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Home My WebLink About20143508.tiff • * CDPHE COLORADO CO d Department of Public I Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 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 LD04 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 Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, i A 1� , < ty Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe r?: e - °d-. John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ) — ILI ae,171-IFUJ HI- IIIl3 ZOLI-35osd CDPHE Public Notice Of A Proposed Project CO 9 Or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - Rohn LD04 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 LD04 EcoNode Oil and Natural Gas Exploration and Production Facility NESE Section 4, T9N, R58W, approximately 11 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 2,700,000 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 14WE0501 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 1 I AVir. COLORADO Y; w,n. .,t 1-1 STATE OF COLORADO • of C LO D T F P�C HEALTH AND ENVIRONMENT mss R AIR POLLUTION CONTROL DIVISION " b' TELEPHONE: (303)692-3150 :! ; *1876 F CONSTRUCTION PERMIT PERMIT NO: 14WE0501 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 LD04 EcoNode, located in the NESE Section 4, 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) 750 bbl and eight(8) 538 bbl above ground Tanks 001 atmospheric condensate storage tanks. Emissions from these tanks are controlled by an enclosed flare with a minimum combustion efficiency of 95%. Twelve (12) above ground 500 bbl and two (2) below ground 100 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%. Flare 004 Well head separator controlled by a flare. Flare has a minimum combustion efficiency of 95%. Fugitives 005 Fugitive VOC leak emissions. One (1) Caterpillar, Model G3516B, Serial Number JEF02156, natural gas-fired, turbo-charged, 4SLB reciprocating internal GL Comp1 006 combustion engine, site rated at 1380 horsepower. This engine is equipped with an oxidation catalyst and an air/fuel ratio controller. This emission unit is used for natural gas compression. AIRS ID: 123/9C84 Page 1 of 34 olor Depa en li Health and Environment DRit Pollution Control Division Facility AIRS Equipment Point Description ID One (1) Caterpillar, Model G3516B, Serial Number JEF02168, natural gas-fired, turbo-charged, 4SLB reciprocating internal GL Comp2 007 combustion engine, site rated at 1380 horsepower. This engine is equipped with an oxidation catalyst and an air/fuel ratio controller. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3408TA, Serial Number 6NB05118, natural gas-fired, turbo-charged, 4SRB reciprocating internal WH Comp1 008 combustion engine, site rated at 332 horsepower. This engine is equipped with a non-selective catalytic reduction (NSCR) system and an air/fuel ratio controller. This emission unit is used for natural gas compression. One (1) Caterpillar, Model G3408TA, Serial Number 6NB05120, natural gas-fired, turbo-charged, 4SRB reciprocating internal WH Comp2 009 combustion engine, site rated at 332 horsepower. This engine is equipped with a non-selective catalytic reduction (NSCR) system and an air/fuel ratio controller. This emission unit is used for natural gas compression. One (1) Cummins, Model 7.4L, Serial Number 00067675, natural gas-fired, naturally aspirated, 4SRB reciprocating internal VRU 010 combustion engine, site rated at 110 horsepower. This engine is Comp1 equipped with a non-selective catalytic reduction (NSCR) system and an air/fuel ratio controller. This emission unit is used for natural gas compression. One (1) Doosan, Model D146L, Serial Number EEZ0G100147, Gen1 011 natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 449 horsepower. This engine is uncontrolled. This emission unit is used for power generation. One (1) Cummins, Model QSB7G6, Serial Number 22085676, diesel-fired, reciprocating internal combustion engine, site heat Gen2 012 input rated at 7,000 BTU/hp-hr, having a site rated output at or below 135 HP, powering generator set. This engine is uncontrolled. This emission unit is used for power generation.This engine is 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. Points 008 and 009: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3408TA engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. AIRS ID: 123/9C84 Page 2 of 34 li olor-A Depa en . • •li '`Health and Environment it Pollution Control Division Point 010: This m- -d • er e• • - in accordance with the temporary engine replacement provision or with another Cummins 7.4L 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 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 012: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Cummins QSB7G6 engine 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 AIRS ID: 12319C84 Page 3 of 34 olor Depa en li ealth and Environment it Pollution Control Division • model • serial number This information shall be included with the Notice of Startup submitted 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 Emission Type Equipment ID Point SOx NO, VOC CO Tanks 001 --- --- 52.7 --- Point PW 002 --- --- 6.6 --- Point TLO 003 --- --- 10.9 -- Point Flare 004 — 1.8 17.8 9.8 Point Fugitives 005 - - 65.0 — Fugitive GL Comp1 006 --- 6.7 3.3 2.7 Point GL Comp2 007 --- 6.7 3.3 2.7 Point WH Comp1 008 --- 3.2 0.5 6.4 Point WH Comp2 009 --- 3.2 0.5 6.4 Point VRU Comp1 010 --- 1.1 0.5 2.1 Point Gen1 011 — 2.2 2.2 2.2 Point Gen2 012 2.5 11.8 — 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. AIRS ID: 12319C84 Page 4 of 34 olor_i Depa en . ' di ''Health and Environment it Pollution Control Division The permit h. . -II c- -t• -.io - onth - eep 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. 8. Point 005: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas 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 Monthly Valve Monitoring VOC & HAPs GL Comp1 006 Catalytic Oxidizer with AFRC CO, VOC, & HCHO GL Comp2 007 Catalytic Oxidizer with AFRC CO, VOC, & HCHO WH Comp1 008 Catalytic Reducer with AFRC NOx, CO, VOC, and HCHO WH Comp2 009 Catalytic Reducer with AFRC NOx, CO, VOC, and HCHO VRU Comp1 010 Catalytic Reducer with AFRC NOx, CO, &VOC 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 AIRS ID: 123/9C84 Page 5 of 34 olor Depa en li Health and Environment it Pollution Control Division operator and ail t ivi ' pecti on request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID Tanks 001 Condensate Throughput 2,700,000 BBUyr PW 002 Produced Water Throughput 1,000,000 BBUyr TLO 003 Condensate loading 2,700,000 BBL/yr Flare 004 Natural gas flaring 40 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 18.4 MMscf/yr WH Comp2 009 Consumption of natural gas as fuel 18.4 MMscf/yr VRU Comp1 010 Consumption of natural gas as fuel 6.1 MMscf/yr Gent 011 Consumption of natural gas as fuel 24.0 MMscf/yr Gen2 012 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 month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site P 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 006-012: 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 XVI1.