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Home My WebLink About20152011.tiff cgpH COLORADO? co Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St ED PO Box 758 RECEIV Greeley, CO 80632 JUL 0 7 2015 July 1, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On July 8, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - Palomino Processing Facility. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, 1 Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 2015-2011 ` 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe :• c`, John W. Hickenlooper,Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer * , CDPHE Air Pollution Control Division CoNotice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - Palomino Processing Facility - Weld County Notice Period Begins: July 8, 2015 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy, Inc. Facility: Palomino Processing Facility Oil processing, storage and blending facility SW Section 28, T3N, R65W Weld County The proposed project or activity is as follows: Oil processing, storage and blending facility including heater treaters (3), condensate tanks, produced water tanks, venting flare, truck loadout and associated fugitive emissions. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 15WE0017 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-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 I hi:t eis COLOR ApO e 3 A 11 § STATE OF COLORADO ' 0�1 • �9 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION " TELEPHONE: (303)692-3150 \ *� `1876 CONSTRUCTION PERMIT PERMIT NO: 1 5WEOo1 7 Issuance 1 DATE ISSUED: ISSUED TO: Noble Energy, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Palomino Processing Facility, located in the SW of Section 28, Township 3 North, Range 65 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID HTR RB1 001 Up to one (1) 27.3 MMBtu/hr heater treater. This unit only burns natural gas. Emissions from this point are not controlled. HTR RB2 002 Up to one (1) 27.3 MMBtu/hr heater treater. This unit only burns natural gas. Emissions from this point are not controlled. HTR RB3 003 Up to one (1) 27.3 MMBtu/hr heater treater. This unit only burns natural gas. Emissions from this point are not controlled. Up to five (5) above ground up to 250,000 bbl atmospheric condensate storage tanks. The condensate entering the tanks will TK CND 004 come from a stabilizer system that ensures there are no flash emissions entering the tanks. Emissions are based on working and breathing emissions only. All tanks shall have internal floating roofs. Emissions from these tanks are not controlled. Up to three (3) above ground up to 40,000 bbl atmospheric TK PW 005 produced water storage tanks. The emissions are based on working and breathing emissions only assuming the contents are oil. These tanks shall have internal floating roofs. FUG 006 Equipment leaks (fugitive VOCs) from an oil and gas facility. MMS 007 One (1) maintenance vent. The vent will only operate during emergency/blowdown situations. Truck loadout of condensate. Emissions from the loadout are TL 008 controlled by a combustion device (combustor or flare). Truck loadout. The primary method of loadout is planned to be pipeline with truck loadout as a backup. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND AIRS ID: 123/9D6D Page 1 of 19 Condensate Tank SM/M Version 2012-1 Color Depa e df •bli Health and Environment it Pollution Control Division CONTROL ACT C.R.S. et.: _� + E = TERM „_� • CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION , 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, l 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) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i)does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii)discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. Points 001, 002 and 003: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification,with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility AIRS Pounds per Month Emission Type AIRS ID: 123/9D6D Page 2 of 19 PI V---- II :,:„Color.;4:.A Depa ' e f bli Health and Environment { it Pollution Control Division Equipment I , 'int , - O HTR RB1 001 1988 --- 1665 Point HTR RB2 002 1988 --- 1665 Point HTR RB3 003 1988 --- 1665 Point TK CND 004 --- 9343 --- Point TK PW 005 --- 1699 --- Point FUG 006 --- 340 --- Fugitive MMS 007 --- 1699 --- Point TL 008 --- 1699 --- Point (Note: Monthly limits are based on a 31-day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO HTR RB1 001 11.7 --- 9.8 Point HTR RB2 002 11.7 --- 9.8 Point HTR RB3 003 11.7 --- 9.8 Point TK CND 004 --- 55.0 --- Point TK PW 005 --- 10.0 --- Point FUG 006 --- 2.0 --- Fugitive MMS 007 --- 10.0 --- Point TL 008 --- 10.0 --- Point See "Notes to Permit Holder"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 annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. AIRS ID: 123/9D6D Page 3 of 19 pColor ,. Depa e 4f �bli Health and Environment A _ it Pollution Control Division 8. The emission ' . th-th- •le „' .x sh I . �ated aintained 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 TK CND 004 Internal floating roof VOC and HAPS TK PW 005 Internal floating roof VOC and HAPS FUG 006 LDAR Program VOC and HAPS TL 008 Combustor/flare VOC and HAPS 9. Point 006: 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. PROCESS LIMITATIONS AND RECORDS 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Annual Monthly Limit Equipment Point Process Parameter Limit (31 days) ID HTR RB1 001 Combustion of natural gas as a fuel 122.7 10.4 MMscf/yr MMscf/month HTR RB2 002 Combustion of natural gas as a fuel 122.7 10.4 MMscf/yr MMscf/month HTR RB3 003 Combustion of natural gas as a fuel 122.7 10.4 MMscf/yr MMscf/month TK CND 004 Condensate throughput 73,000,00 6,200,000 0 BBL/yr BBL/month TK PW 005 Produced water throughput 18,250,00 1,550,000 0 BBL/yr BBL/month MMS 007 Natural gas venting 0.175 0.015 MMSCF/yr MMSCF/month TL 008 Condensate loading 1,825,000 155,000 BBL/yr BBL/month The owner or operator shall calculate monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. AIRS ID: 123/9D6D Page 4 of 19 11''1ColorADepa - afbiHealth and Environment it Pollution Control Division Compliance w' n ro li 'q e det ed on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months'data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 12. Visible emissions shall not exceed twenty percent(20%)opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 13. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 14. Points 001, 002 and 003: These sources are 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 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. AIRS ID: 123/9D6D Page 5 of 19 I Color s Depa , e .f bli ' Environment it PollutionHealthand Control Division ‘‘ 15, Point 004: T ,I_ - . - re ` ; g, m• Ong, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 16. Points 004 and 005: This source covered under AIRS points 004 and 005 are subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) for which Construction, Reconstruction, or Modification Commenced after July 23, 1984 including, but not limited to, the following: • 40 CFR, Part 60, Subpart A—General Provisions • §60.112b-Standard for volatile organic compounds (VOC) • §60.112b(a) The owner or operator of each storage vessel either with a design capacity greater than or equal to 151 m3 containing a VOL that, as stored, has a maximum true vapor pressure equal to or greater than 5.2 kPa but less than 76.6 kPa...shall equip each storage vessel with one of the following: • §60.112b(a)(1) A fixed roof in combination with an internal floating roof meeting the following specifications: • §60.112b(a)(1)(i)The internal floating roof shall rest or float on the liquid surface (but not necessarily in complete contact with it) inside a storage vessel that has a fixed roof. The internal floating roof shall be floating on the liquid surface at all times, except during initial fill and during those intervals when the storage vessel is completely emptied or subsequently emptied and refilled. When the roof is resting on the leg supports, the process of filling, emptying, or refilling shall be continuous and shall be accomplished as rapidly as possible. • §60.112b(a)(1)(ii) Each internal floating roof shall be equipped with one of the following closure devices between the wall of the storage vessel and the edge of the internal floating roof: • (A) A foam-or liquid-filled seal mounted in contact with the liquid (liquid-mounted seal). A liquid-mounted seal means a foam- or liquid-filled seal mounted in contact with the liquid between the wall of the storage vessel and the floating roof continuously around the circumference of the tank. • (B) Two seals mounted one above the other so that each forms a continuous closure that completely covers the space between the wall of the storage vessel and the edge of the internal floating roof. The lower seal may be vapor-mounted, but both must be continuous. • (C)A mechanical shoe seal. A mechanical shoe seal is a metal sheet held vertically against the wall of the storage vessel by springs or weighted levers and is connected by braces to the floating roof. A flexible coated fabric (envelope) spans the annular space between the metal sheet and the floating roof. • §60.112b(a)(1)(iv) Each opening in the internal floating roof except for leg sleeves, automatic bleeder vents, rim space vents, column wells, AIRS ID: 123/9D6D Page 6 of 19 *Colorg, Depa. ne f _bli Health and Environment A it Pollution Control Division er we + a .ub dr •- • to be equipped with a cover or lid which is to be maintained in a closed position at all times (i.e., no visible gap) except when the device is in actual use. The cover or lid shall be equipped with a gasket. Covers on each access hatch and automatic gauge float well shall be bolted except when they are in use. • §60.112b(a)(1)(v) Automatic bleeder vents shall be equipped with a gasket and are to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports. • §60.112b(a)(1)(vi) Rim space vents shall be equipped with a gasket and are to be set to open only when the internal floating roof is not floating or at the manufacturer's recommended setting. • §60.112b(a)(1)(vii) Each penetration of the internal floating roof for the purpose of sampling shall be a sample well. The sample well shall have a slit fabric cover that covers at least 90 percent of the opening. • §60.112b(a)(1)(viii) Each penetration of the internal floating roof that allows for passage of a column supporting the fixed roof shall have a flexible fabric sleeve seal or a gasketed sliding cover. • §60.112b(a)(1)(ix) Each penetration of the internal floating roof that allows for passage of a ladder shall have a gasketed sliding cover. • §60.113b—Testing and procedures • The owner or operator of each storage vessel as specified in §60.112b(a) shall keep records and furnish reports as required by paragraphs (a), (b), or(c)of this section depending upon the control equipment installed to meet the requirements of§60.112b. The owner or operator shall keep copies of all reports and records required by this section, except for the record required by (c)(1), for at least 2 years. The record required by (c)(1) will be kept for the life of the control equipment. • §60.113b(a)(1)Visually inspect the internal floating roof,the primary seal,and the secondary seal (if one is in service), prior to filling the storage vessel with VOL. If there are holes, tears, or other openings in the primary seal,the secondary seal, or the seal fabric or defects in the internal floating roof, or both, the owner or operator shall repair the items before filling the storage vessel. ▪ §60.113b(a)(2) and (3) If the roof is equipped with a liquid mounted or mechanical shoe primary seal or a double seal system then the testing will follow the procedures outlined in §60.113b(a)(2) or (3), respectively. • §60.113b(a)(4) Visually inspect the internal floating roof, the primary seal, the secondary seal (if one is in service), gaskets, slotted membranes and sleeve seals (if any) each time the storage vessel is emptied and degassed. If the internal floating roof has defects, the primary seal has holes, tears, or other openings in the seal or the seal fabric, or the secondary seal has holes, tears, or other openings in the seal or the seal fabric, or the gaskets no longer close off the liquid surfaces from the atmosphere, or the slotted membrane has AIRS ID: 123/9D6D Page 7 of 19 y C� � olor :yam ,. Depa�� e ' af bli� Health and Environment Ir.Pollution Control Division m• 0 • -n -re •- • •er or •• ` -tor shall repair the items as necessary so that none of the conditions specified in this paragraph exist before refilling the storage vessel with VOL. In no event shall inspections conducted in accordance with this provision occur at intervals greater than 10 years in the case of vessels conducting the annual visual inspection as specified in paragraphs (a)(2) and (a)(3)(ii) of this section and at intervals no greater than 5 years in the case of vessels specified in paragraph (a)(3)(i) of this section. • §60.113b(a)(5) Notify the Administrator in writing at least 30 days prior to the filling or refilling of each storage vessel for which an inspection is required by paragraphs (a)(1) and (a)(4) of this section to afford the Administrator the opportunity to have an observer present. If the inspection required by paragraph (a)(4) of this section is not planned and the owner or operator could not have known about the inspection 30 days in advance or refilling the tank, the owner or operator shall notify the Administrator at least 7 days prior to the refilling of the storage vessel. Notification shall be made by telephone immediately followed by written documentation demonstrating why the inspection was unplanned. Alternatively, this notification including the written documentation may be made in writing and sent by express mail so that it is received by the Administrator at least 7 days prior to the refilling. • §60.115b— Reporting and recordkeeping requirements • §60.115b(a)After installing control equipment in accordance with§60.112b(a)(1) (fixed roof and internal floating roof), the owner or operator shall meet the following requirements. • §60.115b(a) (1) Furnish the Administrator with a report that describes the control equipment and certifies that the control equipment meets the specifications of§60.112b(a)(1) and §60.113b(a)(1). This report shall be an attachment to the notification required by§60.7(a)(3). • §60.115b(a) (2) Keep a record of each inspection performed as required by §60.113b (a)(1), (a)(2), (a)(3), and (a)(4). Each record shall identify the storage vessel on which the inspection was performed and shall contain the date the vessel was inspected and the observed condition of each component of the control equipment (seals, internal floating roof, and fittings). • §60.115b(a) (3) If any of the conditions described in §60.113b(a)(2) are detected during the annual visual inspection required by §60.113b(a)(2), a report shall be furnished to the Administrator within 30 days of the inspection. Each report shall identify the storage vessel, the nature of the defects, and the date the storage vessel was emptied or the nature of and date the repair was made. • §60.115b(a) (4)After each inspection required by§60.113b(a)(3) that finds holes or tears in the seal or seal fabric, or defects in the internal floating roof, or other control equipment defects listed in §60.113b(a)(3)(ii), a report shall be furnished to the Administrator within 30 days of the inspection. The report shall identify the storage vessel and the reason it did not meet the specifications of§61.112b(a)(1) or§60.113b(a)(3) and list each repair made. • §60.116b— Monitoring of operations AIRS ID: 123/9D6D Page 8 of 19 . �1 s�� 3 � as Color %F; Depa er! liPHealth�f and Environment i74 fit Pollution Control Division 1,4 ▪ §6 T AfsLkeep m s of all records required by this section, except for the record required by paragraph (b)of this section, for at least 2 years. The record required by paragraph (b)of this section will be kept for the life of the source. ▪ §60.116b(b) The owner or operator of each storage vessel as specified in §60.110b(a) shall keep readily accessible records showing the dimension of the storage vessel and an analysis showing the capacity of the storage vessel. • §60.116b (c) Except as provided in paragraphs (f) and (g) of this section, the owner or operator of each storage vessel either with a design capacity greater than or equal to 151 m3 storing a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa or with a design capacity greater than or equal to 75 m3 but less than 151 m3 storing a liquid with a maximum true vapor pressure greater than or equal to 15.0 kPa shall maintain a record of the VOL stored, the period of storage, and the maximum true vapor pressure of that VOL during the respective storage period. • §60.116b (d) Except as provided in paragraph (g) of this section, the owner or operator of each storage vessel either with a design capacity greater than or equal to 151 m3 storing a liquid with a maximum true vapor pressure that is normally less than 5.2 kPa or with a design capacity greater than or equal to 75 m3 but less than 151 m3 storing a liquid with a maximum true vapor pressure that is normally less than 27.6 kPa shall notify the Administrator within 30 days when the maximum true vapor pressure of the liquid exceeds the respective maximum true vapor vapor pressure values for each volume range. ▪ §60.116b(e) Available data on the storage temperature may be used to determine the maximum true vapor pressure as determined below. • §60.116b(e) (2) For crude oil or refined petroleum products the vapor pressure may be obtained by the following: ■ §60.116b(e) (2) (i) Available data on the Reid vapor pressure and the maximum expected storage temperature based on the highest expected calendar-month average temperature of the stored product may be used to determine the maximum true vapor pressure from nomographs contained in API Bulletin 2517 (incorporated by reference—see §60.17), unless the Administrator specifically requests that the liquid be sampled, the actual storage temperature determined, and the Reid vapor pressure determined from the sample(s). • §60.116b(e) (2) (ii) The true vapor pressure of each type of crude oil with a Reid vapor pressure less than 13.8 kPa or with physical properties that preclude determination by the recommended method is to be determined from available data and recorded if the estimated maximum true vapor pressure is greater than 3.5 kPa. In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply. AIRS ID: 123/9D6D Page 9 of 19 Color.=; Depa e f a=bli Health and Environment it Pollution Control Division a. At all ti di. n to ,.own,, ;�, alfunction,the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 b. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (§ 60.12) c. Written notification of construction and initial startup dates shall be submitted to the Division as required under§ 60.7. d. Records of startups, shutdowns, and malfunctions shall be maintained, as required under§ 60.7. e. Written notification of opacity observation or monitor demonstrations shall be submitted to the Division as required under§ 60.7. f. Excess Emission and Monitoring System Performance Reports shall be submitted as required under§ 60.7. g. Performance tests shall be conducted as required under§ 60.8. h. Compliance with opacity standards shall be demonstrated according to § 60.11. 17. Point 006: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 18. Point 006: Fugitive component leaks at this well production facility are subject to the Leak Detection and Repair(LDAR) program requirements, including but not limited to: monitoring, repair, re-monitoring, recordkeeping and reporting contained in Regulation 7,Section XVII.F. In addition,the operator shall comply with the General Provisions contained in Regulation 7, Section XVII.B.1. 