Activity Warranting Public CO Comment Website Title: Noble Energy, Inc. - Rohn LD09 EcoNode - Weld County Notice Period Begins: November 12, 2014 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: Rohn LD09 EcoNode Oil and Natural Gas Exploration and Production Facility . E/2 Section 9, T9N, R58W, approximately 10.5 miles north of Raymer, CO Weld County The proposed project or activity is as follows: Applicant proposes to construct a new exploration and production facility with an annual condensate throughput of 2,185,000 BBL. 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 14WE0639 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: Oluwaseun Ogungbenle Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us AV COLORADO 1 I „ • n STATE OF COLORADO �p,�,�7�, of•Coto DRRAFKM C HEALTH AND ENVIRONMENT Ec'. AIR POLLUTION CONTROL DIVISION y TELEPHONE: (303)692-3150 :`tc ." *18]6* CONSTRUCTION PERMIT PERMIT NO: 14WE0639 Issuance 1 DATE ISSUED: ISSUED TO: Noble Energy, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the Rohn LD09 EcoNode, located in the E/2 Section 9, Township 9N, Range 58W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Thirty-six (36) above ground atmospheric condensate storage Tanks 001 tanks with a total capacity of 27,000 bbl. Emissions from these tanks are controlled by an enclosed flare with a minimum combustion efficiency of 95%. Twelve (12) above ground 538 bbl and one (1) below ground 60 PW 002 bbl produced water storage tanks. Emissions from these tanks are controlled by an enclosed flare with a minimum combustion efficiency of 95%. Truck Condensate Loadout. Emissions from this loadout operation TLO 003 are controlled by an enclosed flare with a minimum combustion efficiency of 95%. I Flare 004 Separator controlled by a flare stack. Flare has a minimum combustion efficiency of 95%. Fugitives 005 Fugitive equipment leaks. One (1) Caterpillar, Model G3516B, Serial Number JEF02162, natural gas-fired, turbo-charged, 4SLB reciprocating internal GL Comp1 006 combustion engine, site rated at 1380 horsepower at 1400 RPM. This engine is equipped with an oxidation catalyst and air/fuel ratio controller. This emission unit is used for natural gas compression. AIRS ID: 123/9CA1 Page 1 of 31 olor Depa en li ealth and Environment RAI°rDePa it Pollution Control Division Facility AIRS Equipment Point Description ID One (1) Caterpillar, Model G3516B, Serial Number JEF02207, natural gas-fired, turbo-charged, 4SLB reciprocating internal GL Comp2 007 combustion engine, site rated at 1380 horsepower at 1400 RPM. This engine is equipped with an oxidation catalyst and air/fuel ratio controller. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3304NA, Serial Number N4F03309, natural gas-fired, naturally aspirated, 4SRB reciprocating internal WH Comp1 008 combustion engine, site rated at 95 horsepower at 1800 RPM. This engine is equipped with a non-selective catalytic reduction (NSCR) system and air/fuel ratio controller. This emission unit is used for natural gas compression. One(1) Cummins, Model G8.3 C118, Serial Number 46593798, natural gas-fired, naturally aspirated, 4SRB reciprocating internal VRU 009 combustion engine, site rated at 118 horsepower at 1800 RPM. Comp1 This engine is equipped with a non-selective catalytic reduction (NSCR) system and air/fuel ratio controller. This emission unit is used for natural gas compression. One (1) Doosan, Model D146L, Serial Number EEZOG100146, natural gas-fired, naturally aspirated, 4SRB reciprocating internal LACT 010 combustion engine, site rated at 449 horsepower at 1800 RPM. Generator This engine is uncontrolled. This emission unit is used for power generation. One (1) diesel-fired reciprocating internal combustion engine (Make, Model, and Serial Number: To Be Determined), site heat Gen2 011 input rated at 7,000 BTU/hp-hr, having a site rated output at or below 274 HP, powering generator set. This engine is uncontrolled. This emission unit is used for power generation.This engine may be subject to NSPS 1111 Interim Tier 4 Standards. Points 006 and 007: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3516B engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 008: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3304NA engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 009: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Cummins G8.3 C118 engine in accordance with the permanent replacement provision of the Altemate Operating Scenario (AOS), included in this permit as Attachment A. AIRS ID: 123/9CA1 Page 2 of 31 olor Depa en P li Health and it Pollution ControlEnvironment Division Point 010: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Doosan D146L engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 011: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with the manufacturer and model submitted to the Division per Requirements to Self-Certify for Final Authorization in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment B. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained 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. (Reference: Regulation No. 3, Part B, 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 per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information for each engine shall be provided to the Division within fifteen (15) days after issuance of permit. • manufacturer • model number • serial number AIRS ID: 123/9CA1 Page 3 of 31 Dolor Depa en li ealth and Environment it Pollution Control Division This informati he Start miffed for the equipment. (Reference: Regulation No. 3, Part B, 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 (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Equipment ID Point NO, VOC CO Emission Type Tanks 001 — 42.6 — Point PW 002 — 5.9 — Point TLO 003 — 8.9 — Point Flare 004 3.1 30.6 16.8 Point Fugitives 005 — 63.9 — Fugitive GL Comp1 006 6.7 3.3 2.7 Point GL Comp2 007 6.7 3.3 2.7 Point WH Comp1 008 0.9 0.6 1.8 Point VRU Comp1 009 1.1 0.8 2.3 Point LACT 010 2.2 2.2 2.2 Point Generator Gen2 011 11.8 0.6 14.6 Point 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 be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. AIRS ID: 123/9CA1 Page 4 of 31 Depa en P li Health and Environment it Pollution Control Division 8. Point 005: ThDolor ac ions his emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 9. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed 100 tons per year of any criteria pollutant. 10. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Equipment Point Control Device Pollutants Controlled ID Tanks 001 Enclosed Flare VOC & HAPs PW 002 Enclosed Flare VOC & HAPs TLO 003 Enclosed Flare VOC & HAPs Flare 004 Open Flare VOC& HAPs Fugitives 005 Other VOC & HAPs GL Comp1 006 Catalytic Oxidizer with AFRC CO, VOC, & HCHO GL Comp2 007 Catalytic Oxidizer with AFRO CO,VOC, & HCHO WH Comp1 008 Catalytic Reducer with AFRC NOx, CO, VOC, & HCHO VRU Comp1 009 Catalytic Reducer with AFRO NOx&CO PROCESS LIMITATIONS AND RECORDS 11. 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. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point Tanks 001 Condensate Throughput 2,185,000 BBL/yr PW 002 Produced Water Throughput 900,000 BBUyr AIRS ID: 123/9CA1 Page 5 of 31 epa en ealth and Environment li Tit Pollution Control Division TLODolor3n ing 2,185,000 BBL/yr Flare 004 Natural gas flaring 69 MMscf/yr Fugitives 005 NA --- GL Comp1 006 Consumption of natural gas as fuel 76.5 MMscf/yr GL Comp2 007 Consumption of natural gas as fuel 76.5 MMscf/yr Wh Comp1 008 Consumption of natural gas as fuel 5.5 MMscf/yr VRU Comp1 009 Consiumption of natural gas as fuel 6.6 MMscf/yr LACT Generator 010 Consumption of natural gas as fuel 23.9 MMscf/yr Gen2 011 Consumption of diesel as fuel 117,384 gal/yr Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each m nth 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. 12. Point 003: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. Points 006-011: 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.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. &4.) 15. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 16. Points 003 and 004: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 17. Points 001 and 002: The flare 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.1.b 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, AIRS ID: 123/9CA1 Page 6 of 31 olor Depa en P Iiit Health andControl Environment Pollution Division deter ' -- - - h 's 'ng The tor shall comply with all applicable requirements of Section XVII. XVII.B.2.d.(ii) 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. 18. Point 001: 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)(b) Control requirements of Section XVII.C.1.b. must be achieved by May 1, 2015. 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 constructed before May 1, 2014 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 XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. 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. AIRS ID: 123/9CA1 Page 7 of 31 Depa en li ealth and Environment it Pollution Control Division XVII.C.1.e. IfDolor n ed t is , 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 XVIl.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 I 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)(b) A storage tank constructed before May 1, 2014, must comply with the requirements of Sections XVII.C.2.a. and XVII.C.2.b. by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within thirty (30) days for storage tanks with uncontrolled actual VOC emissions greater than 50 tons per year. 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 AIRS ID: 123/9CA1 Page 8 of 31 olor Depa en li Health and Environment it Pollution Control Division Thies . G. " tora n Ap trum Phase-In Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency > 6 and < 12 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. 19. Point 003: 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): AIRS ID: 123/9CA1 Page 9 of 31 olor epa en li earth and Environment it Pollution Control Division a. Hoses s, v al fined event 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. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with Condition 19 (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. 20. Point 003: 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. 21. Point 009: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum' Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A 2100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 2500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. Note: Per Regulation No. 7, Section XVII.B.4, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. 22. Point 011: This engine is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart 1111, Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (CI ICE) including, but not limited to, the following: a. Owners and operators of 2007 model year and later non-emergency stationary CI ICE with a displacement of less than 30 liters per cylinder must comply with the emission standards for new CI engines in 40 CFR 60.4201 for their 2007 • model year and later stationary CI ICE, as applicable. AIRS ID: 123/9CA1 Page 10 of 31 olor Depa en P Ii Health and Environment it Pollution Control Division b. All fue . all t wi ation (I) Sulfur content shall not exceed 15 ppm. (ii) Have a minimum cetane index of 40 or Have a maximum aromatic compound content of 35% by volume. Compliance shall be demonstrated by maintaining copies of the fuel specifications provided by the supplier on-site or in a readily accessible location and made available to the Division for inspection upon request. c. All engines and control devices must be installed, configured, operated, and maintained according to the specifications and instructions provided by the engine manufacturer. d. If the engine is equipped with a diesel particulate filter, the filter must be installed with a backpressure monitor that notifies the owner or operator when the high backpressure limit of the engine is approached. Records shall be kept of any corrective action taken after the backpressure monitor has notified the owner or operator that the high backpressure limit is approached. If the engine is an emergency stationary CI internal combustion engine that does not meet the standards applicable to non-emergency engines, you must install a non- resettable hour meter prior to startup of the engine per Subpart 1111 §60.4209(a). 23. Point 011: The following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, including but not limited to, apply: a. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 b. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (§ 60.12) OPERATING & MAINTENANCE REQUIREMENTS 24. Points 001-009: Upon issuance of this permit, 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 your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/9CA1 Page 11 of 31 Depa en li ealth and Environment it Pollution Control Division 25. Points 010 aDolor i r t r folio 'vision-approved operating and maintenance plan for these emission points. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 26. Points 001 and 004: The owner or operator shall demonstrate compliance with the no visible emissions requirement, using EPA Method 22 to measure opacity from the flare. The observation period shall be a minimum of fifteen consecutive minutes. 27. Point 004: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content(weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self- certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 28. Point 005: Within one hundred and eighty days (180) after issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas analysis and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 29. Point 005: Within one hundred and eighty days (180) after issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 30. Points 006 and 007: A source initial compliance test shall be conducted on emissions points 006 and 007 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Formaldehyde 31. Point 009: A source initial compliance test shall be conducted on emissions point 009 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in AIRS ID: 123/9CA1 Page 12 of 31 olor Depa en P Ii Health and it Pollution ControlEnvironment Division accordance -q ' e ' n C Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 32. Point 011: The owner or operator shall demonstrate compliance with Condition 14, using EPA Method 9 to measure opacity from this source. The opacity shall be measured and interpreted as an average of the readings taken over fifteen (15) second intervals for a total of six (6) minutes. (Reference: Regulation No. 1, Section II.A.1 & 4) Periodic Testing Requirements 33. Points 004: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the flare in order to verify the VOC content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. 