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Home My WebLink About20142689.tiff STATE OF COLORADO John W.Hickenlooper,Governor /FCO Larry Wolk,MD,MSPH Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado .I 4300 Cherry Creek Dr.S. Laboratory Services Division �.� a t896 Denver,Colorado 80246-1530 8100 Lowry Blvd. " Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Weld County-Clerk to the Board 1150 O St PO Box 758 Greeley,CO 80632 August 26,2014 Dear Sir or Madam: On August 29,2014,the Air Pollution Control Division will publish a public notice for Meadowlark Midstream Company, LLC—Hereford Ranch Processing Plant, in the The Greeley Tribune. 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&Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, "`C'' RECEIVED Clara Gonzales AUG 2 9 2014 Public Notice Coordinator Stationary Sources Program WELD COUNTY Air Pollution Control Division COMMISSIONERS Enclosure 7kl: _ CG#L ;PIA) 2O14-2689 9--eg- 1� X125 STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH F,o -c„ot° Executive Director and Chief Medical Officer Fes/. j Dedicated to protecting and improving the health and environment of the people of Colorado * r i 4300 Cherry Creek Dr.S. Laboratory Services Division .' e]6 Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: Meadowlark Midstream Company,LLC—Hereford Ranch Processing Plant—Weld County Released To: The Greeley Tribune On: August 26, 2014 Published: August 29, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT 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: Meadowlark Midstream Company, LLC Facility: Hereford Ranch Processing Plant Modification to an existing natural gas and liquids processing facility Section 26,T12N, R63W Weld County The proposed project or activity is as follows: Modification to an existing natural gas and liquids processing plant. Modification to the fugitive emissions due to the addition of an emergency flare,two glycol dehydrators, three reciprocating internal combustion engines,two amine units and a hot oil heater. 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.I.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 10WE2188 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: Stephanie Chaousy Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B I Denver,Colorado 80246-1530 cdphe.commentsapcd@state.co.us t III AIT STATE OF COLORADO 04'COQ COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT aRAIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 CONSTRUCTION PERMIT PERMIT NO: 1 0WE2188 Issuance 4 DATE ISSUED: ISSUED TO: Meadowlark Midstream Company, LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas processing facility, known as the Hereford Ranch Processing Plant, located in the Section 26, Township 12N, Range 63W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Emergency open flame flare (make, model, and s/n to FL 011 be provided with a normal operating rate of 12.6 MMBtu per hour, for control of emissions from plant emergency shutdowns, pressure relief valves, and compressor blowdowns. FUG 012 Equipment leaks (fugitive VOCs)from equipment/components in natural gas, natural gas liquid, and heavy oil streams. FUG Equipment leaks (fugitive VOCs) from equipment/components Propane 013 in gaseous and liquid propane service. One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: to be provided) with a design capacity of 4.0 MMscf per day. This emissions unit is equipped TEG 016 with one (1) gas-glycol pump (make, model: to be provided) with a design capacity of 4.0 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Flash tank vapors are vented to the atmosphere. Emissions from this unit are not controlled. One (1) natural gas fired hot oil heater(Make, Model, and s/n HT5802 017 to be provided)for process heating, maximum design rated at 25 MMBtu/hour. AIRS ID: 123/8761 Page 1 of 28 Meadowlark Midstream y, Color o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Facility AIRS Description Equipment ID Point One(1) Diethanolamine (DEA)gas and liquids sweetening system with one liquid-liquid contactor with a design capacity of 75 gpm and one gas-liquid contactor with a design capacity of 10 MMscf/day(Tryer Process Equipment T-6502, SN: 12-011- 300). This emissions unit is equipped with one (1) DXP electric AMInc 018 amine recirculation pump with a total design capacity of 35 gallons per minute. This system includes a natural gas liquids/amine contactor, one natural gas/amine contactor, a flash tank, and an amine regeneration reboiler heated by hot oil. All emissions from the flash tank and amine regenerator are routed to a combustor. One(1) Caterpillar/Olympian, Model G200LG, Serial Number SC13GT304D, natural gas-fired, turbo-charged, 4SRB GE02 027 reciprocating intemal combustion engine, site rated at 289 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for backup power. Emergency flare for plant emergency shutdowns, pressure FL02 028 relief valves and compressor blowdowns. Flare has a minimum destruction efficiency of 95% and it is not enclosed. One (1) Ethylene Glycol (EG) natural gas liquids dehydration unit(make, model, serial number: TBD)with a design capacity of 425 gallons per minute. This emissions unit is equipped with EG02 029 one (1) electric-glycol pump with a design capacity of 6 gallons per minute. This unit is equipped with a reboiler and regenerator. Emissions from the regenerator are routed to a combustor. One(1) Caterpillar/Olympian, Model G200LG, Serial Number To Be Determined, natural gas-fired, turbo-charged, 4SRB GE05 031 reciprocating intemal combustion engine, site rated at 289 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used as an emergency back-up power. One(1) Caterpillar/Olympian, Model G200LG, Serial Number To Be Determined, natural gas-fired, turbo-charged, 4SRB GE04 032 reciprocating intemal combustion engine, site rated at 289 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used as an emergency back-up power. AIRS ID: 123/8761 Page 2 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Facility AIRS Description Equipment ID Point One (1) Caterpillar/Olympian, Model G200LG, Serial Number To Be Determined, natural gas-fired, turbo-charged, 4SRB GE03 033 reciprocating internal combustion engine, site rated at 289 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used as an emergency back-up power. One (1) Diethanolamine (DEA) natural gas, and natural gas liquids, sweetening system with a design capacity of 30 AMIN03 034 MMSCF per day gas treating, and 270 gpm NGL heating (make, model, serial number TBD). This emissions unit is equipped with electric OR gas One (1) Diethanolamine (DEA) natural gas, and natural gas liquids, sweetening system with a design capacity of 30 AMIN02 035 MMSCF per day gas treating, and 270 gpm NGL treating (make, model, serial number TBD). This emissions unit is equipped with electric OR gas HT02 036 Hot oil heater for process heating. Points 027, 031, 032 and 033: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Olympian G200LG engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. Points 028, 029, 031, 032, 033, 034, 035 and 036: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at https://www.colorado.00v/pacific/cdphe/other-air-permitting-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation 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 commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date AIRS ID: 123/8761 Page 3 of 28 Meadowlark Midstream y, Colo o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Sect Point ion II.A.4) Monthly Limits: Facility AIRS Pounds per Month Emission Equipment ID Point NO, VOC CO Type FL 011 646 289 3483 Point FUG 012 — 14575 — Fugitive FUG 013 -- 5742 — Fugitive Propane TEG 016 — 373 — Point HT5802 017 1848 107 1550 Point AMInc 018 — 1088 1835 Point GE02 027 948 476 1896 Point EG02 029 — 51 --- Point GE05 031 238 119 478 Point GE04 032 238 119 478 Point GE03 033 238 119 478 Point AMIN03 034 425 255 2277 Point AMIN02 035 425 255 2277 Point AIRS ID: 123/8761 Page 4 of 28 i Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 HT02 036 1444 85 1206 Point Monthly limits are based on a 31-day month. Quarterly Limits': Pounds per Quarter Facility Emission Equipment AIRS Point I ID NO. VOC CO Type FL02 028 6,402 2,420 34,784 Point 1: Quarterly limits will be established beginning with the calendar month of permit issuance. 