The URL can be used to link to this page

Browse Search

Home My WebLink About20193973.tiffCOLORADO Department of Public Health & Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 November 19, 2019 Dear Sir or Madam: RECEIVED NOV 2 5 2019 WELD COUNTY COMMISSIONERS On November 20, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for DCP Operating Company, LP - Mewbourn Natural Gas Processing Plant. 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 &t Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Jared Polls, Governor I Jill Hunsaker Ryan, MPH, Executive Director Pvbt:G Rev:et,.) ec:PL(TP), HL(L),Pw(sV/Ea/crt/cic), 12/09/1 9 060m) II/031I' �Q1 -3973 Ce Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: DCP Operating Company, LP - Mewbourn Natural Gas Processing Plant - Weld County Notice Period Begins: November 20, 2019 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: DCP Operating Company, LP Facility: Mewbourn Natural Gas Processing Plant Natural Gas Processing Facility SE 1/4 of Section 35, Township 4N, Range 66W Weld County The proposed project or activity is as follows: The operator is requesting the following modifications to an existing major natural gas processing facility located in the ozone non -attainment area: (i) Amine Unit (Point 120) - increase the limit on combustion of supplemental fuel by the thermal oxidizer from 149.84 MMSCF/year to 192 MMSCF/year, (ii) Plant Flare (Point 125) - increase the process limit from 9.09 MMSCF/year to 30.28 MMSCF/year, (iii) TEG Dehydration Unit (Point 131) - Update process limits and ongoing compliance requirements, (iv) Hot Oil Heater (Point 133) - Limit the heat input rate from 40.8 MMBtu/hr to 32.0 MMBtu/hr, (v) Acid Gas Flare (Point 136) - Increase the process limits based on an increase of primary control device downtime from 13 days to 20.5 days, (vi) Plant Flare (Point 137) - Increase the process limit from 15.63 MMSCF/year to 90.0 MMSCF/year, (vii) Turbines (Points 111-112, 118-119 Et 129- 130) - Update emission and process limits to include start-up and shutdown events, (viii) Fugitives (Points 108 Et 135) - Update component counts and update control efficiencies based on compliance with NSPS 0000a LDAR. (ix) Loadout (Point 109) - Decrease permitted limit from 912,500 bbl/year to 200,000 bbl/year. Include limits on pilot light and assist gas combustion. (x) Engine (Point 101) - limit the operating hours from 8760 hours to 720 hours, (xi) Add one (1) 300 barrel methanol storage tank and (xii) Permit natural gas venting from the blowdown of pig receivers and pig launchers. 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 09WE1136 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 COLORADO Tlepartmenn of Publip Health Et Environment Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Harrison Slaughter, P.E. Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 21 COLORADO Department of Public Health & Envftotunent COLORADO Air Pollution Control Division Department of Pubic Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 09WE1136 Issuance: 5 DCP Operating Company, LP Facility Name: Plant AIRS ID: Physical Location: County: Description: Mewbourn Natural Gas Processing Plant 123/0090 SEA/aSEC35T4NR66W Weld County Natural Gas Processing Plant Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description C-211 ' 101 One (1) Caterpillar, G379NA, Serial Number: 72B643, natural gas fired, 4- stroke, rich -burn, naturally aspirated, reciprocating internal combustion engine, rated at 330 HP. This engine runs a vapor recovery unit (VRU) used for natural gas compression. Air -Fuel Ratio Controller (AFR) and a Non -Selective Catalytic Reduction system (NSCR) F017 108 Fugitive emission component leaks from the Mewbourn II natural gas processing plant. None LO 109 Stabilized natural gas condensate loadout to tank trucks. Enclosed combustor (John Zink, ZCT-1-4- 35-X-1 /3) TANKS 110 Four (4) 400 barrel fixed roof stabilized natural gas condensate storage vessels connected via liquid manifold. Enclosed combustor (John Zink, ZCT-1-4- 35-X-1/3). C0170 111 One (1) Solar Taurus 60-7800S, Serial Number: OHH 15-T9606, natural gas fired turbine rated at 50.09 MMBtu/hr (LHV) None Page 1 of 102 COLORADO Air Pollution Control Division Department of Public Health &Environment Dedicated to protecting and improving the health and environment of the people of Colorado heat input at 60°F ambient temperature and 5,995 horsepower at 13,826 RPM. This turbine is used for natural gas compression. This source is equipped with SoLoNOx technology for minizing emissions of Nitrogen Oxides. Identified as Inlet 1. C0180 112 One (1) Solar Taurus 60-7800S, Serial Number: OHE 17-T9134, natural gas fired turbine rated at 50.09 MMBtu/hr (LHV) heat input at 60°F ambient temperature and 5,995 horsepower at 13,826 RPM. This turbine is used for natural gas compression. This source is equipped with SoLoNOx technology for minizing emissions of Nitrogen Oxides. Identified as Inlet 2. None C250 113 One (1) Caterpillar, G3608TALE, SN: BEN00563, natural gas fired, 4 -stroke, turbo -charged,'. lean -burn, low emissions design, reciprocating internal combustion engine, heat input rated at 17.9 MMBTU per hour, output rated at 2,370 HP, powering a natural gas compressor. Identified as Residue 1 Oxidation catalyst C251 114 One (1) Caterpillar, G3608TALE, SN:. BEN00565, natural gas fired, 4 -stroke, turbo -charged, Lean -burn, low emissions design, reciprocating internal combustion engine, heat input rated at 17.9 MMBTU per hour, output rated at 2,370 HP, powering a natural gas compressor. Identified as Residue 2. Oxidation catalyst C252 115 One (1) Caterpillar, G3608TALE, SN: BEN00567, natural gas fired, 4 -stroke, turbo -charged, lean -burn, low emissions design, reciprocating internal combustion engine, heat input rated at 17.9 MMBTU per hour, output rated at 2,370 HP, powering a natural gas compressor. Identified as Residue 3. Oxidation catalyst C253 116 One (1) Caterpillar, G3608TALE, SN: BEN00572, natural gas fired, 4 -stroke, turbo -charged, lean -burn, low emissions design, reciprocating internal combustion Oxidation catalyst Page 2 of 102 COLORADO Air Pollution Control Division Department of Public Heath Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado engine, heat input rated at 17.9 MMBTU per hour, output rated at 2,370 HP, powering a natural gas compressor. Identified as Residue 4. C254 117 One (1) Caterpillar, G3608TALE, SN: BEN00571, natural gas fired, 4 -stroke, turbo -charged, lean -burn, low emissions design, reciprocating internal combustion engine, heat input rated at 17.9 MMBTU per hour, output rated at 2,370 HP, powering a natural gas compressor. Identified as Residue 5. Oxidation catalyst G1 b50 118 One (1) Solar, Taurus 70-10302S, natural gas fired combustion turbine (SN: OHK17- B0263), rated at 61.58 MMBTU per hour heat, input (LHV) at 60°F ambient temperature and 8,046 horsepower (HP) at 10,937 RPM. This source is equipped with SoLoNOx technology for minizing emissions of Nitrogen Oxides. This turbine is used for electric power generation. Identified as Genset 1 None G1670 ' 119 One (1) Solar, Taurus 70-10302S, natural gas fired combustion turbine (SN: OHD18- B1836), rated at 61.58 MMBTU per hour heat input (LHV) at 60°F ambient temperature and 8,046 horsepower (HP) at 10,937 RPM. This source is equipped ' with `' SoLoNOx technology for minizing emissions of Nitrogen Oxides. This turbine is used for electric power generation. Identified as Genset 2 None AM001 120 One (1) methyldiethanolamine (MDEA) natural gas sweetening unit (Make: Precision Pipe and Vessel, Model: T-501, Serial Number: 1830) for acid gas removal with a design capacity of 160 MMscf per day. This emission unit is equipped with three (3) (Make: Schlumberger RedaHP, Model: J350N) electric driven amine recirculation pumps with a total limited capacity of 640 gallons per minute of lean amine. Only two (2) amine recirculation pumps will be operated at any given time. The third amine recirculation pump serves Emissions from the flash tank are routed directly to the vapor recovery unit (VRU) that recycles the emissions back to the plant inlet. The VRU has a maximum of 5% annual downtime. During VRU downtime, flash tank emissions are routed to the plant flare Page 3 of 102 121 COLORADO Air Pollution Control Division L`epartrnent of Public: Health & Envrore erit Dedicated to protecting and improving the health and environment of the people of Colorado as a back-up only. This amine unit is equipped with a natural gas/amine contactor, reflux condenser, flash tank, still vent and amine regeneration reboiler covered under point 123/0090/121. covered under point 123/0090/125 with a 95% destruction efficiency. The acid gas stream from the still vent is routed to reflux condenser and then to a thermal oxidizer (TO) (Make: Anguil, Model: 18714, Serial Number: UCC 15-27) with fuel gas limited at 23 MMBtu/hr. The destruction efficiency for the TO is 96.7%. During TO downtime, emissions from the still vent are routed to an acid gas flare covered under point 123/0090/136 with a destruction efficiency of 95%. The TO has a maximum downtime of 20.5 days per year (492 hrs/year). H776 One (1) Optimized Process Furnace, Inc., Model 200, SN: J091036, natural gas fired amine regeneration reboiler, heat input design rated at 64.9 MMBTU per hour. This is equipped with Ultra -Low NOx combustion system for minimization of Nitrogen Oxides emissions. None D-931 122 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: Precision Pipe Et Vessel LLC, Model: T-531, Serial Number: CL09-144) with a design capacity of 125 MMSCF per day. This emissions unit is equipped with two (2) (Make: Rotor Tech, Model: GS -3308) electric driven glycol pumps with a limited total combined capacity of 28 gallons per minute. This dehydration unit is equipped with a still vent, glycol flash tank, and reboiler burner Emissions from the still vent are routed to an air-cooled condenser, and then to a vapor recovery unit (VRU) that recycles the emissions back to the plant inlet. Emissions from the flash tank are Page 4 of 102 COLORADO Air Pollution Control Division Department of Public Health v Environment Dedicated to protecting and improving the health and environment of the people of Colorado (heat provided by hot gases from various combustion processes supplemented by a hot oil heater) covered under AIRS Point ID: 123/0090/123. routed directly to the vapor recovery unit (VRU) that recycles the emissions back to the plant inlet. The VRU that recycles the still vent and flash tank emissions has a maximum 2% annual downtime. During VRU downtime, still vent and flash tank emissions are routed to the open flare covered under AIRS Point ID: 123/0090/125. H771 123 Two ',(2) Devco, HeliFlow, SN: 3431-3, natural gas fired hot oil heaters, heat input design rated at 26.0 MMBTU per hour each. These are equipped with Ultra-Low-NOx combustion systems for minimization of Nitrogen Oxides emissions. Hot oil is used to provide heat to various natural gas processes at the facility including supplemental heat for "glycol regeneration reboiler. Only one heater to be operated at a time, the other is to be used as a backup. None F-1 125 Routine maintenance activities, purging of gas and malfunctions for the Mewbourn II gas processing train. Activities are controlled by an elevated open air assisted process flare. Purge gas prevents low flashback problems to the flare and keeps the flame stable. The purge gas and pilot gas used consists of residue gas and helps the Aare maintain a minimum required positive flow through the system. This open flare also controls emissions from the TEG dehydration unit covered under point 122 during VRU downtime and flash tank emissions from the amine unit covered under point 120 during VRU downtime. One (1) open flare (Make: John Zink, Model: KMI-12-8-WB, SN: 9215554) Page 5 of 102 COLORADO Air Pollution Control Division Department of Public- Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado TURB-1 129 One (1) Solar Taurus 70-10802S ESC, Serial Number: 1006B, natural gas fired turbine rated at 66.12 MMBtu/hr (LHV) heat input at 60°F ambient temperature and 9,055 horsepower at 11,513 RPM. This turbine is used for natural gas compression. This source is equipped with SoLoNOx technology for minizing emissions of Nitrogen Oxides. One (1) Solar Taurus 70-10802S ESC, Serial Number: 1005B, natural gas fired turbine rated at 66.12 MMBtu/hr (LHV) heat input at 60°F ambient temperature and 9,055 horsepower at 11,513 RPM. This turbine is used for natural gas compression. This source is equipped with SoLoNOx technology for minizing emissions of Nitrogen Oxides. None TURB-2 130 D-2 131 None One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: Professional Projects, Inc., Model:'T-9600, Serial Number: 5667) with a design capacity of 230 MMscf per day. This emissions unit is equipped with two (2) (Make: DXP, Model: NOV 59T -3M PUMP) electric driven glycol pumps each with a design capacity of 40 gallons per minute. Only one glycol pump will be operated at any given time. The second glycol pump serves as a back-up only. This dehydration unit is equipped with a still vent, flash tank, and electric reboiler burner. Emissions from the still vent are routed to an air-cooled condenser, and then to a vapor recovery unit (VRU) that recycles the emissions back to the plant inlet. Emissions from the flash tank are routed directly to the vapor recovery unit (VRU) that recycles the emissions back to the plant inlet. The VRU that recycles the still vent and flash tank emissions has a maximum 2% annual downtime. During VRU downtime, still vent and flash tank emissions are routed to the open flare covered under AIRS Point ID: 123/0090/137. Page 6 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado HT -01 132 One (1) Heatec (Model: HCI-5010-40, SN: HI14-185) natural gas fired regeneration heater. The heater is design rated at 9.6 MMBtu/hr. This heater is equipped with a low NOx combustion system for minimizing emissions of Nitrogen Oxides. The heater provides heat for mole sieve regeneration. None HT -02 133 One (1) Heatec (Model: HCI-16010-50-Q-G, SN: HI17-080) natural gas fired hot oil heater. The heater is design rated at 40.8 MMBtu/hr. The heater is limited to a heat input rate of 32.0 MMBtu/hr. The heater is equipped with a low NOx combustion system for minimizing emissions of Nitrogen Oxides. The heater provides heat for the condensate stabilizer and demethanizer trim reboiling. None TANKS -2 134 Two (2) 755 barrel fixed roof stabilized natural gas condensate storage vessels connected via liquid manifold. Enclosed combustor (John Zink, ZCT-1-4- 35-X-1 /3) FUG -02 135 Fugitive emission component leaks from a natural gasprocessing plant associated with the Mewbourn III expansion project. None F-2 136 Amine unit still vent emissions during thermal oxidizer downtime. Emissions are controlled by an elevated open air assisted acid gas flare. Purge gas prevents low flashback problems to the flare and keeps the flame stable. The purge gas and pilot gas used consists of residue gas and helps the flare maintain a minimum required positive flow through the system. Assist gas consists of residue gas and increases the heat content of the amine unit still vent acid gas stream controlled by this open flare. One (1) open acid gas flare (Make: Zeeco, Model: UFW-12/24, SN. 32097) F-3 137 Routine maintenance activities, purging of gas and malfunctions for the Mewbourn III gas processing train. Activities are controlled by an elevated open air assisted process flare. Purge gas prevents low flashback problems to the flare and keeps the flame stable. The purge gas and pilot gas used consists of residue gas and helps the flare maintain a minimum required One (1) open flare (Make: Zeeco, Model: FL -5100, SN: 31934) Page 7 of 102 COLORADO Air Pollution Control Division Department of Public Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado positive flow through the system. This open flare also controls emissions from the TEG dehydration unit covered under point 131 during VRU downtime. METHANOL 140 One (1) 300 barrel fixed roof methanol storage vessel. None PIG Natural gas venting resulting from the blowdown of pig receivers and pig launchers. This source includes the following equipment: • One (1) 16" pig receiver • One (1) 24" pig receiver • One (1) 20" pig receiver • One (1) 12" pig receiver Three (3) 8" pig receivers Four (4)! 6" pig receivers One (1) 16" pig launcher ° " pig launcher One (1)(1) 2024" pig launcher None Point 101 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G379NA engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Points 111 Et 112 may be replaced with another Solar Taurus 60-7800S turbine rated at 5,995 HP in accordance with the temporary turbine replacement provision or with another Solar Taurus 60- 7800S turbine rated at 5,995 HP in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment B. Points 113, 114, 115, 116 £t 117 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3608TALE engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 118 £t 119 may be replaced with another Solar Taurus 70-10302S turbine rated at 8,046 HP in accordance with the temporary turbine replacement provision or with another Solar Taurus 70- 10302S turbine rated at 8,046 HP in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment B. Point 122 &t 131: The glycol pump may be replaced with another glycol pump in accordance with the provisions of the Alternate Operating Scenario (AOS) in this permit. Point 129 £t 130 may be replaced with another Solar Taurus 70-10802S ESC turbine rated at 9,055 HP in accordance with the temporary turbine replacement provision or with another Solar Taurus Page 8 of 102 COLORADO Air Pollution Control Division Department of Public Health a Environment Dedicated to protecting and improving the health and environment of the people of Colorado 70-10802S ESC turbine rated at 9,055 HP in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment B. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. Points 140-141: 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, y submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall b demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at. www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i)' does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. Point 109: Within one hundred and eighty days (180) after issuance of this permit, the operator must install a flow meter(s) to monitor and record volumetric flow rate of assist gas routed to the enclosed combustor covered by this point. The flow meter must be capable of accurately measuring and recording the maximum and minimum assist gas flow rate. Until the flow meter(s) is installed, the operator must use an assist gas flow of 1,200 scf/hour to demonstrate compliance with the process limits in this permit for Process 02 and to calculate emissions as described in this permit. The hours of enclosed combustor operation and total volume of assist gas flow shall be recorded on a daily basis. 5. Point 125: Within one hundred and eighty days (180) after issuance of this permit, the operator must install a low flow meter(s) to monitor and record volumetric flow rate of gas routed to the flare covered by this point. The low flow meter must be capable of accurately measuring and recording the minimum purge gas flow rate. Until the low flow meter(s) is installed, the operator must monitor and record the gas flow using the existing high flow meter and maintain Page 9 of 102 COLORADO Air Pollution Control Division D'eFiartrraent of Pubtic Health £t Environment Dedicated to protecting and improving the health and environment of the people of Colorado records of rotameter throughput (scf/hr) and blowdown events. For any periods when the flare is operational but the actual metered volume is below the detection level of the high flow meter or the high flow meter is displaying zero, the operator must utilize the sum of the rotameter throughput (scf/hr) and blowdown volume records to determine the total volume of gas routed to the flare. The sum of the rotameter throughput plus the blowdown volume shall be used to demonstrate compliance with the process limits in this permit for Process 01 and to calculate emissions as described in this permit until the low flow meter(s) is installed. The throughput measured by the four (4) rotameters shall be monitored, summed and recorded on a daily basis. The number of blowdown events and volume of gas vented to the flare during each of these events shall be monitored, calculated and recorded on a daily basis. 6. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 7. 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 8. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Process Tons - per Yea r Emission Type PM2.5 PM10 SOX H2S NOX VOC CO C-211 101 01 --- --- --- --- 0.42 0.26 0.42 Point F017 108 01 --- --- ` --- --- --- ` 12.8 --- Fugitive LO 109 01 --- --- --- --- 0.07 1.01 0.26 Point 02 --- --- --- --- 0.81 0.95 3.17 TANKS 110 01 --- --- --- --- --- 1.89 --- Point C0170 111 01 1.45 1.45 --- --- 13.12 0.46 13.32 Point 02 --- --- --- --- 0.01 0.23 0.9 03 --- --- --- --- 0.01 0.19 0.83 C0180 112 01 1.45 1.45 --- --- 13.12 0.46 13.32 Point 02 --- --- --- --- 0.01 0.23 0.9 03 --- --- --- --- 0.01 0.19 0.83 C250 113 01 --- --- --- --- 45.76 64.08 17.56 Point C251 114 01 --- --- Point C252 115 01 --- --- Point C253 116 01 --- --- Point Page 10 of 102 C254 COLORADO Air Pollution Control Division Department of Public Health & Er.virornoent Dedicated to protecting and improving the health and environment of the people of Colorado 117 01 Point G1650 118 01 1.78 1.78 16.13 0.57 16.36 02 0.01 0.1 0.59 03 0.01 0.08 0.58 Point G1670 119 01 1.78 1.78 16.13 0.57 16.36 02 0.01 0.1 0.59 03 0.01 0.08 0.58 Point AM001 120 01 33.59 0.57 15.59 8.13 35.03 02 0.01 0.14 0.89 0.61 Point H776 121 01 8.12 1.49 22.74 Point D-931 122 02 0.57 Point H771 123 01 3.25 9.11 Point 129 125 01 1.26'. 6.99 5.74 02 0.07 0.01 0.06 Point TURB-1 01 1.91 1.91 15.03 0.01 0.61 17.59 02 0.19 0.92 03 0.01 0.08 0.65 TU RB-2 130 01 1.91 1.91 15.03 0.01 0.61 17.59 02 0.19 0.92 03 0.01 0.08 0.65 Point D-2 131 01 0.04 1.01 0.18 Point HT -01 132 01 2.00 3.36 Point HT -02 133 01 1.04 1.04 6.87 0.76 11.54 Point TANKS -2 134 01 1.84 Point FUG -02 135 01 15.17 Fugitive F-2 136 01 1.88 0.05 0.65 0.23 02 0.01 1.05 2.39 4.55 Point F-3 137 01 3.6 16.32 16.41 02 0.09 0.01 0.07 Point METHANOL 140 01 0.3 Point PIG 141 01 02 03 04 05 06 07 08 09 5.85 Point Notes: Page 11 of 102 COLORADO Air Pollution Control Division Departrnent cif Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 1. See "Notes to Permit Holder" #4 for information on emission factors and methods used to calculate limits. 2. Process 01 and 02 for point 109 are as follows: a. Process 01: Throughput of stabilized natural gas condensate b. Process 02: Combustion of pilot light fuel and assist gas 3. Process 01, 02 and 03 for points 111 and 112 are as follows: a. Process 01: Steady-state Turbine Emissions b. Process 02: Start-up Turbine Emissions c. Process 03: Shutdown Turbine Emissions 4. Process 01, 02 and 03 for points 118 and 119 are as follows: a. Process 01: Steady-state Turbine Emissions b. Process 02: Start-up Turbine Emissions c. Process 03: Shutdown Turbine Emissions Process 01 and 02 for point 120 are as follows: a. Process 01: Still vent waste gas routed to the thermal oxidizer b. Process 02: Flash tank waste gas routed to the plant flare (point 125). Process 01. and 02 for point ; 125 are as follows: a. Process 01: Combustion of purge gas and gas routed to the flare due to routine maintenance activities. b. Process 02: Combustion of pilot light gas Process 01, 02 and 03 for points 129 and 130 are as follows: a. Process 01: Steady-state Turbine Emissions b. Process 02: Start-up Turbine Emissions c. Process 03: Shutdown Turbine Emissions 8. Process 01 and 02 for point 136 are as follows: a. Process 01: Still vent waste gas routed to the acid gas flare (point 136) b. Process 02: Combustion of purge gas, assist gas and pilot fuel by the acid gas flare (point 136). 9. Process 01 and 02 for point 137 are as follows: a. Process 01: Combustion of purge gas and gas routed to the flare due to routine maintenance activities. b. Process 02: Combustion of pilot light gas 10. For point 141, the following process designations apply: a. Process 01: Blowdown of 16" pig receiver b. Process 02: Blowdown of 24" pig receiver Page 12 of 102 COLORADO Air Pollution Control Division Department of Public Health & Erairor,merrt Dedicated to protecting and improving the health and environment of the people of Colorado c. Process 03: Blowdown of 20" pig receiver d. Process 04: Blowdown of 12" pig receiver e. Process 05: Blowdown of 8" pig receivers f. Process 06: Blowdown of 6" pig receivers g. Process 07: Blowdown of 16" pig launcher h. Process 08: Blowdown of 24" pig launcher i. Process 09: Blowdown of 20" pig launcher Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 9. The owner or operator must use the emission calculation methods and emission factors found in the Notes to Permit Holder to calculate emissions and show compliance with the limits contained in this permit. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 10. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Regulation Number 3, Part C. II.E.) Total emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 25 tons per year of total hazardous air pollutants (HAP). • 250 tons per year of CO 11. Point 108 Et 135: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate Page 13 of 102 COLORADO Air Pollution Control Division Department of Public Health a Enviro sn errt Dedicated to protecting and improving the health and environment of the people of Colorado actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 12. Point 120: For process 01, the owner or operator shall calculate uncontrolled VOC, HAP and H2S emissions on a monthly basis using the most recent measured gas composition of the acid gas stream from the still vent and monthly measured flow volume of acid gas stream from the still vent to the thermal oxidizer. A control efficiency of 96.7% for VOC, HAP and H2S, based on maintaining the minimum combustion chamber temperature requirements specified in the operating and maintenance section of this permit, shall be applied to the uncontrolled still vent emissions. 13. Point 120: For Process 02, the owner or operator shall calculate uncontrolled VOC, HAP and H2S emissions on a monthly basis using the most recent measured waste gas composition of the flash tank during VRU downtime and monthly calculated flow volume, as calculated using ProMax, of the flash tank waste gas vented to the plant flare (point 125) during VRU downtime. A control efficiency of 95% for VOC, HAP and H2S shall be applied to uncontrolled flash tank emissions during VRU downtime based on operating the flare in compliance with requirements specified in this permit. 14. Point 122 &t 131: 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 extended wet gas analysis and recorded operational values, including: total actual dehydrator gas throughput (measured at the inlet of the dehydrator), lean glycol recirculation rate, vapor recovery unit (VRU) downtime, condenser outlet temperature, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for total actual gas throughput and VRU downtime, shall be averaged on a monthly basis for input into the GRI GlyCalc model version 4.0 or higher and be provided to the Division upon request. 15. Point 125: For Process 01, the owner or operator shall calculate uncontrolled VOC and HAP emissions on a monthly basis using the most recent measured gas composition and most recent monthly measured flow volume of gas routed to the flare. The measured gas composition shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. A control efficiency of 95% for VOC and HAPs shall be applied to the uncontrolled VOC and HAP emissions based on operating the flare in compliance with requirements specified in this permit. 16. Point 136: For process 01, the owner or operator shall calculate uncontrolled VOC, HAP and H2S emissions on a monthly basis using the most recent measured gas composition of the acid gas stream from the still vent and monthly measured flow volume of acid gas stream from the still vent to the acid gas flare. A control efficiency of 95% for VOC, HAP and H2S shall be applied to uncontrolled still vent emissions during TO downtime based on operating the acid gas flare in compliance with requirements specified in this permit. 17. Point 137: For Process 01, the owner or operator shall calculate uncontrolled VOC and HAP emissions on a monthly basis using the most recent measured gas composition for each header routed to the plant flare and most recent monthly measured flow volume for each header. A control efficiency of 95% for VOC and HAPs, based on operating the flare in compliance with requirements specified in this permit, shall be applied to the uncontrolled VOC and HAP Page 14 of 102 COLORADO Air Pollution Control Division Department of Public Health E. Environment Dedicated to protecting and improving the health and environment of the people of Colorado emissions. Compliance for Process 01 shall be based on the sum of VOC and HAP emissions from all inlets to the flare, including but not limited to, the sum of the cold flare header plus warm flare header. 18. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled C-211 101 Air -Fuel Ratio Controller and NSCR NOx, VOC, CO, a HAP LO 109 Enclosed Combustor VOC a HAP TANKS 110 Enclosed Combustor VOC &t HAP C250 113 Oxidation Catalyst CO, VOC, &t HAP C251 114 Oxidation Catalyst CO, VOC, &t HAP C252 115 Oxidation Catalyst CO, VOC, a HAP C253 116 Oxidation Catalyst CO, VOC, &t HAP C254 117 Oxidation Catalyst CO, VOC, Et HAP AM001 120 Still Vent: Routed to thermal oxidizer (TO) (Make Anguil, Model: 18714, SN: UCC 15-127). Routed to acid gas flare covered under point 123/0090/136 during TO downtime. VOC £t HAP Flash Tank: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/125 during 5% VRU downtime. D-931 122 Still Vent: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/125 during 2% VRU downtime. VOC Et HAP Flash Tank: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/125 during 2% VRU downtime. F-1 125 Open Flare VOC Et HAP Page 15 of 102 COLORADO Air Pollution Control Division Department of Pub€fc: Health & Envir nment Dedicated to protecting and improving the health and environment of the people of Colorado D-2 131 Still Vent: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/137 during 2% VRU downtime. VOC Ft HAP Flash Tank: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/137 during 2% VRU downtime. TANKS -2 134 Enclosed Combustor VOC a HAP F-2 136 Open Flare VOC Et HAP F-3 137 Open Flare VOC a HAP PROCESS LIMITATIONS AND RECORDS 19. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, Section II.A.4. ) Process Limits Facility Equipment ID AIRS Point Process Process Parameter Annual Limit Monthly Limit (31 days) C-211' 101 01 Consumption of natural gas as a fuel 1.78 MMSCF -- LO 109 01 Throughput of stabilized natural gas condensate 200,000 barrels --- 02 Combustion assist gas 10.51 MMSCF --- Combustion of pilot light fuel 0.42 MMSCF --- TANKS 110 01 Throughput of stabilized natural gas condensate 912,500 barrels --- C0170 111 01 Consumption of natural gas as a fuel 478.97 MMSCF --- 02 Ten minute turbine start-up event 21 events --- 03 Ten minute turbine shutdown event 21 events --- C0180 112 01 Consumption of natural gas as a fuel 478.97 MMSCF --- Page 16 of 102 COLORADO Air Pollution Control Division Department of Pubic Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 02 Ten minute turbine start-up event Ten minute turbine shutdown event 21 events 03 21 events C250 113 01 C251 114 01 C252 115 01 C253 116 01 C254 117 01 Consumption of natural gas as a fuel for all 5 compressor engines. 35,040 compressor engine - hours per year. 602.47 MMSCF total G1650 119 01 Consumption of natural gas as a fuel Ten minute turbine start-up event Ten minute turbine shutdown event 588.84 MMSCF 02 15 events 03 15 events G167O 01 Consumption of natural gas as a fuel Ten minute turbine start-up event Ten minute turbine shutdown event 588.84 MMSCF 02 15 events 03 15 events 120 AM001 Natural Gas Throughput 58,400 MMSCF 01 Combustion of still vent waste gas routed to the thermal oxidizer. 1,668.44 MMSCF Combustion of supplemental fuel and pilot fuel at the thermal oxidizer. 192.83 MMSCF 02 Combustion of flash tank waste gas routed to the plant flare (point 125) 3.21 MMSCF H776 121 01 Consumption of natural gas as a fuel 541.45 MMSCF D-931 122 01 Total Natural Gas Throughput 45,625 MMSCF 02 Natural Gas Throughput During VRU Downtime 912.5 MMSCF Page 17 of 102 H771 !COLORADO Air Pollution Control Division ceFia; tment of Public Health & Environment lent Dedicated to protecting and improving the health and environment of the people of Colorado 123 01 Consumption of natural gas as a fuel 216.91 MMSCF F-1 125 01 Combustion purge gas and gas routed to the flare during routine maintenance and blowdown activities. 30.28 MMSCF 02 Combustion of pilot light fuel Consumption of natural gas as a fuel Ten minute turbine start-up event Ten minute turbine shutdown event 1.32 MMSCF TURB-1 129 01 637.83 MMSCF 02 21 events 03 21 events TUR 132 131 01 02 Consumption of natural gas as a fuel Ten minute turbine start-up event Ten minute turbine shutdown event 637.83 MMSCF 21 events 03 21 events Total Inlet Wet Gas Throughput 83,950 MMSCF Still vent waste gas routed to and combusted by the open flare (point 137) Flash tank waste gas routed to and combusted by the open flare (point 137) 0.28 MMSCF 0.52 MMSCF HT -01 Consumption of natural gas as a fuel Consumption of natural gas as a fuel 80.09 MMSCF HT -02 133 01 266.97 MMSCF TANKS -2 134 01 Throughput of natural gas condensate Combustion of Amine Unit Still Vent Waste Gas during Thermal Oxidizer Downtime 912,500 barrels F-2 136 01 103.08 MMSCF 02 Combustion of assist fuel and purge gas Combustion of pilot light fuel. 26.60 MMSCF 1.18 MMSCF Page 18 of 102 Notes: COLORADO Air Pollution Control Division Qtbartrnent of Pubic Health & Ervirokunent Dedicated to protecting and improving the health and environment of the people of Colorado F-3 137 01 Combustion purge gas and gas routed to the flare via the cold header and warm header during routine maintenance and blowdown activities. 90.0 MMSCF 02 Combustion of pilot light fuel 1.71 MMSCF METHANOL 140 01 Methanol throughput 4,500 barrels 01 16" pig receiver blowdown event 54 02 24" pig receiver blowdown event 52 03 20" pig receiver blowdown event 94 04 12" pig receiver blowdown event 94 05 8" pig receiver blowdown event 282 6" pig receiver blowdown event 16" pig launcher blowdown event 376 07 54 08 24" pig launcher blowdown event 52 09 20" pig launcher blowdown event 94 1) Point 125: The open flare covered under point 125 will handle gas (inlet and residue) routed to the flare during standard operational process/normal operation of equipment (i.e. purge gas, maintenance activities and blowdown activities). In addition, gas will be routed to this flare during any events that qualify as a malfunction per the Colorado Common Provisions Regulation Section II.E and II.J. The process limit does not include gas routed to the flare during malfunction events or startup and shutdown events per the Colorado Common Provisions Regulation Section II.E and II.J. The process limit also does not include waste gas associated with the dehydrator (Point 122) still vent and flash tank routed to this flare during VRU downtime or the amine unit (point 120) flash tank waste gas routed to this flare during VRU downtime. 2) Point 137: The open flare covered under point 137 will handle gas (inlet and residue) routed to the flare during standard operational process/normal operation of equipment (i.e. purge gas, maintenance activities and blowdown activities). In addition, gas will be routed to this flare during any events that qualify as a malfunction per the Colorado Common Provisions Regulation Section II.E and II.J. The process limit does not include gas routed to the flare during malfunction events or startup and shutdown events per the Colorado Common Provisions Regulation Section II.E and II.J. The process limit also does not include waste gas associated with the dehydrator (Point 131) still vent and flash tank routed to this flare during VRU downtime. Page 19 of 102 Where: COLORADO Air Pollution Control Division Qepartn ent of Putatc Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado The owner or operator shall monitor monthly process rates based on the calendar month. Point 122: The volume of gas processed shall be measured by gas meter or by assuming the maximum design rate of the dehydrator unit of 125 MMscf/day. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 20. Point 109: For Process 02, upon installation of the flow meter(s), the owner or operator shall continuously (i.e., at least once every 15 minutes) monitor and record the volumetric flow rate of assist gas routed to the enclosed combustor using a flow meter(s). The flow meter(s) must be capable of accurately measuring and recording the maximum and minimum potential assist gas rates routed to the enclosed combustor. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit for Process 02 and to calculate emissions as described in this permit. 21. Points 101, 111, 112, 113-119, 121 £t 123: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas combusted as fuel for each listed emissions source using an operational continuous facility flow meter. The owner or operator shall use monthly throughput records and run time hours to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. The facility wide natural gas consumption shall' be measured on the same day that run time hours have been recorded. Allocation of natural gas to each listed emissions source shall be calculated using the following calculations: MMSCF) FCemissionunet ''Month ) Btu _ } HRemesseon unet (month) MMSCF) Btu Btu Btu Btu x FCtaciury ( month ) E HRturbine (,r ) HR (,rte) + E, HRheater (month + E HRother (month) hr Btu HRturbine/engine ( onth) - BSFC (hp tu •hr) x Hours of Operation (month) x Horsepower (hp) Btu HRheater (month) Btu hr = Design Heat Rating ( hr) x Hours of Operation (month) And: MMSCF FCemission unit = Individual Turbine, Engine, or Heater Fuel Consumption, Month Btu HR,ission unit = Individual Turbine, Engine, or Heater Heat Requirement, month Btu HRturbine = Individual Turbine Heat Requirement, month Btu HRengine = Individual Engine Heat Requirement, month Page 20 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Btu HRheater = Individual Heater Heat Requirement, month Btu HRother = Other Users Heat Requirement, month FCfacitity = Facility Fuel Consumption (metered), month MMSCF Btu BSFC = Brake Specific Fuel Consumption, hp hr ' 22. Points 111, 112, 118, 119, 129 £t 130: On a monthly basis, the owner or operator shall monitor and record the total number of turbine startup and shutdown events. By the end of each month, the total number of startup and shutdown events for the previous month's data shall be calculated, and a new twelve month total shall be calculated and recorded based on the previous twelve months' data. The owner or operator shall use monthly records to demonstrate compliance with the process limits and to calculate emissions as described in this permit. 23. Point 120: This unit shall be limited to the maximum lean amine recirculation pump rate of 640 gallons per minute. The lean amine recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Amine recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using amine flow meter(s), or recording strokes per minute and converting to circulation rate. (Regulation Number 3, Part B, Section II.A.4) 24. Point 120: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas processed by the amine unit contactor using an operational continuous flow meter at the inlet to the Mewbourn II natural gas processing train. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 25. Point 120: The owner or operator shall continuously monitor and record the volumetric flow rate of the following amine unit emission streams using continuous operational flow meters: • Process 01: Total amine unit still vent waste gas volume routed to the thermal oxidizer. • Process 01: Total supplemental fuel routed to the thermal oxidizer. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in the permit and to calculate emissions as described in this permit. 26. Point 120: Compliance with the process limit for Process 02 in this permit shall be determined by running the Promax model on a monthly basis using the most recent amine unit inlet extended gas analysis and recorded operational values, including inlet gas throughput, inlet gas temperature, inlet gas pressure, lean amine recirculation rate, lean amine concentration, flash tank temperature, flash tank pressure and VRU downtime. Recorded operational values, except for gas throughput and VRU downtime, shall be averaged on a monthly basis for input into Promax. The total volume of flash tank waste gas vented from the amine unit shall be obtained from the standard vapor volumetric flow of the "Flash Gas" stream in the ProMax simulation. Page 21 of 102 COLORADO 1 Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 27. Point 120: On a daily basis, the owner or operator shall monitor and record operational values including: inlet gas temperature, inlet gas pressure, flash tank temperature, and flash tank pressure. These records shall be kept according to the operating and maintenance plan for this point and shall be made available to the Division for inspection upon request. 28. Point 120: On a daily basis, the lean amine strength shall be measured and recorded. The lean amine strength is defined as the combined weight percent of MDEA and piperazine in the lean amine stream. Records of the concentration of amine in the lean amine stream shall be kept according to the operating and maintenance plan for this point and shall be made available to the Division for inspection upon request. 29. Point 120: For process 022 the owner or operator shall monitor and record VRU downtime for this emission point on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the amine unit flash tank is routed to the open flare (point 125) rather than the VRU. The total hours of VRU downtime, total volume of gas vented from the amine unit flash tank and total volume of gas vented from the amine unit flash tank during VRU downtime shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records and monthly records of gas vented from the amine unit flash tank to demonstrate compliance with the process and emission limits specified in this permit. 30. Point 120 £t 136: The owner or operator shall monitor and record thermal oxidizer (TO) downtime for this emission point on a daily basis. TO downtime shall be defined as times when the waste gas vented from the amine unit still vent is routed to the acid gas flare (point 136) rather than the TO. The total hours of TO downtime, total volume of gas vented from the amine unit still vent and total volume of gas vented from the amine unit still vent during TO downtime shall be recorded on a monthly basis. The owner or operator must use monthly TO downtime records and monthly records of gas vented from the amine unit still vent to demonstrate compliance with the process '` and emission limits specified in the permit. 31. Point 122: This unit shall be limited to the maximum lean glycol circulation rate of 28 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. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (Copt) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4) 32. Point 122 £t 131: On a daily basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure, wet gas inlet temperature and pressure and condenser outlet temperature. These records shall be maintained for a period of five years. 33. Point 122: The owner or operator shall monitor and record VRU downtime on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the glycol dehydrator flash tank and/or still vent is routed to the open flare rather than the VRU. The total hours of VRU downtime, total volume of gas processed and total volume of gas processed during VRU downtime shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records, monthly gas processing records, and the calculation methods established in Page 22 of 102 COLORADO Air Pollution Control Division Department'of Public Health a Errvirotunerrt Dedicated to protecting and improving the health and environment of the people of Colorado the Notes to Permit Holder to demonstrate compliance with the process and emission limits specified in this permit. 34. Point 125: For Process 01, upon installation of the low flow meter(s), the owner or operator shall continuously (i.e., at least once every 15 minutes) monitor and record the volumetric flow rate of gas routed to the flare, including, but not limited to, process gas, gas from routine maintenance and purge gas, using high flow and low flow meters. The flow meters must be capable of accurately measuring and recording the maximum and minimum potential flow rates routed to the flare. The operator shall assume a gas flow rate of 4,493 scfh for all times when the flare is operational but the flow meters are not functioning or collecting data. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit for Process 01 and to calculate emissions as described in this permit. 35. Point 125 £t 137: The owner or operator shall install, calibrate, operate and maintain each flow meter according to the manufacturer's procedures and specifications and the following requirements* Locate the meter in a position that provides a representative measurement of the total gas flow rate and install per manufacturer's recommendation. Use a flow sensor meeting an accuracy requirement of ±20 percent of the flow rate at velocities ranging from 0.1 to 1 feet per second and an accuracy of ±5 percent of the flow rate for velocities greater than 1 feet per second. Use a flow meter that is maintainable online, is able to continuously correct for temperature and pressure and is able to record flow in standard conditions (Standard conditions means a temperature of 293 K (68 °F) and a pressure, of 101.3 kilopascals (29.92 in Hg)) over one -minute averages. At least quarterly, perform a visual inspection of all components of the meter for physical and operational integrity and all electrical connections for oxidation and galvanic corrosion if the flow monitor is not equipped with a redundant flow sensor. e. Calibrate the flow meter initially and recalibrate the flow meter in accordance with the manufacturer's procedures and specifications at least biennially (every two years) or more frequently if specified by the manufacturer. 36. Point 129 Et 130: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas combusted as fuel for each turbine using an operational continuous flow meter at the inlet of each turbine. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 37. Point 131: The volume gas processed shall be measured by gas meter at the inlet of the dehydrator. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 38. Point 131: This unit shall be limited to the maximum lean glycol circulation rate of 40 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on Page 23 of 102 COLORADO Air Pollution Control Division uepartrT.3ent'of Public Health Snament Dedicated to protecting and improving the health and environment of the people of Colorado site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (Lopt) provisions under MACT HH. (Regulation Number 3, Part B, Section II.A.4) 39. Point 131: The owner or operator shall monitor and record VRU downtime on a daily basis. VRU downtime shall be defined as times when the waste gas vented from the glycol dehydrator flash tank and/or still vent is routed to the open flare rather than the VRU. The total hours of VRU downtime, total still vent and flash tank waste gas volume and total volume of still vent and flash tank waste gas routed to the open flare shall be recorded on a monthly basis. The owner or operator must use monthly VRU downtime records, monthly gas volume records, and the calculation methods established in the Notes to Permit Holder to demonstrate compliance with the process and emission limits specified in this permit. 40. Point 132 & 133: The owner or operator shall continuously monitor and record the volumetric flowrate of natural gas combusted as fuel for each heater using an operational continuous flow meter at the inlet of each heater. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit 41. Point 136: For process 01, the owner or operator shall continuously monitor and record the volumetric flow rate of waste gas vented from the amine unit still vent and routed to the flare using a continuous operational flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 42. Point 136: For Process 02, the owner or operator shall continuously (i.e., at least once every 15 minutes) monitor and record the volumetric flow rate of assist gas routed to the flare using an operational continuous flow meter. The flow meter must be capable of accurately measuring and recording the maximum and minimum potential assist gas rates routed to the flare. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit for Process 02 and to calculate emissions as described in this permit. 43. Point 136: For Process 02, the owner or operator shall monitor and record the rotameter throughput data (scf/hr) on a daily basis. This data shall be used to verify the purge rate. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit for Process 02 and to calculate emissions as described in this permit. 44. Point 137: For Process 01, the owner or operator shall continuously (i.e., at least once every 15 minutes) monitor and record the volumetric flow rate of gas routed to the flare, including, but not limited to, process gas, gas from routine maintenance and purge gas, using high flow and low flow meters. The flow meters must be capable of accurately measuring and recording the maximum and minimum potential flow rates routed to the flare. Each header to the flare, including, but not limited to, the cold flare header and warm flare header, shall be equipped with a high flow and low flow meters. The operator shall assume a gas flow rate of 2,782 scfh for each warm flare header and 3,596 scfh for each cold flare header for all times when the Page 24 of 102 COLORADO Air Pollution Control Division Department of Public Health & Envirortrtent Dedicated to protecting and improving the health and environment of the people of Colorado flare is operational but the flow meters are not functioning or collecting data. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit for Process 01 and to calculate emissions as described in this permit. Compliance for Process 01 shall be based on the sum of all inlets to the flare, including, but not limited to, the sum of the cold flare header volumetric flow rate plus the warm flare header volumetric flow rate. 45. Point 141: On a monthly basis, the owner or operator shall monitor and record the total number of blowdown events associated with each pig receiver and pig launcher. By the end of each month, the total number of events associated with each pig receiver and pig launcher 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. The owner or operator shall use monthly records to demonstrate compliance with the process limits and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 46. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 47. 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. (Regulation Number 1, Section II.A.1. Et 4.) 48. This source is subject to the odor requirements of Regulation enforceable) Reciprocating Internal Combustion Engines 49. Points 113-117: All new, modified or relocated (into the state) natural gas -fired reciprocating internal combustion engines are subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation Number 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: Number 2. (State only Maximum Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 Page 25 of 102 COLORADO Air Pollution Control Division Department of Public Health Environment Dedicated to protecting and improving the health and environment of the people of Colorado ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 50. Points 113, 114, 115, 116 a 117: This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation Number 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. Fugitive Emissions 51. Point 108 Ft 135: This source is subject to Regulation Number 7, Section XII.G.1 (State only enforceable). For fugitive volatile organic compound emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart OOOO (July 1, 2017) applies, regardless of the date of construction of the affected facility, unless subject to the LDAR program provided at 40 CFR Part 60, Subpart 0000a (July 1, 2017). 52. Point 135: The reciprocating compressors grouped with the fugitive emissions addressed by AIRS ID 135 are subject to the requirements of Regulation Number 7, Section XII.J.2 including, but not limited to the following: • XII.J.2.a Beginning January 1, 2018, the rod packing on reciprocating compressors located between the wellhead and the point of custody transfer to the natural gas transmission and storage segment must be replaced every 26,000 hours of operation or every thirty six (36) months. A reciprocating compressor located at a well ?production facility, or an adjacent well production facility and servicing more than one well production facility, is not subject to Section XII.J.2. XII.J.2.a(i) Owners or operators of reciprocating compressors located at a natural gas processing plant and constructed before January 1, 2018, must • XII.J.2.a.(i)(A) Begin monitoring the hours of operation starting January 1,2018; or • XII.J.2.a.(i)(B) Conduct the first rod packing replacement required under Section XII.J.2. prior to January 1, 2021. o XII.J.2.a.(ii) Owners or operators of reciprocating compressors located at a natural gas processing plant and constructed after January 1, 2018, must begin monitoring the hours or months of operation upon commencement of operation of the reciprocating compressor. • XII.J.2.c.(i) Owners or operators must maintain the following records for at least five (5) years and make records available to the Division upon request: o XII.J.2.c.(i)(A) Identification of each reciprocating compressor; o XII.J.2.c.(i)(B) The hours of operation or the number of months since the previous rod packing replacement, or a statement that emissions from the rod packing are being routed to a process through a closed vent system under negative pressure; Page 26 of 102 COLORADO Air Pollution Control Division Department of Rath=.c Heath Et Environment Dedicated to protecting and improving the health and environment of the people of Colorado o XII.J.2.c.(i)(C) The date of each rod packing replacement, or date of installation of a rod packing emissions collection system and closed vent system; o XII.J.2.c.(i)(D) Each cover and closed vent system inspection and any resulting responsive actions; and o XII.J.2.c.(i)(E) Each cover or closed vent system on the delay of inspection or repair list, the reason for and duration of the delay of inspection or repair, and the schedule for inspecting or repairing such cover or closed vent system. • XII.J.2.e. As an alternative to the emission control, inspection, repair, and recordkeeping provisions described in Sections XII.J.2.a. through XII.J.2.d., the owner or operator may comply with reciprocating compressor emission control, monitoring, recordkeeping, and reporting requirements of a New Source Performance Standard in 40 CFR Part 60 (November 16, 2017). Hydrocarbon Liquid Loading 53. Point 109: 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 must be conducted by submerged fill and emissions must be controlled by an enclosed flare. (Regulation Number 3, Part B, Section III.D.2.) I. D.2. ) 54. Point 109: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Regulation Number 3, Part B, III.E): The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. All compartment hatches at the facility (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. Inspections of all compartment hatches at the facility (including thief hatches) shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request 55. Point 109: 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. (Regulation Number 3, Part B, Section III.E.) Condensate Storage Tanks 56. Points 110 £t 134: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.17; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other Page 27 of 102 COLORADO Air Pollution Control Division Department of Public Health F.; Environment Dedicated to protecting and improving the health and environment of the people of Colorado convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 57. Points 110 Et 134: The storage tanks covered by this permit are subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 58. Points 110 £t 134: The storage tanks covered under this permit are subject to the recordkeeping requirements in Regulation Number 7, Section XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. • XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. • XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). • XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. • XVII.C.3.f. A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. Page 28 of 102 COLORADO Air Pollution Control Division Department of Pubiie Health &Envoori here Dedicated to protecting and improving the health and environment of the people of Colorado 59. Point 134: This source is subject to the New Source Performance Standards requirements of Regulation Number 6, Part A, Subpart Kb, Standards of Performance for Volatile Organic 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) o §60.112b(a) The owner or operator of each storage vessel with a....design capacity greater than or equal to 75 m3 but less than 151 m3 containing a VOL that, as stored, has a maximum true vapor pressure equal to or greater than 27.6 kPa but less than 76.6 kPa, shall equip each storage vessel with one of the following: • §60.112b(a)(3) A closed vent system and control device meeting the following specifications: • §60.112b(a)(3)(i) The closed vent system shall be designed to collect all VOC vapors and gases discharged from the storage vessel and operated with no detectable emissions as indicated by an instrument reading of less than 500 ppm above background and visual inspections, as determined in part 60, subpart W, §60.485(b). • §60.112b(a)(3)(ii) The control device shall be designed and operated to reduce inlet VOC emissions by 95 percent or greater. If a flare is used as the control device, it shall meet the specifications described in the general control device requirements (§60.18) of the General Provisions. §60.113b - Testing and procedures The owner or operator of each storage vessel as specified in §60.112b(a) shall meet the requirements of paragraph (a), (b), or (c) of this section. The applicable paragraph for a particular storage vessel depends on the control equipment installed to meet the requirements of §60.112b. • §60.113b(d) The owner or operator of each source that is equipped with a closed vent system and a flare to meet the requirements in §60.112b (a)(3) or (b)(2) shall meet the requirements as specified in the general control device requirements, §60.18 (e) and (f). o §60.115b - Reporting and recordkeeping requirements • §60.115b(d) After installing a closed vent system and flare to comply with §60.112b, the owner or operator shall meet the following requirements. • §60.115b(d)(1) A report containing the measurements required by §60.18(f) (1), (2), (3), (4), (5), and (6) shall be furnished to the Administrator as required by §60.8 of the General Provisions. This report shall be submitted within 6 months of the initial start-up date. • §60.115b(d)(2) Records shall be kept of all periods of operation during which the flare pilot flame is absent. Page 29 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado ■ §60.115b(d)(3) Semiannual reports of all periods recorded under §60.115b(d)(2) in which the pilot flame was absent shall be furnished to the Administrator. o §60.116b - Monitoring of operations • §60.116b(a) The owner or operator shall keep copies 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(g) The owner or operator of each vessel equipped with a closed vent system and control device meeting the specification of §60.112b or with emissions reductions equipment as specified in 40 CFR 65.42(b)(4), (b)(5), (b)(6), or (c) is exempt from the requirements of paragraphs (c) and (d) of this section. Turbines 60. Points 111, 112, 118, 119, 129 a !130: The combustion turbines are subject to the New Source Performance Standards requirements of Regulation Number 6, Part A, Subpart KKKK, Standards of Performance for Stationary Combustion Turbines including, but not limited to, the following: 40 CFR, Part 60, Subpart A - General Provisions §60.4320 - Nitrogen Oxide Emissions Limits o §60.4320 (a) - NOx emissions shaltnot 25 ppm at 15% 02 or 1.2 lb/MW-hr; §60.4330 - Sulfur Dioxide Emissions Limits o 660.4330 (a)(1) - S02 emissions shall not exceed 0.9 lb/MW-hr gross output; or o §60.4330 (a)(2) - Operator shall not burn any fuel that contains total potential sulfur emissions in excess of 0.060 lb 502/MMBtu heat input. • §60.4333 - General Requirements o §60.4333 (a) Operator must operate and maintain your stationary combustion turbine, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup, shutdown and malfunction. • §60.4340 - NO. Monitoring o §60.4340 (a) Operator shall perform annual performance tests in accordance with §60.4400 to demonstrate continuous compliance with NOx emissions limits. If the NOx emission result from the performance test is less than or equal to 75 percent of the NOx emission limit for the turbine, you may reduce the frequency of subsequent performance tests to once every 2 years (no more than 26 calendar months following the previous performance test). If the results of any subsequent performance test exceed 75 percent of the NOx emission limit for the turbine, you must resume annual performance tests. Page 30 of 102 COLORADO Air Pollution Control Division Department of Public Health F.; Environment Dedicated to protecting and improving the health and environment of the people of Colorado • §60.4365 (or §S60.4360 and 60.4370) - 502 Monitoring o The operator shall comply with §60.4365 or with both §§60.4360 and 60.4370 to demonstrate compliance with SO2 emissions limits. • §60.4375 - Reporting o §60.4375 (b) - For each affected unit that performs annual performance tests in accordance with §60.4340(a), you must submit a written report of the results of each performance test before the close of business on the 60th day following the completion of the performance test. • §S60.4400 and 60.4415 - Performance Tests o Annual tests must be conducted in accordance with §60.4400(a) and (b). o Unless operator chooses to comply with §60.4365 for exemption of monitoring the total sulfur content of the fuel, then initial and subsequent performance tests for sulfur shalt be conducted according to §60.4415. Amine Sweetening Unit 61. Point 120: This amine unit is subject to the New Source Performance Standards requirements of Regulation Number 6, Part A, Subpart LLL, Standards of Performance for Onshore Natural Gas Processing. SO2 Emissions, including, but not Limited to, the following: - 40 CFR, Part 60, Subpart A - General Provisions ' §60.640 - Applicability and Designation of Affected Facilities o §60.640(b) 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 §60.647(c) but are not required to comply with §560.642 through 60.646. • §60.647 - Record keeping and reporting Requirements o §60.647(c) - To certify that a facility is exempt from the control requirements of these standards, each owner or operator of a facility with a design capacity less that 2 LT/D of H2S in the acid gas (expressed as sulfur) shall keep, for the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. TEG Glycol Dehydrators 62. Point 122 Ft 131: These sources are subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators (Regulation Number 7, Section XII.B., XII.H., XII.H.5., and XII.H.6.); and • Ensure uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month Page 31 of 102 COLORADO Air Pollution Control Division Department of Public Health &Environment Dedicated to protecting and improving the health and environment of the people of Colorado basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 63. Points 122, 131, 125, £t 137: The open flares covered by under Points 125 and 137 have been approved as an alternative emissions control devices under Regulation Number 7, Section XVII.B.2.e. provided the following conditions are maintained: • The open flare will not be the primary destination for emissions from the still vent or flash tank. • The open flares must have no visible emissions during normal operations, as defined under Regulation Number 7, Section XVII.A.17, and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XVII.B.2.b.) • The open flare will be equipped with an operational auto -igniter upon installation of the combustion device (Regulation Number 7, Section XVII.B.2.d(i)). 