19. Point 006: The owner or operator shall follow the Leak Detection and Repair (LDAR) program per Regulation 7, Section XVII.F as approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your DI&M plan are subject to Division approval. 20. Point 008: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology(RACT)requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 21. Point 008: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): AIRS ID: 123/9D6D Page 10 of 19 Color^a Depa' en ifbli Health and Environment �� A it Pollution Control Division a. Hoses a.._ Ins, �a .v al ained, `' event dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 21 (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 22. Point 008: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. OPERATING & MAINTENANCE REQUIREMENTS 23. Point 008: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance(O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) 24. Point 008: Flare shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare, or by other convenient means approved by the Division, determine whether the flare is operating properly. 25. Point 008: The owner or operator of a loadout to control emissions shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. g. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING AIRS ID: 123/9D6D Page 11 of 19 Colors t, Depa e f '` bli 'Health and Environment it Pollution Control Division Initial Testin• _ m, 26. Point 006: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC)and hazardous air pollutants (HAP)that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 27. Point 006: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit,the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service"and"gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 28. Point 007: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site in order to verify the VOC, benzene,toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site- specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. Periodic Testing Requirements 29. Point 006: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds(VOC)and hazardous air pollutants(HAP)that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 30. Point 007: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the vent in order to verify the VOC content(weight fraction)of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. ADDITIONAL REQUIREMENTS 31. A revised Air Pollutant Emission Notice(APEN)shall be filed: (Reference: Regulation No.3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO„) in ozone nonattainment areas emitting less than 100 tons of VOC or NO.per year,a change AIRS ID: 123/9D6D Page 12 of 19 ;Color. Depa e 4.1 bli Health and Environment it Pollution Control Division in annu „ erY n' (1. :,,year or or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5)tons per year, 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. 32. Federal regulatory program requirements (i.e. PSD, NANSR)shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Parts C and D). GENERAL TERMS AND CONDITIONS 33. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 34. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide"final"authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation 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. 35. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 36. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. AIRS ID: 123/9D6D Page 13 of 19 Color,4 Depa e df ' bli Health and Environment it Pollution Control Division 37. Each and eve. •n •w ••,,is - fl.- part h •• and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 38. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 39. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal 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 Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. Newly permitted heater treaters (3), condensate tanks, produced water tanks, venting flare, truck loadout and associated fugitive emissions. New synthetic minor facility. AIRS ID: 123/9D6D Page 14 of 19 * ' . ;Color_b 4 Depa?mnert f °'IlDlie Health and Environment av it Pollution Control Division a, V Notes to Permit Holder gtitl't ° a of s per andel: 41 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 maybe revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions.The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.qov/pacific/cdphe/accc-reqs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (Ib/yr) reportable? Rate(Ib/yr) Benzene 71432 A 990 Yes 990 Toluene 108883 C 1428 Yes 1428 Ethylbenzene 100414 C 114 No 114 004 Xylenes 1130207 C 552 Yes 552 n-Hexane 110543 C 1752 Yes 1752 2,2,4-TMP 540841 C 114 No 114 Benzene 71432 A 166 No 166 Toluene 108883 C 237 No 237 Ethylbenzene 100414 C 18 No 18 005 Xylenes 1130207 C 88 No 88 n-Hexane 110543 C 289 Yes 289 2,2,4-TMP 540841 C 18 No 18 Benzene 71432 A 41 No 41 Toluene 108883 C 41 No 41 006 Ethylbenzene 100414 C 5 No 5 Xylenes 1130207 C 39 No 39 n-Hexane 110543 C 89 No 89 AIRS ID: 123/9D6D Page 15 of 19 Color- 4 Depa e df '" bli Health and Environment •it Pollution Control Division Benzen - x < 40 No 40 Toluene 108883 C 40 No 40 007 Ethylbenzene 100414 C 20 No 20 Xylenes 1130207 C 20 No 20 n-Hexane 110543 C 199 No 199 Benzene 71432 A 3285 Yes 164 Toluene 108883 C 4745 Yes 237 Ethylbenzene 100414 C 365 Yes 18 008 Xylenes 1130207 C 1825 Yes 91 n-Hexane 110543 C 5840 Yes 292 2,2,4-TMP 540841 C 365 Yes 18 5) The emission levels contained in this permit are based on the following emission factors: Points 001,002 and 003: Emission Factors CAS# Pollutant Uncontrolled Source Ib/MMSC F NOx 100 AP-42,Table 1.4-1 CO 84 AP-42, Table 1.4-1 Point 004: Emission Factors Uncontrolled CAS# Pollutant lb/1000 gal Source Condensate Throughput VOC 0.0357 EPA Tanks 71432 Benzene 0.0003 Engineering Calculation 108883 Toluene 0.0005 Engineering Calculation 100414 Ethylbenzene 0.00004 Engineering Calculation 1330207 Xylene 0.0002 Engineering Calculation 110543 n-Hexane 0.0006 Engineering Calculation 540841 2,2,4-TMP 0.00004 Engineering Calculation Point 005: Emission Factors Uncontrolled CAS# Pollutant lb/1000 gal Source Produced Water Throughput VOC 0.0236 EPA Tanks 71432 Benzene 0.0002 Engineering Calculation 108883 Toluene 0.0003 Engineering Calculation 100414 Ethylbenzene 0.00002 Engineering Calculation AIRS ID: 123/9D6D Page 16 of 19 ‘: Color Depa erg f °bli Health and Environment � . "' it Pollution Control Division r actglthem ,,m Uncontrolled CAS# Pollutant lb/1000 gal Source Produced Water Throughput 1330207 Xylene 0.0001 Engineering Calculation 110543 n-Hexane 0.0004 Engineering Calculation 540841 2,2,4-TMP 0.00002 Engineering Calculation Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 600 0 800 500 Flanges 2500 0 3300 1500 Open-ended Lines 20 0 20 20 Pump Seals 10 0 20 10 