2: Quarterly limits are based on a 92-day quarter. Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point NO. VOC CO Type FL 011 3.8 1.7 20.5 Point FUG 012 85.8 — Fugitive FUG 013 — 33.8 — Fugitive Propane TEG 016 --- 2.2 --- Point HT5802 017 10.8 0.6 9.1 Point AMinc 018 --- 6.4 10.8 Point GE02 027 5.6 2.8 11.2 Point FL02 028 12.7 4.8 69.0 Point EG02 029 --- 0.3 -- Point GE05 031 1.4 0.7 2.8 Point GE04 032 1.4 0.7 2.8 Point GE03 033 1.4 0.7 2.8 Point AMIN03 034 2.5 1.5 13.4 Point AMIN02 035 2.5 1.5 13.4 Point HT02 036 8.5 0.5 7.1 Point AIRS ID: 123/8761 Page 5 of 28 Meadowlark Midstream If, to o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 See "Notes to Permit Holder #4 for information on emission factors and methods used to calculate limits. During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly limitation shall be required. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months'data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Points 012 and 013: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, 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. 8. Point 016: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, and other operational values specified in the O&M Plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc. 9. Points 018, 029, 034 and 035: Compliance with the emission limits in this permit shall be demonstrated by running the Promax model on a monthly basis using the most recent amine unit inlet extended gas and liquid analyses and recorded operational values (including gas throughput, NGL throughput, and lean amine recirculation rates). Recorded operational values, except for gas and liquid throughput, shall be averaged on a monthly basis for input into Promax. 10. Point 018: Emissions from the flash tank and amine regenerator shall be routed to a combustor. The combustor shall reduce uncontrolled emissions of VOC from the unit to the emission levels listed in this section, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Point 027: Emissions from this engine shall be routed to a non-selective calalytic reducer. The catalyst shall reduce uncontrolled emissions of NOx and CO from the unit to the emission levels listed in this section, above. (Reference: Regulation No.3, Part B, Section III.E.) 12. Points 034 and 035: 100%of emissions that result from the flash tank associated with these amine units shall be recycled to the plant inlet or to station fuel. AIRS ID: 123/8761 Page 6 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 13. 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 Pollutants Equipment Point Control Device Controlled ID FUG 012 LDAR VOC FUG 013 LDAR VOC Propane AMInc 018 Combustor VOC GE02 027 Non-selective catalytic reduction (NSCR) NOx and CO system and air-fuel ratio control FL02 028 Flare VOC EG02 029 Combustor VOC GE05 031 Non-selective catalytic reduction (NSCR) NOx and CO system and air-fuel ratio control GE04 032 Non-selective catalytic reduction (NSCR) NOx and CO system and air-fuel ratio control Non-selective catalytic reduction (NSCR) GE03 033 NOx and CO system and air-fuel ratio control AMIN03 034 Still Vent: Thermal Oxidizer VOC Flash tank: Recycled to plant inlet or station fuel AMIN02 035 Still Vent: Thermal Oxidizer VOC Flash tank: Recycled to plant inlet or station fuel PROCESS LIMITATIONS AND RECORDS 14. This source shall be limited to the following maximum consumption, processing and/or operational rates as listed below. Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Annual Monthly Limit Equipment Point Process Parameter Limit (31 days) ID FL 011 Consumption of natural gas as a 109.5 9.3 fuel MMSCF MMSCF 1,460 124.0 TEG 016 Processing of natural gas MMSCF MMSCF HT5802 017 Consumption of natural gas as a 216.5 18.4 fuel MMSCF MMSCF AIRS ID: 123/8761 Page 7 of 28 Meadowlark Midstream y, Colo o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Processing of natural gas liquids 39,420,000 3,348,000 AMInc 018 Gallons Gallons Processing of natural gas 3,650 310 MMSCF MMSCF GE02 027 Consumption of natural gas as a M 23.7 2.01 MMsd fueFL02 028 Consumption of natural gas as a 328.5 83.7 fuel MMSCF MMSCF/quarter EG02 029 Processing of natural liquids 223,380,000 18,972,000 gallons gallons GE05 031 Consumption of natural gas as a 5.91 0.50 fuel MMsd/yr MMscf/month GE04 032 Consumption of natural gas as a 5.91 0.50 fuel MMsd/yr MMscf/month GE03 033 Consumption of natural gas as a 5.91 0.50 fuel MMsd/yr MMscf/month Processing of natural gas liquids 3,378,860 286,971.7 AMIN03 034 bbls/yr Gallons Processing of natural gas 10,950 930 MMSCF MMSCF Processing of natural gas liquids 3,378,860 286,971.7 AMIN02 035 bbls/yr Gallons 10,950 930 Processing of natural gas MMSCF MMSCF HT02 036 Consumption of natural gas as a 170.0 14.4 fuel MMSCF MMSCF During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly limitation shall be required. Compliance with the yearly consumption limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly consumption of natural gas and keep a compliance record on site or at a local field office with site responsibility,for Division review. 15. Points 011 and 028: The operator shall continuously monitor total gas volume routed to the flare on a monthly basis using a flow meter. By the end of each month, the total flow for the previous months' data shall be calculated, and a new twelve-month total shall be calculated and recorded based on the previous twelve months' data. 16. Point 016: This unit shall be limited to the maximum lean glycol circulation rate of 4.0 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) 17. Point 018: This unit shall be limited to the maximum lean amine recirculation rate of 35 gallons per minute. A maximum of 27 gallons per minute shall be pumped to the gas- liquid contactor. The amine recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) AIRS ID: 123/8761 Page 8 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 18. Point 029: This unit shall be limited to the maximum lean glycol circulation rate of 6.0 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) 19. Points 034 and 035: This unit shall be limited to the maximum lean amine recirculation rate of 150 gallons per minute. A maximum of 150 gallons per minute shall be pumped to the gas contactor and a maximum of 50 gallons per minute shall be pumped to the liquid contactor. The amine recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 20. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable). 21. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. &4.) 22. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 23. Points 012 and 013: The fugitive emissions addressed by AIRS ID 012-013 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365 Applicability - The group of all equipment, except compressors, within a process unit for which you commence construction, modification or reconstruction after August 23, 2011 is an affected facility per§60.5365(f). • §60.5400 Standards - The group of all equipment, except compressors, within a process unit must comply with the requirements of§60.5400 and §60.5401. • §60.5410 - Owner or operator must demonstrate initial compliance with the standards using the requirements in §60.5410(f). • § 60.5415 - Owner or operator must demonstrate continuous compliance with the standards using the requirements in §60.5415(f). • § 60.5421 - Owner or operator must comply with the recordkeeping requirements of §60.5421(b). • § 60.5422 - Owner or operator must comply with the reporting requirements of paragraphs (b) and (c) of this section in addition to the requirements of§ 60.487a(a), (b), (c)(2)(i)through (iv), and (c)(2)(vii)through (viii). 24. Point 016: This source is subject to the TEG dehydrator area source requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: AIRS ID: 123/8761 Page 9 of 28 Meadowlark Midstream y, olo o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 • §63.764-General Standards o §63.764 (e)(1) -The owner or operator is exempt from the requirements of paragraph (c)(1) and (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). • §63.764 (e)(1)(I) — The actual annual average flowrate of natural gas to the glycol dehydration unit is less than 85 thousand standard cubic meters per day (3.0 MMSCF/day), as determined by the procedures specified in §63.772(b)(1) of this subpart; or • §63.764 (e)(1)(lI) — The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. • §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration o §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under§63.764(e)(1). • §63.772(b)(1) - The determination of actual flowrate of natural gas to a glycol dehydration unit shall be made using the procedures of either paragraph (b)(1)(i) or(b)(1)(ii) of this section. • §63.772(b)(1)(i) — The owner or operator shall install and operate a monitoring instrument that directly measures natural gas flowrate to the glycol dehydration unit with an accuracy of plus or minus 2 percent or better. The owner or operator shall convert annual natural gas flowrate to a daily average by dividing the annual flowrate by the number of days per year the glycol dehydration unit processed natural gas. • §63.772(b)(1)(ii) - The owner or operator shall document, to the Administrator's satisfaction, that the actual annual average natural gas flowrate to the glycol dehydration unit is less than 85 thousand standard cubic meters per day. • §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. • §63.772(bx2)(i) — The owner or operator shall determine actual average benzene emissions using the model GRI- GLYCaIc TM , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc TM Technical AIRS ID: 123/8761 Page 10 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or • §63.772(b)(2)(ii) - The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. • §63.774 - Recordkeeping Requirements o §63.774 (d)(1) -An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. • §63.774 (d)(1)(i) — The actual annual average natural gas throughput (in terms of natural gas flowrate to the glycol dehydration unit per day) as determined in accordance with §63.772(b)(1), or • §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). 25. Points 017 and 036: This source is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A Subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units including, but not limited to, the following: a. The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month (40 CFR Part 60.48c(g)). b. Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record (40 CFR Part 60.48c(i)). In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply. c. 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 AIRS ID: 123/8761 Page 11 of 28 Meadowlark Midstream It, olo o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 d. 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) e. Written notification of construction and initial startup dates shall be submitted to the Division as required under§60.7. f. Records of startups, shutdowns, and malfunctions shall be maintained, as required under§ 60.7 26. Points 017 and 036: Particulate emissions shall be limited as per: Regulation 6, Part B, II.C.2. 27. Points 018, 034 and 036: The amine units addressed by AIRS ID 018 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution including, but not limited to, the following: • §60.5365—Applicability and Designation of Affected Facilities o §60.5365(g)(3) - Facilities that have a design capacity less than 2 long tons per day(LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with recordkeeping and reporting requirements specified in §60.5423(c) but are not required to comply with §§60.5405 through 60.5407 and §§60.5410(g) and 60.5415(g). • §60.5423— Record keeping and reporting Requirements o §60.5423(c) -To certify that a facility is exempt from the control requirements of these standards, for each facility with a design capacity less that 2 LT/D of H2 S in the acid gas (expressed as sulfur) you must keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2 S expressed as sulfur. 28. Points 027, 031, 032 and 033: This equipment is subject to the control requirements for natural gas-fired reciprocating intemal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum' Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx j CO 1 VOC AIRS ID: 123/8761 Page 12 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 1 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. OPERATING & MAINTENANCE REQUIREMENTS 29. Upon startup, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 30. Points 018, 034 and 035: The temperature and pressure of the inlet NGL and natural gas streams shall be recorded monthly. 31. Points 011, 012, 013, 017, 028 and 036: This source is not required to follow a Division- approved operating and maintenance plan. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 32. Point 029: The owner or operator shall complete the initial annual extended liquids analysis testing required by this permit and submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) 33. Point 029: A source initial compliance test shall be conducted on emissions point 029 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) Volatile Organic Compounds using EPA approved methods. 34. Points 018, 034 and 035: This owner or operator shall complete the initial annual sour liquid and sour gas analyses required by this permit and submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) Periodic Testing Requirements AIRS ID: 123/8761 Page 13 of 28 Meadowlark Midstream y, Color o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 35. Point 012: On an annual basis, the pemiittee 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. 36. Point 016: The owner or operator shall complete an extended wet gas analysis of the plant inlet on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit. 37. Point 029: The owner or operator shall complete an extended liquids analysis of the plant inlet on an annual basis. Results of the extended liquids analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit. 38. Points 031, 032 and 033: 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. 39. Points 018, 034 and 035: The operator shall sample the inlet liquid and gas to the plant on an annual basis to determine the concentration 6f hydrogen sulfide (H2S) in the inlet streams. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Onshore Natural Gas Processing: SO2 Emissions (§60.640(b)). The testing required by Condition 40 may be used for this demonstration 40. Points 018, 034 and 035: The owner or operator shall complete extended sour liquid and sour gas analyses prior to the inlet of the amine unit on an semi-annual basis. Results of these analyses shall be used to calculate emissions of criteria pollutants per Condition 6. ADDITIONAL REQUIREMENTS 41. All previous versions of this permit are cancelled upon issuance of this permit. 42. The owner or operator shall submit a cancellation notice for the following equipment within 30 days of commencement of operation for the following equipment: Existing Existing Permit No. Emission Point New Emission Point 10WE2188 123/8761/011 123/8761/027 10WE2188 123/8761/016 123/8761/030 10W E2188 123/8761/018 123/8761/034 and 123/8761/035 43. Revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) AIRS ID: 123/8761 Page 14 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Points 027, 031, 032 and 033: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an altemative-operating scenario and is installing a permanent replacement engine. 44. This source is subject to the provisions of Regulation No. 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The application for the Operating Permit is due within one year of the earliest commencement of operation of any piece of equipment covered by this permit. 45. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 46. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 47. 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 11.8 upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. AIRS ID: 123/8761 Page 15 of 28 Meadowlark Midstream y, olor o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 48. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final"authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 49. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 50. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 51. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 52. 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. 53. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Permit History AIRS ID: 123/8761 Page 16 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Issuance Date Description Issuance 1 August 3, 2012 Issued to Bear Tracker Energy, LLC Issuance 2 May 24, 2013 Change in permit limits for point 011 and addition of point 025. Facility is synthetic minor. Issuance 3 March 18, 2014 Reissued to Meadowlark Midstream Company, LLC. Modified point 018 to include a gas contactor. Changed emissions for points 012 and 013. Addition of point 027. Removed points 019-025 from permit. Issuance 4 This Issuance Modification to Points 012 and 013. Addition of Points 028, 029, 031, 032, 033, 034, 035 and 036. Facility is now major for VOC and CO. • AIRS ID: 123/8761 Page 17 of 28 r Meadowlark Midstream Y. Cob o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Notes to Permit Holder: 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 permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permitee 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: htto://www.cdohe.state.co.us/regulations/airreas/100102aacccommonorovisionsrea.odf. 4) The following emissions of reportable 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. EmisstCrt Are the Controlled AIRS Rate/kr, emissions Emission Point Pollutant CM* BIN pidytt :?' reportable? Rate(lbh/r) Benzene 71432 A 913 Yes 516 Toluene 108883 C 674 Yes 381 012 Ethybenzene 100414 C 90 No 51 Xylene 1330207 C 183 No 96 n-Hexane 110543 C 5872 Yes 3320 Benzene 71432 A 1824 Yes 91 Toluene 108883 C 488 No 24 018 Ethybenzene 100414 C 21 No 1 Xylene 1330207 C 59 No 3 Formaldehyde 5000 A 495 Yes 495 Methanol 67561 C 74 No 74 Acetaldehyde 75070 A 67 Yes 67 027 Acrolein 107028 A 63 Yes 63 Benzene 71432 A 38 No 38 1,3-Butadiene 106990 A 16 No 16 Toluene 108883 C 13 No 13 029 Benzene 71432 A 3707 Yes 185 AIRS ID: 123/8761 Page 18 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Toluene 108883 C 526 Yes 26 Ethylbenzene 100414 C 18 No 1 Xylenes 1330207 C 60 No 3 n-Hexane 110543 C 29 No 2 Formaldehyde 50000 A 124 No 124 031, 032, Acetaldehyde 75070 A 17 No 17 033 Acrolein 107028 A 16 No 16 each Benzene 71432 A 10 No 10 Benzene 71432 A 10495 Yes 492 Toluene 108883 C 1467 Yes 69 034 Ethylbenzene 100414 C 40 No 2 Xylenes 1330207 C 111 No 5 n-Hexane 110543 C 683 Yes 3 Benzene 71432 A 10495 Yes 492 Toluene 108883 C 1467 Yes 69 035 Ethylbenzene 100414 C 40 No 2 Xylenes 1330207 C 111 No 5 n-Hexane 110543 C 683 Yes 3 5) The emission levels contained in this permit are based on the following emission factors: Points 011 and 028: Emission Pollutant Factor Source/Comments Control (%) NOx 0.068 AP-42,Table 13.5-1 0.0% Ib/mmbtu CO Ib m3mbtu AP-42,Table 13.5-1 0.0% 621.0 Engineering o VOC lb/mmscf Calculation 95.0/o Point 012: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 1440 2067 2451 0 Flanges 403 166 375 0 Open-ended Lines 751 233 564 0 Pump Seals 1 11 19 0 Valves 481 272 756 0 Other* 45 5 18 0 VOC Content(wt. fraction) 0.4788 1.0 0.8267 N/A AIRS ID: 123/8761 Page 19 of 28 Meadowlark Midstream y, Colo o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 Benzene Content(wt. 0.00306 WA 0.00306 N/A fraction) Toluene Content(wt. 0.00226 N/A 0.00226 N/A fraction) Ethylbenzene(wt. fraction) 0.0003 N/A 0.0003 N/A Xylenes Content(wt 0.00067 N/A 0.00067 N/A fraction) n-hexane Content(wt. 0.01968 WA 0.01968 N/A 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 Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-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. Control for quarterly monitoring is: 88% gas valve, 76% light liquids valve, and 68%light liquids pump. Point 013: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 297 0 0 0 Flanges 75 0 0 0 Open-ended Lines 583 0 0 0 Pump Seals 1 0 0 0 Valves 132 0 0 0 Other* 8 0 0 0 VOC Content(wt. fraction) 1.0 N/A N/A N/A *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 Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 AIRS ID: 123/8761 Page 20 of 28 Meadowlark Midstream y, Color o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 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. Control for quarterly monitoring is: 88% gas valve, 76% light liquids valve, and 68% light liquids pump. Point 016: The emission levels for this point are based on information provided in the application and the GRI GlyCalc 4.0 model. Points 017 and 036: Pollutant lb/MMSCF Source/Comments Control (%) NOx 100 AP-42 0.0% VOC 5.5 AP-42 0.0% CO 84 AP-42 0.0% Points 018, 029, 034 and 035: The emission levels for this point are based on the ProMax 3.2 model using extended sour gas and liquids analyses representative of the gas and liquid processed by this unit submitted with the permit application. Points 027,031,032 and 033: Emission Factors- Emission Factors— Uncontrolled Controlled - CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 2.2100 9.5500 0.4627 2.0000 CO 3.7200 16.1000 0.9253 4.0000 VOC 0.2310 1.0000 0.2310 1.0000 5000 Formaldehyde 0.0205 0.0886 0.0205 0.0886 67561 Methanol 0.0031 0.0132 0.0031 0.0132 75070 Acetaldehyde 0.0028 0.0121 0.0028 0.0121 107028 Acrolein 0.0026 0.0114 0.0026 0.0114 71432 Benzene 0.0016 0.0068 0.0016 0.0068 106990 1,3-Butadiene 0.0007 0.0029 0.0007 0.0029 108883 Toluene 0.0006 0.0024 0.0006 0.0024 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9530 Btu/hp-hr, a site-rated horsepower value of 289, and a fuel heat value of 1020 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx AP-42; Table 3.2-3(7/2000); EPA Certification Natural Gas CO AP-42; Table 3.2-3(7/2000); EPA Certification Natural Gas VOC AP-42; Table 3.2-3(7/2000); No Control AIRS ID: 123/8761 Page 21 of 28 Meadowlark Midstream y, Colo o ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 CAS Pollutant Uncontrolled EFSource Controlled EF Source Natural Gas 5000 Formaldehyde AP-42;Table 3.2-3(7/2000); No Control Natural Gas 67561 Methanol AP-42;Table 3.2-3(7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42;Table 3.2-3(7/2000); No Control Natural Gas 107028 Acrolein AP-42;Table 3.2-3(7/2000); No Control Natural Gas 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 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 tern 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 027, 031, 032 and 033: 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: htto:// .eoa.aov/ttn/atw/area/fr18ia08.odf 8) Points 027, 031, 032 and 033: 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: htto://www.eoa.aov/ttn/atw/area/fr18ia08.odf Additional information regarding area source standards can be found on the EPA website at: htto://www.eoa.aoWttn/atw/area/arearules.html 9) This facility is dassified as follows: Applicable Status Requirement Operating Permit Major Source: CO,VOC Synthetic Minor Source: benzene PSD Synthetic Minor Source: VOC MACT HH Area Source Requirements: Applicable MACT ZZZZ Area Source Requirements: Not Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below. AIRS ID: 123/8761 Page 22 of 28 Meadowlark Midstream y, Color o D ublic Health and Environment Permit No. 10WE2188 Air Pollution Control Division Issuance 4 http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart 7777-Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 11) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.00v/pacific/cdphe/air-permit-selfcertification AIRS ID: 123/8761 Page 23 of 28 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12,2012 2.Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.& 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. 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements - applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven(7)calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer)as found on the Division's web site at: http://www.colorado.gov/cs/Satellite/CDPH E-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.RS. 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 intemal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below Rich bum engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean bum engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVILE—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements).However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part 8, § LB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. r Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Meadowlark Midstream Company, LLC Permit Number: 10WE2188 Source Location: Hereford Ranch Processing Plant Section 26,T12N, R63W,Weld County(attainment) Point 012: Fugitive emissions Point 013: Fugitive emissions—propane Point 028: emergency flare Point 029: EG dehydrator Point 030: TEG dehydrator(APEN-exempt; permit-exempt source) Equipment Description: Point 031: Reciprocating internal combustion engine Point 032: Reciprocating internal combustion engine Point 033: Reciprocating internal combustion engine Point 034: Amine unit Point 035: Amine unit Point 036: Hot oil heater AIRS ID: 123-8761 Date: August 5, 2014 Review Engineer: Stephanie Chaousy, PE Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered X Modification APEN Required/Permit Exempt X CP4 Transfer of Ownership APEN Exempt/Perrnit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered"no"to any of the above, when did you mail an See Section 14 Information Request letter to the source? On what date was this application complete? April 7, 2014 Section 4-Source Description AIRS Point Equipment Description 012 Fugitive VOC leak emissions Page 1 013 Fugitive VOC leak emissions 028 Emergency flare for plant emergency shutdowns, pressure relief valves and compressor blowdowns. Flare has a minimum destruction efficiency of 95%and it is not enclosed. One(1) Ethylene Glycol (EG) natural gas dehydration unit(make, model, serial number. TBD)with a design capacity of 425 gallons per minute. This emissions unit is equipped 029 with one(1)electric-glycol pump with a design capacity of 6 gallons per minute. This unit is equipped with a reboiler and regenerator. Emissions from the regenerator are routed to a combustor. One(1)Caterpillar/Olympian, Model G200LG, Serial Number To Be Determined, natural gas-fired,turbo-charged,4SRB reciprocating internal combustion engine, site rated at 289 031 horsepower.This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control.This emission unit is used as an emergency back-up power. One(1)Caterpillar/Olympian, Model G200LG, Serial Number To Be Determined, natural gas-fired, turbo-charged,4SRB reciprocating internal combustion engine, site rated at 289 032 horsepower.This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control.This emission unit is used as an emergency back-up power. One(1)Caterpillar/Olympian, Model G200LG, Serial Number To Be Determined, natural gas-fired, turbo-charged,4SRB reciprocating ineemal combustion engine, site rated at 289 033 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control. This emission unit is used as an emergency back-up power. One(1) Diethanolamine(DEA) natural gas, and natural gas liquids, sweetening system 034 with a design capacity of 30 MMSCF per day gas treating, and 270 gpm NGL treating (make, model, serial number.TBD). This emissions unit is equipped with electric OR gas One(1) Diethanolamine(DEA) natural gas, and natural gas liquids, sweetening system 035 with a design capacity of 30 MMSCF per day gas treating, and 270 gpm NGL treating (make, model, serial number. TBD). This emissions unit is equipped with electric OR gas 036 Hot oil heater for process heating. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? If'yes',for what pollutant? PM,o CO Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes",for what pollutant? (Note:These pollutants are subject to minor source PMlo CO Ozone RACT per Regulation 3, Part B,Section III.D.2) Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes"the provisions of Yes X No Regulation 7,Sections XII and XVII.C may apply) Page 2 Section 5—Emission Estimate Information AIRS Emission Factor Source Point 012 EPA-453/R-95-017, Table 2-4 013 EPA-453/R-95-017, Table 2-4 028 NOx and CO:AP-42,Table 13.5-1 VOC from 029 Site-specfic using Promax Simulation Model (refer to Section 14 for calculations) 031 NOx, VOC and CO:AP-42/Manufacturer HAP: AP-42, Table 3.2-3 032 NOx,VOC and CO:AP-42/Manufacturer HAP: AP-42, Table 3.2-3 033 NOx,VOC and CO:AP-42/Manufacturer HAP: AP-42,Table 3.2-3 034 Site-specfic using Promax Simulation Model (refer to Section 14 for calculations) 035 Site-specfic using Promax Simulation Model (refer to Section 14 for calculations) 036 AP-42, table 1A-1 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Process Consumption/Throughput/Production Point Equipment Type Gas Heavy Oil (or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 1440 2067 2451 012 Flanges 403 166 375 — Open-Ended Lines 751 233 564 Pump Seals 1 11 19 — Valves 481 272 756 Other 45 5 18 Equipment Type Gas Heavy Oil (or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 297 — — — 013 Flanges 75 -- — — Open-Ended Lines 583 -- --- — Pump Seals 1 -- --- — Valves 132 — — — Other 8 — — — 028 328.5 MMscf/yr 029 223,380,000 gallons/year= 29.86 MMscf/yr,6 gallons per minute glycol circulation rate 031 5.9 MMscf/yr 032 5.9 MMscf/yr 033 5.9 MMscftyr 034 10,950 MMscf/yr 035 10,950 MMscf/yr 036 170.0 MMscf/yr Basis for Actual Emissions.Reported During this APEN Filing (Reported to Inventory) AIRS Process