64. Point 122 6t 131: This equipment : is subject to the control requirements for glycol natural gas dehydrators under Regulation Number 7, Section XVII.D. (State only enforceable). These requirements include, but are not limited to: XVII.D.3. Beginning may '1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95 percent on a rotting twelve-month basis through the use of a condenser or air pollution control equipment. If a combustion device is used, it shall have a ' design destruction efficiency of at least 98% for hydrocarbons. XVII.D.4. The control requirement in Section XVII.D.3. shall apply where: XVII.D.4.a. Uncontrolled actual emissions of VOCs from a glycol natural gas dehydrator constructed on or after May 1, 2015, are equal to or greater than two (2) tons per year. Such glycol natural gas dehydrators must be in compliance with Section XVII.D.3. by the date that the glycol natural gas dehydrator commences operation. XVII.D.4.b. Uncontrolled actual emissions of VOCs from a single glycol natural gas dehydrator constructed before May 1, 2015, are equal to or greater than six (6) tons per year, or two (2) tons per year if the glycol natural gas dehydrator is located within 1,320 feet of a building unit or designated outside activity area. 65. Point 122 Et 131: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH including but not limited to the following: (Regulation Number 8, Part E, Subpart A and HH) Area Source Page 32 of 102 COLORADO Air Pollution Control Division Department of Public Health & Envirorarnett Dedicated to protecting and improving the health and environment of the people of Colorado MACT HH Applicable Requirements Benzene emissions exemption §63.764 - General §63.764 (e)(1) - The owner or operator is exempt from the requirements Standards of paragraph (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)(ii) - 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(b) - Determination of glycol dehydration unit flowrate, benzene emissions, or BTEX emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate, benzene emissions, or BTEX emissions. §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 - Test §63.772(b)(2)(i) - The owner or operator shall determine actual average Methods, benzene emissions using the model GRI-GLYCaIc TM , Version 3.0 or Compliance higher, and the procedures presented in the associated GRI-GLYCaIc TM Procedures and Technical Reference Manual. Inputs to the model shall be representative Compliance of actual operating conditions of the glycol dehydration unit and may be Demonstration 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. Page 33 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 563.774- Recordkeeping Requirements 563.774 (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)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). Heaters 66. Points 121, 123 £t 133: These sources are subject to the New Source Performance Standards requirements of Regulation Number 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)). Acid Gas Flare 67. Point 136: 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 Number 1, Section II.A.5.) Open Flares 68. Points 125, 136 a 137: The flare shall be air -assisted and shall be designed and operated in accordance with the New Source Performance Standards requirements of Subpart A Section 560.18, General Control Device and Work Practice Requirements, including, but not limited to, the following: • §60.18(b) Flares. Paragraphs (c) through (f) apply to flares. • §60.18(c)(1) Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. • $60. 18(c)(2) Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f). • §60.18(c)(3) An owner/operator has the choice of adhering to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity specifications in paragraph (c)(4) of this section, or adhering to the requirements in paragraph (c)(3)(i) of this section. Page 34 of 102 COLORADO Air Pollution Control Division Department of Public Health f Environment Dedicated to protecting and improving the health and environment of the people of Colorado o §60.18(c)(3)(i)(A) Flares shall be used that have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent (by volume), or greater, and are designed for and operated with an exit velocity less than 37.2 m/sec (122 ft/sec) and less than the velocity, Vmax, as determined by the following equation: Vmax = (XH2-K1 )* K2 Where: Vmax = Maximum permitted velocity, m/sec. K1 = Constant, 6.0 volume -percent hydrogen. K2 = Constant, 3.9(m /sec)/volume-percent hydrogen. XH2 = The volume -percent of hydrogen, on a wet basis, as calculated by using the American Society for Testing and Materials (ASTM) Method D1946-77. (Incorporated by reference as specified in §60.17). O §60.18(c)(3)(i)(B) The actual exit velocity of a flare shall be determined by the method specified in paragraph (f)(4) of this section. o $60.18(c)(3)(ii) Flares shall be used only with the net heating value of the gas being combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam - assisted or air -assisted; or with the net heating value of the gas being combusted being 7.45 MJ/scm (200 Btu/scf) or greater if the flare is nonassisted. The net heating value of the gas being combusted shall be determined by the methods specified in paragraph (f)(3) of this section. §60.18(c)(5) Air -assisted flares shall be designed and operated with an exit velocity less than the velocity, Vmax, as determined by the method specified in paragraph (f)(6). §6018(c)(6) Flares used to comply with this section shall be steam=assisted, air - assisted, or nonassisted. • §60.18(d) Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators of flares shall monitor these control devices. • §60.18(e) Flares used to comply with provisions of this subpart shall be operated at all times when emissions may be vented to them. • §60.18(f)(1) Method 22 of appendix A to this part shall be used to determine the compliance of flares with the visible emission provisions of this subpart. The observation period is 2 hours and shall be used according to Method 22. • §60.18(f)(2) The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. • §60.18(f)(3) The net heating value of the gas being combusted in a flare shall be calculated using the following equation: • K G1H� f21 Page 35 of 102 COLORADO Air Pollution Control Division Department of Public He5tth a Environment Dedicated to protecting and improving the health and environment of the people of Colorado Where: HT = Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25 °C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20 °C; constant, I q molet4,11.7411 x 10 1p. ) sal} , kcal1 waere the standard temperature for (4 mole1 is 20`C scm C; = Concentration of sample component i in ppm on a wet basis, as measured for organics by Reference Method 18 and measured for hydrogen and carbon monoxide by ASTM D1946-77 or 90 (Reapproved 1994) (Incorporated by reference as specified in §60.17); and H, = Net heat of combustion of sample component i, kcal/g mole at 25 °C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809-95 (incorporated by reference as specified in §60.17) if published values are notavailable or cannot be calculated §60.18(f)(4) The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross sectional area of the flare tip. $60.180)(6) The maximum permitted velocity, Vmax. for air -assisted flares shall be determined by the following equation. Vmax = 8.706+0.7084 (HT) Vmax = Maximum permitted velocity, m/sec 8.706=Constant 0.7084=Constant HT = The net heating value as determined in paragraph (f)(3). Requirements Covering Multiple Sources 69. Points 111-112, 118-119, 121, 123, 129-130 £t 132-133: These sources are subject to the Particulate Matter and Sulfur Dioxide Emission Regulations of Regulation 1 including, but not limited to, the following (Regulation 1, Section III.A.1): a. No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel -burning equipment, particulate matter in the flue gases which exceeds the following (Regulation 1, Section III.A.1): (i) For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less than or equal to 500x106 BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. Page 36 of 102 COLORADO Air Pollution Control Division Department of Public: Heath & Environrrent Dedicated to protecting and improving the health and environment of the people of Colorado PE=0.5(FI)-a.26 Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. b. Emissions of sulfur dioxide shall not emit sulfur dioxide in excess of the following combustion turbine limitations. (Heat input rates shall be the manufacturer's guaranteed maximum heat input rates). (i) Points 111-112, 118-119 a 129-130: Combustion Turbines with a heat input of less than 250 Million BTU per hour: 0.8 pounds of sulfur dioxide per million BTU of heat input. (Regulation 1 Section VI.B.4.c) (ii) Points 121, 123, 132, a 133: Limit emissions to not more than two (2) tons per day of sulfur dioxide. (Regulation 1 Section VI.B.5.a.) 70. This source is located in an ozone non -attainment or attainment -maintenance area and subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, Section III.D.2.b. The following requirements were determined to be RACT for this source: Facility Equipment ID AIRS Point: RACT Pollutants C-211 101 Air -Fuel Ratio Controller and NSCR NOx, VOC FO 17 108 LDAR as provided. at 40 CFR Part 60 Subpart 0000a VAC LO 109 Submerged fill, Enclosed Combustor VOC TANKS 110 Enclosed Combustor VOC C0170 111 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC CO180 112 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC C250 113 Oxidation Catalyst VOC C251 114 Oxidation Catalyst VOC C252 115 Oxidation Catalyst VOC C253 116 Oxidation Catalyst VOC C254 117 Oxidation Catalyst VOC Page 37 of 102 COLORADO Air Pollution Control Division Department of Public Health EiErivirobmeot Dedicated to protecting and improving the health and environment of the people of Colorado G1650 118 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC G1670 119 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC AM001 120 Still Vent: Thermal Oxidizer (TO). Routed to acid gas flare covered under point 123/0090/136 during TO downtime. VOC Flash Tank: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/125 during 5% VRU downtime. H776 121 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC D-931 122 Still Vent: Recycled to plant inlet via VRU. Routed to plant flare covered under point 123/0090/125 during 2% VRU downtime. VOC Flash Tank: Recycled to plant inlet via VRU. Routed to plant flare covered under point 123/0090/125 during 2% VRU downtime. H771 123 ' Natural gas as fuel, low NOx burners, good combustion practices NOx, .VOC F-1 125 Installing and operating the flare according to 40 CFR 60.18 VOC TURB-1 129 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC TURB-2 130 Natural gas as fuel, low NOx burners, good combustion practices NOx, VOC D-2 131 Still Vent: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/137 during 2% VRU downtime. VOC Flash Tank: Recycled to plant inlet via VRU. Routed to open flare covered under point 123/0090/137 during 2% VRU downtime. HT -01 132 Natural gas as fuel, ultra low NOx burners, good combustion practices NOx, VOC HT -02 133 Natural gas as fuel, ultra low NOx burners, good combustion practices NOx, VOC TANKS -2 134 Enclosed Combustor VOC FUG -02 135 LDAR as provided at 40 CFR Part 60 Subpart 0000a VOC Page 38 of 102 COLORADO Air Pollution Control Division Department o Pt iie Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado F-2 136 Installing and operating the flare according to 40 CFR 60.18 VOC F-3 137 Installing and operating the flare according to 40 CFR 60.18 VOC PIG 141 Good Maintenance Practices VOC 71. Points 111-112, 118-119, 121, 123, 129-130 £t 132-133: These sources are subject to the New Source Performance Standards requirements of Regulation 6, Part B including, but not limited to, the following (Regulation 6, Part B, Section II): a. Standard for Particulate Matter - On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=O.5(FI)'°.26 Where: PE is the allowable particulate emission in pounds per million Btu heat input. Ft is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. Greater than 20 percent opacity. Standard for Sulfur Dioxide On and after the date on which the required performance test is competed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere sulfur dioxide in excess of: (i) Points 111-112, 118-119 Et 129-130: Sources with a heat input of less than 250 million Btu per hour: 0.8 lbs. 502/million Btu. 72. Points 108, 111, 112, 118, 119, 120, 121, 123, 125, 129, 130, Ft 133-137: These sources are subject to the requirements of Regulation Number 6, Part A, Subpart A, General Provisions, including, but not limited to, the following: a. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation 6, Part A. General Provisions from 40 CFR 60.11(d)) Page 39 of 102 COLORADO Air Pollution Control Division Department of Pubtc Health b Ervir: r,mert Dedicated to protecting and improving the health and environment of the people of Colorado 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. (S60.12) 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. Performance tests shall be conducted as required under §60.8. Compliance with opacity standards shall be demonstrated according to § 60.11. The flare shall be designed and operated, and records and reports shall be furnished, as required under §' 60.18. 73. Points 111-119, £t 121: This source is subject to Regulation Number 7, Section XVI.D. The operator shall comply with all applicable requirements of Section"XVI including but not limited to: XVI.D.1. Except as provided in Section XVI.D.2., the requirements of this Section XVI.D. apply to owners and operators of any stationary combustion equipment that existed at a major source of NOx as of June 3, 2016 located in the 8 -Hour Ozone Control Area. • XVI.D.4. Emission limitations. By October 1, 2021, no owner or operator of stationary combustion equipment may cause, allow or permit NOx to be emitted in excess of the following emission limitations. When demonstrating compliance using continuous emissions monitoring pursuant to Section XVI.D.5.a.(i), the following emission limitations are on a 30 -day rolling average basis. o Points 111-112 £t 118-119: XVI.D.4.b.(ii) Stationary combustion turbines with a maximum design heat input capacity equal to or greater than 10 MMBtu/hr and which commenced construction, modification or reconstruction after February 18, 2005 must comply with the applicable NOx emission limits in 40 CFR Part 60, Subpart KKKK (July 1, 2017). o Points 111-112 £t 118-119: XVI.D.4.b.(iii) Stationary combustion turbines subject to the categorical limits in Section XVI.D.4.b.(i) or (ii) above and stationary combustion turbines with a maximum design heat input capacity less than 10 MMBtu/hr must comply with the combustion process adjustment requirements contained in Section XVI.D.6. while burning gaseous fuel, liquid fuel, or any combination thereof, when required by Section XVI.D.6.a. Page 40 of 102 COLORADO Air Pollution Control Division Department of Public Health f, Enviror,o erzt Dedicated to protecting and improving the health and environment of the people of Colorado • Points 111-112 ft 118-119: XVI.D.5.a.(ii)(A) An owner or operator of a stationary combustion turbine subject to 40 CFR Part 60, Subparts GG or KKKK that has used and continues to use performance testing to demonstrate compliance with either Subpart GG or KKKK, as applicable, may use those performance testing procedures to demonstrate continued compliance with an applicable limitation contained in Section XVI.D.4.b., thereby satisfying the requirements of this section XVI.D.5.a.(ii). • XVI.D.6. Combustion process adjustment o XVI.D.6.a. As of January 1, 2017, this Section XVI.D.6. applies to boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx as of June 3, 2016. XVI.D.6.b.(i) When burning the fuel that provides the majority of the heat input since the last combustion process adjustment and when operating at a firing rate typical of normal operation, the owner or operator must conduct the following inspections and adjustments of boilers and process heaters, as applicable: XVI.D.6.b.(i)(A) Inspect the burner and combustion controls and clean or replace components as necessary. XVI.D.6.b.(i)(B) Inspect the flame pattern and adjust the burner or combustion controls as necessary to optimize the flame pattern.. XVI.D.6.b.(i)(C),Inspect the system controlling the air -to -fuel ratio and ensure that it is correctly calibrated and functioning properly. • XVI.D.6.b.(i)(D) Measure the concentration in the effluent stream of carbon monoxide and nitrogen oxide in ppm, by volume, before and after the adjustments in Sections XVI.D.6.b.(i)(A) through (C). Measurements may be taken using a portable analyzer. o XVI.D.6.b.(iii) The owner or operator of a stationary combustion turbine must conduct the following inspections and adjustments, as applicable: • XVI.D.6.b.(iii)(A) Inspect turbine inlet systems and align, repair, or replace components as necessary. • XVI.D.6.b.(iii)(B) Inspect the combustion chamber components, combustion liners, transition pieces, and fuel nozzle assemblies and clean, repair, or replace components as necessary. • XVI.D.6.b.(iii)(C) When burning the fuel that provides the majority of the heat input since the last combustion process adjustment and when Page 41 of 102 COLORADO Air Pollution Control Division Deeerto ent of Public Health £; £nvirortrmertt Dedicated to protecting and improving the health and environment of the people of Colorado operating at a firing rate typical of normal operation, confirm proper setting and calibration of the combustion controls. o XVI.D.6.b.(iv) The owner or operator of a stationary internal combustion engine must conduct the following inspections and adjustments, as applicable: • XVI.D.6.b.(iv)(A) Change oil and filters as necessary. • XVI.D.6.b.(iv)(B) Inspect air cleaners, fuel filters, hoses, and belts and clean or replace as necessary. • XVI.D.6.b.(iv)(C) Inspect spark plugs and replace as necessary. o XVI.D.6.b.(v) The owner or operator must operate and maintain the boiler, duct burner, process heater, stationary combustion turbine, or stationary internal combustion engine consistent with manufacturer's specifications, if available, or good engineering and maintenance practices. o XVI.D.6.b.(vi) Frequency XVI.D.6.b.(vi)(A) The owner or operator must conduct the initial combustion process adjustment by, April 1, 2017. An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 (November 17, 2016) or National Emission Standard for Hazardous ' Air Pollutants in 40 CFR Part 63 (November 17, 2016) to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017. • XVI.D.6.b.(vi)(A) The owner or operator must conduct subsequent combustion process adjustments at least once every twelve (12) months after the initial combustion adjustment, or on the applicable schedule according to Sections XVI.D.6.c.(1). or XVI.D.6.c.(ii). o XVI.D.6.c. As an alternative to the requirements described in Sections XVI.D.6.b.(i) through XVI.D.6.b.(v): • XVI.D.6.c(i) The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule; or • XVI.D.6.c(ii) The owner or operator of combustion equipment that is subject to and required to conduct a period tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 CFR Part 60 (November 17, 2016)or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (November 17, 2016) may conduct tune-ups or adjustments according to the schedule and Page 42 of 102 COLORADO Air Pollution Control Division Department of Public Health 5Environment Dedicated to protecting and improving the health and environment of the people of Colorado procedures of the applicable requirements of 40 CFR Part 60 (November 17, 2016) or 40 CFR Part 63 (November 17, 2016). • XVI.D.7. Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request: o XVI.D.7.a. The applicable emission limit and calculated heat input weighted emission limit for stationary combustion equipment demonstrating compliance for multiple fuels. o XVI.D.7.c. The type and amount of fuel used. o XVI.D.7.d. The stationary combustion equipment's annual capacity factor on a calendar year basis. o XVI.D.7.e. All records generated to contained in Section XVI.D.8. comply with the reporting requirements !, o XVI.D.7.f. For stationary combustion equipment subject to the combustion process adjustment requirements in Section XVI.D.6., the following recordkeeping requirements apply: XVI.D.7.f.(i) The owner or operator must create a record once every calendar year identifying, the combustion equipment at the source subject to Section XVI.D. and including for each combustion equipment: • XVI.D.7.f.(i)(A) The date of the adjustment; • XVI.D.7.f.(i)(B) Whether the combustion process adjustment under Sections XVI.D.6.b.(i) through XVI.D.6.b.(v) was followed, and what procedures were performed; • XVI.D.7.f.(i)(C) Whether a combustion process adjustment under Sections XVI.D.6.a. and XVI.D.6.b. was followed, what procedures were performed, and what New Source Performance or National Emission Standard for Hazardous Air Pollutants applied, if any; and • XVI.D.7.f.(i)(D) A description of any corrective action taken. • XVI.D.7.f.(i)(E) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule, the hours of operation. Page 43 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado • XVI.D.7.f.(i)(F) If multiple fuels are used, the type of fuel burned and heat input provided by each fuel. • XVI.D.7.f.(ii) The owner or operator must retain manufacturer recommended procedures, specifications, and maintenance schedule if utilized under Section XVI.D.6.a. for the life of the equipment. • XVI.D.7.f.(iii) As an alternative to the requirements described in Section XVI.D.7.f.(i), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 (November 17, 2016) or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (November 17, 2016). o XVI.D.7.g. All sources qualifying for an exemption under Section XVI.D.2. must maintain all records necessary to demonstrate that an exemption applies. XVI.D.8.b. For affected units demonstrating compliance with Section XVI.D.4 using performance testing pursuant to Section XVI.D.5.a.(ii)(C), the owner or operator must submit to the Division the following information: o XVI.D.8.b.(i) Performance test reports within 60 days after completion of the performance test program. All performance test reports must determine compliance with the applicable emission limitations set by Section 74. This source is subject to Regulation Number 7 Section XIX. The operator shall comply with all applicable requirements of Section XIX including but not limited to: • XIX.A. Stationary internal combustion engines at the following major sources must comply with applicable NOx emission limits and associated monitoring, recordkeeping, and reporting requirements in 40 CFR Part 60, Subpart 1111 (July 1, 2016), 40 CFR Part 60, Subpart JJJJ (July 1, 2016), and/or 40 CFR Part 63, Subpart ZZZZ (July 1, 2016) as expeditiously as practicable, but no later than January 1, 2017: o XIX.A.4. DCP Midstream, Kersey/Mewbourn (123-0090) - engine (pt 101). OPERATING £t MAINTENANCE REQUIREMENTS 75. Points 101, 109, 110, 113-117, 120, 122, 125, 131, 134 a 136-137: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) 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 the 0£tM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) 76. Point 109: The owner or operator of a loadout at which an enclosed combustor is used to control emissions shall: Page 44 of 102 COLORADO Air Pollution Control Division Department of Public Health a Ervirunmerb Dedicated to protecting and improving the health and environment of the people of Colorado a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks and route these vapors to the enclosed flare. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. 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. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 77. Point 111, 112, 118, 119, 129. ft 130: At all times during normal operation, the owner or operator shalt operate the turbine in SoLoNOx mode. On a daily basis, the owner or operator shall monitor and record the status of the SoLoNOx mode, including records of when the unit is not operating in SoLoNOx mode. These records shall be made available to the Division upon request. Normal operation shall be defined as all periods of operation except for startup, shutdown, or malfunction events. 78. Point 120: For process 01, the combustion chamber temperature of the thermal oxidizer used to control emissions from the amine unit still vent shall be greater than the combustion chamber temperature established during the most recent stack test of the equipment that was approved by the Division on a daily average basis. The approved daily average minimum operating temperature shall be achieved at all times that any amine unit emissions are routed to the thermal oxidizer in order to meet the emission limits in this permit. The combustion chamber temperature shall be measured and recorded at least once every hour. If the combustion chamber temperature value is measured more frequently than once per hour, the source shall record either each measured data value or each block average value for each 1 -hour period calculated from all measured data values during each period. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 79. Points 111, 112, 118, 119, 129 Et 130: The owner or operator shall complete the initial sampling for net heating value of the fuel used in the turbine as required by this permit within one hundred and eighty days (180) of the issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) f. Page 45 of 102 COLORADO Air Pollution Control Division Department of Pubtac Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 80. Point 120 £t 136: The owner or operator shall sample and complete an initial extended gas analysis of the amine unit still vent waste gas as required by this permit within one hundred and eighty days (180) of the issuance of this permit. This sample shall be analyzed for gross (higher) heat content and total VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4- trimethylpentane, hydrogen sulfide (H2S), methanol and methyl mercaptan content. The sample shall be collected prior to the inlet of the thermal oxidizer and prior to being combined with any other stream. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limitsThe owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. 81. Point 120: The owner or operator shall sample and complete an initial extended gas analysis of the amine unit flash tank waste gas as required by this permit within one hundred and eighty days (180) of the issuance of this permit. Each sample shall be analyzed for gross (higher) heat content and total VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4- trimethylpentane, hydrogen sulfide (H2S), methanol and methyl'mercaptari content. The sample shall be collected prior to the inlet of the plant flare (point 125) and prior to being combined with any other stream. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. 82. Point 120: The owner or operator shall complete the initial sampling for gross (higher) heating value of the supplemental fuel used in the thermal oxidizer using EPA approved methods within one hundred and eighty days (180) of the issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. 83. Point 125: For Process 01, the owner or operator shall complete an initial extended gas analysis of the gas routed to the plant flare within one hundred and eighty days (180) of the issuance of this permit. The sample shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. The sample shall be analyzed for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4- trimethylpentane, H2S, methanol and methyl mercaptan content using EPA approved methods. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. 84. Point 131: The owner or operator shall complete the initial extended wet gas analysis prior to the inlet of the TEG dehydration unit within one hundred and eighty days (180) of the issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the Page 46 of 102 COLORADO Air Pollution Control Division Department of Public Health $Envir,»rtertt Dedicated to protecting and improving the health and environment of the people of Colorado emission calculation results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 85. Point 133: A source initial compliance test shall be conducted on this heater to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained 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 (Regulation Number 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 86. Point 135: Within one hundred and eighty days (180) of the issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) 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. The operator shall submit the results of the extended gas analysis and emission calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. 87. Point 135: Within one hundred and eighty days (180) of the 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. 88. Point 137: For Process 01, the owner or operator shall complete the initial extended gas analyses of the gases routed via the cold header and warm header to the plant flare as required by this permit within one hundred and eighty days (180) of the issuance of this permit. The sample shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. The sample shall be analyzed for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content using EPA approved methods. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 89. Point 141: The owner or operator shall complete an initial site specific extended gas analysis ("Analysis") within one hundred and eighty days (180) of the issuance of this permit, whichever comes later, of the inlet gas vented during pig receiver blowdown events in order to verify the VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content (weight fraction) of this emission stream. Results of Page 47 of 102 COLORADO Air Pollution Control Division Department of Public Health & Enviroronen€ Dedicated to protecting and improving the health and environment of the people of Colorado the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/blowdown event) using Division approved methods. Results of the Analysis shall be submitted to the Division as part of the self - certification and must demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). 90. Point 141: The owner or operator shall complete an initial site specific extended gas analysis ("Analysis") within one hundred and eighty days (180) of the issuance of this permit, whichever comes later, of the residue gas vented during pig launcher blowdown events in order to verify the VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/blowdown event) using Division approved methods. Results of the Analysis shall be submitted to the Division as part ofthe self - certification and must demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). Periodic Testing Requirements 91. Point 101 This engine is subject to the periodic testing requirements as specified in the operating and maintenance (OEtM) 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. 92. Point 108 Et 135: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 93. Point 109: On an annual basis, the owner/operator shall complete a site specific extended gas analysis ("Analysis") of the assist gas routed to the enclosed combustor used to control emissions from this source. Each sample shall be analyzed for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, and 2,2,4- trimethylpentane content using EPA approved methods. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF) using Division approved methods. Results of the Analysis must demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Page 48 of 102 COLORADO Air Pollution Control Division Department of Public Health & Ervironment Dedicated to protecting and improving the health and environment of the people of Colorado Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). 94. Point 111, 112, 118, 119, 129 ft 130: These turbines are subject to the periodic testing requirements of 40 C.F.R. Part 60, Subpart KKKK, as referenced in this permit. 95. Point 111, 112, 118, 119, 129 Et 130: Replacements of these units completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment B. 96. Point 111, 112, 118, 119, 129 Et 130: The owner or operator shall conduct, at a minimum, quarterly portable analyzer monitoring of each turbine exhaust outlet emissions of nitrogen oxides (NOr) and carbon monoxide (CO) to monitor compliance with the emissions limits for Process 01 - Steady-state Turbine emissions. The source may perform a stack test per the following condition in Lieu of portable analyzer testing. Results of all tests conducted shall be kept on site and made available to the Division upon request. 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. 97. Point 111, 112, 118, 119, 129 Et 130: The owner or operator shall measure the emission rate(s) from each turbine for Process 01 - Steady-state Turbine Emissions for the pollutants listed below at least once every 12 months in order to demonstrate compliance with the emissions limits' contained in this permit. Periodic testing shall be conducted within 12 months of the prior test with a minimum period of at least one hundred and eighty (180) days apart. In the event it is not feasible to conduct a test at a minimum of at least one hundred and eighty (180) days apart, a written explanation shall be submitted with the test protocol describing the reasons the testing could not be conducted one hundred and eighty (180) days apart. 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 (Regulation Number 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods Carbon Monoxide using EPA approved methods. 98. Point 101, 111, 112, 118, 119, 129 Et 130: The net heating value of the fuel used shall be sampled and analyzed, at a minimum, once per every three months with consecutive samples taken at least two months apart using EPA approved methods. If sampling is performed more often, the quarterly average results of all valid fuel analyses shall be used in the emission calculations. Page 49 of 102 COLORADO Air Pollution Control Division Department of Pubic; Heath b£rvironment Dedicated to protecting and improving the health and environment of the people of Colorado 99. Point 120 £t 136: At a minimum frequency of once per every three months, the owner or operator shall sample and complete an extended gas analysis of the amine unit still vent waste gas. Consecutive samples shall be taken at least two months apart. Each sample shall be analyzed for gross (higher) heat content and total VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4-trimethylpentane, hydrogen sulfide (H2S), methanol and methyl mercaptan content. The sample shall be collected prior to the inlet of the thermal oxidizer and prior to being combined with any other stream. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify compliance with the emission limits. If the amine unit is not operated during the entire three month period, sampling is not required. 100. Point 120: At a minimum frequency of once per every three months, the owner or operator shall sample and complete an extended gas analysis of the amine unit flash tank waste gas. Consecutive samples shall be taken at least two months apart. Each sample shall be analyzed for gross (higher) heat content and total VOC, benzene, toluene, ethylbenzene, xylene, n - Hexane, 2,2,4-trimethylpentane, hydrogen sulfide (H2S), methanol and methyl mercaptan content. The sample shall be collected prior to the inlet of the plant flare (point 125) and prior to being combined with any other stream. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify compliance with the emission limits. If the amine unit is not operated during the entire three month period, sampling is not required. 101. Point 120: The gross (higher) heating value of the supplemental fuel used in the thermal oxidizer shalt be sampled and analyzed, at a minimum, once per everythreemonths with consecutive samples taken at least two months apart using EPAapproved methods. if sampling is',performed more often, the quarterly average results of all valid fuel analyses shall be used in the emission calculations. 102. Point 120 £t 136: The owner or operator shall complete an extended sour gas analysis prior to the inlet of the amine unit on a monthly basis. Results of the sour gas analysis shall be used for the sour gas inlet in the process model used to determine the total volume of flash tank waste gas vented from the amine unit per this permit. 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: S02 Emissions (§60.640(b)). 103. Point 120: The operator shall measure the emission rates) for Process 01 - Still Vent Routed to thermal oxidixer (TO) for the pollutants listed below at least once every 12 months in order to demonstrate compliance with the emissions limits contained in this permit. Periodic testing shall be conducted at a minimum of at least one hundred and eighty (180) days apart. The natural gas throughput, lean amine circulation rate, MDEA concentration, sulfur content of sour gas entering the amine unit, thermal oxidizer supplemental fuel rate and thermal oxidizer combustion zone temperature shall be monitored and recorded during this test. 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 testes conducted to show compliance with a monthly or annual emission limitation shall have the rults projected up to the monthly or annual Page 50 of 102 COLORADO Air Pollution Control Division Department of Public Health& Err iro; zr. gent Dedicated to protecting and improving the health and environment of the people of Colorado averaging time by multiplying the test results by the allowable number of operating hours for that averaging time. (Regulation Number 3, Part B., Section III.G.3) Sulfur Dioxide using EPA approved methods Oxides of Nitrogen using EPA approved methods Volatile Organic Compounds using EPA approved methods Carbon Monoxide using EPA approved methods 104. Point 122 Et 131: The owner or operator shall complete an extended wet gas analysis prior to the inlet of each TEG dehydrator 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 and be provided to the Division upon request. 105. Point 125: For Process 01, the owner or operator shall complete an extended gas analysis of the gas routed to the plant flare on a weekly basis. The sample shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. Each sample shall be analyzed for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, "' methanol and methyl mercaptan content using EPA approved methods. The weekly heat content and stream composition results shall be averaged on a monthly basis to calculate emission as specified in this permit. 106. Point 136: On an annual basis, the owner/operator shall complete a site specific extended gas analysis ("Analysis") of the assist gas and purge gas routed to. this acid gas ' flare. Each sample shall be analyzed for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content using EPA approved methods. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF) using Division approved methods. Results of the Analysis must demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). 107. Point 137: For Process 01, the owner or operator shall complete an extended gas analysis of the gas in each header routed to the plant flare including, but not limited to, the cold flare header and warm flare header. The sample shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. The owner or operator shall collect a sample from each header routed to the plant flare on a weekly basis. Each sample shall be analyzed for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content using EPA approved methods. The weekly heat content and stream composition results shall be averaged on a monthly basis to calculate emission as specified in this permit. Page 51 of 102 COLORADO Air Pollution Control Division Department crf Public Health w-EnvirQrl rent Dedicated to protecting and improving the health and environment of the people of Colorado 108. Point 141: On an annual basis, the owner or operator shall complete a site specific extended gas analysis ("Analysis") of the inlet gas vented during pig receiver blowdown events in order to verify the VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/blowdown event) using Division approved methods. Results of the Analysis must be used to demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). 109. Point 141: On an annual basis, the owner or operator shall complete a site specific extended gas analysis ("Analysis") of the residue gas vented during pig launcher blowdown events in order to verify the VOC, benzene, toluene, ethylbenzene, xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, methanol and methyl mercaptan content (weight fraction) of this emission stream. Results of the Analysis shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in ' units of lb/blowdown event) using Division approved methods. Results of the Analysis must be used to demonstrate the emissions factors established through the Analysis are less than or equal to, the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). ALTERNATE OPERATING SCENARIOS 110. Points 122 Et 131: The electric glycol pump may be replaced with another electric glycol pump in accordance with the requirements of Regulation Number 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. The maximum glycol recirculation rate of a replacement pump shall not exceed the glycol recirculation rate as authorized in this permit. 111. Points 122 Et 131: The owner or operator shall maintain a log on -site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 112. Points 122 a 131: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 113. All previous versions of this permit are cancelled upon issuance of this permit. 114. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, Section II.C) Page 52 of 102 a. COLORADO Air Pollution Control Division Deprtrhent of Public: Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of V0C or N0,t per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: f the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. Whenever there is a change in the owner or operator of any facility, process, or activity; or Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or Whenever a permit limitation must be modified; or No later than 30 days before the existing APEN expires. Within 14 calendar days of commencing operation of a permanent replacement engine or turbine under the alternative operating scenario outlined in this ! permit as Attachment A or ' B. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine or turbine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine or turbine. Submittal of an updated APEN is also required for replacement of components if such replacement results in a change of serial number. 115. Point 125 £t 137: The owner or operator shall maintain the following records for a period of 5 years: a. b. C. d. e. f. Operating hours for the flare. Volume of gas routed to flare. Gas sampling. Flow meter accuracy. Records of flow meter visual inspection and any adjustments made. Initial and recalibration results for the flow meter and any adjustments made. Page 53 of 102 9. COLORADO Air Pollution Control Division Department of Public Health & £riirorsmerrt Dedicated to protecting and improving the health and environment of the people of Colorado All records required by this permit shall be retained for not less than 5 years following the date of such measurements, maintenance, and reports. 116. Minimum stack heights are required for the following points: Facility ID AIRS Point Minimum stack height (ft) 123/0090 101 16.48 111 35.80 112 35.80 113 45.00 114 45.00 115 45.00 116 45.00 117 45.00 118 45.00 121 123 20.00 20.00 Emergency Flare 75.00 117. This source is subject to the provisions of Regulation Number 3, Part C, Operating Permits (Title V of the 1990 Federal Clean Air Act Amendments). The provisions of this construction permit must be incorporated into the operating permit. The application for the modification to the Operating Permit is due within one year from permit issuance.' 118. Points 111, 112, 118, 119, 129 Et 130: MACT Subpart YYYYNational Emission Standards for Hazardous Air Pollutants for Stationary Combustion Turbines requirements shall apply to this source at any such time that this source becomes a major source of hazardous air pollutants (HAP) solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable '° requirements of that Subpart on the -- date as stated in the rule as published in the Federal Register. (Regulation Number 8, Part E) 119. Point 108, 122, 131, Et 135: MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Regulation Number 8, Part E) 120. Points 121, 123, 132 Et 133: MACT Subpart DDDDD - National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters requirements shall apply to this source at any such time that this source becomes a major source of hazardous air pollutants (HAP) solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Regulation Number 8, Part E) 121. The requirements of Colorado Regulation Number 3, Part D shall apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August Page 54 of 102 COLORADO Air Pollution Control Division Department of Pubic Health & Envi; onrnent Dedicated to protecting and improving the health and environment of the people of Colorado 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Regulation Number 3, Part D, Section VI.B.4/V.A.7.B). With respect to this Condition, Part D requirements may apply to future modifications if emission limits are modified to equal or exceed the following threshold levels. Increases in permit limits for any of these emissions units will require evaluation of the original project net emissions increase to ensure the significant modification thresholds are not exceeded: Facility Equipment ID AIRS Point Equipment Description Pollutant Emissions - tons per year Threshold Current Limit C-211 101 SI RICE 40 40 38.91 32.71 LO 1O9 Condensate Loadout TANKS 110 Condensate Tank C0170 111 Combustion Turbines NOx VOC C0180 112 G1650 118 Combustion Turbines G1670 119 AM001 120 Amine Unit D-931 122 TEG Dehydrator F-1 125 Open Flare TURB-1 129 Combustion Turbines TURB-2 130 D-2 131 TEG Dehydrator HT -01 132 Regeneration Heater HT -02 133 Hot Oil Heater TANKS -2 134 Condensate Tank Page 55 of 102 COLORADO Air Pollution Control Division Department of Public Health &-Environment. Dedicated to protecting and improving the health and environment of the people of Colorado F-2 136 Acid Gas Flare F-3 137 Open Flare TK-6200, 10A, 21A/21B 138 Produced Water Storage Vessels METHANOL 140 Methanol Tank PIG 141 Pig launcher and receiver blowdowns APEN Exempt Sources Notes: • The produced water storage vessels (permit exempt source) and APEN exempt sources do not have permit limits. However, the PTE of these sources is still considered in the project increase when evaluating PSD and NANSR. GENERAL TERMS AND CONDITIONS 122. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 123. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 124. 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. 125. 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. Page 56 of 102 COLORADO Air Pollution Control Division Department of Public Health E Environment. Dedicated to protecting and improving the health and environment of the people of Colorado 126. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 127. 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. 128. 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. Harrison Slaughter, P.E. Permit Engineer Issuance Date Description Initial Approval December 29, 2009 Initial Approval. Synthetic Minor Modification of a Major Source. Public comment conducted to render the permit and permit conditions federally enforceable. Issued to DCP Midstream, LP. Upon startup under this permit, all previously issued permits for this facility will be canceled. Issuance 1 June 21, 2011 Modification to 5 source points: Point 109 (condensate loadout): decrease in permit limit and change of control device from a condenser to a combustor with 95% control efficiency; Point 110 (condensate tank battery): decrease in permit limit and change of control device Page 57 of 102 COLORADO Air Pollution Control Division Department of Pia)lic: He?vial & Erviroime t Dedicated to protecting and improving the health and environment of the people of Colorado from a condenser to a combustor with 95% control efficiency; Point 120 (amine sweetening unit): increase processing rate from 125 mmscfd to 160 mmscfd and increase amine recirculation rate gpm 540 gpm to 640 gpm; Point 122 (TEG dehydrator): increasing the lean glycol recirculation rate from 26.8 gpm to 34.9 gpm, re-routing the flash tank from the RTO to the existing VRU unit, and raising the flash tank temperature from 110°F to 190°F; and Point 124 (thermal oxidizer): increase in NOx and CO permit limits and adding SOx emissions. Issuance 2 June 28, 2012 Modification to 13 points; 104-107: Increase permit limits to reflect 0.5g/hp-hr VOC and 1.5g/hp-hr CO. 113-117: Increase permit limits to reflect 0.7g/hp-hr VOC default factor from Regulation 7. 120: update emissions to reflect change in destruction efficiency of Thermal Oxidizer from 99% to 96.7%. Add H2S limit. 122: update emissions to reflect change in destruction efficiency of Thermal Oxidizer from 99% to 96.7% 123: update to allow a second/backup heater to be used during downtime. 124: update destruction efficiency to 96.7% from 99%. Increase SOx limit. Issuance 3 October 21, 2016 Removal of Points 104, 105 and 107. Combining Points 118 and 119 under one AIRS ID (Point 118). Point 108: Increase permit limits from 31.7 TPY to 50.8 TPY. Point 120: Additional process to equipment downtime for RTO. The RTO to control Point 120 only. Point 122: Addition of its own control device (Point 125). No change in emissions. Addition of points 125 and 127. Removing Point 124 from permit because emissions from this point have been distributed among individual emission sources. Page 58 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Issuance 4 Issuance 5 July 14, 2017 Issue to DCP Operating Company, LP Company name change application was received by the Division on May 25, 2017. Cancel points 102, 103, 106 upon startup of new Mewbourn III Natural Gas Processing Train. Point 109: Increase permitted throughput from 476,190 bbl/year to 912,500 bbl/year. Point 110: Increase permitted throughput from 476,190 bbl/year to 912,500 bbl/year. Update emissions factors. Point 118: Split two turbines covered under this point into two separate points. Include separate process and emission limits for points 118 and 119. Point 119: Increase operating hours to 8,76( hours per year. Point 120: Change control scenario for still vent. Still vent is now controlled primarily by a thermal oxidizer (TO). During TO downtime still vent emissions are routed to=a flare (point 136). Still vent emissions are°,no longer vented to atmosphere. Point 122: Utilize GlyCalc to estimate emissions. Update control scenario so bot;:flash tank and still vent emissions are recycled to the plant inlet by a VRU or controlled by an open flare (point 125) during VRU downtime (max 2% annually). Addition of points 129-137 for Mewbourn III expansion project. This Issuance Issued to DCP Operating Company, LP Point 101: Decrease operating hours from 8760 to 720. Update throughput and emission limits. Remove Points 102, 103 a 106 from the permit. These engines were cancelled and removed from the facility. Points 108 Et 135: Update the component counts. Update control efficiencies based on compliance with NSPS 0000a LDAR requirements. Point 109: Decrease permitted throughput from 912,500 bbl/year to 200,000 bbl/year. Include Page 59 of 102 COLORADO Air Pollution Control Division Department of Pobifc Health & Environ tent Dedicated to protecting and improving the health and environment of the people of Colorado limit on pilot light and assist gas combustion. Point 111-112 £t 118-119: Increase process limit. Include start-up and shutdown emission and process limits. Update periodic testing. Point 120: Increase supplemental fuel from 149.84 MMscf/year to 192 MMscf/year. Update ongoing compliance demonstration. Point 125: Increase permitted limit from 9.09 MMscf/year to 30.28 MMscf/year. Include limit on pilot light combustion. Remove Point 127 from the permit. Emissions from this source are now accounted for under point 120. Points 129 £t 130: Include start-up and shutdown process Et emission ' limits. Update periodic testing. Update emission and process limits based on manufacturer specifications. Point 131: Add N0x and CO emission limits. Add process limits on combustion of still vent and flash tank waste gas. Point 133: Update emission limits and emission factors. Limit heat input rate from 40.8 MMBtu/hr to 32.0 MMBtu/hr. Point 136: Increase still vent waste gas routed to the flare from 65.37 MMscf/year to 103.08 MMscf/year. Increase TO downtime from 13 days to 20.5 days. Increase combustion of assist fuel and purge gas from 17.21 MMscf/year to 26.60 MMscf/year. Point 137: Increase permitted limit from 15.63 MMscf/year to 90.0 MMscf/year. Include limit on pilot light combustion. Add points 140 £t 141 for Mewbourn III expansion project. Page 60 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https: //www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) Formaldehyde 50000 " 39 10 101 Acetaldehyde 75070 6 3 Acrolein 107028 5 3 Methanol 67561 6 3 Benzene 71432 3 2 Toluene 108883 1 1 Ethylbenzene 100414 0.1 0.1 Xylene 1330207 1 1 1,3 -Butadiene 106990 2 1 108 Benzene 71432 880 63 Toluene 108883 690 49 Ethylbenzene 100414 17 2 Xylenes 1330207 121 9 Page 61 of 102 111 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado n -Hexane 110543 3917 278 2,2,4-TMP 540841 44 3 Hydrogen Sulfide 7783064 16 1 Methanol 67561 12 1 Methyl Mercaptan (MeSH) 74931 19 2 109 1 0 Benzene 71432 538 27 Toluene 108883 1,491 75 Ethylbenzene 100414 111 6 Xylenes 1330207 1,127 57 n -Hexane 110543 4,066 204 2,2,4-TMP 540841 3 1 Benzene 71432 1,005 51 Toulene 1 08883 2,784 140 Ethylbenzene 100414 208 11 Xytenes 1330207 106 n -Hexane 110543 5,406 271 2,2,.4-TMP 540841 1 Formaldehyde 50000 312 312 Acetaldehyde 75070 18 18 Acrolein 107028 3 3 Benzene 71432 6 6 Toluene 108883 57 57 Ethylbenzene 100414 14 14 Xylenes 1330207 28 28 1,3 -Butadiene 106990 1 1 112 Formaldehyde 50000 312 312 Acetaldehyde 75070 18 18 Acrolein 107028 3 3 Benzene 71432 6 6 Toluene 108883 57 57 Ethylbenzene 100414 14 14 Page 62 of 102 COLORADO Air Pollution Control Division Department of Public Hiealth & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Xylenes 1330207 28 28 1,3 -Butadiene 106990 1 1 113- 117 Total Formaldehyde 50000 73,200 7,360 Acetaldehyde 75070 5,200 2,600 Acrolein 107028 3,200 1,600 Benzene 71432 240 120 Formaldehyde 50000 383 383 Acetaldehyde 75070 22 22 Acrolein 107028 4 4 Benzene 71432 7 7 1,3 -Butadiene 106990 1 1? Ethylbenzene 100414 18 18 Toluene 108883 71 71 Xylenes 1330207 35 35 Formaldehyde 50000 383 383 Acetaldehyde 75070 22 Acrolein 107028 4 Benzene 71432 7 1,3 -Butadiene 106990 1 Ethylbenzene 100414 18 18 Toluene 108883 71 71 Xylenes 1330207 35 35 120 Benzene 71432 164,641 5,201 Toluene 108883 127,227 4,051 Ethylbenzene 100414 2,451 78 Xylenes 1330207 25,859 832 n -Hexane 110543 4,406 29 2,2,4-TMP 540841 19 1 Hydrogen Sulfide 7783064 34,591 1,139 Methanol 67561 25,733 849 Methyl Mercaptan (MeSH) 74931 1,820 53 Page 63 of 102 COLORADO Air Pollution Control Division Department of Public Health E -Environment Dedicated to protecting and improving the health and environment of the people of Colorado 121 Benzene 71432 1 1 Toulene 108883 2 2 Formaldehyde 50000 41 41 n -Hexane 110543 975 975 122 Benzene 71432 136,415 137 Toluene 108883 129,275 130 Ethylbenzene 100414 2,475 3 Xylenes 1330207 43,242 44 n -Hexane 110543 17,785 18 2,2,4-TMP 540841 32 1 Hydrogen Sulfide 7783064 361 1i 123 Benzene .' 71432 1 1 Toulene 108883 1 1 Formaldehyde 50000 16 16 n -Hexane 110543 390 390 Benzene 71432 30 Toulene 108883 23 Ethylbenzene` 100414 1 Xylenes 1330207' 80 4 n -Hexane 110543 3,850 195 2,2,4-TMP 540841 29 2 Hydrogen Sulfide 7783064 10 1 Methanol 67561 8 1 Methyl Mercaptan (MeSH) 74931 13 1 129 Formaldehyde 50000 412 412 Acetaldehyde 75070 24 24 Acrolein 107028 4 4 Benzene 71432 7 7 1,3 -Butadiene 106990 1 1 Ethylbenzene 100414 19 19 Toluene 108883 76 76 Page 64 of 102 COLORADO Air Pollution Control Division Department of Public Heath & Erkvirorunenf Dedicated to protecting and improving the health and environment of the people of Colorado Xylenes 1330207 37 37 130 Formaldehyde 50000 412 412 Acetaldehyde 75070 24 24 Acrolein 107028 4 4 Benzene 71432 7 7 1,3 -Butadiene 106990 1 1 Ethylbenzene 100414 19 19 Toluene 108883 76 76 Xylenes 1330207 37 37 Benzene 71432 300,524 301 131 Toluene 108883 287,235 288 n -Hexane 110543 111,566 112 Hydrogen Sulfide 7783064 83 1 132 133 Formaldehyde 50000 6 6 Benzene 71432 1 1 Toluene 108883 1 n -Hexane 110543 145 145 Formaldehyde 50000 21 Benzene 71432 1 Toluene 108883 1 1 n -Hexane 110543 495 495 134 Benzene 71432 978 49 Toluene 108883 2,709 136 Ethylbenzene 100414 202 10 Xylene 1330207 2,047 103 n -Hexane 110543 5,259 263 2,2,4-TMP 540841 4 1 135 Benzene 71432 900 71 Toluene 108883 1,280 101 Ethylbenzene 100414 142 11 Xylene 1330207 423 34 n -Hexane 110543 19,575 1,536 Page 65 of 102 137 140 COLORADO Air Pollution Control Division Departmeni cif Public Health b.Ervirarirnent Dedicated to protecting and improving the health and environment of the people of Colorado 2,2,4-TMP 540841 865 68 136 Benzene 71432 8,819 441 Toluene 108883 6,873 344 Ethylbenzene 100414 133 7 Xylenes 1330207 1,413 71 n -Hexane 110543 2,998 152 Hydrogen Sulfide 7783064 1,938 97 Methanol 67561 1,444 73 Methyl Mercaptan (MeSH) 74931 89 5 Benzene 71432 1,123 57 Toluene 108883 881 44 Ethylbenzene !. 100414 22 1 Xylenes 1330207 155 8 n -Hexane 110543 10,945 551 2, 2,4-TMP 540841 3 Hydrogen Sulfide 7783064 1 Methanol 67561 1 Methyl Mercaptan (MeSH) 7493 24 2 Methanol 67561 501 501 141 Benzene 71432 22 22 Toluene 108883 17 17 Ethylbenzene 100414 1 1 Xylenes 1330207 3 3 n -Hexane 110543 177 177 2,2,4-TMP 540841 1 1 Hydrogen Sulfide 7783064 1 1 Methanol 67561 1 1 Methyl Mercaptan (MeSH) 74931 1 1 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. Page 66 of 102 COLORADO Air Pollution Control Division Departrnent'of Public Health &Environment Dedicated to protecting and improving the health and environment of the people of Colorado 5) The emission levels contained in this permit are based on the following emission factors: Point 101: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors - g/bhp-hr NOx 3.638 13.0 4.48x10"1 1.6 CO 3.638 13.0 4.48x10"1 1.6 VOC 8.68x10"1 3.1 2.8x10"i 1.0 Note: Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7,878 Btu/hp-hr, a site -rated horsepower value of 330, and a fuel heat value of 1,050 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer. VOC Manufacturer Manufacturer Point. 108: Component Gas Service Gas Control % Light Oil Light Liquid Control Connectors 8,912 81 6,971 81 Flanges 4,090 81 2,283 81 Open-ended Lines 2 75 --- Pump Seals - 47 88 Valves 4,417 96 3,261 95 Other* 23 75 3 75 Relief Valves 174 96 107 95 VOC Content (wt. %) 22.77% --- 100% --- Benzene Content (wt. %) 0.0555% --- 0.2437% --- Toluene Content (wt. %) 0.0435% --- 0.1911% --- Ethylbenzene (wt. %) 0.0011% --- 0.0046% --- Xylenes Content (wt. %) 0.0076% --- 0.0335% --- n-Hexane Content (wt. %) 0.247% --- 1.0848% --- 2,2,4-TMP Content (wt. %) 0.0028% --- 0.0121% --- Methanol Content (wt. %) 0.0007% --- 0.0033% --- Hydrogen Sulfide Content (wt. %) 0.001% --- 0.0042% --- Methyl Mercaptan Content (wt. %) 0.0012% --- 0.0051% --- *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents T0C Emission Factors (kg/hr-component): Page 67 of 102 COLORADO Air Pollution Control Division Department of Public: Health f Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 Relief Valves 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Table 2-4 Note that the emission limits included in this permit are derived by multiplying the emissions resulting from the component counts in the table above by a factor of 1.1 to. accommodate other minor changes to the facility and to provide a conservative estimate of facility -wide emissions. 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 extended gas analysis. Point 109: Process 01: Throughput of stabilized natural gas condensate CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 6.52x10-4 6.52x10"4 TNRCC CO 2.6x10"3 2.6x10"3 TNRCC VOC 2.023x10"1 1.012x10"2 AP -42 71432 Benzene 2.689x10-3 1.344x10"4 Mass Balance 108883 Toluene 7.45x10-3 3.726x10"4 Mass Balance 1330207 Xylene 5.63x10-3 2.816x10-4 Mass Balance 110543 n -Hexane 1.447x10-2 7.234x10-4 Mass Balance Note: The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.0032 psia M (vapor molecular weight) = 66 lb/lb-mot T (temperature of liquid loaded) = 512.45 °R Page 68 of 102 COLORADO Air Pollution Control Division Dvpa; tment ci Public Health f; Er viroOrner L Dedicated to protecting and improving the health and environment of the people of Colorado 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. The mass fractions of each NCRP were obtained from the Mewbourn extended natural gas liquid analysis obtained on March 11, 2009. Controlled emission factors are based on an enclosed combustor efficiency of 95%. The NOx and CO emissions factors (EF) in the table above are based on the TNRCC Technical Supplement 4 emissions factors of 0.138 lb/MMBtu and 0.5496 lb/MMBtu respectively. The emissions factors from TNRCC were converted to units of lbs/bbl using a waste gas heating value of 3,397 Btu/scf and a gas -to -oil ratio (GOR) of 1.391 scf/bbl. An example of this calculation is as follows: EFNOx /0.138 MMBtu 1 * /33 fMMsctu\ * 1,000,000 scf * 1MMscf (1391 bb1 cf) _ 0.0006) 52 lb NOx Actual emissions are calculated by multiplying the emission factors in the table above by the recorded condensate throughput. Process 02: Pilot light and Assist Gas Combustion For combustion of assist gas the following emission factors and calculation methodologies shall be used to calculate actual emissions: CAS # Weight Fraction of Gas (%) Pollutant Emission Factors Uncontrolled lb/MMscf Emission Factors Controlled lb/MMscf Source NOx 150.7 150.7 TNRCC CO 600.16 600.16 7.46 VOC 3601.96 180.1 Gas Analysis 110543 0.231 n -Hexane 111.44 5.57 Note: The uncontrolled VOC and HAP emissions were calculated using a residue gas sample obtained from the Mewbourn Natural Gas Processing Plant on March 29, 2017. The controlled VOC and HAP emission factors are based on the enclosed combustor control efficiency of 95%. The NOx and CO emission factors from the TNRCC Technical Supplement 4 (0.138 lb/MMBtu and 0.5496 lb/MMBtu respectively) were converted to units of lb/MMscf using a heating value of 1,092 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the total metered volume of assist gas routed to the enclosed combustor. Until flow meter installation, assist gas shall be assumed to be routed to the enclosed combustor at a constant rate of 1,200 scf/hr. For combustion of pilot light gas the following emission factors and calculation methodologies shall be used to calculate actual emissions: Page 69 of 102 71432 COLORADO Air Pollution Control Division Department of Public health & Enviro m feral Dedicated to protecting and improving the health and environment of the people of Colorado CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source N0x 102.94 102.94 AP -42 Chapter 1 Table 1.4-1 CO 86.47 86.47 AP -42 Chapter 1 Table 1.4-1 V0C 5.66 5.66 AP -42 Chapter 1 Table 1.4-2 n -Hexane 1.85 1.85 AP -42 Chapter 1 Table 1.4-3 Note: The emission factors in the table above are based on a higher heat value of 1,050 Btu/scf. The flare pilot light flow rate shall be assumed to have a constant flow rate of 48 scf/hr. Monthly pilot gas throughput shall be, determined by multiplying the total pilot light flow rate (48 scf/hr) by the enclosed combustor monthly hours of operation. Actual emissions are calculated by multiplying the emission factors in the table above by the total pilot gas throughput. Total actual emissions are obtained from the sum of emissions resulting from the condensate loadout process and combustion of waste gas (process 01) and the combustion of pilot light gas and assist', gas (process 02). Point 110: Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Emission Factors Controlled lb/BBL Condensate Throughput Source V0C Benzene 8.28x10"2 1.1x10"3 4.14x10"3 5.5x10"5 Tanks 4.0.9d Mass Balance 108883 Toluene 3.05x10"3 1.52x10"4 1.15x10-4 2.96x10-4 Mass Balance 1330207 Xylenes 2.3x10"3 Mass Balance 110543 n -Hexane 5.92x10-3 Mass Balance Note: The controlled emissions factors for point 110 are based on the enclosed combustor control efficiency of 95%. 