Valves 1100 0 1500 600 Other* 100 0 100 100 VOC Content(wt. 0.85 1 1 0.01 fraction) Benzene Content(wt. 0.002 0 0.03 0.0003 fraction) Toluene Content(wt. 0.002 0 0.03 0.0003 fraction) Ethylbenzene (wt. 0.001 0 0.003 0 fraction) Xylenes Content(wt. 0.001 0 0.03 0.0003 fraction) n-hexane Content(wt. 0.01 0 0.06 0.0006 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 ervi S 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 Note that the emission limits included in this permit are derived by multiplying the equipment counts in the table above by a factor of 1.73 to accommodate other minor changes to the facility and to provide a conservative estimate of facility-wide emissions. AIRS ID: 123/9D6D Page 17 of 19 rya:, � II Color4 Depa e ,f -bli •Health and Environment L it Pollution Control Division Compliance with e it ,u9 •pis ••; ill • "•-" trated ILing the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. Point 007: Emission Factors CAS# Pollutant Uncontrolled Source VOC 96685.71 lb/mmscf Engineering Calculation 71432 Benzene 228.5714 lb/mmscf Engineering Calculation 108883 Toluene 228.5714 lb/mmscf Engineering Calculation 100414 Ethylbenzene 114.2857 lb/mmscf Engineering Calculation 1330207 Xylenes 114.285 lb/mmscf 7 Engineering Calculation 110543 n-hexane 1137.1429 lb/mmscf Engineering Calculation Point 008: Emission Factors - Emission Factors -Controlled Uncontrolled CAS Pollutant lb/1000 gal Source Lb/1000 Source loaded gal loaded VOC 4.76 AP-42 0.238 AP-42 71432 Benzene 0.0429 Engineering 0.0021 Engineering Calculation Calculation 108883 Toluene 0.0619 Engineering 0.0031 Engineering Calculation Calculation 100414 Ethylbenzene 0.0048 Engineering 0.0002 Engineering Calculation Calculation 1330207 Xylenes 0.0238 Engineering 0.0012 Engineering Calculation Calculation 110543 n-hexane 0.0762 Engineering 0.0038 Engineering Calculation Calculation 540841 2,2,4-TMP 0.0048 Engineering 0.0002 Engineering Calculation Calculation The uncontrolled VOC emission factor was calculated using AP-42,Chapter 5.2, Equation 1 (version 1/95) using the following values: S= 0.6 (Submerged loading: dedicated normal service) P(true vapor pressure) = 5.0 psia M(vapor molecular weight) =65 Ib/Ib-mol T(temperature of liquid loaded) = 510 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on a cornbustor/flare efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division.A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit.For any questions regarding a specific expiration date call the Division at(303)-692-3150. 7) This facility is classified as follows: AIRS ID: 123/9D6D Page 18 of 19 Color De aw e p � f bile Health and Environment it Pollution Control Division Applicable F3 a Requirement Status Operating Permit Synthetic Minor Source of: VOC NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable NSPS Dc Applicable NSPS OOOO Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60,Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXX)OCX 9) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9D6D Page 19 of 19 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc. Permit Number: 15WE0017 Source Location: Palomino Processing Facility SW Section 28,T3N, R65W, Weld County (non-attainment) Point 001: Heater Point 002: Heater Point 003: Heater Point 004: Condensate tanks Equipment Description: Point 005: produced water tanks Point 006: Fugitive emissions Point 007: Blowdown flare Point 008: Truck loadout AIRS ID: 123-9D6D Date: April 6, 2015 Review Engineer: Stephanie Chaousy, PE Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit 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? December 4, 2014 Section 4—Source Description AIRS Point Equipment Description 001 Up to one (1)27.3 MMBtu/hr heater treater. This unit only burns natural gas. Emissions from this point are not controlled. 002 Up to one (1)27.3 MMBtu/hr heater treater. This unit only burns natural gas. Emissions from this point are not controlled. 003 Up to one (1)27.3 MMBtu/hr heater treater. This unit only burns natural gas. Emissions from this point are not controlled. Page 1 Up to five(5) above ground up to 250,000 bbl atmospheric condensate storage tanks. The condensate entering the tanks will come from a stabilizer system that 004 ensures there are no flash emissions entering the tanks. Emissions are based on working and breathing emissions only. All tanks shall have internal floating roofs. Emissions from these tanks are not controlled. Up to three(3)above ground up to 40,000 bbl atmospheric produced water storage 005 tanks. The emissions are based on working and breathing emissions only assuming the contents are oil. These tanks shall have internal floating roofs. 006 Equipment leaks(fugitive VOCs)from a natural gas processing plant. 007 One(1) maintenance vent.The vent will only operate during emergency/blowdown situations. 008 Truck loadout of condensate. Emissions from the loadout are controlled by a combustion device(combustor or flare). Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria x Yes No pollutant? If"yes", for what pollutant? PMio CO X 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 PM10 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 X Yes No Regulation 7, Sections XII and XVII.C may apply) Point 005: Is this source claiming exempt status for Operator this source based on the fraction of oil in the stored X Yes No requesting water(less than 1% by volume crude oil on an average permitted limit annual basis)? less than 6 TPY Point 005: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 005: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC)805 Rule? Point 008: Is this source located at an oil and gas Yes X No exploration site? Point 008: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP) emissions? Point 008: Will this equipment be operated in any X Yes No NAAQS nonattainment area? Point 008: Does this source load gasoline into Yes X No transport vehicles? Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 NOx,VOC and CO: AP-42, Table 1.4 002 NOx,VOC and CO:AP-42,Table 1.4 003 NOx,VOC and CO:AP-42,Table 1.4 004 Source may provide site-specific emission factors using EPA Tanks. See Section 14 for calculations. 