34. Point 005: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 35. Points 006-009: These engines are subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 36. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. 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 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 AIRS ID: 123/9CA1 Page 13 of 31 olor Depa en li Health and Environment it Pollution Control Division For a It If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Points 006-010: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. g. Point 011: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment B. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 37. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) 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 No. 3 Part D). 38. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 39. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 40. 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 AIRS ID: 123/9CA1 Page 14 of 31 olor Depa en li Health and Environment it Pollution Control Division permit does n' de " ' " a fo • ' ity or ation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 41. 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. 42. 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. 43. 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. 44. 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. 45. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. AIRS ID: 123/9CA1 Page 15 of 31 Dolor epa en li ealth and Environment it Pollution Control Division By: Oluwaseun Ogungbenle Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. for a new E&P site. AIRS ID: 123/9CA1 Page 16 of 31 olor Depa en P Ii Health and it Pollution ControlEnvironment Division Notes to Permit Holder = - me o e a . 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 (Reference: Regulation No. 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: http://www.colorado.eov/cs/Satellite?c=Document C&childpaciename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 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. Uncontrolle d Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (Ib/yr) Benzene 71432 12018 Yes 601 001 n-Hexane 110543 78660 Yes 3933 Benzene 71432 6300 Yes 315 002 n-Hexane 110543 19800 Yes 990 Benzene 71432 2185 Yes 109 n-Hexane 110543 6555 Yes 328 003 Toluene 108883 4370 Yes 219 Xylenes 1330207 2185 Yes 109 Benzene 71432 8425 Yes 421 Toluene 108883 8425 Yes 421 Ethylbenzene 100414 4212 Yes 211 004 Xylenes 1330207 4212 Yes 211 n-Hexane 110543 25274 Yes 1264 2,2,4-TMP 540841 4212 Yes 211 Benzene 71432 3,914 Yes 2124 005 Toluene 108883 3,914 Yes 2124 AIRS ID: 123/9CA1 Page 17 of 31 olor epa en li ealth and Environment it Pollution Control Division Ethyl 316 Xylenes 1330207 568 Yes 316 n-Hexane 110543 7,113 Yes 3888 Formaldehyde 50000 11,727 Yes 2,665 Acetaldehyde 75070 831 Yes 831 Acrolein 107028 511 Yes 511 006 Methanol 67561 249 No 249 n-Hexane 110543 110 No 110 Benzene 71432 44 No 44 Toluene 108883 41 No 41 Formaldehyde 50000 11,727 Yes 2,665 Acetaldehyde 75070 831 Yes 831 Acrolein 107028 511 Yes 511 007 Methanol 67561 249 No 249 n-Hexane 110543 110 No 110 Benzene 71432 44 No 44 Toluene 108883 41 No 41 Formaldehyde 50000 495 Yes 110 Acetaldehyde 75070 20 No 20 008 Acrolein 107028 19 No 19 Benzene 71432 11 No 11 Formaldehyde 50000 175 no 175 Acetaldehyde 75070 24 No 24 009 Acrolein 107028 22 No 22 Benzene 71432 24 No 24 Formaldehyde 50000 638 Yes 638 Acetaldehyde 75070 87 No 87 010 Acrolein 107028 82 No 82 Benzene 71432 49 No 49 Formaldehyde 50000 20 No 20 011 Acetaldehyde 75070 13 No 13 Benzene 71432 5 No 5 AIRS ID: 123/9CA1 Page 18 of 31 olor Depa en P li Health and Environment it Pollution Control Division 5) The emission level d i b folio ission factors: Point 001: Emission Factors Emission Factors Uncontrolled Controlled Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput VOC 0.78 0.039 EPA TANKS 4.09d n-Hexane 0.036 1.8E-03 EPA TANKS 4.09d Benzene 0.0055 2.75E-04 EPA TANKS 4.09d Note: The controlled emissions for this point are based on a flare control efficiency of 95%. Point 002: Emission Factors Emission Factors Pollutant Uncontrolled Uncontrolled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 PS Memo 09-02 n-Hexane 0.022 0.0011 PS Memo 09-02 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions for this point are based on a flare control efficiency of 95%. Point 003: Emission Factors - Emission Factors - Uncontrolled Uncontrolled Pollutant lb/BBL Source lb/BBL Source loaded loaded VOC 0.162 AP-42 0.0081 AP-42 71432 Benzene 0.0015 Eng. Calc 7.28E-05 Eng. Calc 108883 Toluene 0.0021 Eng. Calc 1.05E-04 Eng. Calc 100414 Ethylbenzene 0.0002 Eng. Calc 8.09E-06 Eng. Calc 1330207 Xylenes 0.0008 Eng. Calc 4.04E-05 Eng. Calc 110543 n-Hexane 0.0026 Eng. Calc 1.29E-04 Eng. Calc 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) = 3.94 psia M (vapor molecular weight) =68 lb/lb-mol T (temperature of liquid loaded) = 520 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. AIRS ID: 123/9CA1 Page 19 of 31 olor Depa en li ealth and Environment fr Pollution Control Division Controlled emi rs jc fla of 9 Point 004: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled 0.068 0.068 NOx "' lb/MMBtu lb/MMBtu AP-42 0.37 0.37 -COlb/MMBtu lb/MMBtu AP-42 VOC 29.01 17713.04 885.65 Engineering lb/MMscf lb/MMscf Calculation Benzene 0.20 122.101 6.105 Engineering lb/MMscf lb/MMscf Calculation Toluene 0.20 122.101 6.105 Engineering lb/MMscf lb/MMscf Calculation Ethylbenzene 0.10 61.043 3.052 Engineering lb/MMscf lb/MMscf Calculation Xylenes 0.10 61.043 3.052 Engineering lb/MMscf lb/MMscf Calculation n-Hexane 0.60 366.290 18.314 Engineering lb/MMscf lb/MMscf Calculation 2,2,4-TMP 0.10 61.043 3.052 Engineering lb/MMscf lb/MMscf Calculation Point 005: Component Gas Heavy Oil Light Oil Water/Oil Connectors 2717 179 1647 379 Flanges 485 0 375 48 Open-ended Lines 3 0 0 0 Pump Seals 0 0 4 0 Valves 1538 69 1612 293 Other 432 40 201 100 VOC Content(wt. 0.2901 1.0000 1.0000 1.0000 fraction) Benzene Content(wt. 0.0020 0.0000 0.0300 0.0003 fraction) Toluene Content(wt. 0.0020 0.0000 0.0300 0.0003 fraction) Ethylbenzene(wt. 0.0010 0.0000 0.0030 0.0000 fraction) Xylenes Content(wt. 0.0010 0.0000 0.0030 0.0000 fraction) n-hexane Content(wt. 0.0060 0.0000 0.0500 0.0005 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): AIRS ID: 123/9CA1 Page 20 of 31 :, olor-i Depa en li Health and Environment it Pollution Control Division Component Gas ervice Heavy I ig t Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-4531R-95-017 Table 2-4 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Point 006: Emission Factors - Emission Factors— Source Uncontrolled Controlled NOx 0.5 g/hp-hr 0.5 g/hp-hr Manufacturer CO 2.43 g/hp-hr 0.2 g/hp-hr Manufacturer VOC 0.71 g/hp-hr 0.25 g/hp-hr Manufacturer Formaldehyde 0.44 g/hp-hr 0.1 g/hp-hr Manufacturer Acetaldehyde 0.0084 lb/MMBTU 0.0084 lb/MMBTU AP-42 Acrolein 0.0051 lb/MMBTU 0.0051 lb/MMBTU AP-42 Benzene 0.0004 lb/MMBTU 0.0004 lb/MMBTU AP-42 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8226 Btu/hp-hr, a site-rated horsepower value of 1380, and a fuel heating value of 1300 Btu/scf. Point 007: Emission Factors - Emission Factors— Source Uncontrolled Controlled NOx 0.5 g/hp-hr 0.5 g/hp-hr Manufacturer CO 2.43 g/hp-hr 0.2 g/hp-hr Manufacturer VOC 0.71 g/hp-hr 0.25 g/hp-hr Manufacturer Formaldehyde 0.44 g/hp-hr 0.1 g/hp-hr Manufacturer Acetaldehyde 0.0084 Ib/MMBTU 0.0084 Ib/MMBTU AP-42 Acrolein 0.0051 Ib/MMBTU 0.0051 lb/MMBTU AP-42 Benzene 0.0004 lb/MMBTU 0.0004 Ib/MMBTU AP-42 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8226 Btu/hp-hr, a site-rated horsepower value of 1380, and a fuel heating value of 1300 Btu/scf. Point 008: Emission Factors - Emission Factors— Source Uncontrolled Controlled NOx 13.11 g/hp-hr 1.0 g/hp-hr Manufacturer CO 13.11 g/hp-hr 2.0 g/hp-hr Manufacturer VOC 0.93 g/hp-hr 0.7 g/hp-hr Manufacturer Formaldehyde 0.27 q/hp-hr 0.06 g/hp-hr Manufacturer AIRS ID: 123/9CA1 Page 21 of 31 olor Depa en Ii eattho and it Pollution ControlEnvironment Division I a sion — Source Uncontrolled Controlled Acetaldehyde 0.0028 Ib/MMBTU 0.0028 Ib/MMBTU AP-42 Acrolein 0.0026 lb/MMBTU 0.0026 lb/MMBTU AP-42 Benzene 0.0016 Ib/MMBTU 0.0016 Ib/MMBTU AP-42 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8586 Btu/hp-hr, a site-rated horsepower value of 95, and a fuel heating value of 1300 Btu/scf. Point 009: Emission Factors- Emission Factors— Source Uncontrolled Controlled NOx 11.6 g/hp-hr 1.0 g/hp-hr Manufacturer CO 11.0 g/hp-hr 2.0 g/hp-hr Manufacturer VOC 0.7 g/hp-hr 0.7 g/hp-hr Manufacturer Formaldehyde 0.0205 lb/MMBTU 0.0205 Ib/MMBTU AP-42 Acetaldehyde 0.0028 Ib/MMBTU 0.0028 lb/MMBTU AP-42 Acrolein 0.0026 Ib/MMBTU 0.0026 lb/MMBTU AP-42 Benzene 0.0016 Ib/MMBTU 0.0016 Ib/MMBTU AP-42 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8266 Btu/hp-hr, a site-rated horsepower value of 118, and a fuel heating value of 1300 Btu/scf. Point 010: Emission Factors- Emission Factors— Source Uncontrolled Controlled NOx 0.5 g/hp-hr 0.5 g/hp-hr Manufacturer CO 0.5 g/hp-hr 0.5 g/hp-hr Manufacturer VOC 0.5 g/hp-hr 0.5 g/hp-hr Manufacturer Formaldehyde 0.0205 Ib/MMBTU 0.0205 Ib/MMBTU AP-42 Acetaldehyde 0.0028 Ib/MMBTU , 0.0028 lb/MMBTU AP-42 Acrolein 0.0026 Ib/MMBTU 0.0026 Ib/MMBTU AP-42 Benzene 0.0016 Ib/MMBTU 0.0016 Ib/MMBTU AP-42 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7914 Btu/hp-hr, a site-rated horsepower value of 449, and a fuel heating value of 1300 Btu/scf. Point 011: Emission Factors - Emission Factors- Uncontrolled Controlled CAS Pollutant Ib/MMBtu lb/MMBtu g/kW-hr g/kW-hr NOx --- - 5.99 5.99 CO -- - 7.38 7.38 VOC - - 0.32 0.32 SOx 0.29 0.29 - - 50000 Formaldehyde 0.0008 0.0008 — — `Note that these emission factors are based on manufacturer's specifications for maximum load and represent the manufacturer's not-to-exceed values. Emission standards requirements per 40 CFR 60 Subpart IIII are based on a weighted cycle average. 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 then 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 AIRS ID: 123/9CA1 Page 22 of 31 ii olor-. Depa en P li Health and Environment it Pollution Control Division associated with thi ., or • - -- -g cific ion date call the Division at (303)-692-3150. 7) Points 006-008, and 010: This 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/fr18ia08.pdf 8) Points 006-011: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: CO, VOC, Benzene, formaldehyde, n- Hexane, and total HAPs PSD Synthetic Minor Source of VOC MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable NSPS JJJJ Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.g poaccess.a ov/ 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 7777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 11) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdohe/air-permit-self-certification AIRS ID: 123/9CA1 Page 23 of 31 olor Depa en Ii ealth and Environment it Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS STATIONARY SPARK.IGNITION (SI) ENGINE 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 AIRS ID: 123/9CA1 Page 24 of 31 olor Depa en P li Health and Environment it Pollution Control Division requirements applicab - - g • nt of sions 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. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the 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: http://www.Colorado.qov/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 AIRS ID: 123/9CA1 Page 25 of 31 Depa en li ealth and Environment it Pollution Control Division the test results will beDolor m in th th or year(8760),whichever applies. For comparison with a short-term limit that is either input based (lb/MMBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOx and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. 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 PM10 at any level of emissions and to NOx and SO2, as precursors to PM10, if the potential to emit of NOx or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOx:The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§72.2), natural gas contains . 20.0 grains or less of total sulfur per 100 standard cubic feet. 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 bum engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9CA1 Page 26 of 31 olor Depa en P Ii Health and it Pollution ControlEnvironment Division Lean bum 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: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9CA1 Page 27 of 31 olor epa en li it Pollutionealthand ControlEnvironment Division A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart 7777. 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. AIRS ID: 123/9CA1 Page 28 of 31 olor Depa en P li Health and Environment T„ Pollution Control Division ATTACHMENT B: ALTERNATIVE OPERATING SCENARIOS STATIONARY COMPRESSION IGNITION (CI) ENGINE October 1, 2011 3. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of Stationary(CI) 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. 3.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an 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 any all tests and the associated calculations required by this AOS shall be submitted to the Division within 60 days. 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. 3.1.1 The owner or operator may temporarily replace an existing engine that is covered by this permit with a different 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. Calculation of emissions from the AIRS ID: 123/9CA1 Page 29 of 31 Dolor epa en li ealth and Environment it Pollution Control Division tempor lb set fo ion 2.1.3. 