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.) AIRS ID: 123/9C84 Page 6 of 34 olor Depa en P li Health and Environment it Pollution Control Division 17. Points 001 aImil)h e d • rmit ' ject 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, determine whether it is operating properly. The operator 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; AIRS ID: 12319C84 Page 7 of 34 olor Depa en li ealth and Environment it Pollution Control Division XVII.C is o olluti trol 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. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted • with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(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 AIRS ID: 123/9C84 Page 8 of 34 olor Depa en li Health and Environment it Pollution Control Division a) f e unc led 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 Threshold: Storage Tank Approved Instrument 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 O P q 9 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. Record keeping 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. AIRS ID: 123/9C84 Page 9 of 34 Depa en Ii earth and Environment it Pollution Control Division XVII.C.3.f.A IDolor d rag 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): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. 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 012: This engine is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart III!, 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. b. All fuel used shall meet the following specifications: (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 AIRS ID: 12319C84 Page 10 of 34 Depa en li Health and Environment it Pollution Control Division emergDolor o al 'on e 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 IIII §60.4209(a). 22. Point 012: 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 23. Points 001-010: 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.) 24. Points 011 and 012: This source is not required to follow a Division-approved operating and maintenance plan for these emission points. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 25. 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. 26. 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. AIRS ID: 123/9084 Page 11 of 34 Depa en li ealth and Environment it Pollution Control Division 27. Polnt 005: WDolor d h 0) a ' suance 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. 28. 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. 29. Points 006-009: A source initial compliance test shall be conducted on emissions points 006, 007, 008, and 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 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 30. Points 010 and 011: A source initial compliance test shall be conducted on emissions points 010 and 011 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. 31. Point 012: 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) AIRS ID: 123/9C84 Page 12 of 34 olor-� Depa en li Health and Environment it Pollution Control Division Periodic Tes uir t 32. 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. 33. 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. 34. Points 006-010: 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 35. 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 For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Points 006-011: 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 AIRS ID: 123/9O84 Page 13 of 34 Depa a li ealth and Environment it Pollution Control Division that thDolor r t er ' Item operating scenario and is installing a permanent replacement engine. g. Point 012: 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. 36. 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). 37. MACT Subpart HI-I - 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 HR. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 38. 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. 39. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide'liner authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 40. 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. AIRS ID: 123/9084 Page 14 of 34 IIolor.� Depa en . P di Health and Environment 0 it Pollution Control Division 41. Unless specific ' - ed - . - -- g- _• spec- onditions 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. 42. 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. 43. 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. 44. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: 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: 12319C84 Page 15 of 34 olor Depa en li ealth and Environment it Pollution Control 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.aov/cs/Satellite?c=Document C&childpagename=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. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# (lb/yr) reportable? Rate(lb/yr) Benzene 71432 14850 Yes 743 001 n-Hexane 110543 97200 Yes 4860 Benzene 71432 700O Yes 350 002 n-Hexane 110543 22000 Yes 1100 Benzene 71432 3931 Yes 197 Toluene 108883 5678 Yes 284 003 Ethylbenzene 100414 437 Yes 22 Xylenes 1330207 2184 Yes 109 n-Hexane• 110543 6989 Yes 349 Benzene 71432 4917 Yes 246 Toluene 108883 4917 Yes 246 • Ethylbenzene 100414 2458 Yes 123 004 Xylenes 1330207 2458 Yes 123 • n-Hexane 110543 14750 Yes 737 2,2,4-TMP 540841 2458 Yes • 123 005 Benzene 71432 3936 Yes 2145 AIRS ID: 123/9C84 Page 16 of 34 olor Depa en li Health and Environment it Pollution Control Division Tolu 2145 Ethylbenzene 100414 577 Yes 322 Xylenes 1330207 577 Yes 322 n-Hexane 110543 7174 Yes 3936 I 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 1,282 Yes 321 Methanol 67561 73 No 73 Acetaldehyde 75070 67 No 67 008 Acrolein 107028 63 No 63 Benzene 71432 38 No 38 1,3-Butadiene 106990 16 No 16 Toluene 108883 13 No 13 Formaldehyde 50000 1,282 Yes 321 Methanol 67561 73 No 73 Acetaldehyde 75070 67 No 67 009 Acrolein 107028 