Consumption/Throughput/Production Point Page 3 Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 1440 2067 2451 - 012 Flanges 403 166 375 — Open-Ended Lines 751 233 564 — Pump Seals 1 11 19 — Valves 481 272 756 — Other 45 5 18 — Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 297 — — — 013 Flanges 75 — — — Open-Ended Lines 583 — — — Pump Seals 1 — — — Valves 132 — — — Other 8 — — — 028 328.5 MMscf/yr 029 29.86 MMscf/yr,6 gallons per minute glycol circulation rate 031 5.9 MMscf/yr 032 5.9 MMscf/yr 033 5.9 MMscflyr 034 10,950 MMscf/yr 035 10,950 MMscf/yr 036 170.0 MMscf/yr • Basis for Permitted Emissions(Permit Limits) AIRS Process Consumption/Throughput/Production Point Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 1440 2067 2451 - 012 Flanges 403 166 375 — Open-Ended Lines 751 233 564 — Pump Seals 1 11 19 — Valves 481 272 756 — Other 45 5 18 — Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 297 — — — 013 Flanges 75 — — — Open-Ended Lines 583 — — — Pump Seals 1 — — — Valves 132 — — — Other 8 - - - 028 328.5 MMscf/yr 029 29.86 MMscf/yr,6 gallons per minute glycol circulation rate 031 5.9 MMscflyr 032 5.9 MMscf/yr 033 5.9 MMscf/yr 034 10,950 MMscflyr Page 4 035 10,950 MMscf/yr 036 170.0 MMscf/yr Does this source use a control X Yes No device? AIRS Point Process Control Device Description % Reduction Granted 88%gas valve; 76%light 012 01 LDAR per NSPS OOOO liq.Valve; 68%light liq. pump 88%gas valve; 76%light 013 01 LDAR per NSPS OOOO liq.Valve; 68%light liq. pump 028 01 Flare 95% 029 01 Combustor 95% 031,032, e1 NSCR and AFCR NOx: 79%; CO: 75% 033 034, 035 01 Thermal oxidizer 95% Section 6—Emission Summary (tons per year) Point NO. VOC CO H2S Single HAP Total HAP 012 - 150.6 — — 2.9 (Hexane) 3.9 013 - 46.4 - - - - 028 12.7 96.3 69.0 - - - 029 -- 6.5 — --- 1.9 (benzene) 2.2 0.1 031 6.7 0.7 11.2 -- (formaldehyde) 0.1 PTE: al 032 6.7 0.7 11.2 — (formaldehyde) 0.1 033 6.7 0.7 11.2 -- 0.1 0.1 (formaldehyde) 034 2.5 117.4 13.4 3.4 5.3 (benzene) 6.4 035 2.5 117.4 13.4 3.4 5.3 (benzene) 6.4 036 8.5 0.5 7:1 - - - 012 - 150.6 — — 2.9 (Hexane) 3.9 013 - 46.4 - - - - 028 12.7 96.3 69.0 -- - - 029 -- 6.5 — --- 1.9 (benzene) 2.2 0.1 Uncontrolled point 031 6.7 0.7 11.2 — (formaldehyde) 0.1 source emission 0.1 rate: 032 6.7 0.7 11.2 — (formaldehyde) 0.1 033 6.7 0.7 11.2 — (formaldehyde) 0.1 034 2.5 117.4 13.4 3.4 5.3 (benzene) 6.4 035 2.5 117.4 13.4 3.4 5.3 (benzene) 6.4 036 8.5 0.5 7.1 — — — Total(TPY) 46.3 537.2 136.5 6.8 12.5(benzene) 19.2 Page 5 012 - 85.8" - - 1.7(Hexane) 2.2 013 - 33.8" - - - - 028 12.7 4.8 69.0 - - - 029 -- 6.5 - - 1.9 (benzene) 2.2 0.1 Uncontrolled 031 1.4 0.7 2.8 - (formaldehyde) 0.1 pant source al emission rate: 032 1.4 0.7 2.8 - (formaldehyde) 0.1 033 1.4 0.7 2.8 - 0.1(formaldehyde) 0.1 034 2.5 1.5 13.4 0.2 0.3 (benzene) 0.3 035 2.5 1.5 13.4 0.2 0.3(benzene) 0.3 036 8.5 0.5 7.1 - - - Insigniflcants - 6.5 - - 0.06(n-hexane) 0.08 Total(TPY) 30.4 16.9 111.3 0.4 2.5(benzene) 5.3 ^Not included when determining facility status Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Amen Controlled Emission Pollutant CAS# BIN Emission Rate imams? Rate(lend (IW0 Point 012 Benzene 71432 A 913 Yes 516 Toluene 108883 C 674 Yes 381 Ethylbenzene 100414 C 90 No 51 Xylenes 1330207 C 183 No 96 n-Hexane 110543 C 5872 Yes 3320 Point 029 Benzene 71432 A 3707 Yes 185 Toluene 108883 C 526 • Yes 26 Ethylbenzene 100414 C 18 No 1 Xylenes 1330207 C 60 No 3 n-Hexane 110543 C 29 No 2 Points 031,032 and 033 each Formaldehyde 50000 A 124 No 124 Acetaldehyde 75070 A 17 No 17 Acrolein 107028 A 16 No 16 Benzene 71432 A 10 No 10 Point 034 Benzene 71432 A 10495 Yes 492 Toluene 108883 C 1467 Yes 69 Ethylbenzene 100414 C 40 No 2 Page 6 Xylenes 1330207 C 111 No 5 n-Hexane 110543 C 683 Yes 3 Point 035 Benzene 71432 A 10495 Yes 492 Toluene 108883 C 1467 Yes 69 Ethylbenzene 100414 C 40 No 2 Xylenes 1330207 C 111 No 5 n-Hexane 110543 C 683 Yes 3 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Extended gas 029 01 VOC Regulation No.3, Part B, Section III.E. analysis 029 01 VOC Regulation No. 3, Part B.,Section III.G.3 Stack test 031,033 032, 01 VOC, CO Regulation No.3, Part B., Section III.G.3 Stack test Extended sour gas 034, 035 01 VOC Regulation No.3, Part B,Section III.E. and sour liquids analysis Section 9—Source Classification Yes; No; Is this a new previously un-permitted source? X Points X Points 028-036 012-013 What is this facility classification? True Synthetic X Major Minor Minor Classification relates to what programs? X Tide V PSD NA NSR MACT Is this a modification to an existing permit? X Yes No synthetic If"yes"what kind of modification? Minor X Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? For Reg. 3, Part B, III.C.1.a(emissions increase> 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? X Yes No For Reg. 3, Part B, III.C.1.d(synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards(NAAQS)? If"yes',for which pollutants?Why? Page 7 AIRS Point Section 12—Regulatory Review _Reoulation 1 -Particulate. Smoke. Carbon Monoxide and Sulfur Dioxide Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant 012-013; which is in excess of 20%opacity.This standard is based on 24 consecutive opacity 028-036 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. Jteaulation 2—Odor Section IA-No person,wherever located, shall cause or allow the emission of odorous 012-013; air contaminants from any single source such as to result in detectable odors which are 028-036 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. _Regulation 3-APENs. Consbucfion Permits. Ooeratina Permits. PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants,Air Pollutant Emission Notices are required for. 012-013; each individual emission point in an attainment area with uncontrolled actual emissions of 028-036 two tons per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is attainment. (Applicant is required to file anAPEN since emissions exceed 2 tons per year VOC) 012-013; Part B-Construction Permit Exemptions 028-036 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility am greater than the 5.0 TPY threshold(Reg.3,Part El,Section II.D.3.a) Part B,IIl.D.2- RACT requirements for new or modified minor sources 012, 013 This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is not located in the 8-hour ozone nonattainment area. Since source is in attainment, RACT is not required. _Reculation 6-New Source Performance Standards NSPS 0000: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS 0000. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and 012, 013 sulfur dioxide(SO2)emissions from affected facilities that commence construction, modification or reconstruction after August 23,2011. Is this source at a"natural gas processing plant'?" Yes Is this source subject to NSPS 0000? Yes WHY?Facility meets the definition of a natural gas processing plant and commenced construction after August 23,2011. 028,029 None NSPS JJJJ: applies to stationary spark ignition internal combustion engines that commence construction after June 12,2006,where the engines are manufactured: On or after July 1, 2008 for engines with a maximum engine power less than 500HP. 031,032,033 Commencement/construction dates were not included with the application (I am assuming operator does not have the engines available yet for applicable dates). Operator will comply with the requirements of this subpart for all stationary sources that will meet the above criteria. NSPS 0000: Each sweetening (amine)unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after August 23, 2011. 034,035 Applicant is not subject to NSPS 0000 because this source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.5423(c) to keep for the life of the equipment an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. 