3.1.2 An Air Pollutant Emissions Notice(APEN)that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine and an analysis of any new applicable requirements for the replacement engine as required byCondition 2.2.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. 3.1.3 Compliance of the replacement engine with the applicable emission limitations of the original engine shall be monitored by one of the following methods: 1) Manufacturer certified emission factors showing compliance. 2) Stack tests of same make and model showing compliance. This would only be considered if the test was done under similar conditions to Colorado(i.e. at altitude). 3) Stack tests on the engine. 3.2 Applicable Regulations for Permanent Engine Replacements 3.2.1 NSPS for stationary compression ignition internal combustion engines: 40 CFR Part 60, Subpart 1111. A permanent replacement engine that is ordered after July 11, 2005 and manufactured after April 1, 2006 or is modified or reconstructed after July 11, 2005 is subject to the requirements of 40 CFR Part 60, Subpart 1111.An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in any request for a permanent engine replacement. 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 date of manufacture for purposes of determining the applicability of NSPS 1111 requirements). 3.2.2. MACT for Stationary Reciprocating Internal Combustion Engines:40 CFR Part AIRS ID: 123/9CA1 Page 30 of 31 olor Depa en P li Health and Environment it Pollution Control Division 63, Su•- Any permanent replacement engine located at either an area or major source is subject to the requirements of 40 CFR Part 63, Subpart ZZZZ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in any request for a permanent engine replacement. 3.3 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9CA1 Page 31 of 31 Division Information Engineer: Oluwaseun Ogungbenle Control Engineer: Chris Laplante Review Date: 05/22/2014 Application Date: 03/17/2014 Facility Identifiers Permit No. 14WE0639 AIRS County# 123 Weld Facility# 9CA1 Facility Type: exploration and production facility ❑Located in the 8-hour non-attainment area? O True Minor Synthetic Minor for: 1 VOC r NOx R-1 CO Administrative Information Company Name: Noble Energy, Inc. Source Name: Rohn LD09 EcoNode Source Location: E/2 Section 9, Township 9N, Range 58W SIC: 1311 Address 1: Noble Energy, Inc. Mailing Address 2: 1625 Broadway, Suite 2200 Address r,State Zip: Denver, CO 80202 Name: Taryn Weiner Person To Phone: 303-228-4362 Contact Fax: 303-228-4286 Email: tweinerenobleenergvinc.com 'Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the Rohn LD09 EcoNode, located in the E/2 Section 9, Township 9N, Range 58W,Weld County, Colorado. Point Name Type Control Action Newly 001 Tanks Condensate Tanks Flare reported source Newly 002 PW Water Tanks Flare reported source Newly 003 TLO Loadout Flare reported source Newly 004 Flare Separator Venting Flare reported source Newly 005 Fugitives Fugitives None reported source Catalytic Newly 006 GL Comp1 Engine Oxidizer reported source Catalytic Newly 007 GL Comp2 Engine Oxidizer reported source Newly WH ic 008 Comp1 Engine Cata Reduceer reported source VRU Catalytic Newly 009 Comp1 Engine Reducer reported source Newly !ACT 010 Generator Engine None reported source Newly 011 Gen2 Engine None reported source 001 Thirty-six(36) above ground atmospheric condensate storage tanks with a total capacity of 2 Requested Throughput 2185000 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.78 lb/bbl 852.15 tpy 42.6 tpy E&P TANK Benzene 0.0055 lb/bbl 12017.5 lb/yr 600.9 lb/yr E&P TANK n-Hexane 0.036 lb/bbl 78660 lb/yr 3933 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. 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. NSPS Kb does not apply to these tanks since they are located at an E&P site, which is prior to the point of custody transfer NSPS OOOO: for storage vessels in the natural gas production,transmission, and processing segments. This source is not subject to the requirements of this subpart because controlled actual emissions from each storage vessel are 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 the source is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this section since actual uncont►olled emissions exceed 20 tpy of VOC.) 002 Twelve(12) above ground 538 bbl and one(1) below ground 60 bbl produced water s1 Emissions Calculations Requsted Throughput 900000 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 117.9 tpy 5.895 tpy CDPHE Benzene 0.007 lb/bbl 6300 lb/yr 315 lb/yr CDPHE n-Hexane 0.022 lb/bbl 19800 lb/yr 990 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. 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. 003 Truck Condensate Loadout 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 5 Saturation Factor 0.6 AP-42 P True Vapor Pressure 3.9363 psia Sales Oil Analysis M Molecular Weight 68 lb/lb-mole AP-42 of Vapors T Liquid Temperature 520 deg. R Field Data L 3.85 lb/103 gal 1.62E-01 lb/bbl Annual requested Throughput 2185000 BBL/yr 91770000 gal/yr Annual requested V0C emissions 353154 lb/yr 176.58 tpy Control: Flare Efficiency: 95.00% NCRPs Component Mass Fraction Benzene 0.0090 n-hexane 0.0160 Toluene 0.0130 Xylenes 0.0050 Source: Pressurized oil analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 0.1616 lb/bbl 176.58 tpy 8.83 tpy AP-42 Benzene 0.0015 lb/bbl 3178.38 lb/yr 158.92 lb/yr AP-42 n-Hexane 0.0026 lb/bbl 5650.46 lb/yr 282.52 lb/yr AP-42 Toluene 0.0021 lb/bbl 4591.00 lb/yr 229.55 lb/yr AP-42 Xylenes 0.0008 lb/bbl 1765.77 lb/yr 88.29 lb/yr AP-42 Regulatory Review 'Regulation 7-Volatile Organic Compounds This facility is not considered a bulk plant(in Reg. 7) because it does not distribute gasoline. 004 Separator controlled by a flare stack.Flare has a minimum combustion efficiency of 95%.The flare is enclosed. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: 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=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/Ib-mol)at 60F and 1 atm Throughput(0) 69 MMscf/yr 7878 712329 scf/hr MW 23.14 Ib/Ib-mol 0.189041096 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr Ib/yr tpy Helium 0.01 4.0026 0.000 0.000 0.01 7287 0.04 CO2 2.58 44.01 1.135 0.049 23.60 206719.27 103.36 N2 0.37 28.013 0.104 0.004 2.15 18869.97 9.43 methane 74.13 16.041 11891 0.514 247.12 2164811.50 1082.41 ethane 13.50 30.063 4.057 0.175 84.32 738653.62 369.33 propane 5.64 44.092 2.486 0.107 51.67 452603.45 226.30 isobutane 0.76 58.118 0.442 0.019 9.18 80393.30 40.20 n-butane 1.63 58.118 0947 0.041 19.68 172414.94 86.21 isopentane 0.43 72.114 0313 0.014 6.51 57032.09 28.52 n-pentane 0.43 72.114 0.310 0.013 6.44 56441.29 28.22 cyclopentane 0.02 70.13 0.015 0.001 0.31 2732.29 1.37 n-Hexane 0.10 86.18 0.085 0.004 1.76 15423.04 7.71 cyclohexane 0.03 84.16 0.022 0.001 0.46 4045.01 2.02 Other hexanes 0.19 86.18 0.161 0.007 3.35 29371.24 14.69 heplanes 0.08 100.21 0.079 0.003 1.65 14467.52 7.23 i methylcyclohexane 0.03 98.19 0.025 0.001 0.52 4540.58 2.27 224-TMP 0.00 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.02 78.12 0.016 0.001 0.33 2887.14 1.44 Toluene 0.02 92.15 0.017 0.001 0.36 3154.01 1.58 Ethylbenzene 0.00 106.17 0.001 0.000 0.02 173.96 0.09 Xylenes 0.01 106.17 0.006 0.000 0.12 1082.43 0.54 Cat Heavies 0.04 13]4837288 0.057 0.002 1.18 10337.40 5.17 VOC mass tract 0.215 Total VOC(Uncontrolled) 453.55 Notes Mole%,MW,and mass fractions from Critter Creek 2-03H gas analysis. 