63 No 63 Benzene 71432 38 No 38 1,3-Butadiene 106990 16 No 16 I Toluene 108883 13 No 13 Formaldehyde 50000 163 No 163 010 Methanol 67561 24 No 24 AIRS ID: 123/9C84 Page 17 of 34 olor epa en li ealth and Environment it Pollution Control Division Acetal 0 22 Acrolein 107028 21 No 21 Benzene 71432 13 No 13 1,3-Butadiene 106990 5 No 5 Toluene 108883 4 No 4 Formaldehyde 50000 638 Yes 638 Methanol 67561 95 No 95 Acetaldehyde 75070 87 No 87 011 Acrolein 107028 82 No 82 Benzene 71432 49 No 49 1,3-Butadiene 106990 21 No 21 Toluene 108883 17 No 17 012 Formaldehyde 50000 20 No 20 5) The emission levels contained in this permit are based on the following emission 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 factors for point 001 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 factors for point 002 are based on the flare control efficiency of 95%. AIRS ID: 12319C84 Page 18 of 34 olor Depa en li Health and Environment it Pollution Control Division 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. Caic 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 Ib/Ib-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. Controlled emission factors are based on a flare efficiency of 95%. Point 004: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas (°/0) Uncontrolled Controlled 0.068 0.068 NOx Ib/MMBtu lb/MMBtu AP-42 0.37 0.37 CO "' Ib/MMBtu lb/MMBtu AP-42 VOC 29.01 17835.00 891.75 Engineering lb/MMscf lb/MMscf Calculation Benzene 0.20 122.925 6.146 Engineering lb/MMscf lb/MMscf Calculation Toluene 0.20 122.925 6.146 Engineering lb/MMscf Ib/MMscf Calculation Ethylbenzene 0.10 61.450 3.073 Engineering lb/MMscf lb/MMscf Calculation Xylenes 0.10 61.450 3.073 Engineering lb/MMscf lb/MMscf Calculation n-hexane 0.60 368.750 18.438 Engineering lb/MMscf lb/MMscf Calculation 2,2,4-TMP 0.10 61.450 3.073 Engineering lb/MMscf lb/MMscf Calculation AIRS ID: 123/9C84 Page 19 of 34 olor Depa en Ii Health and Environment it Pollution Control Division Point 005: Wil Component Gas Service Heavy Oil Light Oil Service Connectors 2843 179 1682 379 Flanges 493 0 375 48 Open-ended Lines 3 0 0 0 Pump Seals 4 0 0 0 Valves 1598 69 1627 293 Other* 449 40 203 100 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) Ethylhenzene(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): Component Gas Service Heavy Oil Light Oil Weser/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Point 006: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu ' g/bhp-hr . lb/MMBtu g/bhp-hr NOx 0.1340 0.50 0.1340 0.50 CO 0.6513 2.43 0.0536 0.20 VOC 0.1930 0.72 0.0670 0.25 50000 Formaldehyde 0.1179 0.44 0.0268 0.10 75070 Acetaldehyde 0.0084 0.03 0.0084 0.03 AIRS ID: 12319C84 Page 20 of 34 olor Depa en P li Health and Environment it Pollution Control Division io Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr 107028 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n-Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8225 Btu/hp-hr, a site-rated horsepower value of 1380, and a fuel heating value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer 75070 Acetaldehyde AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 67561 Methanol AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 110543 n-Hexane AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-2 (7/2000); No Control Natural Gas Point 007: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 0.1340 0.50 0.1340 0.50 CO 0.6513 2.43 0.0536 0.20 VOC 0.1930 0.72 0.0670 0.25 50000 Formaldehyde 0.1179 0.44 0.0268 0.10 75070 Acetaldehyde 0.0084 0.03 0.0084 0.03 107028 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n-Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8225 Btu/hp-hr, a site-rated horsepower value of 1380, and a fuel heating value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer AIRS ID: 12319C84 Page 21 of 34 olor CASDDePFTthmnmt ontrolled EF Source 75070 Acetaldehyde AP-42;Table 3.2-2 (7/2000); No Control Natural Gas 107028 Acrolein AP-42;Table 3.2-2 (7/2000); No Control Natural Gas 67561 Methanol AP-42;Table 3.2-2 (7/2000); No Control Natural Gas 110543 n-Hexane AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-2 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-2 (7/2000); No Control Natural Gas Point 008: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 4.0927 15.23 0.2687 1.00 CO 4.0927 15.23 0.5374 2.00 VOC 0.2257 0.84 0.0376 0.14 50000 Formaldehyde 0.0537 0.20 0.0134 0.05 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8204 Btu/hp-hr, a site-rated horsepower value of 332, and a fuel heating value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer 67561 Methanol AP-42;Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3(7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3(7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3(7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3(7/2000); No Control Natural Gas AIRS ID: 12319C84 Page 22 of 34 olor Depa en li Health and Environment it Pollution Control Division Point 009: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 4.0927 15.23 0.2687 1.00 CO 4.0927 15.23 0.5374 2.00 VOC 0.2257 0.84 0.0376 0.14 50000 Formaldehyde 0.0537 0.20 0.0134 0.05 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 I 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8204 Btu/hp-hr, a I site-rated horsepower value of 332, and a fuel heating value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas Point 010: Emission Factors- Emission Factors— Uncontrol led Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 2.9978 11.24 0.2667 1.00 CO 2.1470 8.05 0.5334 2.00 VOC 0.3147 1.18 0.1334 0.50 50000 Formaldehyde 0.0205 0.08 0.0205 0.08 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 AIRS ID: 12319C84 Page 23 of 34 olor Depa en li Health and Environment it Pollution Control Division Emission facto nsu Factor of 8266 Btu/hp-hr, a site-rated horsepower value of 110, and a fuel heating value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer/Reg. 7 limit Manufacturer/Reg. 7 limit CO Manufacturer/Reg. 7 limit Manufacturer/Reg. 7 limit VOC Manufacturer/Reg. 7 limit Manufacturer/Reg. 7 limit 50000 Formaldehyde AP-42; Table 3.2-3 (7/2000); AP-42; Table 3.2-3 (7/2000); Natural Gas Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42;Table 3.2-3(7/2000); No Control Natural Gas Point 011: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 0.1393 0.50 0.1393 0.50 CO 0.1393 0.50 0.1393 0.50 VOC 0.1393 0.50 0.1393 0.50 50000 Formaldehyde 0.0205 0.07 0.0205 0.07 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7914 Btu/hp-hr, a site-rated