036 NSPS Dc: This heater is subject to this subpart because this heater's design capacity is between 10-100 mmbtulhr and commenced construction after June 9, 1989. Page 8 Re ulation 7—Volatile Organic Compounds Section XII.G: If facility is a natural gas processing plant located in non-attainment 012, 013 area,then subject to Section XII.G. It is a natural gas processing plant, but not located in the non-attainment area. Therefore, not subject to this subpart. 028, 034, None 035, 036 Is this source subject to the control requirements of MACT HH? (Regulation 8-Hazardous Air Pollutants review). No Is this source subject to the exemptions under MACT HH (i.e. throughput exemption less 029 than 3 MMSCFD or benzene exemption of less than 1984 lb/yr)? Yes Even though this source is subject to some requirements of MACT HH, it is not subject to control requirements. Therefore, it can also be subject to Regulation 7 control requirements. Section XII.H: 029 Is this source located in the non-attainment area? No This source is not subject to this regulation. Section XVII.D(State only enforceable). 029 Applicant is not required to reduce VOC emissions from this dehydrator by at least 90% since uncontrolled VOC emissions are less than the 15.0 TPY threshold. 031,032, If the engines are not subject to NSPS JJJJ (i.e. manufacturer date prior to July 1, 2008) 033 then the engines shall be subject to Regulation 7, Section XVII.E. Regulation 8-Hazardous Air Pollutants MACT HH: If facility is MAJOR source for HAP at a natural gas processing plant ONLY(summation of HAPS of dehydrators and fugitives),then fugitive emissions are subject to MACT HH. 012, 013 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? Facility is considered area source for MACT HH; so only TEG dehydrators are subject to this subpart at this facility (at this time of review). 028, 034, None 035, 036 MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators and fugitives greater than 25 TPY total or 10 TPY single HAP),then all glycol dehydrators at this facility are subject to MACT HH. If facility is an area source of HAP, only TEG dehydrators are subject to MACT HH. 1.Is facility a production field facility per 63.761 (Refer to Section 14 for definition)? No 029 2.If facility is NOT a production field facility(i.e. natural gas processing plant), then is it a major source of HAPS when summing all HAP emissions from ALL HAP emitting units? No 3.Is this facility considered MAJOR for HAPS? No 4.Is this source subject to MACT HH?Yes 5.WHY? This facility is an area source of HAP. No area source requirements of HH apply to this EG or DEG dehydrator. 031, 032, MACT ZZZZ: applies to stationary reciprocating internal combustion engines at 033 major or area sources of HAP emissions. This facility is designated as an area source of HAPS. Therefore, these engines are subject to this subpart. Page 9 , Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Pollutant/ Fugitive Emission Factor Control CAS# (Y/N) Source (%) 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, 43.0% 012 Emissions Table 2-4 ' SCC 31000220: All Equip. Leak Fugitives(Valves,flanges, connections, seals,drains) Fugitive VOC Leak EPA-4531R-95-017, O7 Emissions VOC Yes Table 2-4 27.2% 013 SCC 31000220: All Equip. Leak Fugitives(Valves,flanges, connections,seals,drains) Engineering 621.0 Ib621.0 VOC No Calculation 95 (previous permit) 01 Emergency Rare 0.068 NOx No AP-42, NA 028 lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA lb/MMBtu Table 13.5-1 SCC 31000205-Flares 1.190 VOC No Promax 0 Ibs/mmsd 0.3401 Benzene/ No Promax 0 Ibs/mmsd 71432 0.0483 Toluene/ Glycol MMSCF lbs/mmscf 108883 029 Dehydrator No Promax 0 01 per 0.0016 Ethylbenzene No Promax 0 Ibs/mmsd /100414 0.0055 Xylenes/ No Promax 0 Ibs/mmsd 1330207 0.0026 n-Hexane/ No Promax 0 Ibs/mmsd 110543 SCC 31000304-Glycol Dehydrators: Ethylene glycol: general 0.231 VOC No AP-42 0 lbs/mmbtu /Manufacturer 031, 01 RICE 5.9 MMSCF 2.21 NOx No AP-42 79 032, per year lbs/mmbtu Manufacturer 033 3.72 CO No AP-42 75 each lbs/mmbtu Manufacturer SCC 20200253 4-cycle rich burn Page 10 21.4429 VOC No Promax 95 Ibs/mmscf 0.9584 Benzene/ No Promax 95 Ibs/mmscf 71432 0.1340 Toluene/ No Promax 95 01 Amine Unit Ibs/mmscf 108883 034 0.0036 Ethylbenzene/ No Promax 95 Ibs/mmscf 100414 0.0101 Xylenes/ No Promax 95 Ibs/mmscf 1330207 0.0624 n-Hexane I No Promax 95 Ibs/mmscf 110543 SCC 31000305—Gas Sweetening; Amine process 21.4429 VOC No Promax 95 lbs/mmscf 0.9584 Benzene/ No Promax 95 lbs/mmscf 71432 0.1340 Toluene/ No Promax 95 01 Amine Unit Ibs/mmscf 108883 035 0.0036 Ethylbenzene/ No Promax 95 Ibs/mmscf 100414 0.0101 Xylenes/ No Promax 95 Ibs/mmscf 1330207 0.0624 n-Hexane/ No Promax 95 Ibs/mmscf . 110543 SCC 31000305—Gas Sweetening; Amine process 100 NOx No AP-42 NA 170.0 lbs/mmscf Hot oil5 01 Myc ar lbs/mmscf per5 VOC No AP-42 NA 036 heater Ibs/mmscf 84 CO No AP-42 NA SCC 31000404-Natural Gas Process heaters Section 14—Miscellaneous Application Notes AIRS Point 012 Fugitive VOC Leak Emissions A permit modification will be issued. With the permit starting with a 10-number, I was confused why Issuance 3 showed the fugitives subject to NSPS OOOO and not NSPS KKK. Andrew Parisi with Summit explained this for me on 8/5/14: The entire facility was built after August 23, 2011, so the whole station falls under NSPS OOOO. I'm not sure why the original issuance had NSPS KKK in it, but Peter Armington corrected that issue by putting the correct NSPS rule into the construction permit. The only thing I can think is that since the original air permit was processed . before the Division adopted NSPS OOOO, they put KKK into the permit. I've attached a copy of the notice of startup for the Hereford Plant.As you can see the facility started up at the end of August 2013, and the facility construction began back in March 2013, which is well after the 08/23/2011. So no splitting out will be necessary. I had a few more questions regarding Point 012. I emailed the operator/consultant on 8/5/14: 1. Is there a gas/liquids analysis for the fugitives?I did not see one in the application.Also I think Point 012 is showing a 300%(not 200%) on the APEN. Does Meadowlark want 300%or 200%(200%is reflected on the calculation sheet, but the emissions I am getting is consistent with 300%). I also calculated controlled e- benzene to be 50.61 lb/yr and xylenes 96.06 lb/yr. Point 012 also has uncontrolled HAP emissions. I calculated 913 lb/yr benzene, 674 lb/yr toluene, 90 lb/yr e-benzene, 183 lb/yr xylenes and 5872 lb/yr n- hexane. This will change the emissions listed on the APEN. I can redline the APEN if you agree. The gasfiquids analyses are attached. It is buffered at 300%in the calcs. The 250%note is incorrect. Page 11 AIRS Point 013 Fugitive VOC Leak Emissions A permit modification will be issued. With the permit starting with a 10-number, I was confused why Issuance 3 showed the fugitives subject to NSPS 0000 and not NSPS KKIC Andrew Parisi with Summit explained this for me on 8/5/14: The entire facility was built after August 23, 2011,so the whole station falls under NSPS 0000. I'm not sure why the original issuance had NSPS KKK in it, but Peter Armington corrected that issue by putting the correct NSPS rule into the construction permit. The only thing I can think is that since the original air permit was processed before the Division adopted NSPS 0000, they put KKK into the permit. I've attached a copy of the notice of startup for the Hereford Plant.As you can seethe facility started up at the end of August 2013, and the facility construction