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. Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer Tornado Model 40'Flare Stack Serial Number 12345678 Gas Heating Value 1549 Btu(scf Throughput 108881 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales line. Make Model Requested Control 100.00% Annual Bypass TI 50.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 jib NOX/PAMBtu 0.37 IIb COMfiiBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 13148.37 Ile/MMscf 657.32 lb/MMscf 453.55 tpy . 22.68 tpy Gas Analysis Not 0.07 lb/MMBTU 0.07 lb/MMBTU 3.63 tpy 3.63 tpy AP-42 CO 0.37 lb/MMBTU 0.37 Ib/MMBTU 19.77 tpy 19.77 tpy AP-42 Benzene 41.84 lb/MMscf 2.09 lb/MMscf 2887.14 lb/yr 144.36 lb/yr Gas Analysis n-Hexane 223.52 lb/MMscf 11.18 lb/MMscf 15423.04 lb/yr 771.15 lb/yr Gas Analysis Toluene 45.71 lb/MMscf 2.29 lb/MMscf 3154.01 lb/yr 157.70 lb/yr Gas Analysis Xylenes 15.89 lb/MMsd 0.78 lb/MMsd 1082.43 lb/yr 54.12 lb/yr Gas Analysis Ethylbenzene 2.52 lb/MMscf 0.13 Ib/MMscf 173.96 lb/yr 8.70 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section Il.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." 005 Fugitive equipment leaks Regulation 7 Information Operating Went 8760 noun/year Emission Factor Source EPA-453/R-95-017 Table 2-4 Control Elficlency Source. Table 5-3 Monthly Monitoring Calculations Emission Farrar(kgils- Emissions Service Compomm Type Count source) Control(%)Pollutant Mass Fraction (tpy) Table 2-4 Table 24 Reg.3 Connectors 2717 2.00E04 100605 00% VOC 0.2901 18.85256792 Flanges 485 3.90E04 5.70606 00% Benzene 0.002 0.130179055 open-Ended Lines 3 2.00E-03 1.50E-05 0.0% Toluene 0.002 0.130179855 Las Pump Seals 0 240E-03 350E-04 0 Ethylbenzene 0.001 0.065089927 Valves 1530 450E-03 250E-05 680% Xylenes 0.001 0.065089927 Other 432 000E-03 1.28E-04 0.0% n-Hesane 0006 0.390539564 Connectors 179 )SOE-06 750E-06 00% VOC 1000 0030855436 Flanges 0 398E-07 390E-07 0 Benzene 8 0 Open-Ended Lines 0 140E-04 7.20E-06 0.0% Toluene 0 0 Hoary Oil Pump Seals 0 0.00E+00 0.00E+00 0.0% Ethylbenzene 0 0 Valves 69 940E-06 8.40E-06 0.0% Xylenes 0 0 Other 40 3.20f05 3.20E-05 0 n-Hexane 0 0 Connectors 1647 2.10E-04 7.50E-06 00% VOC 1.000 30.84340696 Flanges 375 1.10E-04 240E-06 0 Benzene 0.03 0.925304609 Open Ended lines 0 140E-03 140E-05 0 Toluene 0.03 0.925304609 Light Oil Pump Seals 4 1.30E-02 5.10E-04 68.0% Ethylbenzene 0.003 0092530461 Valves 1612 2.50E-03 1.90E-05 68.0% Xylenes 0.003 0.092530461 Other 201 7.50E-03 1.10604 0.0% n-Hexane 005 1.542174348 Connectors 379 1.10E-04 1.00E-05 0.0% VOL 1.000 13.98200636 Flanges 48 2.90E-06 290E06 00% Benzene 0.0003 0004194602 Open-Ended Lines 0 250E-04 3.50E06 0.0% Toluene 0.0003 0.004194602 Water/Oil Pump Seals 0 240E-05 240E-0S 68.0% Elhbbenzene 0 0 Valves 293 980E-05 9.70E-06 68 0% Xylenes 0 0 Other 100 140E-02 590E-05 00% n-Hexane 0.0005 0006991003 Emissions Summary Table Pollutant Uncontrolled Emissions Controlled Emissions SourceI VOC 63.75 Ipy 83 _74 ipv EPA-453/R-95-017 Table 2-4 Benzene 2120.00 lb/yr 2119.36 IbM _EPA-453/R-95-017 Table 2-4 Toluene 2120.00 lb/yr 2119.36 Ibyr EPA-453/R-95-017 Table 2-4 EVrylbenzene 31531 lb/yr 315.24 lb/yr EPA-453/R-95-017 Table 2-4 Xylenes 315.31 lb/yr 315.24 lb/yr :EPA-453/R-95-017 Table 2-4 n-Hexane 3080.50 lb/yr 3079.41 lb/yr EPA-453/R-95-017 Table 2-4 Regulatory Applicability Reg.3 Source is located in an attainment area:therefore.RACT is not required. One(1)Caterpillar,Model G3516B,Serial Number JEF02162.natural gas-fired,turbo-charged,4SLB reciprocating 006 internal combustion engine,site rated at 1360 horsepower at 1400 RPM.This engine is equipped with an oxidation catalyst and air/fuel ratio controller.This emission unit is used for natural gas compression. Engine Information Engine date of mfg 3/6/2013 Manufacturer: Caterpillar Model Number: G35168 Serial Number: JEF02162 RPM: 1400 Site-rated RPM: 1400 Engine Function Compression Derating IMfg's Max.Rated Horsepower a sea level. 1380 Horsepower used for calcuations: 1380 BSCF a 100%Load(btu/hp-hr):8226 Site-Rated BSCF(g 100%load(btwTp-hr):8226 Engine Type 4SLB Other Parameters Aspiration turbo-charged Electrical Generator Max Site Rating(kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate©100%Load 8732.2 scf/hr ACTUAL Annual Fuel Consumption MMscfi r MAX POTENTIAL Annual Fuel Consumption 76.49 MMscf/yr REQUESTED Annual Fuel Consumption 76.5 MMscf) r Fuel Heating Value 1300 blu/scf Emission Control Information This engine Is equipped with an oxidation catalyst and alr/fuel ratio controller. Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 gmp4r 0.500 graph 6.65 ley 8.65 Ipy Manufacturer CO 2.430 gmpmr 0.200 amp-hr 32.31 tpy 2.86 tar Manufacturer VOC 0.710 gmplm 0.250 gmpanr 9.44 tpy 3.32 Wy Manufacturer FarmWehyde 0.440 gmp-hr 0.100 gmphr 11702.0 lbyr 2859.5 Ibyr Manufacturer Acetaldehyde 0.008 IbIMMBTU 0.008 lb/MMBTU 835.3 dyr 835.3 lbyr AP-42 Aadai 0.005 IbIMMBTU 0.005 lb/MMBTU 507.2 pyr 507.2 . lb* AP-42 Benzene 0.0004 IMAMBTU 0.0004 IbfMMBTU 39.8 lb* 39.8 Ib/yr AP-42 Regulatory Requirements aSource nal sj not required to model based on Division Guidelines/No NMSO Ndadone expected(see details of modeling Ambient Air Impact MACT= located at an Area source Rep 7 XVII.E NOx:0.0 CO:0.0 VOC:0.0 Standads(gmp-hr) Reg 7 XVI.B(Ozone NAA requirements) No apples? This engine mmiamed conabuction after 06/12/2006 and is located at an MACT 2272(sea Is this engine subject to MACT RZZ area source requirements? Yes area source of NAPS.Therefore,this source) engine is a new area source under MACT ZZZ2 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after Is this engine subject to NSPS JJJJ? Yes the NSPS JJJJ applicability date of NSPS JJJJ 07/01/2007.Therefore,It is subject to the requirements of this subpart. Note:JJJJ regurtenants are not currently included as permit conditions because the rag has not been adopted into Reg 6. One(1)Caterpillar,Model G3516B,Serial NumberJEF02207,natural gas-fired,turbo-charged,4SLB reciprocating 007 internal combustion engine,site rated at 1380 horsepower at 1400 RPM.This engine is equipped with an oxidation catalyst and air/fuel ratio controller.This emission unit is used for natural gas compression. Engine Information Engine date of mfq 3/25/2013 Manufacturer: Caterpillar Model Number G35160 Serial Number JEF02207 RPM: 1400 Site-rated RPM: 1400 Engine Function Compression Denting Mfg's Max.Rated Horsepower©sea level: 1380 Horsepower used for calcuations: 1380 BSCF fa 100%Load(btu/hp-hr): 8226 Site-Rated BSCF©100%load(btu/hp-hr): 8226 Engine Type 4SLB Other Parameters Aspiration naturally aspirated Electrical Generator Max Site Rating(kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate©100%Load 8732.2 scf/hr ACTUAL Annual Fuel Consumption MMscfNr MAX POTENTIAL Annual Fuel Consumption 76.49 MMscf/yr REQUESTED Annual Fuel Consumption 76.5 MMscf/yr Fuel Heating Value 1300 btu/scf