005 Source may provide site-specific emission factors using EPA Tanks. See Section 14 for calculations. Page 2 006 EPA-453/R-95-017, Table 2-8 007 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T 008 L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P =true vapor pressure of liquid loaded [psia] M = molecular weight of vapors[lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 122.7 MMSCF/yr 002 122.7 MMSCF/yr 003 122.7 MMSCF/yr 004 73,000,000 BBL per year 005 18,250,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 600 --- 800 500 006 Flanges 2500 --- 3300 1500 Open-Ended Lines 20 --- 20 20 Pump Seals 10 --- 20 10 Valves 1100 --- 1500 600 Other 100 --- 100 100 007 0.175 MMSCF/yr 008 1,825,000 BBL per year Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 122.7 MMSCF/yr 002 122.7 MMSCF/yr 003 122.7 MMSCF/yr 004 73,000,000 BBL per year 005 18,250,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 600 --- 800 500 006 Flanges 2500 --- 3300 1500 Open-Ended Lines 20 --- 20 20 Pump Seals 10 --- 20 10 Valves 1100 --- 1500 600 Other 100 --- 100 100 007 0.175 MMSCF/yr 008 1,825,000 BBL per year Does this facility use control devices? X Yes No Page 3 AIRS Point Process Control Device Description %Granted Reduction Granted 004 01 Internal floating roof Per manufacturer Per 005 01 Internal floating roof manufacturer 006 01 LDAR per Regulation 7, Section XVII.F Per regulation 007 01 Flare 95 008 01 Combustor/flare 95 Section 6—Emission Summary (tons per year) Point NOX VOC CO Single HAP Total HAP 001 11.7 --- 9.8 --- --- 002 11.7 --- 9.8 --- --- 003 11.7 --- 9.8 --- --- 004 --- 55.0 --- 0.9 (hexane) 2.5 PTE: 005 --- 10.0 --- 0.1 (hexane) 0.4 006 --- 2.0 --- 0.04 (hexane) 0.1 007 --- 8.5 --- 0.1 (Hexane) 0.2 008 --- 182.5 --- 2.9 (hexane) 8.2 001 11.7 --- 9.8 --- --- 002 11.7 --- 9.8 --- --- 003 11.7 --- 9.8 --- --- Uncontrolled point 004 --- 55.0 --- 0.9 (hexane) 2.5 source emission rate: 005 --- 10.0 --- 0.1 (hexane) 0.4 006 --- 2.0 --- 0.04 (hexane) 0.1 007 --- 8.5 --- 0.1 (Hexane) 0.2 008 --- 182.5 --- 2.9 (hexane) 8.2 001 11.7 --- 9.8 --- --- 002 11.7 --- 9.8 --- --- 003 11.7 --- 9.8 --- --- Controlled point 004 --- 54.8 --- 0.9 (hexane) 2.5 source emission rate: 005 --- 9.0 --- 0.1 (hexane) 0.4 006 --- 1.2 --- 0.04 (hexane) 0.1 007 --- 8.5 --- 0.1 (Hexane) 0.2 008 --- 9.1 --- 0.1 (hexane) 0.4 001 11.7 --- 9.8 --- --- Requested permit 002 11.7 --- 9.8 --- --- limits 003 11.7 --- 9.8 -- 004 --- 55.0 --- 0.9 (hexane) 2.5 Page 4 005 --- 10.0 --- 0.1 (hexane) 0.4 006 --- 2.0 --- 0.04 (hexane) 0.1 007 --- 10 --- 0.1 (Hexane) 0.2 008 --- 10 --- 0.1 (hexane) 0.4 Total APEN Reported emissions: Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions (lb/yr) reportable? Rate(Ib/yr) Point 004 Benzene 71432 A 990 Yes 990 Toluene 108883 C 1428 Yes 1428 Ethylbenzene 100414 C 114 No 114 Xylenes 1130207 C 552 Yes 552 n-Hexane 110543 C 1752 Yes 1752 2,2,4-TMP 540841 C 114 No 114 Point 005 Benzene 71432 A 166 No 166 Toluene 108883 C 237 No 237 Ethylbenzene 100414 C 18 No 18 Xylenes 1130207 C 88 No 88 n-Hexane 110543 C 289 Yes 289 2,2,4-TMP 540841 C 18 No 18 Point 006 Benzene 71432 A 41 No 41 Toluene 108883 C 41 No 41 Ethylbenzene 100414 C 5 No 5 Xylenes 1130207 C 39 No 39 n-Hexane 110543 C 89 No 89 Point 007 Benzene 71432 A 40 No 40 Toluene 108883 C 40 No 40 Ethylbenzene 100414 C 20 No 20 Xylenes 1130207 C 20 No 20 n-Hexane 110543 C 199 No 199 Point 008 Benzene 71432 A 3285 Yes 164 Toluene 108883 C 4745 Yes 237 Page 5 Ethylbenzene 100414 C 365 Yes 18 Xylenes 1130207 C 1825 Yes 91 n-Hexane 110543 C 5840 Yes 292 2,2,4-TMP 540841 C 365 Yes 18 Note: Regulation 3, Part A, Section Il.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 006 01 VOC, State only requirement Extended gas HAPS analysis 006 01 VOC, State only requirement Hard component HAPS count 007 01 VOC, State only requirement Extended gas HAPS analysis 007 01 VOC, Regulation No. 1, Section II.A.5 EPA Method 9 HAPS Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic 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.ii (subject to MACT)? Yes X 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? AIRS Point Section 12—Regulatory Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Page 6 Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 001-008 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-008 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, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 001-008 each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is non-attainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions 001-008 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg.3, Part B, Section II.D.2.a) Applicant is not required to obtain a permit since the stored produced water 005 contains less than one percent by volume crude oil on an annual average (Reg. 3, Part B, Section II.D.1.m) However, applicant wants a federally enforceable permit limit under 6 TPY to minimize NSPS OOOO requirements. Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is/is not located in the 8-hour ozone nonattainment area. 006 The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the fugitives will be in service after the date above, this source is considered "new or modified." The operator has implemented LDAR per Regulation 7, Section XVII.F. LDAR satisfies RACT. Part B, III.D.2-RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is/is not located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 008 The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the tank battery from which loadout is occurring will be in service since after the date above, this source is considered "new or modified." Operator is using submerged fill (0.6 saturation factor), therefore, RACT requirements are satisfied. Regulation 6- New Source Performance Standards 001, 002, NSPS Dc: The reboiler heaters are greater than 10 MMBtu/hr inlet design capacity and 003 are therefore subject to NSPS Dc. NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. Is this source greater than 19,800 gallons(471 bbl)?Yes 004, 005 Is this source subject to NSPS Kb?Yes WHY? These tanks are greater than 19,800 gallons and have a commencement date of July 2016. All tanks will comply by having an internal floating roof. Page 7 NSPS OOOO: Tanks with the potential to emission equal to or greater than 6 TPY. 004, 005 Are uncontrolled VOC emissions greater than 6 TPY?Yes All tanks are subject to NSPS Kb, therefore, not subject to NSPS OOOO 60.5395. NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS OOOO. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and 006 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?" No Is this source subject to NSPS OOOO? No WHY? Facility does not meet the definition of a"natural gas processing plant." 008 No applicable subpart. This facility is not a bulk gasoline terminal. Regulation 7—Volatile Organic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... 