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. The mass fractions of each NCRP were obtained from the Mewbourn extended natural gas liquid analysis obtained on March 11, 2009. Page 70 of 102 COLORADO Air Pollution Control Division Departrlent'of Public Health & Er: ironmerct Dedicated to protecting and improving the health and environment of the people of Colorado Points 111, 112: Process 01: Turbine emissions during steady state operations: CAS Pollutant Emission Factors - Uncontrolled Source lb/MMBtu PPM at 15% O2 PM2.5 6.6x10-3 --- AP -42 Chapter 3 Table 3.1-2a PM10 6.6x1O3 --- AP -42 Chapter 3 Table 3.1-2a NOx 5.98x10"2 15 Manufacturer CO 6.07x102 25 Manufacturer VOC 2.1x10"3 --- AP -42 Chapter 3 Table 3.1-2a 50000 Formaldehyde 7.1x10-4 --- AP -42 Chapter 3 Table 3.1-3 Note: Emission factors are based on a heat input rate of 50.09. MMBtu/hr, a lower fuel heat value of 916.1 Btu/scf and 8,760 hours of operation a year. Actual emissions shall be calculated by multiplying the lb/MMBtu emission factors in the table above by the actual net (lower) heat value from the most recent quarterly heat content sample and the most recent monthly metered fuel gas volume. Process 02: Turbine start-up emissions CAS Pollutant Emission Factors - Uncontrolled Source lb/event NOx 1.0 Manufacturer CO 86.0 Manufacturer VOC 22.0 Manufacturer Note: The manufacturer provided emission factors for turbine start-ups are based on 10 minute start-up events. Actual emissions shall be calculated by multiplying the emission factor in the table above by the recorded number of turbine start-up events. Process 03: Turbine shutdown emissions CAS Pollutant Emission Factors - Uncontrolled Source lb/event NOx 1.0 Manufacturer CO 79.0 Manufacturer VOC 18.0 Manufacturer Note: The manufacturer provided emission factors for turbine shutdowns are based on 10 minute shutdown events. Actual emissions shall be calculated by multiplying the emission factor in the table above by the recorded number of turbine shutdown events. Points 113, 114, 115, 116 and 117: CAS Pollutant Emission Factors - Uncontrolled Uncontrolled EF Source Emission Factors - Controlled Controlled EF Source NOx 0.5 g/hp-hr Manufacturer g/hp-hr NA CO 2.74 g/hp-hr Manufacturer 0.1918 g/hp-hr Manufacturer + 93% control Page 71 of 102 COLORADO Air Pollution Control Division Deppartrnent of Pubic Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado CAS Pollutant Emission Factors - Uncontrolled Uncontrolled EF Source Emission Factors - Controlled Controlled EF Source VOC 1.03 g/hp-hr Manufacturer 0.7 CDPHE default 50000 Formaldehyde 0.40 g/hp-hr Manufacturer 0.04 g/hp-hr Manufacturer + 90% control 75070 Acetaldehyde 0.0084 lb/mmbtu AP -42 0.0014 lb/mmbtu AP -42 + 50% control 107028 Acrolein 0.0051 lb/mmbtu AP -42 0.0013 lb/mmbtu AP -42 + 50% control 71432 Benzene 0.0004 lb/mmbtu AP -42 0.0008 lb/mmbtu AP -42 + 50% control Point 118 and 119: Process 01: Turbine emissions during steady state operations: !' CAS Pollutant Emission Factors - Uncontrolled lb/MMBtu PPM at 15% 02 Source PM2.5 6.6x10-3 6.6x10"3 AP -42 Chapter 3 Table 3.1-2a AP -42 Chapter 3 Table 3.1-2a PM10 NOx 5.98x10-2 6.07x10-2 Manufacturer CO 25 Manufacturer VOC 2.1x10-3 7.1x10"4 AP -42 Chapter 3 Table 3.1-2a 50000 Formaldehyde AP -42 Chapter 3 Table 3.1-3 Note: Emission factors are based on a heat input rate of 61.58 MMBtu/hr, a lower fuel heat value of 916.1 Btu/scf and 8,760 hours of operation a year. Actual emissions shall' be calculated by multiplying the lb/MMBtu emission factors in the table above by the actual net (lower) heat value from the most recent quarterly heat content sample and the most recent monthly metered fuel gas volume. Process 02: Turbine start-up emissions CAS Pollutant Emission Factors - Uncontrolled Source lb/event NOx 1.0 Manufacturer CO 78.0 Manufacturer VOC 13.0 Manufacturer Note: The manufacturer provided emission factors for turbine start-ups are based on 10 minute start-up events. Actual emissions shall be calculated by multiplying the emission factor in the table above by the recorded number of turbine start-up events. Process 03: Turbine shutdown emissions CAS Pollutant Emission Factors - Uncontrolled Source lb/event NOx 1.0 Manufacturer CO 77.0 Manufacturer Page 72 of 102 COLORADO Air Pollution Control Division Department of Pubic Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado CAS Pollutant Emission Factors - Uncontrolled Source lb/event VOC 10.0 Manufacturer Note: The manufacturer provided emission factors for turbine shutdowns are based on 10 minute shutdown events. Actual emissions shall be calculated by multiplying the emission factor in the table above by the recorded number of turbine shutdown events. Point 120: Process 01: Still Vent Waste Gas Routed to the Thermal Oxidizer Emissions for Process 01 include venting of acid gas (amine unit still vent overhead), combustion of acid gas (amine unit still vent overhead) and combustion of supplemental fuel and pilot light fuel by the thermal oxidizer. Controlled still vent acid gas emissions: Actual VOC, HAP, H2S and methyl mercaptan (MeSH) emissions from venting of still vent acid gas to the TO shall be calculated based on the most recent waste gas sampling of the still vent acid gas stream and most recent monthly waste gas flow volume of the still vent acid gas stream routed to the thermal oxidizer. Controlled VOC, HAP, H2S and methyl mercaptan (MeSH) emissions are based on a thermal oxidizer control efficiency' of 96.7%. The following equation shall be used, in conjunction with the sample and flow volume data, to calculate actual emissions: VOC/HAPwaste Gas VOC1HAP concentration (wt %) r scf 100 x Still Vent Waste Gas f month) lb x Gas Sample Molecular Weight ' " ,379 scf x 1— 96.7% control ff �lbmol) \lbmol) ( *VOC/HAP/H2S/MeSH concentration and gas sample molecular weight are based on actual sampled values of the amine unit still vent waste gas stream. *Still vent waste gas is the actual measured monthly flow volume of the amine unit still vent routed to the TO. TO combustion of still vent acid gas: Actual emissions resulting from the combustion of the acid gas (still vent acid gas stream) are calculated using the following emission factors, the most recent quarterly acid gas stream gross (higher) heat content, and most recent monthly volume of total acid gas (still vent acid gas stream) routed to the TO. CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source NOx 0.138 TCEQ CO 0.31 AP -42 Chapter 13.5 Note: Permitted combustion emissions are based on a gross (higher) heating value of 14.085 Btu/scf. SO2 emissions resulting from the combustion of H2S and methyl mercaptan (MeSH) in the acid gas (still vent acid gas stream) are based on a mass balance assuming 64 lb S02/lb-mol, 34 lb H2S/lb- Page 73 of 102 COLORADO Air Pollution Control Division Department of PublicHeafth ,Environment Dedicated to protecting and improving the health and environment of the people of Colorado mol, and 48 lb MeSH/lb-mol. 5O2 emissions are also based on the assumption that 100% of the H2S and MeSH in the acid gas is converted to SO2. The following calculation demonstrates the mass balance: HZS tonsl 61 b4 lb SOZI ( lb — mol 11 +uMeSH tonsl (64 lb SOZI ( lb — mol SO2 (tpy) _ [( year / * \ lb — moll * \34 lb HZS/J + R year / * \ lb — mol I * \48l lb MeSH TO combustion of supplemental fuel and pilot fuel: Actual emissions from combustion of supplemental fuel and TO pilot light are calculated using the following emission factors, the most recent quarterly supplemental fuel heat content, most recent monthly volume of supplemental fuel volume routed to the TO, and most recent monthly volume of fuel to the TO pilot lights. The TO pilot gas throughput shall be assumed to have a constant value of 0.1 MMBtu/hr (95.24 scf/hr). Monthly pilot gas throughput shall be determined by multiplying this hourly pilot gas throughput by the TO monthly hours of operation. CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source SOx. 5..88x10"4 AP -42 Table 1.4-2 NOx 0.138 TCEQ CO 0.31 AP -42 Chapter 13.5 VOC 5.39x103 AP -42 Table 1.4-2 Note: Permitted combustion emissions are based on a gross (higher) heating value of 1,050 Btu/scf. Total actual emissions for process 01 are based on the sum of controlled still vent acid gas emissions plus TO combustion of acid gas plus TO combustion of supplemental fuel and pilot fuel. Process 02: Flash Tank Waste Gas Routed to the Plant Flare (Point 125) During VRU Downtime Emissions for Process 02 include venting of flash tank emissions to the plant flare (point 125) during VRU downtime and combustion of waste gas (flash tank emissions'during VRU downtime). Page 74 of 102 COLORADO Air Pollution Control Division Department of Public Heatth & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Controlled flash tank emissions during VRU downtime: Actual VOC, HAP, H2S and methyl mercaptan (MeSH) emissions from venting of flash tank emissions during VRU downtime shall be calculated based on the most recent gas sampling of the flash tank waste gas stream during VRU downtime and most recent monthly gas flow volume of the flash tank waste gas stream routed to the plant flare (point 125) during VRU downtime. Controlled VOC, HAP, H2S and methyl mercaptan (MeSH) emissions are based on a plant flare control efficiency of 95%. The following equation shall be used, in conjunction with the sample and flow volume data, to calculate actual emissions: VOC/HAPwaste Gas _ VOC/NAP concentration (wt %) scf 100 x Flash Tank Waste Gas (month) lb \ cf x Gas Sample Molecular Weight (' 379 (lbmo Ibmol I l I x (1 — 95% control) *VOC/HAP/H2S/MeSH concentration and gas sample molecular weight are based on actual sampled values of the amine unit flash tank waste gas stream. *Flash tank waste gas is the actual total flow volume of the amine unit flash tank routed to the plant flare obtained from the standard vapor volumetric flow of the "Flash Gas" stream in the ProMax simulation that is run on a monthly basis. Plant flare combustion of flash tank waste gas: Actual emissions resulting from the combustion of the flash tank waste gas (flash tank waste gas during VRU downtime) are calculated using the following emission factors, the most recent quarterly flash tank waste gas gross, (higher) heat content, and most recent monthly volume of total flash tank waste gas (flash tank waste gas during VRU downtime) routed to the plant flare (point 125). CAS # Pollutant Uncontrolled : Emission Factors lb/MMBtu Source NOx 0.068 AP -42 Chapter 13.5 CO 0.31 AP -42 Chapter 13.5 Note: Permitted combustion emissions are based on a gross (higher) heating value of 1227.72 Btu/scf. Page 75 of 102 COLORADO Air Pollution Control Division Department of Public Health & Envirorttnent Dedicated to protecting and improving the health and environment of the people of Colorado SO2 emissions resulting from the combustion of H2S and methyl mercaptan (MeSH) in the flash tank waste gas (flash tank waste gas during VRU downtime) are based on a mass balance assuming 64 lb S02/lb-mol, 34 lb H2S/lb-mol, and 48 lb MeSH/lb-mol. 502 emissions are also based on the assumption that 100% of the H2S and MeSH in the flash tank waste gas (flash tank waste gas during VRU downtime) is converted to S02. The following calculation demonstrates the mass balance: H2S tonsl (64 lb SO2l ( lb — mol 11 f (MeSH tons) (64 lb SO2) mol ll SOZ(tpy) — [( year / * \lb — moll * \34 lb HZS)i + R year / * \lb — moll * \48 lb MeSH Total actual emissions for process 02 are based on the sum of controlled flash tank waste gas emissions (flash tank waste gas during VRU downtime) plus plant flare combustion of flash tank waste gas during VRU downtime. Points 121 and 123: CAS Pollutant Emission Factors - Uncontrolled Uncontrolled EF Source NOx 30 lb/mmscf Manufacturer CO 84 lb / mmscf AP -42 VOC 5.5 lb/mmscf mmscf AP -42 Point 122: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Actual controlled emissions are based on a ' 100% control efficiency when emissions are routed to the VRU and a 95% control efficiency when emissions are routed to an open flare during VRU downtime (max 2% annually). To determine actual emissions during VRU downtime, the operator will multiply tb/hr emission results from the monthly GlyCalc model (based on the total actual gas throughput during the month) by the total hours of VRU downtime. A 95% control efficiency will be applied to this calculation based on the destruction efficiency of the flare. The operator will determine the actual monthly gas throughput during VRU downtime using the following equation: (Total Gas Throughput, MMscf VRU Downtime, hrs (Total Monthly Hours, hrs) Gas TkroughputvReDowntime = * / Month Month Month Point 125: Emissions associated with the open flare result from the combustion of maintenance gas (inlet and residue), purge gas (residue), and pilot light gas. Total actual emissions are based on the sum of the emissions calculated for the combustion of maintenance gas and purge gas (process 01) and the combustion of pilot light gas (process 02). This open flare will handle gas (inlet and residue) routed to the flare during standard operational process/normal operation of equipment (i.e. maintenance and blowdown activities). The process limit does not include gas routed to the flare during malfunction events or startup and shutdown events per the Colorado Common Provisions Regulation Section II.E and II.J. The process limit also does not include waste gas associated with the dehydrator (Point 122) still vent and flash tank routed to this flare during Page 76 of 102 COLORADO Air Pollution Control Division Department of P.cblic Health & Envirotanent Dedicated to protecting and improving the health and environment of the people of Colorado VRU downtime and waste gas associated with the amine unit (point 120) flash tank routed to the this flare during VRU downtime. Process 01: Combustion of routine maintenance and blowdown gas (residue and inlet) and purge gas CAS # Pollutant Emission Factors Uncontrolled lb/MMBtu Source NOx 0.068 AP -42 Chapter 13.5 CO 0.31 AP -42 Chapter 13.5 Note: Combustion emissions are calculated using the emission factors in the table above, the most recent monthly flare gas higher heat content and the volume of total gas combusted. Actual VOC, HAP, H2S and methyl mercaptan emissions shall be calculated based on the most recent gas sampling and most recent monthly gas flow volume. Controlled emissions are based on 95% control for VOC, HAP, H2S and methyl mercaptan. Actual VOC, HAP, H2S and methyl mercaptan emissions are calculated using the following equations: Equation for Actual VOC Emissions Calculations: lb VOC (l _ VOC concentration (wt %) _ 100 x Purge 'Process Gas ( sc monthmonth x Gas Molecular Weight lb • 379 Scf l x 1— 95% control) (lbmol) ^ (lbmol) ( ) *VOC concentration and Gas Molecular Weight are based on actual monthly -average sampled values of the gas streams routed to flare. The gas sample shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. *Purge/Process Gas is the actual measured monthly flow volume of the gas routed to flare. Equation for Actual HAP Emissions Calculations: HAP (month) = HAP concentration (wt %) _ 100 x Purge/Process Gas (month) x Gas Molecular Weight (lbmoll 379 (lbmoll x (1 — 95% control) *HAP concentration and Gas Molecular Weight are based on actual monthly -average sampled values of the gas streams routed to flare. The gas sample shall be representative of all gases routed to the flare, including routine maintenance gases when applicable. *Purge/Process Gas is the actual measured monthly flow volume of the gas routed to flare. Page 77 of 102 COLORADO Air Pollution Control Division Department of Public Health u& Environment Dedicated to protecting and improving the health and environment of the people of Colorado Process 02: Combustion of pilot light fuel CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Source N0x 102.94 AP -42 Chapter 1 Table 1.4-1 CO 86.47 AP -42 Chapter 1 Table 1.4-1 V0C 5.66 AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.85 AP -42 Chapter 1 Table 1.4-3 Note: The emission factors in the table above are based on a higher heat value of 1,050 Btu/scf. The flare pilot light flow rate shall be assumed to have a constant flow rate of 150 scf/hr. Monthly pilot gas throughput shall be determined by multiplying the total pilot light flow rate (150 scf/hr) by the flare monthly hours of operation. Actual emissions are calculated by multiplying the emission factors in the table above by the total pilot gas throughput. Point 129 and 130:. Process 01: Turbine emissions during steady state operations::. CAS Pollutant Emission Factors - Uncontrolled lb/MMBtu PPM at 15% 02 Source PM2.5 PM�a 6.6x10-3 6.6x10"3 AP -42 Chapter 3 Table 3.1-2a AP -42 Chapter 3 Table 3.1-2a N0x 5.19x1 0"2 6.07x1'0-2 13 Manufacturer Manufacturer CO 25 V0C 2.1x10-3 7.1x10-4 AP -42 Chapter 3 Table 3.1-2a 50000 Formaldehyde AP -42 Chapter 3 Table 3.1-3 Note: Emission factors are based on a heat input rate of 66.12 MMBtu/hr, a lower fuel heat value of 908.1 Btu/scf and 8,760 hours of operation a year. Actual emissions shall be calculated by multiplying the lb/MMBtu emission factors in the table above by the actual net (lower) heat value from the most recent quarterly heat content sample and the most recent monthly metered fuel gas volume. Process 02: Turbine start-up emissions CAS Pollutant Emission Factors - Uncontrolled Source lb/event N0x 1.0 Manufacturer CO 88.0 Manufacturer V0C 18.0 Manufacturer Page 78 of 102 COLORADO Air Pollution Control Division ? Department of Public Health -& Environment Dedicated to protecting and improving the health and environment of the people of Colorado Note: The manufacturer provided emission factors for turbine start-ups are based on 10 minute start-up events. Actual emissions shall be calculated by multiplying the emission factor in the table above by the recorded number of turbine start-up events. Process 03: Turbine shutdown emissions CAS Pollutant Emission Factors - Uncontrolled Source lb/event NOx 1.0 Manufacturer CO 62.0 Manufacturer VOC 8.0 Manufacturer Note: The manufacturer provided emission factors for turbine shutdowns are based on 10 minute shutdown events. Actual emissions shall be calculated by multiplying the emission factor in the table above by the recorded number of turbine shutdown events. Point 131; Theemission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Actual controlled VOC, H2S and HAP emissions are based on a 100% control efficiency when emissions are routed to the VRU and a 95% control efficiency when emissions are routed to an open flare during VRU downtime. The VRU has a maximum of 2% annual downtime. To determine actual emissions during VRU downtime, the operator will multiply lb/hr emission results from the monthly GlyCalc model (based on the total actual gas throughput during the month) by the total hours of VRU downtime. A 95% control efficiency will be applied to this calculation based on the destruction efficiency of the flare. The VOC, H2S and HAP flash tank waste gas emission rates (lb/hr) are obtained from the "Flash Tank Off Gas" stream in the GlyCalc model. The VOC, H2S and HAP still vent waste gas emission rates (lb/hr) are obtained from the "Uncontrolled Regenerator Emissions" stream in the GlyCalc model. Combustion Emissions: Total actual NOx and CO emissions are based on the sum of the emissions for the still vent and flash tank controlled by the open flare during VRU downtime. Actual volume of waste gas combusted shall be based on the monthly GlyCalc report streams described in the notes beneath each table. Actual heat content of the waste gas stream shall be calculated monthly based on the GlyCalc report streams described in the notes beneath each table. Total combustion emissions are based on the following emission factors: Still Vent Controlled by the ECD: CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source NOx 0.068 AP -42 Chapter 13.5 Industrial Flares CO 0.31 Note: The permitted combustion emissions are based on a still vent waste gas heating value of 1,537.1 Btu/scf. Actual emissions are calculated based on the heat content and waste gas flow rate from the "Condenser Vent Stream" in the most recent monthly GlyCalc report and the hours per month the still vent waste gas is routed to the open flare. The heat content is calculated on a monthly basis using the composition of the "Condenser Vent Stream" in the most recent monthly GlyCalc report and the higher heating value of each component. Page 79 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Flash Tank Controlled by the ECD: CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source NOx 0.068 AP -42 Chapter 13.5 Industrial Flares CO 0.31 Note: The permitted combustion emissions are based on a flash tank waste gas heating value of 1,445.4 Btu/scf. Actual emissions are calculated based on the heat content and waste gas flow rate from the "Flash Tank Off Gas Stream" in the most recent monthly GlyCalc report and the hours per month the flash tank waste gas is routed to the open flare. The heat content is calculated on a monthly basis using the composition of the "Flash Tank Off Gas Stream" in the most recent monthly GlyCalc report and the higher heating value of each component. Point 132: CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Source NOx 50 AP -42 Chapter 1 Table 1.4-1 CO 84 AP -42 Chapter 1 Table 1.4-1 Note: Emission factors are based on a rated heat input of 9.6 MMBtu/hr, a higher heating value of 1,050 Btu/scf and 8,760 hours of operation a year. Point 133: CAS # Pollutant Emission Factors Uncontrolled ` lb/MMscf Source! PM10 7.82 AP -42 Chapter 1 Table 1.4-2 PM2.5 7.82 AP -42 Chapter 1 Table 1.4-2 NOx 51.47 AP -42 Chapter 1 Table 1.4-1 CO 86.47 AP -42 Chapter 1 Table 1.4-1 VOC 5.66 AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.85 AP -42 Chapter 1 Table 1.4-3 Note: The emission factors listed in the table above were obtained by multiplying the AP -42 Chapter 1.4 emission factors for the listed pollutants by a ratio of 1,050 Btu/scf to 1,020 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the metered fuel gas volume. Point 134: CAS # Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Emission Factors Controlled lb/BBL Condensate Throughput Source VOC 8.06x10"2 4.03x103 Tanks 4.0.9d Page 80 of 102 COLORADO Air Pollution Control Division Department of Public Health E^ Environment Dedicated to protecting and improving the health and environment of the people of Colorado CAS # Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Emission Factors Controlled lb/BBL Condensate Throughput Source 71432 Benzene 1.07x10"3 5.35x10-5 Mass Balance 108883 Toluene 2.96x10"3 1.48x10-4 Mass Balance 1330207 Xylenes 2.24x10"3 1.12x1O4 Mass Balance 110543 n -Hexane 5.76x103 2.88x10"4 Mass Balance Note: The controlled emissions factors for point 134 are based on the enclosed combustor control efficiency of 95%. Point 135: Component Gas Service Gas Control % Light Oil Light Liquid Control % Connectors 5,488 81 9,057 81 Flanges 3,125 81 1,966 81 Open-ended Lines 1 75 --- Pump Seals - 58 88 Valves 4,207 96 3,320 95 Other* 155 75 37 75 Relief Valves 61 96 34 95 VOC Content (wt. %) 28.09% - 100% Benzene Content (wt. %)! 0.0653% 0.2326% Toluene Content (wt. %) 0.0929% --- 0.3308% - Ethylbenzene (wt. %) 0.0103% -- 0.0365% Xylenes Content (wt. %) 0.0307% --- 0.1091% --- n-Hexane`Content (wt. %) 1.4216% " --- 5.0607% - 2,2,4-TMP Content (wt. %) 0.0628% --- 0.2236% --- *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 Page 81 of 102 COLORADO Air Pollution Control Division Department of Public Health 8 Ervirohrnent Dedicated to protecting and improving the health and environment of the people of Colorado Relief Valves 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Table 2-4 Note that the emission limits included in this permit are derived by multiplying the emissions resulting from the component counts in the table above by a factor of 1.1 to accommodate other minor changes to the facility and to provide a conservative estimate of facility -wide emissions. 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 extended gas analysis. Point 136: Process 01: Still Vent Waste Gas Routed to the Acid Gas Flare (Point 136) Emissions for Process 01 include venting of acid gas (amine unit still vent overhead) and combustion of acid gas (amine unit still vent overhead). Controlled still vent acid gas emissions: Actual VOC, HAP, H2S and methyl mercaptan (MeSH) emissions from venting of still vent acid gas to the acid gas flare shall be calculated based on the most recent waste gas sampling of the still vent acid gas stream and most recent monthly waste gas flow volume of the still vent acid gas stream routed to the acid gas flare. Controlled VOC, , HAP, H2S and methyl mercaptan (MeSH) emissions are based on an acid gas flare control efficiency of 95%. The following equation shall be used, in conjunction with the sample and flow' volume date, to calculate actual emissions. VOC/HAPwaste Gas VOC/HAP concentration (wt %) scf 100 x Still Vent Waste Gas (month) x Gas Sample Molecular Weight ( lb ) : 379 ( scf ) x (1 — 95% control) Ibmol lbmoi *VOC/HAP/H2S/MeSH concentration and gas sample molecular weight are based on actual sampled values of the amine unit still vent waste gas stream. *Still vent waste gas is the actual measured monthly flow volume of the amine unit still vent routed to the acid gas flare. Acid gas flare combustion of still vent acid gas: Actual emissions resulting from the combustion of the acid gas (still vent acid gas stream) are calculated using the following emission factors, the most recent quarterly acid gas stream gross (higher) heat content, and most recent monthly volume of total acid gas (still vent acid gas stream) routed to the acid gas flare. CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source NOx 0.068 AP -42 Chapter 13.5 CO 0.31 AP -42 Chapter 13.5 lote: Permitted combustion emissions are based on a gross (higher) heating value of 14.0 5 Btu/scf. Page 82 of 102 COLORADO Air Pollution Control Division Department of Public Haekh & Environment Dedicated to protecting and improving the health and environment of the people of Colorado S02 emissions resulting from the combustion of H2S and methyl mercaptan (MeSH) in the acid gas (still vent acid gas stream) are based on a mass balance assuming 64 lb 502/lb-mol, 34 lb H2S/lb- mol, and 48 lb MeSH/lb-mol. S02 emissions are also based on the assumption that 100% of the H2S and MeSH in the acid gas is converted to 502. The following calculation demonstrates the mass balance: HZS tons\* (64 lb S02)* (lb — mol11 r(MeSH tons) (64 lb S02)* r lb — mol \311 SOZ(tpy) _ [\ year / \lb — moll 4 lb H2S)i + L\ year / * \lb — moll \48 lb MeSH)] Process 02: Combustion of assist gas and purge gas (residue) and pilot light fuel For combustion of assist gas and purge gas the following emission factors and calculation methodologies shall be used to calculate actual emissions: CAS # Weight Fraction of Gas (oh)Uncontrolled Pollutant Emission Factors lb/MMscf +° Emission Factors Controlled lb/MMscf Source N0x 74.26 74.26 AP -42 Chapter 13.5 CO 338.52 338.52 S02 6.42x10-' 6.42x10"' AP -42 Chapter 1 Table 1.4-2 7.46 V0C. 3601.96 180.1 Gas Analysis 110543 0.231 n -Hexane 111.44 5.57 Note: The uncontrolled VOC and HAP emissions were calculated using a residue gas sample obtained from the Mewbourn Natural Gas Processing Plant on March 29,'2017. The controlled VOC and HAP emission factors are based on the acid gas flare control efficiency of 95%. The NOx and CO emission factors from AP -42 Chapter 13.5 (0.068 lb/MMBtu and 0.31 lb/MMBtu respectively) were converted to units of lb/MMscf using a heating value of 1,092 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the sum of the assist gas and purge gas routed to the acid gas flare (point 136). The assist gas routed to the flare is measured using a flow meter: The purge gas shall be assumed to be routed to the flare at a constant rate of 120 scf/hr. This rate is verified daily by monitoring the rotameter throughput (scf/hr). The total purge gas flow rate shall be determined by multiplying the total purge gas flow rate (120 scf/hr) by the hours the flare operated during the month. For combustion of pilot light fuel the following emission factors and calculation methodologies shall be used to calculate actual emissions: CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Source N0x 102.94 AP -42 Chapter 1 Table 1.4-1 CO 86.47 AP -42 Chapter 1 Table 1.4-1 V0C 5.66 AP -42 Chapter 1 Table 1.4-2 S0x 6.18x10"' AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.85 AP -42 Chapter 1 Table 1.4-3 Page 83 of 102 COLORADO Air Pollution Control Division Department of Public Heatttt w Environment entt Dedicated to protecting and improving the health and environment of the people of Colorado Note: The emission factors in the table above are based on a higher heat value of 1,050 Btu/scf. The flare pilot light flow rate shall be assumed to have a constant flow rate of 67.3 scf/hr. The flare is equipped with two (2) pilot lights. Therefore, the total flare pilot light flow rate shall be assumed to be 134.6 scf/hr. Monthly pilot gas throughput shall be determined by multiplying the total pilot light flow rate (134.6 scf/hr) by the flare monthly hours of operation. Actual emissions are calculated by multiplying the emission factors in the table above by the total pilot gas throughput. Total actual emissions for process 02 are based on the sum of the emissions calculated for the combustion of assist gas and purge gas, and the combustion of pilot light fuel. Point 137: Emissions associated with the open flare result from the combustion of maintenance gas (inlet and residue), purge gas (residue), and pilot light gas. Total actual emissions are based on the sum of the emissions calculated for the combustion of maintenance gas and purge gas (process O1) and the combustion, of pilot light gas (process 02). This open flare will handle gas (inlet and residue) routed to the flare during standard operational process/normal. operation of equipment (i.e. maintenance and blowdown activities). The process limit does not include gas routed to the flare during malfunction events or startup and shutdown events per the Colorado Common Provisions Regulation Section II.E and II.J. The process limit also does not include waste gas associated with the dehydrator (Point 131) still vent and flash tank routed to this flare during VRU downtime. Process 01: Combustion of routine maintenance and blowdown gas (residue and inlet) and purge gas Pollutant Emission Factors Uncontrolled lb/MMBtu Source NOx 0.068 AP -42 Chapter 13.5 CO 0.31 AP -42 Chapter 13.5 Note: Combustion emissions are calculated using the emission factors in the table above, the most recent monthly flare gas higher heat content and the volume of total gas combusted including, but not limited to, the volume of the cold header plus the volume of the warm header. Actual VOC and HAP emissions shall be calculated based on the most recent gas sampling (including gas samples of the cold header and the warm header routed to the plant flare) and most recent monthly gas flow volume (including the volume of cold header gas and warm header gas routed to the plant flare). Controlled emissions are based on 95% control for VOC and HAP. Actual VOC and HAP emissions are calculated using the following equations: Page 84 of 102 COLORADO Air Pollution Control Division Department of Public Health i Environment Dedicated to protecting and improving the health and environment of the people of Colorado Equation for Actual VOC Emissions Calculations: lb VOCTotai (month) = VOCCold Heater + VOCWarm Header lb VOCCoId or Warm Header month) scf = VOC concentration (wt %) - 100 x Purge/Process Gas (month) x Gas Molecular Wei lb 379 scf ht x 1— 95% control) Weight Ubmot) (lbmol) ( *VOC concentration and Gas Molecular Weight are based on actual monthly -average sampled values of the gas streams routed to flare. *Purge/Process Gas is the actual measured monthly flow volume of the gas routed to flare in each header. Equation for Actual HAP Emissions Calculations: HAP Total lb = HAP Cold Heater + HAPkyarm Header (month) HAP Cold or scf = HAP concentration (wt %) _ 100 x Purge/Process Gas (month ( lb lbmol) lb Ni Warm Header, (month) x Gas Molecular Weight' 379 (lbmoll x ) (1 — 95% control) *HAP concentration and Gas Molecular Weight are based on actual monthly -average sampled values of the gas streams routed to flare. *Purge/Process Gas is the actual measured monthly flow volume of the gas routed to flare in each header. Process 02: Combustion of pilot light fuel CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Source NOx 102.94 AP -42 Chapter 1 Table 1.4-1 CO 86.47 AP -42 Chapter 1 Table 1.4-1 VOC 5.66 AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.85 AP -42 Chapter 1 Table 1.4-3 Note: The emission factors in the table above are based on a higher heat value of 1,050 Btu/scf. The flare pilot light flow rate shall be assumed to have a constant flow rate of 65 scf/hr. The flare is equipped with three (3) pilot lights. Therefore, the total flare pilot light flow rate shall be assumed to be 195 scf/hr. Monthly pilot gas throughput shall be determined by multiplying the Page 85 of 102 COLORADO Air Pollution Control Division Department of Public Heath k Environment Dedicated to protecting and improving the health and environment of the people of Colorado total pilot light flow rate (195 scf/hr) by the flare monthly hours of operation. Actual emissions are calculated by multiplying the emission factors in the table above by the total pilot gas throughput. Point 140: CAS # Pollutant Emission Factors Uncontrolled lb/BBL Methanol Throughput Emission Factors Controlled lb/BBL Methanol Throughput Source VOC 1.11x10-1 1.11x10-1 EPA Tanks 4.0.9d 67561 Methanol 1.11x10-1 1.11x10-1 EPA Tanks 4.0.9d Note: Actual emissions for this source are calculated by multiplying the emission factors in the table above by the recorded methanol throughput. Point 141: Total actual V0C emissions are based on the sum of emissions calculated for processes 01-04. Process 01: Blowdown of 16" pig receiver CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled' lb/blowdown event 22.78 V0C 26.17 Mass Balance Note: The emission factors for 16" pig receiver blowdown events are based on a volume of 35.487 scf, an absolute pressure of 862.2 psia, an inlet gas analysis obtained from the Mewbourn Natural Gas Processing Plant inlet on 12/02/14 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/°R*lbmol. Actual emissions are calculated by multiplying the emission factor in the table above by the recorded number of 16" pig receiver blowdown events. Process 02: Blowdown of 24" pig receiver CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled Source lb/blowdown event 22.78 V0C 90.96 Mass Balance Page 86 of 102 COLORADO Air Pollution Control Division DeO rtment cd Pubiic Health& Environment Dedicated to protecting and improving the health and environment of the people of Colorado Note: The emission factors for 24" pig receiver blowdown events are based on a volume of 123.344 scf, an absolute pressure of 862.2 psia, an inlet gas analysis obtained from the Mewbourn Natural Gas Processing Plant inlet on 12/02/14 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/°R*lbmol. Actual emissions are calculated by multiplying the emission factor in the table above by the recorded number of 24" pig receiver blowdown events. Process 03: Blowdown of 20" pig receiver CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled Source lb/blowdown event 22.78 VOC 15.44 Mass Balance Note: The emission factors for 20" pig receiver blowdown events are based on a volume of 68.839 scf, an absolute, pressure of 262.2 psia, an inlet gas analysis obtained from the 'Mewbourn ' NaturalGas Processing Plant inlet on 12/02/14 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/ ° R`lbmol. Actual emissions are calculated, by multiplying the emission factor in the table above by the recorded number of 20" pig receiver blowdown events. Process 04: Blowdown of 12" pig receiver CAS Weight % of Gas Pollutant Emission Factors Uncontrolled lb/blowdown. event 22.78 VOC 5.79 Mass Balance Note: The emission factors for 12 pig receiver blowdown events are based on a volume of 25.815 scf, an absolute pressure of 262.2 psia, an inlet gas analysis obtained from the Mewbourn Natural Gas Processing Plant inlet on 12/02/14 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/ ° R*lbmol. Actual, emissions are calculated by multiplying the emission factor in the table above by the recorded number of 12" pig receiver blowdown events. Process 05: Blowdown of 8" pig receivers CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled Source lb/blowdown event 22.78 VOC 1.702 Mass Balance Note: The emission factors for 8" pig receiver blowdown events are based on a volume of 7.591 scf, an absolute pressure of 262.2 psia, an inlet gas analysis obtained from the Mewbourn Natural Gas Processing Plant inlet on 12/02/14 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/°R*lbmol. Actual emissions are Page 87 of 102 COLORADO Air Pollution Control Division Departmentof Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado calculated by multiplying the emission factor in the table above by the recorded number of 8" pig receiver blowdown events. Process 06: Blowdown of 6" pig receivers CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled Source lb/blowdown event 22.78 V0C 8.02x10"' Mass Balance Note: The emission factors for 6" pig receiver blowdown events are based on a volume of 3.576 scf, an absolute pressure of 262.2 psia, an inlet gas analysis obtained from the Mewbourn Natural Gas Processing Plant inlet on 12/02/14 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/ ° R*lbmol. Actual emissions are calculated by multiplying the emission factor in the table above by the recorded number of , 6" pig receiver blowdown events. Process 07: Blowdown of 16" pig launcher CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled lb/blowdown event 7.61 V0C 10.15 Mass Balance Note: The emission factors for 16" pig launcher blowdown events are based on a volume of 35.487 scf, an absolute pressure of 1212.2 psia, a residue gas analysis, obtained from the Mewbourn Natural Gas Processing Plant on 03/29/17 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant:, 10.7316 ft3*psia/ ° R*lbmol. Actual emissions are calculated by multiplying the emission factor in the table above by the recorded number of 16" pig launcher blowdown events. Process 08: Blowdown of 24" pig launcher CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled Source lb/blowdown event 7.61 V0C 35.27 Mass Balance Page 88 of 102 COLORADO Air Pollution Control Division Department of Public Health &Environment Dedicated to protecting and improving the health and environment of the people of Colorado Note: The emission factors for 24" pig launcher blowdown events are based on a volume of 123.344 scf, an absolute pressure of 1212.2 psia, a residue gas analysis obtained from the Mewbourn Natural Gas Processing Plant on 03/29/17 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550°R and (ii) Ideal Gas Law Constant: 10.7316 ft3*psia/°R*lbmol. Actual emissions are calculated by multiplying the emission factor in the table above by the recorded number of 24" pig launcher blowdown events. Process 09: Blowdown of 20" pig launcher CAS Weight % of Gas Pollutant Emission Factors - Uncontrolled Source lb/blowdown event 7.61 VOC 4.26 Mass Balance Note: The emission factors for 20" pig launcher blowdown events are based on a volume of 68.839 scf, an absolute pressure of 262.2 psia, a residue gas analysis obtained from'the Mewbourn Natural Gas Processing Plant on 03/29/17 and the ideal gas law. The ideal gas law is based on the following parameters: (i) Temperature: 550'R and (ii) Ideal Gas Law Constant:' 10.7316 ft3*psia/ ° R*lbmol. Actual emissions are calculated by multiplying the emission factor in the table above by the recorded number of 20" pig launcher blowdown events. 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) Point 101: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting - effective October 19, 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/rice/fr20au10.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 8) Points 113, 114, 115, 116 and 117: These engines are subject to 40 CFR, Part 60, Subpart JJJJ— Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http: / /www.epa.gov/ttn /atw/area/fr18ia08. pdf 9) Points 113, 114, 115, 116 and 117: These engines are subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Page 89 of 102 COLORADO Air Pollution Control Division Department of Public Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 10) Point 108 £t 135: This source is subject to 40 CFR, Part 60, Subpart 0000a —Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting - effective August 02, 2016). 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: https://www.gpo.gov/fdsys/pkR/FR-2016-06-03/pdf/2016-11971.pdf 11) This facility is classified as follows: Applicable Requirement Operating Permit Major Source: CO, VOC, and NOx Synthetic minor source: HAPS NANSR Major Source: VOC and NOx PSD Synthetic Minor Source: CO MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable Area Source Requirements: Applicable, to Points 101, 113, 115, 116 and 117 MACT ZZZZ MACT YYYY Not applicable [4, MACT DDDDD Not applicable NSPS KKK Not applicable NSPS OOOO Not applicable NSPS 0000a Applicable to point 108 a 135 NSPS Kb Applicable to point 134 NSPS KKKK Applicable to points 111, 112, 118, 119, 129 and 130 NSPS Dc Applicable to points 121, 123, and 133 NSPS LLL Recordkeeping requirements only for Point 120 Page 90 of 102 COLORADO Air Pollution Control Division Department of Public Heath & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 12) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT: 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM. MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX 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.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been Page 91 of 102 COLORADO Air Pollution Control Division Department'of Ptahlin Health & Eretronmere Dedicated to protecting and improving the health and environment of the people of Colorado 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. 1n 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. Page 92 of 102 COLORADO Air Pollution Control Division Department cif Public Health & Emu-atm-lent. Dedicated to protecting and improving the health and environment of the people of Colorado The AOS cannot be used for the permanent replacement of an entire engine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non - Attainment Area New Source Review ("PSD/NANSR") unless the existing engine has emission limits that are below the significance levels in Reg 3, Part D, II.A.42. 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 accompaniedby 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 Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) ''a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 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. Page 93 of 102 COLORADO Air Pollution Control Division Department of Public Health El Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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: https: / /www.colorado.gov/pacific/sites/default/files/AP_Portable-Analyzer-Monitoring-Protocol.pdf 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 unitis currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results "indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.4 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. Page 94 of 102 COLORADO Air Pollution Control Division Department of Pob;icHe„lth $ Enviro rnent Dedicated to protecting and improving the health and environment of the people of Colorado ATTACHMENT B ALTERNATIVE OPERATING SCENARIOS TURBINES WITHOUT CONTINUOUS EMISSIONS MONITORING August 16, 2011 1. Routine Turbine Component Replacements The following physical or operational changes to the turbines in this permit are not considered a modification for purposes of NSPS GG, major stationary source NSR/PSD, or Regulation No. 3, Part B. Note that the component replacement provisions apply ONLY to those turbines subject to NSPS GG. Neither pre-GG turbines nor post GG turbines (i.e. KKKK turbines) can use those provisions. 1) Replacement of stator blades, turbine nozzles, turbine buckets, fuel nozzles, combustion chambers, seals, and shaft packings, provided that they are of the same design as the original. 2) Changes in the type or grade of fuel used, if the original gas turbine installation, fuel nozzles, etc. were designed for its use. Page 95 of 102 COLORADO Air Pollution Control Division Department of Public Heaith & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 3) An increase in the hours of operation (unless limited by a permit condition) 4) Variations in operating loads within the engine design specification. 5) Any physical change constituting routine maintenance, repair, or replacement. Turbines undergoing any of the above changes are subject to all federally applicable and state only requirements set forth in this permit (including monitoring and record keeping). If replacement of any of the components listed in (1) or (5) above results in a change in serial number for the turbine, a letter explaining the action as well as a revised APEN and appropriate filing fee shall be submitted to the Division within 30 days of the replacement. Note that the repair or replacement of components must be of genuinely the same design. Except in accordance with the Alternate Operating Scenario set forth below, the Division does not consider that this allows for the entire replacement (or, reconstruction) of an existing turbine with an identical new one or one similar in design or function. Rather, the Division= considers, the repair or replacements to encompass the repair or replacement of components at a turbine with the same (or functionally similar) components. 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of combustion turbines and turbine components has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility'- Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a<Construction Permit for any turbine or turbine component replacement performed in accordance with ` this AOS, and the owner or operator shall `be allowed to perform such turbine or turbine component replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Turbine Replacement The following AOS is incorporated into this permit in order to deal with a turbine breakdown or periodic routine maintenance and repair of an existing onsite turbine that requires the use of a temporary replacement turbine. "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 turbine is in operation. If the turbine 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. Any permanent turbine replacement under this AOS shall result in the replacement turbine being considered a new affected facility for purposes of NSPS and shall be subject to all Page 96 of 102 COLORADO Air Pollution Control Division Department of Public Health &Ervironrnett Dedicated to protecting and improving the health and environment of the people of Colorado applicable requirements of that Subpart including, but not limited to, any required Performance Testing. All replacement turbines 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 the NSPS 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 turbine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the turbine (s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement turbine. 2.1.1 The owner or operator may temporarily replace an existing turbine that is covered by this permit with a turbine that is the exact same make and model as the existing turbine without modifying this permit, so long as the temporary' replacement turbine complies with the emission limitations for the existing permitted turbine and other requirements applicable to the original turbine. Measurement of emissions from the temporary replacement turbine shall be made as set forth in section 2.2. 2..1.2 The owner er operator may permanently replace the existing turbine that is covered by this permit with a turbine that is the exact same make and model as the existing turbine without modifying this permit so long as the permanent ; replacement turbine complies with the emission limitations and other requirements applicable to the original turbine as well as any new applicable requirements for the replacement turbine. Measurement of emissions from the temporary replacement turbine shall be made as set forth in section 2.2. 2.1.3 An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement turbine shall be filed with the Division for the permanent replacement turbine within 14 calendar days of commencing operation of the replacement turbine. 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 turbine. This AOS cannot be used for permanent turbine replacement of a grandfathered or permit exempt turbine or a turbine 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 turbine replacement. The AOS cannot be used for the permanent replacement of an entire turbine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non -Attainment Area New Source Review ("PSD/NANSR") unless the Page 97 of 102 COLORADO Air Pollution Control Division Department of Pt t)lic Health t Environment Dedicated to protecting and improving the health and environment of the people of Colorado existing turbine has emission limits that are below the significance levels in Regulation 3, Part D, II.A.44. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent turbine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent turbine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 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 turbine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement turbine. All portable analyzer testing required by this permit shall be conducted using the most current version of the Division's Portable Analyzer Monitoring Protocol as found on the Division's website. 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% 02) that the existing unit is currently subject to or the replacement turbine 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 turbine is in compliance with both the NOX and CO emission limitations for the relevant time period. Page 98 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the turbine 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 turbine is taken offline. 2.3 Applicable Regulations for Permanent Turbine Replacements 2.3.1 NSPS for Stationary Gas Turbines: 40 CFR 60, Subpart GG §60.330 Applicability and designation of affected facility. (a) The provisions of this subpart are applicable to the following affected facilities: All stationary gas turbines with a heat input at peak load equal to or greater than 10.7 gigajoules (10 million Btu) per hour, based on the lower heating value of the fuel fired. (b) Any facility under paragraph (a) of this section which commences construction, modification, or reconstruction after October 3, 1977, is subject to the requirements of this part except as provided in paragraphs (e) and (j) of §60.332 .' A Subpart GG applicability determination as well as an analysis of applicable Subpart GG monitoring, recordkeeping,' and reporting requirements for the permanent turbine replacement shall be included in any request for a permanent turbine replacement Note that under the provisions of Regulation No. 6. Part B, Section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the commence construction date for purposes of determining the applicability of NSPS GG requirements). 2.3.2 NSPS for Stationary Combustion Turbines: 40 CFR 60, Subpart KKKK §60.4305 Does this subpart apply to my stationary combustion turbine? (a) If you are the owner or operator of a stationary combustion turbine with a heat input at peak load equal to or greater than 10.7 gigajoules (10 MMBtu) per hour, based on the higher heating value of the fuel, which commenced construction, modification, or reconstruction after February 18, 2005, your turbine is subject to this subpart. Only heat input to the combustion turbine should be included when determining whether or not this subpart is applicable to your turbine. Any additional heat input to associated heat recovery steam generators (HRSG) or duct burners should not be included when determining your peak heat input. However, this subpart does apply to emissions from any associated HRSG and duct burners. Page 99 of 102 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado (b) Stationary combustion turbines regulated under this subpart are exempt from the requirements of subpart GG of this part. Heat recovery steam generators and duct burners regulated under this subpart are exempted from the requirements of subparts Da, Db, and Dc of this part. A Subpart KKKK applicability determination as well as an analysis of applicable Subpart KKKK monitoring, recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in any request for a permanent turbine replacement Note that under the provisions of Regulation No. 6. Part B, Section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the commence construction date for purposes of determining the applicability of NSPS KKKK requirements). 2.4 Additional Sources The replacement of an existing turbine with a new turbine 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; a turbine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite turbine has to go through the appropriate Construction/Operating permitting process prior to installation. ATTACHMENT C INSIGNIFICANT ACTIVITIES Description NOx VOC CO Eight (8) Comfort Heaters (Amine Building) 0.01 --- 0.01 Four (4) Comfort Heaters (Overhead Compressor Building) 0.04 --- 0.04 Four (4) Comfort Heaters (Overhead Compressor Building) 0.08 --- 0.04 Comfort Heater (LP Fuel Meter House) --- --- --- Two (2) Comfort Heaters (Inlet Meter House) --- --- --- Comfort Heater (VRU Meter House) --- --- --- Comfort Heater (M2 to M3 Meter House) --- --- --- Fuel Gas Meter --- --- --- Four (4) Comfort Heaters (Turbine Building) 0.04 --- 0.04 Four (4) Comfort Heaters (Turbine Building) 0.08 --- 0.04 2,000 Gallon Methanol Tank --- 0.03 --- 90 Barrel Methanol Tank --- 0.08 --- 300 Gallon Methanol Tank --- --- --- 150 Gallon Methanol Tank --- --- --- Methanol Tank (TK-30) --- 0.08 --- Page 100 of 102 COLORADO Air Pollution Control Division Department of Pubic Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 300 Gallon Gasoline Tank 0.03 Pressurized Raw Condensate Loading Rack Compressor Blowdowns (inlet 8 residue) 2,000 Gallon Norkool Tank (TK-15) 560 Gallon Coolant Tank (TK-3) Two (2) 400 Barrel Storm Water Storage Tanks (TK- 31 Et TK-32) 300 Gallon Inlet Compressor Lube Oil Storage Tank (TK-0165) 2,500 Gallon Residue Compressor Lube Oil Storage Tank (TK-0560) 80 Barrel Instrument Air Water Drain Tank (TK-1455) 80 Barrel Underground Secondary Containment Tank (TK-1690) 200 Barrel Amine Makeup Tank (TK-801) 300 Barrel Water Makeup Tank (TK-802) 200 Barrel Amine Drain Tank (TK-803) 300 Barrel CO2 Vent Tank (TK-806) 90 Barrel Glycol Makeup Tank (TK-831) 90 Barrel Open Drain Tank (TK-883) 90 Barrel Cooling Water Drain Tank (TK-885) 90 Barrel Cooling Water Makeup Tank (TK-886) 90 Barrel Lube Oil Make -Up Tank (TK-887) 80 Barrel Hot Oil Drain Tank (TK-888) 90 Barrel Hot Oil Drain Tank (TK-889) 1,000 Gallon Residue Compressor Lube Oil Drain Tank (TK-1360) 5,600 Gallon Hot Oil Surge Tank (V-483) 1,036 Gallon C-9320 Lube Oil (TK-7000) 150 Barrel Glycol Storage (TK-7600) 400 Barrel Storm Water Tank (TK-6100) 55 Gallon Expander/Compressor Lube Oil Makeup Tank (TK-654) Refrigeration Propane Storage Tank (TK-7) Ethylene Glycol (TK-17) Slop Oil (TK-24) Residue Compressor Cooling Water Tank (TK-1276) Equipment Blowdowns Pressurized Raw Condensate Unloading Rack (UL) at Mewbourn II 0.94 0.74 0.53 0.95 Pressurized Raw Condensate Unloading Rack (UL -2) at Mewbourn III Natural Gas Compression - Purge 0.95 0.08 Page 101 of 102 COLORADO Air Pollution Control Division Department of Public Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado *There is a blowdown vent for each compressor package so each is a separate emission point VOC emissions calculated separately for each vent. Page 102 of 102 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Harrison Slaughter,' Package it: 389849 Received Date: Review Start Date: 11/1/2010 3/26/2019 ,..!. Section 01- Facility Information Company Name County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: Natural Gas Processing Plant What industry segment70# &Natural Gas Production &Processing: Is this facility located in a NAAOS non -attainment area? If yes, for what pollutant? I [amen prom. (cal Updated Application Received 04/11/2019; New source received 06/22/19; Additional updates received 07/22/19,08/27/19, 10/04/19 &11/1/19. DCP'Operating Company kP 123 0090 Mewboum Natural Gas Process -Plant 561/4 quadrant ar Section 35, Tawnship 4r1, Range SSW Weld County Section 02 - Emissians Units In Permit Application Iartkuiate Matter (PM) Qu d t Sect T nsh p Range 1 ✓ prone (ties a WC) AIRS Point # Emissions Source Type Equipment Name Emissions Comrol? Permit k Issuance# Self Cot Required? Action Engineering Remarks 101 Natural Gas RICE C 211 You 09WE1136 5 _... No Permit Modification 102 - - Nadia₹ Gat RICE 0167 'Yes 09W11130 5 - No - Cancellation Cancellation received 08/14/18 -: 103 Natural Gas PUCE C179 Yes 09WE1136 - 5 No Cancellation Cancellation received 08/14/18 106. --: Natural Gas ldCE C-130 .yes 09WE1136 5 :. No Cancellation Cancellation.. received 08/14/28. ' 108 - Fugitive Component Leaks F017 `. - No 09WE1136. 5 No Permit . Modification .109 L€goid Leading LO Yes 09WE1136 S Yes Modification '..110 Condensate Tank TANKS Yes 09WE1136 5 - ten NoAcgon Requested 111 - Turbine 00170 - No 09WE1136 5 - Yes Permit Modification 112 Turbine C0180 No 09WE1136 - 5 Yes Permit Modification 113 Natural Gas RICE 0250 Yes 09WE1136 5 Nu NoAnUon Requested 114 -- Nature₹Gal A₹CE C2S1 Yes -' 09WE1136 5 No No Action -- Requested 115 Nature#Gas RICE 0252 Yes 09WE1136 -- 5 NO No Action Requested 316 Nature#Ga5RlEE 5253 •Yes - 09W01136 5 Na- No Aciion .Requested .. 117 ' Natura€ Gas RICE , C254 .Yes 09W01136 :.. 5 No No Action Requested 118 - :Turbine 01650 ;. No 09WE1136 5..-. Yes Permit Modification .119 Trrb#no 01670.... No 09WE1136 5..: Yes Permit Modification 120 AreineSweeteningtUnt AM001. - Yes 09WE1136 5 You Permit Modfiication 121 -- - N6 Heater - 14776 - No 09WE1136 5 - No NoAction Requested 122 Dehydrator 0-931 Yes 09WE1136 5 -. Yes -- No Action Requested 123 NG Heater 14771 No 09WE1136 5 No No Action Requested 125 Process Flare F-i No 09 3u 5 -Yes Pertain -.Modifacation 127 - ProcecuFlare Backup. TO ; - 09WE1136 5 - No - - Cancellation Cancellation received 04/26/18.' 129 Turbine. - TURB 1:. No 09WE1136 S Yes Permit Modification 130 - Turbine TURB 2 No : 09WE1136 S - Yes Perm₹t Mod'dicadon 131 Dehydrator 0-2 - Yes 09W01136 5 Yes Permit Modification 132 NG Heater HT -01 No 09WE1136 S Van No Action Requested 133 NG Heater HT 02 No 09WE1136 5 Yes Permit Modituatian 134 Condensate Tank TANKS -2 Yes 09WE1136 ": 5 Yes No Action '- Requested 135 Fugltive Component Leaks P0G-02 Yes 09WE1136 5 Yes Permit '. Modfication 136 Process flare F-2 No _'. 09WE1136 5 Yes P.anit Modiification;,. 137 ` " Pracesu Flora F 3 -:- No - 09WE1136 : 5 You Permit Modification. 139? - URtoid Loading UL -- -;: No 09WE1136 5 - NO - - Cancellation Cancellation request received 06/22(19...... 140 Ocher (E lain) -- METHANOL No .- 09WE1136 ' 5.. - - Yes - Permit Modfication New. source 141 .. - hata€ntenance Rlewdovms PIG .: No -.. 09WE1136 5:: -.. Yes Permit - Modification New Source Colorado Air Permitting Project Section 03 - Description of Project DCP Operating Company, LP (DCP) submitted permit application to modify the Mewbourn Natural Gas Processing Plant. With this modification, DCP is requ estieg to add tom new sources and modify several existingsources at this facility. The updates requested in this application are as follows, .DCP is requesting the following modifications to existlgg.sour. j) Amine Unit (Point 120): The operator is requesting to increase the limit on combustion of supplemental fuel bythe lthermal oxidizer M Mscf/year. The ongoing compliance demonstration wasalso updated wth this modification. (bi Mewbourn hi Plant Flare (Point 125): The operator is requesting To increase the limit on waste ga3 and purge gas combusted by -the:; MMscf/year. (c) TEG Dehydration Unit (Point 131): Update process limits and ongoing compliance requirements. (di Hot Oil Heater (Point 133)rThe operator s requestingto llminthe heat input rate fromd0.8 Mt ntu/hr to 320 MM8tu/hr. (0) Amine tint Acid Gas Flare (Point 236): The operator is reqesting to increase the process limits as follows: (i) Increase the downtime of the prima 13 days to 20.5 days. (ill Increase the. Combustion of still vent waste gas from 65.37 MMscf/year to 103.08 MMscf/year. (lid Increase -the combustion of assts gas from 1721 MMscf/year to 26.60 MMscf/year. (f) Mewbourn lit Plant Flare (Point 137): The operators requesting to increase the limiton combustion: of maintenance and purge MMscf/year. (g) Turbines (Points 111, 112,118, 119, 129 & 130): The operatoris requesting to modify each of the turbines at the facility to include emissions assoc shutdown events. The process limits and emission limitswere updated for eec)t of these sources. (hi Fugitives (Points 108-& 135): The operator is requesting to increase the component counts for each of these sources and updatethe regulatory-:applicabili The operator is also requesting to update the control efficiencies based on Compliance with N5P5 00000 LDAR. ( } Loudest(Point 109): Decrease permitted throughputfrom 912,500 barrel/year to 200,000 barrel/year, Include limits on putt light and assist gas combustion (l Engine (Point 101): Limit'. operating hoursfrom 8760 hours to 720 hours. Update uncontrolled emission factors based on catalyst data. 2 DCP is also requesting to add the following sources to the facility: (i) one (1)300 barrel fixed roof methanol storage vessel and (ii natural gas venting from the blowdown of Public comment wtll be required because new synthetic minor lieius are being established and the change in CO emissions esult'ofthe project is greater than 50 tpy.: The operator submitted: notice of start-up documentation for points 129-137. Each of these units has been operational for more than one year. As a moult, monthly limits were removed from the permit ter these sources Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Aei€ueutiug5Yndtetice,alnoepeeedt Section 05 -Ambient Air Impact Analysis Requirement Wass quantitative modeling analysis required? If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06- Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (P50) Title V Operating Penults (OP) Non -Attainment New Source Review (NAN5R) Tide V Operating Permits. (OP) Non -Attainment New Source Review (NAN5R) 502 Nut CO VOC PM2.5 PMSD TSP dI l Il I LI. IJ 1 I HAPs ICI Maps RICE Emissions Inventory Section 01-Adminstra8veInformation 'Facility Allis ID: ' 5r 2 :its .D -z,` County Plant Point Section 02- Equipment °esnipda, Details Emission Control Device Description: Requested NOx Control Efficiency %: Requested VOC Control Efficiency 56: Requested CO Control Efficiency %: Requested HCHO Control Efficiency%: Engine Manufact Date: 1• ''21t/0993 ._ Manufacturer. :„ Caterplllat_,: `:. Model Number. 'n00379NA,, serial Number r ,326643 Engine Function Denting Mfg's Max. Rated Horsepower @sea level: timittam Horsepower used for calcuationyY Ey�'330p 0SCF @ 100% Load (btu/hp-hr): 4,.M061421 -W.' 11 Site - Rated RSCF @ 300% load (btu/hp-hr): 7078 Engine Type, IXher Parameters Aspiration Electrical Generator Ma Site Rating (kw) s -n",?•-. 0 _ 'Requested Hours of Op ati 3 281 PTE Hours of Operation a +•..,..,. 976d Actual Hours of Operation _9 ¢• 127229' 5ectfon 03 -Processing Rate Information for Emissions Estimates Fuel Use Rate @ 10096 Load 2475.942807 scF/hr ACTUAL Annual Fuel Consumption yj,�."ii '�}... MMscf/yr MAX POTENTIAL Annual Fuel Consumption 21.699 MMscf/yr REQUESTED Annual Fuel Consumption 1.790 MMscf/yr Requested Fuel Heating Value ±..•._, s` ,..-c.. 1090btu/scf Actual Fuel Heating Value ........ ".::-.: -.11150 btu/scf Section 04- Emissions Factors& Methodologies WEIMMTE Pollutant SI RICE ngine Uncontrolled Natural Gas Consumption) 13:000MIEESEIMMIS= _ '`3.100 ®® Controlled Source ITM® :. :. -® IIIIMIECEIMMECIEEIM.. +.. e... WEEMECINIESEMEIMPIMIEMEMMEIMEMt 1===l1INEEMIME==IIIIEEMIIMIE=MC ® IE =MIMI U,rrrNM.Z®MEMIEB Z=2:M- 0.0.'x'Ea, �� " ME=EN Formaldehyde Section OS- Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled ILon5Near) Actual Emissions Uncontrolled Controlled (Roos/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tans/year) ltons/yearl NOx CO VOC PMu PMo SO2 41.83 36.60 0.51 3.40 3.419 41.42 39.60 4.01 2.40 0.42 3,08 6.23 2.02. 