horsepower value of 449, and a fuel heating value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Conservative Operator CO Conservative Operator VOC Conservative Operator 50000 Formaldehyde AP-42; Table 3.2-3(7/2000); AP-42; Table 3.2-3(7/2000); Natural Gas Natural Gas 67561 Methanol AP-42; Table 3.2-3(7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42;Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control AIRS ID: 123/9C84 Page 24 of 34 olor Depa en P li Health and Environment it Pollution Control Division CAS nt oll me Controlled EF Source Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas Point 012: Emission Factors - Emission Factors - Uncontrolled Controlled CAS Pollutant lb/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 1111 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 than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Points 006-011: These engines are 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 006-012: These engines are 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: NOx, 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 AIRS ID: 12319C84 Page 25 of 34 Depa en li ealth and Environment it Pollution Control Division 10) Full text of the TitlDolor f • e is Co Federal Regulations can be found at the website listed below: http://ecfr.q p oaccess.q 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 ZZZZ—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/oacifidcdohe/air-permit-selfcertification AIRS ID: 12319C84 Page 26 of 34 olor Depa en TiHealth and Environment it Pollution Control Division 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 requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9O84 Page 27 of 34 olor Depa en li ealth and Environment it Pollution Control Division 2.1.2 The owner or o y a epl fisting ressor 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.gov/cs/Satellite/CD PH E-AP/CBO N/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760),whichever applies. AIRS ID: 123/9C84 Page 28 of 34 olor Depa en P li Health and Environment it Pollution Control Division For comparison with a I a er ' (Ib/ ), 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 NON: 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. Lean bum engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9C84 Page 29 of 34 dor Depa en li Health and Environment it Pollution Control Division 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: Max Engine HP Construction or Emission Standards in G/hp-hr Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine(RICE) MACT: 40 CFR Part 63, Subpart 7777 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 AIRS ID: 123/9C84 Page 30 of 34 olor Depa en li Health and Environment it Pollution Control Division requirements for the ., :v- e incl 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 P 9 9 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: 12319C84 Page 31 of 34 olor Depa en li ealth and Environment it Pollution Control Division 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 temporary replacement engine shall be made as set forth in section 2.1.3. 3.1.2 An Air Pollutant Emissions Notice(APEN)that includes the specific AIRS ID: 123/9C84 Page 32 of 34 Depa en li Health and Environment it Pollution Control Division manuf_,- Dolor •d s b pow e 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 by Condition 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 IIII. 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 63, Subpart ZZZZ. Any permanent replacement engine located at either an area or major source is subject to the requirements of 40 CFR Part 63, Subpart 7777. An analysis of AIRS ID: 123/9C84 Page 33 of 34 olor Depa en li ealth and Environment it Pollution Control Division applica ri g, 'ng re ents 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: 123/9C84 Page 34 of 34 001 Thirty-six(36)750 bbl and eight(8)538 bbl above ground atmospheric condensate storage tank: Emissions Calculations Pollutant E.F. Source VOC 0.78 lb/bbl E&P TANK Benzene 0.0055 lb/bbl E&P TANK n-Hexane 0.036 lb/bbl E&P TANK Requsted Throughput 2700000 bbl Control 0 No Control 0 Flare Pollutant Uncontrolled Emissions Controlled Emissions VOC 1053 tpy 52.65 tpy Benzene 14850 lb/yr 742.5 lb/yr n-Hexane 97200 lb/yr 4860 lb/yr 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 flare orother flare for the combustion of waste gases shall allow or cause emissions into the smokeless a e atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Requlation 2—Odor 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. Requlation 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 0000: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 OmanicComoounds 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 since actual uncontrolled emissions are greater than 20 tpy of VOC.) 002 Twelve (12) above ground 500 bbl and two(2) below ground 100 bbl produced water storage tan Emissions Calculations Pollutant E.F. Source VOC 0.262 lb/bbl CDPHE Benzene 0.007 lb/bbl CDPHE n-Hexane 0.022 lb/bbl CDPHE Requsted Throughput 1,000,000 bbl Control O No Control ®Flare Pollutant Uncontrolled Emissions Controlled Emissions VOC 131 tpy 6.55 tpy Benzene 7000 lb/yr 350 lb/yr n-Hexane 22000 lb/yr 1100 lb/yr 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 AP-42:Chapter 5.2 Equation 1 L= 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S=Saturation Factor P =true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] 1 degree Fahrenheit=460.67 degree Rankine Source S 0.6 Submerged loading: dedi AP-42 P 3.94 psia Sales Oil Analysis M 68 lb/lb-mole AP-42 T 520 deg. R Field Data L 3.85 lb/103 gal 1.62E-01 lb/bbl Annual requested Throughput 2700000 BBL/yr 113400000 gal/yr Annual Uncontrolled VOC emissions 436802 lb/yr Requested Emissions 218.40 tpy 10.92 Regulatory Considerations The average daily throughput from this facility is 310,685 gallons, which is above 20 gallons. However,this facility is not condisdered a terminal (in Reg. 7) because it is a well head facility. This facility is not considered a bulk plant(in Reg. 7) because it does not distribute gasoline. NCRPs uncontrolled Controlled Component Mass Frac. lb/yr tpy Emission Factor lb/yr Benzene 0.009 3931 1.97 0.0015 lb/bbl 197 Toluene 0.013 5678 2.84 0.0021 lb/bbl 284 Ethylbenzene 0.001 437 0.22 0.0002 lb/bbl 22 Xylenes 0.005 2184 1.09 0.0008 lb/bbl 109 n-hexane 0.016 6989 3.49 0.0026 lb/bbl 349 005 Fugitive VOC leak emissions Operation(M1rs/yrl 8760 SCC Cole:31040220.Al Epuip.Leak FSORNes lVaNcs,Flanges.Connections,seals,drains) Fugitive