004, 005 The tanks are located in the ozone nonattainment area. However, all tanks have an internal floating roof and are not designed to vent to the atmosphere. Therefore the tanks are exempt from Sections XII and XVII of the regulation. Section XII.G: If facility is a natural gas processing plant located in non-attainment 006 area, then subject to Section XII.G. Facility is not considered a natural processing gas plant, therefore, will be subject to this subpart. It is considered an oil processing, storage and blending facility. No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 008 76,000 liters of gasoline(20,000 gallons), which is loaded directly into transport vehicles. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. Regulation 8—Hazardous Air Pollutants 001, 002, 003, 007, None 008 MACT EEEE: Organic Liquids Distribution 004, 005 This source is not subject to MACT EEEE because it is not located at a major source of HAP. 004, 006 MACT HH This source is not subject to MACT HH because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Emission Process Emission Pollutant/ Fugitive Control Point Process Description Throughput Factor CAS# (Y/N) Factor (%) Source 100 NOx No AP-42, 0 122.7 lb/mmscf Table 1.4-1 01 Heater treater 001 MMSCF/yr 84 CO No AP-42, 0 lb/mmscf Table 1.4-1 SCC 10200602—10-100 Million btu/hr 100 N0x No AP-42, 0 01 Heater treater 122.7 lb/mmscf Table 1.4-1 002 MMSCF/yr 84CO No AP-42, 0 lb/mmscf Table 1.4-1 SCC 10200602-10-100 Million btu/hr 100 N0x No AP-42, 0 003 01 Heater treater 122.7 lb/mmscf Table 1.4-1 MMSCF/yr 84 CO No AP-42, 0 lb/mmscf Table 1.4-1 Page 8 SCC 10200602—10-100 Million btu/hr 0.0357 VOC No EPA Tanks NA lb/1000 gal 0.0003 Benzene/ No EPA Tanks NA lb/1000 gal 71432 0.0005 Toluene/ No EPA Tanks NA lb/1000 gal 108883 01 E&P Condensate 73,000,000 0.00004 Ethylbenzene No EPA Tanks NA 004 Storage Tanks bbl/yr lb/1000 gal / 100414 0.00021b/10 Xylenes/ No EPA Tanks NA 00 gal 1130207 0.0006 n-Hexane No EPA Tanks NA lb/1000 gal / 110543 0.00004 2,2,4-TMP No EPA Tanks NA lb/1000 gal /540841 SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses 0.0236 VOC No EPA Tanks NA lb/1000 gal 0.0002 Benzene/ No EPA Tanks NA lb/1000 gal 71432 0.0003 Toluene/ No EPA Tanks NA lb/1000 gal 108883 01 Produced Water 18,250,000 0.00002 Ethylbenzene No EPA Tanks NA 005 Storage Tanks bbl/yr lb/1000 gal / 100414 0.0001 Xylenes/ No EPA Tanks NA lb/1000 gal 1130207 0.0004 n-Hexane No EPA Tanks NA lb/1000 gal / 110543 0.00002 2,2,4-TMP No EPA Tanks NA lb/1000 gal /540841 SCC 40400315— Fixed Roof Tank, Produced Water,working+breathing+flashing losses EPA-453/R- 01 Fugitive VOC Leak Emissions VOC Yes 95-017, NA 006 Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections, seals, drains) 96685.71 Engineering lb/mmscf VOC No Calculation 0 228.5714 Benzene/ Engineering lb/mmscf 71432 No Calculation 0 Maintenance 228.5714 Toluene/ No Engineering 0 01 Slowdowns/ 0.175 lb/mmscf 108883 Calculation 007 MMSCF/yr 114.2857 Ethylbenzene/ Engineering Flare lb/mmscf 100414 No Calculation 0 114.285 Xylenes/ No Engineering 0 lb/mmscf 7 1130207 Calculation 1137.1429 n-Hexane/ Engineering lb/mmscf 110543 No Calculation 0 SCC 31000205-Flares 4.76 lb/1,000 VOC No AP-42 95 gal 0.0429 Benzene/ Engineering lb/1,000 71432 No calculation 95 008 01 Truck Condensate 1,825,000 gal Loadout BBL/yr 0.0619 Toluene/ Engineering lb/1,000 108883 No calculation 95 gal 0.0048 Ethylbenzene/ Engineering lb/1,000 100414 No calculation 95 gal Page 9 0:0238 Xylenes/ Engineering lb/1,000 1130207 No calculation 95 gal 0.0762 n-Hexane/ Engineering lb/1,000 110543 calculation 95 N° gal 0.0048 2 2 4-IMP/ Engineering lb/1,000 540841 calculation 95 No gal SCC 40600132: Crude Oil: Submerged Loading (Normal Service) Section 14—Miscellaneous Application Notes AIRS Point 001 Heater A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY NOx/CO. Operator used emission factors from AP-42, Table 1.4-1 to calculate NOx and CO: NOx= 100 lb 27.3 mmbtu scf 8760 hr 1 T =11.96 TPY NOx mmscf hr 1000 btu year 2000 lb Operator calculated 11.7 TPY NOx. This could be due to rounding and then what was eventually put on the APEN. I will permit the source at 11.7 TPY NOx. CO= 84 lb 27.3 mmbtu scf 8760 hr 1 T =10.04 TPY CO mmscf hr 1000 btu year 2000 lb Operator calculated 9.8 TPY CO. This could be due to rounding and then what was eventually put on the APEN. I will permit the source at 9.8 TPY CO. AIRS Point 002 Heater A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY NOx/CO. Operator used emission factors from AP-42, Table 1.4-1 to calculate NOx and CO: NOx= 100 lb 27.3 mmbtu scf 8760 hr 1 T =11.96 TPY NOx mmscf hr 1000 btu year 2000 lb Operator calculated 11.7 TPY NOx. This could be due to rounding and then what was eventually put on the APEN. I will permit the source at 11.7 TPY NOx. CO= 84 lb 27.3 mmbtu scf 8760 hr 1 T =10.04 TPY CO mmscf hr 1000 btu year 2000 lb Operator calculated 9.8 TPY CO. This could be due to rounding and then what was eventually put on the APEN. I will permit the source at 9.8 TPY CO. AIRS Point 003 Heater A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY NOx/CO. Operator used emission factors from AP-42, Table 1.4-1 to calculate NOx and CO: NOx= 100 lb 27.3 mmbtu scf 8760 hr 1 T =11.96 TPY NOx mmscf hr 1000 btu year 2000 lb Operator calculated 11.7 TPY NOx. This could be due to rounding and then what was eventually put on the APEN. I will permit the source at 11.7 TPY NOx. CO= 84 lb 27.3 mmbtu scf 8760 hr 1 T =10.04 TPY CO mmscf hr 1000 btu year 2000 lb Operator calculated 9.8 TPY CO. This could be due to rounding and then what was eventually put on the APEN. I will permit the source at 9.8 TPY CO. Page 10 AIRS Point 004 Condensate Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY VOC (permit threshold). Operator used EPA tanks for emissions. The condensate entering the tanks will come from a stabilizer system that ensures there are no flash emissions entering the tanks. Emission estimates are based upon working and breathing losses only. Tanks have internal floating roofs. EPA tanks calculated 19922.59 lb/yr for 1 tank. Multiplying it by 5 tanks and a 10% margin, VOC emissions from the tanks are 54.787 TPY, or 55.0 TPY(matches APEN). The EPA tanks model did not speciate the HAPS and so the operator used table 3-2 of DOC#EPA-453/R-94-002a to calculate HAP emissions (except for 2,2,4-TMP which is typically more similar to ethylbenzene). I will be asking for a liquids analysis in the initial testing requirements. HAP emission factors were calculated with a throughput of 73,000,000 bbl/yr: Component Component Lb/yr Operator Emission Emission factor wt% lb/yr* factor (lb/1000 gal) (lb/bbl) 54.8 55.0 0.0015 0.0357 TPY TPY Benzene 0.9 990 990 0.000014 0.00032 Toluene 1.3 1430 1428 0.0000195 0.00047 Ethylbenzene 0.1 110 114 0.00000156 0.000037 Xylenes 0.5 550 552 0.00000756 0.00018 n-hexane 1.6 1760 1752 0.000024 0.00057 2,2,4-TMP 0.1 110 114 0.00000156 0.000037 *There is a small discrepancy between what I calculated and what the operator calculated. I believe this is