0,8:1 0.20 0.22 0,20 0.211 0,02 0.02 0.22 0.20 0.20 0.02 0.02 0.01 801 9.01 0.00 0.00 Ha5ard0us Air Pollutants0hs/year) Potential to Emit Uncontrolled Actual Emotions Uncontrolled Controlled Ilbs/year) llb:/rear) Requested Permit Limits Uncontrolled Controlled 9bsNear) llbs/year) Formaldehyde Acetaldehyde Acmlein Methanol Benzene Toluene Ethylbesoene xylene n -Henn. 2,2,4-TMP 1,3-Butadlene 467 412 33 0..37 :2,11 64 - 26 5.21 2.61 60 00 20 4.82 2,46 70 62 31 55.70 7.86 86 32 16 2.96 1.40 13 01 6 1.04 0.02 0 0 0.00 0.02 4 - 1 0.37 a5. :r 0 0 0.00 0.00 0 0 0 0.00 0.00 23 13 1.24 0.62 Emission Factors Units 3.617906799 0.447036175 Ib/MMBtu 3.637986799 0.447836175 lb/MMBtu 0.867519929 0.279861923 Ib/MMBW 6.936E-02 g016hr 6.936E-02 g010 -hr 2101E-03 g/hp-hr 7.325E-02 1.377E -0i g/hp-hr 9.970E-03 4.905E-03 g/hp-hr 9.398E-03 4699E-03 g/hp-hr 1.093E-02 5.467E-03 g/hp-hr 5.646E-03 2823E-03 g016hr 1.994E-03 9.970E-04 g/hp-hr 8.862E-05 4.431E-05 g/hp-hr 5.968E-04 3.484E-04 g/hp-hr 0.000E-000 0.000E+00 g/hp-hr 0.000E00 0.000E+00 yhp-hr 2389E-03 1.105E-03 g/hp-hr 09WE1136.CPS RICE Emissions Inventory Section 06- Regulatory Analysis Re oleo Reotrirements Regulatlon) Section Ildl- Excep[as provided in paragraphs 2through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which k in excess of 20% opacity. This standard Is based on 24 corsecu[Ive opacity readings taken at 15 -second Intervals for sh minutes. The approved reference test method for visible emissions measurement k EPA Method 9 (40 CFR, Part 60, Appendix A (July, 19920 in all subsections of Section II. Aand B of this regulation. Regulatlon 2 Section I.A- No person, wherever located, shall .use or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes It k a violation if odors are detected alter the odorous air has been diluted with seven (7( or marevolumes of adorfree air. Regulatlon3 Part A-APEN Requirements Criteria Polluter.For criteria pollutants, Air Pollutant Emission Notices are required fon each individual emission paint in an attainment area with uncontrolled actual emissions of two ton per year or more of any Individual criteria pollutant. (pollutants are not summed). Applicant Is required to file an ADEN since emissions exceed S ton per year NOx. Porto —Construction Permit Exemptions Applicant Is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 2TPY threshold (Regulation Number 3, Part B, Section II.2.3.5) Regulation Section drf.t: This engine has a design rate less than 500HP (reported m330HP) and is located in the ozone non- . attainment area. As a result, the engine is not subject to the air pollution control technology requirements of Section 011.0.1 for rich bum engines. However, the APEN submitted indicates the engine Is equipped with an Air/fuel ratio controiler and a non -selective catalytic reduction system to control emissions. Section MILD: The most recent AOS completed for this engine occurred on o5/15/2014.As a result, this engine exerted at this major source of NOx as of lune 3, 2016. However, uncontrolled requested emissions as a result of this modification are less than 5 tpy Nor:. As a result, this engine is no longer required to meetthe requirements In Section X11.0. Section MIME: According to Regulation 7 Section XVII.B.5: °internal combustion engines that are subject t0 an emksions control requirement in afederal maximum achievable control technology ("MAR") standard under 40 CFR Part 63, Best Available Control Technology "BACT"( limit, or a New Source Performance Standard ("NSPS1 under 40 CFR Part 60 are not subject to Section XVII., except for the leak detection and repair requirements in Section XVII.F." This engine does not have emission control requirements in NSPS1IIJ or MACTZID. Asa result, It Is pa[erNally subjectto the requirements of Regulation 7 Section 1CVII.E. Based on the operator, this enginewas relocated and retracted in Colorado by 2005 at the latest. Asa resus, the amissiors standards Intable 2 do rat apply to this engine. Further, this engine hasa name plate design rating less than 500 horsepower. Asa result, Regulation 7 Section XVII.6.3. requirements do not apply to this engine. MACE 2222 This engine k subject to MAC? 2222. The facility is an area source of HAPs, ss the engine is not subject to major source requirements. Since this engine 5 located at an area source of HAP emissions and commenced construction priorto June 12, 2006, it is classified as a"Existing Stationary Rice.. According to§63.6603(a):"R you own or Operate an existing RICE located at an area source of HAP emissions, you must comply with the requirements in Table 2d [otitis subpart and the operating limitations in Table 21 to this subpart that apply to you." NSPS11H Is this engine subject to N5Ps lit? - I This engine commenced mrstruction prior to June 12, 2000, and It was manufactured prior marl, 1, 2008 (§gg4230(a)(4)(ili)(. As a result, the engine Is notsubjectto the standards In NSPS AIL o9wcicsu-CPS RICE Emissions Inventory Section 02 -Technical Analysts Notes S.An initial compliance testfor rhnginennot required for the following reasons: fi{WhentheA05 was completed nMay2014, the operator provided pentacle aleaer data demonstrating the engss. et the existingpermitted ltmts fill Inspection reportscompleteda al te ACM engrne stalled Irldin.the ongoing punchle analyzer( to ntinueticompliance with the existing permit gm...Since this source hes demonstrated ongoing vempranc since its installation, an addttenalcompliance rest was deemed unnecessary. Additionally, he operator removes -Peg to lint the operatng.60ursto720 hours per year wtththsapplicett recess -the engine leer yieoeeaeaov beatedtncheob up pP s. Requiring the engneto be eper000eeeley for a compbence test was deemedoountmroductiven this Instance duete the limited e007e0ng hours 2. Paced On elf rm [on prodded bythe perator, this engine is grlysuhleCt to MACI22ZZ The mqucements under MAC -2222 areas follow:Table2d (at;Change oil andtliter every1,440 heursot operation en dally, whichevercomes first (b) inspect -spark plugs everye.aae hours of operatic or annually, whichever first and replace ssary, and (c) inspect all hoses and belts men/ 1,440 hours of mi aasnece operation or annually,whichever co ee first, and molasses necessary, 3. With this application, the poemtor is requesting toImt the operating hours on this enginefrem826e hoursjyear to -770 houstyear Fhie lIm a aken inoder toreduc In netting analyzisto, beimo 014-140.rmodnbcation threshold ofb0tpy. 4 The ernosionfactor used forr POC raoresentsthe total hydrocarben exussionfactor from the manufassurer data sheetmciudedn the application. Since methaneand ethane are not inclusso n vOC, using an mission factorthetincludes methane.. ethane Tithe emis.on rate results In a consetvetiveeStImeteeiV0C emissions Asa. result, the 30C on (act ee deemed to end.etteptable for permitting purposes 5 bocce emission factors arefepresented in itiggssetu inthe permit h operator iseequiredto sample -beat content of the f elgas combust d in order. caleuiste actual e00007ts... 1. The opera reported actual n Mee Nihe actual wed or vented 00904 of thrsanayss.Aca resvh, l m in{ormationshould be referenced on the t emissions ens were not -reviewed scion submitted forths source, not -this analysis. mission fassors for HAP, are nor Included Intl. Pt beaaeee eme,Iona 30e below .PEN reperihigthresholds. 8. Even though VOC em sin nt are below APES repeahro thresholds, tmhetd emission factors sell included in the permit berm se the eperateeis eetablzhingiim avoid other repo, cements 0. Who the anginal application, the operator requested emesion factorefen g/hph-andlse.lhp-hrfor NON end CO respectively. However, the catalyst data sheet provided bythe operator for this engine - listed unedntrolledetusson factor ranges for NO% and CO The ranges for'VOv and CO were 1l-13 and0--13g/he hrrespectivey 5ncetheee rangeset emissle 0en0000wae highs than the originally nested vale h operator to use the h ghestrepaned em ionfactors on the catalyst data sheeeeeestun a contreeed emissions goiriefonvare.Sincettee is rvtiveestimate of s, it is of le for pn, tong Purposes. 10. The catalyst data sheet provided in application demonstrates 0be engine o capable of operatingat the r copycat on on VOC lit orde 11. Based on data provided by the operator,th 3 engine was relocated and constructed le thestete of Collorado by 2005 at the la0 est. Based on areview of heerds,APgw000bmittad indicate this engine may have been installed and operating in Mestate of Colorado as ear, as 1993. This information further supports the determinat ion made abovethatthis engine tsnotsubuectto theeminfnn rte ndards of`able 2 i Regulatldn75ection XVu. Section 08- Inventory See Ceding and Emissions Factors AIRS Point to 101 Process 0 SCC Code 01 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.010 0.00% gYMMBIu PM2,5. 0,(113 0.M% b/MMBer 300 3.6380 0'7.69% h/MMI5tu VOC 0,03A RJ.yobe b/MMBIu CO 0.030 97.65% b/MMBtu 502 5.06203 0.00% b/MMBtu Formaldehyde 2,056.02 76.[0010 b/MMBhz Acetaldehyde 1.700113 'htt.ltT.i b/MMBtu Aaolein 2.o;H10 x0.00°.5 b/MMBtu Methanol 3.0eCO3 5e,6613 b/MMBtu Benzene 056E -0A 50.00% b/MMBW Toluene .0,603,023 60.00% b/MMBtu Ethylbenzene 2.6X6-05 34,00% b/MMBtu Xylene 0.05214 00.041% Ita/MMBlu n -Hexane 0.000000 50.00% b/MMBtu 2,2,4-TMP 10.00003 30.03% b/MMBtu 1,3 -Butadiene 6.41E-04 :10,00% 11/MMBIu 09WE1136.CP5 Fugitive Emissions Inver,ory Sect. 01- AdmInswarive Information 12adlityNRalo: Detailed Emissions um. Oexaktiont Emission rand 0 wa Desalpdor: an. rochrire mama ,.�„�Lfik'4. t b Ivbsi 04_1 .. r"nemnn. zakn W-Embsbns tenon a 84m .dnlnzFs Reeulatlon 7 Information Operating Fours: Emission Factor Source Conhol Ehmncv Souge: CalculaBons NONIMN.&A sea section 07 notes 1, 2 83 kr ...al infomeSon Service Comp nom Typ c.urN IEr acto.(blk-1110,644X4 real Connectors Flanges 05.bEndeci lion Pump.. Values Ober RelierVaNas Pollutant lb.. Fraction VOC Benzene 0 Toluene , 0.00042 nen. 7.62122 Etny ne .`, 1.058752 m.ane 0.002420125 224-TMP 275.8;85 Methanol .11.505 H Methyl 00 VOL Serweno Toluene Ethy nzene Manes MelhanolP 1QS Mehyl Melceptee VOC Comene 1816.002436541 �I O hylbenzene 882', 4-645.2.05 Xvienes r0.000334752 0- 2n 224 -IMP 1418'0.204120022 Methanol M GK 4.6452505 Mehyl Merceomr..::sd1458E-05 VOC Benzene Toluene henaene Xylem. nixeane 2,24-1512 Methanol HES Methyl Uncontrolled Mmiled Emisskns thy) Gas He. Oil Light 011 Water/Oll Connectors Flanges 0. -Ended Lines Pump Seals onor Relle,V. 100 Connectors Flanges Ended Lines 9 ak Vakes Geer Maier Va. Connect. Flang s open-Endedunes wmP6 a4s Valves Oker Refer Vanes 3,90E-04 5.302. 010% 100.3 1502-22 ]50% 2.40E-03 3_50504 50% 4.50.3 250E05 98.091, 8.80203 170504 8.80E-03 130E-04 96.0% 206 7505.] 00% 5-0 90] 0 1.402-04 150506 00% 000.0 040500 8.10.6 8402-08 0.0% 9.70506 810% 18.6 01,0% 140405 50% 5.10E -0l 88.096 950% 130E. 75.0% 110EM 85.0% 1,10E-04 100.5 0.096 2.50.5 2.50E-06 0.0% 250E-04 350.6 0.0% 2402435 240200 0.80205 9.70E-06 0.0% 1.40.2 520.5 ga% 7699.3 85]01 0.10501.103 00.55071 96097879 0.0.64.3121 0.811782545 0603205564 0602510573 09.1486552 137 0.208591323 005075229 124208 840&1890 0.013195751 06°0°51111 107181. 0.008301]37 0..6511427 0.0015842 0.001.0607 0.0368617. 0.208411012 m0110.1 0.000142557 0.0001.213 374003 0.020050014 0.0 5732819 0.1527% 0.002]56132 306524 00099527 0810267957 0x04210]6 4044 m-Em4rlons heaemo21 operator a 088827 Regesre... Buffer (%): Pollutant VOC Benzene Toluene Ethylbenzena Xvl nos Uncontrolled EMI.. Con.. Emiss.. Source 100.61 879.63 tov itior Iblyr 16.79 120.06 391688 Itlyr 43,65 11.75 15.11 10.42 12.85 0289 43.94 1.10 8.57 0272 3.096 0.00 1.07 221 Ibkr Ibbor It/yr Itikr iblyr Sano2N EFs-EFA.4531R-95-017 Tabe 2-0 Standard EFs- 5-017 Table 28 0.8153/0-95-017 Table 2.2 Standard FFc- EPA -05318-95-017 Table 241 Standard EFs -52.-453/2-95-017 Table 2d Standard EFs-EPA-4536,960V Table 24 Standard EFs - EPA -453/B-95-611 Ta de 2-4 224-1141 Methanol IQs Mmny1M12ylan de s Itlyr listyr INyr 5312-95017 Table 2-4 Standard EFs E25-453/595-017 Table 2d Standard EFs - 52..453,1-95. W 7 Table 24 knew Reguktion 3, Part 6, SMbn 01.02 to de.. 5 FACT is required! R0Vew40 CFR. Pert 60, Subpart KKK to deemJne 0 mplIW51e te his 0451601 RaMky 40 CFR. Part 60, 320ryt 0000 to determine 218.5380 0424180.536510 08..6,RautewSekion XNI: a determine is MAR Is applicable, Rebula6onl • Section 11A1-awakespmrided in ragraphs...ugh6 below, no, roar or',para.'s(a source shall allow ofeatise he amissl04 into the 4bn.phem of any air 9116:44 which is in excess 820% opa41y. Th. ...08 is8.019 34 ......82 teaanec 4lsn att5-secend(nerreb for. rnnutes.The e Movai reference fa. method IBMsibe,0ssions meas.... EPA Methed 9(40 CFR, Part 65, App4n4MA(July, 1992)) In ell subsections of5e45on II. A and 0ofhk regulation. Fyuletlon2 Section Poperson, wher.er located. h as to nlsutt N detectes blel odorswhichmuse or 0 arshmeasured in ee emission xcess of the following limits any single used predominantly the For airhaedb,, 2lltrwmsldeven ecommercial oreyr.es8purposes. avloitlon ifotlmsamdemcletl WW1 tim odorwcairnu been hlmedu8n wren 014rmorewlumesal4d4r0aeair. 50901,64,4 2,141,Pollutants, For criteria 7411.44., Air PallutantEmissgn Na4ees ere mqulmd hr eenh lnda250l mkslon points a non-2144,ment area 000 ummn0o410 actual 000200s of one ton per 00,4 year, more of any ndividual cr.. m.1lutants are not aumreot erwhkh he area is n4maminmem. Appikant k required h glean MEN since emissions exceed lion per year Vibe part 10 —Construction Pernik Exemptions ;Walk. K required to obis. a permit since ummnholled VOG emissions horn ilia facility are greater than he 2,0 TPy threshold (Reg. 3, Pad 2,..uon II -0.28) la he source located loan ozone non -attainment area 4r attainment maintenance area, If yes. Is t0k source wyect to leak de.c5on end repair(LOARI reggmrmnts per 9.2188 9, 6.iiin 125IF 8..0 or 40 CFR. Part 60 Srbparm KKX 0000.8000069 Part 6,11301- PACT requlremen6for newer modked minor sources Thk section of Regulation 2 requires FACT rear new or motllged minor sources belated In nomattalnmeet or ahahmentimal.nan.e are.. This source is located hike .our ozone The Ems of8,remlor d.rmlning whether the source is newer modified is 448810]8 November 20, 2007 [the date of he.031our 40 ozone Mar. 2.1. 15 since ..g... win he. .8ee 494/ he date above... source Is conslderetl vnew or motllged," The epem0r Indicated hatequlpment located rt.. facility forhk source is sable.. NSP0 KKK, 0000 a.based on he m322.0,0 date. N4wswr, he opera., h. chosen to 04450,1. nwih HOPS 0000a for all fugitive components at Ns facllly. Fel:owingthe leak deedlon and repak ram per NSP6 0000a satisMm the RACT requlrtmenh of 2.21 383, The permit will con. a condition refleeting his d.rmination, 22369974 00554]99] 00.515. 000105878 00076232 0.24701292 0.002752%2 0.0000945219 003116465 024365407 019111035 0.00460.589 00334]910 1.08451858 .003971 0.00325492 0.00511480 112 0.43961392 0.0311963 0.34496555 0.0204898 0.0083934 0.0005.3 0.08043215 0.0042865 1.95817916 0.1399919 0.02182283 0.0015479 0.00507538 0.000418] 0.00755408 0.0005358 0.039'232]1 0.6006549 14W mass fraction 2000.6 5.214502 1351.3 13502414 204450:4 CO2 methane Ghana 21.6422 12.5601 2.0760 4.5055 13245 .3802 9.1142 kohulana 1.560.2 4252502 1.2132-02 5.6412 7.0069 0.0000 10518 0,0000 0.0000 4.5173 0.0000 0.0121 2-0 0.0002405 2323203 .002405 0.0000 0000 Other bananas 5,Msns inethylcyclohexer 224-7512 Benzene Toluene Ethylbewne Xylem. Methanol (34III 1442141 122 ) met. merceokn 1404 Ce+Hes,. VOC mass 0.2151 22,7699]5 100.0000 IMtlmcarhrnaMass Frei 9.446.1 0.0000 3.2532-03 002408 2.6002-05 5.240504 0.0005 05,528 102 0.1011 0.0046 1.0002-06 ' 22002-05 20 .00585 1200205 1 105-0:4 .011 6.076 0.0007 0.0010 0.0403 0.0033 0.0042 0:0051 0.1772 Fugitive Emis;icns ineenttory Regulations le Hissnorts at an onshore-naturalgas processing plant- as defined in 40 CFR Pan 60.631, Did cols source common°. constmalan reconswc.n or modiScadon arse -January 201864 r y before As edabove. discussedsame equipment covered under miz source maybe subject. NSPS I.I( has. Wthe date.wever,e source has chosen m voluntarilyvoluntarilycomply.. NSPS 0000a for n thecocomponents atthfacility. OW source commences construction. remnseumon, or mMRaeon aherAugust 232011. toe September l6 2015, 20151 As d.cua5ed shave, same equipment covered under this source may be subject. ASPS 0000 ..,.�-• based on tha constmetion dab. Howe., Me me has chosen . velum:wily comply with NSPS 0a fin alli to .. comnoeen<s...acie... Regulation, Is e source located in an ozone nonalanment area or attainment mamen5nce area, is Hie sours -eaten ons.re -natural gasp0cesang plants.. defined... CFR Part60.631' ', y or Facility. 055100* as a natural gas processing pant ma TM1erefore, this soe. subject. Regina.. Is the facility classified as a well production*city or nateral gas compressor satpni ART4 •, facility is not cassMed as a well production fa.. or natured gat compressor station, It Is notsubject. Regu.tron 2 Section AVILA. ',ea...,e Is M. source at a•natural gas processing Mae as damned "n 40 CFR, Port 61,611 le 5¢ reality considered a'mjer spume. of HAP as specrfiwM ceaned In 40 CPR, Part f0.261 A . ere not'.... on 66410,, t'es? N If, repond ryeryes. to Westions above. HMIthu pr ers...o... of 40 CFR. Pad 61269 Leak Standar.' applylH So.ce Is not subject. MAST HH because...sillty Is cla..1.1 as asyn.etic minor source of HAP. NAPS 00006 Old this source commence constructor, reconstru.o or motlecxtlpn alter September. 21115 ≥ y Is this sources at a wall site compressor sa1Sn or onshore lnalstral gas processing damp as defied in W2 CFR, Part 60.5430., y an.r. facilitymeets.. definMen of onshore-a...a1 processing palSS 0000a. As at this acliPy are subject. ASPS 0000a. As discuss.d .eve, some fugitives someone's cozvered under ...pure. may he subjects NSF. IOW of 0000 .sed on the construction des.. However, the operator has chosen to follow NSIS 00003 tar all .pltive camponerrfs aft, act., Section 00 -Technical AneM6 Nester J.. Weald for v.Wesn ISp4140 (96%ln10050 In Ass se ,ce i56%),onnectorsarts rtango] asamtll glt[�Ig42 { 'slant pumps in Igh.liqu14 cirvmis%larebassdobthebna10044 osgand NEs 0nd „antral .Recdven Me EPA Promcak Egop an I0'orufazimatesl P,14./0. AS.017) Inented dlereetulataryana*,.abae result, me sources o 0mplywlib1le pauldsufhl..v*,4110easdefru p50000znsa i lam[ ,10 lemelamd pomosInb.114u z ttas. nentososv0vdwA7THarfi-nary 4th ar:Aza 1004 def.-nun. 70 tfremltrole tis=sue wrh0 ncf q urn - ura aepo on tit tt- • IN Anti tl wBNsereress { dot e. fn v valuuare Iht. aesfprzmlrces ubru 0000aandfo bwingmrm 2.T1 s'al n. shq.10 04 40010,0 g alt f r o <01140 IYOm76,44 lines ]6%and ItlDther IS%,111€,. meep m1Y t rem. o seasons why41010010111111000164400,5070500020f eml.go ese mnva Sur a molrn10V r cram me a�iva emiS (pwidt ,00 ¢dOnludrkh 09_,6zrcctoss a arsmou nor j eel'uta0ammn rePet0epdrgW del ! n 01 611404 Inc wM1ede.sohddr,ge iseonsjtw] Atge tlmeVssmri�' malpdmi la'iNs acBry'a duntler mecrePu. tanryc0mprymg • na010101. ed n f sso Npreu lues(aza a . tesStries,.tas=ty s s oa te1M0Omramf5B nt10A0per5SP50000a.nallfugi fat ▪ Ngtrve p TCeVbasa mntNpermntageval o0raamglop<n.M .,00 1ls,�a.aorz/Pav)Samp rig bee tripped ts,„ blind .nge,plos orswond salve to scat Melina Pm reputransansis to Me seaulmmenticrapen-eusi. Imes under .15 visa; AddOl ly. 'e p0Eq 1.0Arzp pr 'r vgUzand so'rs{oN o[yf h f mitts of the i[F OnWprog m it Acant • tlnmd grgizsance. ire nSiuet naatc,N Baud .460041st e spy _d.zbeem nzlrmn mttp.H ma edtbe111 _ g, y" 095%m assumed 00044 „muse a 964 only. for schei Sal e: I1 erne146041,14 h=.exfi 44% sM1e-fd5P5O0oD'0ARomp reds¢ .owe -0014 140/1104<nry M/w 4410 0 744000 Tuul'Basi. Me mfm • cpf�u ,a6f,cam 011 ipso= 2PemrNn n 1 of 6 adrrsies.. n feu wssi reapatdaay. 4 he VOCaM Hnnmaight%a ssehf« razed tz[n,m rh<M0.mmh pl b 2014 Shame. fractrostsweserorreas. to a,o ..514 ngaOPdowmt «frval .e0�s prawm,.rax;ia,�p q r 1044aam4m re for ltlial'ga'M<mpS.4100 ¢,wnn (ee rideetluodei 4j Thkmcua le o[WCand NAP we 1e2nd 104".6 amlyss. ns_ as 00'6. _ .our. g W. �• � M H 0044luesio - d - 1 ..posed p -v aga(K Ass eMoa x11100 wagbtpera wuesalWm0101 harems 60th O4 rm me en,i:v, edncsampk=mina, all .sin Per11, parmew a roes gxsan rue rd toadem Me I mite., e limbos erm t 51100 on drc.moon rrs bases. n „desIrea„My g2d26 W.ab4,4 ntofp0cnaa `u z..As permipwl daa�ltra4 1 kiN omplere 0 844 010167th ,s balky 01gl4rArd55Y3haw .opted Into Clore Asa'msuflth rrdl0ogrefe o I6< d. n,cne t permH.haae xmlogof..epprtl c, 4,As0zaezedabbv m.Aa1C.zensappytl¢.mn raed1 n ors{8f%)s6arrges.3ltbcakdmlm uazameped forty t e..rc<n¢go tic lemeno's ahrs. t.„. the Jlonge9 suewe.m-tfi .p.r• dtecrcoupiate ti'1Wd'et ry754011 *540Vdbemme .=bets 4080th weMetl<m406006011.6dd'*M ep(.a erkc d n ofsxregWadOn.'Aszr ix 'mrdy s . bus' Wngttav ' e s -es uwetMcmuep tnedeininan.mererco-c m<mnm0i. w g.fora= ungembaoeA hom6oH=omppnent;ypoi aer�p.6ie:' -'-" „ . be nos rod 0CC gets Sectlort p1 pro fog0t vdaU(eorganknundemz4o urnk0M'.rlgi4upm mtbe .4018e'eiilo andrepa 4140410 a110100� E art600,00 OO0,41.'y'811414,,. pp ks regnd osrFN eotcgreaucmngimeaffeaed foal ry,vnksszdeiea sob t aoiprwi-'YLFR�er50,.66. 0 10a 00,1. 20.4- As arasult, wlh atN uM. c r,dre p OOOCnhr.„ ...Ps. S000010e end Emla.om Fecmn Process If 01 Uncontrolled Pollutant Comsat. Source Varl. by ies by component component... 4456 tae Stan.. FFs EPA -453/1-95.010 Tab*M Varies Varies bym5Pm6nt eensne m130140tl002 type Standard ETe-EPA453m-55410Table2-4 trades by Varies by component Toluene componentpe type tySarea.EF4-EPAd331S-95411Ta6Ie24 .m by Va.o by someone. Ethylbenaene c omens type type 3andard EPs-EPA-453/1-35'01, Table 2-4 robs IMO. by component xylene component.. tae 5an4ard EFs-EPA-45311-85412 Table0.4 Varies by Varies by component n-He0ne mmeon.nttypa type standard FFR-EPA-4531A-9541T Table 2.4 Varies by V aria by component 224TMP component type tae Sardard EFs-EPA-45315-9541,Table4'4 trades. Valles hymmpoent Methanol comment type type Standard Eh- E1044343A3.010Ta2.21 vadohy do bymm,orcnt 1QS component type type Standard EFs- EPA.4221R.95410 Table 21 dohy varies by component Methyl ercapan cnmp7ner05PC toe standard EFs-EPA-4.5311-95-044 Table 2-4 Hydrocarbon Loadout Emissions Inventory Section 01 -Administrative Information IFaNRy AIRS ID: 0090 County 109 Section 02 -Equipment Description Details Detailed Emissions Unit StablDzaf6 Description: Emasion Control D S`'``.°i+ Description''` 0 this loadout controlled? Requested Overall VOC &HAP Control Efficiency %: Section 03 -Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Leaded= !Requested Permit Limn Thro ugh put= Potential to Emit (PIE) Volume Loaded = MONBMIENNEEM Barrels(bbl) peruser Secondary Emissions -Combustion Device(s) Heat content of waste gas= '$sA Actual Volume of waste gas emitted per year = Requested Volume of waste gas emitted per year= Actual heat content of waste gas routed to combustion device= Requested heat content of waste gas routed to combustion device= 200/000/ Barrels (bbl) per year S'.. yjM,F, \'-,i'if00u,➢00',,t,Barred(bbl(peryear W s% Potential to Emit (PTE) heat content of waste gas routed to combustion device= 339033:/Btu/scf 24602 scfNear 276185 scf/year Requested Monthly Throughput= 10985 Barrels (bbl( per month 04 MMBTU per year 9455 MMBTU ger war 045 MMBTU per year Assist Fuel Use Rate: Assist Fuel Heating Value: Pilot Fuel Use Rate: Pilot Fuel Heating Value: 1200 son 1092 Btu/scl 40 s;rn 2050 Biu/scf 0 MM 11479,104 MMBTU/yr 0,42 MMscf/yr 441..5 MMBTU/yr VOC and HAP from Assist Gas Combustion Throughput (Q) 10512 MMscf/yr >?.1813 lb/lb-mot 1200 0,0288 scf/hr MMscf/d loess :=_coon Ib/hr lb/ yr toy Helium - 0 000w0 0,00 0.00 0.00 CO2 1,649E-02 0.96 8367.82 4.18 N2 ' 4713EM9 0.27 239216 1.20 methane 7317E-01. 44.71 391699.53 195,85 ethane 1.316E -Al 7.68 67248.06 33.62 aware 4.302E -0Z 249 21837,25 10.92 Isobutane :'.6.0120-03 0.38 3356.06 1.68 n -butane :'. 1.534E-02 - 0,69 7763.61 3.88 isopentane -3.590E-03 0.21 1822.18 0,91 n -pentane `> 3.730E-03 022 1893.24 0.95 cyclopentane 0.000E300 0,00 0,00 0.00 n-Hecane 2.308E02 0.13 1171.48 0.09 c3cleheaane 0000E+90 0.00 0.00 0.00 Other wanes 0.000E+00 000 0.00 0.00 t'splanes 0000000 0.00 0.00 0.00 ncllrykyclghaiane 0:0000100 040 0.00 050 224- MP 0.0000:00 0.00 0.00 0.00 Benzene 0000EM0 000 0.00 0,00 Toluene 0000E+0R 0.00 0,00 0,00 Ethyberaene 0000E+0fk 0.00 0.00 0.00 Xylenes 0.000E+06 0,00 0,00 0.00 C84 Heaues 0.000E+0Q 0.00 - 0.00 0.00 VOCnrass fraction: Section 04 -Emissions Factors & Methodologies Doesthe company usethe state default emissions 0.0740 Total VOC (Uncontrolled) Are the emissions factors based one stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation Cs 12.46'9'P'M/T 18,93 i0eed hgdroourbon liquid sample is voila for developing site specific emissions factors. Factor Meaning Value Unit Source 5 Saturation Factor 0.6 ��y�� (y!¢2e'°4/i ' /d0042;1Wir-sto 0.021052.1 h"vme'd ing.-bedreatedka:mai<e3ca 100.0). P True Vapor Pressure 5.6032..-.: :-. psia Average vapor pressure from EPA TANKS 4.0.39 w1Gasolma cot, to racated in 0000ertCO M Molecular Weight of Vapors ;- 66 '::: Ih/Ib-mol A Chapter 7 Table 7.1-2.0VP10 T Liquid Temperature ,,. „ 512.051,: i'.,,, Rankne a :.;. Liquid Burke n10/Tanks 403d w/ Gasoline RVP 10legated h, oc0000, CO L Loading Losses 4.017365452 lb/3000 gallons ,.. 0.213'2329348 lb/bbl Component Mass Fraction Emission Factor Unit Source Benzene ➢.013251':u�/2 lL 0.002088957 Ib/hbl C 41 4tabiik domldans ₹e Fame) k? h0 wb reg veaels 03/uu/zOen Toluene - & ➢0386304 '%'3'i' 0.00745179 lb/bbl�," Ethylbenzeno m,,,:iroomorommv 0.0005 0192 Ib/bbl Xylene'.0/hi/A>0. ➢ 02794: r 0505682340 lb/bbl n-Henne Ma,WPAVOMV.MOVON0.014468572 lb/bbl 224 TMP ,.`:*..,, .a0➢W53 '., .. 1.07237E-05Ibbbl / 8 of61 K:\PA\09\09WE1336.CPS Hydrocarbon Loadout Emissions Inventory Section 05- Emissions Inventory Criteria Pollutants Potentialto Emit Uncontrolled Icon/vearl Actual Emissions Uncontrolled Controlled hees/yearl Nos/year) Requested Permit Umits Uncontrolled Controlled Imm/vearl 1.m/read Requested Monthly Limits Controlled - (lbs/month) PM10 PM2.5 500 600 VOC CO 0.94 0.000 0.00 0.04 0.44 3 0.04 0.00 0.00 0.04 0.04 n 0.04 0.00 0.00 0.00 0.00 1 0.50 0.03 0.00 0.079 0.575 440 39.5.,3 2.14 0.11 09.1: 5.959 503 3.43 • 0.04 0.04 3.432. 3.432 563 Hazardous Afr Pollutants Potential to Emit Uncontrolled (lbs/rear) Actual Emissions Uncontrolled Controlled IIIss/earl Ilbs/ycar) Requested Permit Limits Uncontrolled Controlled Ilbs/y arl (I6:pearl Benzene Toluene Ethylbenzene %ylene n-Hezone 224TMP 53'029 56.94 4.05 59'7.?0 24.09 1430.03 157,79 7.89 1400.36 74.52 . 111.04 21.70 0.49 13144 5.55 11.6.57 114.20 5.06 112657 50.33 2090.71 306,37 15.32 4065.97 ' 24.4.04 2.14 0.23 0.01 2.14 0.11 Section 06 -Re euletoor Semite Analysis Regulation 3, Parts A. B' RACE -Regulation 3, Part B, Section IILD.2.a (See regulatory applicability wnrloheet for detailed analysis) Section 07 -Initial and Periodic Samnline and Testlne Requirements Soutr.'0 044nifes a permit' The loadoot mflitoperat2 with submerged fill and loadout emissions mint be routed so Ogre to satisfy RACT. Does the company request control deVlce efficiency greaterthan 95%far a flare or combustion device? •yte -1 If yes, the permit will contain and inrtRIl compliance test condition to demonstrate the destruction efficiency of the combustion device based on Inlet and outlet concentration sampling - 9 of 61 K:\PA\09\09WE1336.CPS Hydrocarbon Loadout Emissions Inventory Section OS -Technical Analysis Notes LThe.rnple used to estimate the NAP emissions from this source was obtained heard. Mewbauragas plant on March 11,2009_This sample was used to estimate the HAP emissions inthe CPS Tileemtsh isstran.pf the gem..Sine the operator is only requesting to increase the throughput m this issuance, it was determined that a new semplewouif not he requiredtaestablish new emission facto.. 2 The404 weight °%'values -from the sample analysis were corrected. byessuming the entire sample consisted of VOL.This resuhedn a conserve... estimate of the weight%values and wasthus accepted for permitting purposes. The corrected}1AP weight%values corrected using the following calculation: corrected weight %'(wt %of censtltuent)/(5OCwt%i'(?D0! (g Benzene: (13287%199.98%)'(100). 1.329% -:. (it) Toluene: (3.6822%/99.98%)'0007= 3.083%- (10) Ethyl%enzene. (0.2743%/99.98%).(100(eo 2744% (N)Xylenmf2.7832%/99.98%)*(100)= 2.784% (v7 n -Hexane: (7.1492%/9998%)"(100)=7,151% fxif 2,2,4-TMP: (0.0053%/09.98%)4400)= 0.0053% 3. Based o,0 information proof dedbythe operetor,themnissions oesult'hgfromthe loadout pperaefop are routed directly From theeankertruckc to -an enclosed flare. This enrtosedflare e: ilk usedta central emissio 4. mord.- to calculate combustion emissions, °pelmet calculated the volume venteddudngloadout operations using the ideal gas law (PV=nRT), The values used in this calculation areas follow: (I)n = (0,2023316/bh(' (200;0006%1/year)(t ib-cool/661%) -. 613111g limmni/year_ (It7 p _ 1212744 (Oh T= 512,45 R (52.45'1 (le) B = 10,731 psis"it.3/00b-mot V=(613,1217 ib.mol/yearr(10.731 psis•ft^3)/RMb.mol)'(512,45R)/(1212psia)= 278,186 eel/year Typically; the volume -ofwoste gas vented during loading operations is ealahhted using the.' following equation: Volume (sot/year). [Unconimiled VOC(ton/year)]•(200001/tonl1iMelecuW Weight lib/Ib-mdl)jaj3795cf/Ihreolj:Ubingthis equatIOn,thevoWme vented ft calculatedasfollows:41202931%/bbir(200,0006b1/year)/(6616/ib-moll.(379 scf/Ib-moll=232,373 scf/year. This value Is less cons, rya... than the value calculatedby the operator -Asa resuh, the operator provded halo. far waste geswlame will be used foe permitting purposes, 4. Theoprratordeterminedthe heetvalueUsed ;in the sombustiar Calculationsthruugh interpolation: BaseddotheastomedRVP of 10, thecorresponding Molecular weight (MW)'was determined to be6Edb/Itrmol based on AP -42 Chapter 7Tabie 7.1-a. Basekanthls molecular weight k woo assumed the heat content of the gas would fall between thaeef Butane (MW-58,1221b/lb-moil, Heat Content = 3:0042 eta/set) andPentane(MW = 72.1491b/Ib.mot,Heat Contents 9,699 8tv/,ctl. Aping the moleeularweighf and heatcontent of Butane and Pentane, the operator interpolatedthe beat content of tbewaste gas to be 33973000Joof. This heat content is the net heat value (lower heatingvatuo) which is less conservativethan the grossheatvaiue{higher heatingvatue(. However, theTNRCcdocument specifically identifies. the use to the net heat value for NOx and CO emusmns calculations. As a result, the use attic net heat value is acceptable. G. The NOx and CO emissions associated with wastegas and assist gas combustion were calculated using the emissions facors€rom the TNRCLTechn cal5uoplement4: dares. The emissions factors used are 0.1381%/MMBty and 0.5496 ib/MMOtu for NOx and CO respectively -Based onthe document, the emissionfactor utilized far CO isfor air/unasseted flares with a waste gasstream that has a law'Raceme:h. Thedoc...dehoest= Mu content as 192-1,008Btu/scf-Technically, the wastegas would he classified. high Btu ccordingta this document sincethe waste gasheat content was estimatedto be 3,397 Btu/scf and 1092 Btu/sfi, however, the emirs on factor pro,. ided for tow Btu is more conservativethantheamisslon factor provided for high Btu (42755 ib/MMBtu7. Asa result, the operator estimate ofemissionsiserrs rvatweandthereforrecceptable, ... 7. The operator did notdalculate PM emissions assacated with the combustion load°. and condensate tank. missions that +_routed to and controlled bythe enclosed Hare(1ohn Zink, 2CT.1.435.3.1/7(,-The operator asserted thetsince theendosed flare is designed to be a smokeless combustiondevice,particulata matter is not expected to be generated from themmbustionof condensate tank and loadoutwaste gas routed to and controlled bytre flare, address thf5¢'tatetnent,tho emission factor source for combust. o 'salons (NOx and'COLthe TCEQ"tachnioelsopplement a flares" w.revIewked,SIMIlarioAP-42.thigdaturnentdoer not proubdes 'Mahon Ion with regards to PM emissions, AP -42 Chapter 13,5 was also + eared -Thin document expresses .the "emissions from flaring may include carbon particles (soot)., unburned hydra cans, CO and partially burned and altered hydrocarbons:d'so emitted are nitrogen mod.(NOx) and, gauger containing materialsuch as hydrogen sulfide or mercaptans is flared, sulfur dioxide (502)." Based on this statement, the document does not provide information with regardato particulate matter, except with regardsco soar. The document further provides that a smoking -0.e directly results in soot formation when it states "The tendency Of a fuel tociPOke or make soot N influenced by fuellcharacteristics and by the amount and distrlktttiol¢ofoxygen in the Combustion?one'This is furtherSuPPOrted b9footnote°o" beta. table 13:53- which providesthe following..Soot concentration values, nonsmoking fl res,o'micrograms per liter (heft); lightly smoking flares, 40 pg/L, average smouingfllares, 177 pg/t, and heavllysmokingferes,274yg/d.'r At this time, there Is not another eo ice ofdetathat'quenttles' PM050e P542.0 from fedustriai flares and therefore it will be assumed thatthe only source of particulate matterhom a flare is soot from smoke as expressed In AR.42 135. It s%ould: be noted Mat the 0&M plan requires that daily checks be conductedto determine if the enclosed flare is smoking If smoke is observed during the daily check thosource is required to erthar conduct a method 22 or immediately shot in the equipment to Investigate -the cause of the smoke and conduct repairsas necessary. Based on this requirement forth. enclosedflare and the manufacturer design rhrdidenclosed Bare ta be smokeless if operated property, can safety beassumedthatthe enciosedflare will operate without smoke on a regular basis.Aso, if smoke is observed, the operator will be required to assess the problem and perform necessary maintenance. to preventthe enclosed flare from smoking Assbch,Iam. comfortabieassumng a soot concentration of a microgams Per liter or provided MAP -4.2 Chapter 13.5for msrnmokingflares- if the total PM mission faster of7.0Ib/MMs{fsonsAR-42 Chapter 1.4 were used, the total PM emissions(fb requirements. ouid he below APEN thresholds.As such, the emissions would not result in permit Smitsfor PM or result in additional regul Bas ed on the Information dIsc.sad above,¢was determined2hat the operator's assertion that asmoiteless flare would not be expected to have PMembslonsessoclated with the combustion ofwastegas wine acceptedat thistlme.However, if better data is developed In the future forestlmating PM emissions from Industrial flares. it should he included in future analysis.. B. With this application. the operator has chosenta reduce the permitted throughput forth. pointfram 912,500 barrels/year-to 200,000 barrels/yea. Thisopdate was madebeause the facility. equippededthu4ease Automated CustdyTtansfer(tACT) unit, 700 LACT unit sused to transferee condensate from the storage vessels directly to pipeline. This operation reduces the needfartradkioneltnockleadipg operations. The operator h. still requested to havethe abi0tyto loadout a portion ottbe condensate raWtingef tbis#aciilty using truck ioodovt. This is necessary because there are periods of operation when the pipeline is unavailable and the condensate must be loaded art usingtracks. 9, The previous permit for this source did not contain limits en NOx or CO. Th. decision was made because the emissions are below APEN thresholds. In this issuance of the permit, Safi. will be included for both NOx and CO even though NOx emissions remain below APEN thresholds This decision was made because the operator is establishing NOx andVOC limits in this permlttoavoid other requirements. 40. The combustor used to control emissions from this source has emissions that result from both Out light combustion and as combustion —Since Mese emissieoscontrb to the overall NOx, COardVOC emissfoniimhs contained in then rmtr a limit on pilot, 1'gtr and assist fuel Mmbustian was Included In the permit 11. The operator provided the fallowing informetionwith regards to assist gas used bythe enclosed combustor."!: stens Is not+seeded to increase the heat content of the condonatetank orbadaur vaporsroutedto theonebsed combustor. 7bnemissionsfiennthe condensate tanks and loadout are not constant Therefore, there is not a steady stream of waste gas amng m the ECD. The adduronat gas is needed,. maintain the temperature of the ECIIso that It is always; temperature ready when There teapots from the. condensate tanks orloodou fcoedeosote, WHenrheynctur, amrreredrothe 0f6,." - 12Th, operator reported actualemrsslo s on the APEN submitted for th.source. No review of actual emissions alcul.lans wit conducted as part of this mview,As a result, actual emission information should. referenced on the APBN, not in thsanalys., he operator indicatedthat there is not carreed,/a method tomeasured. volumerFasaist gas utilized by the enclosed combustor used et this famlity.The operator has proposed -to install a meterta measure this volume as part,*the .self. 5errBicrationredgitements atty. The operator will 'mike the requested assist gas rviume in orderta demonstrate coMplle.e until the how, meter O mstafted. Once the meter Is. 'totalled, the operatorwill be required to monitor and record this drta continuously. Section 09 -Inventory SCC Coding and Emissions Factors AIRS Print 109 02 03 Process# SCC Cade 01 4-06-00132 Crude Oil: Submerged Loading Nomral Service (S.3.8) Uncontrolled Emissions Pollutant Factor Cannel% Units PM10 0.01 0 b/1,000 gallons transferred PM2.5 0.00 0 b/1,000 gallons transferred SOx 0..00 0 b/1,000 gallonstransferred NOx 020 0 b/1,000 gallons transferred VOC 422 95 b/1,000 gallons transferred CO 037 0 0/1,000 gallons transferred Benzene 6,401.00 95 b/1p00gallons transferred Toluene 1.72E-81 95 %/1,000 gallons transferred Ethylbenzene 1.3:942 99 %/1,000 gallons transferred Xylene 1.32E -01 55 b/1,000 gallons transferred n -Hexane 3.4=9.01 50 b/1,000 gallons transferred 224TMP 2.55E-04 95 b/1,000 gallonstraneferred PM10 :,8435 0 b/MMSCF PM2.5 0.00230 0 b/MMSCF SOx 0,gl0 0 b/MMSCF NOx 102.0412 0 %/MMSCF CO 800.07066 0 %/MMSCF VOC 5.0315 0 b/MMSCF n -Hexane 1,8329 0 b/MMSCF PM10 8.1305 0 Ib/MMSCF PM2S 8.1'_8x5 0 b/MMSCF SOx 0,5024 0 b/MMSCF NOx 250.6900 0 b/MMSCF CO 8003652 0 b/MMSCF VOC 808190005 95 b/MMSCF n -Hexane 10101'7 95 b/MMSCF 10 of 61 K:\PA\09\09WE1136.CP5 Osclamer mmemMmta m.�. m ,Turbine Erc:issions Inventory l iatllryAlRS IO: �"''' UmY ,_ 1ri1}2;",!% unry ▪ hsbm for pound Its -111 wen estimated through the ammo method. A* ouch, WI apm.sh,. provide* an anahoh tor bath turbine urih as 'minions am W ont., from aesh. , anion m-E9ubment Description Walls Detailed I1�So4a.gt$t W,a,t, 3T-m;grniaF u etullex OesblpJan:.v.arsU PAtThkmbimicused for nanJral , Enesilon Control Device E9ugpaawrth vatleil OuWPnm T+tzmh cons ,F054 Jr •h. Requested Overall wC&Hap Control = EH.ciency%: ,; th mmeidered an Integral control device. Section o3-Proce,abg Ram Information for Emissions Estimates H. Input Rate. ,,, .✓rd Heatmntan[ piwaste gas= Actual Hmmaf OperaJon- Requearea Hours d CP..Um = Actual heat Input rate= R.I.. Mat Input rate= Patent., m Emit (Pip heat Input rate= Actual Fuel Canwnptlon= Request. Fuel Consumption= Potential [riEmit IPiEl Fuel Cansrbpilon= Number of tub. startup events nom persbrtupepmt Numberm:Nrbhr5hmd a e. Number per s nv alneow seven events ram. x.axpmpwn event VCO N neater 938,rAF ta .MEN per year A3a,. spdp MMBN per year Ertl Woof/year A,ssna Whcf/vear !7&.9349 Whet/year Emisslon Factors Emmwn Factor source Uncontrolled ion ll6/hrin.a i e 1 1 wntp voc NO co a fmtsslon Factors Turbine Emission Factor Lure pollutant unIl16mta.n ah/nvamia (Startamt Isla u evantl VOC iLar & Po, NOx CO 19 479.1,10 RAPA\a9\a9wa136.cP Turbine Emissions Inventory M E*kminwmery prod.M a. wdy:snte O ..w. • C.. Pollutants MOS Potentiate t Uncontraled ItosAearl Actual Emissions Uncontrolled Controlled IwaAesl (mm/earl ACID 0 CO Iwo a ed Permit Limits UControlled Nom/year, ltons/Yearl Oactrl 0.660.7 OOP O. 6.76 6.70 1.3.16 .12 On 11.06 12.36 Hazardous Air Poibnnm Formaldehyde Awkehyde Acroloin Potential ma. Uncontrolled {tom/Ye-ad 1,60,01 Ames Emissions Uncontrolled Controlled OewAead llons/yearl 0.0.606,06 Ohneriln OOPIEONI Requmted Perm Un controlled Controlled fmrohearl itonAwrl 1.362,01 Requested Permit emits UncontrollControlled nbs/seade limAwrl 16.6616 31.16,393 17.5516 2.633.6.01 0..06600 0.1861 0.160, 16 56..25 0.6563 26,26 Ethllbe con Toluene 7.0216.03 066,66. 66m0gw0 67..26 11,6656 PAH Saone .1.607,04 Criterla Pollute. VOC NOa Potential to colt Uncontrolled ItomAe.rl 0661 oro Actual matrons Uncontrolled antra. (m,./Mrl 1.m/war) 6.00 0.0tr Orltr0.611 Requested .trolled Permit Ult.Whe.rI Controlled Itnn/warl 6.23 n.av 0.911 Cote. elute. Potential m Emit Irons/yeasU,ws/yearl Actual Emhsdms Uncontrolled Controlled (tons/wad Requested PVT... Uncontrolled Contra. (wsoeanl Rom/Year) VOC NOY Oa OOP 0.00 CM OW I car O.00 MOO 0M 0.m Section.- Reeulatory summary gnaMl Repletion Salto IIA.1-Except mproaldd rte paragraphs 2 through 6 below,,. owner or operator of a source shall allow mouse Me em6a'm Into the atmosphere of any air pollutant which is In excess of 2096 opacity. Thls 4ta.ard is based on 2<oawecalve option, rwongs mien at 15- seocriclIntervals Ocala mlnutes. The app.. reference test method hw9N r e emWo lameasurement'stmeasurement's RGO, EPA...9 (COR, Part , Append, A lluly,1s92)1 in all subsections of Section II. A and B of this regulation. SectionIlLA. No oer ore operatoroor permit to be emitted into the amosphen any fuel-bun-Ongequipment W ashen shall a the matterIn Me Nw g II.L.Al.b. For fuel burnIng tlalgnd heat bleu. greater than 1x10.Bm m Mn per hour, balms equal to5ma10s BTU per hour, the fallowing equation will be used Co determine the allowable paNalate emhulonllmkatlon, ms(el9e Pan Pardus.. Emimm In Pounds s per million eheat input. Fie F. Input In Million Bm per hour. The turbines covered under pants 1116112 hew a design heath,. Me ns0.o9 6 6:/Nr. Asa ,wult,Ml mhkw an subject to Orb no Using the above equation, the allowable par. . emission llmbetbn 60.120716/MMgtu. The AP -42 emission factor of 6.644 Ih/MMqu used !nth* olabtbes a9ava 6 bedew M6 particulate emission threshold. SectIon W.. new...606w.amide shall not emit w muse to be emitted sulfur dioxide in mns of the following pmxss-speoflt ...eons (Heat Input rates.. be the manufacturers guaranteed rn.mum heat Input rates) s.. ). Combust,.Tuklnes table heat input of less den.° m6N. BTU per howl 0.gponnds of rulhu rile.. per real.° Ism of heat men. The turbines mwred under palm L116112 112 hew a design heat input rte. a SILOSMMMBu/hr. As a result, the turbines an subject to this portion afthe regulation. The AM seeks. f.worof3.4110'W6/MMmu used. tienkulet6w ahem is belowth0 sulfur dbeideeemMbn threshold. RMu6tlsn2 Section LA -Noe wherever Land, shall rase or alive the amiss,. of dame bfrom any single sou. such as to r which are measured In excess ofthe rd6wMglml¢ ref areas used pred°minandy for .9,f tlal or.mmereal purposes It's n dohaNdon If odors are detected after the odor.. air has been diluted with sewn 171 or more volumes do. foetal. Regulation Part ...ANN 7.99Mm.9* criteria Pollutant. for mteri. polumna Air Pollutant Emid. Notices an require. Tar: each In2Mdwl embom point In a 1m-atminment area wl. uncontrolled orme con per year or more...nyldlddu.l criteria polu.mwm nt(polluter. ere for welch the arreaIsnonap non -attainment t Anal.. is requhad Oa file an APWI emiuem exceed ton per ywr NOw. Part B - Conlin.. PenaEx.mpt6n Applicant 6 ',and to obtain a permit since 6,0,60lld NBx emlssbmfrom .6 mdilty are greater than the 20 IVV threshold (Reg. 3, Pattie Se.onlineal a .Mbn6 Pan 6SoNom II: Stedans of Performance tar new Peel Burring Equipment Standard for Particulate Madan On end after the dateon whl.. re.. perfnmvnce testis.mpieted, no OW. Or°Pent. subject to. pNsion. this regaation maydischarge, or causethe ells.arge Intotfoe atmosphere d any particulate mates which 6: C3. For fuel burning equipment generating greater Man one milli. but less than SC mNllon Btu per hour Mat input,. following eqmtlon will Wyse, .determine the allowable particulate erasion limitation: PSI�Iwa6 Where: PE the allowable particulate emission in prowls per rail,. Btu hew., Fl lssthe fuel Input In million 0u per hour. if ...more uni1 conneCt teeny one.. the maximum allowable emission ran shall be the sum of de idbd.l emis9. races IL.C3. Greater con 10 perunc opaery, Ito Standen? SuMenkdda: On end after Me date mwihi6the required performance MA Is completed, no owner or operator subject tot. erovislons or thls y discharge, arouse the d hxherpe Into .e atmosphere sulfur amide in woes oh. M MOO.. Sources wla heatlInput d Ion than SO Hilton Btu per hour. 0$@vSOl/nglbn Btu Th...Inas covered under pants 111l111 he..a9Ign hew lap... ofs6m MM./. end were constructed a nt01npn9. result, theu,bbw an subj... this portion of dw...Non. 0,I,.6. amw equation In !LOS., the allowable Par... nnWbn Imitation h OM, lb/MOM m.AP-42emission femoral 6.6.0lbPM/MMBtu used in the calculations above Is below b1laabove this particulateia6k,Wly.the AP -I2 2 emission tutor of 3.440` lb3OMBtu wed in the calculations 1.w • this ldbadm e ern m n Ulna .f On 7 50x/MMgu. PISPSOG:Tha provisions of bable to the following affected radii., All stationary cos carbines wIth a hew Input at peak load equal m« grmterhthansubpart10.7 &gala. 110 milli. Ball per hour, band on the hewer heating val. of N. fuel Bred. The hew Inpur et pealt ow, for... turbines (points 111 6112) 6 SON MMM./hrwhkh 6 gnatertM,19 MMMuille Ara neat, the turines would be subject Se however, the turbines anamalt subject. N*P5 Mlee apppwb$6y 0600.6, below). Accordiu6 elms; ng to FOPS 9 I0 0,460,300.9 u stwbnary mbusdan turbines.M turbines regulated alder b subpart on mM ew. horn the nqumenn of subpart 6O of. Heat nsteam Sews.. enddew bum.. nears.knal69Odn nehPe11a ...Pt...the nqulnme. w a ,PO6, n2 IX of.. pane 2000ultx5rsal.0se does t apply. points 1116112. nisPS KRIM If you are the our. or operator of a emtimary comb.t.55601* e heat sp.atpeak load Equal...greater than 10.7 6'Pbdes OP MMB0I per hour, based co de higher heatleg ealw0 the rud,whrahmnme5S m*W¢h., mudIN,*M,. or ...rued. after February 18,2005, your turbine is subject to this subpart Then turbines (Pella 11161121 henna Mat input peak kwi.e..o9 MOW. le 10MMI u/M1rl and...erced ....Oen attar February16.2PM. Asa mule.P16.6IIXappMs to these turbines. The .ppllwble nquknm.nb Mva been included In On e2 Regulation ld)uwmem Applicability. v A Extant provided In Section IM.0.2., As Waning 1,1a17,eM1b Seabn RVL0,6. applies to began, dew human, process stationary combustion curb., and stationary neprosating Intemw'ambits.° engnw with uncontrolled actual...lens eF. w .sate... than Ree al..per yeer,art misted at major sources of elm et alum 3, 2016. On turbines .vend order points 2216112 are bated at major sewn. of M1.ad were bu1l0a 6ebn...3,2016 (reported as 05/09/2011), Add6mnally, uncontrolled actual NO, .miulew an greate5l6 5 toy. As 0 rerun, the +allmt.., pon.n MAR .MRyy1r: you en subject. Mbaubp,t B ce. you owner operate a Walkman, combustion turbine Iod at a mebr source et NAP nWbm. Th6 turbines (PreI.11161121 an not subject. MARTO./ because they anew: ad wan aneown of BAP•mbslem. 13..61 R:\9At001090E1136.CPS Turbine Ernissions Inventory AlgyealmitagAttalyglalgel £Age Eebe Turhlneprodlitt kart, (81x60' ..: --- ofderoom rd gor to �'roatK��Pwmii'pa %°mot rower nl Twrr%., Xd/ i .,,,,,,,,,,,..p.,4,0 0 3 pV,O �qs�D „pa d'V tM Cd�w� Tft#i B U9 3098 Tlk'ust ha a b P9 '".,,,°;,,'"t•-, st.e it MPr�K ae mdpat<m8a'o& _V11 3vIUe - IK q Ired WN5Pn K0NV 1 pe me M mpl�fi;eWq}tlf6' r gar Hwtwe ne r n rt&dwq+4u1q`vgs9. - s< xx K TmdPde;µngp ..,,., emn mmplla!rvwwaha75PsxIGed throe wand n I.W ene« �a .T ...�Pra e«a n d even....' d' k a1 d rn8di'me P Rds m 9pe mipruvdya �die4 ....0000-'7<!......' 0 00018 :null 001 tdidto echiurbne>n.t,,, ,„,,ItutaP�m 110--7,1%,...,-"'L...-7^,-'49- 0 b it, ay P wl� s 004Ml IEya wdmn m � seo 1r3n 3n t,... tdsiwtdmv T PPntside rlsMroawunr tors. f ntl £h td 1 aplti ',letter,' anO±bhW9o0 00 0, pkaa Inbr da` s`Y6aSa'PP'y s w la c uwrm m w b s� 4 dcaata a w I r aPur and II .xa o6 /e 1 �Ceeea y a - a w a� ry rw urcov P' 0/d fi N W fro w amtheI 0± result47040±440± nete�d�: geenm Inventory 600 Ceding end Embpbm Fawn AIM Point g 111-112. 02 nE eH Gg-opeAAttwiltA¢ W anwyep: dxu�p wa as 'n au aarr �fiaa IrcNdeE;emt � area rar 4703,04448 h ,e EturMne pelatip,_^ tar''[ Pollutant PAILS NOY yoC SOx Fmvidel-de Acetaldehyde Acroleln 1,3-eutedlen EBrylh.40ne Toluene PAH Wen. V. CO 000 Emlebnt CAMAS Getter Comm! ft 3.10:mmL, bput /f..±4±Input ,/50094o!PPnt b/MMBtu Input 0/MMetu0Wt b/MMstu 14401 h/MMemmput 6/505001, Input b/A4Mewlnput WNW Btu Input 3jAnAgtu Input 0/MMBtu 0401 3/TIMBtu 040/1 „Agog Input 3/MMBtu Input b/svrtup evert gtert .pemnt h/svrt, went b/snumwvn went ItIduAdwm went /Aumwn gent N:\P0\09\a9 W Eta 136.006 Turbine Emissions Inventory Seal. hl. AaminemtKw Mbnne°. FocIllty l0: ,,, :118-119. nt paintssalsss an an al sis.a <Finacx Me same ma emissio M.Mlly=eacMm provides an an.lwbbr hotM1 mrbine unite m.maelam,m H.mimlhom.ecx. Section 02- Equipment Demintlen Data. One 111:sole. r I5..' P. u - Detailed Emissions unit ClIDIS-61835), rated at 61.5allinalituAr heatm,ur Iviv, at 60, arm., tanraw6Ivo raarn �l Eml Cant. Pula Bgplepad O calptlan system Pequeeted Overall W0 & HAP Control EMnency 96: m.,meltm IMorm,Hon br Fmc ▪ 9b. 0?.#m .Pautlu _,_, Haat Input ;la.. Heat content °heart. pas. Actual House OperaHan= liequeated Input ram. Attwlon Fequeated heat input rate. Patentlel to Emit IPKEI Feet lnputrare. Number of tut.* startup events Tine per smrreup event NurnInar of turbine Pmpw D3Yurge shutdown n one perenumwnevent 5.etlon 0a Embalm Factors & Malbodelaaia. SoLoNOt Is ounsIdered an Integral cont. 'device 61.50 Btu#v ;64.815/050 MOTU WV.. a3s.Ce08rs MMeN Per year i3EP.40.M1 Mel, par year u;_u MMs€F/6ear 00&609 MMsef/year 5P1taO9 MM.50/leer EmfolonFacrnrs 6mMbn Factor Source Pollutant tlPM/.6.ml Uncontrolled ncontiolled ,ertup even') a54rt,eve.) VOC 18 0047: NOa CO r..urn Einrs.en F,mrsomm Pmluvm 6n pp/e„nt/ ,Ihmr1 Ism .MI Ism .nry LS of 61 K:\PA\09\O9WE1136.ca5 Turbine Emissions Inventory aste.av=p.re*bn ...POE Potential m Emlt monodlM (torn/year, Uncontrolled Inv. wlled Controlled (tons/v.0 (0m/year) Bequotod Peron, Orr. Unoantroged Controlled Itnns/yearl Rom/ynarl' COPotrntlal. 16.2E N.Nom Air Pauenn Er. O0/y.al,l ActualEmrsslms Uncontrolled Jive /yvrl Requoted Permit.. Uncontrolled lions Controlled Requested Permit Um. Uncontrolled PMad um/wm la rmebehyd. - - -- loehvd. c032.0c 1 949.4:. mteda Pollutants VOC P to Emit Uncontrolled ItomNmrl Aural Emisdom Uncontrolled Controlled Itmahearl lmmheerl 0 co Requested Per. Omits Uncontrolled Controlled (tanyearl (014 l trOn 0.9 Pocesr 03- Turbine Shutdown Eye. i:neera Pollumnrs Potential mfmitRequested (san19.2a (0892940) (tmaaW2) Permit] . rolled trolled (tos/earl Immhnar) m 0.08 I .5_ .0 14 0 S n:9 trai Se 05 - govulatore Summery Amehnb Regulation Section il.A.1- Except as provided In paragraphs 2 through & below, no owner a operator of a sou, shall allow or muse themishon Into the atmosphere deny.polu.nt which is In mess of 20%cpadty. This stsdard is based on 24 consecutive opacity readings taken etIS- cmd intervals far six mines. The epprwed reference test method for visible emlsslans measurement IS EPA Method 9 (40 CFA, Part60, Appendix A Culµ 1992), in all suit ..W5..1V Aar. 0 of rho regulation. a permit. 001114 S... or shallto he emitted into the atmosphere from any fuel -burning equipment 83,in the matter the flue gaxiwdach exceeds ...Perrino III.Al.b. For fuel bumine equipment with deolgned heat Inputs greater tMn 1x10°BM per hour, h.. than orequal to 500,0° BTU per hour. Me renewing equation will be used tadet..a die allowable partial. emission.1.tron FO5(Fllaaa Where: PE=Particulate Emission In Pounds par million BTU heat Input. PI Fuel Inputln Million BM peril.. The0Nin. mwnd under po..11&lv have a deal. boat etu0r..W a result. the NNrtw an.ubpct Oda portion olthe ovule .. Using the above equation, ,b. allowable particulate emission Ilmmtbn Is 0.1213 16 /140 0,,.. The AP -42 emis,on factor of 6.6aos WdMMBtu used tithe ...Wes abe4. es ...Oh oar.... ...Ion thmho4. Section VISA. New sources of sulfur dioxide shall not emit or muse to be emitted sulfur c.a. in eves of Mn following enws yycifIc Ilmmdms(Neat Input retesshall he the manufacturer's guaranteed madmum Ion 1npvt taro) VLB.4.c(I). Co mbuston Tutbine wit a heat input°, less than 290 m Eton 0N. per hour. 08 pounds of.,.golf d'sade per mNb, BM of heat Input. The t whines covered under p,1oa119&III hew.adesign heist In. rate of0a.5lMMBm/he As. newt dr.w0hr.. are subpetm this portion of tag �uletisn. The AP..mb.un lector of B.4.4dalb/MMBm m d Inth. cm... aboveh6wthh .6augur hsb dioxide em n Nresheld. g,,,,a SectionI.A - No person,whoever located, shall cause or allow the emision of odorous Or contaminane from any single source such as to 'e.t.d.r.csae odors which are measured mss of, following limits: For areas used predominantly for reskiermal or mmmemal purposes It's a violation onate detected after the odorous air has been diluted wish seven(]) or more volumes of .or heed],. BN bng Part EN Requirements Criteria Pollute.: For criteria pollutenh, Air p9II6.t n, Emission Plotless are fequlred for: each individual 10(260, point In a non -attainment area with unosotrolled el. .sofone very. a m more Individual ai h pdiwntlpawnaam....red(for whim the. f eactual 6m hrequired. OW an APN4 since emhsbre erred 1ton per year... Part II — Construction Permi4.mptbn pollo. b nqu1M to oh... pen. sine uncontrolled NGrr.... from this facility are...hen Om 2PTPIdue.hokl(Reg . Pert B,SectIonII.O.].a) 8.003288 Part B Section Ili Standards of Performance for New Fuel Buo, Equipment m ltendeN nor Pertiubtter. te MeOrlandaher the dam onch the required pct M.. dust h contr.... comerormta suhlem m the pro Aslae of G. regulation may discharge, a cause the discharge Into the atmosphere of any pa Nod arc matte' which Is: For fuel bwnlnv eguipment...Inv greater then one million but Wm then 291, million Btu per hour heat Input the following equatron will !sensed m aetenmlrse the allowable particulate emission limitation: .OS(PI)-0. 791418 alewa41e particulate evils]. In pa2nds per mllllon Btu Mac input tH Is he fuel ',wain million Btu per how. If two or moon. connect. any Greaten Man 20 peremgaary. ]. ope ning, the madmum allowable emission rate shall be Neatenof the indivlduel emission rat. ll. ILO Stend.N for SUNur Made' On and after the date on wh. the required performance test h completed, no owner a operator subject to the provisions of Cris regulation may de aisdrargeIn. the a°impheresulfur dioxide In exc.of, II.o.Ba.5nrmes with a heat Input less Nan 2.50 makcause Btu per hour: 0a Im.so2/mmmn Btu The under point 11a&iv love . desgnF a of 61.48 MMBtWbr end. IIa constructed after 01/100/2€. As a sul..wrhb,..are.ubjectmthis poNonaft.ngsroenO.11100 1oveeg1at6nlnn.Ct.OwOhm.. Porn emission lint.lon h 0.1713WABMB,. The AP -I2 amhswn fazmr of 6.6xld" W 9M/MMBl used I.em14414 mabase Is below OA hold. Additionally, fof&4v1d'WSOe/NMBm nod In the calculationscalculationsab28.6. below thb�,1 threshold. dioxide .mbalon thresh. of 0.B. 30x/MM632. WISPS Gr2The pmAdomofthis subpart are applicable to ted following affected feel. All smtlei. gas ...with a heat Input at peak fwd equal toor greater pan 10.2 gipjouies 110 million Bml per how, basedon Mrs lower heating.. Iv fie] Bred. Our ...put et peak bad brthese NOY., (porter lag &lag) h 6158 MMnuahrw0kh Is greater 0. 10 MMa1/M. Asa nook. the turbnert would he subje0m Nh NSF5: however, the turbines are also subject to NIPS 14102 (see applkah.By db.ssbn below). According. WISPS WOO 960.4305(h)stetbnarymmhmhen Whines ovulated undermh solo. are eomp Nom the requiter.... sebpert GG of the part fleet ncog.fy town venerators and dust bum.. ovulated under Nh.ubp14 anenmpodfie.the .. require. of subpart. W, cab, and Os of this pert As ...MPS GO dorm not sp.. polnell&&118. POPS N.If you are the owner or -operator of a SOB..mmbustian mAke with a heat Input at peak fwd equal to a greater than 1n.T giploWc(10 (ElMBtu) per hoe, based on the higher heatingvalue of the fuel, which commenced Edo..an, mediflotion, or remnstuctlon after February., 2005. your turbine Is subject to thIssubparc Thb turbines (P.brt118& II.) have. hen Inputrt peek load of 6158 MM8tu/hr(a 10MM&u/hrl and will commence construction eller wry19,1065. As a result, NS➢6 NWeon,. es,. v... To •pplIcable oquIremertslwee been Included M N. Pen..Combustion Beg. .. Pom.Adluebeel. ppllrebiIl4. Except. pmvA.d In Se.Ion 0V10.2., As nllwu.ry 1,101], this Sedlon NVI.0.6, appll.s to boil.., duff heroes, pogo heater stationary combustionmtbrt.s, and atstbn ad h redproty iournalrnmbustAn.nvbus w3hm�t umwn ved actual erehslo of NO equal. orgreater,n 14.(5) tons per year.. exhod at major Hums of Noe es of lure B, IOU. The turbines mood 0ss(rep 05/09/2011). Add,nally,the uncontrolled arta.NOx emnamrei are greater than s top As a ors b,tn. mnI es 3,2V0.6 (reported MACE OM: You are subjeethh subpart gyn.,. or operate aet.onary combustion turbinelocated rt a major sowrca of P emm u bill. Theo turbines (Pol.110 & 119, are n8tsuhpctto wormy because they are tinted at an area spem ofNAP ,,, obm. 169,61 12PA113101W02106.as Turbine Emissions elventoiy sec[lonm I. wlaaotn p tPLl bee e.pm=ecs 33. based On, rat, 0,0.1 t*ao.mettanOyd,ocattonsram - na; a x s e o�,t*,mat2Taszss nAn i®-s e,ur .f.4.7,C.teint,von factor ....et -ermined tz 433.63 td ihf,Liwratu /MMBaub Using h-. to.LB, tpa vm'em rrw[Etsmo, msr nE r vac emswr e.,n nm nn ary xrmn t ro,��„s . et a lb/nANISt,laz ft..tErtninedn,.,..e aye mar fa,,-aaePtab.ia-xt,,:ftqosstog- coca: leatalsotst,m tha,.In theal.,. of ueltpacrtk or repr esnd Sd a41Httl'St,.. n'raI« otherp a a"RI 11 Pala0040/3494100300800038243-8042%5, • (14 On am2rappto.. me,eator._30244940200138:003340a.ne m,•.,,�4P-.'•' ,o Cdr .pem.,A,snrn«.+04),3.0 and Ne IO,fslon accepts.... awn:des,arena,erpauan_zmit:ea!tornnob., er u,ea u -.x wcemyao,a: Stu. 0/4032 cur mmer 00,:0 xnfa gash, 0240320438:40004409,002833-2.34noted Ns -accepted tl+e-use r,42 f orMtocthe mheEa sfmaacrif.0above, The epiit.ortitat,rs for PNIILAtd_ Sorc peratonexatessed U.,. fitmEty.ft,meret,ttseciton,..,the fuel cons,rm.......e.Ne turbine-, a:,2,..att, the taran, utiO v.mmin. a condition that n.et n .l card so .s ,s_pe .See o 3..111: fu-n.:mkt, on he ,*it,Asa crsn u.ns to ry,x meter. nn St. and 1.art load tor gas ; 022200SoL0N0rmode is not en0?ged.on the tandmes, emissions are Rely higher h,a+i tre WAn olttesusea.for,perrnV,ne',ns a result,, permit:..p.i con:ama bond% irn, h egV,esmeihr6 eheopemted ln, z, acs SL made s:no pr da eelavon.pa ._lath na ,.a,th not got SdtdN sue, v e h the. Based onxoeand CO 30 99 039 00. I sdetermined rtzble znalwar tas,Ing 2,400 reerTheTheTheeaearterly besTh O. than for these 02002 1011 rest - e, re, m ea .3 0,00.at1,1, rpIl00x7001 7015%01 3', 021 NOxtpYO }9;1'lew l ho OM at,x llcO trty _ My,Ev)noxp a PPro tl y a9aet estrro4, bu 003004clutled n 0 fn 2.T 4e .e the NOx e1 Wf5P51,318 qu �KKxr<PoxstenOOM of man a erdaa, 25 eye, aateh.,.nemrThee p oopera rn. .eaaaor4pp-1xhnn o,yeen;.e;aexte..namgult,t era,ar d 3rnonsvatecemaar:enn,rremEsse: addlOon 1.154.5)...e.ta.s.nor Ittcluded, the operator may detn.,:trate. campl.,t1t, with Inc wouldn't nec,starr, demomtratte compIttance ...wtt. the p.m, r,3,, Farm tsbutdouto ever.s must be r a nemee.. ndslneaoa. totalaI nd shutdown eaaera/ 0th ,nenufian d a tn... uniszion rates -for NO, nand.g.duang 000shutdownsThe opeam.rk 04 rtes are b.0 en 29'mnurouta vpene ¢ awne.Yb,4 udpc a042tea N tdowr¢ meihoi,sctIo41n 0r-01320 01009 m p s noneeeke n dJ dshurd on tor NO, CO and arreeearaengp dbvm a,® n �wee+»Iv r ,+me nraaaap ,n .,ppn .oa,an,n are ,r 4pan22rpxawprNaaa eorar re ne doe anon. - e)pomarc 100rora Teem, 00.0.re,e4, .n9,nnO2 deesera, ma1cnamnN and t4mmndel e nt z the best represent..03 based on th ea by Ow opereater.tuastu ae,-ed :tor perm., purpcs, 9. 4, The mxotbutdpoiication. the coers...c.utilftecl d Btu/sr tOOILuttRehter s ns Maresuto( tame camel:. Dt91 / mode,. tartli.theda:a N y Tram n ff U Ire .opentor requited tau,Ilze [he heat updated i,M eh edge da a mmeem aefuel aaamp nnda,erai r, the Omits permit will be e v from.me mantiNcturef specifications... tempo w e2pN„ A3a result, 001212msona 0307,00 rot ..ata1e04ft,.tnuma nart89: fa42 «mat submItted .41000019!or ,tnualemi4 as Senbn m• Inver -mm SR Cod,. end Bmgbm Parton MRS Palma 110-11, 02 03 rve Pelµwnt HAM MOC CO Formaldehyde Acetaldehyde Mal. 13823E e Ethytlhenxre Toluene PAH Xylene 4AC CO voc NOe CO Uncontrolled Emissions Factor Conaof% LIMO h/MMBtu Input ed. 43 e.fst OS 6.40,45 43.00 S..IM 00314 U BOO 074 48 ,/34Metn Input "428984 None Malew Ingtt NM. Input /Ideate Input U'MBtu Input 0MMBtulnput ,/MMBtu Input Mout /MME. Input "'Meta Input NM. Input /MMBtu Input hmehm7 event /start, event /se '+P went /shutdown /shutdown moo r /shutdown went 4:1PA183143 W E11ae.03! Amine Sweetening Unit Emissions Inventory Section o1-MmWstrative Inbnnatlon 'Facility AIRS ID: Section Og - E0 ulpment Description Oe.I b Amine Uniink:ma:Mon Amine Unit Type: Make: Model: Serial Number: Design Capaciry: Radreulaticn Pumplty ,.don Number of Pumps Make: Model: Design/Mss Rec'neulatlon Rate: Amine Un0Eauipment Flash Tank Regenerator Heat Source AIRS ID Amine Unit Equbment Description Emission Control Device Description: 121:': MMscf/day gallons/minute tank, One (SI tte0syhdtetisa:wlar..ine i,MDE.a)eaturi gas tareetening unit Wake: Pmurmn Pipe aM4essel, M050: TEDLSedal Nmm(e0M0) with a desissso 0 gsritS of 3O MMsc4 per day. lists emissions unite equipped missal Was:5do000rger Oed.HP,Model: s350Ni amine pumper.. gssigesspassyM6sscallmonermoor .t?as assn gas sweetening OtD Is equipped wiik a All amt, fhshlass,. amiss rogenenationheat rotate LAMS neim.32:1. Emis40, Mon MeatiiI t are mutedtethe Thennaioaidiaer. Asanern+.aryeerhaidgoice,:.tiii mass ernis%k amt moss: MNa Open Floe. imiesssmfr:n thediaah Loners mst'siirmIVW she Vapor Heeaw+yUna. MOO.. secmrlary cantml Mdse, flesh tank ettessiens are muted to Me Open slam. Session 0- Processing Ra4lnformation for Emissions Estimates Primary Emissions - Amine Unit Still Vent and Flash Tank Of present) Potential to Emit (PTE) Throughput= 53,404 MMscf per year Scrunch ytt,HAom-Combnstloneevice(s)for Ah Pollution Corral Sion vent control Primary .ntrol device: Ptirssry control device operation: Secondary control device: Secondary control device operation: Still Vent Gas Heating Value: Still Vent Waste Gas Vent Base: Rash lard[Control Primary mntmlde e: Primary control device operation: Secondary cormoldesscs: Serondarycontrol device operation: Flash Tank Gas Heating Value Rash Tank Was. Gas Vent Rate: Pdmary CorrEW Pilot Fuel Use Rate: Assist Gas Rate: Pilot Fuel Gas Heating Value: Assist Gas H eassm Ualue: Pilot & Assist Gas Heating Value Thermal Oxldlur Requested Pem:Hpmcess omits Requested Monthly-M.10put= d.:D MMscf per month Control Efficiency% Requested TO Temp , 4's M.,1.Sd3i. Degrees Control Efficiency% Requested TO Temp iS:-;"`'SS%;;-"^. 006,00sF Degrees F %:Control EffidennL RequestedT0 Temp ';a: , +iv+ser Degrees F 046 fultrIscf/yr x.00 MI:Asof/gr SecControl Devi se Pilot Fuel Use Rate: Assist Gas Rate: Pilot Fuel Gas Heating Value: Assist Gas Heating Value: PRot&A.. Gas Heating Val Was4Gasfnmbustad: RMI Vent PrimaryControl: M ess.00 MMscf/yr Still Vent SecendaryC5ntml: 0.0 MMscf/yr Waste Cos Combusted: Flash Tank Primary Control: :.0 MMscf/w Rash Tank Semndzry Control: 9.Y_ MMscf/yr Open Flare I 0.0 MMsof/yr 0,0 MMssf/yr U.S. Will Source Demonstrate compllancei Process Parameter Inlet Sour Gas Throughput Inletsour Gas associated with SSII Vent, motto Open Flare SUIT V ent W mate Gas. Thermal Oddber still Vent Waste Gas to Open Flare Inlet Sour Gas associated wOh Flash Tank sent. Open Flare Flash Tank Waste Gas. Vapor RecoveryUOR iVRU) FlashTank Waste Gas. Open Flare Combuston.0Pnotand Supplemental Fuel atThermal ossdlter Cambustlon ofPilotand 5upp:erne. ' Fuel at Open Flare Glycol Recirat:Mon Rate Maximum Amine Concentration Inlet HPS Concentration Inlet VOC weight% Annual Limit (DANIscf/yr) Monthly Limrt 31 day) (MMsd/maMh) Metered Parameters Sfrdd dfi 3.21 d (Gallons Per Minute) (%I L %I Nato on Me PI nsU Information for the open flare is admesmsi under point ME Sectlon 0A Emissions ethod 1 'Um used Pro0ax0c estimate 3,1sclons The operator used the same 000,00000J that w ns wdls ME aPpa dal sbasetl nalysts0 ed h ,n IpdellsW d00.e(oll0w:igcarats, hss. Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Inn Arose Recirculation Rate Lean Amine Weight% Flash Tank Pressure Flash Tank Tempem.re 10110 "MS Concentration Inlet Me50 Concentration Inlet UGC Cc nsentration he p,evie.e modification4 silmato aminoun n. um 00001 best Amine Sweetening Unit Emissions Inventory lVErf n. S. do rim Pary econdary Po lluhnt Unc°walled(Ib/hrl Con troiled (Ib/hr) Controlled(Ib(hr) VOC dI8023N38: ] Benzene 10 2939 ,t Y Toluene 128996.: - t2hk Ethyihenzene 0244803;' NnFe '- G M' lag 0 y2mes 26D9En �;.4'9'a uz,4H b n -Hexane L.F; 0809 22 MP 0334894 4 102?f u e_4 -SG tlB Has 3.58084 Methanol f.fAROy"2 Methyl Mernapran(MeMil 0 tibnit: CfaR,2ia9 0.0352 C5. FLASH TAM Control Scenario Primary Secondary Pollutant Un ntrolled lib/hrl Controlled (MAO Controlled 0Ohr) VOC .29614363.W ...V.6.-;,..-...'3.6.1.421 Benzene 0.]923 J Toluene 0.5036II 0 u :,ess Ethyibenzene 9.00989951•'. 5.50 ,4 , , 0 09009"349:6 Wiens nM13 FFgy-"V1 ;00]362448 6 0 n-Hexane0101199"Z"19300.0".290292':; 0 001111.' 224-TMP 000f]5322 :-;< S _'c`.£<5 11,3 ft f'31R:. D0.00111.91 Methanol ;r,600269532e,F' Methyl Merwpmn (MoH) ..:..� p p24554e1._ 0 b 001212295 30x Emission Calculations: Molecular Weight o2SO5 55 I6/Ihmol Molecular Weight of Hz5 34 I6/lhmol Molecular Weight of Me5H 4k IhAhmal Sea. EntimM 2 (Still Ventl 10 599.97 ltess toy S. Emissions (Flash Tank) 2.012121204 try Did operator request buffer, or is the operator using emission factors from Worn as an initial compliancedemonstrzbpn. Pequested Buffer (10: on Fa 223. 269 2.10 0.04 0.01 0:43 059 0.44 0.03 354.67 0.13 0.00 000163 0.01216 Il.03322 00029 000150 0.00049 0. 00900 PPIIUGrK VOC Benzene Toluene XVime n Hexane Has Methanol Pollutant 10 WNW PM£5 PalluGtK Methyl Momentan (MESH) (Waste Heat Combust.) Amine U. Uncontrolled (Ito/MUSS( IIb/Muss[) Emission 51255,5,5555 Controlled (Sour Gas Throughput) (Sour Gas Throughput) 210asso.s 5 6.041.91314 0.'4'2005]5. 0.9234.177 03.499.3 SHIT Vent Primary Control Devi e Uncontrolled (Ito/MMBN( WM. Heat Combusted( 9.95390296 0.0.1.533 Uncontrolled (Ib/FsMscil (Waste Gas Combust.) still ac Veirt Se dm Control De Me Uncontrolled boiled (Ito/MMB0) (Ito/MMscfj (Wash Gas (Wash Heat Combust.) D .1'09.0,1- omhunmd) �F 11122,1 O.l5S: •t X 05, ct.ov. Flash Tank Primary Control Devise Uncontrolled Uncontrolled (Ito/MMES) (Ih/MMse0 (Walt, Combusted) Flash Tank Secondary CorNvl Device Uncontrolled Unco.one. (Ib/MMES) (16/Musty (Was[ Gas 0 0 - 31)532 pp me., Fuelh.5till Vent Primary Control Uncontrolled Umontronea (Ito/MMES( (Ib/MMssf) (Wash Gas (Waste Heat Combusted) Combusted) VOC Fuel to Rill Ve [Secondary Caving Uncontrolled Uncontnlled (lb/MMES) e Heat Combutted) Emission factor Source Emission Facmr5aurce Emission Factor Source (Ih/MMsd( Emission Factor Source (Waste Gas Combusted) 1215 Amine Sweetening Unit Emissions Inventory Section OS -Emissions Inceman( Requested Permit Momhty Emirs.Om. ProcesstParameter Pollutant (Ibs//month) PINES (lbs/monk) Obstmomh) Hz5 Ilss/mm'U[) . NOr (I./mom. (314)0rdh) VOC n6s/monfhi s.Ga Oxidizer U 0 ].:1.71x :342;3...OJ-!',.1 142133 1M,50238541 SStill upplementalSent 6 mano 5upPlemental Fuel SeM.Thermal Oxid'aer - :]5.'13S4EB:; i'8.1,334ii52 :G.ili:>M12-:2 � 1:3213.'4/4:. 3:9.1.29GSu .__...z .1;2 32:P..E]2G3!£ Still Ve[.Waste Gas to Thermal Orldberand Supplemental Fuel Sent. Thermal Oaiditer 124.1:,14.6..1:. 3314253 5.3'x sr32?5 305305.1514344.557410 1444.4x 233 %526.21,1445 Still Vent Waste Gas to Open Flare 0 Supplemental Fuel Sent. Open Flare U 0 0 - 1 u Still Vent Was.Gas. Open Flare and Supplemental Fuel Semtt Open Flare Flash Tank Was. Gas. Vapor Recovery Unit(VRUI 0 4lash Tank Waste Casco Open Flare z 7 _.14471.3110 0.014144150 31.734449'1^ /111433214h 53.1144>'?3 Requested Permit Annual Emlssioe Wnl. Process Parameter Pollutant PS410 (42"/year) PM2.5 (.ns/year) (tans/year) (tens/veer) Rom/year) (42314/year) (.11/444,) Still Vent Waste Gas to Thermal Oxidizer Supplemental Fuel Sent toThermal Oxidizer ;t:..rl O:(MS: 3'3.5.52,21. 1SS93.224 3.115:14':' 3.1429.:::-9 ':"31,30522 93154 .3.'a 04....3.:...,13 - .?.7..1544 4.11.%B .,5304_51?:. Still Vent Was. Gas to Thermal Oridtrer and Supplemental Fuel Sent. Thermal Oxidizer 4.?14 1.7.54 1.5.599044557 0.545.423711 21152x5442 355'2140'154 3.121411175 Still Vent Waste Gas to Open Flare Supplemental Fuel Sent to Open Flare 0 o q SHIT Vent Was. Gas. Open Flare and Supplemental Fuel Sertm Open Flom 0 0 J 3 b Flash Tank Waste Gas. Vapor Recovery UMW.) 0 0 Flash Tank Was. Gas. Open Flare .3 0 4,4110411149.LsOB 37/14; 3.3231353411 z,.fi..5.:..5 /4 414443/1411 Criteria Fellownes Poten.al to Emit Uncontrolled ).315/553,) Actual Emissions Uncontrolled Controlled (Ions/car) Ii../earl Requested Permit.. Uncontrolled Controlled (tonsryear) Nom/year) Requested Month(t Umils Controlled (Ib4/monthl PM. MIMS Sea Hz5 NOP CO VOC OM 0.l5 0.13 129.12 2,75 n.7S 5975 '.29.13 .SO ' . 