Component Counts 8 Emissions voc Benzene Toluene ENvlbenzene Xylem n-Hexane TOC EF Component lb/hr- TOO EF Control Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Service Type Count 1101AC0 kg/hr-source lyl Bpv) (tool IlOyr) (lb/yrl (lb/y0 IINyr) (lbOrl Il&pr) (lb/yr) (IVyr) IIIVvr) lthArl Valves 1598 9.92E-03 4.50E-03 68.0% 20.14 6A 277.8 88.9 277.8 88.9 138.9 44.4 138.9 44,4 833,3 266.6 Pump Seals 4 539E-03 2.40E-03 0 0.03 0,0 0.4 0,4 0.4 0,4 02 0.2 0,2 02 1.1 1.1 Gas Others 449 1.94E-02 8.81E-03 0 0% 11.07 11.1 152.6 152.6 152.6 152.6 76.3 76.3 76.3 76.3 457.8 457.8 Connectors 2843 4.41E-04 2.00E-04 00% 1.59 1.6 22.0 22.0 22,0 2E0 11.0 11.0 11.0 11.0 65.9 65.9 Flanges 493 8.60E-04 3.97E-00 0.0% 0.54 0.5 74 ]4 ]4 7,4 3.7 37 3.7 37 22.3 233 Open-ended lines 3 641E-03 2.03E-03 0 0.02 0.0 0,2 02 02 0.2 0,1 0.1 0.1 0.1 0,7 07 Valves 1827 551E-03 2.50E-03 60.0% 39,28 12.6 23566 754.1 2356.6 754,1 235.7 754 235.7 75.4 3927.7 1256.9 Pump seals 0 287E-02 130E-02 680% 0.00 0.0 0,0 0.0 00 0.0 0.0 00 00 00 0,0 0.0 203 165E-02 7.50E-03 00% 14.70 14.7 862.1 882.1 882.1 882.1 88.2 08.2 88.2 88,2 1470.2 1470.2 light Oil Others Connectors 1682 4.63E-04 2.10E-04 0 0% 3,41 30 204.6 204.6 204.6 204.6 205 20.5 20,5 205 3411 341.1 Flanges 375 2.43E-04 1,10E-04 00% 040 04 23.9 239 23,9 239 2A 2A 2A 26 39.8 39.8 Open-ended lines 0 3,o3E-03 1.40E-03 0 0.04 0.0 0.0 0.0 00 0.0 0.0 o.o 00 00 0,0 00 Valves 69 1,85E-05 840E-06 00% 0.01 00 0.0 00 00 0.0 0.0 0,0 0.0 Pump Seals 00 0,0 00 ... .,., ....... Heavy Oil Othera 40 7.05E-05 330E-05 00% 0.01 00 0.0 0.0 0,o 00 a0 0.0 00 0.0 00 0.0 Connectors 179 1.65E-05 7.50E-06E-06 00% 0.01 0.0 0.0 0.0 0.0 0,0 00 0.0 0.0 0.0 Oo a.0 Flanges 0 B6CE-04 3.90E-07 0.0% 0.03 00 0,0 0.0 00 0.0 00 0.0 0.0 0,0 0,0 0.0 Open-ended lines 0 309E-04 140E-04 00% 000 0.0 0.0 0.o Oo 00 0.0 0.0 0.0 0.6 0,3 Oo Valves 293 2.16E-04 980E-05 68.0% 028 0.0 0,2 01 02 0.1 0,0 0,0 0.0 00 03 0.1 Pump Seals 0 539E-0a 340E-02 680% 3,9 2. 00 0.0 00 00 0.0 0.0 00 0.0 00 0.0 Water/OA Others 100 303E-02 140E-02 00% 1352 135 8,1 a1 8,1 61 00 0.0 0.0 00 135 13,5 Connectors 379 2.43E-04 1.10E-04 00% 0.40 0,0 00 02 0.2 0.2 00 0.0 0,0 00 OA 0.4 Flanges 48 6.39E-06 190E-06 0.0% 0.00 00 0.0 00 0,0 00 00 0.0 0.0 Opemendee lines 0 5.51E-W 2,50E-04 0 0% ON 00 0.0 00 0.0 0.0 00 0.0 0.0 00 00 0.0 TOTALS (1tpy) 105,41 64.81 197 10] 1% 10] 029 0.16 0.68 0,18 3,9 197 TOTALS(INyr) 3938,1 2144.6 3936,1 2144.6 5'9.9 222.2 576.9 322.2 7174.0 39384 With safety fasted 1 1.97 1.07(TOTAL TOTAL Ibay) I Ibyr) 10581 64.51 I 393813 121465 1 393813 1214465 / 576.90 I 32222 57890 32222 I 7174.02 13936401 Emission Factor Source: EPA-153/R-95.017.Table 2-4 Stream VOC Fraction lest) Stream HAP Components net fraction) GDS 02901 HAP 0 ar tins 011 rvea We 06 ter/oil Light Oil 1.0000 Benzene 0002 0.030 000 00003 Heavy Oil 10000 Toluene 0002 0030 0th WO2 Water/oil 1.0000 Ethyl benzene 0001 0002 0.00 0.0] oylene 0001 0.0]3 000 000 n-Hexane 0006 0050 000 000005 Notes Req.3 The source le In atldnnK therefore.It Y not subject to RACT regcmmxM Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0501 Facility Name Rohn LD4 Econode AIRS 123/9C84/006 Facility Location NESE Section 4, Township 9N, Range 58W Review Date 04/14/2014 Facility Equipment ID GL Comp1 Permit Engineer Oluwaseun Ogungbenle Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One(1) Caterpillar, Model G3516B, Serial Number JEF02156, natural gas-fired, turbo-charged, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine is equipped with an oxidation catalyst and an air/fuel ratio controller.This emission unit is used for natural gas compression. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 76.48 PTE Calculated at(hpy) 8760 Requested(mmscf/m) 6.50 Permit limits calculated at(hpy) 8760 Fuel Heat Value(btu/scf) 1300 BSCF(Btu/hp-hr) 8225 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer Manufacturer VOC Manufacturer Manufacturer CO Manufacturer Manufacturer Formaldehyde Manufacturer Manufacturer SOX AP-42;Table 3.2-2(7/2000);Natural Gas No Control TSP AP-42;Table 3.2-2(7/2000);Natural Gas No Control PM10 AP-42;Table 3.2-2(7/2000);Natural Gas No Control PM2.5 AP-42;Table 3.2-2(7/2000);Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources- HAPs, etc. Point Summary of Criteria Emissions(tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 6.7 6.7 6.7 0.0% VOC 9.6 3.3 9.6 65.3% CO 32.4 2.7 32.4 91.8% SOx 0.0 0.0 0.0 0.0% TSP 0.5 0.5 0.5 . 0.0% PM10 0.5 0.5 0.5 0.0% PM2.5 0.5 0.5 0.5 0.0% Total HAPs* 0.0 0.0 6.8 66.4% 'Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. • Point Summary of Hazardous Air Pollutants lb/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde 11727 2665 11727 77.3% Acetaldehyde 831 831 831 0.0% Acrolein 511 511 511 0.0% Methanol * 249 0.0% n-Hexane * * 110 0.0% Benzene * * 44 0.0% Toluene • * 41 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Source is not required to model based on Division Guidelines/No NAAQS violations expected(see Ambient Air Impacts details of modeling analysis) Public Comment Public Comment Required MACT 7777 Missing or invalid entry information over 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? This engine commenced construction after 06/12/2006 and is located at an area Is this engine subject to MACT 7777 area source of HAPs.Therefore,this engine is a MACT 7777(area source) Yes source requirements? new area source under MACT 7777 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the Is this engine subject to NSPS JJJJ? Yes NSPS JJJJ applicability date of 07/01/2007.Therefore, it is subject to the NSPS JJJJ requirements of this subpart. Note:JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes This engine is one of five compressor engines at this facility.All five engines in addition to two generator engines are part of a facility wide permit for this facility. Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0501 Facility Name Rohn LD4 Econode AIRS 123/9C84/007 Facility Location NESE Section 4,Township 9N, Range 58W Review Date 04/16/2014 Facility Equipment ID GL Comp2 Permit Engineer Cluwaseun Ogungbenle Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One(1) Caterpillar, Model G3516B, Serial Number JEF02168, natural gas-fired,turbo-charged, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine is equipped with an oxidation catalyst and an air/fuel ratio controller. This emission unit is used for natural gas compression. Natural Gas Consumption Hours of Operation Requested(mmscf/yr) 76.48 PTE Calculated at(hpy) 8760 Requested(mmscf/m) 6.50 Permit limits calculated at(hpy) 8760 Fuel Heat Value(btu/scf) 1300 BSCF(Btu/hp-hr) 8225 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer Manufacturer VOC Manufacturer Manufacturer CO Manufacturer Manufacturer Formaldehyde Manufacturer Manufacturer SOX AP-42;Table 3.2-2(7/2000);Natural Gas No Control TSP AP-42;Table 3.2-2(7/2000);Natural Gas No Control PM 10 AP-42;Table 3.2-2(7/2000);Natural Gas No Control PM2.5 AP-42;Table 3.2-2(7/2000);Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources- HAPs, etc. Point Summary of Criteria Emissions(tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 6.7 6.7 6.7 0.0% VOC 9.6 3.3 9.6 65.3% CO 32.4 2.7 32.4 91.8% SOx 0.0 0.0 0.0 0.0% TSP 0.5 0.5 0.5 0.0% PM10 0.5 0.5 0.5 0.0% PM2.5 0.5 0.5 0.5 0.0% Total HAPs* 0.0 0.0 6.8 66.4% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants ,Ib/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde 11727 2665 11727 77.3% Acetaldehyde 831 831 831 0.0% Acrolein • A511 511 511 0.0% Methanol * * 249 0.0% n-Hexane * * 110 0.0% Benzene * 44 0.0% Toluene * * 41 0.0% *Uncontrolled requested and controlled requested values am shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Source is not required to model based on Division Guidelines/No NAAQS violations expected(see Ambient Air Impacts details of modeling analysis) Public Comment Public Comment Required MACT 7777 Missing or invalid entry information over 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? This engine commenced construction after 06/12/2006 and is located at an area Is this engine subject to MACT 7777 area Yes source of HAPs.Therefore,this engine is a MALT 7777(area source) source requirements? new area source under MACT 7777 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the NSPS JJJJ applicability date of Is this engine subject to NSPS JJJJ? Yes 07/01/2007. Therefore, it is subject to the NSPS JJJJ requirements of this subpart. Note:JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes This engine is one of five compressor engines at this facility.All five engines in addition to two generator engines are part of a facility wide permit for this facility. Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0501 Facility Name Rohn LD4 Econode AIRS 123/9C84/008 Facility Location NESE Section 4,Township 9N, Range 58W Review Date 04/16/2014 Facility Equipment ID WH Comp1 Permit Engineer Oluwaseun Ogungbenle Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One(1) Caterpillar, Model G3408TA, Serial Number 6NB05118, natural gas-fired, turbo-charged,4SRB reciprocating internal combustion engine, site rated at 332 horsepower.This engine is equipped with a non-selective catalytic reduction (NSCR) system and an air/fuel ratio controller. This emission unit is used for natural gas compression. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 18.35 PTE Calculated at(hpy) 8760 Requested(mmscf/m) 1.56 Permit limits calculated at(hpy) 8760 Fuel Heat Value(btu/scf) 1300 BSCF (Btu/hp-hr) 8204 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer Manufacturer VOC Manufacturer Manufacturer CO Manufacturer Manufacturer Formaldehyde Manufacturer Manufacturer SOx AP-42;Table 3.2-3(7/2000);Natural Gas No Control TSP AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM10 AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM2.5 AP-42;Table 3.2-3(7/2000);Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources-HAPs, etc. Point Summary of Criteria Emissions(tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 48.8 3.2 48.8 93.4% VOC 2.7 0.4 2.7 83.3% CO 48.8 6.4 48.8 86.9% SOx 0.0 0.0 0.0 0.0% TSP 0.2 0.2 0.2 0.0% PM10 0.2 0.2 0.2 0.0% PM2.5 0.2 0.2 0.2 0.0% Total HAPs* 0.0 0.0 0.8 61.4% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants Ib/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde 1282 321 1282 75.0% Methanol * * 73 0.0% Acetaldehyde * 67 0.0% Acrolein * 63 0.0% Benzene * * 38 0.0% 1,3-Butadiene * 16 0.0% Toluene * * 13 0.0% *Uncontrolled requested and controlled requested values am shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Source is not required to model based on Division Guidelines/No NAAQS violations expected (see Ambient Air Impacts details of modeling analysis) Public Comment Public Comment Required MACT 7777 Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? This engine commenced construction after 06/12/2006 and is located at an area Is this engine subject to MACT 7777 area Yes source of HAPs.Therefore,this engine is a MACT 7777(area source) source requirements? new area source under MACT 7777 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the Is this engine subject to NSPS JJJJ? Yes NSPS JJJJ applicability date of 07/01/2008.Therefore, it is subject to the NSPS JJJJ requirements of this subpart. Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes This engine is one of five compressor engines at this facility.All five engines in addition to two generator engines are part of a facility wide permit for this facility. Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0501 Facility Name Rohn LD4 Econode AIRS 123/9C84/009 Facility Location NESE Section 4, Township 9N, Range 58W Review Date 04/16/2014 Facility Equipment ID WH Comp2 Permit Engineer Oluaaseun Ogungbenle Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One(1) Caterpillar, Model G3408TA, Serial Number 6NB05120, natural gas-fired, turbo-charged,4SRB reciprocating internal combustion engine, site rated at 332 horsepower.This engine is equipped with a non-selective catalytic reduction (NSCR) system and an air/fuel ratio controller. This emission unit is used for natural gas compression. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 18.35 PTE Calculated at(hpy) 8760 Requested(mmscf/m) 1.56 Permit limits calculated at(hpy) 8760 Fuel Heat Value(btu/scf) 1300 BSCF (Btu/hp-hr) 8204 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer Manufacturer VOC Manufacturer Manufacturer CO Manufacturer Manufacturer Formaldehyde Manufacturer Manufacturer SOX AP-42;Table 3.2-3(7/2000);Natural Gas No Control TSP AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM10 AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM2.5 AP-42;Table 3.2-3(7/2000);Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources-HAPs, etc. Point Summary of Criteria Emissions(tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 48.8 3.2 48.8 93.4% VOC 2.7 0.4 2.7 83.3% CO 48.8 6.4 48.8 86.9% SOX 0.0 0.0 0.0 0.0% TSP 0.2 0.2 0.2 0.0% PM10 0.2 0.2 0.2 0.0% PM2.5 0.2 0.2 0.2 0.0% Total HAPs* 0.0 0.0 0.8 61.4% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. • Point Summary of Hazardous Air Pollutants Ib/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde 1282 321 1282 75.0% Methanol 73 0.0% Acetaldehyde 67 0.0% Acrolein 63 0.0% Benzene 38 0.0% 1,3-Butadiene 16 0.0% Toluene 13 0.0% 'Uncontrolled requested and controlled requested values am shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Source is not required to model based on Division Guidelines/No NAAQS violations expected (see Ambient Air Impacts details of modeling analysis) Public Comment Public Comment Required MACT 7777 Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? This engine commenced construction after 06/12/2006 and is located at an area Is this engine subject to MACT 7777 area source of HAPs.Therefore,this engine is a MACT 7777(area source) source requirements? Yes new area source under MACT 7777 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the Is this engine subject to NSPS JJJJ? Yes NSPS JJJJ applicability date of 07/01/2008. Therefore, it is subject to the NSPS JJJJ requirements of this subpart. Note:JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. • Comments/Notes This engine is one of five compressor engines at this facility.All five engines in addition to two generator engines are part of a facility wide permit for this facility. Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0501 Facility Name Rohn LD4 Econode AIRS 123/9C84/010 Facility Location NESE Section 4, Township 9N, Range 58W Review Date 04/16/2014 Facility Equipment ID VRU Comp1 Permit Engineer Oluwaseun Ogungbenle Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One(1) Cummins, Model 7.4L, Serial Number 00067675, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine, site rated at 110 horsepower. This engine is equipped with a non-selective catalytic reduction (NSCR) system and an air/fuel ratio controller. This emission unit is used for natural gas compression. Natural Gas Consumption Hours of Operation Requested(mmscf/yr) 6.13 PTE Calculated at(hpy) 8760 Requested(mmscf/m) 0.52 Permit limits calculated at(hpy) 8760 Fuel Heat Value(btu/scf) 1300 BSCF (Btu/hp-hr) 8266 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer/Reg.7 limit Manufacturer/Reg.7 limit VOC Manufacturer/Reg.7 limit Manufacturer/Reg.7 limit CO Manufacturer/Reg.7 limit Manufacturer/Reg.7 limit Formaldehyde AP-42;Table 3.2-3(7/2000);Natural Gas AP-42;Table 3.2-3(7/2000);Natural Gas SOX AP-42;Table 3.2-3(7/2000);Natural Gas No Control TSP AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM10 AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM2.5 AP-42;Table 3.2-3(7/2000);Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources- HAPs, etc. Point Summary of Criteria Emissions (tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 11.9 1.1 11.9 91.1% VOC 1.3 0.5 1.3 57.6% CO 8.6 2.1 8.6 75.2% SOx 0.0 0.0 0.0 0.0% TSP 0.1 0.1 0.1 0.0% PM10 0.1 0.1 0.1 0.0% PM2.5 0.1 0.1 0.1 0.0% Total HAPs* 0.0 0.0 0.1 0.0% 'Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants lb/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde * 163 0.0% Methanol * * 24 0.0% Acetaldehyde * * 22 0.0% Acrolein * 21 0.0% Benzene * * 13 0.0% 1,3-Butadiene * * 5 0.0% Toluene 4 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected (see details of modeling analysis) Public Comment Public Comment Required MACT 7777 Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? This engine commenced construction after 06/12/2006 and is located at an area source Is this engine subject to MACT 7777 area Yes of HAPs.Therefore,this engine is a new MACT 7777(area source) source requirements? area source under MACT 7777 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the Is this engine subject to NSPS JJJJ? Yes NSPS JJJJ applicability date of 07/01/2008. Therefore, it is subject to the requirements NSPS JJJJ of this subpart. Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes This engine is one of five compressor engines at this facility.All five engines in addition to two generator engines are part of a facility wide permit for this facility. Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0501 Facility Name Rohn LD4 Econode AIRS 123/9O84/011 Facility Location NESE Section 4,Township 9N, Range 58W Review Date 04/18/2014 Facility Equipment ID Gen1 Permit Engineer Oluwaseun Ogungbenle Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Doosan, Model D146L, Serial Number EEZ0G100147, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine, site rated at 449 horsepower.This engine is uncontrolled. This emission unit is used for power generation. Natural Gas Consumption Hours of Operation Requested(mmscf/yr) 23.94 PTE Calculated at(hpy) 8760 Requested(mmscf/m) 2.03 Permit limits calculated at(hpy) 8760 Fuel Heat Value(btu/scf) 1300 BSCF (Btu/hp-hr) 7914 Emission Factor Sources Uncontrolled Controlled NOx Conservative Conservative VOC Conservative Conservative CO Conservative Conservative Formaldehyde AP-42;Table 3.2-3(7/2000);Natural Gas AP-42;Table 3.2-3(7/2000);Natural Gas. SOX AP-42;Table 3.2-3(7/2000);Natural Gas No Control TSP AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM10 AP-42;Table 3.2-3(7/2000);Natural Gas No Control PM2.5 AP42;Table 3.2-3(7/2000);Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources-HAPs, etc. Point Summary of Criteria Emissions (tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 2.2 2.2 2.2 0.0% VOC 2.2 2.2 2.2 0.0% CO 2.2 2.2 2.2 0.0% SOx 0.0 0.0 0.0 0.0% TSP 0.3 0.3 0.3 0.0% PM10 0.3 0.3 0.3 0.0% PM2.5 0.3 0.3 0.3 0.0% Total HAPs* 0.0 0.0 0.5 0.