Emission Control Information This engine is equipped with an oxidation catalyst and alr/fuel ratio controller. • Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 gMp-hr 0.500 gtipJa 6.65 ipy 6.65 tpy Manufacturer CO 2.430 grhp-hr 0.200 g/hp-hr 32.31 IPy 2.66 Ipy Manufacturer VOC 0.710 P/hp-hr 0.250 gfpJrc 9.44 Ipy 3.32 tpy Manufacturer Formaldehyde 0.440 gabp-hr 0.100 g/hp-hr 11702.0 b/yr 2659.5 Iblyr Manufacturer Acetaldehyde 0.008 Ib/MMBTU 0.008 IbuTABTU 835.3 byr 835.3 lb/yr AP-42 Aoolain 0.005 b/MMBTU 0.005 lb/MMBTU 507.2 lb/yr 507.2 b/yr AP-42 Benzene 0.000 b/MMBTU 0.0004 Ib/M.ABTU 39.8 lb/yr 39.8 lb/yr AP-42 Regulatory Requirements Source is not required to model based on Division Guidelnes/No NAAQS violations expected(see details of Ambient Air Impacts modeling analysis) MACT ZZZZ located at an Area source Reg 7 XVII.E NOx:0.0 CO: 0.0 VOC:0.0 Standards(gmp-hr) Reg 7XVI.B(Ozone - - --- NM requirements) No applies? This engine commenced construction after 06/1212006 and • is located al an area source of MACT 7777(area Is this engine subject to MACT 7777 area source requirements? Yes HAPs.Therefore,this engine is a source) new area source under MACT ZZZZ and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after Is this engine subject to NSPS JJJJ? Yes the NSPS JJJJ appicability date of NSPS JJJJ 07/01/2007.Therefore,it is subject to the requirements of this subpart. Note:JJJJ requriements are not currently included as permit conditions because the rug has not been adopted into Reg 6. One(1)Caterpillar,Model G3304NA,Serial Number N4F03309,natural gas-fired,turbocharged,4SRB 008 reciprocating internal combustion engine,site rated at 95 horsepower at 1800 RPM.This engine is equipped with a non-selective catalytic reduction(NSCR)system and air/fuel ratio controller.This emission unit is used for natural gas compression. Engine Information Engine date of mfg 7/30/2008 Manufacturer Caterpillar Model Number G3304NA Serial Number: N4F03309 RPM: 1800 Site-rated RPM: 1800 Engine Function Compression Derating 'Mfg's Max.Rated Horsepower @ sea level. 95 Horsepower used for calcuations:95 BSCF gg 100%Load(blwhp-hr):8586 Site-Rated BSCF(5)100%load(btu/hp-hr):8586 Engine Type 4SRB Other Parameters Aspiration turbocharged Electncal Generator Max Site Rating(NN 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate(5 100%Load 627.4 scf/hr ACTUAL Annual Fuel Consumption MMscf/yr MAX POTENTIAL Annual Fuel Consumption 5.50 MMscf/yr REQUESTED Annual Fuel Consumption 5.50 MMscf/yr Fuel Heating Value 1300 btu/scf Emission Control Information This engine is equipped with a non-selective catalytic reduction(NSCR)system and atMel MOO controller. Emissions Summary Table Pollutant Uncontroled Emission Factor Controlled Emission Factor Uncontrolled Emissions Conksled Emissions Source - NOR 13.110 gliphr 1.000 gAtphr 12.00 tpy 0.92 tP`/ Manufacturer CO 13.110 gmp-hr 2.000 g/hp-hr 12.00 tpy 1.83 tpy Manufacturer VOC 0.930 gmphr 0.700 gmphr 0.85 tpy 0.84 Wv Manufacturer Formaldehyde 0.270 grhphr 0.080 g/hp-hr 494.3 Ibyr 109.9 W/yr Manufacturer Acetaldehyde 0.003 b?.MBTU 0.003 lb/MMBTU 20.0 Ibyr 20.0 l/yr AP-42 Aaolein 0.003 LMMBTU 0.003 lb/LBABTU 18.8 Ibyr 18.8 lb/yr AP-42 Benzene 0.002 DA.MBTU 0.002 lb/MMBTU 11.4 byr 11.4 b/yr AP-42 Regulatory Requirements Source is not required to model based on Division Guidelnes/No NAAOS violations expected(see details of Ambient Al Impacts modeing analysis) MACT 7777 located at an Area source Reg 7 NOR.0.0 C0:0.0 V0C:0.0 Standards(grhphr) Reg 7 XVI.B(Ozone NM requirements) No applies? This engine commenced construction after 08112/2008 and is located at an area source of MACT an(area Is this engine subject to MACT ZZZZ area source requirements? Yes HAPs.Therefore,this engine is a source) new area source under MALT ZZZZ and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured alter the NSPS JJJJ applicably Is this engine subject to NSPS JJJJ? Yes date of 07/01/2008.Therefore,R is NSPS JJJJ subject to the requirements of this subpart. Note:JJJJ requriements are not currently included as permit conditions because the reg has not been adopted Into Reg 8. One(1)Cummins,Model O8.3 C118,Serial Number 46593798,natural gas-fired,naturally aspirated,4SRB 009 reciprocabng internal combustion engine,site rated at 118 horsepower at 1800 RPM.This engine is equipped with a non-selective catalytic reduction(NSCR)system and air/fuel ratio controller.This emission unit is used for natural gas compression. Engine Information Engine date of mfg 4/1/2006 Manufacturer: Cummins Model Number G83 C118 Serial Number 46593798 RPM: 1800 Ste-rated RPM: 1800 Engine Function Compression Derallog Mfg's Max.Rated Horsepower @ sea level: 118 Horsepower used for calcuations: 118 BSCF @ 100%Load(btump-hr):8266 Site-Rated BSCF @ 100%load(btu/hp-hr):8266 Engine Type 4SRB Other Parameters Aspiration naturally aspirated Electrical Generator Max Site Rating(kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100%Load 750.3 sct/hr ACTUAL Annual Fuel Consumption MMsct/yr MAX POTENTIAL Annual Fuel Consumption 6.57 MMscf/yr REQUESTED Annual Fuel Consumption 6.6 MMscf/yr Fuel Heating Value 1300 btu/scf Emission Control Information This engine is equipped with a non-selective catalytic reduction(NSCR)system and air/fuel ratio controller. Emissions Summary Table Pollutant Unconboled Emission Factor Controlled Emission Factor Uncontmled Emissions Controlled Emissions Source NOx 11.600 prhp-hr 1.000 grhp-hr 13.19 tpy 1.14 Ipy Manufacturer CO 11.000 pmp-hr 2.000 q/hp-hr 12.51 tpy 2.27 tPy Manufacturer VOC 0.700 gmp4hr 0.700 g/hp-hr 0.80 tn. 0.80 ,Ivy Manufacturer Formaldehyde 0.021 IbsIMBTU 0.021 Ib/ MBTU 175.2 lb/yr 175.2 lb/yr AP-42 Acetaldehyde 0.003 thrMMBTU 0.003 IbMlMBTU 23.9 lb/yr 23.9 lb/yr AP-02 Acrolain 0.003 IbMMBTU 0.003 Ib/MMBTU 222 Ib/yr 22.2 lb/yr AP-42 Benzene 0.002 IbeiMBTU 0.002 Ib/MMBTU 13.7 lb/yr 13.7 lb/yr AP-42 Regulatory Requirements Source is not required to model based on Division Guidelines/No NAAQS violations expected(see details of Ambient Air Impacts modeling analysis) MACT ZZZZ located at an Area source I Reg 7 sE N0x:0.0 CO:0.0 VOC: 0.0 Standards(g/hp-hr) Reg 7 XVI.B(Ozone NM irements) No applies? The date of commencement of construction of this engine is MACT 7777(area Is this engine subject to MACT 7777 area source requirements? TBD unclear at this point.Therefore, source) MACT 7777 appicability to this engine cannot be determined at • this lime. This engine was manufactured before the NSPS JJJJ applicability Is this engine subject to NSPS JJJJ? No date of 07/01/2008.Therefore,t is NSPS JJJJ not subject to the requirements of this subpart. Note:JJJJ requirements are not currently included as permit condtions because the reg has not been adopted into Reg 6. One(1)Doosan.Model 0146L,Serial Number EEZOG100146,natural gas-fired,naturally aspirated,4SRB 010 reciprocating internal combustion engine,site rated at 449 horsepower at 1800 RPM.This engine is uncontrolled.This emission unit is used for power generation. Engine Information Engine date of mfg 6/15/2012 Manufacturer: Doosan Model Number: D146L Serial Number: EEZOG100146 RPM: 1800 Site-rated RPM: 1800 Engine Function Primary and/or peaking power Derating 'Mfg's Max.Rated Horsepower@ sea level'. 