33.61 ¢.5J 530%95 11.34 17.34 _4231 17.10 0.5? 35.71 1'5.%3 15,53 3.S.?4 i4?134 55.54 :'sect 45.44M,54 15.. .02.51 .5sA31 554.9% 9.01 331.0E 0.[44 5.4RY Hazardous Air Pollutants Potential to Emit Uncontrolled (Ihs/year) Actual Emissions Uncontrolled Controlled ((5s/year) (Ibsr13ar) h Requested Pe mUmils Uncontrolled Controlled illarAear) (Ibs/year( Rennes.d..it.. Uncontrolled Controlled 1374) (1pv( Benzene Toluene Ethylbenzene Svlene mlierane M4 TOP II ,S34g4a5 Methanol Methyl Mmcaptan (MISS) 3!31.3.51 .161513x MM.35 53'5!1,31 92M. 2.23 22722,10 3'315,26 COMM 5%221.30 855045 M.01 24263 2414,42 2437.45 --- 04593.4B 1.3 0.04 MMUS MM.. 4}!.33 354550.35 _ 12.94 4242 dczl--tell 450S.E 29.5 0.44 1... . 3923 0.48 4242,.. U. 5 14SH183 1134.43 13 ..n-.. 1MGM e. ..a. 1.31 15?111.34 5915.32 117:33.:35 .f.A'i.32 ^-..S1 1313-r.1 3414.52 .52.43 '3813.50 33.44 5510, 0.01 Section o6- Regulatory Summary Analysis Regulation 3, Parts A B 40 CFR, Part 60, Subpart ELL 40 CFR, Part 60, Subpart 0000 40 CFR, Part 60, Subpart 000Oa (See regulatory applicabilkyvmrloheetlor detailed analysis) Section OP- Initial and P.M. Sampling andTertlne Requirements f 17151:,' is sunle:t 0 Ge_P5131.- Ra,nrl1eepin5 and301t7.3 Reg:drtmenis par 3,:34.4?&l You Mrtv 20th 41341Satt. Mucm 7 and mut.. 4313145431434. You 54.4 i3dicc..e taali55= 2131311 1001323ta Ia5PS444Oa. Stream Has source provided a site-specificsampie 2.1hin the34150a14 Is Periodic Sampling Needed? Isln'Hal 6ampllng Needed, Comp.Non? Heat Contra? Conclusion 43431(0/7/4 H ry 4 'll Vent Glasse Gas %// :- No Engineer must specirvsumPRM Flash TankW as tie :,- .tt'Vp Na ssmi.mmusstpssitycanssiim Supplemental Fl to Thermal Oxidizer R 't'+ 4 .. 711 7437 NIA 700 .i 4? Open Flare Supplemental Fuel [o OPe `a�.`L.., _:_-.,, ��a,{.,�2J0 NM 41 Pugin,. #3'7...7, 314 17 .: 0 Still Vent Control 12.34,3 Device IS Mk an enclosed combustor or thermal oaldhe,?(Cant]. tml device be .stud?) Requested Control % Resented minimum Combustion Chamber Temperature oxldizerwith requested minimum combustion chamber temp below MOO P? Has a control perm tt pea.. than 55% been redo . Mr a testae combustion device? Conclusion Primary Control Tizecma,'Oxidizer yes b%.4 1522 112 40x 'Mit TnermalOxId.crk...stacit Ms.. detrunim t tm9.vi cHic!ezcye?therecues.d ,simmum6:'o,131r Mmnar410:o of 1,532 Secondary Control 431x,:Fare No 9F:% ?a/A la. N0 No 9.19 lasting A mquim,t Flash Tank Control Primary Control VnuorReco4erf Unit MGM 00 134'3 .. o N:: P£esaG17*,01rig is>er�ufmd Secondary...I 0,f, Flare Nd F_?6 NM 4242_ Ne No 4teck.1.5Imauthed Amine Sweetening Unit Emissions Inventory k g 08- Teel,nical Analysis{ro0, 1 W-rhi the madifieetiorh.eeperatur ,recegesting to ',Wase.e pr 711$4 pm nva(al fuel 1010usted by the 70-rnam 14..4 lggAsefnew le 152 MMbcf/y o ether changeswerer<quested 2. The average fudges fl'tote measu mg*e sack tortwas153.,MMs<1Near(25_224R/mnh The newly requestedsuppleMentalfueluse rate Were:. -than ti's measured rate, re.5I1 of fhb application.' 3. With Me'prevleu'sappkxdon, blooper$ for requested a control percentage of46T. 5inceth6 control values greater 17071he standard 05% control granted b2 the Demon, initial testing was required to demonstrate the iherma7carnet' 11 47011eof ac1,0Wn2796.7E n 070.enry when controlling still vent emissions i.. testing oho required thatlhe TO he operated at the minimum regvestedcombustio0 chamber temperature of 1.407F during 0,e50. The lni151 testing sea,ron441172 on 09/25/2018 and a 766460 • ]511/01/2018. The rest epertsubrnitted to the OM provides*. followintg,gulls:j!j NOx emissions (spy)=3.65,(ill CO.muskstrey) =3.73.iee VOC emissions (tpy)=0W,{n)502 emissions(lpy{, 12.37, iv(VOC destruction eNaen, 99.4.5 These res.,. meet the fission limits listed in{ It permit and the request.d siestrtedon211,2ri4 for the TO_ However, the average TOcornbvseon chamber during -the te52waz1522'F. Thk is greater limn the requez04 minimumeom0uaxlon c0amhertemperature of 1400F.H4gbercombusl3on chamber mrriperatu.sgenemily l®dm bend- combustion_ Erased on this information, the testre.l0 will be accepted as meeting thelnitul sesCTg requiremen0 fisted in previous...me of penni. Howecer, the operator will now be reginred to meets minimum rnmbuseencha07er [towel -ewe of 1122rFrather than the previously requested.value of 1400'F.A permit conditionMilibe added to the pent to -reflect hs recite ,t. The"until Mach testing requireme17,,lbe semmed hom'0epenih 4 With th6 m40,976non, 61447 re- for is not requesdigtochange the metisod in which emissions are co -iodated As a result, the operators b fitted he exact ame.ProMaxzmuladon that tuns usedto memattremissions 605 the prevwousapplicabTh2simW23on, based one ttific cetera, gas ample Soh the Mewbour processing facility obtalnedprm[otheamne unit inM.ThiS sample 4as:ob[aine0 on Oeeembera 2014 WM1 <thssample is tame than a year old, twas de[enninned to be 4109abe forced dating R142(1, 5Theaeasens this.. mplewesacapted ran ern calcalat!ngpermi[!imits as as fellow: ($Tix amdez0pplied wazused and approved with the previous modifica lion of this permit(ksuance4:07/i4/17(,0i)Theopera[ors notrequezlfng any change. the emiszionsalcuhfool with the previous. d4ibcaton,(1I(764sampk and P[OMax slmulatien subrinttrd as parf4615223{ tificatIon processihdcatnthe ernimhn esbmata used forpermenng purposes are conser44225and fief Thepermit requires caste gas sampks(flash tank and stall vent( to be 4bta2edona quarterly basis to demonstrate ongoing cnmplamew'*the emission limits. - - - - 5. It should henoted 'hat then/MSS& yaliMS71700111715, Mega, en ,4- hepsane,Z2,4hFMP and McOH 00 not match treatyw.th the sample sa basso, the imekh2o.Haweve0 thevaldes in the Imula[lenaie more conservatve[hontfle-values report.. thesample•. 45014. As a result, this like. result sn a conservative memo. o£ emissions from the arnine unit.- - - - - 6Sell vie rlymtrolle4 with a thermal ey dray (T0}. During TO r controlled wiha tla. However *cap stngto p71722165l1eamaloxdil708760 hrs of operation per emirin editontopenitthgthe still Pont t0*, (lee far4021re per year (20.5 days/475,). While this resulewn double conahngat crossionss,5tiis a coreervaove estimate. The operator expressed*St this Ponserte6t¢es0mate is necessary because*ey"do not want to take a rmtrotino the 53017ionof the ' prima control dev 01amex el-.enddenne 505754ed to bpallocled bathe thermal oxidize+ for stack testing per s. This- se 02 stack test results baledby 8,260hrs/yea order WWMemsslan 5m!h.lfthe y d hours of flare operation 6691e subtracted from the TO hours, 55629tic operatic, ,9 would only be allowed 8,263 h1294 r of primary control device eyes 60adrwould therefore fait the stack test when he results are waled to 4,260ies/year, ...aunt fora potential full year&primary control device operation Sin. this estimateis_conservabve; providesa compliance Duffer and allows far the use ofhe primary control device for a 50 year, It 2 acceptable and will be used Mr pemitreng W10 -pa -e, • •7, The VCC and HAP emissions associated with thesellvent being contricsred trcc the 251k451516 are amounted for tidier porn: 136th co esltsn a.nserwtrre estimate because because chngfor the VOead IMP emissions associate, wiCa,2®Ms/earofT0 -operation under dal -Stream pent and the old'545012461139,1,1131142.enthis95inatlonmet0od, the still '4034ondary control device Is ested as an openflaren k wnrsheageothoors of operation are1155d0Ohm/year beo0se the emissions arc accounted _ her separately under351et 136. B To.imla0 Nlh and Ca ern1iens aseaciatedwfh the TOcorehWerat.ofshll it,gash*e operator usedthe NOxemssi on realer non TCEOand the CO etrimion ...or from AP -42 Cha'pter14.1 This is the method the operator used 16estrmatcon1dianne emssons Were Ohagouroe issuance of the nefml[ Additionally, this result in a 0150rvativ0 estimate ofem4sons because the AP -42 emission Motor Mr CO is moree4nseiatwe hap the TCcsemiesmkr. n1ac5tm,brly, the TCIO emission factor for hlOx is more conservative than g the n , the phavioag facto bn4P-42.Snce he operate, essimatesconservatve,I1,52129155l, and will he22,0 lurpermittng purposes. . „•94Theinperetomaiculated SOP emissions manning frorri.the combustion ors.,se and Bash tad( waste gasu and the assunioan that1W%of the H25 and methyl mertaptaa_(MESH(res ring hum the amine unit.. rosimd son combestion devicei. converted to 502 These calculations are contained shove in Secii2405. ThddperaMr used the following molecular sveghnn the 7,4707ons171026416Phm4l(i7524'421b10,,,o and (1G4Me2H-481h/Ihmol. " , - . The operator didol calculate PM en.ssiomossociamd with the combustion of Mill vm,tmihflash tank emissions that mu prated to andeontriaged by thetnermal oxdier(sell vent( or plant gum (flash tank(., The opera eel t0atseme the themalaxid2eran4Rare ate 491gned to bee smoketrss.rnbustion07.,.2.32114ulate matter isnot expected to he generated from the combustion of amine unit waste gas plated to th252599ol devices • • n order to address this t, the ernhsion.ctor source for dash tankjdOnnd NOM and still vent(C0) ca ...or., 5042 Chapter 13,9, w231,4owed. thisdocument expresses the °emissions from (bring may include carbon particleslrot(, unburned 142741arbons, • alarm( mi t e. burned intl altered-hydrocarbon...so emitted e-2 nitrogen oxides (Nazi and ,..sulfur antaimng material such as hydrogensulfide or meroptarss is flared, sulfur dioxide (SOZh^Based 3n this sdtemen[, the document does not movideinformaton sulth memds m particulate matter, t With regards to Soot The document further providesthat a smoking3are directly results in soot format...hen ftstatesS.Thetendencyhf a fuel to smoked Make soot influenced byfuel charanerstio and by the amount and dntrbusan of oxygen. the sombusnon zone' Tlusb further supported by 94474710'Si bekwt61e1072 which provides theklovnng:''Soot m(4110nbationvau mo.ngflares,Omicrvgramz per liter Qug/Ll;ligitdy smoking flares, 40µg/t, average smoking Rarer, 117 µg0; and heavRV0#46i113 j gams 224pg7L" 49152 dine, these 3 not another source opda[a that quantifies 64120 2,902.5 from industrial flares and therefore it Prelim assumed. that Ma only sorrce of paNmilateemtter bona Rare ss4ot from smoke asexpressedi0 AP42 Chapter 13.5. Ad'bonally, theTt6O"4echnial supplement flare, waseviewed since the NOx amnion factor he. this docmehnses used forMill vent wmhustion.5fmdzrt4Ap.42, 6Ws d4ebment does not provide- specifionfdnationwth regards MPh0eml,,i,2s,. 6190404,40432317454014212017004517.10Further, AP -420 matron 33,3paragraph 2,the document st-.fez'Vest planes employ elevatedo4,Wears Pares or tad gas incinerators forc2mplefecembuston of all waste gas constituents,ocludinga.r[ua15300 percent co riversionef6126ts502.1trt0e particulate, smoke, or hydrocarbons m these devices.' This is further supported by table 5.3.1 which Provide; emission factors for gas sweetening 7171$bThsmbleespresses.theys,024la0emission factor for amine units ntrol edby smoaeles Haresand tall gas dcmeratorsxnegl2,25 - - - - - - - - -I[ should be noted Nat the O&A4planrequires iha[ dady4Aeoks be conducted to Mtermineif the fare.Cmokg.famok, is deserver during the deity check the source's requ{ed to either conduct aformal epairy observation ormmediatelyp0u[fn the equpmentW ime the mus65104smakea4024601ct repairs as necess217 9e- and the manufacturerdesign for the Pare he be smokele0Jonafed properly,;tan sz{ery7eassumedhathe Rarewdl opere.e Wthoutsmoke one 10122,bui2ASO,!12,442 is observed, he wht he required to assess., prob1ern 240600for ntthe flare from arm.g. As sueh,l am cornfortribtr assuminga soot concentration o#O ...grains per Mar as provided 'MAµ42 Chap .5 for nonsmoking fames. The ,TSM m plan air, permit 724403 a min,0, mb0don chamber, p re for the TO. By maintaining this f tap and other good condonation practices, the TO h. unlikely fo emit sign!fltan[ med. ofeancc2562 as a tenet of the combustion of still 74 etwas1 gas. • 11681251PM emirs nftorof2,61b/MM c31,471 AP-42tlapter'l 4wer<used,the-tidal PMemission, (for both PM 10and 2,51 would hebclow4PEN t,reshalds;As such, the emissions would not result In pen!thmirs for PM orresult ;n.add'tanal regulatoryrequ'rements.. 6. n she-iinformation discussed al...t uses determined that*e opera for nthaea sin k m and tit, sal ommzawould not he expected to have PM emsswnsa ated M. the combostion ord.. gas all be accepted at this time. However, if bettor2254 0 ro re dove red tithe roNre hest mating PM emissions nom industrial9are<-tdam. be includedinfu nfltysis. we] em calcul7[ed'nSecticin05'hi vie do nor Matchw ported on the APEG%. Thins dieto fag t that then red ...date anal emissions ipngasimulation-one montnlyhaus rather thane issens factors. Asa result,'do riot In all the mkulatrorausedmemir.. edam emissions Due. this, 060001 emissions for the source should be referenced on Uie most re4mtAP4Nsubntted on 11/01/2013. • The operator expressed but every amine uniti5002lgn condense; -on the still vent because the anal gas stream tomire offtlae MillMt-mated with water if ...mans were routed tdthemmbustloir derccwthout passing tit 'gh'a condenser first, the contrdr '. desmo would not he capable of 2145,0sornbudingthe010e gas. Since he condenser is patter, the design oft he amine unit raher hanan add-on control device171165 nsidered process equipment rather than control equipment. This determination ui t0 question 3.65 3 which Amen 'Would the mid,. be installed if no air qua -tyre are ...lace} theegapment is inherent to he process.;ngeneral the answer to -this world be ses.' Based angle aboyedizcusson the answer helix quest0eon would 644¢3: Additionally, the opera'Memtor rexpreaedihe primary purposes°,*c ponders w pollution marsh -ME to s n 1 in P5MboyIod03 which -dams cs*e Wimarypur Se of the pollu[oafftlaeecpepmereds inherent the proviso;thee o, this question old he no nthe a othis o would be no.5ince these two strong -case an be made Hrm.ec nden tome pad amid shoo nu'dered airpolluM 214677iµ-nen should 10030er natal that typically comparison of he acid gas stream routed h randthe acids.etream routed atoreimcontrol device from the nd nz 'tithe FroA.Vaxsmulation demonstrates the hontlenser emit. In negligible reduction PP UOC.W.IPtthe opentofdi35 not proddethese streams for reviewwnt0*is partcu0r protect, l am comfortable Aaszif.0,0 i condenser. process 421110an control equipmenthased on 770272010 withhisequ,pmeMmadsimilar mtripleted 45$500 by the ridden....err the • operator -05012o requital tom rnpfethe still ven[wastega3 steamafteri[ has passed through thervndensel in order to demonstratebngeing compliance with the mm115..ass,mint, the assessment of the pre and post condenser ProMmiskdams bemrtesrrtNeant 15, The operatorsuhml[teda self -certification forih<amIn 10/05/2,318 Based. lhs inf orinct100.010.1d00 10 013 1011'0.1,1100,11.0.21,01i11,q mats from the m<vmus 00306549 tip -well be r<naved from*sz permfb Atldidonaldepded duussivn atria..,nitlalmmplingand stack testing requirements,. contained in notes above.' - • • 14. The specifliation sheet provided Id the application Millaatrithe rnaainzu. Scum chrnbusiiir capacity of the thermal exidizeris33MMotu/h Process heat release. The ope1247 nas chosen Me permit the supplemental fuel sentto the TO at 23A0M9tu(hr. The,perat5r indicated the TOizegeppad untha flow meter to measure only the Supplemen5l(uoL the damfrom Mis flow meter will be esedmmonimrc8mWance with 0,4 perm uteri supplemental fuel fbw {392 MMxf/year(. - • .sad in the pedals preen nafysp the Operatot alma required to meet a VOCimiltaf 706 tpy throu65 Instac test conducted on the. TO ism r [716 inthe PAM,C94(.The te0L1[Softhe st7Gktestzhoered Coral VOC eitrigslians at 0.00 a -insult, the.peraiier - dedt0waled compliance with the 5OClim11 for the thermaloxidlzer through the Mack test. - - - 16.. With this application, the °maples ompamedemonstra0on for Pm am.on s07071din or a.0 work form ad. using Psoktax ongoing comer a the operators novzrequeedlo 0mplest2Penland eashtank waste gas,Typic2ly meko wog{d also be rouged kfbothzbllvatend Raxh dnkwas[e gazslreams. However, ehis amine umt 70241'151,004aPernlred to ailow7ash tankwazte gas [nre3g0pot to be obtained from Me ProMax simulation, As a resuh,the sail sent caste gasstrearn will be meterodand the flash tank smite gas e mvalum will confine to to obtained from rohtax. The opera "red t0 sample heat content when the camposi6on manes a obtained ono umtedy basil. Thls1egwrew9711,o vdedb0 se the operator ¢quo t1 list*e7 on Raters for embus o.0116/MMBIu. The sampled ughpu[ actual combusts ns.The use of sampled compositin/1mM caztent should provide • a' bete, represental f missionsather than.<u g f simulation software. Theoperator agreed with the updates to the ongoing P- e-domonstratlonln t'hepermit m,M 11,77400101110/hidde5 the fonphing ason... fmcdmin pw, met,'coudrmbe i425e414,4,asu0the Rash 54392532,1554412401 waste 'Thereisno Row meter on the.ashgasstream.Norder ...fie goy/meter on Me Parham strain the layout of he curent44010 would require tahanges tie rape of Any piping soktted,de t1ryof h - ffeared-mi and heat fanym eel pfp1g n ry,.Ins1a1'nga 1luw tee on the hsh gas amwouldbe- nasetl per. o This eesoning' aver uipment [tea ince edfi summa me m -"? Gum ":, Ce<nnna ly ',psi., hvtwoWd beextremeVcox,Yfrpmamo and productio ass vie. This reasoning and the flails tank tnm.ishpu[vn w to tie 06prnedfrom the PmMar zpnWa[mn run aria morphy hasix engy, how meters are levelled a[Lae fvllowingloatns. fl Still Vent The waste 227 glowis measured using. flow meter ['hardy downstream of the our e.. This mph Row mem In conlunc[w poi. TO down -timer -Monk will be used to d..ea.00 volume gm routedtodtherthe TC'prhe.acd gas Aare(point 136) during TO duustme (I(Snppler,,Mal fueli0utedhrheTO has,. own 09040edmetr,. The flow rtmasur. by this meter lrtaddtion theansmeit lod,ghebd0091(1 be used to tlernonseratrcornol.eceng. the romnnied limiten Snppkmeirelfuavane viwtbgnlgaa in- Hie 'penic - - 41231456712122omb22110 by*010224 eorst5931310 of55.2sere, (O.1 MMetu/Cr(. in result, the 0peratorwall asnrnehi:Ncl flow .e pilot rant em1szmns.sncehs is a co to and he peatar expressed p t norm1n12110, the, rm 14114etndude a condtm1051re,4,es Co pile, light fudbe measredehroueh the use of a 2051 meter. - - 20. Typia Ey, the operator wouldotbeequtedfe 2h4in inlet gas samples in addition to waste gas samples. 525740,,712295512, nos requested o mconv 9g Prnailar in mtrentrideterrninu volteneof flash tams,. gm, As a. result, the.operago r egg lap oht2i monthNnler z mp., io order using Pro.Pro..5, dote 7g flashtankzn me. - - - - 21 waste gas and treat contm[samp'ng was includetln the permit because sampling of waste, as a new ongoing compl'anre demo rat,onfortOszou e. As ayesul[ the initial samples MET.domt0110 cer517 Mar the current s.: aecegete for 44,4ers. Es m(on he n with the self,. e 1 - ofhk'x fihe pe - - - aced n teal of 17,30 tee ef ligS let0 sThe con,wrsfort ofthe value to LTAge g h asFollows: (1 . eryyecrl.(leear/315 days1'1210110447('1111(24415( a 0.0a21273-ton/day This aku5111700mo [rates*-s3m! eum0 has a:. .:‘,00,90 capacity lers0562 longtoo/day in.lhead0 gas.. Section 09 -Inventor/ See Ceding and Emissions Factors MRS Pointe 120 Process p 01 Pollutant PMlo PM4S Hzs Na VOC CO Benzene Toluene Ethylbe One hylene n-Herane .4 (MAP Methanol Methyl Meraptan (Me5H( Uncontrolled Emissions factor Control SS 0,26 L%51 0.592. 015,3 003 u,6 06.3 00,1 0,044 O.tta 0, 050 0,031. Units h/MMscf h/MMscf b/0Ms09 b/MMscf b/Mahar b/MMscf b/MMscf b/MMscf b/MM24f h/MMscf WMMscf b/MMscf h/0M2cf b/MMscf 6/MMscf Amine Sweetening Unit Regulatory Analysis Worksheet Gatorade Re (aeon 3 Parts A and B-APEN and Permit Requirement -ISenrre 6 in *0 5 n5. Ath reven:400 ATTAINMENT 1. Are uncontrolled actin' emissions from any... pollute from this individual source greater than 2 TPT(Regularian 3, Parte, Section llIlla)? 7; 2. Are total facility uncontrolled ROC emisslons greater than 5TPV, NON greater than SOTP* or CO emissions greater than 10 TRY lReguletion3, Part B, Section 11.031?' J ' ITo3 em . Indicated .6buy mime s in the llonYkilulumentffieu NON -ATTAINMENT 1. Me uncontrolled emissions from any criteria pollutants from this individual source greater thanlif? (Regulation 3, Part A,5ectIonit0.]al? 1133O Source Requires an AMEN. Go to the next question 2. Are toed facility unconeolledVOC emissions from the greater than 2TPn, NOR greater than 5 TPYor CO emissions greater than IOTA'IRegelatlon 3, Part B, section 110.2)? Source Requires a permit ISc run regulrevn uermit NSPS Analysis 1 I the sweetenng unit located at an onshore natural gas processing plant that processes natural gas produredfrem either Onshore or offshore wells? ISearce 066bjectW 1855,5 •Greni.v. deterndue ueviDuhle mcdons 40CFR. Part 60. Subvert Ltl, Standards ofPerformance for S02Emissi0ns from Onshore Natural Gas Processing 1. Old ooretmction or madlficaOon (see definitions40 CFR 60.2) of the sweetening unit commence after January20,1304 and on or before August 23, 2011(60.640(41)? 1 Does facility havee design capacity less than lane tons per dey(LT/D) of hydrogen sulfide (H.) in the acid gas)expressed as sulfur)(60.340(611? 3. �Facilirvkauhiect>+nJ5PSi.t1-?ecnNk7Pineend a^mr:Mg limmiremerts pert -M.64701 Subpa td, General Provisions §60.642 -Standards for sulfur dioxide Do 601405ly 660.646- Monitoring of emissions and operations DO Not ApPly §60.647-Recordkeeping and reporting requirements 4068 Part60 Subpart0000. Standards of Performance for Conde Oil and Natural Gas Production. Transmission and Olehibudon 1 Old construction, modification or reconstruction (see definitions40 CFR.60.21 of the sweetening unit commence after August 23, 2013 andenor before September 13.2015? 2 Goes facility haves design capacity less than 2 long tons per dey(LT/Ol of hydrogen sulfide(H35)in the acid gas (expensed as sulfur) (605365(03W (Yea have ipdA:atad th'.44:lotacil(fy (v nno6oLi:{act Sc 056.5 411212. SubpartA, General Provisions per §605425 Table 3 660,5405 -Standards for sulfur dioxide §605407- Monitoring of emissions and operations 6 60.5423 -Notification, Recordkeeping and reporting requirements 4061, Parise. Subpart0000a, Standards of Performance for Crude Oil and Natural Gee FacilNes 1 Did construction, modification or reconstruction (see definitions 40 CFR 60.2) of the sweetening unit commence atter September 13, 2015? 2. Does facility have a design capacity less than 2longtons per day(lT/Ol of Hydrogen sulfide(H351in the acid gee)eryressed as sulfur((6053653111(311? I've have Cedh:urndli42S. NORily Is 'net suhjeutr000cn MOO. Subpart A. General Provisions per 3606425a Table 3 560.5405a -Standards for sulfur dioxide §60.54073 -Monitoring of emissions and operations 6 606423a- Notification, Recardkeeping and reporting requirements Colorado Regulation 3 Parts O, SeNon 111.0.2.x- aria So_rce.ss:4hiec5t060CT Disclaimer This document assists operators with determining appycob y ofcertain requrements of the Clean AN Ad, its implementing regulations, and Ak quay Control Comrnlssbn regulations. This document le not a rule or fegulednr4 and Me enaysk d =nee,. may not apply to a particular situation based upon Ile individual facts and circumstances. This document does not change orsubs61ufe for any law, neW/cOon, or any other legallybke'mg requbenwd and As not legally enforceable. Mthe event of any coniict between the language of this document end the language of the Clean Alt Act.,74 bnplementing regulations, and Ai. Quality Control Commission regulations, the legdege of the statute or regulation wit control Meuse of non-mandatorylanguegssueh es"reconerlend,""nosy; "shoo*,"and"cent"k ldendedto deeC,JDe APCD Interpnetafbns and recommendations. Mandatory terminology such as "must' and "requkeo" ere intended to &samba c2M0Mhg reWlrenents under the terns of the Clean AN Act and Ak Quaky Control Commisstin regulations, WO* document does not esteb7sh legally bkdbg reglaemerls heed of Roe,T. Yea 'you have indicated the facility type on the Project Summary Sheet Flare Ernissions Inventory 233Alon OR- Admlustnnive Information I,„,,,v„,„ I .b, One (al oven re 344.164 Mil na'ak Modal: Deluged Eml$Monaunt uw Pam6 & RM occr ptlom td, i1N.v dauo i, Ernkslou Control oeu Repua¢d Overall VOC131143 Control Elfizknry X: @an'! „. Nrot VolUrne of 63s: 0.000 MssyG HeetConentofeaz. ifn.,,,. ,..1' 0,Stu/M Requested VolUme of p3i. PTE volume of o eq tM heat content 4313 MMecOsa ..6ia MMayyeer Riseluuv Acta volUrne of Rem M.Neer rfEwNme0ORIM .„U.31 MAR./3.43 Volume of gas: 'pt ./.1dry x 0tuaef RMouesech:M p4mm ti. - MM,>Mar AMA VolUrne enter PRE volume of gas: 3.154063 MMedMar Request. heat content EASIMUM VolUmeolpmm 11.t Coutent gm: Requested VO.Turneof ALtual VolUme of 6831 PTEVolume Oxus: Requntetl Featmeknt atdThmuAM1Puk 104,77.373 MME/war Mm(war 1r....,i.M MMat/wer -,T:A.GT.1 MU Mar ThroughMunMerm3 umIR • mugmit 0 MMrdMar PTEThrou.pat ._.-xi.._ MM>sfMer 2.043413MM nMer 520 1.4 ezfmr IMw put 101 Ia 04J nM�o I 00.0.0,6 muss Madan NellUm COR NZ methane mom MAT 0.00 1.02 0.00 0.00 417 3949.30 33.44 4762 121 187 0.41 0.36 622 636 41012265 71.1.39 28854.. 9339.31 3994.57 1643.03 3024.91 203.46 36.36 Molzene Nabutine 4.16 623 1.01 0.00 mpernene CyclOpentane Mmlaheusme Other Reams Moen. 00000100 "k ha2JmEbJ „,eaF'LLoWE,ao 0.00 100 0.00 609 0.00 0.00 1252.66 0.00 SOO 0.00 600 0.00 100 eth3L-mahmne 0.00 660 TolUene EorylMnzene 0.00 600 0.00 0.00 0.00 0.00 000 ,s.::,:. tbromehout 19 M77576 ents 217428 scrAm ta,ta leuamdl I 0.66213824 MMecf,O Nehun 0.00 042 61380,12 22.99 0.00 0.00 3331E. 046 9760 10 1.03 5,5asat E6.86 03030,52 291.. muumuu ethane .01 26.. 221326.42 113.66 15.06 101923.32 66.. 242 2172173 6.41 4736.7 29.62 MoMPune 3136.2 Muuentene npmmne egelopenlane 140202 0,6 503R42. 1.91 167-52.29 139 0.90 2584. SOO 0.00 630 ghrhmnee hertmes maMNcvcicherane 0.0003, .724-414.13 I 203343 2600E. .623.67 0_00 600 0.00 0.01 0.07 882.76 0.29 106 457.00 600 1412 0.01 0.01 Toluene Eumlenaene Ha 40003.6 • 1Me010 H0dmaen SUM. MM.) • e:ozen (Meat) C64 Neavles voc mae taNpn Total Vo0(JMo0Ooaey 7.000400 - 2400340 a afa� 0.00 10.01 001 0.00 12.26 0.01 32332 0.21 Total A.m. Nest .ntent 1214.994329 (0000.405.. Residue Gas Inlet G. HeatContent Jokt1 0371.266262 1623716762 1222.144365 230361 n1V&\os\0SWE11ss.Ces Flare Emissions Inventory P011.2.gym//ap. IwlewF ast hart co as a¢ adlel ad ""liuss�l""� roe comu fmh+nn+faeersaumioetlan mom» IMMIIIII IMIEMW tames ¢eWm Pelwent ndrtd a E.F.. este heat co Masted cont. ed umn. waste pa vol a comaxntll Eml,rl¢m.a.,erSource Citation MNEZMIIIMMaSkal,Aseelgill 04111".".\mil F, . , .. . - .....-.._...,<..,� 7[1! shoe :': ® MIMINEE Pollutant I tia/MM d.senl cia drteal mh le f me. a tlan . ,..,..., .u..... -. , .,.., l ',:i .IIOS`Ol a ® mo Fame PahRant °^nm/MM waste rt cornaustedi E.F"Ilmiei Uncontrolled volume comiauatadl Soul. Citation m¢ a Factor W �,,, F....,6&� .. ...... .....'. VcC ItellliaiM CO d3R n.,sP. NO -eine(7M Plamn.NMseas{p(tCO EriMMEilli Emhuon Factor sous oed05M Mtill ME=_®.. 1¢eaThmuRnp,nl m�xwq _ ERIIMNI ®®` IlMilItiM mina nallnlESEMaillaaireVWFierinAallelielWa lalant Mare Pollutant Uncontnallad Controlled II¢/wwel Ito/ Mrel leas lae.Th055505 1 Throualiputi VOC Benzene I 531 NaS Sai Methanol Oda? Cairn 7.5:=5171174tUyan Emission Factor Source Criteria Poll.... MOx VOC CO 502 POrandal On en. Uncontrolled lenarye n • Requested Permit.. Uncontrolled Controlled (mm/yearl Imnahea( OM Uncontrolled Controlled (tons/awed Ilor¢pearl MOO areal rairiaiDe 0.77 .37 .012 crlteila FaUtania Potential m Emd Uncontrolled lions/year) Request. Permit IV,. Uncon.illed Controlled Dona/WO immtyearl Actual rnisalons Irolletl Controlled ImnaNaarl Immryearl aiiIM2.5 0.00 Ova tl ealliVOR Criteria POlNvn¢ CO m EMt itollS/Vearl Pequeated Permit Urn. Uncontrolled Controlled (V,¢/avail ImnaNearl Koval Emissions Uncontrolled contraliad itoni/yearl Dons/war) 0.0 rad Lae 6c Criteria Poll.. VOC PoterMal Eat 00aNeerld Requested ?emit.. Uncontrolled controlled ImoNe.rl ImnaNearl 0.0 KWal Emhalom Uncontrolled Controlled Itomtyearl lnmaNaao( 3.43 2.10,61 tc\Pn\os\wwEvaas.CPO Flare Emissions Inventory 3aa'Siannu'nYMM3detltlaCti�r6unwniPtii4&indKiiitllk(.t.�•...''i''. nitna Polloanv Potential to Emit Uncontrolled s/yearl Requested Permit Unit. nom/year' Imns/wrl MOM Erntsfors tr imns/T.rl Ms.Anal xsardumur Pollaens Patendal to Fmk Uncontrolled Peso.. Uncontrolled Perrnit Um. Controlled ) Actual ET.1.011.5 HoreAs..I I,5 Controlled Requested PernitUrnIts Uncontrolled d+ m.M.,I Toluene Ethymam en Wen. S.Sc. ST/AV P.R.I., CT.,: C.StYCO U... - _ _,00.10 _ &USW Criteria Pollutant Potentlal to En, Uncontrolled Itons/T•url Requested Permit Limits Uncontrolled Control. Ions/year) Imes/earl Actual ErnissIons Uncontrolled Controlled Imns/yeerl Imneryearl Toluene bthylbenuene 'Wan. ra imp Methyl plan lMaaMl POW. le Saul Uncontrolled used Penrt[;5 Uncontrolled Controlled m,e/I.l ttemiveurl Uncontrolled Iore/yearl OSSA MISS Requested Pm..., Uncontrolled Onn nrl anneal UV SW 0,561 nn 0 0 0100 1.24,3 13 S0SO nCIO 6.0030 04.17 1.34,7 MSS ssass cmCSI clams Pmwvnt Unconeoted (mns/yearl Msn'iss Im,rs/Tar) Ins/rna.) Sons/sad Nox CO sot 1,25 1.50 SAM 01. "CS 5.7d1 ,I.SrS1 SthSt Ca1S1 0.0...t Hun...Siren... Potential tor. Ins/yeml IIP.ILSIed Perrlinilli. mmMarl Ims/mearl Actual vwld MIninnearl 1.50...1 P.equomt Permitwniv flsM.A� Om.eerrll nbvlgyal.mene n -Heave 214 TAIP SletlIonol Methyl Mnoplan moot] _1.2:21B MISS C.0007 01;245 U.CIA11 28,1S, SASS* Mr.,: HAMS ucca2 0.3302 seal 0.W11 vote ae-a_ t.NT1 UI_.a ry.-1p section actRewixarvsummary McMP. wrvlvmnl - gnshslmrougn6beow, noawner or operator ofd source shallellowor causeme emtslon Into Meammpnere ofd pro.. n pollutant.. a in excess of av%,paaa.*nksanaw Is based on aaraaeruwe assay readings ran,. w.wh Haw. aM3w am�a° mafeamnll.nandga d,kregaladam gpareeo a rorslrmnere II:scanjeferenmratmegmrnb,srlearwmionsmenarementevnaemods seNan OAS -Smokeless Flare or Hares far me<ombusaan of Waste Gases No owner or operator ofasmaleless flare a other flare fee the combusmn arum. gums snail Slaw or cause embtlons Into Ilea...hereof any alrpollutant whlch b In acess af306°poe ry mina. 'bra pencil or periods aggngatirn more Oen sis mnu lyry consecutive hen n. R.t.txlany section the ernisslanofodorous obs tiros anySingle s to nrmultin which are M ess red excof thefollowngl6Mt: predominantly for restdendal or ercO purposes ise.atlun',odors ecedeteted after the odorous TIT has has been wits seven pl ormpre volumes ..or (nePan a •FAPOM,uirernans Megulslan3 Criterla Polluninn For criteria pollutant, nk Polluant ...inn mann. are required ton each Inmvmual emission point In a non- mmn n°m ofone or, W.V.,. or moreoanondindmiahene pollutant 1palluant are not m nO farsykh the area Is non -attainment s A.I.IIII, required to Mean MEN gnat mNviom au* 1ten peeves,VOL -construction Hermit East... Applicant . required to Q.T. a per.state uncontrolledwe emissions fromrot fecillryaw pester then the 2aTM...soma Snag 3 PartS,Suodonn.o.2a1 Regale., : Simonet epos Sarah s e m usual cbrp to control ern,* from the TEenannreian unit onon..wunder p ont a31 age fllefed'Pa3V,htsubjee tunas seelon of Seguinia.T.TMa portion ofOe regullion nste: Of a combustion device aseeds control enUsslons &VC. and other hydrocarbons.f.hall be enclosed, have no 'Atria ernIsslons dating normal cation, and be designed w that. Observer can by means oNSual obSerVaton Vault.vt'due o, the ...ad combustion device, sr by other mapproved by the D.., determine wtetar Isis operating Pao FS 05 n appro.. an altercate control dew's per neguladon TYc6onsN1.62e Please see Ole dtsoussion provided approval mnah. veapmmrmlwmea 1the .gblo ad,e6mm: col nninnpgvnuesno .- mgsuspportthnrequcemopemdtm'a flare. alternative minims control equtpnammr In pysls dehydrator durtng vgu aowname. ss 5551 g:\Pn\os\oswc113g.cps Flare Envi=sions Inventory Section m-IN..and PedemMsmdlMandTesImgRequirements Oxe the company than 95.3 for flare or eantualon deem, eves, tea permit pall oonteln and NOM wmallan[ maaeounatlpon m demenatrareme desw[mn eft -Henry of the come don deooe based on unlit and Dulletmnceno-adon sampling lahevolurne k d nteeman tletimt wepref. reducled un4er.ITTOnttan sna gpadudns Well I deerourproNdedaiefd0axrtq lefoneatfue regadingdMBow randinrgetareeted Pat gm.The WrradnmmeterW regutseeaaan me eremdUtanvPlx NUM. volume. These.Chnetettare meddalry. Thennewtoum opszdam up, mml gas . 're as ',tweeters -Y. offer an indlrece ne Drphaspense reavele wB Fapwgegnmvmmaf3roacfM Rap >s Utmanmerrtsj. ercc • mrmulsten enNW �Pabe° ( terwnlm regwrea m rue.,.taumehrde aMb1opawmeue„ a Nepnm[e Me.m Oa ptVOCan6.5emisslonsessoclutedgapeed purge gas la 1,etl on realdue sampl: 05/29/3, 5see eHvi M pod R niaMLamh ng ervs pa udz bap , tl cent( ml anP €aIR mam ..+ Igbt I WM1.m r emud am Pea ueedmob > Y if ,,,, mdmaletleeinUTlsaPetcnnetaathtM[omppar dmnmhamn meupeated Puu- antP t pmxta[eonernP d xolgn'„ mNN ear er. e.Teu el.. e5 m PnotmtWt mut h g r • o'd.%17, r shade as nn e address Urs.nrement,IteeMlu omh m esi. I aP.,3l,ererv5wasaev eweo-:Th omtlarmgmay leetwun:.«i �anvaraeareaae,mdmw�ww+mmera rn:t w m tentregane;.'“ Jana, f:ulw,,m ae,:w,ngen mbaolunglruram.de1•d9.Iaaed n.nvNemseTeete mpaape m theamourtrartd aatehueon uxnv ,enul.mtgm mmeaasen attrmtiveaaadlq by bf rah pup*ami,TT dRM- Atteu time m Interns Prmry1pr Bgyddt erglorn p+aiWc Agemow izrptth MeeWNamoae ea.I1, napgT-'ttme rerptaPChap am dzaty,undres,Mlo *ern mNu bar [wemassumeathat eonlvwwsafparnavpmsna4erfromanarek wothamsmdsas evprosed Purely Rgd kmaed ttlettheth th OM a lR tel a Mtat 1 leItemolle OWPfulddal) ,he y a Mese.. mqUIretlm eltlercortdaaa imttn�pS rlmmedltelyttubm pm { gate: •w tM ... ord. retn,rsaseuPessary easedotete.l am be munufeenTeraengntarele Taebmokelss ndptopp v.ltw Pasty aapmedt Nell udl art B ABo ifViv.d ; b Wred ssb3Na pgapp perform aHtbmantem prevetathe nem namsmdangaasedMP a w dept the eco. 'hues dam n :r tnMenanpmr DmwroBama Pee pgwk d#b2[haP nommaXAag Tartzaribk nmc PIIPmwiPmernIssion fattorofl.O WMMsttframnPhxthatee La used rotalos (;arbour M35}a�Wdce below np t3fi,(it pegfetelN rssu,.ultetldPiteldiMaulatOrytapulremenU wa dewmrn ban w.n mrsaa¢rt dni a,.Barawa peamdrnb vneM atdszmra. eupea nos ra;eamnant�PM at'H Rdu t a w th a lmtun, Mntwo-m waparamte 1p.Pareammtuntaa:ny an. A a amne nn, w the=zpn le., meter the1.44330 ita pWm umanamW pswrtWn nab m. i tK W:dr hag npiorasau t geato pod M1atpt04tht nu bn nshtnddymd do W apalr.m peaty IE li.lsea (ao MdtoluB Mather asaratnist MUMmaeh' Na plm'. mA b far dal rmo nmmt=theaMRd. jattetaar n amddms adsmegara. op1RtMgMM Pandth onap b, ashes ahemt.M ediMtt ati pperme Tegus aduadwnP.laehgamia,,,:uk autt.. �attdwahunk.tamplepon mpudi.,e ,t.a5tm.Wauegaeiwu3tP4 pd .oetm ...lparmamlosshenkdttdlMP tltpd pntr...me wmmndamarzuly.,rleflahadumddempnbareameI0Pl*lesukt[ttPat ltapt,tmdp.neu linoMtwwrodmtaatta,atop..htalmmmaaanitnaM Mf5yapa`anPEdwntmaa1O1y M.t $PdPh kdu.MMPabwtmmei.d04Pa derlantetoluanvntMtaHvdonter. PM.plp ,liad1Mlniadpa-+mralsdmataMaato w:an.pap ertmrtsmawernissy.n.enad5PMt lints.afmaotbpplaea'tPedmaattMahspt04a3P ....ten em°®mft+wa ',MWa fonts pikxtoxbea'e. tips mm awr,taretM1Mem MI. .mgr. m my x adn+a+Rapp a mklamquednetnopazsetlmwmvolume Msethearm 3aiatdnacl(vear aa0uam.,,.. ml zy weekry amoRamedn>umnr. mN ma:e. Tnea„no. ato amnenaaeda.,, ,,,t,,a wadaatmneaN ,,,.17.,,,moe,a em. ,,r: a 0, eamore oretacroze m.teUon oflm,y Ned,xaalece do Wame':;e tetpaltd letotaz ,ed...lett residua gsm Mlcu • ra d s. Pule° nrmwdaamaaend aseamalalare adawm fleas h k nravinnwera T.... me vae P1 thkandvspta hg 'ssl B ough W edkr, T W ttro wb wstliiB arelbrl.Z, f.„,4MMurt ISo50NMBtu/MMsstf/I„0.1 BrvHJ.Msery(31nMMs[fNeale000u e/vear lORenlae1Welo/va.II-/1011 ntsarea la0 ▪ IIPM OIPMMMeeanlrrmMMBdyMMartv'ter<MMpefv,-,t�,o)ronrdtl i*an,aMelldm j=Io-am.rorMMam^am-omMBP,/Mrdtmitto3 td/MM:dn-l»< = mte.htNtlmutretess mmmnt.uareadGR,eve+vass,ane the el rarpray 4edpktnyrtvel'Itemrue, see ana PenaepmaamepOottueliueenatmontued,mepem'twi tledtWnam dam demos a nlaergbt fuel he'moneME • megwaadetivaatorropeted by wtatl. smkatmil enclosed combustor l',meet premed erne .ennedonefrorrareed.nPUPeu, rave.,Pltdmtmtr dmiiMmgN veredueul.,bwmcsnae drtapto te.ie,theopentorsernircedit•u«dppdteeenteequctpomrmeuprwtteleeneetmaeaeaPaore rame`aan.tn enr •sa v w.Pegalzmn1eanoaxvg; eased one Goo.eir,Panem9uPu ue,Tern”weueed rymeapeta',e sanema neP,?reee Ne▪ taeolaeapenea?exacenvole!eglyaa dehydatoraudnglmua tM1erP aw,grexone Ur pea, flare Is not. pnmay.sen.on for unissiums from. glee oldelled,ulee nueT. 5aau dtld 1 ant nb[vapeaadualyllPln(t)tW ng noun. ateada rhueVentafVPUdoeuPelletrUauorNanniluldouneinlel,Iluentend gas urpluvons are routed tar., FT AU yd ( I heapen flare wOTeal* mcentgdtsll of hydrocerbaner,salormandhesamanufacm dslangueranteeo odaonnel r ys«Mr on dine open flare wleieera.u.nd WJweemrssmnzabe wTwwe see am,gittmr, atite comply Wm the reoora lierree source has provide. reaustand mmWwfuede[zdenmtM lie .. Centel Ppetpreenteepuot Forne,Peerkred mdltheaw wzra yi/p ospNlydlontMsvutudaesno daymmmM 7 ms4rrteueream mmpgowtandem skn gyesmtl dawrWme a tul ou wnkdl ea debvammpt inteNHaepeOBare`,k rpsing.t0goestedSfiplCameGaasneslglsco lepv pWentk stn I N mecandeni`aoz,sm e o prodpFed tank rvardvslsao re e,dgtheteal ottdsapppca ... a m evWetl Pleaxreeeen bm,M drtW/sD(meB (our PoIntX 1. NDz VOC sagen ps-InuentoryBaCoding* Emission...era Onoantrzatud Talons rector Control% Units 0,17 0 3.71 Toluene 15,355 EN4333ne 4ykne cB Methanol 2.571,411 e0WMercepm HOT VOL 5.7 n.Hemane 1.. 95 95 95 95 95 IPMMsal Bunted IbMMPaBunter IbMMsap Burned IMMMXI Burned IbMMscf Burned WptMM(Bumm WMPdsa(mma IbMMuf Owned I MMafeumed tbMMscf Burnes IbMMs[f Burned mMMsct Burned tbMMuf Burned WMMpPOuma WMMuf euma PMMutOumed lbMMul OuIned WMMasfeuma lbtalen m0/ IBMMBurned WWMAaeleuma MMafMmM mrtlonn ppeleta with purge sex Inlet gs and re...peas wen. process m represents peat eget wnbustlenTm maatonetad:on represented In prams mere based on weightedeverage of Inlet endneskluegee • X: P.tmtaWEn3B03 Turbine Emissions Inventory Section 01 - Adraintrtratiw Information IFacIWAnsle: . t 6 ;tt _ — ° COunty Plant Pant 4SmIssitans for porn 1241.30... estimated through eb. earn. mornodpw suck this .... prnuld.a an.natysb for bath whine units as on aeons an tlemlolltom.nb. S.ann OE Enulomant 0.eelpepn Roil: Tie 111 setae 1 rarW Att.12twat input rUi4 Detailed WWI.. Unit Emf.. Control Device n nP a Requested Overall SOC&HAP CarmControl €n. o< ea Efficiency. SdaNOx ['considered an integral coot. device. 4nbnon-PmaninPMpIrlwr r1b Hem3eNdV:5L ON ..,.. ap a�eRata. Rwmr ea ant of wane ws= eu/scf Actual Hwrs of Opemtlan. nr:/war New Source of yet installed ,001.44..4.1.14144 nea30.. vendHoursHof Operation. ROSS ors/war Anal bee[ Input rate. Requested neat Input rate. Potential to E.nitIPTEI heat Input mm= Amel Fuel Consumption. Requested Fuel Contumpdon. Paco ,LY? Nrblip:5l.if.up Eblrcg...:., .: Psoau&!3 [bi41*td wlm Humber of tuhrne shutdown Time per shutdownevent events per year MMBN per year 51.4.7.3.1.20 MMBTU per year 0.a MMscf/year 03..ffi/6 MMscf/year 15)3271 WALT/year Pollutant Con Wonl WW1,. factor Sour. a s s o®® M27===liffEMMIMEIMEM MIEMETSIMM MMIZMM WIRIEWR' �ruha�F. npEn.me Emission Factors WWI. [mlukn Wt. soum. Poi..0(Ib/..1 Poi.. Unman.. 15/Irl ( ml I otl voc a. rf�;u m'::n��uu:,sndaa Emission radon Whin. [mwtn P,m.senm. wlluwm Uncontrolledtin ntrand ll I. (Stan -up aver. (Swhup.u..1 27of B1 Turbine Emissions Iflventory sedvistow .ap.andr.. . CM. Pdltann Pain. to ErnIt Uncontrolled Actual 'Melons Como -bled Uncontrolled Mom/yarl ...tad Permit.. trolled moiled Uncontrolled (Mmrye.rl Monthly limn rolled (bs/monMl VOL 50,4 NCle CO 5.00 a., CAM, bdt.EM 101.105835 bolea1.9114 324,75546 0.9$ MOO a ue 0.9R 147,57152 15.09 .0 L5.03 15.02 .55.04105.6 17.N9 COO 0. Imo ILS9 .196,VMAII Hazardous/1M Pollutants Potential to Emit Uncontrolled (tun/year) Actual Emissions Uncontrolled Controlled hens/Karinomrvwrl Requested Permit Umin Ummnwlled Controlled IteaS/Vean Imryearl Requested theft Permit the Uncontrolled Controlled abrntid Pn/eeed Formabehd. - Acetaldehyde I4 442 1,5M.02 13.1634 25.1684 13Mnaakn. 2db) Ethylhensene 42.6TEa3 SMr4,9 Toluene 3 of 0altbA0 23y9 PAH 6.1d111.04 OM... bOOLCMOil 6.3,1,0.1 5.171,04 1.22M laM1 Xylem ..A53_[lt 0_.000. . 0.000.0.1 1..33E 01 1...3E/11 37.0635 3. CARS Criteria Pdl.na VOC Potemial Malt Uncontrolled ltonshearl Actual Em Uncontrolled [rolled (tom/e=arl Itom/yearl Permlt Unolb Un ntrolletlControlled Itoe/.arl hors/earl bib boa MOD a. 11,11 b.s2 0.011 Criterla Pollutants VOC Potential to Uncontrolled l[ itons/yearl .mane 06 Regulator, Summery MA. Regaled.. Section II.A.1-Except as provided In paragraphs through B below, a owner or operator ofd source shall allow or ante the emisdon into Me ere deny air pollutant which kin exams, 20 206 opacity. T issandard Is based on. consecutive opacity readings van at 1.5. Intervals fa.minutes The approved referee. test method tor tribe emissions measurement is EPA Method 9(40 Madded , App.a.a Vol, 1592)) in all s,AsectianofSecton ILA and B db.m dal:a M.A. No owner or operator shall cause or permitto be emitted Into the atmosphere from any fuel -burning equipment. P.M... matter uIn the flue pus which exceed the following: l.0>.11. barbel burning equipment with desyned heatlnpungrezter than 1xlO'ale Perdw, hales than °requal ho500,-..... dO'eTU per her, the following equation will be used to determine the allowable portico.. emission limitation. PEns(Nl.. Where: pE=Partltulate Em,lalonlnpoundapar million BTU heat input FI=Fuel Inpueln Million BTU perdur. The turbines coven. under pond 1296130 have a design hen input rate °66.12 MMetu/ r. Asa mule the turbines are subject to ibis portion°Ma regulation...loaOm above potion, the allowable wdiculate emission 6mianen h 0.16111bMMana The AP -41 emission lector&66x0" W/MMalu used kr the.ku.bre also. h below., particulate omission threshold. Section VI.B.e. ur° sulfur dioxide shall not emit or ache to be emitted sulfur do.. towns. of the following press -meet. Iimladons (Heat Input atm shall be the manufacturers guaranteed maximum heat Input...) e.o.o.m. Combustion Turbines with a heat Input of less dun 350 million BTU per hour: 0.e pounds of sulfur dbvtlo par,tike BTU of hut Input The turbines mound tattler po ion 123 8130 have a design hen Inpn rata .66.12 MMBa/hr. As a m ub, the turbines are subject w this portion althe regulation. The Av.ax ...babe factor of 3.mu'b/MMMu..d in the al..bm above h belowthtsurur druid ...don Mnaheld. Regulatlonl section IA -No person, wherever located, shall cause w allow the emission of odorous air wAaminann from any single source such to result detectable des which are measured 'names of the following limit: Far areas used predominantly for residential amnmerdel purposes It's vfoladoni on are detected after the odorous air has been diluted with seven Tn a more volume ofodor free A. Regulation Port EN Requirements tern Pollute.: Pa criteria pdiwne. Air Pollutant Emission Nademare required fa: each Indl .dual emission polnt in a nal-attainment with uncalbdied actual....done ton per year or mare of any lndiwdual criteria poll.nt(polaann are not summdl for which the area lsn ' Applicant b required too file an APEN since amhsiem.xceed l ton per visor NO. Out B —Construct,. Penult Exemptions Applicant h required to obt.e permhdme uncontrolled NM emissions from MK bent, are anew.... 20 TPYMreshob(Reg. 3, Parc-9,Sedon 11.0.1.1 ...lens Pert a Section 11: bender. 01 Perbrrearru for New Fuel Burning Equipment: AStandard for Particulate Nieman[' on which the regwrd performance test is completed, no mune a operator I:deam the paws atlasregulaew mays .dame, venom the discharge Irmo the eoncepdaa Parnate mat. Wda ch heat Input.. fol low.. sal burning emdpment generating greater Man ore mOBon hum lea den 250 million en per ha.d equatIon will be us' to determine the allowable particulate emission llmivdon: Ec051R1a.2s . Where: EN the allowable mrdeulate emlalon In pounds per m1111on 0tu heat Input. Ft K the fuel Input In roOll. Btu per hest. If two ar more unlb connect to any nln e maximum allowable mission fate shall be Me sum of the Individual emission rates. IL.. Greater than 20 pecan -capacity. ndotd arSuduroloJde: an and atterthedatea which the remeed perrermenee m ho mpletd, p pwnera oparanvsuble.t provisioned. regulation may dscarge, ormuse de discharge into the atmosphere sulfur dialde In excess°: Dag., Salmi with a heat Input of less than 250 mutton Btu per hour. 0.e In. sol/n.Blion Btu The turbines covered under point 120 8130 have a design beat input rate of 66.12 MMMu/hr and will he constructed atter 01/30/11. As . muh, the turbines are subject to this portion .the regulation. Using the above equation n d.C-2, the allowable par* s.woman, The npdx emhmn foot. a6.6.0. PM/MMMu used nMe oak.... above hb.low this wawa. emiaun.ash& d.Addim,aM.the AP-1lemh.bn amrof 3.aa0.'Ib SO 4MMMea used in the akulama above h helowthbsurer dim. onalon thmheM a o.a m.o./moat. N€PS W. The prwWas of this subpart are applicable co.be f....gaBmd laclliden All stationary gas Wolin YAM a hat MPa et pack load equal to or greater Man 10.7 gigamlesiln million etuj per hour. based.......anrgwl.atie fuel... The heat input at gab load brthese 'whites (Pita 129 8130) h 66.12 MMBtul3rr which h...rth n 1a MMBeu/hr. As a mush, the turbines would be subject. thb MP. however, the turbines are also subjenm MPS KKKK(seeepplkabuhy*cession bah.). amt... MPS IOW 460.43050) Stationary combustion turbines regulated ender Mk subpart are exempt from Me regebamm. of subpart. of this part Haat remwry stem generators and duct lumen regulated under,. subpart ere exempted ham the rest manta of subpart. Da, Oh, and Deaf this wt. Asa...4.PS. does tea apply top 12 1000b 1l you are tleaena a operator., mnaary mmhusdon Outline with a heat input atpak load equal toe greater than IV gigajawes 40 Writhe' per hoe, based on de higher hating value ° the fee, whim commend construction, and IPab'm, or ratans...naaer February., 200S, your turbine fs subject to thissubpart This turbines (Point 123 8.130) haw. heat input at peak lad of66.11 MMBtu/Tr(a SOMMBtu/hr) and will commence construction aftaIFebnsary1,2005. As a result,NSPS KK (applies to them turbines.The applicable sequlrememr Nee been IIcled.d in the Beguletion7 aarses Adlunrnea APPRaiNg. a...as provided In Avon XN0.2, As als...1,1017,Mo Section XN.O.G. applies to boilers, duct human, proms heaters. stationery combustion turbine., and stationary wdproating internal combustion engines with uncontrolled actual emhsbns a woo...Ito or.mmrthenMe(silo oor000r that ..ad at majoravumes of Nose a of lime 3,3016. The turbines severed under p..1296130 an bated ata major sours., of NOI however, the turbines were stalled .ft.rlone 3, mfi(tey 0e/as/2uvl.Asaresod, Meturbines are net subject a fhb portion a Me mgnhtbn. MAR MAR W W: You are subject. this subpart idyou own or operate. stationary combustion turbine bated at a reefer source of HAP 'Mauled:4nel (Point 129 8130) a a net subject to MARY.because 'haven located sten aria seam of MAP emissions. dual Emissions Uncontrolled Controlled Mons/marl (tomNarl GC brM cda 0.50 Requested Permit Llmin Uncontrolled Controlled (tons/year) ItomNeerl 0.0a 0.13 0.0.1 MM1 06n 0.„s 28°61 r:VAMS\05WE1136.CP5 Turbine Emissions Inventory based on a ratloo120,21norNnethanehydroca2bOns0[ato2022pr2v.lez22,32.ervatIveestIrnate-o,OC emI222ans "Mb um -220.22k,, the ,o505000'66409rate of 610/22µe I23615,5/hr F./5525592 -tub the75 .5221 a b/22rnstu u.2 s 6/2269h4 02µv 2021,,,M2,, tletermirled Oxus. of the AP -22 emissione for the foOravArerea,ons, Pm m erapproprratereferencedocbmen,m,..,2n22.mar.ufaccurepspecOcat,c222.neets express that.ebrOCemIssbre ore cy (25i2210326250 by Saar 11 1/5,5551 m 5o buzedAp OJocrorsJp 0504544001055557 on4Nnpemissb 0 oar, Noxp c Jxr. b1O1/044EMms h tl 0 1accept2.2P222emission fact,sforY b. use of AP -121222222table for the VOC em,s2Ions2 In terms f PI2 emlssuarts, Solar P12 271su.es.22e (EPA is )f 5 hmvable ndtel"eM A d.e fB r of cnn on. ea:o xp em. 59%n 0¢%loadforgaefue /5459. NOx eke{4n 01+ nA .ts 5t 2,2,2224,22.e turbine reted:nawxy mat Jc 5olcNo 5515,5 M . 4575,5 vmycu ttvf eefeczonsp o <ontlnua mpn nsIdei S. 2222,21.1 2,02 emissossl0100 v/ de55m1ne sortzO enaryac end vmudhecoo oenuartet(ybasla. hemicial suck e055.2.2,bnenmO44 0n as5oinva po 2s:1i1 5911140 mY 03 rov 11, 00556120 engraved 5_(21600 fl0 10 Percent too 7525%.I I6Op2rna 1.602,1C N lmtp0 O 5wriP 0. pure cr.15,409 66 (e5N0,5,1 52050. anaina compliance udd Ia. 221,4tIn order todernonstrata ong22,6 compliancewth Thep mn-d be2,22 2,222 .2,,22 ,e2t,e2 ,22...,...2.2Te2,2,e2,he2f .2222r lo dernonstramcomollance +6.1. the 26P222.M2x 52212.21 25 ,pn12215.022gelL2lowev2r, zs d on mm1,60.514922 .60252:n25 the2urbine iscapable of oparatin2aEl202653.3112 ppm at 1:92. oxygen rf the sta,estrigrepurin,.e operator to demorL22-2,2 comuRan2e-wrtn the em,2.2m 2212155.1 o, snoc, ed t6c er e t 0550 55.0, wouldn't"_ry orstrat with J+ep thstert-. antl el2122 26214 wasdscusshdwlih tNcepataotifie 72,n722.22 fac2mAemand aaurerprov,ad claca Included emisson rate,. 2,02, ana VC^ Elwin; d regpemdtopermma mgfof shutdowns 5 o Indicated o W loll,. : xu Section .1 about, T. Iqu v* / r6 anWawv emIsslom «silting and shemawrc a adm+onmrrormatttkbmopetamn a. In theyeeMot2 n.1F dto hurter ahO2h frr wasnn 00 oo9hp 2061 -rim 5015 mnoyera 40lBled apP a oaltcomP >e; th N t help elmer '6 nuddtattifa namt 54{555 009054 t ew n.e�`Th.na rpa "leaved aa raaa,aemvf 15905/ P122,5221,2,204 IA Iv fo95 1 2:1::hat Octon ,seat e bymultiply,-�+1b/M onfactors", rFe des,eolleatc. r pa a obla0,5115 005550 u. 15559 50,6555(0 d 1 s result.eactvafemssonc ons were uorevaluateda©slated 750400. there con mos leas05/s6/5a18.50526 I Bess e .d.e& #afsP rE sr.. no inventory SC, mane end Coilsern recce. rmhebmed PoNµene Factor Cenbolx Unlo PM10 5.5 42 422 6/Mµ550 npst 6µM850 input We VOL .10646/MO3 b/MMB tu Input 5.010.6 h/MMetu Input 502 5.455.1 4/9205959 Input Formaldehyde 5.04 A 2/5505256 Input Atetaldehyde 500r. 6/2222296 Input 59666/2222950Input 6/µM650 input 1,3-Buatl a 530E.C7 6/MMBtu Input Emvibnuene b/MINIltu 6220 Toluene 4/µM050 Input Pelt b/µ22B50Input Xylenn 6.401. 5/222295,4 Input VOL NOe CO N. too 62.00 b/sareup event Wm:art-up even` Wet.6/067571 event b/shutdown event b/950521.,50 event 29 of 61 504A\09\08 W E1136.5P5 Glycol Dehydrator Emissions Inventory Seabnm Admb6trative IMe:mntbn County Section 03 - Equipment Description Math Dehydratorldprmatbn Mhydnear Type: Maket Model: Serial Number: DeMg:opadN: RedrtuleJgn Pump IMnrmetbn Number of Pumps PumIs *Rs Make: Deep/Mae RedrculaHm Rem: Dehytlmmr Equips.,, Flesh Tank hoilerMmer SelppingGas ,(ash tank, end reballes burner Cat, *NU:vises gpmi(IFCI•abrel gas delegemtlets k:Mukn: Pnfem eelPmjeun del.TatLw, .e*lsgRhe **liespultygE23G Msel psyM,em6ames unhuequipwgh ped3 EMek'a:in'i:. ModekMOISNT-3M POPO; eled�exs*en yycwte_he P dttsiau (seq.,' ¢ Os eermC..M. Mfr Dehydrator Equipment Oettdpdon ttakeHir, ellen mhk equipped with a sdilue** flashtsek, turd mMiMr bum :cot Mtee En..0u:C the aims:* are 011,a10{.1 settees, and*maw:he vsee.ememeutt. mused, zn'n lAtt AssCWdevise,e- leen from the Eesb ineR am:mued dkecrytp the M:pne Rescuers Gnh RAl:i As Resent*, sae,. desk ,Rash Molt *missies, ere Emission Control Mule Description: touted. Um Rees pen Fa. Sestina e3. Processing Rata Inbroatbn for Emissions &Rmnte. Primary Emissions -DebydmbrSCR Vent and gab Tank *tunnel 'Requested Penult Limit Throughput= .: .,SC,S5a s`n MMsd pe,tear Potential to Emit (PTE) Throughput* _ Metxf peeves* Second, Frnlmians • Combustion Mekelb for Air Pollution Control Stet Knifemen! Condense Condenser emission M.O. dela: Primary control desk.: control dente operation, Secondary control desks: Secondary inner, dal¢ operation: Still Vent Gm Resting Value: Still Vent Waste Gas... ILITE Raab unit Como* Primary mallet dee.: Primary control device Seated, contest dew.: on. secadaT conerd desk:mopes-aeons Flash Tank Goa Healing Value Hash Tenk Waste Ges Vent Pete: Section a - Fm hsbns Pe sten 8 Met bo dabeh Inlet Gas P:esure Inlet Gas Temperature Requested Glycol Recirculate Pate MILL VENT Pollutant unscestrolled (IS/hr) Controlled (bind controlled(Ib/n) Scream x. _: Td CSCCCSuane - `I b]S G x 46<Pa Weni-Cia d :. mgen5LN's(Hsl 'toni'F`:q%. a O.CR1,132s Den Renuened Monthly Throughput= 5%I ContrN EMtlencV % [terry% control Sanado Pnmary I e Pollutant Unconedled(bM) Controlled (IhR,r) Controlled OW] 4.70632 Bertlent 0.) Toluene :. J r a 33 0257,3 Ethylbensene %ylenn Went. v_aTMP .. ....0 0 tl Hydrogen Sdgde M)sl =a0mx a *RIM. 7130 NIMsof per moles GasThmuehont: su§ ventpon,,cgnnm: fl.iIC.e NINtscf/vr Still Vent Wvdary[mwl: 1,67R.0 INIVIscf/yr un SSW Vent Pdm.N Coned: .0 MM. -Ns Still Vebiecondary Coned: e.'ge MMxf/vr ors0 i flimu hers: Flash Tarsk Primary Coned: MMscI/Tr Flash Tank Secondary Centro: F,6+.0 MMscf/Vr Wote Gas �ehd�ea: Flash,.Primary Coned: 0.0 MMscf/yr Flash Tank Secondary Control: 0_4x7 MMsd/yr tun qml Want Oman Carelenser Temperature £48..3 MMMT/mmlh CO MMsrf/monen ;O4 36 tit 63 1***** seuttet3,3etee 13303,4 33, Glycol Dehydrator Emissions Inventory Scotian OS - Fmbsrans'Mentos( DM operator request buffer? Requested Buffer (96), Criteria Palma,. Potential tEnit tmlled (Mabee') Feud Emissions Uncontrolled Controlled Rao/Wad Daras/Verrd Requested ermltUnl¢ Uncontrolled Perna Im¢hat icons/Wed Regneated Monthly Urnits Controlled pba/mantbl MI6u.gcBagar va[ e.tm a.uo tl.a. eat a.Blft rmra 0.07A Gan 73.2 lSra.tol Mal. laMear Loa la Hazardous Mr Pollumn¢ Potential o Emit Uncontrolled lllasMealrl Caul ...eons Uncontrolled Slashrearl Ilbapearl Requested Pemit llmlla tiControlled 0barywrle IlM/wri Toluene ENrylbam ne Xylem EteTM Hydrogen sualde(HRB) ara2S9.71 73,234 7.1 ara.a3 7.8,2a4.71 IV., ft. a00 Sae - 'a 5:x at 6;araal ia SS 07,30 Rad iZ8t salon al.W uleorv'ymmary Analysis Regulation 3. Pena 0.B Restrict:1.7,5e.. MN) Source um.. wpm Regulation ',Sanaa. AC, Subpart MC (Areal Regulation 8, Part E, M0Crsbwrt HN (Mafori Regulation It Pert S. MACS Subpart HMI Ise n9uYwrvaPPlham{W umrblmrt ( odO.8.d anatV.01 AYn,&6: TM macro, :Mao. Hratadobnimmri< soda. a RAMMIMn?,sxaarnMai .¢:.e cart: mace±ru marrow aeeuLtbu., srt'icaM H itFb PaMitt r You Mae Mars.- IJOcanas aarartt EtnaMorttnc acmes fitm Mo. m cot* dr. rvs Lower nq va Mcrae, Xeotioq MOO. ot rutaccooro :oz taars Int Ana antactoon marntera namnas taraMlarclaimora alaracca lacenc Earl-.nocra na nano -IMP aaVaartr or rmootena, MZe Lower Heat, Value &cos Nigher Hcalmgvaluoof cos 1.13,11V2 Fitttarr Glycol Dehydrator Emissions Inventory Section 07 anal Periodic Semis.. ± IV0. 3±44/pm rnes Was the artanded was gas sample Gmars mmdd4,pedge andmie<te4Wmn a year lin, the penult., contain an Diehl<emplane tatting reg0 nmamm damanrtrate comp.... emhalan Do. 0. eosaPsiarreg nnal 4401re Wider., gr eater er then95% for a Dare or combos re Dyes, the pe h tzero.i nb. end InInitialm pU Initial .ttestmMNanindemonstrate-the d...DioneM"d.43Ndie mmhraWn davi hued onInlets. attaar concealsI.o sensor, has mud deviceeffciencygreatrthang5%,isathemaloxidlxrearegenerativethermalmlalsrheinous.mashieeltMI Nn yx,t. poem±win containcondition sp.3±08g rho minimum comhurtbn .rmh.rbmparatne fort. thermal orliber dar using a thermal midb., AND resimeileg a minimum mnhmtlm chamber temperature taam.. 1,000 degrees F' .. If y., she permit will contain an Inhhltamplhnce tasting raqu4ram.4 AND. 8*rm lmndidon specifying the minimum aomburionclimber temparaton forth. .Senn ad-TeN10±0 33 ±Nate g, iWNs dgsappliead n,NOsarMBtlliml4 xartrtart Ae Perm CAtldltlwml y,4ie Prooeslim..5i. 8i^h.S50ii,s0ii-OoDtsosi,asiSSosrtisassOArses75s7 osioi5in7 iho m irdra4a Das Orterztentled.ssnalysis used as bndslorae 013* 0lm,Wdpn5basedOn snoop.. o0 slmutatl. or 00 newts ncedte Cams., gasartalysisosedAi tsaesPKOQ.ag.ehl'.e011 apcerm qukerpmtyzzl±0 00dlrv0,00,0 otisfssria00 500103 rm8. b serequ4esUm vin gas pt pn'ur me00 nl0 *0,et*, t.slmu09Mrant.annmteateeampPa,0.o±0100., olonI4±,&Thecperamrhexnoto±08 ddtlrsinl.4lexdngs.5 8±1enc00sresult,d80 a remamin aMp.o,,, adsedors .. aporsoilartithe roes.. her indicated thattwo esp. res.a.'ponitsiVAID.11 Dais. to cipturestel ntand MehtaakurWe ADZ mum:ehvYm thephnt n4eOr. vxu Wd actors e* andthe s004*10UWll he in plans in boa eve VRUizn eradonel.ln theorem dmtMMVNhm en Asheweam.has axFa ap waste gas torn win item time mum.Delray-?5.l airs/testi. , 4..51nc4Megqoldehydremtcoaeredbythhpdmfssehfachmgeyv4aanlnearton755,znenUmM00000 m0tequircdtomnwiemkiwr¢.f*Aislnsta80Meweramr questingmeomrde.rrofs4ms'troin;he dehYdmtm, 1,0 0 10 0/ROOgwnf.e,Mrpaghi. weaEanopoo Pare Dore 0.5 Win 00,13 d4 ama a egtdiosoramdei Naegiadpny 1400 %1&S:m thaDperamwm te" r bea MAlxmas[ve ants.0*IPmentffe0uesthgreros34080 0 requetti um nn open hate that.nane0dosed Darr mm90orre vA.Arguhdanl5e±00000I1, Bas*oaamkwel MCNtervo"ye Emisloo *41±00044 06 ±10,0,00000 00090-0108.00080 Matema 75.5, Implapprw8Meose±0 Me opent0remcamol MeolycoldNrydmtwd4d8gom0dgwmlme.for thefaAowingrea4001 /00Nhort. Odra It nathapknarydashlatlemfdremlrslans.framr. Decal rtehyrtirca,THA Aare ice.5.as backup DAD,80 Oahe (1061i:T0± 101 o o1±ssand nashrosa4eanrsedad Slam n4srte5ePor liecpyeryUnlfs/VPltidluingnwmM Weradm,m.e event oeVaua(umime(meroEY%rt.urafdewntlrtrj Wirent.rt Mshgasemisarorzmerwtadto flare 7.3 with 95% ORE DCP is requeedngtoriheapaneare tote rne¢ aniy. openBieee be.00400ry.rantm000 fir dace Di) open Paaewml:taad bnt95%ophydr0.00, nnail rsendhas nuracuvv p±0 b eopo,8000* farhyrrm tW)iheooeneDare vrltoperaamwai usse..Yeemorljes,beaOWppedv:ManalatMgNter and OlherynsebeabrebwmplrvaalquIpmentrequ tsofPega6gw+]xalm XVII. B. Dv) Doofl d.5n0cea0. ten tenon.. V eapereme requesting sdowntime&eepnrtani000 hit nes.175.113 .One31p application sore iuse ssinAtdeaps acedees0aszmed LrnemAlasaca4M year.TAebperems -ear they±p ,00,1 n8em.£Me3ldaymentHhaslu(murs.smm4weart umisshm 00ontl,ereq.»r.0anwnemas rani 00,0,0,00 mtb00/ .0,0 o Im tlxhw dnare48 nor oducewhcnititco.o,,00.oM1ydxmr. (v}Th x i4smzrve.em span degwpmenefwemrivanskorrz}end Dude or produced wa4rsmmge4nk. -- 5 Whea000 MC0emtsdo,0 0e:b 1.0APEN re60aeng tie...the periolmal DV contain ¢000,00 lm m NON and C6. These ihreis were included in0, 10ri101, .0040o0,aria taDlaradisaiNanioraaahlailmitshorrteria.sold MAY NANDI require..- . The emissions from AestAirentare mated me cOMemarmlor tobe1ng00o0d 10-010ll. ortersilare.lioriesor,rt.operaorleAotWongspolr. any man'dachievedbyth4000400aar, DID saamonsna0d in the 04 0004 00003*000 #4000±000,emhsl010 strewth:on theDirColcmadelortralcartatronsOnnolled ertaisslorAsiode.ga1IX0%con0dass0OTted0Aah0VRUard95%eomrdas 00484.wlth Omgere00 calculate Axasesol, norther dm permitnar the 004 pioneer. manna.00 demands 4mpermae. poems , 00. 43raeore Worts acwuntiorr.conalenser. Uam,n.stianr0100 0nsaz ah..0 00 .010 t tt.r d Ledbaiow.Ps-msutGtMpermltwnt egNxtlnopee?�tar to monitor are DinclortzetrivrterxlnReram krux ntllcmorsthlY4Ya2al9sknAatbrt. a tsx deh oDnes. 0± nildrce0±rpm esodated with 0*'CandetmerVm05heam'inthe G1Cikva4..A. DADA.ropera. h4 iWtlg aedrtfor Ae de device. the wart. the co...sweetDramto±0 atoto tyencmm0.ustlwwnleso00 00eRtable aeltf Nader b<000 11eserail c000 101 m heetharopettifs104tebU'Astilisen0 h emis0aswodd0avehorn In ads50rsam.'1F0000ma,M,4O.nsi.d,NOsandDOemisdmtsuaWdlsaseea Pi.005tpyan0G.46rapvreweetrtsiV*Nat m Ub Moloch A7.500 sefilari.ComparafivelD d'DeroStrean,Orapertiertresolt ihNOAArtitC6rinissto.asrtfiLOT5,0404 od0.'eoojanserWeh'IA [mod ei X0000 ill 4a0N r dasuRmdme.nga, rathprteg41et0ryreg0 remema /a surly.Eward<4rmipea E.weort:9omp.ortaardnmrrzm.awdalaawtume'rmWense errcstmem-uadecrp4 0rzsvmetrR ventcornhtrazlon ,. ernh.wrar. ' erTheisperator calculator 9tr0 emissio40001#ga m04.lmt®.arid the assumption A¢0300%olrho 005r<mdting Dorn Dm dehydmianunit0 a.vert..502 }4d0WNan besto0arie: soz{n*Near4=(Bx.aN1.4754earisi t06blbsos/usedNl'a OPe°°ibHss11.0110000mimnlrnasmnwz/Year:thismlr4bdonhmekaconserradetedmateartd therefore acepvble ter permit. The quietist dld not.iculate PM emisdorsaseecieted urea this mmbw0onutstle tandelash 4nkemtta w..rears at sited mandmnhaledhythe p4rrtnare {point an theoperamresen<dthetsin. Das Rareis design. to. sindielessm0Matlonde3m,Wrifc4he matter is w[expectedm.gnc0ed rerrrtAs o urticoordhy0ramrwaite gee so.ea mthisderie. maaareuth art Deo...eras Wm W.I einkslonsMOsand COLAP-i;C. tot terirortrt.lhis d.amerrcexpresuiNe amt.10.5amnzsiilgma04,00d0±0000pa00 4Umrl, bored 0±00 0r ar0dlybu0 010al4eed hydracarbons.A 0111 darers.ogeteAdespme/aw...futmnmnfog massrlal wanes hyamgen 1 orins map.. lsNr00 1 mme45OE1"eared on. Ms's44mem the doom smile.notprevia. h Carmattonwth ragaMs topartlesiD.mrten Arapewkh rear. Di The.a ntrurtherpraad atmokinghata aactfri.','540oriortnadorteten Itsams"the tonae0Nyia.Art.stnokeorm.0esmti5inikenreaby4urithar34303 ,0dby Me amountand dlwibuam of rarer,. m themmhusdoneee Thhts harem woo.. by`aomoae'0/1 0mbte 3.Stwhkh perides Ae forrisener "Soot in onvduesanoratmaWgflrr 0miwpam i0100,I/b#oDom000brrgaw xa0008,'.aea ter fleas; llltg,„an heavnyam0Mngliaes.l,dI000000 th0 e.rebnotarwt.r'.- orreoEdate teat 4 dOes'PM£6onPM 5_tr mfndrevtlel.Ar ther..D.1E.assumed chat the dysourliof partleala[amat4r ice a fare Is.sooitmm smokes earns., InApolfllap[et 138 It should noted. McOgM plan repulses -Mat deify eras. he .noluetralanderan.e irtherleintsspping ifsmo.A. observer Mg the daitycherkthesoer¢isrnqu red: to eitherc.woa a too.. TFm immedhmy cn.e.egvrpmenem....iga4.Uw ode..ram smoke and conduct moo. or worsts,. Oasedot dais requirement -for she -rare and.er.m.coer desieDiert.dare lobe smokatessffopera. .t.*oped,se. Altair tart waned that the flora wOlopente most...kr one xgil. hesrt, ADD zmpk<Isa rred;the aparatmwGOe reg4e0, maasese • d perform nneessary0100 irtato00 emdre Dam 0!Wng,ga.ed on 01008,arta 1000000 0wlliaze9tafl00 tlndaxatcanc az0sinant,000 Lx4Osp100 d 0l.outser.135. fotronvnobngnamsmths gme.5nca theftatt.ptlsopetdhattiQB�Fl3/10Y8),t1iere Have onrybeen MorepOrledoparftpewn4fordil re.Thissupp0r¢ har umenti.tM mwnabtenNVaperateewithomsmoke: - One ollree0 mthot. tirt ...Arend is that. pe team{mpgav/0 if.r.Ostahrtlatairtg h artiesilinStrie VDU tote yd a.Th Vml zen0/ 4000? to have Amax of$%anneel Nsw0t0ge audngwa0 In,uufafie r08000tharlere.ntinmb/PM emission factor WWM.,from00'40 a#0800.ewee usedtneto4030. rs,as/000±05 psi 10eaaigoM heeddu00000000,0±0ucn. Me ars..0 a,es d vawld rosrerukln pmmicOmits. DM= rau±ln addit.nalregNamry regtdmmentz Eased on theinrdrmadondrroased rhis., Awns desumTaaerat exmhesseroon theta-.. ass narers.knot beexactedtah.vapMem wears w9 he me;NOwmm,nhemeda4gstlevempedn rap a die ..< asdmaeng PM anici0rsframirMmrahihies itdn idbe loralurtootintA.e analysis. 10. Issuance of shapermltmdudeda gm an mralgas 00834 0,1045000 ma.ilaslmitseer dsWe0/0,80 rt0mit Arras pa40,m.o*dramoo,tooarerauted moo 0mip0 .Atoi Jenne. this deDsloa toarinortobecaux toot Bask an Aortal megsucrdviitoot tl443/40F0000480 008000,01,3 03,1 010, 0/0,00 108 *ton±.0araatintasif geseareesoted.±gsalsdep.rtanteniho . mo/0± 0,44ratbowttrMgas ±0rnpoeld0n,Aaa roe' tail ! gas row *toils s0Bvatand nrxhtanklrarrxd to..bat pmnoold.Nebetxrraprexnts 1 IamrMtg the arrrsAntat sant 0003,41,0 3,40000 ±M2.eesmr,. sa1000830009 11±00 00040±006000 VainVISSIe130ArierDrea;lwvirret,.erma11 Alned.ai00010 a arm I:sMILd.,31, TN xtream, from wllkb the waste gas flow will to abtnneaa03±hale.,0401, isirtraiteirs 0m."M`DondonVent Gas Streams the GlycelosfmuhdamThr antral....,±00 Ur.. Data matte I aerance Dreams 11. Torismonsrte.oarrttillarsca.5.00e 010C20.8 and tnalesion Itrtits,tlar OperatorwNI ux 00/10,iestrn04 0 onamanr[tl0b.01 00000o4000nvn0lhelhxtlonthe .41.0 i?' drre00I/ten gmapntktiteapera.r WII. 0 tusk URI downdme0wu0Th'slnfarmaaen vnllbe dmdetaamhxdte era. pas thmughasisteuringilit0 daumdmeaM to ...man...40000ddspe000, 00 examistrathrrtrtireir.sionsrairsohcarrtart ham she slmdat.n*axd oni8teigas thiorashorttiADI h8m410p6ed bytMtmuna'800*Oawnd0 00 00 70,¢ IS. 830,00 rethex to the na.amissfo 5030 a contrdefnchnc800 8% d applf . Dar remaining oN asmns all' H ea. i00%/O.caI±00800 appNedas they wee record. hot. 1004Ad42000110, the a pm., rnetet tartAlettual vet 09ArOughe...e400400008 37. According. the operate, dte.atco00nti. than eras. gas streams (Derh4nk andreasisiortraetelestI I hasal304000oae0 00 W 00#001GltWerum Gyco1±040 dm heat value each eher dvn hd..g Az heatvatue4sedt0Pmmttrrg000 theerrteelert Entera.artiartratereari te ahbmtetenarter 014,001000acturately. Tara x9ma4461esasactatedwhht.oanbm0t.Proas. (Ossh 40k<a8v00edby openflare& stilluentoorartalleritiononnfterstare.rtiainedirDita Ant.00 rmltbotaer .dearly de the missions.theraxsmder..s.De deN0t irdtamthe beat content 000± sail vent and -Dash tareiviatirorsstrearnsaaillhuraltufatedarrarriontirtrisartSanciassoilalertgovida the aalealmed flow.re.rt mad.tare hootsafoaemlNnto dmain.t. Die mm4esdon.m'sslar0¢ 80 0,0000ii1AsnisiiroirttearAieai tv do You wars rearide anoresseArtairrhaoroncroikai arms.. up. Sinter asst.'s., Dana determined .0 000 should breciosseered a aosatan device rather an poetessaqu pines; The r.a /0 g e sdeds,Onrs...os: 00 .40 menear03A.he 00404400003adtyeegaadomvierernplac_meMcwmasrl.recover, epwez4ges rain dehprzaanianrtosnata Are...aa rmee.. anrvdahsrlrarw assort. hags. caste,. d notes. nedmhwenesane. detrydndenpre<em 0003 ns0/ espe rc Asa,es, N n 6 4 n a11Y:t.del0Gd t me iced" ono$,, d n.theosi 0. A edown n the VDU.. D . ten , Y ti suede Ora TNl de 20005. thmug ewcam xsi.r eee04 a04dawntm used,k aehydra4.aunh001. In otierp0190 ddlt.dOwwme afM9VaKellt0 ,0,wuldben014* Meunmen4Mbdrent. nis DItsno0100a dehydration .NydracionuI (lShe ar ks004100* 0hvblte VRU4ze ta-.MedehydtatmuntmrereausitlerpoimFl;.atemt mniidereaptacets ihevateinsceapinaluded-withNeurawlwHedemisel Ii n n watleNydrsHan tnaa '- ata tivii.04,00 M1mamn of Asa 000 Is airpwlart-ona0,0410* prods, Is be.sr.mvereq.more afar DIU is intended Merriam an... Arrtaarocarra inmamm aaamwr regulatory...snort., In rho disco. or -.ceamrlMimmd Aevaluesw.. dtesimuhdonfm,lan groat ddlyPauatercamm.a...... Darthirsr hartrDstAnia As aaesuk,ticperaniew'Y re Ae opemm m ]S.A0000.3 ssiwhom.frooum.aecai004te00Nrie monster monitoredparzatete. M amositerD3*000 n44timpii0z* romade Da svl5.zmslemizsl0neln atch4. ahe soar, ernissionstappriail0,1 the --40000 Masse reTwvnce*. /001 recel.4.0410115 for 8100±1emWlorls 15.1. Doer.. Inrilme0 the stillv.randflash Dinka...red to the sainoVrtii.As aresolethme±m7one sondttbnmtfwpamh rag Weopcasor m srarliVADrtor.Difesoihsisdue.W .VFU rteowry bath SD. phwast gad "1,800waz gas±0i he routedi0 Disi ...Ova irtaint13,7 i041pera0, pawl advise Ydrawingi0mmabon roils retards m.otemlnl inert -A.1 Me 000 As inure amaurm0tmethem(mazbnarry aretlet¢0We In Mewbown M.s...w iso t,,e vre,rer,acane -inthe Pramae0mule'estop<hwas0zed.100000 '0EGA1dinthd'ehydramr Semi ap8Pnd nsaki. deea.00Vhas determlrcd.0i,hasMaz4ewbmlm.EGAz, Oar amountaf methanol drier aooIoresu[ amedmm..sollo. loss than NCFG.PwtNg.toshda M NDItPoareMeno/negBg94me0.00,.espe<lep.' - - tat'.PravNkathe f0 00, 44 tl hseer.0Il 400 F{er,rtsioa.iltO 00 tszau00081 ter5kaPV far trT,emurtoraonlYoaurdmhgVRUdowrWme,whfNtsamteuo,y di ,0,01 ih ants 5.40 nildzlnfiwm ,t wax detverinadmet emim.pare not evenWdudtuted immmonMao mmrmand..re.remon.ivi noiappraprwte.lh. mondrryn remover frpmth A IS Pointe .1 pm±0 v^?us%s,ela%y'm'xd�","' ,ebn Sore. OS - !mermen, OCC Code and emissions rattan lincantrolled Polk.. Emissions Vector Control% lin. orA10 0.005,57 544..0 h/MMse Prel2.5 0.000200 0.0 0.314 00±0,.0 Nor 4.560,04 /1.0 0/4Mscf 000 ?3.000 ±/40,80 oo 0.35543 0.0 h/0,M.cf 4/0,1000,0 Trim.0411.0 0 b/MM.uf 2Melheve00 *00±000 0.0 4/4±00 Adana - 0/4480 nilavons l.038.00 0/MMxi .4 'DAP 0000000 ...0 h/4Msd Dehydrator RegubmrYAnalyslc Worksheet lsuar.