due to rounding. I emailed the operator on 4/8/2015 letting her know that HAPS should be on the APEN and that the emission factors should be in lb/1000 gal. A new person of contact was assigned to this person from Noble (no longer Catherine Flanders but Shaun Higgins in May 2015). I heard back on 5/12/15 that he agreed with the calculations and to redline the APEN accordingly. Page 11 AIRS Point 005 Produced water tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY VOC (permit threshold). The emission estimates are based on EPA Tanks 4.0.9d and a created mixture that is based on the source's analytical data/source's engineering judgment. The mixture assumed gasoline(RVP 12). The total requested wastewater throughput of 18,250,000 bbl/yr was divided by the number of tanks and this value was used as the throughput in the model. The emission estimates from EPA Tanks 4.0.9d were then multiplied by a variability factor of 1.1. Emissions calculated from the model are 9.03 TPY. Operator requested VOC emissions to be 10.0 TPY. The EPA tanks model did not speciate the HAPS and so the operator used table 3-2 of DOC#EPA-453/R- 94-002a to calculate HAP emissions(except for 2,2,4-TMP which is typically more similar to ethylbenzene). I will be asking for a liquids analysis in the initial testing requirements. HAP emission factors were calculated with a throughput of 18,250,000 bbl/yr: Component Component Lb/yr Operator Emission Emission factor wt% lb/yr* factor(lb/bbl) (lb/1000 gal) VOC 9.0369 10.0 0.000990345 0.02357965 TPY TPY Benzene 0.9 163 166 0.0000096 0.000229 Toluene 1.3 235 237 0.0000137 0.00033 Ethylbenzene 0.1 18 18 0.0000010 0.0000248 Xylenes 0.5 90 88 0.0000051 0.00012 n-hexane 1.6 289 289 0.00001675 0.00040 2,2,4-TMP 0.1 18 18 0.0000010 0.0000248 *There is a small discrepancy between what I calculated and what the operator calculated. I believe this is due to rounding. I emailed the operator on 4/8/15 letting her know that HAPS should be on the APEN and that the emission factors should be in lb/1000 gallons. I heard back on 5/12/15: Your calculations in lb/1000 gal are pretty close to what I get. There is a bit more rounding error on this one, for your reference I have pasted my calculations below. If you think the rounding error is close enough I'm not concerned. Component Emission Factor Rounding to 4 What I lb/1000 gal decimals... calculated (from above chart) VOC 0.023580039 0.0236 0.0236 Benzene 0.000217143 0.0002 0.0002 Toluene 0.000308571 0.0003 0.0003 Ethylbenzene 0.0000228571 0.00002 0.00002 Xylenes 0.000114286 0.0001 0.0001 n-hexane 0.000377143 0.0004 0.0004 2,2,4-TMP 0.0000228571 0.00002 0.00002 So, I believe our calculations match and will use what is listed above. AIRS Point 006 Fugitive emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY VOC (permit threshold). An extended gas analysis was not provided in the application. An updated extended gas analysis will be required because one was not included in the initial application. Page 12 AIRS Point 007 Venting flare I emailed the operator for a gas composition but was reminded that this flare is for venting of equipment blowdown vapors, not flaring. So combustion emissions do not need to be calculated. The operator's calculations included HAP emissions based on an assumed gas composition. It was confirmed with the operator(6/12/15) that the compositions included were meant to be conservative potential compositions (since an actual gas composition was not included in the application). Equations used for calculating VOC are: Mscf= V cf T+ 460 R (Pi-Pf) psi Mcf #events Yr 520R 14.7 psi 1000 scf year Lb = Lb-mol MW lb Wt% lb 1000 scf mcf 379 scf Lb-mol lb mcf Lb= Mcf Lb yr yr mcf Compressor Stabilizer Slug Catcher Maintenance volume cf 300 2500 5000 Initial Pressure Psig 50 50 50 Final Pressure Psig 0 0 0 Temperature F 60 60 60 Scf/event scf 1 9 17 Events per year 48 6 3 Emission factors based on a throughput of 0.175 mmscf/yr: Component Component Uncontrolled Uncontrolled Requested E.F. wt% lb/yr TPY Ib/mmscf VOC 85.0% 16929 8.46 10 TPY 96685.71 Benzene 0.2% 34 0.02 40 lb/yr 228.5714 Toluene 0.2% 34 0.02 40 lb/yr 228.5714 Ethylbenzene 0.1% 17 0.01 20 lb/yr 114.2857 Xylenes 0.1% 17 0.01 20 lb/yr 114.2857 n-hexane 1.0% 169 0.08 199 lb/yr 1137.1429 Page 13 AIRS Point 008 Truck Condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 5.0 Psia AP-42, Table 7.1-2 based on Gasoline RVP 11.5 M 65 Lb/lb-mole AP-42, Table 7.1-2 based on Gasoline RVP 11.5 T 510 Deg R Based on source's knowledge of bulk liquid temperature L 4.76 Lb/10^3 gal 2.00E-01 Lb/bbl This value is used to calculate annual emissions AP-42: Chapter 5.2 Equation 1 L= 12.46*S*P*M/T L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P =true vapor pressure of liquid loaded [psia] M = molecular weight of vapors[lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] L 4.761b/10^3 gal 2.00E-011b/bbl Annual requested Throughput 76,650,000gal/yr Annual requested VOC emissions 365,170lb/yr 182.6Tpy uncontrolled Controlled by combustor/flare 9.1Tpy controlled I emailed the operator on 4/8/15 and received feedback on 5/12/15: 1. Shouldn't the requested throughput be the same as the condensate requested throughput of 73,000,000 bbl/yr? It looks like the primary method of loadout is planned to be pipeline with truck loadout as a backup, I believe this explains why there is a discrepancy. Therefore, the loadout will have a limited throughput of 1,825,000 bbl/yr. The EPA tanks model did not speciate the HAPS and so the operator used table 3-2 of DOC#EPA-453/R- 94-002a to calculate HAP emissions(except for 2,2,4-TMP which is typically more similar to ethylbenzene). I will be asking for a liquids analysis in the initial testing requirements. HAP emission factors were calculated with a throughput of 1,825,000 bbl/yr: Component Component Lb/yr Emission Emission factor wt% factor(lb/bbl) (lb/1000 gal) Benzene 0.9 3285 0.0018 0.0429 Toluene 1.3 4745 0.0026 0.0619 Ethylbenzene 0.1 365 0.0002 0.0048 Xylenes 0.5 1825 0.001 0.0238 n-hexane 1.6 5840 0.0032 0.0762 2,2,4-TMP 0.1 365 0.0002 0.0048 Page 14 • V CO O U 4 co .� E _ N a o COoov. Uc`, • o CD 01 C e0 d E z V 0 `i `i `i cGVd o N ❑ L ro C) C .Q� �D �p V' E ti -O O QU " O, aJ O C .- O- N C0 \ C A V �' C ", O O O � V O O O n E W ° o a > 0 , o ��-W o 1-. °) a ro F. o c d " a = C.:5"." a) o c ?, Z m ro °�" c c o d 'ea.' ° o L •� •� bD N z > z 77 C::Lr a, �ct Cr ".C r °D .a 77= i ro 3 ° Y w E o ° •v a`i �./ d V . U F-+ L •� c.r C >` O - u L .2. C O O V T >, a) cat d E w 4i N ° c P `° a n .° a o o o C1 L C C O V G i a'•, as O V v V _ bD U r. C uA CV G L .+ .. LC CC Q) R O a... ° V A '. - O - •� O' CY C U N aU) v K d O R A U "7"c r. 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