449 Horsepower used for calcuations:449 BSCF©100%Load(btulhp-hr): 7914 Site-Rated BSCF©100%load(btu/4-hr):7914 Engine Type 4SRB Other Parameters Aspiration naturally aspirated Electncal Generator Max Site Rating(kw) 0 Max hrs/yr of Operation 8760 Calculations Fuel Use Rate L83 100%Load 2733.4 scf/hr ACTUAL Annual Fuel Consumption MMscf/yr MAX POTENTIAL Annual Fuel Consumption 2394 MMscf/yr • REQUESTED Annual Fuel Consumption 23.9 MMscf/yr • Fuel Heating Value 1300 btu/scl • Emission Control Information This engine Is uncontrolled. Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 gmp-hr 0.500 gRlp-hr 2.16 Ipy 2.16 tpy Manufacturer CO 0.500 o/hp-hr 0.500 g/hp-hr 2.16 tpy 2.16 tpy Manufacturer VOC 0.500 gmp-hr 0.500 g/hp-hr 2.16 Ipy 2.16 tpy Manufacturer • Formaldehyde 0.0205 Ib/MMBTU 0.021 lb/MMBTU 638.1 Ib/yr 638.1 lb/yr AP-42 Acetaldehyde 0.003 Ib/MMBTU 0.003 Ib/MMBTU 87.2 Ib/Yr 87.2 lb/yr AP-42 Acroleen 0.003 lb/MMBTU 0.003 Ib/MMBTU 80.9 lb/yr 80.9 lb/yr AP-42 Benzene 0.002 Ib/MMBTU 0.002 Ib/MMBTU 49.8 lb/yr 49.8 lb/yr AP-42 Regulatory Requirements • Source is not required to model based on Division Guidelines/No NAAO expected S violations excted(see details of modeling Ambient Air Impact, analysis) MACT ZZZZ located et an Area source Reg 7)0/II.E Standards(g/hp- NOx:0.0 CO:0.0 VOC:0.0 hr) Reg 7 XVI.B(Ozone NAA requirements) No appbs? This engine commenced construction after 06/12/2006 and is located at an area source of MACT Z2ZZ(area Is this engine subject to MACT 2722 area source requirements? Yw RAPs.Therefore,this engine is source) new area source under MACT ZZZZ and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the NSPS JJJJ applicability Is this engine subject to NSPS JJJJ7 Yes date of 07/01/2008.Therefore,it NSPS JJJJ is subject to the requirements of this subpart. Note:JJJJ regalement,are not currently included as permit conditions because the reg has not been adopted into Reg 6. One(1)diesel-fired reciprocating internal combustion engine(Make,Model,and Serial Number:To Be 011 Determined),site rated at 274 horsepower at 1800 RPM.This engine is uncontrolled.This emission unit is used for power generation. Engine Information Engine date of mfg TBD Manufacturer: TBD Model Number TBD Serial Number: TBD RPM: 1800 Site-rated RPM: 1800 Engine Function Pnmary and/or peaking power Mtg's Max.Rated Horsepower @ sea level: 274 Demling Horsepower used for calcuations:274 BSCF @ 100%Load(btu/hp-hr):7000 Site-Rated BSCF @ 100%load(btu/hp-hr):7000 Engine Type Other Parameters Aspiration Electrical Generator Max Site Rating(kw) 0 Max hrsryr of Operation 8760 Calculations Fuel Use Rate @ 100%Load 13.400 gal/hr ACTUAL Annual Fuel Consumption gal/yr MAX POTENTIAL Annual Fuel Consumption 132774.57 gal/yr REQUESTED Annual Fuel Consumption 117384.00 gal/yr Fuel Heating Value 126542.91 btu/gal Emission Control Information This engine is uncontrolled. Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 4.485 g/hp-hr 4.465 9/I1P-hr 11.79 tpy 11.79 tpy Manufacturer CO 5.500 gRrp-hr 5.500 9/110-hr 14.52 tpy 14.52 tpy Manufacturer VOC 0.235 g/hp-hr 0.235 g/hp-hr 0.62 tpy 0.62 tpy Manufacturer Formaldehyde 0.0012 Ib/MMBTU 0.001 Ib/MMBTU 17.5 lb/yr 17.5 lb/yr AP-42 Acetaldehyde 0.0008 Ib/MMBTU 0.001 Ib/MMBTU 11.4 lb/yr 11.4 lb/yr AP-42 Acrobin 0.0001 Ib/MMBTU 0.000 lb/MMBTU 1.4 lb/yr 1.4 lb/yr AP-42 Benzene 0.0009 lb/MMBTU 0.001 Ib/MMBTU 13.9 lb/yr 13.9 lb/yr AP-42 Regulatory Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAOS violations expected(see details of modeling analysis) MACT ZZZZ located at an Area source Reg 7 XVII( NOx: 0.0 CO: 0.0 VOC: 0.0 Standards rds(g/hp-hr) _ Reg 7 XVI.B(Ozone NPA requirements) No apples? MACT ZZZZ(area Is this engine subject to MACT ZZZZ area source requirements? TBD source) Is this engine subject to NSPS II II? TBD NSPS IIII Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTE Y— �-,N. Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) j RE�E��`]EL AIRS ID#s: ' .� -' `i(1-A- - ) O ADEN update only4 [ - ® New or previously unreported battery O Modification to existing sources ii ❑ Previously grandfathered battery O Registration for coverage under general permit no.GP 1 ancj r, / ® Synthetic minor facility cancellation request for individual permit6: oU">-/ / ❑ Located in the 8-hr Ozone Control Areas ® Application for or Modification of an individual permit 1 ❑ Registered under general permit no. GP01 O Administrative permit amendment' ❑ Permitted under individual permit: O Other: For individual permit applications,check if you wants: O A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Name9: Noble Energy,Inc OGCC Operator if: 100322 Mailing Address10: 1625 Broadway Suite 2200 . tweiner®nobleenergyinc City: Denver State: CO Zip: 80202 E-mail: .com Contact Name: Taryn Weiner Phone: (303)2284362 Fax: (303)2284286 Tank Battery Names': ROHN LD09 ECONODE Number of tanks: 36 Locations=(QQ Sec.Twp.Range.): E/2 SEC9 T9N R58W County: Weld Total tank capacity[bbl]: 27,000 Calendar year for which"Actual"data applies13: 2014 Year(s)tank(s)were placed in service°: 2014 Control Description's: Flare Control Efficiency': 95% Condensate Throughput"[bbl/year] Requested": 2,185,000 Maximum for PTE calculation1s: 2,185,000 Actual20: While Controls Operational' Other equipment at facility22: Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. 0 Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions's Actual Emissions20 Pollutant's [lb/bbl] PTE25 Uncontrolled26 Controlled2' Uncontrolled2s Controlled2' VOC[tons/year] 0.78 852.2 852.2 42.6 NOx[tons/year] CO[tons/year] Benzene[lbs/year] 0.0055 12,017.5 12,017.5 600.9 n-Hexane[lbs/year] 0.036 78,660 78,660 3,933.0 Wells serviced by this tank or tank batter?' API#: Name: See attached list ®Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well The signature below indicates-that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. f this is.a registration for coverage under general permit GPI,I further certify that this source is and will be operated in full complia wit sac ondition of general permit GPI. March 17,2014 Signature of L Authorized Person(not a vendor or consultant) Date Brian Taylor Air Quality Manager Type or Print Name of Person Signing Above Official Title Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 w+ (303)692-3150 07 1 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South 07 registration to: Denver,CO 80246-1530 FORM APCD-205 Pane 1 of 3 ROHN LD9 ECONODE TB APEN.doc z o O O +• o. u o m o E 0 _I v c is o f c a .. z .� c O C a , o L0 aa. o � �00 el _ _ d C m �' 2 z o u " a .W. cn cn en E C 4! .004 ❑ 0 L a A c N c.AI vg . C C \O �O �O C J Oz ? `. 3 p p, q0q c q E " z, d 44) oo i In E Fair, o n u dC'~ `°' cz v co a �n y o x a y > m ° a�' w 0 P o O O 2 c a ct,CO c y y° >. G U = .0 .E v Q • _ " �0• v'i u o W z ... '-e- x � � � p .o a m 3 u ca n ._ E " c .. .. in dS W P� _ o C 4 • d U O. o y a w+ y > two o Y3 = N t cFC '�/' a� u Po o E `° € = x q vci c 5 o a m N . F.. = a c z o a o ❑ v ., w E = v Q0 d y = m y .F. ,o o CO m 3 v v v ° x. 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