began back in March 2013, which is well after the 0823/2011. So no splitting out will be necessary. I had a few more questions regarding Point 013. I emailed the operator/consultant on 8/5/14 and he responded 8/6/14: 1. Is there a gas analysis for the fugitives-propane?I did not see one in the application.Also I think Point 013 is showing a 250%(not 150%)on the APEN. Does Meadowlark want 250%or 150%(150%is reflected on the calculation sheet, but the emissions I am getting is consistent with 250%). I don't have a propane analysis, but one shouldn't be needed since this propane system is 100%propane. To be conservative we assumed 100% VOC. It is buffered at 250%in the cafes. The 150%note is incorrect. It is all propane and is in a closed-loop system. It's basically used to chill things down(part of the chiller skid). AIRS Point 028 Flare A permit will be issued because uncontrolled VOC emissions are greater than 5 TPY(and greater than 10 TPY NOx and CO for the source individually). NOx and CO emissions were calculated using the emission factors in AP-42,Table 13.5-1: NOx= 10.068 lb 142.54 mmbtu 88760 hr 760 lb = 12.67 TPY mmbtu hr • CO= I 0.37 lb mmbtu 142.54 mmbtu 1 8760 hr 8760 lb =68.94 TPY I had a few more questions regarding Point 028: 1. Is the emergency flare enclosed? How was the VOC emission factor calculated? Pm pretty sure the em. flare is not enclosed correct? VOC emission factor was taken from the permitted value for the existing flare onsite(AIRS 1D 011) VOC emissions were generated from using a previously approved emission factor for an emergency flare already permitted onsite(which will be cancelled after the commencement of Point 028). Page 12 AIRS Point 029 Glycol Dehydrator A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY(permit threshold). The throughput was provided on the APEN in gallons/min. I converted it to mmscf/yr: 425 gal 525600 min 0.13368055556 ft' 29.86 MMscf/yr min I yr 1 gal 1000000 Emissions were calculated using a Promax model. Uncontrolled emissions and their associated emission factors are: VOC=((6.4828)'2000)/(29.86"365)= 1.190 lb/mmscf Benzene=(0.42313'8760)/(29.86"365)=0.3401 lb/mmscf Toluene=(0.0600849"8760)/(29.86'365)=0.0483 lb/mmscf Ethylbenzene=(0.00200904`8760)/(29.86'365) =0.0016 lb/mmscf Xylenes=(0.00688471"8760)/(29.86"365)=0.0055 lb/mmscf N-hexane=(0.00327919'6760)/(29.86'365)=0.0026 lb/mmscf MACT HH indudes requirements for both major and area sources of HAPs. The definition of major source for MACT HH(63.761)states: (3) For facilities that are production field facilities, only HAP emissions from glycol dehydration units and storage vessels with the potential for flash emissions shall be aggregated for a major source determination. For facilities that are not production field facilities, HAP emissions from all HAP emission units shall be aggregated for a major source determination. The following definitions from 63.761 are also needed to determine major source applicability: Production field facilities means those facilities located prior to the point of custody transfer Custody transfer means the transfer of hydrocarbon liquids or natural gas: after processing and/or treatment in the producing operations,or from storage vessels or automatic transfer facilities or other such equipment, induding product loading racks,to pipelines or any other forms of transportation. For the purposes of this subpart,the point at which such liquids or natural gas enters a natural gas processing plant is a point of custody transfer. Natural gas processing plant(gas plant)means any processing site engaged in the extraction of natural gas liquids from field gas, or the fractionation of mixed NGL to natural gas products, or a combination of both. Based on the definitions above,this source qualifies as natural gas processing plant Does this deh)drator have a reboiler?Yes AIRS Point 031 4SRB Engine A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). AIRS Point 032 4SRB Engine A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). AIRS Point 033 4SRB Engine A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). Page 13 AIRS Point 034 Amine Unit Amine unit has 2 contactor towers(one for gas and one for liquid). That's why on the APEN under the Lean Amine Stream section there are 2 numbers(the first number is for gas,the second number is for liquid). The table below summarizes the inputs to the process simulation used to calculate the PTE for this equipment TABLE 1 Parameter Pressure Temperature(F) Flowrate Inlet Gas 896 psig 77 - Rich Amine feed 18 psia 211 - Lean amine stream(gas) 888 psia 114 150 gal/min Lean amine stream (NGL) 288 psia 111 50 gal/min Sour gas input 890 psia 92 30 mmscf/day NGL input 326 psia 80 270 gaUmin Flash tank 74 psia 128 - Uncontrolled emission factor calculations using Promax VOC=(117.4'2000)/10950 mmsd/yr)=21.4429 lb/mmscf Benzene=(5.2474'2000)/10950=0.9584 lb/mmscf Toluene=(0.7334'2000)/10950=0.1340 lb/mmsd Ethylbenzene=(0.0199'2000)/10950=0.0036 lb/mmscf Xylenes=(0.0ar5'2000)/10950=0.0101 lb/mmsd n-hexane=(0.3414'2000)/10950=0.0624 lb/mmscf Does this amine unit have a reboiler?No I emailed the operator/consultant on 8/8/14: • Should there be two dfferent throughput limits for the amine units(one for gas the other for liquids)? APEN just shows 10,950 mmscf/yr.If we need to have both gas ad throughput finks since them are two different towed the liquid NGL throughput is 270 gpm,or 3,378 860 bbis/yr. This throughput is the NGL throughput for each amine unit from the Promax run. The 270 gpm is listed under the'NGL Feed'stream on the output report properties. AIRS Point 035 Amine Unit Amine unit has 2 contactor towers(one for gas and one for liquid). That's why on the APEN under the Lean Amine Stream section there are 2 numbers(the first number is for gas,the second number is for liquid). The table below summarizes the inputs to the process simulation used to calculate the PTE for this equipment TABLE 1 Parameter Pressure Temperature(F) Fiowrate Inlet Gas 896 psig 77 - Rich Amine feed 18 psis 211 - Lean amine stream (gas) 888 psia 114 150 gal/min Lean amine stream (NGL) 288 psia 111 50 gal/min Sour gas input 890 psia 92 30 mmscf/day NGL input 326 psia 80 270 qal/min Flash tank 74 psia 128 - Uncontrolled emission factor calculations using Promax VOC=(117.4'2000)/10950 mmsdiyr)=21.4429 lb/mmsd Benzene=(5.2474'2000)/10950=0.9584 lb/mmsd Toluene=(0.7334'2000)/10950=0.1340 lb/mmscf Ethylbenzene=(0.0199'2000)/10950=0.0036 lb/mmscf Xylenes=(0.0555'2000)/10950=0.0101 lb/mmsd n-hexane=(0.3414'2000)/10950=O.0624 lb/mmsd Does this amine unit have a reboller?No I emailed the operator/consultant on 8/8/14: Should there be two different throughput limits for the amine units(one for gas the other for liquids)? APEN just shows 10,950 mmsd/yr. If we need to have both gas ad throughput limits since there are two different towers,the liquid NGL throughput is 270 gpm,or a378,860 bbisyr. This throughput is the NGL throughput for each amine unit from the Promax run. The 270 gpm is listed under the'NGL Feed'stream on the output report properties. AIRS Point 036 Hot oil heater A permit will be issued because the uncontrolled CO emissions are greater than 2 WY(APEN threshold)and the total uncontrolled facility CO emissions are over 10 TPY(permit threshold). Page 14 / \ _ 0 2N / .C \ = T. m ❑ O e W 0.e ! / rn y a Ci y 1�— f/ _ w o %p O O. C>. Q 9 U \ t l rn O O O 0� •y v m C ore, 0 0 a E; YC u L T N c C E C o — .E GOY 0 t°E 2" ? R a yl L c '° a .. 0 E .2 , a fa N Coi olI z : c o v. ono = y r R ,'^ C ny W v. N V go E w E ° - °' > > m e n r C. o o. a o a N Q o Y m `m u .Lc. 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