¢ v.afHx N:...L.e�m:en zz: NrrAnYnalart 1. are uncontrolled amol from any criteria pdba nu hom this Individual solace greater than 2171. InKWatlm 3. Pan 4. swan II.0.1aR X. Are total fad. uncoandled Id ssIona _ewrthan S i.mNnaTgreater than iomv orrn etnlsslons anaterthan 1011.,lnesulannn 3, Pan e,satlenll.pal, katvefoew NOWKITAINMENT 1. Are urraTtrolled whom anymterla ml4ororani thhb2Mtlual source wean Ineaulatlon3, Part., seauwn.0.1a1? 3. AmtcalfawMmt unmorn rn the 219Y, Nat m steWnslFywm m COfd easmeta<hamaoTPy(Reealm at3, Part B,SeoSon11.0.2P la Caharada A.Nadan J, iongx wg natural ms dehydrator bated lntbbhrwam cowal area wany mane nit-malmnet are or attalnmen/mamtwnceatu(gKlncI.R.31 con...coua- mu have lfdothuu t.deattanenstatua the urn. mm Sumangh. watt natural gas red 3 dter leeat an al and gasap4a0on and produalon o4eradaa, natural p, c.,.. asnrstauen,rutunrgas dnanatlorguP�•Ing ',rant (,,C 3.m mndd vi nue-you have lndlcerlefaeolry type on the holed wmmarvsheer. 3. lathe aunt of ach.,al Lino:warded aaw dctmman, snd4Ww 6ledraor®wp dndga.toa w at a destatwnarvswra m equalwoto .11t4ea than 35 (rt4 sesmnwl.xa.13p Getothe flat question 4, Are actual un 'mike ernesrens,vommertheldmau.lrex. natural ea, aNWratorequal to or greater than s'corneaT. satkaslr.x2.a1?OeMdmorbsupwtoneeubtbn J,searmnl.x rce Requires an APFN. Go to the neat question roe Rept... a permit sectlan vu1—Oaksrm wefuxnm fromylaml natural g dehydrators MAR Analysis 1. Is the dehydratorllmtdatan oil and natural pas waaman hauythatmac, elther(tlafalonneakw: a. a t t mmea,u or store hydmarhnn nqula'I63.J6Walp1l: On eenaomnat gas Paatat.Pee. at wad,naturalgas eme$ ma naturalrataaramhslw adxarayoaoran rateentink aumadin qr.,ndoa er=163.T6h1a11311? • itythat 3. Is the tleldrator to mtdwtRauft ar r+.esit elor auto-.rmite Mr..t HMett_-art3n. 1741 eartAn-saurenkwamwMAR RR rew4mmema.yes havemated the coonode.,wthe oars'slannareslat. MAR NH Area anuQax...6 mse.on 40 CFR Part a3,.pu t raga,,. lam and a.s Pnauma n Facilities Area sown...roman. 3. tithe ddrwnter tried...cm Asm19re01 dehydration unit(53.J6012112.17 Iym IC 42442-rou have IM'wtedthe ddramartuaenn theaehyrata- InaarteryfheC lathe actual actual eve.Psnnmmdmtualgas to theghml dehydatb4 unit lea than 3.0017,17 MM., .4V1632341e411Ilne 28 Are act., slmn,leasehon tleetood2a Watbnuntmoesswe totheatmosohe than 19342 mM 163.Julalalnl? 3. lathe ant bated ',Ida ef a U11 pl. &Fact and uClaoundarvarea, as 4..76414,6.2 subpart Enmabn, mtrwstadawbaNet apply 463.773-Mmnannestandara Ora Not An. 463.444-nemrdkeealnc 4..713-nePamngstandaraa 0a Ra 4044., Mafer sown naquinmaro 1. Does the fad', have fealty.* actual annual aaoage natural gas tNcudrput lessthan 0.65 MNA.M.Y,4,3•,mey.uldeanualannwlawraea M1ytlro.rbonlpultl hna.e utlestbn a.ta24 annual average flawnts a(mtu.Pamthe ghsd dehldaua adan39aothe MMsd4eay(mas113 26, nualamualrvenAeenbbmafbwa.relmmthe nhnd d.Fydmlw unit prizesswent nthe atmospM1emiwthan 3980 IFM1639si1J small mrM Woan.ma.aa 3. nonehcaee aul.tantmmmm04 arbda.Auone23, 20ss163.m0e equnlaland IeIJ +. w.me,m.nadr,,eh,mrmdxarnmqulydtameet me6rExenblan lime,laawme.Pdlnwewaauan? ties a q.f.m.mauh3,.111. Subpart 1,..rieral 4 gn3.J& talTabl.x 443.Jn-M coca erg .63.274-Renbkeeql4 9..44a -Reporting 40 CFR ,wbpaa52 14844 wtanlw3Tmnmdlon.ndvarK• 3.8480.3 smalbh�M204.aaua annual....2 ..turalnitduwghpa km Nan 09924051 MMeapay and eval dehdratanele.4044444 awum(6312400R l or largeo.M dMmdmdon nI 41201lan3! average ',ware dmtunl ms 0544442 d3Maabnud leas tbng914m3 4.860eay(mess4*@10.11? rah waseernxamns...acnehorn the glycol aarMnOununn proms vent b theatmophere lees tbn19342 mM163.1130@Ipll? Small oaMw 3. Did nou'dv�dehWatlw 111a3.12mblpl ad All? e Forth. smallddn, ha contM d.nmmqulmdmm�tlxn.mmblon ime[standdaar. U.0Wrneapd4=hkrgwnon? ka 4..4 submit 9, Calera, pr021310u per 353.127442 n2.a 3432446-Enha aCory.2tanda. %s7sa>antml Equipment uanGNs 96.112E39aa13eg Iner.,en and e®MkeaneMmltoang 963.3.5-ResatA,R calm -ado byagm0, samba WILD 1. M1edeh4dmorsuaat ndeM4RHRorMIRIRKdAIw ,sectlangMhg91? 1. Watleharatorlmwea atransmission/storage faalkyi 3. Nora dehydrator boated at an al and gas exploration and prodummtapesdap. nxunl gas mnpr®r aleconor gas p,o *3 pare(Reg 7,0emetra4lna), 4. Wasab glycol moraleae dehydratorepatruaea beram4ayl,2pu (75375ealen4Al.0.44(7 Ifmmrumdpanm May;2013. are uncontrolled actual asmssloa from a single gllwlre4ualgas da,ydr54 9 gmnerdonst pew wgo4tp4M30F4he dehydrator*, bate. within 1,330. of a WMingrmnodaputedouuldeaasiryo arl3K1s.n4ans150A.4.61, 6. Ifconstruct. on or after Ma 1 2015 art uncontnallerlactual ernissionsfmrna single flMd natural ms dehydrator equal to orematertbn3 tw vOe lRegulaum J, sedan M.o... wax —Geneml Fuklona for AirPalMlonCanrd Equtpnam and Pre...Emhabm 5enk 6. tmtsals Ws healn algas hydatnrcontrolled M a hack.unwahemammmbunon device ...not the prima,, mnml deem that k w encored? rdv':::;N.:n swop x V I.e.L—Ahermthe ernmlaa mend eMmnnrt O(4 04r Thu dmumentaasiata ace,. of the Oben A4 Act. M inplemnt(34:44 4fl4,aMAraalrry Cmbd Commission regulabpns. Thu doom.11a nof a rule or regulation, and Moanaystr hcm3lna may not apply b a paricular3Aualon based upon the btlrridual facts wont Thu 551443 'Cam w change orsulsb'tub lraMlau', rep/Mb, oram'prher leg* dMirgrqui 4414, M....4 44 042440m/wcahb. In ✓re ,any umnlFc'1 between the language,. document enNe urguge,fhe Llmn Ainµ, iW 9npAsnnbgreguntom, and Ai..4 Lob, �mis.°regu.lb, bnguage',Mesnt73 or regublbn will con. The eofrw aandelory bnguege such as'recammend—m411"'anoud.• and•caq' sbu...adl0 describe A£CO of and remmmndsliuv nCtoryla01004gyau-0,as427/3 ard're474 *0 are 5144/4 rode,mbe mnbdlrrp ',.:rem. .4w., isms of the Clean AfrAct and Air gnlAy ConbulComMssian mgt...., but Ibis Cxumenl does not establsh.0,N...V.V ... estIon The d lb;u.,Innu txebenzene vermatbn -law havemMoaNlndloud 'Ns in the MAT smlm continue -You hampMws3 Intllntedt84In the b9lnn4e of tb MAR. Onntinue-You have pmMauN IdlevR d thg in the K J, setkm nI detem1704nnlen Source Is sublet Natural Gas Heater Emissions Inventory Section 01- Administrative Information 'Fac€lity AIRs ID: Section 02 -Equipment Description Details Heater Information Fuel Type Number of Heaters Purpose Make: Model: Serial Number Design Heat Input Rate: Equipped with Low -NOR burners: Equipped with Add -On Control Equipment: County Natural Gas Plant Point One (1) natural gas hoatef(s) (Make: Heater Model: HC1-1B010-90-O-G, Sasial Number: 8117-080) each with a design heat input rata of 40.8 fi7M9tu/hr. Each unit is equipped with low-NOx hurter. Each unit is a hot oil heater. Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency 53: Section 03 - Processing Rate Information for Emissions Estimates Limited Heat Input Rate = Heat content of waste gas= Actual Hours of Operation = Requested Hours of Operation = Requested heat Input rate = Actual Fuel Consumption = No add-on control equipment ow Nog combustion system is considered an integral control device. 2.0 MMBtu/hr Btu/scf rs/year hrs/year 280,320.011 MMBTU per year 0.00 MMscf/year Requested Fuel Consumption = 266.97 MMscf/year Requested Monthly Throughput= 23 MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04- Emissions Factors & Methodologies PM Emission Factor Buffer: Emission Factor. Pollutant PM10 PM2.5 Natural Gas Heaters Uncontrolled Uncontrolled Ib/MMBtu lb/MMscf (Fuel Heat (Fuel Combusted) Consumption) 7.8239254 SO 6,000588235 0.517 NOx 0:049019608 51,470518 ...4:082352941....: 56,470 VOC ::0.005392157 5.6(17 Fodmaldeh de 35294E 05 0.11122 Benzene Toluene n -Hexane 2.05882E-0fi- 0 02363.765 335 06' 0.00 Section 05 - Emissions Inventory 266.97 MMscf/year Emission Factor Source 1001764706...; 1,852941176 70&L Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM25 SOx NOx CO VOC 1.04 0,00 0.00 1.04 1.04 177 1.04 0.00 0.00 1.04 1.04 177 0.98 0.00 0.00 0.08 0,08 14 6.87 0.00 0.00 6.87 6.07 1166 11.54 0.00 0.00 11.54 11.54 1961 0.76 0.00 0.00 0.76 0.76 120 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Formaldehyde 20.61 0.00 0.00 00.61 20.61 Benzene 0,58 0.00 0.00 0.08 0.03 Toluene 0.93 0.00 0.00 0.03 0.93 n -Hexane 494.68 0,00 0.00 .594.08 494,68 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a perms€ Regulation 1, Section VI Based on the requested emissions and emission factor, comp€lance is presumed. Regulation 1, Section III & Regulation 6, -Part B, Section II Based on the design beat input rate, the source Is subject to Regulation 'Section IIIM.1.6. and Regulation 6, Part 8, Section lt.C.2. and 3. Based on the requested omission fac',nr, compliance is presumed. Regulation 6, Part A, Subpart Db, SO2 Standards Source is not subject to NSPS Ob. Regulation 6, Part A, Subpart Db, NOx Standards Source is n,o{ sulzject to NSP5 Db. Regulation 6, Part A, Subpart tic Source is subject to ,4SPS Dc. Regulation 7, Section %VI.D Source Is not subject to Regulation 7, Section 1011.0. Regulation 8, Part E, MACT Subpart DDDDD Source it nut subject to M.ACT ODDD0. 34 of 61 K:\PA\09\09WE1136.CPS Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Is the project close to the 40 tpy modeling/ NANSR threshold for NOx? If yes, stack -testing should be requred for NOx, as well as for Co. Is the operator limiting their heat input rate below the design rate? dyes, stack -testing should be required for NOx, as well as for CO. Is the project close to the 5 spy modeling threshold for PM 2.5? dyes, stack -testing should be required for PM 2.5 Does the company use AP -42 emission factors (or more conservative factors(? If no and testing hasn't already been required due to proximity to modeling thresholds, testing should be required for any pollutants for which alternative emission factors have been used. If testing is being done for only NOx or only CO, the other should be included as well. Section 08 - Technical Analysis Notes 1. Based on a review of records and CACTIS the required for this heater was completed on 01/15/2015. However, the inspector that observed the stack test requested that the Source be rede ' installation Of nevi alr-fuel•ratio controller onthe unitaft"eethe'st'ac0testing was completed.'As a' result, the•I itial test Ing quire mentWill remain in this -Issuance oft₹he permit: itshouldba!furtber notedthet,thisheater-has maximum heat input of 40.8 MMBtu/hr. With thistnodiffeation, the operator is limiting the heat input rate to 32 MMBtu/hr-T hisfurther supports the need tq have this and tested again. 2. With the original application, the -operator requested to utiliuemanufacturer provided emission factors to calculate PM emissions. A result, the stack test in the permit included testingof PM. During review of the •application, the'operator requestedto utilize AP 42 emission factors rather than manufacturer data to estimate PM emissions. With this change it was determined that testing for. PM would no longer be:required. It should be - noted that the total change in PM emissions is rose. to the modeling threshold (5 tpy for PM 2.5). However, this.was the case with. the previous issuance of thepermit as well and PM testing for this unit was not included: This decision was made because natural gas is used as fuel4nd'.thug'PIv1 is less of a concern in -the corrtbUstion process, Withthe cU iron information, the.4P-42 emission factor is -almost double the urnissIon factorprovlded by the ma nufacturer- As a result, the use ofthe AP 42 eci orenfader is€ikelya very conservative estimate of PM emissions. The useof the manufacturer emission factor would result in a change imemisions less than 4tpy. iftt?e heater is operated andmaintaiueA according to"mahuf slurerrequirements,ft is likely that PM emissions are closer to. the ma nufacturer ratethan the rate presented using. -AP -42 data; Ultimately, this datasupportsthe removal of PM testing from. the stack test in the permit. • - - >'° 0 3. In the previous applicatron, the operator'sfailureto property convert the AP -42 emission factors to a heat content of 1,050 Ptujscf was accepted due to the minimal difference in em ssions: During review of this appheadon, it was determined this error in the calculation was not ptable movingfdrward, As a resulg the AP -42 emission factors were properly scaled by -multiplying the emission factpt5 by the ratio of the operator • - -- provided heat content (1,050 Btu/scf) to the heat content basis of the:emission factors (1,020 Btu/scf). Thecalculation used to convert the emission factors is as follows: Corrected EF (Btu/scf)= (AP -42 OF, Ib/MMscfl'(1050 atu/ref)/(1,020 Btu/ref). 4. Based on information provided in the previous application, this heater is used to provide heat for the condensate stabilizer and demetbanizer trim reboiling. 5- This heater is equipped with a low NOx combustion sysf`em Asa result, the operator utilized the Nt7Ym eission factor from AP d2Table 14-1 that is based on small boilers (<100' MMBto) equipped with low NOx burners... 6 N -Hexane is the only HAPfor which an emission factor will beincluded ii the permitsince itis.theonlytiAP that is above reporting thresholds -(250 le/year).- - 7. In the previous application,The operator confirmedithatAo.P MMBtu/hiris themaxrnrum heat input rating forthls'heater. As stated above, the op rateris limiting the. heat input rate to 32 MMBtu/hr with this application. 8. The notice of start-up (NOSj was provided forthis source and point 13200 August 16.2018. This NOS'tncluded make', model avid relish number information -The self certification requirements regarding the NOS and make/model/5N information will be removedfrom the permit for tins source and point 132. 9.The previous issuance of this permit iri<orrectiyindicated this source was subject to Regulation 7 Section XVl. While -this fanhtyu anexisting major source of NOx, this heater was nottgcated at the facility riot lune 3, 2016. As a result, It is not subject iotheconthostivb toceaaadjis tment regdirertientsof legulatloo79eaton Xvt. The perdat Wa&updated based on this corrected regulatory determination- AIRS Point # 133 Process # SCC Code 01 3-10-004-04: Sidon₹riol Process; CA & Gas Production; Process Heaters: Natorei Gas (Mfdiscej Section as - Inventory SCC Cothene and Emissions Factors Uncontrolled Emissions Pollutant Factor Control % Units PM10 7.82 0 Ib/MMscf Burned PM2.5 7.82 0 Ib/MMscf Burned SOx 0.52 0 Ih/MMscf Bumed NOx 51.47 0 Ib/MMscf Burned CO 06.47 0 Ib/MMscf Bumed VOC 5.66 lb/MMscf Burned Formaldehyde 7.72£-02 O Ib/MMscf Bumed Benzene 2.160-03 0 Ib/MMscf Burned Toluene .3.50E.O3 0 Ib/MMscf Bumed n -Hexane __ 0 Ih/MMscf Burned 35 of 61 K:\PA\09\09WE1136.CP5 Natural Gas Heater Regulatory Analysis Worksheet 6,,,,,ipmeo.snvt 1a.aio 2.-2,2an4.t. ega,VerMe and :Eu,v..kM1nxrwn.vuaa.ama:ahlnS.. h.2D..a.ve:r.p a5s:g.wdsotwr „n ewlsae,af-aaln. Pew.. 2x:62 Colorado Population 3 Parte ',end a-M.2Nani Parma neaukeme,m 1.s& ..nls._d54_ea4,221mena cone 1. Are uncontrolled actual ern.lons &any .Pea pollutants Tpy Virgule. 3,P 44 setknn,0.lal? Dom the heater have xtIgn heat input malm than oregealm5M mu(rn ARyuletlen part A, seelea 110.111 3. pees the Ilene, have ae.ignho5Znpn ratelen ehanme55I42 to MMet4TNIRqulauon3,pane,s,.Hon11n2n1 a. Art total faclifty uncontrolled ssws greatertban5 spy x01 greater Men ao-MYor. call* greater then to my l2ceulatim 3, part e,5eebnh.03R tta M dw.maLL5n 1. Are controlled emlssbne 4(79 crAene pAManta from Cuss in7Malulaouren pater Olen lire (aegulatlan3, parch sedan ll.o.vali meheeterhave adult, heart,. meleeawnweguslta5 MM4nry.E (4eguark53, Part A. .W0.0.0114 3. Dots the Meter tea deign hex Inwe rattle's I n2. s or,guel m t5 64407(6,0 IRsguldlon 3. pa n e, sww II.D.1.e1 4, Amtal !scatty urcontrdld weemisslons pnter.nl VV. 2102 g,otatNns my ormembalamneater than 1022, Ifiesuletion 3, part e,s.mon 11.021E Co(arnia 5.02521541. Seaton VI Aleewa Sea. vl It am,ern a4ertion2tons 7er�., Regulsw.•seS54. x manu4a4ani1 R �eg4epa4ire, onaRealm Wanda Repletion 1,Sealen III end raloreda..dodo., s, Pert A,Seeuon u, Ranier& dm ver ...m5ter NeReav, lare 4eulpn. 1. VAr the heeler"? Rag ad21e1one, Part 1 Con u mMat e.,ge particulate d te meter In mo0.5 m6Mmbtu heap byps(saubtleeel,535310021.4.1.1.2.2nd Rawanms,pana,srebn 11.2.11 3. Does thesourtedischeetepertkulatemeter ergo. dthefdtrx,y eq.milom22.05121P'? illeguletion1.Seoknrk,• and 2eguame 6, 22 a,smlen ILO -)ILO -)a. Does2 mrnenhtu hot input? (Regulation 1, Section 1 4.1, l,t0s,.luleItnenbrn:zw.re, xhs sow. 22.22.24a neyda:m:e_2.1.::mJ..1., and lteNa,can s, eaea3, nvq:ane a:rl3.22..22rnaewanxaamix:k.:n:ae 021.erotual gas Bred heater wet et a major sourcen020a as es oflune3, 1016E pegulebn2Sectl±17±50.1.1 2. Don the of NM eau., to orpreeterthan s toy?(Reedatb1 'section xu.o.s.a natural .x111.2 9,oreaMm<met Section x40 Per...re NSPS Ana Ives 1. Does guhrdM.terhaveama5lmvnaulgn neat Input nparit222229 mtgawam(M.55,V(MMMu7Aw less, 1? platter than or equal l5 Mw(10MMeb/m12149.40clall z. 0� neural as had heater have a maximum des. Martoms cepaoNIFe erNnnas maavels 02'24 MMmuA,AE I49,.ea11 45644 Pen as 5uhprnoe,vawN.of Performance Per Smallldeed.I.,commerel4a,aromonel sum Ger .mall. 1. LW construction, bat oflneneam eenemene uo4 commence aRelwe% 1533? 1460.4cra11 l5or o2222 tx sullp40A 4aural 14.0ms 445442-Reporting and R®NlmeobeRwuu mmta 42.2212. Pert eaxddertc6,studerd. of Per/mammal for uduariewmmwnaeuwrtunoneiSteam w,.radreunas 1. LW constnaelon. dge Pan,or,eambud5n ofI.teem seneringum commence aftermme19, 1924E I4c0.4012(4 so2 standards 2. M%Aw6aler Nyea Memel 502 miss. n2 eel (0±5744 2014 hot Input 0155x?146.0.4ab1k)all 3. ouuthe4Hendr.4M4<mmece m,um4im,,eavestun1on or mmmrauon alter sauane 22,2555E(460.436N41111 140 Ia.5<nm.a<t t..plvv Pea.. HOaStarderds 4. Oe. the natural pea. -inn o4lydM 2a wpSO MMgnAnlarl55u (49446 .1411 5. po.. the heater aegllw mm llauing dal l460.44b(k)l 52. Combust, alwearin embw<w,.a4v mrval as, doeltueal, or,uNual ell* It raoaen mmend03 won oven agm149.444A1i1k 512 Have; coml.. 1opadMl5ctard10 paten orIns for nvtleaI545, distillate o4, and lMewl,AWtnamlm5enrantenlof030M,µ4 percent alas 1445.4.111211; and Are subject bz�fn45el2.r.uyagase4erwrnenanummngwer+tfon of theaimmfwuwmahendngdptuul w. andleaxl,adb,u4,aldwbna m�emmema0.3o weight percent glee 2.2mning operation5.065. dtie erected fadleytoa em4ndanm5l opacity fader dm percent or 'make natural gasp awllate ol, and residual Mlwrtha nnm2co 5c. content dwd5M peseet0157, 5 §40.ub111411 6. 5d eheaffectd nslurymn ernradlmMnanelulyw, s°n(45a.44W01 uralps4,dM.ter',Aleusa.d m mmpoanavxnefdaalNddo,vabeeegubemertehd llmdape+atbnd<Mfadllrytoan ena,alowdrvfaaore,10 lerceo2(a151erlesh co4og, and natural gas(orany combination dine th,m)21460.442,21(111 5mdemtval ga.red better Nye low heatmleasameaM combust neural gasoraaelleleon ore&M3a peon* of the nut Input m a 30Gy rlpng awaa.fnm ahem.* of al e. 5,57x(465. "ow cE..requeluon. Iso.aaa 1,2 4ocs.2 2, cte 945.52074441.sm 4erafer.uuvmoaa. IRaal 445.544515,(6 .,117 1,4 .d IA 04 ill-Ra,dW b, 45455.5 odan (x5.1 §9As6.mmdl.n..d pa. mono tart md5aaani pmodu,55 leraweu.dlovra. g4aA46campli.ne and verfoemance but metlx.elland Amman.. or pwkdd5 miner end ndmeen ',Wan 445,x16-4mhdn enema., for sale doe4e 4.46,&MaI men..for partkuler. motor and nitrogen oxides 49.5Cb Reporting end ramr4ndre ea.errx. MAR Analysts 1. Is the horn looted al a fadl(ythat a a majoraaun. furH.'s? 1443.1.451 2. D4tonstructIon 15s3a41(bller,emmuetbn156a14s7kll ofbederoemmence after lune 4, 20102 he Mot Inpnowob1ess<Nn52e22,5.3,265,5/2,2 (463.7soole)) 4. Is the hue mp,n eMdM e.meterthan 5 mmetu/hrlaut less than or cowl to 40 MMetume 1443.1s5n1e2 4,2325,201.1.d - Pr2CLIre svnm4s §53.1552 NI -g 53.44141.135val�Wrn,em fcr55Mlnitsw,m 5892310 lel Ice new sown 5 4.3.194 W-Sabewwetesn, fuelercMn co -cum -We 2..795 ,e,•nd oemerew6bkal compliance50.2.7s451.1110150.2.7s451.111016 o1 and 41(151- 0emem<mmg 6minpov compliance 49,1s.1a41b-br.ddre or e- for rowL 41.1.1111, 40. Oh OM- Nwrotla s §9292 lah l•Ilil rani a15ni 924x514, Ibl and Ie1 -RemdN.plre This ec0051±assists opeatas Nina deleMning applicabdlTya4ae-bm s54164menls of (he 0650 Ns AO its irple enfkg reg.Hfiwu, and Air cual?y Conbd Comml5bn14gualbm. This document is not 7450regula1bn, end 1110 analysis cmlabs may not app* kapvlk4401sawn. based upon Oled4Mdwl4ch and ms. This. document does notthane or subs..la- any law, r.guatba crany4Me-k (914177642agu1amnt and ksd1545441krcwba(.502 Brent deny=WV between Rre argw..Inis ...ant and the 67pvege of the Clean AN Act. A5inpMantagrpu6ta9 and. . . contra' the Is Mlede4b crl6e(47440wungaesyha slladl.orregu.., an.14joueesm54±andel arp�gedwh ax54,64454 4Tray,540764(7M 4a5' uWry0alcm bobgysucll 084(7±5 era Nleededb ransnsbe mn4'olb'tg- resWernes the lelmr dlM Clean AFAct and A: pslM Control Co, sion9gualims,WI. document does notes... MpMbinorwoSMu.mants ,elas2 toed., FogE vo Emissions Inventory Section 01-Atninstrat !facltyuulo: swim 01-Equipmentcewnpelm Dealt DebIlled DeerHptlEmissnm unit ;is tir .mho[ renmmr i t 1{axp or si pi o ....1m. d , ;iuPMi[d,M«kavm41mmw4ti�pn ...., 6mIsslon Central oevir rbpirer6li- W ved'ierilnliiim£ nYoFiLueriti5«Iwk Desermtlen kjMireit progCuh4g•kl`n ire wtelirtomutlonfor Emlumn+Ett10a1.r ;Ore;aekla Emission Facier Soma Calculations zmon:u:b' - Service Gas r-0mPare pp. Ica nt I En' nmrlEynr. 7 Flanges Coen -Ended Uned _ssnr 4-50,63 Rebel Yaks 680E-03 m ell%1 200%04 1.036-05 51.0% 390E. 5.70E-05 81. 1-50E-65 no% 2-50E-65 90.096 Hem, Oil Open -Enure Linea mp Seale Reel Valves OeeF,2.10E-64 0.70E-00 01.096 .o0Rang. £1.16E -04m Open-EEnded tines 40E-03 1.408.05 Sealeabet 790E-03 110E. 75.096 60 5bn Relletvanes 7.50E. 110E-04 7.50,06 7.50E -bb 3.50E-0,7 390E-07 0.096 1.406-04 7.205-05 0.096 0.0% V. Sengene Etbylbanzene Bentane Toluene mryleenze Flanges Dpen£mee Linea buillp Seale Yates Oltsr Rellel Va. 110E-04 1.60E-05 60% 260E. 290E. 6096 2.40%05 20E-06 0.096 1405.02 590E -05 0.0% VCC Beraene Toluene EtlRlmnze Mass Fiaction Source 32.73320571 0.052313539 0.088612054 3.177851395 6140586061 Contoged Emleelens 110‘,1 52 0,112997111 O. DOISSIES, 0.004815516 6114100474 0.000401.0 0.1818.58 6.1150751 0.1.107082 6,1973483 65617136. 9.500241897 0.0.7.137141 0.831815207 6010490.3 6.163016037 0..1273713 Dlealan pwmr6.ue72 Inwemory e aura RoOn l`st Patient VOC Benzene Toluene EtlMbenueea XNerea n-Hextre Unmet.. Emlulans 10310 090 51 pa; ibtr liNer 141 11 .32228 Ititr 13574 87 Rho Cantab. Et 70 S7 ihkr ItIgr 13.-31 aeons iblvr Stagda IV Eg,-453,R-c5-017Table 3.4 Standard Et, - EPP,53.95-017 Tab. nmp EPs-EPAs9-35.017Tel. 2< Standard EPa-FRA458ea-ssel77able 2< Section 05'xe®nwvsom""TReNawi40 CFR, VIda, subpart 0000 ty m, applicable, enter eu la ppiabbx Reg, atReaulamn3,Paee seemnlaoxmmmmblelaPACT Isrequlnai . ff 60.5380 an deteane Is determine kapp. ble m MN ee0rte7 60053 6.010 60102 60307 1.4316 aosze 100 0.1328 0.5308 ames 0.1091 3.0007 0.2233 0,4497518 0.0352834 0.63970041 0.0501847 607070035 0.0.5455 0.11111995 0.0165613 3.75763301 0,70780. 643141006 0.0339225 fugitive Emissions Inventory Rsguhlon, waCAI _ Except as pmauea n magaps Leven a below, no owner oropeatorofa scree shall ry ham of. aipot 01,h lain a.m.Dxs6�TMtym opr .n w�7n,7 w e.la m.�. 0,)," esfacrm0,Pa020 Appendix, (duly, 1442)) In aalll sub tlam 0(0,00n flee n and B oft. regulation. 0"....... edlon LA - No. pemon, wherever located, shall cause or alive me emlwhn m odorous all...mi.. from any single source such este result table odors whlch are in mess VI. bmCK Forma. titled inan�mrrelsldntlxll or commercial purposesItisa0ota it odors aro dery ted after fie*sous alrhas been ew.seven Moe mare wlomes V odor hex all. Repuabn3 Cp.& potbsarric parer.. pollaanc,Air pollutant. Embsbn paces ana rect.. for:each...at lermmwllad aiss with mem0r eci actual em.sions of one. per Ivar mm. ray APPIlevd Is required befits 4nAPI. elms emissions exceed, ton p90092+9)90 Pan El —Exemptions Applicant rrequlnd toeowalne permit ranee ensono-aled vOC emissions hem this facility are grader than the CO TIT' threshold (Reg. 3, PartB. sedan ILu.va) non-atialnment area or attainment Yes Ifyas lefts source saga.. e k detection and spa r(LDNR) requirements maintenance nnts per Repletion i, section %v or% Pal40 CFA Part°g Subpar. KKK C0.0 era:000 Yee Part 9.150. -PACs requirements for mw a mWlned minor sources obble of Interest for debannMing Itts sasree Is new or moolmed is therefore November RO, 2007 phe date...shoo mom PA area rdes lvrulbn) sin tit. luglavec vnll be In senile. mar,lm ...eve, this source. considered 'new or moat., ittle Ng. e SMUTS Is900990)22 P900000 F0budOg,b leak detection ma rear program per PSPS 0000a sMismes the CACI. mouirementa of Regulation. The prod.., contain a condition (enabling tbdscletermirrNort le Ws so ace at an onsnom-mwal sae pm22®ng pant. as defined,140 cfRPad 60.6310 3tsconstruction, mmnabucuon or modfiabn afterJanuary 20, teen and on or Tits source Isnot sogedta N535 Mb beaus the new equlpmentcovered eythle fugitive Source Will coml.. constsvotion alter Aug.. 0, 30,, DM thls souse commences eorsaudbn mmrmotiMn or madMCaaan alb(A2gurtx Mend on or Wore 9epemberle x15] Cornea Isnot subject. IMPS 0m_a beause the new equipment covered by Ws fupdve satires will commence Cmdrmlen after September. l4 x15. aill,illidlo, Is this source leo.an ozone noitallatnraentareatons ma Cana%Ace y, 0p8 '.: Fedl.te eeeeemed u s meg�� natural pea pnce.eaq part merelo0 non source Iswgxt to Regulation', Is .1n<Ig2a fealty or Since this x110110anoteclxamed az awell1,840 o0 facility m natural gas compressor clatlern 9 I not subject to Regulodon>9edlon XVI,.. m ems source at a Varural gas ProcessIng OM, as defined in 400FR Parts',610 la tills Celery consIdered a 'major soUrca.of HAP as specfray defined In 4o CFR Partba',0l Cr altos Out ye_pg, production field fealties, leek9tarevme y ppb.,L.......,,NMer...,,,N.,,...nam 40 CFly Part 65.tbe 'Equipment 902122 Is not subject to 2.CTHH 2amue.the facllllyis C.O.. a synthetic mhdsource of H0P0 P.VP90.v4 Did am or ficaVonabler Cap.., 0. 20151 *202 source commence um2081 onorrdomhor. rmdlmlgaap10020agpartas bend 040 CFR Part 50.54.'mav•s ..... nIs facility meets the degnmonofember."mwral°. pxeul.9 Plan, as dahned qm CFR, Pan BO 5aua Therefore ths!online emissions Mtn. Neb. are S. feel m Nsps 0000a Notes rbection 07 -Technical ;„,,.,,,,,,,,,,,,,„----------r Wes. gh,hgvfdse�n ( <I -.wanes'. LIBa°.1) mnnecm n",' sand qr 00 Ia1.6f baled 0)0 l bl d rh N I k m 1 1 N, 1 rH rt t I 1. W 14 Asaasa) Wii00) eoumdto0 (t M a:mvmrmo17 1 kae,1„ nmongandreb rrememfor2. 1 Pad Ign0gadsr.ram1) 0041 ps 1ln Oght 110100 sarv'ce)..u.er ivy amso1larad100, im).70000200000 sung ma so- 1WRgl re raabpumd arthis hd.Itaw nattMse ...,.n,c,wa0010) a ..m. - Mesavaluebare .bed on Nasarcepe gecb4w 40000y nonlmdngnn 6emen0 ' meeperam13pmreg020 2010bpow en,yraa)Ropee~v,dadlna-nxa II100a]5 i 0r0e remand pan xi1��eme^..m rawasuitytlmsemnpd mrcenp6ewlues were aec„edxrepank 10122 naku,edngfupti-eemhvons „comNzsmnaolercew0cuareappmadf use 1 nc!mlrnese b 1010400 ty/ 0020....., ,av tom and tulardmf&aoejm u<de 00 1 p00eprrm11:70Iron''',,f77.,,,,,,.:,,,,7,,,,.r 3 Pa r) gou21 7 a ss overt a 0000hml 00 111 sineW S0.l aebsfadxryds19) gasrmN5ps.Qopoa <rcgmrgmennm pen aaa:�w�Nr� a oarormaR ref .vial. danbra da0.wen sg npP rme wdr�r2�I a nblmvl=�� g 9nRp-rrvs:Fs b pan4s.,w m naahpp cemmlp"rc P08 em l90cenamedu a anal)00010omp120000NR0/SamPrmg, hem} 55 biC002 p euam P rage W g rhery.,,,,,yaapen<aded aedJ MPmgr.,.„-[- .7,,7,aawr Pawand pessosh,naeatagvy)rtm N-apmdonWNercgWrem use hbvd r a '''''.,man dmeegWrme,u8vit.T[EQ'18MIDtapo en ua4itlusmsdna er'a[egory 9asMon,M®scimradtlauwNlnINmearmacr grWJ54rdu2fbappl 420eam sbmfrend,"s:LaufpBmLype.Haa10200eoperam02400{m 00012)rgarpla40004 nga95%wnpolferrenn• eN 00800 bmedauero 40 umn ec �ayeblexd 0neoledioraxr 8Cr0a+m110104tenay Flo b. domrwudaup40/ a 20Pld10hcsan erebub,o,rmrePS 2/P9Pses0e05PL eonno.,°0-.--------,,-;--- :,.,L,,,,,,:,„7,e tlreumo6a55%and B6%rb00100 0404appopdsp e0essurs010)1401161rt11peudavtl aeH Tha,,, welglrr.4.uel024 used to tlma,eerrmaam from bellmdiromarepres ace fe[021 Ipl ,4,0. h ago ..,,,,,,.‘„,14,0.t,, ,,,vdraa,,,,,. ape loos ceeblfeperm,btheapsaWr p 1 ro torslni u mmltae Par, bhptNfe } A mp0 {? M Z I XI h W 61, R ess c t M v. C0 04C ¢Nov wruesee dr..ay01 0cs pk nos vsla afro,. eveure,w<rene e u o .tor m, .,, purposes Me6dind 6rtalaulerorcused Wdprtrmipe0e� gh x22, ohw..rtyiKodNe1 10010 ',000001 mnteahnaAw 1/aronlhyo value alepg MP, the vOC OP co.cono4000neneanerm.:esw, 2.n1124(151 x02 ?'Sd,eeorzuced wcwe16,,,, �wsdemmNm asmlovds Svlxltarecte4 ss](34 SPIx-1 wars. d.. for N ebb, va S. r100.0 wvapnxw14aueedrortram the 000gwe eeretc0010(0 4 20 01. Hebb vwn m Allb.Ix, mug w..PrshI,lb es rcwwa,ed,eefory aseae e,.....ras,mAbngOmpba. Pc cam* of 11, calcdabon wed .m then M azAmCAA 0.042120080010+ ntenr of, le. awani40.404444,0 assume 100441,1404arloartalsee0 alcu4lmnm000110 nom 4) �i04 0024x6•s,.m ,-txlar.K4ed1=1.rzS0rzao3,00- dm�wasn6om d d rn ioA:tie a r 2,�aaes00,, sf-avns peneooe,ned.Eot 4n e ,yu,ad ln,na,,r nasNlit. npprimc q e cq r , p of w. auuo enOo ro 2 g,. gabovaae,. awrceBe2gaam NS0-5°WaaHe.4w a n. e,.al beaddressed nb0nom .f dm 444, ed-aww,010 operator has chosen to apply Me cannot percentages non,,HCC nsiwe sPSWaatamwsamnncm,m,aar0Jwgad0s 010404 040040used 4040404004w «dos{close anipenIng tongaeea completely around nbidebedtenneotbil)w4)purp0seof MON tofaonbao25bas doeaedegoltivn 122101<a,cotingemluiON(PPM both emno.154=.m.. 10 h0 dbe 004041114a1C0lare00 AMC 010010.475ecd N'11,0,L reppIre0 010 101104400 tor NOM 0000 2g)0vt W1001e erg 02nd 0.41 a nea2hgKpu10 e meeaktla«Cdo n PSI, PAM tla ed a01 .411 /0( a xlgIapplled,retidml .acemb� a1111101011ma amIw2 :Parc t60, ,,uc0..aueyffZ.,ma uSm s}nakgm ,,. aminmen:amp y,a0d0regLleaen NSPSo000 :omponeng. As Polnaaresugeaelaps000a Fugitive Emissions Inventory Uncontrolled Pollusent EnntsOrts Factor Cont.. Vary by voecomponentWe ....MN. V.I../ Herne. Component type rontonontyne Weskit, Va,kaby Toluene COmeOnenttype component tote ark by arap Ethylbenrene component type rorrylOrtent Yr. Vannby Variant Wenn component type cannon.. Me Vanes by anesby nnenne component type connonenttype Verbs 124 TMP conform.. Component Ono smntarn Era ffnn53m9se1,Taba2-n Standard Era EPA -653/.5o1, Table 2d Standard Ens -EPAnto/P-95-017 Table2-4 SsMaN ffs-EPA-453/T-9S01,Tabk2-4 sonean FR EPA-OP/R.95-017 Table 2-4 Standard ffa-EPA-a53/A95-01,TSWe 2-a Standard Ens EPA -53/A95.01, Table 2-4 Add Gas Flare Emissions Inventory sedbn 03-Aamlestehe bdenednn iiSEESAIPAAGAgilAAvali County rna arc ISLa'Kiii,.. Mulled Emissions Unit DescrIptlon: Emission Control Device Desorption: Requested Overall VOCB HAP Control EMdency sesebOOa. Pm..,sbe wu lnm.msnan ter EmW 10400 um000 gas: Actual volume or gas: of Bas: Requested hear content of gas Volume doss: Heat Content of gas: Requested me of gar. Ansel wiuneof gas: PTE volume of gas: Peyvested heat content Volume of gas Heat Content of 5990: Requested volume of Bas: Actual volume of gas: PTE volume of gas: Requested heat content of gas: roelThroug5pue Total Requested Thraughtp, (Permit 0090) Amlal throughput friNrscflyear PTE Throughput 37.01143509 90.5sof/year ah:r1,5Gb'wm" ""'. .`EumEaawn LM0000000 101 w rn Jon NhrIhr Haam .0 211]044 10.59 N2 11]Ea]GO 9 03 melh0e0 113.13 090992A3 495.50 et rine 01 tMP 1552!]0] no 3022.0 6?f 7.62 00 Tone Wlane 9.05 oroloo0 90 .. O. $610.09 31 Iro]30E05 BSS 4709.01 3.]9 sl tens 000E 00 Erne 30 • 0.39 216:5300 fAe ohevne 0.000E 0 op 0 00 Other 0ones 0.0001500 0.00 0.00 0.00 hegen0s 0 0000000 meth clonesene n4cE+a90.00 004 0.00 214.790 sm e Toluene m0Ew0 OM 0.30 o.00 IW0:enn !1000: CS He es 0000:0 OM 0.00 0.00 we mass fnehan. 007445 Total V0037noontroliml 00.90 Oro 5004.1 MMsd/day 1450:^^. muted 175009 Mond/Soo Me01heer 1,0000 w hear 30440000 MMnuhaa Mssf/day 1042Btu/acf {954 MMacf/year 9Madheer 29.53 MMrthser 0,994.0':414 MMetuheer _5403 = ISIVerfhear lm Total Avenge Hest Content 24]5010)59 Tore, 095. Based an only upending es e back up control devise for 205 day9 per year Ib'Ibmol ININseficl Gas processed Insane unft while emlsalons are 0.53 device, ed mean. Cmtd Effislenry Control device operation: 5tlll Vent Gas Heating Value: ToVIM, Vent.. Gas Vent Ram: Still Vent Gas Ram Willie smi ...5 muted to sere: Buffer: 3251. VENT Pollutant 09.04 Mwdhear o a5 x VOC mo-aled ,501 30.3009: Sa• Toluene ethyleenxne Xylenes 224.TMP .00032000S t; Methanol Methyl Merc300599¢551 66204' .164611 Uncontrolled OWheatl ealeaseaa evrerreser 353.2520,033 1413.96 35 91.9994,215 39.9939392 oasis 400!61 K:\PA\m\09w41136.KP5 Acid Gas Flare Emissions Inventory Methanol ]441" Section o4-EmIssions feRir a MetMaoloaies Polkas,. voF. e s Uncontrolled EFnllm�tS Man as Emissions Emissions Fapruc .rSource tion a aw.s 1 1� Co N. .mitmes Pollute.rz lled W"W r�nw'P- svelte heat teal E.F.11mdxtntan masts, Pes yawn. u:atu Emissions Factor Source Macon AV Lr 5So StterSkra4�E i aci%F/,f≥bia NO so ,,,Ns, '' e64Sa ilk Polkas. W"E.F. (Id/[susso wave Feat ud)combust.] E.F.IId/mx volume eml.alun+waursou,c.<wnon PPM &Wusm:ikb {tkNKAI MOS f8 SOP IMEMEMINIZI Emission Fodor... Polwe:n IIMEMEMEEMEM .P;r;.1rl, :t al I6m ThmuAPur) (6= mmucxP voc .b ...:..... ........ MirES=® -__MIE2= ®® n -[sell. it<.uz zv",›VF..S,s, Emislon Factors Plant Here Uncontrolled IIII/Iaxtscry Mas5500 a bas muaxPutl volba 1A/este s nm,ah.00 Emission rector Source Toluene SCPP MPS felsrthyl Nlercapten(xmslll Pollutant OVO 09.1 Pie. Clam Uncontrolled Uncontrolled (Ixa0Matn) (mRaxl+dl ComhustetV ld) Emission Factor Som. swoo NO ',Amon...;; A3adf Criteria Pollutants Phtla NOv Potential d Emit nmaodld ions/wan >iiF--:i Requested Permit Lim,. Uncontrolled Done/ .mil 6�on:nosy ax"11415 Actual mrslw Vr cofnon Imnsheed m)I 0.WtI_n wORRF:k. s.ou-/a 15.0,03 0.011.71 5.10,02 061,04 n Evil, Criteria Pollutants PPAPO MPS NOx WIC SOP Potential to Ern, :Doodled itOnS/Peal 0.00.0 m (tuns( Unmatched Controlled (ns-shear) (tona/warl Actual Emislwls Uncontrolled Controlled Ions/wall V00/Peat) OOP DOA 044 0,4 0 IS Criteria Paluent, PIPPO N. VOC SOP Potential to Emit Wyurl ln Requested Permit Walls Controlled Uncontrolled (tons/war) ova Actual Emissions Controlled Uncontrolled (tore/rear) 0.0 11.55 oca 0.00 4 32 0..0 VOCEadO Atd61 Add Gas Flare Emissions Inventory Criteria Pollutants - Emit Uncontrolled Ct./year) Requested Pennft omits Uncontrolled trolled lmnsheerl Itnns/vearl Actual Emissions Unconholled Controlled ImnM1.arl Imns/tearl we Hazardous Air Pollutants Potential to Emit Uncontrolled Itons/Yeerl Uncontrolled Controlled 084.4.0e/searl hmhm.l Uncontrolled m Controlled (cons/(tons/year'nol(tons/year'' Requested Permit Units Uncontrolled Controlled PI5Aprl IRslen Benzene Toluene Ethyibemana Wane n-Heione 110,111 0.0000 8.0.1 .100 0..9 0ACA'r ' 0 0910 ' 00000 0004. 005.70 0.0002 0.0001 0.4,990 1.220, 04741 1.44.19 921231 7963..3 1.43.1905 Criteria Palwon¢ Poteneal to Ernit Glom/year) Actual Emissions Gltmu/yeerl (tons/year, Requested Permit Limits Uncontrolled Controlled itoro/yearl (tom/year) PNI10 PROS NOn IOC 302 000 0.00 000 0.00 CHI 11.00 0.00 0.05 0.73 98 19.90 0.03 2810 0.43 1.86 1.92 Haardous Air Pollutants Potential to Fmk omtrolied Iron/wrl UncontrolledControlled I�c/yearl Permit Uncontrolled trolled lom/ye.11 (mm/year) - Requested Permit Umits Uncontrolled (lSO.)55/Am Sansone Toluene Xylem TE-Xenane 231 TNP 839 gktlryl 1.reapmn(Me6H1 3.41 0.21 4.41 9012.25 440411 5214 012 3.44 0.17 .0.02 802 0. 0.02 9.314-40 137.22 9.34fthylbenaene 9.344 4.90 0.11 5.2U 000 0.32 2.37204 31.. 0,2 ...w 0.04 000 0..4 0.232. 90.00 2035 Tote missions IPm-n.912 .1 Criteria PollutanPollutantsConvMm Potendal to Emit Uncontrolled (tons/year(tons/year) Requested PennitUmfm Uncontrolled 11000/ear) ItauAeerl hovel Emissions Uncontrolled (torx/Yeer) loons/year) 0.000 140x MX Sou 0.8640 0.0046 0..4 -110 LID 1.80 0.99 ROO 66291Pf400 1.22 LEY 1.88 a.tq 0. s HazardoAlrPMutants Potential m Emit Uncontrolled (tons/ear) Requesmd Permit Limits Uncontrolled CmMWIm • 1.,./v..)l 1tmeAnrl Mtual Emission Uncontrolled Controlled Itona/yeerl Imn/earl Ragweed Permit umi¢ Urmnmolled [ Med Ilin/Yes0 Ilmvearl Toluene , Etl00.. Xylem n-Hoxane 224 T. YRS b0.yl Mem,. 34363 ILO. .441 048543 - 00016 0.7062 0.7062' 00.. 00103 0412.0472 70.4 14.78 24030 1..2 00749 1387.8832 1513.7 000. 08003 .04 0,99. 2 X89 9.042,2 n3329 JAW 1937.8422 28.2024 ' OZ. 1..7. 6 0044, 0.0429a... s. ;.. Sawa. 3.ro33 00.0000 A-.aF Section 09-Reauhdory Summary Analysis - Regp6Non1 Section il.A.0 -Except as provIded In paragraphs 2 through 6 below, no owner w operator of a source shall allorr n MUTE the emission into the atmosphere of any en polutantWach is in excs of 2U19owdty. This standard Is based on 24 consecutive opacity readings taken et. second Intervals fosia mllwres. The approved reference test method for visible emissions measurement Is EPA Method 9140 CFR, Pert 60, Appendix A(July, 19928 In all subsections of section n. A am eofwsreguiatwn Section is -Smokeless Flare Flares for the Combustion of Waste Gases Noovw mer operatorole smokeless flare or other flare for Me combusnen of waste gases shall allow or muse emission Into to atmosphere of any a9 pdiumnt wdrh is in excess of 30% opacity fora period or periods agxreganng more Man six minutes in any sixty conse.ve minute, Reg4YNon2 Section LA -No person,herever located. mall maven allow the emission of morns air mnramlmn¢from any single source result In detectablewhich are excess of Me following limits: For predominantly for residential or march) puodors Ms a vlolaNm if odors are detected after the moos air has been dilutes with seven or more volumes of odor free.. . Regulation3 Part 0,APEN a Polutanto Fo ur rements teed.. palumnts,AlrPolludmEmissl4n Notices are requlreafor: each lmlvidual emission paint ins nmrvztelonem area WM uncontrolled actual emissions doe ton per year or more ofany Individual criteria polluem(Pdiuents are not summedl Ito which the area Is non-attainment Appl6nt 6 required to Me an ADEN since emissions exceed 1ten per year UOC Part 8 —Construction Permit Exemptions Applicant Is requima to obtain a parmO sine uncontrolled WC emissions from this facility are greeter than th 2.0TPVNxasho0IReg. x, Part ',Section l Regu6tlon 2 Section MB., 3inca this open flare my as a backup 10 control still vent emissions amine unit covered under point 120 at this .84, h's notsub}dtothe a ixon of Regulation 7 bemuse this portion of the m a -Hondo. not have requirements for amlne Section 07 Initial and PeriodlcSempilne and Testiest Renubemene Does the company request control device efficiency greeter than 95% for a flare or combustion device? If yes, the wrmlt Wil mminam Inb'al compliance tzstmmlu'on mdemonstrate the aaswrnmr efficiency dthe cemi.sdmr am®baxa on Inlet and oude[mmenv.am sampling 957,7082 68.00392 53.00282 1.020036 10.89231 23.10198 0.000521 11.13403 0.687017 420,61 K:\PA\W\WWE1136.w5 Add Gas Flare Emissions Inventory nay Tonbn,..atAnttht.t.fit.. volume of pilot gas cr, Elm ma mpecrfe 2(623 acr]H,Is_led by a nactor two because tne the tnequippettwm two pilots -h tnmem lee nteedmm,mdsdu omm ‘21,clunnethermaaam l trol tIntnceldowmne EhWsonsassocfated with the antIne on, stIll vent tint, ,emtszlons are routed to tins Hare areauoun.N tor unde, tfin. point rant-er thana[ or VOt and ni/11, emutsions stnne the operator Is als,lassurnungthe, er(cove 501 emanate, at 8,7filhrsivear Stone thi, rnnt,1 rn cons ',nate of erranstonannt„tnceptabla far The operator did noncel.ate PN.temlsztottnassoctatedwrthlbecomb.ntanallttlln and purge gas. The nnoke,nnfne,t-tinutan.ntannnt ts..,pectetl tote genera ted tfia rambunnon arryne untt vent waste pa, ansIst Pnonft....6-egan'anted tn...< n attic h sacement,. ernEnsion facto.- n2ICol aP 2Cbapm br m oca r115,wasrevIewed.012 document expresses:. ' arnt,tons fro n flaring may include partictes (soot, n dthyarawtioterner the do document °Infoca n withreOrds vox( ullvmmaln a azhM g Sun,de 1fort [[sane emergthedxnmentdee gbyfueld w#ragaroswew. documen the wands gfirther n[y results tn pportosnor foot, latabw table 1.S.ss dercyoraiel smoke rm2s2lte 22208 5d aktes.da cads( r,nd rt mmncmeder (pa ayg enpn flan usaonz average ns smote,fla rcodbyfootnote8t.g110ai2744 Nc2102 5, 011 rows', s 12 01411 den end therefore nee -o flares, /g/ fV riirefl c.,fro tit- r- :15,0m ( nillie5PM10oypM2 S'from mdusrtJ Wen atthe on ,u parnetfiate matter from aria. m smoke asr-voressent A.,...11Chataner 135. It abeno too,. ow, ton ifiume m NH rag lr dell the fu ",,,acne lfsmoke[s obzenve 2'122 da,/che< sconhoct a format uld red a tv t, e[eu re rrqur der opacity ryp ctape. gularh ft's,sary ea design for the be ontkeessarylessXbp y theIt safely be assumed that n1101.04410 ao..-tIc gr oke probtetn m e o a sum u. -t r as 2[F>p1er35 for nonsmoking • total PM emission,. Factor 151M zdl %pa2 chap siomlorlpth Nta4 ar421svada 02580±124221 441 I orpMor resin lnaddltlbrkiagula[oN equ remenm :. on me nformahandbaussed man m a dnvebpnrotryehl readtrwting�pM em{upratpmndus ll 185111210418 .. t ana . The ....don ot VC, and HAP emissions associate+, wtth the anal purge.e 45/`002.e '.c Veal' prim to 044nssltadb,m mod of e ass wren purge an,1 asst.as.M]the operator will non, nsuate ,gm g .p5 muLha s /e 6 ease r 6 a samplemdemanatt,e the ezabishedemt,0Onnt factors renlatr. accuratenanzetratr.e. Based on this tneo.eato 6. rile prge gat tate tsbaneti on thefuel gas purge-nate pncreitlerl cmt,eanuracturen spectficatton rceta xbuerli_-rr/h oas-a120.s,/f,, actual now rare essacared0ththeu.ge g.zs cp ratp 1120s,.i/drl0ymelwurs per monthWacnettabte onnatnn the purge rat, cornnant ri.te operator unit ne reot,a2 tin mon., rotameters in ore re'if y the purge8srace ona da 7. The required asstst gas b see on the stnakntestate112,3.6991 fi p uei rate ts 'nowt. to maintain rtnnImurn heaLcontnntot.tantn.t/nd(55150211n, i8(orarwnasiisted flare'. The idb,Wngnatculaaan n.ras used to deurtnine the. flow scf/date. nm twibmgIMMan/day1 /2 /hrr@van<r/ mole{/1a26lb/lb.-mole)/ l 02 me<u VII/M/dzyl uttet lt,eltnd na SO2mee> pwa<r'dua-.ra bw� ,. ?.nd(1h/yearIn1/1,31.84541S/neasj'I6a 2)b.tnm//(3415 n too)(1/(59201 MESHlvnarplealh502/Ib.man/1445. ]16.maljj=,g]6si90SO4/o.,,.. pacing. find Sow rate. canonplc a1,ef, .Ieprnt rgfu em 424 ll820,a d.the ptIontuxtuse ls not monttored,thedto ptbtl gh,ntn, bem wed .10. The opera.r e.ressed that these la/Manhunt flow meters nnstaned from v.:. data mey be obtatnet. the Intrst flownleter laa aireedvalownstream oft. amneunitsolf vent and .11 meavme rho_ no, wlutne venawasne gas.The second flow meter ,tAtI be Installed, the open ed n ,hep Rio wmpI5so with .e i andw 6 u usted bythe Pate, spI1114 '. 014 tan. the opera.r will measure total waste gas vented from the stni veitt. Una, thin data tn contunction vnthtmonitorirgof thermal otadt2er downtimef deterrrtInIng to natal volume of stil vent 'mantes. routed In, and unto by the open r (still dry roe' 111 ., measure the tonal vatrue otasus,g stoand contbusted by , e.are mtd Sow meter v0[aM enlIsslom routedmandamh+attdbyd,e IleredurInCrOnlawrunrnewth this pd venture thcapemmr tuna.m total vo4meolstanuem wens gas 52211 above dte operator nnll [neck ens Irma ustng stM vent ransgannnu meter,. J rte hlliftd Wn ltricre pids,F.N,er vp�and MRpemix em dibe ca eNia ea fog a nmly ,AnttrecfStIllycninuente Ire operararsekdpnmary0OCard1 { emissions and cot...Mort enisnlonslNO; CO, SO,etc.) annoctetech with the otmlbusnonol saf vent waste e_ k oEle to cepsabfppem bngpbm 1sb be notedthatt, operato,. 2I/$. the 50Itsenttuastegastlouttor esnl.nsaansonatenitutthnombustIon .2. avever.thea Yl ventwaste gas ccntht.nbon eeleukuots for point 120.are Maly ttn.ared ssnce theM1ezreeueted 876 tm op a.wn,the therrnatetddizane.penence oownsn, dnt, rewewort. preoous maappikadon4ssua,ad), cheoperator expresned ma. the au.N.Ns9<sed0-050,0.1±280101521l • hs$ 1 e,true,10.5000, t/:20 /n +o perrnm flee tht5is va09 end Ma*res. /greet monitored worth a (low wll're[ndudea anntilticunthatr ge gasiohemanmredusinfl 411811105850dokstonta1,, 8105004145 19440 rue/(w0510 I meoperze,,ol n. the im¢0ncpbn6ea a fuel . plre0 withthepraae 1 nlchdeltn a deemed to bea<c andwa ton issuance at the per ei • en,theopeietortu nervfallhedtlat theflare header ha nfl(ty an Ito. !ram the Ilya el4asv gasr s strea re routed 12 the tlarn «era Oct ga flare n ka e l The. operator ent:erated that the puns,. 4tto,a,en at, rt. .ttn-g.tnntn, d naMaanon gas rwill. ,Lt volume n valtnne menare. uar:<na:ea>da aara.amonho mme thly are rt....dinfats Rae beCanst Itt onlytnned as a back up torltrd devIce far the amt tetlllvent e,95,F & only permIttIng to tot. ern..., kr+ .ert nut, device for 245 clays per year : sln,lernonUnafttperanan.ws s lurca IS, In the pItt,lous tssua me Ns cm1210!$.1141105'4251411111240218515/014100,l.11021 purge anti ass 1st gas routed to..bmbvsled by CMe tare. ffiI factors t.den.lonsr. ate camplIancx Additionally, tha ourgn, and ass:114n are only composed of nent.egts Ifits.,..nnnosittant, nnt 2,c:ea nava, ern,/ to rant mote frequen“ampling 22 02 228.11 ktortaitynthe flare. is. o lyperm,2e m operate. for :2p Slots theyeer., thane ns,,,,as tinterrntnedtherontnnttedu myawnaptors were sues non • okpi>2on of emtsston.anaact.ged wIththerambusnona 40845442(24025210.ek 16..02,411.11a15,4 201,552 factors wereuapd acul0e pllatifghcernnst.o0,Ms ems., lanttnn net provIden anninstan ',ors for hentanne,lotmaldebude,and rortter, as well an rtn`intrane The enttssnan,ants benzene, mitten. are ein< ed Ihthts analyst, ',cause theresulong emastoms are xma enoughmbe constdered ned5ble The erntsstona0Nadanz for tit se paluana are as ',lows 11 0 /b Near sl 2£Ib/0m1noytle54 M /nd fill / nffl l M / f *oar le hW 1 1/ ar). (5410 54 7 (451['[5 r M 7/'115 mrseiv/Wadril MIN./year), a51.13hearO 1 tcdueneU J earl loco5alg(M 14105 otu/MM211/(10210016u1 ) I'l; ®MMwr/yearl- 0ooa5/yee,. stoos reported. IN, 1remnatvarwysl donot match wrthe antual valves eeported onthe MEN 1242 are to the faalhatrdeaauMmalertrwort€den the4EN by.ce opce+o-o58 tetued6evaluatIon of this applIcatIonbecause ac the 1101.1nuttmated on 441101 023 for -01.13.14551001. meo,re,220584022014402111205411100ived o r t v24011.5210 M1 41112 P'tmao gam 42,25 en ou[ theamlrtevnl tl8 tepusz olz 40,202'ntl movermn r 2$25$02ngdng th' h operalnrpswdedthe f2llrtunngirifor gardtn21/4 o fit gasl5awayz ata rate[hat 5,5225the nth Mteerdl0nmtnnl et 25 MN,.imxvim 1 11110141 tic ma, tMSNeleon[rofle....il fdl.The a g via the 6eakn 09 Inventory SEC iodine and Emission. Paton AIDS Pol. -7" `..e b W^4.,8.9,±6' 156 02101 0110 ▪ above aro an kllaw: /0 21 -Combustion pf 055. u Priet Mt Not lllllllllllllllllllllllllllllllllllllll h bonPollutant d Em Rector .mml VOC MMaf Toluene I6/M [hV 6emene oA, 1ni Wane 2Heure ti; 90 � lb/MMuf 224502 1.00 ,0 a-lh/MMsd b/MM Methanol 35 iIh/MMYf Methyl Merapanl -1/5541 sot ttsce4 lPlbIJOa lb. 50x CO w2 Nib n-Razane Pula . 4.12.5 VOC CO 502 h/MMsf h/MMscr 28129a.mutad 1os °P .. 0a 2381.111 geld- Combtnwnma.he and prtegas .40, 5.,. 'Paint 1561, lip 021b1-cembumn of. of 61 K:\54109\09 VVE1156.a5 Flare Emissions: Inventory Section 01- Pelminstretkue Prtermation 158,68721310, 66766,686,116111166' County Plant Point w AIM; .6602226,0,6666,70 831803512rniss,ns Unit Enka, Control Device 20Requested overall VOCE HAP Control /n do da:MM>n/a Im NeatContant of 7826 wlume of ges: kavl62mmeof PiEValurne 01.66 of VOlumeof 82E Mee [Content nlRas: 3Mueade anmeulp3 276 me cl gas Ileyueseanearro„ent fraMARTWOM Poktme of 2911 E42,0'871.42491466:6111,10406586/2, xa acondB.,: rwwe%an MM., Neer n/ 1.,.1,. MMre/ve49ar re/e>r "'' aemr 2,1612 MMrdMar Mae/war 332.. MMm/n.r 6Mwlume019929.51 W014/0..1 M,1/w.1 ITEwMmeolgas. 29.51 MMae year 262100.1. 801108e of 2211 011091 Total Throughput: emgewesde ra181,11nlpernac u ltl Mre/a.4 724/281 36,7 Polklaclipeer 0321 M11,4 as<a_ MMgmryer 83.7022 61141sEllyeer ME Throughout _.,vx, 51161651/18191 X 6666sad2121 u lr6116r'an"WorTigfE664"'d':7QUE IMw1a1 651/hr GMaeM ''1 466L'.2;6 f43 lalomel I 0.6a601g0a0 MMarne tare Relliin, 6100 OM 0.00 CO2 51 -02 1.26 17129. 21.20 N2 71 -01 1.39 12132,9 667 meihane - 7,17691 22925 1907266,7 09982 ethane 1325E-01 22.95 641176.24 170.29 0,00ene -02 1206 110709.92 28.29 Isobulare 2 683E-02 1.26 17031162 0.61 EPUtane Ise ntane 6046609 600E-02 1.61 1 00 Man.& 102 nmre 2 .00 1_18 280612 4.20 Elle8.66ne 2.692 0.60 600.26 2.97 cyclohexane n 0008200 600 0.00 0 00 Other 22.23nes 0 020E+00 MOO 0.08 600 11e0elnes 0 000E+00 0.00 0.00 0.00 edNcKlehevne 1100066-00 900 0,0 0.00 221-11.1P 0 C212.60 600 600 0.00 TolUene 0.00 600 0600 6.12,06n8ene 0.221E100 600 0.00 600 %Ewes 200..00 600 200 600 Mr Pleavlen 6, 00006600 0.00 0.00 0.00 0 0148 Tads vx(V:emrooWa)1 Ina(al Mw Meets X14 IMlbma 4186.079052 sahr 6108226760 20.125610 1 messEractlon 18512 Helium 0.08 0.00 92 12,6 111220.06 1213.60 129.89 EEO 1121662.00 137229.29 324110.62 1190902 0121,91 22022.63 12280.02 682,3 212.92 137.00 20.99 46.61 1,00 18.12 0.00 250 600 600 8810683 26146111 IsobuIane 172 1.79 10.11 227 RopenInne hOenterm e Mrenhne cyclohexene Ether hexanes Haanes .V61.6 4262692 3,01 2 06006160 1.77,66 60008200 00006200 000 0,7 0.00 1987.88 600 60008200 2 000 2.26.0291 11108,4 600 EDO 0.00 2610 111240 800,2 11.42 16426 16.00 1626 33666 922 641 0.01 Toluene EurylGwre XYlenes 154e0111 memaen 20210 1251 Mend Manama McS21 9.0006-02 38126,4 0.00 903 060 0.00 0.09 061 0.01 0.06 0211 MOO Maas harnen 0_661 Total Mac(Mreeamld0 200.2.1 - Total Menge Heat Content: 1173.9.72 MaIgMee.wm Residue Gas Inlet Gas Nealmnene(Padua &mdtl 6592502246 0.107137662 1176.339292 Hof 61 g:wnrn5®wF1e36.6P6 Flare Emissions Inventory Control Device Pollutant °°,e;/MM moneusteel eslim/aohn combust.. mwma r.aorsosi�Cia<I.n o -c iavaxremaxs� OC n-liamma WaMINEWA Pollutant uolm/mm atu mute host dal cenUncontrolled wastage. volum un.al emmmn. ratarSoma Citation rasrna.dr# �nnu:okm:°h, CO Control Pollutant 1:17,::",:' waste neat combust. controlled '.'"?..."dEmfisions mall Factor Source Citation d1..\".,, ,Z,:: aximm cQ�501 vr.a , aaaa�lOO a.'JA Or N Polltrtat tinuss pm/ co �l er(aateSa a .alum. co 0a ml emminm Ramrsnsimsieado. U l\1.104iii :ttcSa Uhu`aM2e B ® : ; 'iaeusvrazns ?f.�"vYmn.&.rc.6sscahvanrdnt✓ww.ad xm W HMEM 7 ecto Plant Ran emission racmrsoune Pollutant Ilb/tawel Ito/mlwnl le. ThrougiauI Icss muaxwrl vac f. t, neeal: t... n. 0 00 an o Emission FaCton Nara Sere Pollutant Uncontrolled Comma., Im/xlnanl I5/n+xssnl Immmmumel (ea m wxwcl soimot annum trotter 1.531 Volcano ethylb.nan• ammo .84 lieTPAP flaa non OaKM methanol 0..100 Methyl x.maptnn hoax) CCM .iitslon factor Source Noe VOC CO 501 Uncontrolled ImmHorl Requested Pennit Urn. Uncontrolled Controlled Mans/vearl Dons/marl MOM 0.0.57 mnoMea Controlled ImnSamer1 Imn.ryearl araM enrsar CMCV 0 Mall COMO narmo COMO OMOS 0.000510 OCCIO CLOMP VOOOM OCOM z7: %7 VOV VOC CO 501 Potentel Uncontrolled ¢ Imn.ryeorl um= p rolled tilmn./yorl Imn.Norl Komi mKsIons Un controlled les./Ve.•l Imo/VC.0 COO COO usot CCOM COO o-wrarawono Omen., to Ornit uncontroom Immhorl Requested PemdtUmk Uncontrolled Controlled Imm1orl Imn.h..rl Acme, Emissions Uncontrolled Controlled (tone/Veer) Dons/ .1 MIES N. VOC 501 DAM VOOM MOM Criteria Pollutant amendel mama lmn./vssrl wnestea rewltumw arwile Immryort Imm/yeatll Mural Ernisaions Uncontrolled Inno-oned Imn.Norl mnoroon l 5O2 aou SAC 1,2 Oct 7.0 d5 oral Flare Emissions inventor [,trade Polluana Polandal to Emit Inensryearl Requested Pennitlirni. (ensNead ItomNml Actual EmissionControlled {tans/Vend (tonS/Yeell voc lt Hazardous ar Pollutenn Potential to Emit Uncontrolled Iens/yeerl Requested Permit Limb Uncontrolled umMrl leans/v.0 uRoos/Von, (tom/neer) Requested Perm... trolled lieAee m Ob.Mrrl Toluene hny0amne C.M.1 GAMIC Hmerdoua Nr Polluann Illentene 'donna EthMe.nene PAP Methanol Methyl Marc.. M+el) Crimea Pollumnb ONIES elOtt V. 5O2 Potential to Emit Uncontrolled Iens/yeal nntl tit PotentialEmit Uncontrolled l ld e Requested ParmitUndts Uncontrolled ICn./yeeControlled Uncontrolled Mt Request. Permit.. Actual Emissions Uncontrolled Controlled (tonsrpeerl /e/e/ T30.34 J 11.51 Mtn. missions Uncontrolled lea/yearl edit Uncontrolled Permit trolled llmdedAea(Ite/yesrl 1137.48.51 50.124, 0.003 34771 necinn 4,56 EmiviaS Pa It Valued) Potential to Emit Uncontrolled Ien./vearl Requested Pemdt .. Uncontrolled (empaael Iea Controlled n.0 tri <18,16 Actual Emissions Uncontrolled Controlled ttons/yearl (tons/Wad 0.037 11 nen ,26.392 entl CACI CABE toluene nimlyenene xde. 2.24'MP MethanMethyl Moro.Mee.l Paten., to Emlt Uncontrolled ltonsrWrl Requested Permit Units Uncontrolled nmaA®ri ttntiai issions amtd� Controlled Itons/ysarl Uarla/aarl Mqvurl Requested Paint one Uncontrolled Conrad. 4111.311 0,1307. 1,.4215 0,771. SAM 0,27.6 7.7117 WSW 6,41.4 0.0,04 etenn CAM 5.tio on R Ulm Sum. Ma ls Ryaaziana Section HAI-Cremates provided In paragraphs zthmugh a helm, no owner or operator o/ a source sheuamw or cause the emission Into Me exosphere ore v all pollutant *Mar is In e.sz camas op.,. This standard's based onzamnsecudve opacityredep ekertatuxcomIntervaIntervals tor sleminutes.The approval reference wanted. Mrv6mle emtm'ons measurment% EPA Method s Ice CFR, Partso. Appendh A UuM, assail In all subsections of ...on II. A me a of this regulation. Secliontl.A-S-Serakelcm Ham or Hares for ['m.o.... of,Matte Gases Ho ar opener ore smoke. Oa re wall. wee for the combustion of waste gases shall alMwor causeer.stans Into Me ammpneno any air polluantetich h In excess af3aM apsty utIve Meaner,. oc periods aggregating more Mans mnutos in any arty ton Ryumlmz Section,- No person, t.aretter bated, shall cause oration, tre enesslncofodorous air contaminants from., single source such as commercial detectableused predomlnandy for resumtlal or its a vrcnton n odors areal as after theodorous air hash areas with seven rl or mare volumes of mar .a erPart R.ryleim EM Require CrIteda Pouu¢nn: Forcater. polluann, An PollutantEme:Nn prepare required ton.each Individual emindnnpMnemanon. nmualemiasbnaofone en pet -year or more of env Individual criteria pollluantlponuanb are not summed) for which the area Is nonattainment Anglian h rot.. to m. an APEx alma emissive even a tan per year voc Penn -Construction Parmh Enemptlom Applicant reau...oMdn a pemsharnce uncontrolled we emssiom from this/:ut/are pemerthanthaLOTPythrendd(Re. 3. Part B, Section n.o.zal Repletion, Setliell .ppbebl.aopenft.,e reed ass b.mpecontrol bpeepNmwfmmdupo doh...A =It covered under at Ws race f,hI.subpaathhsectionofwsuadm P.mhpardonaftheregulamn.ates•Ifacombustion e*Isem mtanwlI emissions o(VOCs d other hydrocerhons.ltshall heenclosed. have navhmle emssloas during nomolapepdon, and he dedgnm rver en, by mefrom,. otside ofthechdeed combustion device, ar hyother means approved I by Menlutllon determine wheee tl op...ngpmpniy Since tilts flare Is n i, it has been approved as an alter. M control denies per Rego bdo ti's Section %ua I.h,a.e. Please see Me discussion predo...In...OP of the tab labeled l3a cryeoloeeyd ra ef. regarding,. approval.Md manauv, the EqulpmentRequrVForrn'a support their request to permtthhparees aitemalveeme>onscondm equIppnenttfortheglycol dehydrator duringyRM downtime. ttnICOn semen m. eM.l and P.nme..inn and resting Regml.mants Does the LOIllpanY request a control device eflidellef greater then s5%/oraflare orrenmusdan device, • let and oudetconcentradon sarnolinn 45P,65 A:\Pgm\®WEv3R.CP3 Flare En,innions Inventory xaNna.-ramnlaunalweNava ____ e.alumeofplot gas nwsmoats rr m.e-:P•xm.we><alao ba'®raahl.inrt law apdnC.InreWrebrotarcNtvtiv.meawatne.rr:.uen... Tmpurge gm reMisba.omlm Wagers' m tapmanoon mrersyecl flonnviaaA earn wafmtrewgzygumgegvhesa pyrye nk sJF,29G>-✓NnYfieaGdFend y purge raNvl9BOscf/N., G N p r od m zandP knaetlo mplaab4. nub,. Oas Pianton03/1911.7.5inte ddIs .Nteapeclk sa I lnnnnnaLepolnOnnenntungpurpvse Mtll.nany,th On mdnnneriassmmae.iaml*et. tombm afmf. gas area soma m. Me McWioum 641Plantanivvbi/vnvanmo recent -Wet gasomp was brat¢d didieielrnenrnab'anrwmwneein0MSlxmrie. W.I.ample ndudmwtngon sell. nnndvn• 'rerea k " su ricenr I ,laterLtn.a kr. weigh I H w mw. rehanaMls lu sxtry.. gni 1' amgcama lam NU uied gas m this arulphwndetem.e.e,o br r Ionsaae'rtfor sourNisbeinmN.esmpi.a harp gingpurpa.,tmoperzmrwiwrevunetltoobtalnanmcJsampe.'. g. muted Uelluebewmemeara[ganademmnpaemfor asaucaisbdngaaa Nu arMtaWm; V. the original appr<awn.Uevaeram-mIrytrviceaaacevauegusan,em ewmamwcannr:samhsianshvmddsmuae.muoeo Lire zninonnnn /aravgas<alaulntwnsa.¢vom aecouraboOlnlet ant residue prz. Since g.µpagy Mr a hl0ncwcranrennaUm mrwry_o7Nme residua s. :.i mim(tMPG 3draNg noma - I•drnnnpnns: snaetw gesroumas mb flare watm<�wzedmu kof gal nMptyral amplem moMarea-- akNatlonsiprWs fare ona6/a¢/nwnl. acacmunttor ntetgas wm.strom this results In a mare arse nrwe ucsue rght•<n megaatreairaxa.mseWereroreeetermrn. to amore a<arate Irepraanaonbl Ole water Fsmet—WU to rcumtlmtnkfare, " v ent,N.I1OeMN0nnn ones "at.ylh Me<omb imope e bdea grred Mbaazmoee szcombmaon devlpe,pardw aid, m0 zrratnwa¢tli--ohs amn (amine coml,100IIofdekydiam!'gas. resipltle-onl Basm mdmWsdea<e m ne tp.tlresre,f enlmeennsm Moor a%rWmb awbedea /on/lnnnn wl•nr.nlcemmss ,warear wad.rhs n.aanrnennn lay aeatbnn Varddeelsom�,undumdbydrxubbns,Coae partranvb+mea.srkalonmlMreaarhom.asa emttMerenupeenoeneslffal snW,cg Hallfitle or 'mapdnzlsrored.zunedn ie(ma}'/nnln, nMY an¢ mprouldenm+madoawtb repartlsmparahln m ueptwilwegards¢soo[ the aaumeM III4r-cher provides. that asmeIclog arednmr/.tes - Ma wt aO�e¢aswsandwmeameuntarw otvrygenln the terrwuseentaffoo nhtunmrzupportetjn Ngmote c <h p:vp. ne bwrig,-,o mmn<'eno-atiodueuessnvmnaldnpda�.o tdearomaarker(pal.), smolorr6Rves.no Pg/.: aveagesmmdrynsre,m44(I: Es ey�.adnsrares, va ssgA.'pa au a nr8vm opM .loaf. flares am one erNsoma arauIam,-_,rtersrnrn a fare es soot eomsmote aw¢sm,n awxrneoerrr3.5.. should.. mad thatNe O&M plan requnaducnallnmecbbe conduct. todearmuort tneaesv niesourreare0uum m either-<orecrf ,eeyshu anµ,e.nmlmesdgato the cause, Oa sm:okeeFa<onos�reaetnasnenewsn Baer may qulrementmr- gfopeta¢dprapmwcvnveelyb,msuned Out On flare wig opera:evaamvxa:e on a regelarbssrs.nha. llznake lzatemed;mevperam Wnbeeyulrehm asses. Ore pspuklcpenvn ndperbmr mleemr - mnra:Aare. pperom .I'nM axenapurt3.Six nvmwk(ngfl...m.edme.slrrme MvdaCe eetan e; zdon!os/IxsCadel;nere M1aveonryceenxo repo•rreaaevciryeueai;ybrzhhfare.fihsuPpvrs me argumenc-that this flare mnss¢nttywce smoke. I:If sib/MNsciro sP PMe r c m L r esolt1,2,di l a q ua . =Basedon anEorq v.¢.nd rrwkeg's mhave o mmwltbea peed, a sdeveloped'', 'Wareits✓n onnusvn flares amainWmraoy - amitierulheonnMmsr.g.raing he armaoagina uappliat BS laxptlppedwanbxhcmbhvx aendmrhxa waerawm aThese hra ulereaut,,t.operator lareq„ired.muter Gnh mmxiystaasepama., drm Uomtdmmereevaumntademomtata mndiem with rho anrdtaallma..tn. P.rn.ltpmos mtm Pam aoNea>.;daraop:r.nrrw nao x/rrxmaopxahreeequlpm.re.Ute. mdm.mnoem voaaownewi Nekton. ate<o, the mm Naar el el'1sts WI. lend there;rmraamrman',pram of. 33sm/m,Tnawrge mawaam.aademaretanfromthetwf .MWmumaaetebn lNdprOiirieter.Wawator r salsa masmrea gasMvrate a.3:595./Nrortmrdaluaac<arre- eadm:to�Mwarmlrre der.T+uramtmaawlluisana�n CUUniamuma.senlai Ur®m.I4e0.mnyrynou me.; e»ad a rstmrwurmmmtfam«aNW nyarWlrpshbflaa,..mnsring mghnm lnrmpmmY II. mrgCa. gwnemtmmet.da aqulamam fxboU mad!tiara-iFamtamumfbwmatM must. summinamewmtmew Pau red sbaowane meter ::atadlannmtrrmaaataaeamef<amattiW-=amnar.maa.h wmPadwmathermdmavnwsmaer. .. aeaa< t«alkwmmnnsmwammmatmttNepreavIln.dam rr« -male gammfayo Meaadurhrp malnrdcivaeueras-aswrtunand enmdawm fumes,. R.lorach,CommartPro.lon% o-satran.-aha;rxauau<n,rm<pernmwuneasto- dnmanrrtetim anYhs owlrtfadudrrgUaeavenn-that is evaded W .flow mIrter. 5.14tfar#t4ma M Menuanmcammn Wmoiort ftegukttanantl it Bun not nar roomed as :,..:,,,IimzI,Ioel.ahoFINIAhreelutliteethe•pb.coutembeurtlIrnitaat ihouldalwM MnrraddvluntI, Remslimkddmrrathula awuwpnroutodhom<MdHlydWorlWlmtt311aellzwhtaflcl h htlunbg abwlstfhls:tne, 1 HP*, the I mq I mtwak*a5 .yatn.nerodurlpf,;>Puammd r tfimMkm -- reed bvtmn punata. Tn.aar.t«aspmaa'a. pl wi¢m� ra un.routed r:. dwsfravery:MeYtiult.lmnbno:rr:.aro:. a.pmm dadl'aaa.ma. mwnrt,I npu Hw+.rrta:iepnra P vgmkti 1'bt w.tagm Tottmfb.efrratMopomu aararemsmmlaplad ad.iwnvmtfiddm ova Mira r)kmtm fa twnarvdsetMa+mhun6nmaslauo„Inl.mrid prir6oju. tkOear,grrnlappamnlhecenmznsl,therroeramrrlorwsmdmpamuta tow1 a£w.35MMSUAa aroma tsludN @^ tvelleag.anoc aadw s wvponsrgmI mnm ao¢y.sln<eemwlm weemramsaeedn..Mrnnmd.are pokeue•nginnallyrmssfPm ewsymmem.mnor soasrmatOefnagry saeaam.inhaasatketIon two Osta e/adyofith,.uasteds mugrpur roaxedryaxlarge r eventsa a<kr q.p(acalmo�nnw'onsgagufavon(Seek.1,-.O1.), ks=resut meompeamrmaamrtOa.ixTegesta.dmpya conservative, . mt.Mertypwh em even fpI,pO/.o r went ...could not have., r rwsormeseen am aweeclIarenot.. mrd«raasm ar<i Iiest, waeetomtys mUammvgh0tassotlamtwmz¢mard opeadoml,roasslnomutopendon,tb rapmentuesamcpad Berea on Olsnmmudon rte • equestedt.4,prtms Mse/yeo•.Bumen prebwmad.,p..2mmu6apndarrmmmmvlamatecelasdor0pnpbsourreeenb..wh OIO igatlonslpptnceduesmWaaa-n+ame autism reeassgcaas we minor awermansyntneoominm.ltusrehpl.poomf tows on to al .forme prewouvmodiPndon Ns pemdt:Pkaesee We YubP<Cormmern'vbm Ue p,,Ii.naryaralyea fork suana<Im.d dmziMktmaaaipeminNeU pup imc[rpmarenty. tmmmaWn,.. r: WMW& idle opo Ong, ...lard W vybpabnan Nap Q ve M1z dl uue 9PSre W O _a!, y+l . gap snrstel. IW '.W gap ap d,h 1 oamJYip4'blo tstathentla trJvreWessoemta gr04,i4, d awwntrdedd i 4,Ni-e:I.e4ortWra eaaamdMra 4 1 agar <s Bedasa 001 tardwr I,�': i'ltor ntl75I own be Mk ,son Uc 1 tv lad the,tualtioluntemorinlerepd v-sf 6 tlied q f raprite vfm<weeluys p s mnonadanunMmemeter. uavmes g nM/padnlTheapn mnpleheazcontenermme VaPWypsaw rater cIcule.Th 01¢Ild ,,rep Maopereter rmnquntedmnaveVl-sample ilea..sbnsarler tnadW ps plsed.tlnnepp.a.,il.ca.lawee uedaslrtwttso[ -pa. ga LIn moe.UermakWehawalmreft.tattssfFwLMtA notNmuu redetbti4sanraIum,rcomeand res Man Devalueuls....espK5Ionsn.iNsmr.en, pn,.....MW• ..,lea m.atbnofattaOaMsdomsinceftaoa miudgxapreldtwel eprNraayofnaetard reuduegas malwWkacmlemtsumdunngoPeratlons.lnnead.atpwt' aampalgons,Natcmrrencand naN*��esvRtLemmdmrca.iewdmandusMmWak�rmsikn. weremM¢rakrhxe tu;le, emissba.,..em..rr.arsetpte.eseMssbnhawritorbeoaefm.fmm.I.,tle,rm toluene as welt. nNenne.ihe zwra fartb¢roae kmmde ryle,mdaivwea. hot -Included Msa0NYsb Mtatsedrcaa0Wnnerd.nsaresmanerrougr mhos�mNerasheglgtde..TheeMukncnkubdons for rAese pdfudnnareas fdmus(n/arzecellWW}ear}—(uamim/idlea<P/north raerrr/nu.er//PuaeNIMBRO/ /Op(itmrtafaa<'Asati—o.00-:m rhvrarmawarWellb(year).MDR bAIM11.lt`pb5B eagmmMwefl/Elmdurt•awRtnEsaMiXeMNI1d/yexl• o.i1u/yNr(fii rrn oet1.0.laco34,..drwartons.A..gcd/IxmoMra nupanictmme zubmMnam Paps ors naB)i6/xo'ia SMbn P9•Invenlan•5CC Coding end Emissions radon vu 02 Max 502 Bemene Toluene Ethyllnenzene McWa Mettanal Me+optar pmlo untrol IUM Eraulmmaw 54 bMMscf Bum. 10.1sR.umtl h/MMsdsumed • 9 b/MMY. Bum. b/MMvcf Bumed b/MMsn Burned b/MMsci Bumed b/MMuf Bumed b/MMscf Burned b/MM, Bumed b/MM.f Bumed b/MMscteumed elMMscfBum. e/MMssg Burned 9 b/MMssfBum. b/MMsd Erma O/MMnfBumm Prei M/MMscnumed b/MMYd Burned 0/MMmfeumed b/MMscf.umed A.x. b/MMscr.umed ofsaua nacuntlw p rga gu, inlet gas end mi.,. whga prams mnpman. plat firm combustion The amisalans factor. mpaent. war,'iam andmamyu Methanol Storage Tank(s) Emissions Inventory Section 01- Administrative Information Facility AIRs ID: "„009(1 . . County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Sfrie {1) 300:harreLTat Section 03 - Processing Rate Information far Emissions Estimates Primary Emissions - Storage Tank(s) Actual Methanol Throughput = Requested Permit Limit Throughput = 5U Barrels (661) per year Actual Methanol Throughput While Emissions Controls Operating = Potential to Emit (PTE) Methanol Throughput Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of wastegasemitted per BBL of liquids produced= cf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 4;5001* Barrels (bbl) per year _ Requested Monthly Throughput = Ai Barrels (bbl) per year Btu/scf 0 MMBTU per year 0 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? E&P Tank Results Pollutant Methanol Emission Rate 500.51 .,l lb/year Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (Ib/bbl) (lb/bbl) (Produced Water Throughput) (Produced Water Throughput) Emission Factor Source VOC 0.1112 0.11. 0.000 0,000 0.000 0.000 0.1100 0.000 0.111 Control Device Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Methanol 0.111 Pollutant Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Produced Water Throughput) PM10 PM2.5 0.0000 0.0000 0.0000 0,0000 NOx CO Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) VOC PM10 PM2.5 NOx CO 0,25 0.25 0.25 0.25 0.25 43 0.0 0.0 0.0 0,0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0,0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Methanol 0 r 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 II 0 0 0 0 501 501 501 501 501 302 Barrels (bbl) per month I 52 of61 K:\PA\09\09W E1136.CPS Methanol Storage Tank(s) Emissions Inventory Section 06 - Re: ulatory Summary Analysis Regulation 1 section'il:A:l -.except as provided an paragraphs 2 tnrougil.b below, no owner or. operator at a -.source snail anal. or: -cause -the emission into the etmospnere 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 visibleemissions measurement is EPA Method9 (40 CFR, Part 60, Appendix (luly, 1992)) in allsubsections if Section II. A and B of this .. regulation. Regulation 2 Section I.A- No person, whereuer located, shall cause or allow the emission of odorousair contaminants from any single source such ant* result in detectable odors which are measured inexcess.tithe following limits, For areas used predominantly for residential or commercial purposes it is aviolation if odors are detected „- after the odorous air has been diluted with seven (71 or more volumes of odor free air.