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants Ib/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde 638 638 638 0.0% Methanol 95 0.0% Acetaldehyde 87 0.0% Acrolein 82 0.0% Benzene 49 0.0% 1,3-Butadiene 21 0.0% Toluene 17 0.0% *Uncontrolled requested and controlled requested values am shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Source is not required to model based on Division Guidelines/No NAAQS violations expected (see Ambient Air Impacts details of modeling analysis) Public Comment Public Comment Required MACT 7777 Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? • This engine commenced construction after 06/12/2006 and is located at an area source Is this engine subject to MACT 7777 area Yes of HAPs.Therefore,this engine is a new MACT 7777(area source) source requirements? area source under MACT 7777 and is required to meet applicable NSPS JJJJ requirements. This engine was manufactured after the Is this engine subject to NSPS JJJJ? Yes NSPS JJJJ applicability date of 07/01/2008. Therefore, it is subject to the requirements NSPS JJJJ of this subpart. Note:JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes This engine is one of two power generation units at this facility.The other unit is diesel-fired. Both engines in addition to five compressor engines are part of a facility wide permit for this facility. Division Information Engineer: Oluwaseun Ogungbenle Control Engineer: Chris Laplante Review Date: 04/17/2014 Application Date: 03/03/2014 Facility Identifiers Permit No. 14WE0501 AIRS County It 123 Weld Facility# 9C84 Facility Type: exploration and production facility ❑Located in the 8-hour non-attainment area? O True Minor *Synthetic Minor for: r VOC r NOx 17 CO Section 01: Administrative Information Company Name: Noble Energy, Inc. Source Name: Rohn LD04 Econode Source Location: NESE Section 4, Township 9N, Range 58W SIC: 1311 Address 1: Noble Energy, Inc. Mailing Address 2: 1625 Broadway, Suite 2200 Address :ity,State Zip: Denver, CO 80202 Name: Taryn Weiner Person To Phone: 303-228-4362 Contact Fax: 303-228-4286 Email: tweineranobleenergvinc.com Section 02: Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the Rohn LD04 Econode, located in the NESE Section 4, Township 9N, Range 58W, Weld County, Colorado. Point Name Type Control 001 Tanks Condensate Tanks Flare 002 PW Water Tanks Flare 003 TLO Loadout Flare 004 Flare Separator Venting Flare 005 Fugitives Fugitives None 006 GL Comp1 Engine Catalytic Oxidizer 007 GL Comp2 Engine Catalytic Oxidizer 008 WH Comp1 Engine Catalytic Reducer 009 WH Comp2 Engine Catalytic Reducer 010 VRU Comp1 Engine Catalytic Reducer 011 Gen1 Engine None 012 Gen2 Engine None Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit ,OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTE \ CuReason for ADEN Submittal(Check all that apply) / /4,C___, . AIRS I Status(Check all tint apply APEN update only° i - ' --y. AIRS ID New 1iou y[CB4 apply! O or previouslly unreported battery O Modification to existing sources \ � 11 1541? . / ❑ Previously grandfathered battery? O Registration for coverage under general perrnitno. 1 arnr O Synthetic minor facility cancellation request for individual permits: � ❑ Located in the 8-hr Ozone Control Area3 0 Application for or Modification of an individual permit-- Administrative permit amendments ❑ Registered under general permit no.GP01 O Other: ❑ Permitted under individual permit: 14wEosO [ O s: A copy of the preliminary analysis conducted by the Division 0For individual permit applications,check if you want O To review a draft of the permit prior to issuance OGCC Operator#: 100322 Company Names': Noble Energy,Inc Mailing Address10: 1625 Broadway Suite 2200 twefoer@oobteevergyinc City: Denver State: CO Zip: 80202 E-mail: .com Contact Name: Taryn Weiner Phone: (303)228-4362 Fax: (303)228-4286 Number of tanks: 36--15P ' g—cvgbb Tank Battery Name": ROHN LD04 ECONODE Sec.T Range.) NESE SEC4 T9N R58W County: Weld Total tank capacity[bbl]: 2'3;090" 31,3/3?÷ Location12(QQ w'P g ) Calendar year for which"Actual" data appliesis: 2013 Year(s)tank(s)were placed in services: 2013 Control Efficiency's: 95% Control Description's: Flare Condensate Throughput's[bbl/year] Requested18: 2,700,000 Maximum for PTE calculation's: 2,700,000 Actual": 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. ®Check if site-specific emission factors provided to calculate emissions". Re uested Emissions" Actual Emissions" Emission Factor Battery 9 Pollutant" [lb/bbl] PTE Uncontrolled26 Controlled?? Uncontrolled26 Controlled ss 0.78 1,053.0 1,053.0 52.7 VOC[tons/year] NOx[tons/year] CO[tons/year] 14,850.0 742.5 0.0055 14,850.0 Benzene[lbs/year] 4,860.0 n-Hexane[lbs/year] 0.036 97,200.0 97,200.0 Wells serviced by this tank or tank battery's API#: Name: See attached list ®Newly Reported Well O Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a registration for coverage under general permit GPI,I further certify that this source is and will be operated in full compliance with each condition of general permit GP1. �/ -1 /r l��}u, March 3,2014 ! lJ Date Signature f Legally Authorized Person(not a vendor or consultant) Environmental Engineer Taryn Weiner Official Title Type or Print Name of Person Signing Above For information call: Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment form 692-3150 filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-Bl $250 General Pennit fee for each new GP 4300 Cherry Creek Drive South 06486 registration to: Denver,CO 80246-1530 FORM APCD-205 I Page 1 of 3 ROHN LD4 ECONODE TB APEN.doc Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Wells serviced by this tank or tank battery API it: 05-123-37480 Name: ROHM STATE LD04-67-1HN ®Newly Reported Well API#: 05-123-37481 Name ROHN STATE LD04-66HN ®Newly Reported Well API#: 05-123-37470 Name: ROHM STATE LD04-66-I HN ®Newly Reported Well API#: 05-123-37445 Name: ROHN STATE LD04-65HN ®Newly Reported Well API#: 05-123-37451 Name: ROHM STATE LD04-65-l1-IN ®Newly Reported Well API#: 05-123-37463 Name: ROHM STATE LD04-64IN ®Newly Reported Well API#: 05-123-37482 Name: ROHN STATE LD04-64-1HN Newly Reported Well API#: 05-123-37448 Name: ROHM STATE LD04-63HN ®Newly Reported Well API#: 05-123-37459 Name ROHN STATE LD04-63-1I-IN ®Newly Reported Well API#: 05-123-37461 Name: ROHN STATE LD04-62HN ®Newly Reported Well API#: 05-123-37460 Name: ROHN STATE LD04-62-1HN ®Newly Reported Well API#: 05-123-37450 Name: ROHM STATE LD03-67-1HN ®Newly Reported Well API#: 05-123-37483 Name: ROHN STATE LD03-66HN ®Newly Reported Well API#: 05-123-37458 Name: ROHN STATE LD03-66-1I-IN ®Newly Reported Well API#: 05-123-37455 Name: ROHN STATE LD03-65IN ®Newly Reported Well API#: 05-123-37467 Name: ROHN STATE LD03-65-IHN 0 Newly Reported Well API#: 05-123-37457 Name ROHN STATE LD03-64I-IN ®Newly Reported Well API it: 05-123-37462 Name: ROHN STATE LD03-64-I HN ®Newly Reported Well API it: 05-123-37453 Name: ROHN STATE LD03-63HN ®Newly Reported Well API#: 05-123-37471 Name: ROHN STATE LD03-63-1HN ®Newly Reported Well API#: 05-123-37475 Name ROHN STATE LD03-62I-IN ®Newly Reported Well API#: 05-123-37452 Name: ROHN STATE LD03-62-1HN ®Newly Reported Well API#: 05-123-37472 Name: ROHN STATE LD09-69HN ®Newly Reported Well API#: 05-123-37476 ?Jame: ROHM STATE LD10-69HN 0 Newly Reported Well Page 2 of 3 ROHN LD4 ECONODE TB APEN.doc t. e Q i m o E --- ` _ Z ei y t a c n a- o ia al • $ � 3 to , Q IS G4 ..Syy` && C �.a ,o .o n p O • 'O o L. a Q ' rn rn en C. 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