-' - - Part A-APEl'f Requirements Air Pollutant Emission Notices are required foie Individual emission points having uncoil greater than 250: pounds per year. (Regulation 3, Part A, Section 1 -➢3.b.) Applicant is required to file an APEN since emissions exceed 260 lies/yew of methanol. Part -0,— Construction Permit Exemptions Applicant is required to obtain a permit since ancontrolled VOC emissioosfrom this facility are greater than the 2-0 II.D.2.a). Methanol is a component of VOC. Therefore, all emissions from this source are considered to be VOC. Regulation 3, Parts A, B The RACE discussion is contained in Section 08 below. ctual-emissions any individual: con s rig -reportable' pollutant hreshold'(Regulation 3i Part B, Section Regulation 7, Section XVII.B, C.1, C3 Regulation 7, Section XVII.C.2 Regulation 7 Section RVR.A.16,: defines a storage tank as meaning "anyfixed roof storage vessel orseries of storage;vessels that are manifolded together via liquid line. Storage vessel is as defined in 4O'CFR Part 60, Subpart 0000 (February 25, 2014). Storage tanks may be located at a well production facility or other location- NSPS 0000 defines a storage vessel as meaning "a tank or other vessel that contains an accumulation of crude oil, condensate, intermediate hydrocarbon liquids, or. produced water, and that is constructed primarily of nonearthen materials (such as wood, concrete, steel, fiberglass, or plastic) which provide structural support, Intermediate liquids are further defined to be "any naturally occurring, unrefinedpetroleumliquid.". This storage vessel: contains only methanol. Asa result, . it does notmeet the definitionofstorage ' vessel in Regulation? Section XVII and therefore is not subject to - 3 , the control requirements of the regulation, As discussed above, the methanol storage vessel does not meet the definition of storage vessel in Regulation 7 Section XVII. As a result, the methanol storage vessel Regulation 6, Part A, NSPS Subpart 0000 NSPS 0000 defines a starage vessel as meaning, "a tank or other vessel that contains art accumulation of crude oil, condensate, intermediate hydrocarbon liquids,or produced water, and that is constructed primarily of nonearthen materials (such as wood, concrete, steel, fiberglass, or plastic) which provide 'structural support. Intermediate liquids are further defined to be "any naturally occurring, unrefined petroleum liquid." This storage vessel "contains only methanol. As result it does not meet the definition of storagevessel in NSPS 0000 andtherefore is note storage vessel affected NSPS Subpart OOOOa NSPS 0000a defines a storage vessel as meaning "a tank or other vessel that contains an accumulation of crude oil, condensate,; intermediate hydrocarbon liquids, or p oducedwatertand that is Constructed primarily of nonearthen materials (such as wood, concrete, steel, fiberglass, or plastic) which provide structural support'__ Intermediate liquids are further defined to be "any naturally occurring, unrefined' petroleum liquid." This storage vessel contains onlymethanol. Asia result, it does not meet the definition of storage vessel in NSPS OOOOa and therefore isnot a storagevessel affected facility. (See regulatory applicability worksheet far detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? ?,_*'•"'�� Ol;�°' N/A emissions from this source are not controlled. If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling 53 of 61 K:\PA\09\09WE1136.CP5 Methanol Storage Tank(s) Emissions Inventory Section 08 -Technical Analysis Notes 1. Thisstorage vessel is only used to storestabilized methanol. As a result, EPATanks 4.09d was used to estimate emissions from this source. The EPATanks simulation uses methyl alcohol (mo[hanol) as the fluid basis and Denver, CO for the location basis. Since the methanol is stabilized, flash emissions will not occur -As aresult, EPATanks is acceptable for estimating emissions as it only accountsfor working and breathing emissions. 2. Typically, the EPATanks 4,09d report uses annual as the time basis. The operator used monthly as the time basisfor the EPATanks report provided tin the application.'the monthly report provides ' methanolNOC emissions of 500.5116/year. A test EPA Tanks 4,09d simulation was nun with the report in theannualtime basis format. The annual time basis format results in methanol/VOC emissions 464.06 lb/year. Since the emissions provided by the operator are conservative, they are acceptable for permitting purposes. 9. Methanol is a component of VOC Since this source only stores methanol, the methanol emissions from this source are equal to the VOC emissions from thissource, ' 5. An APEN is required for this source because methanol is alsu'considered a flAP and emissions are greater than 250 lb/year. time an APEN is required for this source, a permit i VOC emissions from all APEN required sources are greeterthan 2 tpy. o required because 6. Since the methanol emissions equal VOC emissions from this source, the VOC emissions are calculated to be 0.3 tpy. While thisis below the VOC APEN reporting threshold of 1 tpy a limit on VOC was still included in thepennit,. This was done because the methanol emissions are greater than 250 lb/year and individual HAP Imits are not included in permits. As a result, the VOC emission limit serves to limit the methanol emissions from this source. 7, Colorado Regulation 7 Section XVII requires storage tanks (produced water/crude oil/condensate) with uncontrolled actual VOC emissions greater than 6 tpy to be controlled with an enclosed combustion device, This control requirement is also considered to be RACT for storage tanks in the ozone non -attainment area. There are no requirements for methanol storage vessels in Colorado's regulations. However, the control requirements tor storage vessels in Regulation 7 Section XVII may he used as a surrogate for determining RACi for this source. In this instance, uncontrolled actual VOC ' emissions from the methanol storage tank are lessthan 6 tpy_ Since storage vessels covered under Regulation Section XVII arenot required to he controlled unless emissions exceed 6 tpy,.this source will also not be required to be controlled for RACC proposes due to the level of emissions. S. The operator provided the following information with regards to monthlylimitsforthis source: "For METfiANOi, usage -is typically Lmited to the colder months to avoid freezing: This is in line with the monthly: emission limit tables which have been issued in permits for other DCP natural gas processing plants." Based on this information, it was determined that emissions are not evenly distributed from month to month and therefore monthly limits were not appropriate, The monthly limits were removed from the permit as requested by the operator,,; Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 140 Process A SCC Code 01 3-90-900-08 Fixed Roof Tank, Methanol: Working Loss Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons liquid throughput PM2.5 0.00 0 lb/1,000 gallons liquid throughput NOx 0.00 0 lb/1,000 gallons liquid throughput VOC 2.65 0 lb/1,000 gallons liquid throughput CO 0.00 0 lb/1,000 gallons liquid throughput Benzene 0,00 0 lb/1,000 gallons liquid throughput Toluene 0.00 II lb/1,000 gallons liquid throughput Ethylbenzene 11,00 0 lb/1,000 gallons liquid throughput Xylene 0.00 0 lb/1,000 gallons liquid throughput n -Hexane 0.00 II lb/1,000 gallons liquid throughput 224 TMP 0.00 0 lb/1,000 gallons liquid throughput Methanol 2.65 0 lb/1,000 gallons liquid throughput 54 of 61 K:\PA\09\09W E1136.CP5 Blowdowi. Er nlsrcn= Inventory Section 01 -Administrative Information Facility AIRS ID: County 090 Pl ant 141 Point Section 02-Tnulomenteescri000e Details Detailed Emissions Unit Description: Emission Control Device 0eecdption: Requested Overall VOC & HAP Control Efficiency%: liatoraf gasven91ng resaingftdm- the btowdown afpl7n000lvemand,pig faun0Jien. Limited Process Parameter Section 03 -Processing Rate Information for Emissions Es immes Consamsr R (Ideal Gas Law Constant). Atmospheric Pressure= Temperature= PHmary Emissions Number of receivers= Receiver Volume= Receiver Pressure= Requested Slowdown Event, Actualllawdown Events= Total Moles Vented (n). Total Mass Vented= Receiver2r 0150 OS) Number of receivers= Receiver Volume= Receiver Pressure= Requested Slowdown Event, Actual Slowdown Events= Total Moles Vented(nl= Total Mass Vented= Reeeiuer20" 250pelg) Number of receivers= Receiver Volume= neceiuer Pressure= Requested %lowdown Event, Actual Slowdown Events= Total Moles Vented ln)= Total Mass Vented= Rerelver 12'2750 psig) Number of receivers= Receiver Volume= Receiver Pressure= Requested Slowdown Event, Actual Slowdown Event, Total Moles Vented (n)= Total Mass Vented= 1b000h4C20"/00077$) Number of receivers= Receiver Volume= Receiver Pressure= Requested Slowdown Event, Actual Slowdown Event, Total Moles Vented (n)= Total Mass Vented= Actualmhroughput= I Requested Permit UmitThroughput= tl '-._10.7318 R^3'psia/-R'Ibmol Weal Gas Law= PV=nIT 35,48} scf 50 psig 0 00/ye 1.18302.707E lb-mol 114.1174277 Ibs • ts/year 0 events/year 71770040 Ib-mol ......3201'702 Ibs 250 psig 94. eyents/year • %'0' events/year 3.358018'57 lb-mol 57..^.124211 Ibs scf psig :970' events/year 0 events/year 505 lb -real 71111 Ibs 03.359'scf 250 psig 94 evens/year 0 events/year ₹5,9:118257 (bins 85084308 Ibs 3.13 MMscf per year ReeeiverO"/dlbpstgf Number of receivers= Receiver Volume= Receiver Pressure= Requested Slowdown Events= Artua101owdown Evens, Total Moles Vented In)= Total Mass Vented= RMehmrp' (250pelg) Number of receivers = _. Receiver Volume= Receiver Pressure= Requested Slowdown Evens, Actual Slowdown Event, Total Moles Vented (n)= Total Mass Vented = Number of lairnche Receiver Volume= Receiver Pressure= Requested Slowdown Events= Actual Slowdown Event --- Total Moles Vented (11= Total Mass Vented= Number of launche Receiver Volume= Receiver Pressure= Requested slowdown Event, Actual Slowdown Event, Total Moles Vented fn)= Total Mass Vented= 94. events/year 0 events/year 0.537110 lb-mol 7.423545782 Ibs 250 psig events/year • 0 events/year 6 Ih-mol Ibs 1204 poll 10//350r al events/year 0 evenss/year 54385 lb-mal 4:;9.54.35x8& ibs Potentialto Emit (PTEI Throughput= Total Requested Slowdown 14010= Total Actual Slowdown Events= Praces.ontral (Recycling) Equipped with a VRU', k VRU process equipment 0.0315 MMscfper year 04301 MMscf per year 1.152.00 events/year 033 events/year Secondary Emissions-Camhus0on Deylce(s) for Alr Pollolion Control Section 06-Emiabna FaMrs& Methodologies Description The 0700410 noed'11N0300 rc e 12/02/14000a0mabe e0 W ion533000 Inlet Gas Com Pehars,llie aperaforale 02.1015 40$ Requested Monthly Throughput= ingreeelveri.Vol 4.0100loelamp Displacement Equadan et. 4. MV7'lfa/c 0.7030 MMscf per month ggip Iaurschemhandlesmrddegss.Asafastilt;lh ptisstop •32033046,0PTesecg ewbaumfac5Ryan 03/91/17 eelreate emissions from Mole Molecular Weight lb/lb-mole Mass 16 Corrected Mass% Hydrogen Sulfide 1325) 0.W---' 34- 0.900000 0.0/4020755 — COl 253- 43:33 1,156037 5.320202612 — N2 027:-- 2102. 031730P.l5o 0.310001773 — methane 7296`-:- ' iS:O£. 1133235358 52,48621253 5757615321 ethane 13.09 :' 30,02. 053004043 20.4425$775 31.33615.1 propane 5.83"' 44,03'.' 1.37.573175 31.40100172 12.7467.547. Isobutane "0:25', ' 50.14 . 0.434:4143 /96620277 2076135:74 n -butane 1.69 53.86 1.04417205 3250551724 352127375B hopendne 0.33 7205 3.3806265 1213500343 1235025555 n -pentane 0.46 72:05 0.3941'..5 1.S0Yonne 1546218073 rydopen.ne n -Hexane 0,06 :. ..88 9,9511$6 0.200211.10 0.240341431 Cyclohesane Heptanes 0.07 - 100.2' 0.3724443 0.1VVbV141i4 0.3061770371 Methanol 0.00. 3206 -0.01111412 _ 11001020107 0.tiV37255 2 Methyl Meroptan(Me5H) 000 0.00024 65510079// 0.071116556 224-TMP 114,75 0.00017123 0002570101 0.072100030 Benzene 0.01 -'- 48.1' 20110365 n.0r12S0S725 0.050197377 Toluene 001- :' 52,14.' -.730'701&6 0.441110102 04011501744 Ethylbemene 000 ? 106x7'- 000321:.34 0.110950097 0.`01016502 Ones_.740 106,17 0.00154215 0.007015727 0,0.160$:66 CO. Heavies 0:01. 110- 0.004036 0331333578' 0041:014005 Total 10605 VOC Mole% 4.35 TOC% 04.04 VDCWtti 22:70752107 Residue Gas Comoo3tion: MW I 00,71130032 Ill/ltrmol Displacement Equaean Ex= 4' mu Mole% Molecular Weight Ib/Ibmole Mass% Corrected Mass% Water 0.40 '18.02 0 3 - CO2 030215751 1.55..14 - N2 6,01: - - 21,02 00$bt41e 0.43,1107 - methane 18:21 10.01 141'7'09117 77.17401 71.34113 ethane e.➢8' ' ' " 00,92 24�e' ✓1050A 13 7501 15.54231 propane 174 74.03 0.78773073 43]-554 :,300055 Isobutane • - 0'.21 38,04 0.1^.100:44 0.741503 0.175911 n -butane -- 0.4B - 58.04 3.'.3375'!52 :.536637 1,567729 bopentane - 003 -1200 606578105 0.550401 0357268 0,09 71,05 77.0683034 9:57:3040 0.381547 cyimpentane . 70.0 0 a 0 is -Hexane . -:0 Y3 16.10 0.03512572 0.21:171 7,210047 cyclohetetne Otherhesanes . 9:00 2-:--85.18 0 0 0 hepp000 1007 0 0 methylondohenane 0.00 -9&10 0 0 0 224-5400 ':6,09- -., 136.23 0 9 Benzene - :]8.1 0 n 0 Toluene "090 9214 0 7 tl Ethylbemene Terms 0.00 - 10612 B 0 0 CBS Header 000 104.2 0 -0 0 Total 170.80 VOC Mole% 271. TOC% 37.08 VOCW0% 7331303 550161 PAPA\09\o9WE5101.110 Blowdewn Emissions Inventory Pollutant Pollutant Pollutant Uncontrolled Controlled rommnt Total PI:: In; Emission Factors Uncontrolled Controlled lb/event Ih/event Prima Control Device Uncontrolled Uncontrolled b/MMBb W/MMscf lWasie Heat Combusted) (Gas Throughput] 1E! ayiq Y�',I3.�.+.•'. Uncontrolled Controlled lb/event lb/event Rt *Ver 2d" 850 lb/event lb/event MIUMMMI==MMEEMIll Pollutant Pollutant Uncontrolled Controlled lb/event lb event Uncontrolled controiled ,lox g«elver l2' 250._- ve. lb/event lb event Emission Factor Source Emission Factor Source Emission Factor Source Emislan Factor Source Emission Factors Emission Foetus Source Emission Factor Source ®® MEOMEI Po4mnt Uncontrolled Controlled Pollutant Unrom,nned Conssoissd lb/event lb/event lb/event lb/event MID:=M® IlliFEJEZZEBEIM Emission Factor Source Emission Factor Source Pensene Pollutant Uncontrolled Controlled lb/event lb/event s®® ®® =13==® MENIM ",741t Emission Factor Source Pollutant ®®i Pollubnt Uncontrolled ControlMd lb/event lb/event a.aaeido Uncontrolled Controlled lb/event Ih/event C.0af'.:Ca ®�3 Emission Factor Source Emission Factor source 56 of 61 K\PA\09\o9 W E]136. C P5 Blowdown Emissions inventory Section OS - Emissions Inventary Total Emissions Criteria Pollutants Potentialto Emit Uncontrolled (tons/Wail Acmal Emissions Uncontrolled Controlled Nees/yearl dons/war) Requested Permit Limlle Uncontrolled Controlled DB./Veer) (mne/yearl Requested Monthly Um. Controlled (III/month) EM10 PEALS SOX Nos Vac lA _ 000 an 0.00 aaa 000 0.00 -3.300 0.00 0.00 0.00 100 COO 0'00 s.xs a.bn Q.ee a3 313.87 G.CG 406 0.00 z (SW Hazardous Alr Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled Ilbs/yearl Ilbs/vearl Requested Permit Umib Uncontrolled Controlled Ilbs/yeed Ilbe/ye.rl Benzene Toluene Ethylbenzene Xyiene n -Hexane 224 TRIP 11:1] 0.00 71.77 7717 17.07 6.00 0.00 1TAl 17.0'1 R.i3 0.00 0.00 _ 11.00 _ 0.01 2.48 0..1 0,00 2.90 2.00 175.58 0.00 0.00 115,53 176.5E LOT 0.00 0.00 4.01 1.-7 .....5 Rere$`�2sivezo I>v3) Criteria Pollutants Requested Permit Umib Uncontrolled Controlled (mm/year) (mns/year; oog000ted Monthly tlm1ts Controlled (l./month) PM10 000 000 P.,0,00 0.70 0 SOx NO .00 001 1.00 000 0 VOC 0:11. 0.71 410 CO 0,. Requested Permit Umib Hazardous Alr Pollutants Uncontrolled Controlled (lbs/veer) Ilbs/year) Benzene Toluene EMTlbenzene .'.T0 es. 0.00 Xylem n -Hexane 0. n 1.532. .1.07 31 224 1EAP 017 IBSO psi •- - Criteria 00110anb Reques ed Permit limits Uncontrolled Controlled (tom/yeed Iton:/yearl Requested Monthly Umib Controlled (Ms/month) P14110 0.1 000 M12.5 0.0 SOx0.04BOO NOx LE. 0.00 0 VOC Lim 2.3£4 40'. CO CCO _.O Requested Permit Limits Hazardous Air Pollutants Uncontrolled Controlled (Ibsryear) Ilbs/yeenl Benzene 1115 1.1.45 Toluene 4... 05 Ethylbenzene 0.21 0.21 Xyiene is -Hexane 0.50 31.25 224 TMP 007 050 e000mt20.0250'001 Criteria Pollutants Requested Permit Limits Uncontrolled Controlled (tons/year) (tans/year) Requested Monthly Umite Controlled . llbs/month) PMIO PM -2.5 0.00 SOx NOx VOC L ra 0 C Xl 0.73 0.73 123 CO 0.00 0.00 Requested Permit Umlts Hazardous Air Pollutants Uncontrolled Controlled 110000®x) llbs/yearl Benrene .50 Toluene 178 1,70 Ethylbenzene C.u6 OAS Xyiene 0.413 n-Hetrane 13.73 15.73 224 TMP 0. 6.17 Hese Criteria Pollutants Requested Permit Umib Uncontrolled Controlled Imns/Yead (eons/yearl Requested Monthly limit Controlled Ilbs/monthl PM10 000 OM PRESS 0.00 410 0 NOx 0.00 VOC 5.1] 6.27 45 Co 0.00 0.n0 Hazardous Air Pollutants Requested Permit Umib Uncontrolled Controlled (Ibe/vead llbs/eearl Semite 1. 4.33 Toluene LOS Lite Ethyibeeeene 0.00 0.0/ Xyiene 0.00 033 n-Nelane 4.90 530 224 TMP 0.07 1.0t 33 ' 7 Criteria Pollutants Rogues Permit Limitz Uncontrolled Controlled (tons/ear) (rons/yearl ues` q Monthly Limits Controlled (ins/month) PM10 PMLS sox NOs CO 0.00 0.06 G EMU0.00 0 0.06 PAO CM0.00 Oki, kiii, 0.20 34 0.00 0.00 Hazardous Air Pollutants Reques ed Permit Limits Uncontrolled Controlled pbe/year) pbe/eearl Bement Toluene Ethylbenzene Xyiene n-Hesvne 224 TMP G:2R 400 Cu] 000 000 0.]t 0.00 6-00 11.40 ezo too Requested Permit Limits Requested Monthly Umits Criteria Pollutants Uncontrolled Controlled Controlled (mm/yearl (.0/Year) Ims/momh) PM10 000 0.00 PM2.s 000 0,00 NOx 0.40 0.00Er VOL 01.400 0.00 01 CO 600 0.00 Hazardous Air Requested PermitUmib Pollutants Uncontrolled Controlled P./T.1 ltro/yeer) Benzene 1.1] Toluene 0.01 Ethylbenzene 0.00 Xyene 0.20 n -Hexane 5;.0 .S.20 224 TMP 0.00 0.06 Criteria Pollutants Requested Permit Limits Uncontrolled Controlled Irenn/year) (tom/year) Requested Monthly 11010 Controlled (lbs/tenth) PM10 PEALS SOK NOR V.eIs CO 11.00 thrm 600 0.10 0 0.00 0,00 it e00 000 0.15 10 650 0.00 Bazardou..kir Pollutants Requested Permit Umib Uncontrolled Controlled 1./yearl lilts/year) I Benzene Toluene Ethylbenzene Xyene mNexane 224 TMP 5.74 0.73 0.S.0 001 0.01 Requested Permit Umlb Requested Monthly Urn/c Criteria Pollutants Uncontrolled Controlled Controlled Itrot/toarl (tons/year) Os/month) PM10 .00 0.00 PM25 0 0.00 SOx 0.00 o.w NOx RA. VOC _ 5.1.71 0.0171- - 1. CO 0.50 6.95 +) Hazardous Alr Requested Permit Limits Poll..Uncontrolled Controlled EM/y0.1 p4s/rearl Benzene 5::x) 0.00 Toluene Ethylbenoone 0.0/ _ 6,1//0 Xyiene 406 1. n.Hexane 02.50 01.00 224 TMP O.aa MOO 570061 K\PA\o9\09WE1136.CP5 Blowdesun Emissions Inventory Section 06- Rents., Summary Analysis Regulation 1 Section 3.4.1 -Except as providedte paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission iota the atmosphere of any air pollutant which is in excess of 20% opacity. This standard Is baseddn 24 consecutive opacftyreadings taken at l5second lntervab for six minutes, The approved reference test method for visible emission measurement is EPA Method (40 CFR, Part 60, Appendix A Duly, 10921)1n all subsection of Section II. A and B of this regulation Regulatbn2 Section la -No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result In detectable odors which are measured In ercecs of the following limits: Far 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 Part A-APEN Requirements Criterla Pollutants)for criteria pollutants, Air Pollutant Emission Notces are required for: eachtndivfdual emlsslon paint Ina non -attainment area with uncontrolled actual emissions of one tan per year or e ofany individual criteria pollutant (pollutants are not summed) for which the area Is non -attainment Applicant Is required to file an APEN since emissions exceed 1ton per year VOC -Construction PermC Exemptions Applicant Is required to obtalo a permftslnce uncontrolled VOC emission Fram this mc01y are greater than the ZO TPythreshold (Reg.3, Part a, Section 11.03.01 Partg%I11.O-2- RACT requirements for new or modified minor sources This secdon of Regulation 3 requires RACE fo, new or modl(ed minor sources located In nonaldinment or attainment/maintenance areas. This source is looted M the 8 -hour ozone nonattamment area. Thedate of interest for demrmining whetherthe source Is new or modified is therefore November 70, 2007 (the date o00 00ouromneooareadetgnaoon(.Sime0e pigging blewdowns will he in service after the dam above, this source b. considered 'Meg( or modified, The operator Indlcated RACE isadsfied through good maintenance practices, These Include the rllowing:'Best Management Practices Include proper plping design, adequate depressurization of the vessels In a am manner pdorto pig removal and appropriate reordkeeping of pigging %outdo., events.' Please see add,onal Informotion regarding RAC, the Technical Analysts notes In Section GS beow. Section OT - Initial and Periodic.amaiing and Testing Requirements Using Gas Throughput. Monitor fompl tan ce goes the company use siIspecific emission factors based on a gas sample [estimate emissions, This sample should represent the gas outlet of the equipment covered underthoAIRs ID, and should have been collected within modified (e.g., no new wells brought online( then it may be appropriate to use an older site -specific sample. application received date However, if the facility has rat been If no, the permitwill contain an" Initial Testing Requirement" to celled site-spedflcgas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. ySXg9 Are Wei ntywide permitted emissions of VOC greater than or equal to 90 ton ,_ per year, ,__„_„T If yes, the permit will conain) -AnInidal Testing Requirement" to collecta sitespecifie gasszmple from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application - -A "Period. Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis. demonstrate that the emission factors are less than or equal to the emissions ,actors established with this application on an annual basis, noes the company requests control device efficiency greater than 95%for a flare or combustion device? If yes, the permitwill contain and initial compliance testrondfdon to demonstrate the destruction efficiency of the combustion device based on inlet and outlet toncenhation sampling N/A -source is notontrolled. Seddon 0a Technical ANotes......... ....._.. _ ,,,.,,, i.Th¢operbtor used twpsrp2001egal forgses to deagf Ire 00101, M. Pccord ngm lbeappiiatmn. the pigging eesewesstandle fote[gazand th:leer punrhershanme ie idu0 gas. A5. esuit the opeatas used :stespecigcinlet gassampl0 from the Mewbovm fetiEW,ot obtained coo. -12.(02)1 {oesbmateeml3 anfromblpwd'o(vmoPpiggln8receye .Thepperat relso sadasite0 :00 residue gaesamptg brained hamttwMew"o::leer ilty pn 00/09/17estImato emksion from blaw{xvisofpiggingl nchers. Whits the ampins:re Ito pe 00e,they01.00 halm more thanano}'aar _ pnorbtheapPllca000 IdTheopmamris addrrgow equipment to thefaclty whichooWdka4 change m gascampas hon.. aresuR,2teyermh 0ll oegtmetbeoperato font d1.'nelza no es aFgas Ilia&5 opr sank{we.. fi iztgas mid residue gas. order molydateacoat emissions,the operator wlltnck the number of blowdo00 ven000002ated witheachpig e< ser]t 0,0001 rd muitiprytlo a0000bytim moths ion factorsdevebped for eachreceiver/Iaundier 00 it le emisvionfactomhavebe,0 comrertedtoumh afthieve. and are available for refererwe,otec0ono0abma. Thisspenfwtu 6reressaryhexause the bbwdown solurneasso.tedvdth each s be of 0g...dr/launcher izditfererrtandth20 the lb(eventemhsionfactorsareddferentdependingonv,Mchzpedfpiece of egoipmemhblowndowhT₹ereararecei0000 and la umbers that havethesamesize(.e. 760(010 (0owever, ire VOCcmnpositionofdhegasbbwm down)fomshezeO paaI 0002000 tlxapeodngprez3useadMeren[,00070 h0 ,0000n l00100a0 agate d4f ren2400,00havinglhe�unevoWme of Baz 3,Th¢aperatacexpressedthep g,teweherandpgrecewertoluroes wise estimated Using etrtheeerIng estimates and al0ilatrot £rpm- mT epnglaunchessa,rdrecehersInsta(tad tether➢CPfa<hites. S. The gperatorprovided-thefo1102,,ginformation o000 regardz00 RAC,': `oho would like tarnalotaIn Ooadvsork-0racbces/east Manag men2Pmcdces'azo200a00rw.thk perm[rtedldewhournpI ng 0pe ration at this point incline. See bebwfordescrlp(Ionvfeaa'tot mE5)35)PRcTterpggrrl S. The operator g with regards. 00 would like ta000000 ssor0aponat vesssh1na satemarmerpri0rt0pg1 valand ipprop ep00211 pingof pggmg htowdewn everts.":ItshoOldaboberated Na000, otColoadp,regal tons do no;address PAOtforhlowdownnfpfgging2EoiversandawuheRA22,020atyipiglaunchersandreoeroots:rooftenborodataiot,entpkceswfthm a fad; anddadelver[toacommonsratk,As.ases4l'{,common that eachpgoorro lerortecn0erumm,000 d.en individuatpo,Msourc eerdevabumd telY thiega APFrf ndpe applinblF10.0 hhh db .don 1141 2 mcervz would ....fedPEN.and pe: tMdthresholds1 t4 toy)'. (0,000101 w 2, tegwpme F0. pl CTfor-t tie I 002ere4 ! d com4psbon device. However, Re gula0on74ecbon'XVltdoes wtrequite(0,000ntrolurdessuro_ntrolled emnonfromtfie st 010cvessgliore gees[er{Hen9{p0,triWsimtance, 00000trolled e00 onso r, II tM 10 ddrersand: eoeivarsmmb nedar0100 thanstpµ Theo 20,00 iiadotrgyof grouyf. ¢. Hezeto ra aao r, ,o tyewth ego, its:o mndard pemdr ng'tltaU cos. AsaI I0R&Tgasonable'massume hat000trsl b0 0mtbe Fegoiredfoelhtz.solute, 1..40o -this informton, the Opeato s ssessmentahalgood workp cCoessebs1y NAtto,eoorepted N this iristdp.%. O 0020, thls:fautGegW(000020 0 e-aValtotedonor t,000lledem ss afyglncreaa000 /1(12 regu1a1iom are upda1e2m addre ss ddntial tequbpmenFstormalyitenarlaeblowdown. 5,000 pR¢mtpr prov de20200 0(1 polOg nfprmaitoS oLowhµthe ec 161 II res at thus fauhrywoultlnntfoe usedhnx ntrolt,u nghiowdownOro(oo ns^&ggm80,00020n des2Wd ,0000 C0eaussWtes nr000 1 r ssi a problems .002 1 010010 toth000rat Alewboatorte the Fatlfi2000wit0000dngeas000 layout changes,0, puntf flares could be wed to control em0l trompiggings however, was., scope thecmeemprotecb OCPlscutrentlye6100001 this opt on nit seeksro potentallyimplemeiit ewdfrfunia.madffiotfonzat Mewbourn.':'' 6, Monthlylimltswerenot included: mthe pe0ndtf0r this source because theevenh andenussians are not evenly Erstn00 led from month to month. rho determination's canzstentwitkthe pern0,0 0ategyforblowdowOsourees at other stmearfaulWess T rte I tga PI doe t Ird' h I Ii25 n¢ thy) apbpi th mml pas H h small mount latheInlet gf achpolluk 67(.4 enough make mission glgtbk As a lr the ca[culahon of the musmrob he p ll taritsa t deluded atiy„,, An e09 Piet I01rmnrrme010101raPtnhas l0.It0ws'100o110T%1/100(1'11400001bsla(54 evenh/yeal (000kg4Yb11110010(099.300000(52: events/Ve001 (000114T%)/I1(0(1q>24 lbsl'190eVenhF4aarlt(OOa11A7%1/10 (°2(4010.1(¢4-ements/`/car 17(0303Rd%Ii(001''(YAO lh..(0(002 even/year)♦(0A01140%1/I300('(3511bsI`1376eiorh/yearl`0A0Ibo/vror The compositionsnNOS and methanolmthe In let lAsaresmaller than theta methylmeroptan,so the eiultng embsbnsaretowarthadihe prnvitle00102(0001 . Secdpn O9- Invenmry SCC Coding and Emissions Factors AIRS P01ntg 141 Pmcessq of �t�,go�}t�§§RE.de.'B„„IN9tn3d Pollutant PM. PM25 50r cox VOC co gem. Toluene Ethylbenene Xylet 0Resane 224 "MP Uncontrolled Emlssmns Factor 0.00 OCC 0.00 OOC 0.00 EISA0 440,.56 11,15 33,33 4922.17 010,1(9 Control % 3 0 a 58 of 61 00(1*0400000 W E 1136.015 Perna. Po im Permit Descriptio lune 26 2012 NINnng Nibs.. at 100.,9ingofcvnem930.0.ouz period) October 6(Project n Contemporaneous Period) Pe I loa 6'1136 Engine 102 00W...136 Engine • 054461136 Engine 104 09W61130 Engine • 09.1136 Engine 106 064061136 Engine • 094061136 Engine 108 09.1.6 Fugitives (VOL only mom.) UO09..6 Loadout 094/61136 condensate Storage Tank 111 4.61136 Turbine 112 WE..36 Turbine113 09..36 Engine a mw 1136 Engine 115 00€1135 Engine 116 09.1156 Engine 7 030061136 Engine 118 09W611.36 Turbine 166 09W61136 Turbine 120 09W6.6 Amine 111 09W011.36 Amine Unit 121 09W61136 MG Dehydration Unit 113 o9waiaas Natoli heater Permitted NDa(tp11 Baseline Actual 6 n Project In Emksbm1NOe1 In 5.1 2433 2141 0,3 033 3.64 2.14 032 6071 13.14 11.44 11.04 .44 11.44 1612 137 8.12 124 09.1136 liegeneraNe Thermal oddkzer 0.66 — — insiNifIcant Sources 014 rotat Total Point Permit Description 101 03W61136 Engine Engine .103 36 Engine '000.,0010100430. Engine;_, '!iffi 09WE1136. ;JINN los 3136 Engine x317 091113013f0 Raga, los 6 Pugt.(VOL only mete.) 109 09..0 Loactout 110 09W611.36 Condensate Storage Tank 1. 09W61.6 Turbine 112 09W61.136 Turbine 113 09W611.36 Engine 114 ll6 Engine • a9W36 Engine 116 011Engine 117 09W611.36 Engine -001 001VE3136 Tuzbtne 4 115 ° Warns Turbine 126 090061336 Amim0nit 121 09.1136 ANN; Reboller 133 09,061136 0030ehetea4on Umt 123 0061.6 Hot l:Iheater 123 060061136 Po.60.,3tive Tfmnml aidfzer, 126 0900£1136 BeckeNtle001mldizec tenIgnifiralu Souraea 1619 Beal: 00096104 114 Baseline Actual Emissbas Project Change. 5.1 2433 3.64 062 0.071 1144 11.44 11. 11.44 38.86 064 6.12 8.95 298 0,67 • 2495 Paint 6.0000mn 001 09WIi0035 49gi11- • 001 /100111/16 Rnelne 103 09 6 Engine. `rea09WEN.36 {36 0014E. Engino:, 106 OSW€1130'. €nglne "DT 09WE113fi: Fugitives Ms IDS 03WE1136 s NOeonly sou.e) 103 09W.136 apeKdouc • 116 09WE3131 Cwidbnsau5fnngaTeuk k 0961135 MWns' 13 0900W&0306 T: beer 114 0.61136 Engine 115 3136 Engine 116 1136 Engine 117 C0W611.36 Engine 0124 09006013 6 Ttnhln 110 6 Turbine 136. 0.61136 Amlrm UniC 121 09W61136 Amine borer 3.e *MI6. TO ceMdraavntlna • mw61136 Hot oil neater 620 10061136 Plant9Ure .3.M ft- ?e.Xadgeziayw 6 Beek011103rm210340101 a: TarMn 6 Twine:: • TEGDenydmmn HS 00WE113NeturatUaselmd Heater "133.:'mWE1'148 401 NI heater 190 09WP1131.. ccndenNiN6Mtent,NN Fugitives (V.only amt..) lab O9W3136 a Ga1Ebre ;1303. 330101336: Maori, omn101101rare Produced Water Storage NS 170060517 Vessels 139 09006.6 Pressurized Unloading Sao mwesi36 Nateral Gas Venting from .141 09W61130,Pigging .— Imlgalfiwatiources �fium Tod Permitted RIDE 13.14 13.14 11. .44 .44 1144 16LT8.12 1615 1613. 3.25 16.05 0.04 6469 et Teal 33'303 3 is 0.43E 248 Combined Protecti0tal: xe tneNM. Emhsin (rvOa) - No change in this monmcadoN No change in this modification. No change in mks modification. G meiNion,0533/2015and remrvedhwnseritNetta ten LINN Gnmlfad gin mtfl/2014rW eedmeed'fiom setra t.reerieM 64000)0001. No change fn Nis mod 10on. an«ned' 0,32/2615_ a.lem,year =d1.nmw bVt0C7.:>: , .. Updated fugitive coent andncrease ernIssNns. Fugitivesare notcmmted when evaluating major modification No change In INN modifimaon. No change In this modification. No change N this modification. NoNange N this modification. No change in this modification. No change in this aindifiwdon. No change In this modifiesdon. No change m ads modmcadnn. No change In this !Nankin. WItlpain .ONcilimeaseetrifssion fine Cunbine,thpom ,1 an asembdon liners Poe Aided dew.. RlOandVRtt- .. ... No change In thisopmodification. 0etmetethrou0, iupdatnxenud Ee (az 1,,100edby'Iil.atii103 tit siv01010)a2ecunA4 comb ,1011 f Yr:zen[etnimimsta.000704inectiee iNet0100.1043119.ZtdllrC1040 .. ..:.:. No<hanga in Nis modification. PN0carrcdled-emlafansaltaw0,34mindluiduatscwcssmn0dleahymisspu 1 0101 '1031310 eded 0a4eer3004.1.*.,Acsr R hsaw1310 1 3,.' III greet d.erhe 3Mm100011i) N6306330.401,111 "1 003630d.selmineN tit ho. the bhnmeteee. l'o d e:..dnd: 10 111 13 3 6,8 31 13ttw113131 013 343htiunaimhs 0 00143 111130 0T1at313 0ncum0X.5a4t$ 900101 P70 theaCtInsithemiNettateattitto reet1na0600994a90103 tt -. _ 30031lddprl3113133 11330903<E00030 a000101100404Pg0010 4 r,; Sauce ti0.mdtio1311i06.p.mne Ix..emnmrma. e6ameNetnertinttatiltileteNgventeemiettdott. t.9tada-mmugie u.01,1.ns 3esaud$crw;guw a1010,.00uneem' 'unfelt ulatbn Metlwd 1Mine 3300. rc pe d t 02 11.4rsto 720h Actual M- VP n«Motion teeniest' 06/04/10.001008 o longterm. Ne Nall Actual to PIE alotan received 60114/ 6.5ou eno.6rrger eatsa[m&fa — 060040 33 OWauNd{,,intf0ecatoteetee .11 3 0030 ( lualmPTE 0300el14 9received 11416'B+S0110 I 9arosistsatih Foga. are not counted when taekltedarrd-a�mamea ror,:;tkGtam36v 1.. evaluating major modification thresholds. DeNease ram;netted Neoughetit inclbd !INN onassfatgasend.36340010!004p1119 210. Inceeede,e:ttmm01213003 In0Wmtsetareupand shusdo11es,upd23 ,033.9. 004. 110 NONNed stan-uaand Numawn emissions, apdateptecrosiftnm, - o change with thka modification - No change wish Nis modification - No change...modificamn - No change wlNNe modification o change with this modification Actva441lutmzdm edsewpaehuzdownemlasio,Updatemues.Attc m aem11>1E0 0' xjudedsmlhufdrrr ounnaions,Updssp: eaesiimits. Aimia4mPTE' ..i. UptieWedntte0eN0e10a. tzN[€sse suPPiemeet0 feat M10..:,;.... No change with the made,.401 von Aea.tw- POµ m Update. ntrpfscene1l0. Laiculate emissions using ere1Calc Nit n nae.th t mac ficadon fedanc eccmznted eonmto the-3016Prolect :23000 llmltdromommMurto.W W MMsci 6z6 al an.. Soar.. aaaaalrad ctuefem 10.raaanimm.aeemb.rlBls[d August RD16.Eiao eme ddcr1 330nwngne ye®36WtiK.. New iaBma:_. m PEE' rD P: increasehkumbn Melted Remark. 0.3014t3PT1 h013111 PEE" PTE Pre P?E PE • Pi6 P3E P1£801£ New Soum-Eu0003 are counted when eva0va majormodificatl0 New:smreeNew Sam. New Source -004 Only Source (emissions are not name:A41 9.003006.920! celled piorm enmities -Liam,. Emlssiarzs are now accounted for with imlen1ficant sources New Source -VOC Only Somme Newsouth-VOC Only Sour e rls a edk(ttN lal i ti r !m fie g _ d -1 aazme Cornpllan.dicter'ott.ftenetCOCIL focCase N05.101,057,101 .alit W(30) days ofth fr ve date of HS Consent Order DCP,M1 NPS Paints 104.405 and 1.07 ft.... and Me caqtaliatdahrwtke to confirm he rat remenrof the pontstramaa,aa 'He COewasagaed byth.Ovfgon on 041fa01S,Ths date ztbectactta date of the CO[ TNe englheiwces buquencfartara.<Iedtm05/b4f4 g kd„,,,,„0 t an IAa.bii9jpmvk¢5 Nefoliow gv+f«mavvitwNrgrY ee_aewa emsz rtes Tnezreag rate hap be adjustedpaoanWard toe any emissions h we have exceeded in emeslonm,anwehwh,hh rato-wny sou raaaa• de Uysompry,htlthemafars [onetysmrtebeen <quPomaompY hwchbtnlaclaadm(s U+e''"''twtwerytour nom pe od owewr. ("an 'vs a+ ar on zparto maasnnm be ccn«ot.W ,I5 le:eandardm h,, ed i,U,,,atlonuvmbe,a,meeasNlneaetm em[zsassneldvMybeacQ oared ifNe sate has token cred't tar such m suonlieairatlanssAan attafoaahh0ama5ia0aa arm n nanevp}an 000grhaeyg eaweta,e9V ed obe+.moved hecoctKecocda mabsnarrzwamsz d mlethaaaaroginasneedadc trios t ga'naingeh fd15 Based pelt d.purmanldl Oeadahas,eznd ec hat ed e s ache edbmtsaraUaaapaa gzahertlteoffd h otN.coc cf.a y,3he[oc'dd.s adz yzam h Iof theengaes norbeuaed Corfu etefngawlysex atthe Cal Rrind' h warmn;adawssed perodof hef fact the was demrad h s,he.m a:and. a am w-o(the eng u „ ra downw.rtl ( t at of actua on,ihe •aperat Iculananof bas malemfaimns far the period of a5/3011 OB/S033 as mmed ahta-nthh lrv[ar�cem�e L me[DnaemDor a us peaoa uiedfa thsanalysa x09/3 ] R039 '''"""-''''""'"'"'"oar' r044o Dendd,tw p o boar pAt. p p;h pe Eedon Ocmber 211016((1 e3k 04e.econ`dD 1 t v b0lp PPJrnt Issued 'en idol , ao Iauanc ) tea theomnenc be abYM Amor., to Pega b(M'p?r a regalateduabparean uldph em nzf« h ,sshena d+angm arbd<an',used for n egtlhte hSRRvaut r makev tmia thsdeiln:a n prole. ce.rcer 3sotem -a Here o*4 proles ruafem earbM deters kbnda.pem b.ueagsslonb ], z01b, haopd,:a ualrmaatw,mj) urmrn hpp adsgana ng oms.papmger3 a A a3�er 44t3. tunas boa acma.m swnfn h • rmm pro,aa, be x am bon d enty rodrmo dad apanAdg/ ms¢arema¢r zo sodagasErntgf« a termuingbxael et .mss. rtes; 1] ,0,,,,,,f, adlRcativai. y •olla, 6 u «n hedena uor,ad ooldhe latedab .1aa, ( _ Jaavl ( arl (i .09 naa2mJMMzcf(i0-38 b1TaMb ul f- n/IOCOltii*,[O.Oarz3hotd zlpky115 dayinearl (]-9b bahgtq]MMae]•(413a 1 savnzervat,aan ha wuecalculamdbyM «raaoyor h zoarre1l-e[Dy1.A. rec k,h opes:rod Iculaavnawere deemed aosia.Forpell Otis orp eheevaluaa • onznganalg combustion of pema,o 1pe, pylzezl n'n aa, ngzof minis vave I deemed to.... For mtationapaz sandN sprint. of rh znca ng adalysz czharld be further no ed l,aiN o .dowl w - ghom themnbust0 of ydiai oq n s Il vent wdste Baswitht i ▪ Iairvm PS day, of opetai of Ne tXerma ovdzer n adtlDon ....clays afvpeano as ar-0for Id512oisMdladon(,Rnsed ehe aaahp¢tmthp ro dv Medehydra stlivent andflnnnkandam,. ankar-az edto hava5%da Ime Ougtiffs d roedtytheflanaa0a4ed asedanitnalnfoamatan, the toff i re woud h. avatedlas follows, 11 AarneRos (avast., I/aavi l3ssaav/ve a (x051 33.13 n+af/venr,l loahydm or vent ( 0,ssaa 5aapahf/dayl l3ah a.y/,earl l oat_ b312ssM /yeaa,llloanya o ,,Foams throughput andaaorcesrouwd ass am ''. (00f9va/haaa l l/(3bodayjyearwadJsa l64asnnhfzcorha.eazed nnfiei lhlsdvdonz the tans vaume routed to d.rrden,Tary as aareiaw mevaa.34NarN ms«sbased haimaron. uaseda rely (1'?33MMscrasan,,„, .IMMbajh shpla[OOsB lM Ili m / ll [( / 1 1 / 1 ( AI 1/R / 11 ! 11 a Ig M WOIU 11 ua afazt Mtsxt(¢enr py larwamgezrmtad thefar oil,Neu values red tradi culad edee N.r,V. lyafH. ✓rJl�� s. ihroughoucM ad sat Nlgappllre n,there wereseve P drharrequ red n nd he eabotha company 6 to wth-Nee vedinae ardsManager.Howe gnitkant Items d,atwere' saad, 111 .he rc atedhere Inca lyxla,Thedeseltem, was the PTE toe'IE halo rused for seve arthak by netnen r¢ 1 oi/her�: 'In h e rh,aban Tha /insn sal ranila ehaadldsalneamaemdlnahrdaaaa dme reclirested'asebne penodmeeemd expressed d- years -of actual emzs,on date rtiwuepersnn!4ms twasargued thatthe abaasaeof«rmt Inn. dad notlu:aNNeassu p afporanaale • cm pea. .M1nuen dh e4 N M1adal gt d f h de h 'se f - ( • N W k.d zed M1.dhl dd embewn eirnt a.crii selo p<rodq gr,Regbalasaap OSe on lA ,endrl spas des oaarasdgn dnoaateed aE foll rn<0 nmay M1 dcalowaalee £r MeurR�a • statues t aoaavhe 2onl41f aat[�{FeeM ( wtbeaerertnnhlaosluantea5ietlon a,above"and"Forarryemisvfaysn sertor to atbeg • rmalgpesaton teciated lartla:he ma.nazagns;nlqual Nepote cal oche ro:he -id • arwlvsdi theopr or gbaaad do nhlon ntml Wec angeeforthe haasadand dehydration [aiNehriryauow<dahe operator ssum<theFlENOv miss gnsazttrt ted wl ro,he on Ttvn7a arm's ass Ntlia aaeradnbamdorWu feu Nas nd anhh emadahpshandod [rvovaem sslomdinrtrg Ne sek sdlsom lircpeaspa n'u mnew «tea¢dwidirie «vfee easetlanahelnf«madonp:axdd no h fi,d 1 Ie.. f Iap bait, to df A ry d b • h du fie ktl thud -:W dl 1 ! ( Jte ax unedtafiasra2snvralreaird«ao acaraanadecreaseM ,Coed's' zdaaa ze Tnesdd 1 utedamaafe hsdaCLm s3lbd a Paws rr/hn(gxedudara n phhata m m101homgl h u rao add ae twos gnpur toad,, daaavnstpaacla}}tam9 a'bl,yesatoasraiaadr,ab oy mafabahh!31m90 MMsca. (vl paste mad. hasaharaao on5yl5sartupa5Fbzhutddaa/5asparrts]leandii4 t41Mtnexrequeaied reduanars,Mene na5ysvaraulted rte da! zwgF re studansaas Rz nbsadby Rltmt[haffasbs00rinaaseaefecad1nrraaepeanaaps ev <wre dpptin h de Uhauonnrh als.a.lable n aanagertedemssoraesceeded.A p t mrts TFe:e re sFeredw N peamrandt p apcmp:,.ia v f ed N,.att E ma�m,sdownroN perm¢sm z.az req reaW gal cPSectivn (fli.b 111}..TIu ge atan3 .spec(&,urv¢w whghtNU aDOtlu tp'edntne ma aaable� Rec.., Manager. 4, The -follow atem rahaned em nthe n arysis„p Eng Ines N�U)Eg exedasdan .301 wazNme IIOHaursperyezr. l91(Thedabsdadvn order mach( Ted�zuah that 9.of emlss n e eaydedmtnap n pv)hacreas dfirougoau fNe adaou[op. n(pafe nslfvl ;tru/hr. (ad . Pa down ospdntvai;(aP/ erd hutdown even eachfarboth areas 3la and]3R (NI YP,fiwe h nglna lv q der«eez:Y f r sdlbaly.ar w N d ntheanalysfd' 1rve rhea aaa,a as ve ec smade'yNa per de tR n ,....pnojectrernalned below0tpy h Itl tl h d P ar f nv g eg .h rt _ ruuti mvrez Coale m_M1 .e as Noaliaa's Neop s q f dN arzl ernissi«ahamfnignw aneadoa further begfrwa d.054Chat gn(gnrack naE I wacaeaginoa hoahoamt 9. ours the selected baseline perfads(ae/213;fo1i/10]3 d03/201aana.4, 61, there were aeepyzumadRatanz.atre tacky. T.: base,. anNear.,ges raccu m ss,nnce 1.o-Lssua,ce ct the permit As aresufr_twasgss.rnedthat the baselineacrual.anczs.mzaluelathefns,111aas old mflegtbesamewlaz bath praleces hsl ed rho ea rkfa rw <rrla rmA.a.P:z r>v adds rdp1 d,a Olslrhan In tM1 lerpreseniedIA h prject(gdE5ept'2011 mnay013) riglrraipermit Issuance apolddarr,aeda more ',sumac," eqp entivl Mort the as bvrrtapdatea a1 eel alliNlMz vaaul hov e beer documented vs port of rle.ep g ) e bydefrnlhanpamr rer,tp .fare a arc doesn't sanity aurb«rsenewer updated insyiasbh app. azajoc v. Moreover, rte appl!remn Ceuta ndeptem8r sar wdej'kdin ano1015*d,haane«yrrci,de vA N the -.f 7 he a /Me F. Ir rh t umticasbaukbek C➢dMtwepr .ual n 'ao r g�z darat N .r.N e the d'fto. n baseline -ale i4sFtw1 rtus..gthe fa, had, per or&(o 15 1 - ...rem., F4sZ vdthd: d method, calculatao,he OtFtpy � od 5 t stacfent dam at thre and the dIfference dlea Ilt,S triggermafaraowc thresholds. the', sartels tloM1,011 basaep ,m due palresfated �.,. e. th , m! ry l momma rtes e 0 p for source Perot Perna 086814tIon Permitted V311061 Noel UPI 105 106 108 109 110 112 41, l 0I00n9 emissions at 113 a g contemporaneous p od, 115 116 117 116 119 120 1.21 122 123 124 0918101136 Engine Engine Engine gine 0918,16.6 Engine 09.1136 Engine09,91136 Engine 099.46.6 aglW.g)N41w1source) OW91136 Condensate storage Tank 09WE1136 Turbine 091.1136 Turoine 05.1136 Engine Engine 09.1136 Engine 09W611.36 Engine 091891136 ,nee 03W611.36 TEGDehydr09,91138 Amine 09W61136 Amine ation 816an Unit 09WE1136 Hot oil heater ve Thermal Oxlaizer - 166 Sources 3.19 .17 14.27 3.64 7.14 31.73 2.41 1.29 OAS 0.02 1602 16.02 16.02 057 0.05 8,43 1.49 12. Tato Prorect Change emaris Pa IISLIAIRCO 016(Project In Contemporaneous Point Perrna Defedp4en 101 00,8161.136 Engine 102 09.1136 Engine 103 09,91136 Engine 504 099.1136 Engine laS 091511135 Engine 106 09961138 Engine 04W41046 Engine 142 108 109 110 114 115 117 1]8 1. 124 121 In 123 124 135 6 Fugitives (U44nn41oupa) wE1136 toadout 09.1.6 Condensate...rage Tank 06.1136 Turbine 09,161136 Engine 06,91136 Engine 091191136 nine 09,8161136 Engine WE1130 Engine 00W42133 Turbine 00WE1136 turbine. MOM Amine Unit 09.1136 Amine lieholler 09.1136 PEGOeh4441404 Unit 0696 36 Natoli hearer 00W611.36 Regenerative Thermal Oadizer 099.1136 Pant Flare 09961136 Acid ge5[Ose:l[' 11464414444111110)404I061 Insignificant. Sources Sources Total EnDescription 6girm Engfn. Engine Eigln :b Engine 6 Engine 738 0991161.6 141 -Mmes WOE crib/source) 509 099.1336 boaddul • cendemattsmrege Tank Tit 069.1136 Turbine - 112 099.3136 Turbine 113 09..6 Engine 11.4 03WE1136 Engine 115 09.1136 Engne 099.1136 Engine 117 091.11.36 Engine 313 09.11.36 T[nvne 09.6116.6 Tuchine- 120 09.1136 Amine Limit Amine Peholer 122 09961136 TEG Dehydration 044 dl..Er 09WE11444egenti0WeEPernroi 04W51036 Piant.tare 136-Andgestbvend Permitted WIC 3. 14.27 3.64 2.61 129 0. 0. 16.02 16.02 16.02 16.02 • pb8 19 I WaelPie Actual hsions Pope Chang..Eme+nm(v04 !mamas., Calculation method 035 0.30 339 459 328 Torr 0.02 8.99 Penal in PTE Actual to PTE Advil mPIE Actual to PIE Acadia PTE Actual m PTE 1120246 No change in Ws modification. No change in thrs modigradan. No change in Wlsmodifiotion 404002640104202/4012 and removed Poo caprice (61480 lre420424). Cancelled and removed -from service lw 16401edb09041, No change in Wiz mom0adan anGaa m03j12l2f15aM removed -am ...lee tw has required -4 CACI, 50. o dlHaentE5 during bpe dal fugitive count and ase gelM1 shrl ... Updated ma nmdee em mm. Fa®w are nor counted when eaalwpnemajor modification No clunge in this rnodlEudion. No change In this modificatlon. Poo., in this modification. No change in this rnorilficatIon. No change in this modification. No change in Wiz innd1Na.op No change in this madlfiao'on. clunge In Win modification. No lunge in Wiz modification. LomWne wish pains 119 and ineeaa emission imim Comffne m140112nt138 and increase errdvio16 Plinks Added dew8dme tor Rio anciVRU Shine rellecuNiiuentmmmhkdbv NTO.etiNoemsordtoatmoephnm 601 and flash Unit cona3.4 No change in this sethroughpueut pdaie trot deicesfasraqu4ed by404)-2v8ue0Nezts00mhwtlonalatiltvent Pry. WI and fare and combustion nt0zhbnidy.n. Does not include 0.A9tpy...clad 'WIPED minhinitionninunialeminunif.. No change n this modification on - to mdhmiaP sources controlled by this source. (PDC minions wan never dulated fw WIT istributed 00w5 100041,4 de puae.piata04 ba.04040113 Aare4 Sacra vaswwWped Iwlgnifiontin Previa. issuances ofIlui nia. Undkdwke[o33013as3709.4...1.753.3.3tmced117,. 71.33llQ -.. ice 45rmit I6Efirl1Oeemce includ 044080iono6zsppremxmifue2TE64Ullvnrt wmbuat0nl6PWIWIarW amineupnalliventwasups4wmgprhnatywnimldwkaeowmimc, Pe lu v ld, 2017 and Current Project 527 526 129 130 131 132 133 194 135 Lodi 33] 1.36 39 09,40105 164403004011161400]409: 09.1136 Turbine 012229034 Turbine 499.143142E 48244raecn Unit 1136 Natural G.Ered Heater 000WE1136 Hot diheacer 9WE113014540.s41042020 Tank • ugimrer 11/GC only source) 09WE1136•Aad 0fiam 099.1.4 Mewb40oum 111 Plant Nam Roluaa Water5[mege 17WE0F Worele 09W61.6 Pre:sorbed Unloading 099311361.31.7 W5tonagevessf Nature! Gas 1040 from 091461136 Pig6Nng.06740340 -.. Insignificant Sources sad WC itpyl Baselile AxIIIII16111,1806[ Project 0.26 216 — . ... 3988 .� 11443 25 128 139 .33 0.88 .4.3981 0.80 AAOS 16.02 16.02 16.07 02 0,6 4.25 9.02 052 tee tot 022 an- LBa 300 26.33 03 5,65 0356 - 0234 ssas 559 0.006 DS 05 6.99 1.29 1,1 3.3313 0.38 A"2 3.73 1.33 733 13.13 317 Net Total, rico /WWI TPTE 433313PV£ Actual to PTE Actual onPTE 0410,144944 AN31 mPTE Actual. PTE Actual WPM 02Na10940 PTE 5E PTE PIE PIIE PIE PTE PTE PTE toPTE Limit ion from 37601.4.0Conwit,20 hrs. 109104x081 received 08f1410e.6omce nob94992 9841 he16criPP Canceling. rem152841414N.5wn'0nolm64444 tsazticehtllity. Caned00440'aocounteator13040,e2003incis04 09142dan9avw1401/0/10.444r04011410401 r�.'.. t-arreibdon rece(ved2N)131x&source nolongeredssaT4.1148W iWinteinidEndinccountedTior wink Ww2U160WPEiT uginves are nor counted when evaluatingmajor modification Wr0hdds. x0 0rezm permitted Mrougbpue lnclWe hold on west gasard'pibtrvel. bureau" permitted 311006440140. 14tludM 6brc-096rds2u1Gnwn04)81440140daa 4aoass41100. included surtrupaMshotdoonemisslaru:UpdatepmxsI1100. No change with this modification No change with this mannatlon No gee with this modification No dangewW this modlRmdon No change W.I. modification Included startup and shutaawn emiszbns. U plate p mass l)mlts. rocesiimis Updateentrol owned.. lncreasesupplememal Weibral No gee with34 thism404101on Update tontrots... Ceculateemrolon4 SnNGETCaic No change with Nis modification Inu perm064810168040010;20000001/000940402&011104/108 red accounted 00116006646080.0000111001011112404004641093104481414015104602for • d dasdlrcpedod,tpe0puaa[ zrq[dklrigaurvaedlttar thb Madge asodated tleNne . 40]3444049044]0400446449000464102944414044 - IbooSource New5ouro PrewNmuSource ource New 533.3 Newera New -Fugitfw are not waned when evaluating major modidmdontM1rwiwltlz New Source New Sour New Source oncelled prior to Mt (nuance. Omissions are now accounted for with insIgnIfIcantscurces NewRuru-WCWW0uaa , blew 54004 -PDC 00)4500,11 eali�gAw ' S.P0110007(26x02104,Ca2dpl:t vaneI61.79)Nh[F'70,0)8 300w, spp-tammxedaipaftMxvaal mF 433375.5 ewiaetyattve eaAmb5e 2'ltieopemm<sennIndoh li 3.4333.71130.337.3ninifiediii ;uad210414 4)093435 Combined Pm6e TORE Weaambus 332224akWatedas, idOdcSBAmd40 appiemerdalvelazulnmsii8fothow gtNsI 14000.AddRidal04,the31100040idTedp 4m 0904444030903,1041004 orgee0' denaln1abat2.perainteuiml§ mreud4ed Wil.WCrlett )Ywaed�dg6ramhmmtiortwtlirnasbe rmmn403401e 11.02157 E'(1-9Gily{003 (1WOItl1 1.Y380ylb7Ga1 4444044140041141d ma10mfi4496 feam449 asu1C, ICwwd2Om6421104 ab00kfumAi Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit_.. All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your /TEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fea. The re -submittal will require. payment for a new filing fee. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be'found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 AIRS ID Number: 123 /0090/101 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: (Include Zip code) 370 17th St, Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Contact Person: Phone Number: E -Mail Address2: Marie Cameron (303) 605-2029 MECameron@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 421988 Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 COLORADO _ 1l I„..a AIRS ID Number: 123 /0090/ 101 Permit Number: 09WE1136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name4 ❑ Add point to existing permit El Change permit limit ❑ Transfer of ownerships O Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: Reduction in C-211 engine operation to 30 days of operation on a 12 -month rolling basis 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? C-211 If yes, provide the Company Equipment Identification No. C-211 General description of equipment and purpose: Natural Gas Colllpression VP‘‘) StivviC. For existing sources, operation began on: 1987 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.gov/cdphe/attainnient) ❑✓ Yes ❑ No Normal Hours of Source Operation: 24 hours/day 7 days/week 4 Seasonal use percentage: Dec -Feb: Mai': June -Aug: Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 weeks/year ( w kV51 Sept -Nov: 21AYI COLORADO Depenment ors H.atlTb EnWroIMN \:wc.s op,Ya#W. ace ‘‘`1gI1,1 Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ 101 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power ❑ Emergency (max. 500 hrs/year) ❑✓ Compression O Pump Jack O Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Caterpillar Engine Model: G379 NA Serial Number7: 72B643 What is the maximum designed horsepower rating? 330 hp What is the maximum manufacturer's site -rating? 330 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,878 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke D 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Aspiration: ❑✓ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes O No If yes, what type of AFRC is in use? V] 02 Sensor (mV) ■ I ensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? EYes Engine Dates: What is the manufactured date of this engine? 1987 What date was this engine ordered? 1987 What is the date this engine was first located to Colorado? N/A- Zpc5 What is the date this engine was first placed in service/operation? 1987 What is the date this engine commenced construction? 1987 What is the date this engine was last reconstructed or modified? N/A Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. ?, 1', .5 ti (Taro-kr:r. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 " tIs ti ®NTICOLORADO Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ 101 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information 40.2666 / -104.7553 operator Stack 11.5: NOS Discharge Height Above Ground Level (feet). Temp_ �; F) _ Flow Rate --Atk Velocity (fusec)y C-211 16.48 1,086 1,398 43 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 10 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load;. (SCF/hour) SK`s Actual Annual Fuel Use (MMSCF/year)' Requested Annual Permit Limit$ (MMSCF/year) 2,476 SCF/hour 19.16 MMSCF/year 1.78 MMSCF/year From what year is the actual annual amount? Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1,050 BTU/scf ❑ Propane (assumed fuel heating value of ,2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 2018 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 4 COLORADO xgtnbaiirar fr Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ 101 Formaldehyde TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Primary Control Equipment Description Overall Requested Control" Efficiency .. (% reduction in emissions PM10 PM2.5 SOX NOx VOC Primary: NSCR / Secondary: AFR Primary: NSCR / Secondary: AFR 68% CO Other: Primary: NSCR / Secondary: AFR tAA " / Formaldehyde - Primary: NSCR / Secondary: AFR Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 CjC7ej 76% Criteria Pollutant Emissions Invento` TSP (PM) 0.20 Source (AP -42 , Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions tons/year) Requested Annual Permit, Emission` Limit(s)8.° Uncontrolled , Emissions (tons/year) Controlled Emissions tons/year) 1.94E-02 Ib/MMBtu AP -42 0.20 0.02 0.02 PMio PM2.5 1.94E-02 Ib/MMBtu AP -42 0.20 0.20 0.02 0.02 1.94E-02 Ib/MMBtu AP -42 0.20 0.20 0.02 0.02 SOX NOx VOC 5.88E-04 lb/MMBtu AP -42 0.01 0.01 0.00 0.00 .ere- I3 3.10 g/hp-hr g/hp-hr Manufacturer Manufacturer 26.75 9.53 4.63 2.89 -2-28- 3 ,y 0.81 0.42 0.26 CO vs AD g/hp-hr Manufacturer 24.29 4.63 0.42 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: 0✓ Yes ❑ No Non -Criteria Reportable Pollutant Emissions nventory Chemical Abstract Service (CAS) Number 2.05E-02 Emission Factor Actual Annual Emissions'( Units, Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) Controlled Emissions (pounds/year) 50000 lb/MMBtu AP -42 412 101 Acetaldehyde 75070 107028 Acrolein Benzene 71432 Other: 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 5 I �'• COLORADO 1�1 N aRlllhb£nrlosnmgnl ?,{.,(lid S red O pd0.i`tc C.ad W a:60 A.%. lNi-)S Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ 101 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. 71‘e:iLICII IVI Signature of Legally Authorized Person (not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance 17 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: / /www.colorado. Roy /cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 COLORADO 6I 'V 7 HaaUNb Enrl= Fugitive Component Leak Emissions APEN Form APCD-203 Air Pollutant Emission Notice (APEN) and Application for Construction Permit AU sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for fugitive component leak emissions only. If your emission source does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Al- Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 1136 AIRS ID Number: 123 /0090/108 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Marie Cameron Phone Number: (303) 605-2029 E -Mail Address2: MECameron@dcpmidstream.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 414833 'COLORADO 1 I AV Permit Number: 09WE1136 AIRS ID Number: 123 /0090 / 108 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) - OR ▪ MODIFICATION to existing permit (check each box below that applies) ❑✓ Change process or equipment ❑ Change company name3 El Add point to existing permit ❑✓ Change permit limit El Transfer of ownership's O Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Adding additional fugitive component counts for future projects and revising controls to apply control factors applicable to NSPS OOOO/OOOOa. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information Company equipment Identification No. (optional): For existing sources, operation began on: F017 5/19/2011 For new or reconstructed sources, the projected start-up date is: O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Facility Type: ❑ Well Production Facility5 O Natural Gas Compressor Stations 0 Natural Gas Processing Plants ❑ Other (describe): hours/day days/week weeks/year 5 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 'COLORADO 2 I UflIO, Enfl Punk AnUTb EIIV110nM�4� Permit Number: 09WE1136 AIRS ID Number: 123 /0090 /1 08 Gas [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? Will this equipment be operated in any NAAQS nonattainment area? Will this equipment be located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? Is this equipment subject to 40 CFR Part 60, Subpart 0000? Is this equipment subject to 40 CFR Part 60, Subpart 0000a? Is this equipment subject to 40 CFR Part 63, Subpart HH? Is this equipment subject to Colorado Regulation No. 7, Section XII.G? Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? tAckc.. E9wpr►Auk tccAkce+ iC l e-vV& row o^;t5 a,vt sol jest to a vlt{ 'AST% V ALvl. pa,p o..kel a 5a co=ca o+L tc aser ilw& o14, -4T_ • volt; Kkar;" (-°"-�'1 ��t� i4' cCof3k 4,r _Cu,i1iv(_ cov,►%.po+.e. ict- a#, cal -a:at">S vKtf.,.- Section 5 - Stream Constituents ✓❑ The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight % content of each applicable stream. 5/19/2011* ❑✓ Yes D Yes ❑ Yes ®-Yes Yes ❑✓ Yes ❑ Yes ❑✓ Yes ❑ Yes ❑ Yes ❑ No ❑✓ No * Process Unit Construction Dates: NSPS KKK - Amine/Glycol, Cryo, Dehydration, Inlet Tui ❑✓ No bine, NGL, Propane, and Tank Farm commenced construction prior to gi No -8/23/2011. 0SPS 0000 - Inlet Compressor and North Inlet were modified in Q3, 2015 O No and Q4, 2013 respectively. ❑✓ No NSPS 0000a - The condensate pipeline was ❑ No modified 3/06/2017 ❑✓ No Changes to the TANKFARM process unit ❑✓ No were made in 3/2018. VOC (wt Benzene (wt %)' Toluene Ethylbenzene (W %) Xylene (wt n -Hexane (wt %) 2,2,4 Trimethylpentane.,: 22.8 0.06% 0.04% 0.001% 0.01 0.25% 0.003% Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) 100 0.24% 0.19% 0.005% 0.03 1.08% 0.01% Water/Oil Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2666 / -104.7553 Attach a topographic site map showing location Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 `cj01,1ius.5 I:.c,r arecl 01. 3, f,- 'COLORADO d. , Permit Number: 09WE1136 1136 AIRS ID Number: 123 /0090 / 108 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: ❑ LDAR per 40 CFR Part 60, Subpart KKK ❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump ❑ Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump ❑✓ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81% connectors ❑ WAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: O No LDAR Program , 6,.Attach other supplemental plan to APEN form if: needed. , Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 COLORADO 4 I Hfl thhttMronm.nt Permit Number: 09WE1136 AIRS ID Number: 123 /0090 / 1 08 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. ❑✓ Table 2-4 was used to estimate emissions7. Table 2-8 (< 10,000ppmv) was used to estimate emissions7. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: ❑✓ Estimated Component Count 0✓ Actual Component Count conducted on the following date: 8/201 8 Count8 Connectors 4090 Equipment. Type Open -Ended Lines Pump Seals 4417 -2- ton - 8912 • 2 Emission Factor 0.000440. 0.000860 . 0.004410 • 0.009920 0.019401 Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source Heavy Oil (or Heavy Liqui Count8 Emission Factor Units light Oil (or Light. Liquid) Count8 Emission Factor 6971 • 0.000463 . 2283 • 0.000243 - 47 0.028660 • 3261 0.005510 3- (i) 0.016535 Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source Water/Oil Count8 Emission Factor Units 7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The "Other" equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seals, or valves. 5 I L VI'COLORADO H.attTb Envte= Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 l`�ekt'c-5 CtiIIW�0LO�S. .4 t�5 tOltt lq 1 Permit Number: 09WE1136 AIRS ID Number: 123 /0090 / 108 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: (Use the data reported in Section 8 to calculate these emissions.) Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s)11 Uncontrolled (tons/year) Controlled10 (tons/year) - Uncontrolled (tons/year) Controlled (tons/year) VOC 30.52 4.90 12.80 180.47 ►cdo.s I Does the emissions source have any actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? El Yes ❑✓ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name 71432 Actual Annual Emissions` Requested Annual Permit Emission S),. Uncontrolled (lbs/year) Controlled1° (lbs/year) Uncontrolled' (lbs/year) . Controlled (lbsl year): Benzene 880 (.ot.N Toluene 108883 690 49 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 278 2,2,4 Trimethylpentane 540841 Other: 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability, and gas composition variability. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 1.017_1111 (�{�LW COLORADO 6 I A by 4rcKo PuM� fivalfhb FnulvaNb& Permit Number: 09WE1136 1136 AIRS ID Number: 123 /0090 /1 08 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 7f)- / O Signature of Legally Authorized Person (not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to; Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.Rov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 COLORADO n.wnaEmltrimmi Hydrocarbon Liquid Loading APEN Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and wilt require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.coilorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / 109 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewboum Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: (Include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Contact Person: Phone Number: E -Mail Address2: Marie Cameron (303) 605-2029 MECameron@dcpmidstream.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. ems\ 19 • S\\° 471989 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 k COLORADO H�allhb EnYheNn1M Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 109 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source O Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑✓ Change permit limit ❑ Transfer of ownership4 0 Other (describe below) - OR APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Reduced throughput and added NOx, CO, and VOC emissions from enclosed combustor pilot and assist gas. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Stabilized Condensate Loadout controlled by enclosed combustor with 95% DRE. ECD pilot and assist gas emissions included at this AIRS point. Company equipment Identification No. (optional): LO For existing sources, operation began on: 1993 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? Yes No ig ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes No • p Does this source load gasoline into transport vehicles? Yes No ■ ig Is this source located at an oil and gas exploration and production site? Yes No ■ p If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No • ■ l� ( , Dees this source splash fill less than 6750 bbl of condensate per year? Yes No • • Does this source submerge fill less than 16308 bbl of condensate per year? Yes No ■ ■ Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 AVEViCOLORADO 2 of wee a`P'utwata �m.muneni Permit Number: 09WE1136 AIRS ID Number: 123 / 0090/ 109 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: 0 Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 200,000 bbl/year Actual Volume Loaded: This product is loaded from tanks at this facility into: tank trucks (e.g. "rail tank cars" or "tank trucks") 21,175 bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: �.6 Average temperature of bulk liquid loading: =,.1 2 ^ 5 .`-F °F True Vapor Pressure: 5.032 Psia ® 60 °F Molecular weight of displaced vapors: 66 lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 COLORADO ncpal I what 3 I H.rtlb b U%ulanmtnl Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 109 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2666 / -104.7553 Operator 5tackID No Discharge Height Above Ground Level Temp ( F)1 Flow Rate (ACFM) Velocity sec) {ftic. ECD 35 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Other (describe): O Upward with obstructing raincap Interior stack diameter (inches): 4 ft Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. O Loading occurs using a vapor balance system: Requested Control Efficiency: ❑ Combustion Device: Used for control of: loading emissions and condensate tank vents Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: John Zink / ZCT-1-4-35-X-1 /3 Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: °F Waste Gas Heat Content: 3,397 Btu/scf Constant Pilot Light: ❑✓ Yes O No Pilot Burner Rating: 0.05 MMBtu/hr O Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 4 COLORADO flsputcecn: of RN.ie scmtnnenr m., Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / 109 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): PM Description of Control Method Overall Requested Control Efficiency' (% reduction in emissions) SOx NOx CO VOC Enclosed combustor 95% HAPs Enclosed combustor 95% Other: ❑ Using State Emission Factors (Required for GP07) ❑ Condensate ❑ Crude , VOC 0.236 Lbs/BBL 0.104 Lbs/BBL Benzene 0.00041 Lbs/BBL 0.00018 Lbs/BBL n -Hexane 0.0036 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 201 8 PM Uncontrolled Basis Units Criteria Pollutant Emissions Inventory Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/ year) Requested Annual Permit Emission Limit(s)5 Uncontrolled Emissions (tons/ year) Controlled Emissions (tons/year) SOx NOx 0.38(loZgy TCEQ/AP-42 AP -42 0.02 0.02 0.88 0.88 CO VOC o C`15t0J9)6. 1� o.l.c5 ( S.bb/ 3�aO�.Gb TCEQ / AP -42 0.09 "s51/law,- i A?-4-1(,,„sAlawtt 2.14 LSlw+� rr{ 0.09 0.11 3-34S.kk3 39.20 1.41 2794- Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg.; etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 It\.vti rbi,,,., cy,cLha(anL( 306 15 2,2,4- Trimethylpentane 540841 Other: 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 7...ct1;yue S COLORADO 5 I A ` ficalll:5 En'll.6ximxl csa.tC4)( pct it1,111 Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 109 [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. Signature of Legally Authorized Person (not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 COLORADO 6j ? Hw=wow General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit APR 1 0 20i Ap`G All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/111 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name' DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 (Include Zip Code) 17th St, Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 33918 Form APCD-200 - General APEN - Revision 3/2019 COLORADO 1 l I Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/111 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Revising emissions to include startup and shutdown emissions (SUSD) as two additional permit limks 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Inlet 1 compression Manufacturer: Solar Model No.: Taurus 60 Company equipment Identification No. (optional): For existing sources, operation began on: C0170 Serial No.: OHH H 15-T9606 5/19/2011 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operations:, hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 3/2019 Jun -Aug: Sep -Nov: COLORADO 2 n.,.. t. g4 4 H�Nm B€nwro4R�t.:1 Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 111 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limits (Specify Units) AAatetia consumption s Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information eographicalti5o di tei Latitude/Longrtude or UT 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. �r Operator, Stack ID No , ' rs Discharge Height bove Ground Level � (Feet) Temp ( Flow Rate (ACFM) Velocity (ftlsecl C0170 35.8 957 88,703 115 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap ❑✓ Circular Interior stack diameter (inches): 4.8.55 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 3/2019 COLORADO • nT!s+. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/111 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Ft Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) ' Requested Annual Permit Limits (Specify Units) 50.1 372.50 MMscf/yr 4-1s.c,-; MMscf/yr From what year is the actual annua fuel use data? 2018 Indicate the type of, fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ✓❑ Field Natural Gas Heating value: cA1k,, \ BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: ❑ Other (describe): Heating value (give units): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. ?v,d1:K.5 ?e,( rvlort vwt-d-e t-Ovr ✓ c) u cc . Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ✓❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description - Overall Collection Efficiency - Overall Control Efficiency (% reduction in emissions) TSP (PM) PMio PMz.s SOx NO. CO VOC Other:. Form APCD-200 - General APEN - Revision 3/2019 41 'COLORADO d Patine ,w,mc,' m RVN!N fr Fnuiw?s.?± Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/111 TSP (PM) [Leave blank unle s APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units) Emission . Factor Source (AP -42, Mfg.', etc) Uncontrolled (tons/year) Controlled (tons/year) uested Annual Permit isston Ltmrt(s) Uncontrolled (tons/year) Controlled (tons/year) 6.60E-3 Ib/MMBtu AP -42 1.32 1.32 1.45 • 1.45 PMio 6.60E-3 Ib/MMBtu AP -42 1.32 1.32 1.45' 1.45 • PM2.s 6.60E-3 Ib/MMBtu AP -42 1.32 1.32 1.45 , 1.45 • 5Ox 3.40E-3 Ib/MMBtu AP -42 0.68 0.68 0.75 - 0.75 • NO,, CO VOC Other: S �t 8x1 't '.1 *.) t.o inievcr-k, Manufacturer I.Q Emile, 10.0} lb r.n 1`$� Manufacturer ' 6..i xIO} t eMVAEe V- Ib(t .e v ..v‘ucsch) rtv 12.75 12.92 0.42 12.75 12.92 0.42 I3..IZ/0.an (o.oq 13.32/ 0.`1/0.%1 l3 t7J o•oli(a.ot 13.32/CA /0.23 0.46 /(5.7../ o.l°l 0.46 / o.Z6(o. l°) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that the requested permit limits for NOx, CO, and VOC include three scenarios: normal operation, startup, and shutdown emissions Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Formaldehyde Overall Control Efficiency Uncontrolled Emission Factor (Specify Units),, Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled Actual Emissions (lbs/year) Yes ❑ No Controlled Actual, Emissions (lbs/year) 50-00-0 0% 7.10E-4 Ib/MMBtu AP -42 285 285 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 3/2019 4ti�S ip (30C1 1 5I COLORADO H1zoS'NbEn'nlsrnm5±ti Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/111 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Ll�(2Org Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance Ei Draft permit prior to public notice (Checking any of these bikes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 3/2019 61 Dew.. al IhrlAw '..COLORADO 1iVMA46eorRoo ml General APEN - Form APCD-200 ,, 9 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/112 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 395919 Form APCD-200 - General APEN - Revision 3/2019 1 I ;COLORADO id 41tbgmrafte4- Hueimoo .PI Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/112 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 El Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Revising emissions to include startup and shutdown emissions (SUSD) as two additional permit limits 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Inlet 2 compression Manufacturer: Solar Model No.: Taurus 60 Serial No.: O H E 17-T9134 Company equipment Identification No. (optional): For existing sources, operation began on: C0180 5/19/2011 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Seasonal use percentage: Dec -Feb: hours/day days/week weeks/year Mar -May: Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 3/2019 {'. COLORADO 2 I VVYG 'x m Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090/ 112 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use 0 Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limits (Specify Units) Material .' Consumption:; 5 Requested values will become permit limitations_ Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical; Coordinates (Latitude/Longitude orUTM 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator xr $tack ID NO Discharge Height Above Grou.d Level (Feet) Temp ( F) _ Flow Rate (ACFM){ Velocity (ft/sec)f C0180 35.8 957 88,703 115 Indicate the direction of the stack outlet: (check one) ❑✓ Upward Horizontal Ei Downward Other (describe): Indicate the stack opening and size: (checkone) ❑ Upward with obstructing raincap ❑✓ Circular Interior stack diameter (inches): 48.5 El Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 3/2019 3 I COLORADO ngac!t� v Enwr?rn?sm Permit Number: 09WE 1 1 36 AIRS ID Number: 1 23 10090/112 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment a Fuel Consumption Information D Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) ' Requested Annual Permit Limits (Specify Units) 50.1 366.78 MMscf/yr + 1-).C\ MMscf/yr From what year is the actual annual fuel use data? 2018 Indicate the type of fuel used6: ❑ Pipeline Natural. Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑✓ Field Natural Gas Heating value: otkv,, BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: ❑ Other (describe): Heating value (give units): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control, Efficiency (% reduction in emissions), TSP (PM) PM10 PM2.5 SO. NOx CO VOC Other: Form APCD-200 - General APEN - Revision 3/2019 41 _ D_-. COLORADO I Dep+±Uacal at PtdAK Permit Number: 09VVE 1136 AIRS ID Number: 123 /0090/112 [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) TSP (PM) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Controlled (tons/year) nested Annual Permit; mission;Limitts, Uncontrolled (tons/year) Uncontrolled (tons/year) Controlled (tons/year) 6.60E-3 Ib/MMBtu AP -42 1.30 1.30 1.45 • 1.45 • PMio 6.60E-3 Ib/MMBtu AP -42 1.30 1.30 1.45 1.45 PM2.5 6.60E-3 Ib/MMBtu AP -42 1.30 1.30 1.45 1.45 • SOX 3.40E-3 lb/MMBtu AP -42 0.67 0.67 0.75 0.75 • NO,, CO VOC Other: 1. 0 1 tot& .hlcvcvik 1.o 1, t+ urt3t OM, z qi k, �AVr,MNJ A4-.414 0.41 tit.3cv4 yu�at o�ccFUtCf anufacturer rn ianufacturer 12.54 12.71 12.54 12.71 0.41 l'§.k 10.ba(o.oli 13.32 / a9'o. S% 0.46 / o.7.3/0.ig G,,ILf04111aotl 13.321c?`llp.g3 0.46! a. tIS/0.19 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. ' Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that the requested permit limits for NOx, CO, and VOC include three scenarios: normal operation, startup, and shutdown emissions Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Number Chemical Name Overall Control Efficiency. Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled, Actual Emissions (lbs/year)' Controlled Actual Emissions? (lbs/year) 50-00-0 Formaldehyde 0% 7.10E-4 1b/M M Btu AP -42 281 281 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 3/2019 nna. •Ca-cko vtr 01,,a. . 51 1O iNoil9 ,COLOR ADO Permit Number: 09WE1136 AIRS ID Number: 123 /0090/112 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 1fi?1zo�9 Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance E] Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division r APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 ;t Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 3/2019 COLORADO HwnnasnMromnem 1 4,81.9 General APEN - Form APCD-200,f'�: S+� Jr Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 AIRS ID Number: 123 /0090/118 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 395920 Form APCD-200 - General APEN - Revision 3/2019 1 I COLORADO ceprtmol Yoeac H!NIISE.+'m9Fn•iU Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/ 118 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source -OR - ✓❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ✓❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) O APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Revising emissions to include startup and shutdown emissions (SUSD) as two additional permit limits 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Genset 1 Manufacturer: Solar Model No.: Taurus 70 Company equipment Identification No. (optional): For existing sources, operation began on: G1650 Serial No.: &% °T O'S 5/19/2011 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 3/2019 Jun -Aug: Sep -Nov: � 'COLORADO 2 ASSS�� OaPnmm n.of Nb tq Mont. €�+vtwrtmsrn \\''e._ 'r r'r - + tot\ 1 I`A Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/118 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? - Description Design g Process Rate (Specify Units) Actual Annual Amount (Specify Units) " Requested Annual Permit Limits, (Specify Units) ent, ,'. `"Gon a `option , fin ?tFinisliedF. Pro�'duct(s): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. :,,era 17,,' Stack ID No 4 T Discharge: Height Above Ground Level (Feet) Terri P ( F) Flow Rate (ACFM� , Velocity (ft/sec) G1650 45 928 106,500 141 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap ❑✓ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General. APEN - Revision 3/2019 3 ,COLOR ADO RAM Permit Number: 09WE 1136 AIRS ID Number: 1 23 /0090 / 118 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment &t Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) - Requested Annual Permit Limits (Specify Units) 61.6 272.30 MMscf/yr 5,,?x. '8-\ MMscf/yr From what year is the actual annua fuel use data? 2018 Indicate the type of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑✓ Field Natural Gas Heating value: ellla, i BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: ❑ Other (describe): Heating value (give units): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. t 'tc.,4tJ v V Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No rol equipment AND state the overall control efficiency (% reduction): -k o 5111-119 Pollutant Control Equipment ° Description Overall Collection Efficiency Overall Control Efficiency (36 reduction in emissions) TSP (PM) PM10 PM2.s SOX NO), CO VOC Other: Form APCD-200 - General APEN - Revision 3/2019 COLORADO 4 I t!x_. t. _ Envim+n�em Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/118 [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission " Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) • sfer.Ei i _ " '`Actual Annual.Emissions-` g :. . :.x3=.;'>y.,,; b-.. Y .. , ° Requested Annual Permit: = -• t � �w °=�fx""-> 5 . Emission Limit s - Y. y.. �,. y. • rr ,:.. : , .....: ,.; Uncontrolled (tons/year) Controlled (tons/year) Uncontrolled (tons/year) . Controlled (tons/year) TSP (PM) 6.60E-3 lb/MMBtu AP -42 0.97 0.97 1.78 1.78 PM.to 6.60E-31b/MMBtu AP -42 0.97 0.97 1.78 1.78 PM2.5 6.60E-3Ib/MMBtu AP -42 0.97 0.97 1.78 1.78 SO,, 3.40E-3lb/MMBtu AP -42 0.50 0.50 0.92 0.92 NO. 514sf itsi-,N`,"tt✓ t.e 1.0' le '"- Manufacturer 8.75 8.75Ito.ii®.v.sa.� 10.13 i 'D.00410,02I S CO �.kbl�/lanufacturer s�e 8.89 8.89 tp'� l/0•59to.S� voc 't.coKe -3 ibl,mw ..) o tg �K - LV -ut / " czuu 0.31 0.31 0.57 / �.1 i o.cc 0.57/ o.) u.og Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that the requested permit limits for NOx, CO, and VOC include three scenarios: normal operation, startup, and shutdown emissions Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 Ws/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number • Chemical Name " Overall Control Efficiency Uncontrolled Emission Factor (Specify Units) - Emissi• on Fact.or. i Source - (AP-42Mfg.etc.) , , Uncontrolled ' - Actual : Emissions ((Ps/year) Controlled Actual. Emissions (lbs/year) Yes ✓0 No 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 3/2019 ?c onaA4 i-CcQative,✓ &ak.EI . HAS Ij iu-a-1l1 •COLORADO a..r.ee.�ne.¢ Pubbc 5i Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/118 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. L [zof� Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance ❑� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South. Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 3/2019 COLORADO 6 I AVfr,u,,,..,�dk - A1iN�.1! k €J�YIfMmllfl A General APEN - Form APCD-20,10): Air Pollutant Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/119 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 395921 Form APCD-200 - General APEN - Revision 3/2019 COLORADO eta Peptic 1 Re6F�„vPe,.„, Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/ 119 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source -OR - ✓❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Revising emissions to include startup and shutdown emissions (SUSD) as two additional permit limits 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Genset 2 Manufacturer: Solar Model No.: Taurus 70 Company equipment Identification No. (optional): For existing sources, operation began on: G1670 Serial No.: Ot- 1c2,- B1$sb 5/19/2011 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 3/2019 Jun -Aug: Sep -Nov: COLORADO 2 I awn�..m rwn` ' HNPkb ETYlronmlTt -?c-( c p rako''. 1,45 Ito\ Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090/ 119 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limits (Specify Units) Material .. Consumption: Finished Product(s):"' 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator tack ID No Discharge Height Above GrouLevel (Feet) Temp ( F) Flow Rate (ACFM) Velocity (ft/sec) G1670 45 928 106,500 141 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap ❑✓ Circular Interior stack diameter (inches): 48 O Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): Form APCD-200 - General APEN - Revision 3/2019 3 I COLORADO mmnom Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/119 [Leave blank unless APCD has already assigned a permit R and AIRS ID] Section 6 - Combustion Equipment It Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTUIhr) - Actual Annual Fuel Use (Specify Units)' Requested Annual Permit Limits (Specify Units), 61.6 432.52 MMscf/yr 5`8`-b. V-1 MMscf/yr From what year is the actual annua fuel use data? 2018 Indicate the type of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑✓ Field Natural Gas Heating value: �lb� BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) O Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: ❑ Other (describe): Heating value (give units): s Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. - airs star V j Aitvv Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ❑✓ No c . \Aos ocl,htill If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency ` Overall Control Efficiency (% reduction in emissions) TSP (PM) PMio PM2.5 SOX NO,, CO VOC Other: Form APCD-200 - General APEN - Revision 3/2019 COLORADO 4 - i79z 20.df^€.n.4w,(P.b%I ea±emenn Permit Number: 09VVE 1136 AIRS ID Number: 123 /0090/119 50-00-0 Formaldehyde TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor Specify Units) Emission Factor Source (AP -42, Mfg., etc.) . . Uncontrolled (tons/year) Controlled7. (tons/year) Uncontrolled (tons/year) Controlled (tons/year), g ermi mssion'lom9t 6.60E-3 Ib/MMBtu AP -42 1.54 1.54 1.78 1.78 PM10 6.60E-3 lb/MMBtu AP -42 1.54 1.54 1.78 1.78 PM2.s 6.60E-3 lb/MMBtu AP -42 1.54 1.54 1.78 1.78 SO. 3.40E-3 lb/MMBtu AP -42 0.79 0.79 0.92 0.92 NO,, CO VOC Other: 5r5.-rt 1-t Manufacturer 13.91 13.91 Kali / .00'11� 1b.131.o.co o.m& Manufacturer 14,14 14.14 I\P3b' 0.5`llo.Sg lb•ke1'o•slro.ssa 0.49 0.49 0.57/ fo.c� 0.57/0.1 lo.e. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that the requested permit limits for NOx, CO, and VOC include three scenarios: normal operation, startup, and shutdown emissions Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Overall Control Efficiency Uncontrolled. Emission Factor (Specify Units) Emission Factor Source. (AP -42 Mfg., etc.). Uncontrolled Actual Emissions (lbs/year) Controlled Actual . Emissions? (Ibs(year) 0% 7.10E-4 lb/MMBtu AP -42 331 331 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 3/2019 vtiaw v ( JV r c,(c . 51 .COLORADO Depart, ,,,. alNNkk MAO, _ fnVIIVI P,,m, Permit Number: 09WE1136 AIRS ID Number: 123 /0090/119 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 4l$12orq Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd COLORADO Form APCD-200 - General APEN - Revision 3/2019 Amine Sweetening Unit - Form APCD-206 Air Pollutant Emission Notice (APEN) and Application for Construction Permit AU sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for amine sweetening units only. If your emission unit does not fall into this category, there may be a more specific APEN available for your source (e.g. glycol dehydration unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / 120 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: (Include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com I Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 389841 Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 1 I 'COLORADO bepartmetrg eiPulAlc i He= h FrWannunl Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 120 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name3 O Add point to existing permit ❑✓ Change permit limit O Transfer of ownership4 O Other (describe below) OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft Notes: Acid gas stream from amine unit controlled by a TO. A dedicated flare (F-2) serves as backup to the TO. There are three processes under condition 8 of construction permit 09WE1136 Issuance 4 (dated July 14, 2017).' 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. * Process 1: Natural gas processed by the amine unit Process 2: Combustion of still vent waste gas, supplemental fuel and pilot fuel by the TO Process 3: Combustion of flash tank waste gas by the plant flare (F-1, AIRS ID 125) Section 3 - General Information General description of equipment and purpose: Amine unit to remove CO2 and H2S Company equipment Identification No. (optional): For existing sources, operation began on: AM001 05/19/2011 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area? Does this facility have a design capacity less than 2 long tons/day of H2S in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 days/week Yes Yes weeks/year No ®jC0L0Rk 2 I I1:111117,1`1,11.1,1% Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / 120 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Amine Unit Equipment Information Manufacturer: Precision Pipe &Vessel Model No.: T-501 Absorber Column Stages: Amine Type: stages ❑ MEA ❑ DEA ❑ TEA Pump Make and Model: Schlumberger RedaHPs, J350N Serial Number: 1830 ❑✓ MDEA O DGA # of pumps: 3 (2+1b) Sour Gas Throughput: Design Capacity: 160 MMSCF/day Requested5: 58,400 MMSCF/year Actual: 556,218 MMSCF/year Sour Gas: Pressure: $-7-7 cfbo psig Temperature: 90 °F Lean Amine Stream: Pressure: 912.3 , psia Temperature: 102.1 • °F Flowrate: 640 gal/min Wt. % amine: 44 Mole Loading 0.1044 CO2: Mole loading H2S: 0.00005 NGL Input: Pressure: Flowrate: psia Gal/min Temperature: °F Flash Tank: O No Flash Tank Pressure: 82.3 ° psia Temperature: 133.9 • °F Additional Required Information: ❑✓ Attach a Process Flow Diagram ❑� Attach the simulation model inputs Et emissions report Ei Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) O Attach the extended gas analysis (including BTEX Et n -Hexane, H2S, CO2, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7.r d1z`^-t- [ Q C OOk t0►\ . Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 (COLORADO 3 I ��I Htl radt f .En°b°tlrtl.N Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / 120 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates Latitude/Longitude ®r UTM) 40.2666 / -104.7553 s°i Q erator P , rJ S ad k ID hlo Discha a Hei fg g EAove Ground Level, r {feet)-�� , �� .._-. � Temp 3fAt �� ` " { � � � i �e�'`��h":>�' � e Flow Rate 4CFM �� ,� l . .�� YYeocity € u � (fflsec) � AM001 32 Indicate the direction of the stack outlet: (check one) ❑✓ Upward O Horizontal ❑ Downward ❑ Other (describe): 0 Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 81 Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑✓ VRU: Used for control of: Flash tank Size: Make/Model: Requested Control Efficiency: 100 VRU Downtime or Bypassed: 5 % Combustion Device: * Used for control of: Amine Acid Gas Rating: 23 MMBtu/hr Type: TO Make/Model: Anguil l It'3 ' \ Requested Control Efficiency: 96.7 Manufacturer Guaranteed Control Efficiency: 98 514% °CS, Minimum Temperature: iStL °F Waste Gas Heat Content: 14.09 Btu/scf Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: 0.1 MMBtu/hr Supplemental Fuel Flow: 192 MMscf/year Btu/scf Supplemental Fuel Heat Content: 1,050 Closed ❑ Loop System: Used for control of: Description: System Downtime: ❑✓ Other: Used for control of: Flash Tank Description: Goes to flare backup (F-1) during VRU downtime Requested Control Efficiency: 95 % * There are two operating scenarios for the Amine unit Still Vent (Process 2) Scenario 1: Still vent emissions controlled by TO with 96.7% control Scenario 2: Still vent emissions controlled by F-2 during TO downtime (see F-2 APEN, AIRS 136) Permit Number: 09VVE 1136 AIRS ID Number: 123 / 0090 / 120 PM [Leave blank unless APCD has already assigned a permit tt and MRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) SOX H 2 NO. CO VOC Still Vent - TO, Flash - VRU (Plant Flare during VRU DT) Still - 96.7%, Flash - 100% (95% VRU DT) HAPs Still Vent - TO, Flash - VRU (Plant Flare during VRU DT) Still - 96.7%, Flash - 100% (95% VRU DT) Other: From what year is the following reported actual annual emissions data? 2017 * Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s) 5 Pollutant Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions6 : (tons/year) Uncontrolled Emissions tons/ ear ( Y ) Controlled Emissions e (tons/year) ( Y ) PM -- /4.v2/' -- Ib/MMscf AP -42 ' -- / o.75/ -- -- / o•q S7 -- SOx 1.15./0,lotr4.08E-4. lb/MMscf V o is 4Ap-yL -- / -- 8.04 / -- 33.53'/ 0.067 0.01 33.531 0.00/ 0.01^ H2S 0.59•/ -- / 0.002- Ib/MMscf ProMax 4.44 / 0.04 0.29 / 0.04 17.25.1-- / 0.04. 0.571-- / 0.0001 NO. 0.138i0.138i0.068' Ib/MMBtu TC-CQ(Az`IL 0.31 /-- 0.31 /-- 1.62113.97/0.13, 1.62./13.92/0.13 CO 0.31 • Ib/MMBtu AP -42 1.40 / -- 1.40 / -- 3.64 / 31.38'/ 0.61. 3.64/ 31.38 / 0.61' VOC q•`l} IS.toki,Iiz•t5 Ib/MMscf 7<0w44rAA, -qL 301.4 / 1.1 6.48 / 1.1 2Z4.c.9(o.S513gy,iel_7.5t/44SS/d,Sq Chemical Name Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis. Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6. (pounds/year) Benzene 71432 2.69-/--/0.13' Ib/MMscf ProMax 68,395 / 700 3,969 / 700 Toluene 108883 2.10/ Ib/MMscf ProMax 63,996 / 608 3,805 / 608 Ethylbenzene 100414 0.047-/0.002. Ib/MMscf ProMax 1,467/13 88/13 Xylene 1330207 0.43/--/0.01. Ib/MMscf ProMax 22,297 / 209 1,350 / 209 n -Hexane 110543 0.01'/--/0.07• Ib/MMscf ProMax 4,374 / 15 15/2 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APC * For the calendar year of 2017, this unit was operated as authorized by permit 09WE1136 Issuance 3 (dated October 21, 2016) per condition 80 of construction permit 09WE1136 Issuance 4 (dated July 14, 2017). !COLORADO Py_cikVkv-c_s - v d Cf)AWla s. Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 120 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) 1/2-0/8r Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance ❑� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 (COLORADO 6 I AVIV= Wmlwnl APR 1 0 2019 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit ,t All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/125 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Namet: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-200 - General APEN - Revision 3/2019 3559.15 COLOR ADO 1 I AV „ >a. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090 / 125 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit O Transfer of ownership4 O Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Ft Notes: Plant Flare (F-1) 3 For company name change, a completed Company Name Change Certification Form (Form APCD-1O6) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Flare for blowdowns, amine flash during VRU downtime, and TEG Dehydrator D-931 still vent and flash during VRU downtime. Manufacturer: John Zink Model No.: KMl-12-8-WB Serial No.: 92.1 55s-4-1 Company equipment Identification No. (optional): For existing sources, operation began on: F-1 For new or reconstructed sources, the projected start-up date is: p Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 3/2019 Jun -Aug: Sep -Nov: COLORADO 2 I fl P5Pmvisrene¢n odor. . Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/125 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limits (Specify Units) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information eograPlica COordina Latitude/longitude or'IJT 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operatota�� _'� Stack ID NO s Discharge Height s .ove Ground Level (Feet) �.. � � Tem P (Fj �x ��c'kx ..L - �' Flow Rate AC ; _�' ...# ��k '.'_� � � `-�-,i � �� ' Veloctt Y ft/sec)- F-1 130 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap ❑✓ Circular Interior stack diameter (inches): 8 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 3/2019 3 COLORADO 4fam§.g mwatK Permit Number: 09WE 1136 AIRS ID Number: 1 23 /0090/125 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment &t Fuel Consumption Information O Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) ' Actual Annual Fuel Use (Specify Units) < ' Requested Annual Permit Limits (Specify Units) 0.49 20.66 MMscf/yr 2.`i MMscf/yr (Purge + Waste) From what year is the actual annual fuel use data? 2018 Indicate the type of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) 0 Field Natural Gas Heating value: 1,050 BTU/SCF O Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon). O Propane O Coal Heating value: 0✓ Other (describe): Inlet gas 1 v_\(-5; t_ 5 Heating value (give units): (assumed fuel heating value of 2,300 BTU/SCF) BTU/lb 'Ash' content: Sulfur content: 1,299 Btu/scf /Kilt 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. ?.c.r3J:o&c.5 :c[ taco 0Lo.. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes O No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency ' Overall Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.s SOx NO. CO VOC Flare 100% 95% Other: HAPs Flare 100% 95% 1� te-iiN COLORADO Form APCD-200 - General APEN - Revision 3/2019 Permit Number: Q9WE 1 136 AIRS ID Number: 123 /0090/125 [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) TSP (PM) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled (tons/year) Controlled? (tons/year) Requested Annual Perm Emission Limits Uncontrolled (tons/year) Controlled (tons/year) Ib/MMscf • AP -42 neg. neg. 0.005 • 0.005 • PMio �.� lb/MMscf AP -42 neg. neg. 0.005 • 0.005 • PM2.5 lb/MMscf • AP -42 neg. neg. 0.005 • 0.005 • SOx NOX CO VOC o•4L15Inwwiji c of tbiMovAsc .. AP -42i AP -42 neg. 1.75 neg. 1.75 0.01 ° 1.33 0.01 I.. AP -42 4.33 4.33 S.7,9 5.1-9 uvlaxl5al�'+�C 129.00 6.45 I S9 • `b`-i Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. • Section 8 - Non -Criteria Pollutant Emissions. Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? �✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number n -Hexane Efficiency 110-54-3 71-43-2 Benzene Overall Uncontrolled Control Emission Factor (Specify_ Units)_ l • %I 'ble4�)4 95% 1�.2ilb/MMscf 95% Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled Actual, Emissions (lbs/year) Controlled Actual Emissions (lbs/year) t^^uSs ajetloxcC Mass Balance 3,408.5 623.1 170.4 31.2 108-88-3 Toluene 95% GG.l.tb/MMscf Mass Balance 488.3 24.4 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that Potential to emit (PTE) emissions for non -criteria pollutants are as follows: Uncontrolled n -Hexane Emissions (Ib/yr) `.65 -el Controlled n -Hexane Emissions (lb/yr): lot5 Uncontrolled Benzene Emissions (Ib/yr): 583•Controlled Benzene Emissions (lb/yr): 29 • Uncontrolled Toluene Emissions (lb/yr): 457 Controlled Toluene Emissions (lb/yr): vt. s Please include these PTE emissions in the Notes to Permit Holder section of the permit. Form APCD-200 - General APEN - Revision 3/2019 a 5 I° n.w.im. ,1d -- n+..nntcnwronm •p+ f�( J Cakt)lak c. rpt k fl1 Permit Number: Q9WE 1136 AIRS ID Number: 123 /0090/125 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance 0✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.Rov/cdphe/apcd COLORADO Form APCD-200 - General APEN - Revision 3/2019 Air Pollutant Emission Notice (APEN) and Application for Construction Permit General APEN — Form APCD-200stli,,.. '01c All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/129 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 395322 Form APCD-200 - General APEN - Revision 3/2019 1 I A 0 /(� ,COLORADO Hoo ul,$Enul� rvl� Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/129 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Revising emissions to include startup and shutdown emissions (SUSD) as two additional permit limits 3 For company name change, a completed Company Name Change Certification Form (Form APCD-1O6) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Natural gas compression turbine TURB-1 Manufacturer: Solar Model No.: Taurus 70 Company equipment Identification No. (optional): For existing sources, operation began on: TURB-1 Serial No.: 1006B 8/5/2018 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: -Dec-Feb: " Mar -May: days/week weeks/year Jun -Aug: Sep -Nov: Form APCD 200 - General APEN - Revision 3/2019 2 I A iMANIMMUIVRIM COLORADO Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/129 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limits (Specify Units) Material Consumption: Finished Product(s): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM)', 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No Discharge Height Above Ground Level (Feet) Temp ( F) Flow Rate (ACFM) Velocity ;(ft/sec) TURB-1 45 941 111,141 147 Indicate the direction of the stack outlet: (check one) ® Upward ❑ Horizontal ❑ Downward Other (describe): Indicate the stack opening and size: (check one) O Upward with obstructing raincap ❑✓ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): COLORADO Form APCD-200 - General APEN - Revision 3/2019 Permit Number: 09WE1136 AIRS ID Number: 1 23 /0090 /129 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTUIhr) " Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limits (Specify Units) '. .lt MMBtu/hr 183.86 MMscf/yr* c,,'S1-.'6.5 MMscf/yr From what year is the actual annual fuel use data? 2018* Indicate the type of fuel used6: - ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ✓❑ Field Natural Gas Heating value: 9o� f BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: ❑ Other (describe): Heating value (give units): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. *Source started operation in August 2018. ?-\e_a\V E,c5 c vv,a- c-a.c wreA da_to Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduct?on): Pollutant " Control Equipment,, Description ' Overall Collection Efficiency! Overall" Control Efficiency, (%reduction in emissions) TSP (PM) PM10 PM2_s SOX NO. CO VOC Other: r Oq1,111 Form APCD-200 - General APEN - Revision 3/2019 I COLOR A DO Lap rtmant rt 1'v 5 4 I AV 144011V Enwr91,tn,a Permit Number: 09VVE 1136 AIRS ID Number: 123 /0090/129 [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018* Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutantc Uncontrolled Emissioorn : (Sp cify Units) Emission' Factor Source . CAP etc.) fg i Actual Annual Emissions �� : �`, r" �, .: Requested Annual Permmt s� Emission Lnroit(s)r ' U• (tons/yealr) a$ ' 'Coons/yelard)' U (tons/yealr) d c( ons/yeaea n TSP (PM) 6.60E-31b/MMBtu AP -42 0.67 0.67 l °tl [•1l PMto 6.60E-31b/MMBtu AP -42 0.67 0.67 ICI I.qI PMz.s 6.60E-3Ib/MMBtu AP -42 0.67 0.67 1.011 \."iI Sax 3.40E-3 lb/MMBtu AP -42 0.35 0.35 O.ct O ag NO. 5viXtt5Li?IMMTEP.) I:co ^t t.o '7lcaCxk Manufacturer 4.80 4.80 K-03 I o•ou �o.ouI tc.123/ o•ai1(a•a1l CO 1 t6 1 manufacturer 5.63 5.63 / o.qt /coos- a4.sq � i4.c9 / o.210.A VOC t`lei4 �� % ,�tcve.i.t-. as -ELI .o.,I oc vt✓ 0.21 0.21 akol / o.i�fo.�3 o.bl�..tc(o.og Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that the requested permit limits for NOx, CO, and VOC include three scenarios: normal operation, startup, and shutdown emissions Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes ❑✓ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number 0veralh.:' Control . Efficiency. =: Uncontrolled Emission Factor (Specify Units)' Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled.. Actual Emissions (lbs/year). Controlled Actual Emissions? (lbs/year);, :. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 3/2019 .COLORADO 5 I .6,7.1=4,11,-„,,,t' Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/129 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. �{812ecq Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title' Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance ✓❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. f Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department -of Public Health and Environment For more information or assistance call: Small Business Assistance Program. (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.Rov/cdphe/apcd Form APCD-200 - General APEN - Revision 3/2019 COLORADO Vep.me�nf d nAhc 6 I General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: ‘-.1/0 17th St, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 335323 Form APCD-200 - General APEN - Revision 3/2019 COLORADO AV Qcpvawn[of PclFr 1 I flar�N4flrv14n n+n Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name' ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 O Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Revising emissions to include startup and shutdown emissions (SUSD) as two additional permit limits 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Natural gas compression turbine TURB-2 Manufacturer: Solar Model No.: Taurus 70 Company equipment Identification No. (optional): For existing sources, operation began on: TURB-2 Serial No.: 1005B 8/9/2018 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Jun -Aug: Form APCD-200 - General APEN - Revision 3/2019 2 I Sep -Nov: ;COLORADO D.ww-.a d e ahhc 11Witb E#WMMff)fl Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090/ 130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limits (Specify Units) Material Consumption: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. ,{ Operator Stack ID No —. , . - : "=; :-a._ t -: >_ Discharge Heights � _ . Above Grou d Level u_wG'i, Temp F) �FIo Ra,e (AC ) r ₹} Velocity (ft/sec TURB-2 45 941 111,141 147 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal O Downward O Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap Circular interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 3/2019 COLORADO 3 Hsahl! 8 RrtMr?!y�aPA Permit Number: 09WE 1136 AIRS ID Number: 1 23 / 0090 /130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment 8c Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units); Requested Annual Permit Limits (Specify Units) let; .IL MMBtu/hr 184.15 MMscf/yr* �3� �� MMscf/yr From what year is the actual annua fuel use data? 2018* Indicate the type of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑✓ Field Natural Gas Heating value: 901.1 BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: ❑ Other (describe): Heating value (give units): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. *Source started operation in August 2018. Section 7 - Criteria Pollutant Emissions Information pc,+' w `a vvu Ga c bt, real 64.dost . iZit eI. Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant '. Control Equipment Description , : Overall Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) PMio PM2.5 SOX NOx CO VOC Other: Form APCD-200 - General APEN - Revision 3/2019 41 COLOR400 bepaftment at h@he HYennE€nws?fe.�ann Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018* Use the following table to report the criteria pollutant emissions from source: Use the data reported in Sections 4 and 6 to calculate these emissions. Pollutant Uncontrolled • Emission • (Specify Units) Emission Factor • SourceFactor (AP-42, AP eic.Mfg., ctiial•An ualErniss onsq �b®•- a :. n,x ; 4g `. �.: -r;p. Reques nngal Permit.;. : • Emission Limits) 3:::• p Fa l .,,Q.V- �;e�:, n.6w =u: Uncontrolled Control)r) d7 Uncontrolled y • Controlled.' TSP (PM) 6.60E-3Ib/MMBtu AP -42 0.67 0.67 l.cAl 1.ct5 PM:o 6.60E-3 Ib/MMBtu AP -42 0.67 0.67 \.' 1..C PM2.5 6.60E-31b/MMBtu AP -42 0.67 0.67 l.ql l.ctl SOa 3.40E-3 lb/MMBtu AP -42 0.35 0.35 5.°t`ti, o• a% NOx 5`°Ix,7.1' kbli..4-t 1,0 Ible7K.K %CO Manufacturer 4.81 4.81 ri.O / 0.b\\ O.O11 i 3 IS. o,Oll p,011 e l 821.6 ,,uAk ems— L1aIL4Y Manufacturer 5.63 5.63 ta•sl I / o•9z/o•as 1s�(n914osa om / 0.19 (o.cs , V0C kl. 1Z,c.Lr...ic ' wkr,..(Ativtil 0.21 0.21 o.p1 / 0.1110.Qg Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that the requested permit limits for NOx, CO, and VOC include three scenarios: normal operation, startup, and shutdown emissions Section 8 Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number • Chemical Name• Overall Control' Efficiency Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled Actual - a Emissions (lbs/year) Controlled:..:. Actual Emissions (lbslyear) Yes 0✓ No 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 3/2019 ,r cO.c Ac . -''QS ro 13O11 5I COLORADO a • u. m of PulAk +R9en. DIV1ffN.r1H11 Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. C /200 Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance ✓� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term; or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado. gov/cdphe/apcd Form APCD-200 - General APEN - Revision 3/2019 fi colORk00 Glycol Dehydration Unit APEN Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for glycol dehydration (dehy) units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / 131 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: DCP Operating Company, LP Mewbourn Gas Processing Plant Site Location SE 1/4, Section 35, T4N, R66W County: Weld 35409 Weld County Road 18 Mailing Address: (Include Zip Code) 370 17th St, Suite 2500 Denver, CO 80202 NAICS or SIC Code: 1321 Contact Person: Phone Number: E -Mail Address': Roshini Shankaran (303) 605-2039 RShankaran@dcpmidstream.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permts, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 395911 Form APCD-2O2 - Glycol Dehydration Unit APEN - Revision 3/2019 • COLORADO 1 I n�+n.� Hnru SEnvL WIF4A nn nl Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/131 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action D NEW permit OR newly -reported emission source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 O Add point to existing permit ✓❑ Change permit limit O Transfer of ownership4 O Other (describe below) - OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: The still vent stream and flash tank stream are recycled back to the plant inlet via dedicated VRUs 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Natural Gas Triethylene Glycol Dehydration Unit Company equipment Identification No. (optional): For existing sources, operation began on: D-2 11/30/2018 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment area? hours/day Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions? 0 days/week weeks/year Yes ❑ No Yes ❑✓ No Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019 : © _ COLORADO 2 i iel� fl�!PA�B61Wtrolv!knl Permit Number: 09WE1136 AIRS ID Number: 123 /0090 / 1 31 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Professional Projects,Inc Dehydrator Serial Number: 5667 Model Number: T-9600 Reboiler Rating: Indirect MMBTU/hr Glycol Used: ❑ Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) TriEthylene Glycol (TEG) Glycol Pump Drive: 0 Electric Pump Make and Model: Gas If Gas, injection pump ratio: Glycol Recirculation rate (gal/min): Max: 1.5 • Lean Glycol Water Content: Wt.% Requested: 40 • Acfm/gpm # of pumps: 1 (+1 BU) Dehydrator Gas Throughput: Design Capacity: Requested5: 230 • MMSCF/day 83,950 • MMSCF/year Actual: 7,292* MMSCF/year Inlet Gas: Pressure: 878 • Water Content: Wet Gas: Flash Tank: Pressure: 60 . Cold Separator: Pressure: Stripping Gas: (check one) psig lb/MMSCF psig psig ❑✓ None ❑ Flash Gas ❑ Dry Gas O Nitrogen Flow Rate: scfm Temperature: I] Saturated Temperature: Temperature: 80 • Dry gas: 147• °F 1.6 • °F °F lb/MMSCF ❑ NA ❑✓ NA Additional Required Information: 0 Attach a Process Flow Diagram ▪ Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) ❑✓ Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limits) should consider future process growth. * Source started up in November 2018. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019 COLORADO 3 I '. aMnneennrow•+m Permit Number: 09WE1136 AIRS ID Number: 123tom/ 131 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information e®graphical Coordinates (Latitude/Longitude or UTM) 40.2666 / -104.7553 Operator Stack ID N® Discharge Height Above Ground Level y Temp ( F) Flow Rate (ACFM) Velocity ec (ftls) . D-2 130 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal 0 Downward ❑ Other (describe): O Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 8 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. O Condenser: Used for control of: Type: Make/Model: Maximum Temp: °F Average Temp: °F Requested Control Efficiency: ❑✓ VRU: Used for control of: V0C and HAPs from still vent and flash tank strearhs Size: Make/Model: Requested Control Efficiency: 100 VRU Downtime or Bypassed: Z % ❑ Combustion Device: Used for control of: VOC and HAPs from still vent and flash tank streams Rating: MMBtu/hr Type: Backup Flare (F-3) Make/Model: ZEECO/ FL -5100 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: °F Waste Gas Heat Content: t953 / 1`145 Btu/scf Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: 0.20 MMBtu/hr Closed • Loop System: Used for control of: Description: System Downtime: ❑✓ Other: Used for control of: VOC/HAP from still vent / flash tank (z.%; VRU DT only) Description: Backup/Maintenance Flare (F-3) Requested Control Efficiency: 95 Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019 !COLORADO 4 I _mmVw'vic NMI ro.m5M t�`J O V c -c' t co. - Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 131 PM [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can overall (or combined) control efficiency (% reduction): be used to state the Overall Requested. Control Efficiency (% reduction in emissions)`, SOX NO. CO voc HAPs Other: VRUs to control still vent and flash tank streams 9 octets.) 'Rtuft, 100 (2tdowntime to plant flare) VRUs to control still vent and flash tank streams to payt, 100 (t l0downtime to plant flare) From what year is the following reported actual annual emissions data? 2018* Criteria Pollutant Emissions Inventory Pollutant PM Emission Factor Source (AP -42, Mfg., etc.) Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis lb/MM Btu Uncontrolled Emissions (tons/year) Controlled Emissions6 (tans/year)'_ Uncontrolled Emissions (tons/year) Controlled Emissions_ (tons/year) SOX Mass balance 0.0 0.0 0.08 0.08 NO. 0.068 AP -42 0.0 0.0 CO 0.310 lb/MM Btu AP -42 0.0 0.0 VOC 23.G a- Ib/MMscf GlyCaic 0.024 0.001 lO to. oS 2-52 Lot Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (poundsl year) Controlled Emissions6 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2, 2, 4- Trimethylpentane 540841 Other: Note that Potential to emit (PTE) emissions for non -criteria pollutants are as follows: Uncontrolled n -Hexane Emissions (lb/yr): Ask.A. Controlled n -Hexane Emissions (Ib/yr): I IZ Uncontrolled Benzene Emissions (Ib/yr): ''S�'t Controlled Benzene Emissions (Ib/yr): 301 Uncontrolled Toluene Emissions (Ib/yr): hl,ZSS Controlled Toluene Emissions (lb/yr): z�1-.z Please include these PTE emissions in the Notes to Permit Holder section of the permit. leave COLORADO momfr Pat Punk cula'dv,� . ND5 l l ( 0,71 v51 Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/131 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: �✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019 6 I COLORADO awtrao* at raehc Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit NOV - 1 2018 All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. print shop, mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. Do not complete this form for the following source categories: - Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that are fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: //www.cotorado.Rov/pacific/cdphe/apen-or-air-permit-exemptions. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09W E 1136 AIRS ID 123 /0090/133 Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@DCPMidstream.com I Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-220 - Boiler APEN - Revision 7/2018 389845 COLORADO 1 I ifIna.a MM[gib €Y1V1lP111n9!:1 Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090 / 133 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name3 O Add point to existing permit ❑r Change permit limit O Transfer of ownership4 O Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: 40.8 MMBtu/hr hot oil heater, fueled by natural gasl -\cs&car ;S \:v scr-c1k -Co a se•Likt- t xrti vbL & 3L.D Manufacturer: Heatec Model No.: HCI-16010-50-Q-G Serial No.: H117-080 Company equipment Identification No. (optional): For existing sources, operation began on: HT -02 08/03/2018 For new, modified, or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Seasonal use Dec- Mar- June - percentage: Feb: May: Aug: hours/day Are you reporting multiple identical boilers on this APEN? ❑Yes Ei No days/week weeks/year Sept - Nov: If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Form APCD-220 - Boiler APEN - Revision 7/2018 COLORADO 2 l hparlmmt d PoHlc 1101116 Enaitonroot R \,mac trix1aktA Ca-lcote \oitts. l-\Dj L‘lobll1 Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/133 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) '. 40.2666 / -104.7553 Operator Stack ID No• Discharge Height Above Ground Level (Feet}.,...r. Tam s Flow Rate CF ` Velocity (ft/sec) ....., HT -02 20 350 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): O Other (describe): 0 Upward with obstructing raincap Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate. (MMBTU/hr) Actual Annual Fuel Uses (Specify Units)(Specify Requested Annual Permit Limit Units 40.8 N/A ,� MMSCF/yr From what year is the actual annual fuel use data? N/A Fuel consumption values entered above are for: 0 Each Boiler 0 All Boilers 0 N/A Indicate the type(s) of fuel used: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑✓ Field Natural Gas Heating value: 1,050 BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur Content: ❑ Other (describe): Heating value (give units): 5 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 6 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 7/2018 COLORADO 3 I aV I tic7art4-1 al A:Ct J t(n,UI11t EY1uitAr<MM#i11 Permit Number: 09WE1 1 36 AIRS ID Number: 123 / 0090 / 133 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 No If yes. Dlease describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PMio PM2.5 SOx NO. CO VOC From what year is the following reported actual annual emissions data? N/A Use the following tables to report the criteria pollutant emissions from source: Use the data reported in Section 5 to calculate these emissions.) Primary Fuel Type (natural gas, #2 diesel, etc.) Pollutant Uncontrolled Emission Factor S Units)(AP (Specify Emission Factor• Source 42; Mf3.,_etc.) Actual Annua[ Emissio , p .: .. ' Re uested Annual Permit q Emission Limit(s)6 . .._. _° . Uncontrolled (tons/year) Controlled8 (tons/year) Uncontrolled (tons/year) Controlled (tonslyear) Natural gas TSP (PM) .sz fek>ro,„,,,,cf ,AP -Lit- I.u-1 i•o'-1 — PM,o 5 PM 2.5 • 3.17)tfy w scE Az-'-l'l_ 1.71 l.Ci-+ SOx lv.l`b`t#ol ilmr f_r . AP -42 D.oq, o. pg - NOx 54.4?t lsC1. AP -42 lo.99C �0•`6A- CO $io.`�i'l_ f bi rrir 'ijv� . AP -42 l 1. S°-i r 1k . S ti VOC es,kpipl°1rAti7SC{. AP -42 O. -1-'.o i 0.7r0 J�yr�1i a'or,atteek . E✓ Check this box if multiple fuels were NOT fired during this reporting period and skip to Section 7. DS If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria pollutant emissions table below: Secondary Fuel Type (#2 diesel, waste oil, etc.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42 Mfg., etc.) Actual Annual Emissions : :• .�.�` o=ff lie uested Annual Permit q . Emission Limits b Uncontrolled (tons/year) Controlled8 (tons/year) Uncontrolled (tonslyear) Controlled (tons/year) TSP (PM) PM -to PM2.5 SOx NOx CO VOC 6 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 ii€t15 Form APCD-220 - Boiler APEN - Revision 7/2018 41 COLORADO L!cp r.en: of 1,N.Ic Hnattat ¢ EnuI,gnlnst;t AIRS ID Number: 123 10090 / 133 Permit Number: 09WE 1 136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and s Pollutant ��'`'` �� ,r � Actual Annual Emissionsy .. h , v,,t tiNa`!•'t 3f�R �xt ti6- ..,;K, 'h. -� Requesteci�Annual:Per'iritTM�g :e• •9 s I <: ' •r Emission;Eimit{s\) Na-''isfi`m 11:°t5i,,,,,,,e.. u,'Fwp.. ,, et:5- a�':r :... Uncontrolled (tons/year) ' Controlled8 (tons/year) . Uncontrolled (tons/year) Controlled ' -. • (tons/year) TSP (PM) PMio PMz.s SOx NOx CO VOC 6 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Primary Fuel Type (natural gas, #2 diesel, etc.). Natural gas CAS Number' 110-54-3 Chemical Name n -Hexane Overall Control Efficiency 0% Uncontrolled Emission Factor (specify units) _ 1.%5 (*ni.k5ct Emission Factor Source (AP -42, Mfg., etc.) AP -42 Uncontrolled Actual Emissions (lbsl year) N/A Controlled Actual .. Emissions' (lbs/year) . N/A Note that Potential to emit (PTE) emissions for n -Hexane is as follows: Uncontrolled Emissions (lb/yr): yas Controlled Emissions (Ib/yr): '-1'5 Please include these PTE n -Hexane emissions in the Notes to Permit Holder section of the permit. I I I I ✓❑ Check this box if multiple fuels were NOT fired during this reporting period and skip to Section 8. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the criteria polfutant (HAP) emissions table below: Secondary Fuel Type (#2 diesel, waste oil, etc.) CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor . units (specify ) Emission Factor Source (AP -42, Mfg:, etc.) Uncontrolled Actual Emissions.: (lbs/year) y ) Controlled Actual Emissions' (lbslyear) 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 7/2018 pc-i( .COLOR ADO 5 I °-- fkrarcritent,IP,t., HogNI_en.I. .4.01 \--kW fiio J(I Permit Number: 09WE 1 1 36 AIRS ID Number: 123 / 0090 / 133 [Leave blank unless APCD has already assigned a permit # and AIRS ID] If multiple fuels were fired during this reporting period, use the following table to report the TOTAL non -criteria pollutant (HAP) emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 7: Uncontrolled (tons/year) '. ontrolled° tons/year) 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Si• nature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box if you want: ❑✓ Draft permit prior to public notice ED Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-220 - Boiler APEN - Revision 7/2018 6I COLORADO I or.,nnr:oivnnk TicAiA� EfAitomntrm Fugitive Component Leak Emissions APEN Form APCD-203 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for fugitive component leak emissions only. If your emission source does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 1136 AIRS ID Number: 123 /0090/135 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th St, Suite 2500 (Include Zip Code) Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Marie Cameron Phone Number: (303) 605-2029 E -Mail Address2: MECameron@dcpmidstream.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 414834 ®VICOLORADO 1 Hnith b Em/ronmMl Permit Number: 09WE1136 1136 AIRS ID Number: 123 /0090 / 135 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑✓ Change process or equipment O Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t Notes: Adding additional fugitive component counts for future projects. and revising controls to apply control factors applicable to NSPS OOOO/OOOOa. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information Company equipment Identification No. (optional): For existing sources, operation began on: FUG -2 8/3/2018 For new or reconstructed sources, the projected start-up date is: El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Facility Type: ❑ Well Production Facility5 ❑ Natural Gas Compressor Stations Q Natural Gas Processing Plants ❑ Other (describe): hours/day days/week weeks/year 5 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section VII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 2AgI COLORADO anc of Publk HOOT i EIMIDI m.m Permit Number: 09WE 1136 AIRS ID Number: 123 /0090 / 135 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? Will this equipment be operated in any NAAQS nonattainment area? Will this equipment be located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? Is this equipment subject to 40 CFR Part 60, Subpart OOOO? Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? Is this equipment subject to 40 CFR Part 63, Subpart HH? Is this equipment subject to Colorado Regulation No. 7, Section XII.G? Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? 8/3/2018 ❑✓ Yes ❑ Yes ❑✓ Yes ❑ Yes ❑ Yes ❑✓ Yes ❑ Yes ❑✓ Yes ❑ Yes ❑ Yes ❑ No ❑✓ No ❑ No ❑✓ No ❑✓ No ❑ No ❑✓ No ❑ No ❑✓ No ❑✓ No Section 5 - Stream Constituents ❑✓ The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight % content of each applicable stream. Stream VOC:" (wt' %) Benzene (wt %)`: Toluene (wt %) ' Ethylbenzene (wt %) Xylene (wt %) n -Hexane; (wt %) .. ''4: Trimethylpentane ' (wt %) - Gas 28.09%. 0.07%. 0.09%• 0.01% . 0.03%' 1.42%- 0.06% Heavy Oil (or Heavy Liquid) — — — — — Light Oil (or Light Liquid) 100. 0.23 �0. 0.33% 0.04%5.06% 0.11%' 0.22% Water/Oil _ - - - - - - Section 6 - Geographical Information Geographical Coordinates' (Latitude/Longitude or UTM) 40.2666 / -104.7553 Attach a topographic site map showing location Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 COLORADO 3 I A- IH dm.msn, Permit Number: 09WE1136 AIRS ID Number: 123 /0090/135 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: ❑ LDAR per 40 CFR Part 60, Subpart KKK ❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump ❑ Quarterly Monitoring - Control: 70% gas valve, 61% tight liquid valve, 45% light liquid pump ✓❑ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa ❑✓ Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: ❑ No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 4 I AVCOLORADO Iflotilla Ent„:Z o, Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ 135 Gas [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. ❑✓ Table 2-4 was used to estimate emissions7. Table 2-8 (< 10,000ppmv) was used to estimate emissions7. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: ❑✓ Estimated Component Count El Actual Component Count conducted on the following date: November 201 8 Equipment Type Connectors 3,125 • Open -Ended Lines Pump Seals 4,207 949 Z lip. Counts 5,488 1 Emission Factor 0.000440 • 0.000860 0.004410 0.009920 0.019401 ' Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source eavy Oil (or Heavy Liquid)' Counts Emission Factor Units Light Oil(or Light Liquid) Counts 9,057 • 1,966 , 58 • 3,320 • 37 -4.11 Emission Factor 0.000463 0.000243 0.028660 0.005510 ' 0.016535 , Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source Water/Oil Counts Emission Factor Units 7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The "Other" equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seats, or valves. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 5 I COLORADO HnauR b EnVlranmhst V. (c),Vo_LS R cA `; CLL - G k - 1�S t017.1119 Permit Number: 09WE1136 AIRS ID Number: 1 23 /0090 / 1 35 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: (Use the data reported in Section 8 to calculate these emissions.) Chemical Name CAS Number Actual Annual Emissions Requested Anna t Permit Emission ( )11 Uncontrolled (tons/year) Controlled1° (tons/year) Uncontrolled (tons/year) Controlled (tons/year) VOC 30.52 4.90 193.i 15.11 - Does the emissions source have any actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? 0 Yes El No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name CAS, Number Actual Annual Emissions Requested Annual Permit Emission Limit(s)11 Uncontrolled (lbs/year) Controlled1°' (lbs/year) Uncontrolled (lbs/year) Controlled (lbs/year) Benzene 71432 899.5 71 Toluene 108883 1279.-j 100 Ethylbenzene 100414 Xylene 1330207 422.'5 33 n -Hexane 110543 19504 risls- 1534 16,c) 2,2,4 Trimethylpentane 540841 864.8 68 Other: 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability, and gas composition variability. ?lca1,&c ��Ctt�\o iowk_S bs to Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 COLORADO —Pubtic Ha2W bEMiw IMOET Permit Number: 09WE 1136 AIRS ID Number: 123 /0090 / 135 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. ?(,crr�Y1�'2 Signature of Legally Authorized Person (not a vendor or consultant) Marie Cameron a47/[61 ate Senior Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 3/2019 COLORADO 71��Im � H.aI1Lb F.11VIRM1inI General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: s-1/0 17th St, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 39..5316 Form APCD-200 - General APEN - Revision 3/2019 1 I AVCOLORADO ! li,, 6 >n7111 n'ml Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ✓❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: Acid Gas Flare (F-2) to serve as backup control to amine unit AM001 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Flare for amine unit AM001 backup control during TO downtime Manufacturer: Zeeco Model No.: UFW-1 2/24 Serial No.: 32097 Company equipment Identification No. (optional): For existing sources, operation began on: F-2 4/12/2018 For new or reconstructed sources, the projected start-up date is: ✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 3/2019 days/week weeks/year Jun -Aug: Sep -Nov: :COLORADO 2 I }11M14R N4 HA Permit Number: 09WE 1 1 36 AIRS ID Number: 123 /0090/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Ft Material Use ❑ Check box if this information is not applicable to source or process 2018* From what year is the actual annual amount? Description Design Process Rate = (Specify Units) Actual Annual =' ' "" Amount (Specify Units) Requested Annual ... Permit Limits (Specify Units) Vii•: .++'-•�•''•'%�a:'•f Material :Consumption I`LL Natural gas processed by AMD01dudng TO downtime 2,274 MMscf/yr* 3,260 MMscf/yr Fin shed,: _ Finis {Product(') w s Requested values will become permit limitations. Requested limit(s) should consider future process growth. * Source started up in April 2018 Section 5 - Stack Information eograpa Coordinate ordd nate atitudelLongrrudeor UT/ 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. 4 0peratoE� S a WID.,No� Discharge He ht� Above Ground Leve eet Temp_: ; r' 3 � Flo Rate ' F Velocity )'s c) f ) F-2 75 Indicate the direction of the stack outlet: (check one) ❑✓ Upward O Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) O Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): Form APCD-200 - General APEN - Revision 3/2019 COLORADO MOM. aQi 74nM 3 I nyanna=nrira�vnem Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTUIhr) ' " Actual Annual Fuel Use " (Specify Units) ,` Requested Annual Permit Limits (Specify Units) 0.14 (pilot only) . 44.89/18.25 MMscf/yr (Waste / Assist+Purge)* iO3•t / 245.cgMMscf/yr (Waste /Assist+Purge) From what year is the actual annua fuel use data? 2018* Indicate the type of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ✓❑Field Natural Gas Heating value: O Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal ❑✓ Other (describe): Amine acid gas / Residue gas Heating value (give units): 14.09 / 1,092 Btu/scf 1,050 BTU/SCF y,..O1Yok.cy latiaLcs, t'"f5 o f5tegh BTU/lb Ash content: Sulfur content: Heating value: s Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. * Source started up in April 2018 Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control Efficiency,.. ,(% reduction in emissions) TSP (PM) PM10 PM2.s SOX NO. CO VOC Flare 100% 95% Other: HAPs Flare 100% 95% Form APCD-200 - General APEN - Revision 3/2019 A ((©©�� COLORADO S beOli r4:4111;41-1 4: d b:k Y ,t,,e $Fn.IhN11i.5n1 Permit Number: 09WE1136 1136 AIRS ID Number: 123 10090i136 'TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? 2018* Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units). Emission Factor Source (AP -42, Mfg., etc.) Controlled? (tons/year) nnual Permi mission Limits s Uncontrolled (tons/year) Uncontrolled (tons/year) Controlled (tons/year) 7.6 Ib/MMscf AP -42, neg. neg. --/0.005 PMto 7.6 lb/MMscf. AP -42 neg. neg. c PM2.5 7.6 lb/MMscf AP -42 • neg. neg. --/ 0.00 .- --/0.00 Soo I ci 0.6 Ib/MMscf. Sae -specific l AP -42 • 0.12 0.12 1.89 13.x+ 616-4 1.81 / .tcM6to4 NOX 0.0681b/MM Btu / 100 lb/MMscf AP -42 • 0.73 0.73 1.04/0.06 1.04/0.06 Co 0.31 Ib/MMBtu 184 Ib/MMscf AP -42 3.22 3.22 4/3/0.05 4.73/ 0.05 VOC 951.41 I / 5.5 lb/MMscf Site-specificl AP -42 * 37.72 1.89 60.%0 / 0.003 3. / 0.003 Other: 14-t% XlasN i3ata�cC O. oS 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. * Source started up in April 2018 Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Number` n -Hexane Overall Control Efficiency Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled Actual Emissions (lbs/year) Yes ❑ No Controlled Actual Emissions? (lbs/year) 110-54-3 71-43-2 Benzene 95% Z3'l.tds „, Ap-Jci.en L uses/ .1 `� �$ A �- Utz 95% teLa lb/MMscf Gas Analysis 2,073 3,456 104 173 108-88-3 Toluene 95% s7,.o lb/MMscf Gas Analysis 2,468 123 1330-20-7 Xylenes 95% 12/.31 lb/MMscf Gas Analysis 669 33 67-56-1 Methanol 95% I1•' 3 lb/MMscf Gas Analysis 1,128 56 Note that Potential to emit (PTE) emissions for non -criteria pollutants are as follows. Emission factors associated with these emissions are shown above. Uncontrolled n -Hexane Emissions (Ib/yr):zlrp►g-.9 Controlled n -Hexane Emissions (Ib/yr): 152 Uncontrolled Benzene Emissions (lb/yr): `d` vii. Controlled Benzene Emissions (lb/yr): 441 Uncontrolled Toluene Emissions (Ib/yr):n3 Controlled Toluene Emissions (lb/yr): 344 Uncontrolled Xylenes Emissions (lb/yr): ltitl•c Controlled Toluene Emissions (Ib/yr): 71 Uncontrolled Methanol Emissions (lb/yr): l 1 v,1 Controlled Benzene Emissions (lb/yr): 72 Please include these PTE emissions in the Notes to Permit Holder section of the permit. �•ccl,U ��5 vor V i7AL±`s1 Cctl co I a.tio . "5 o`&11,711° Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 3/2019 'COLORADO 6 I roar Avf oar d Pu51k 64 wromPH NOV ' 1 2018 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Namet: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E -Mail Address2: RShankaran@DCPMidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 389844 pp COLORADO Form APCD-200 - General APEN - Revision 7/2018 Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 O Add point to existing permit O Change permit limit O Transfer of ownership4 O Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Mewbourn Ill flare (F-3) for maintenance purposes 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Flare for Mewbourn Ill Train Manufacturer: Zeeco Model No.: FL -5100 Company equipment Identification No. (optional): For existing sources, operation began on: F-3 08/03/2018 Serial No.: 31934 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 7/2018 Jun -Aug: Sep -Nov: 21 AV(COLORADO {>��neFra2-1„, Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use El Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process- Rate. Specify Units) ctual Annual Arnounti Specify Units) Requested Annua Permit L.i it5 Speeify Units, 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information 40.2666 / -104.7553 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. 3 `rr �t tP ,1 Operator , Stack ID No �' ; {,^rte D)scharge Height '.^et Above Ground Level (Fetjs P - {:1 s 5'yS^ Temp ( F1, ,.. t l S-. .d T Ftow Rate tACFM)Cftlsec) ,Velocity F-3 120 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal O Downward Other (describe): Indicate the stack opening and size: (check one) O Upward with obstructing raincap Ei Circular Interior stack diameter (inches): 70 ❑ Square/rectangle Interior stack width (inches): o Other (describe): Interior stack depth (inches): Form APCD-200 - General APEN - Revision 7/2018 3 I I COLORADO 3 RaLU &Envlml Irn l Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use � (Specify Units) Requested Annual Pei mit Limits (Specify Units) 0.2 (pilot only) • Z1 -<C®„2, b°'""scxilc' 9O..O ,MMscf/yr (Purge + Waste) From what year is the actual annual fuel use data? Indicate the type of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) Field Natural Gas Heating value: (oo BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash content: Sulfur content: Heating value (give units): 1O92 / lz t� Btu/scf El Other (describe): Residue gas/Inlet gas 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency', Overall Control Efficiency (56 reduction in emissions) ? , TSP (PM) PMto PM2.5 SOX NO. CO voC Flare 100% 95% Other: HAPs - Flare 100% 95% Form APCD-200 - General APEN - Revision 7/2018 qc3, c-dK CA-tuJl t4 . 5 l,�s ;Lc\ Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/137 TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP; 42, Mfg•, etc.) Uncontrolled (tons/year) Controlled (tons/year) Uncontrolled (tons/year) , Controlled .wi (tons//year) 4.$ Ib/MMscf AP -42 0.01 0.01 PM10 .� Ib/MMscf AP -42 0.01 0.01 PM2.5 1-,cd lb/MMscf AP -42 0.01 0.01 SOX NO. CO VOC Other: AP -42 o.cot Isjes�,sc-f o.c,cb " k' \8h) loi.`rH ,14.. i c. AP -42 0.s\ �lr�^,'i.) ��.4�!�(►•,,c� AP -42 o.q 3.61°1 las.s.ow X51.mst4 C7,sAva\-fVs/ s.k.:44, Nauti44 Aa- It 5-4.2 0.0 3.(11 0 0.os Ilo.K'7) 0.02 0.0 35 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number n -Hexane Overall Control Efficiency 110-54-3 95% Uncontrolled Emission Factor,- /csifyy Units) Emission Facto r Source (AP -42, Mfg., etc.) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions? (lbs%year) I11.Slo IblvArns. 5Av,2\ ( ft�-BIZ 1OF'-kS SS1 71-43-2 Benzene 95% rcy},Ib/M Mscf Gas Analysis 111.3 108-88-3 Toluene 95% 9A Ibl Y..5Lf Gas Analysis 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that values above are Potential to emit (PTE) emissions for non -criteria pollutants. Please include these PTE emissions in the Notes to Permit Holder section of the permit. Form APCD-200 - General APEN - Revision 7/2018 Staik,.Ls.., �w ,AikkE' COLORADO 5 a� 1P C.� i Fi¢�[U�b EH�9xc.une.R1 0-00- CCA c&(i (a -ti- . NDS Permit Number: 09WE 1136 AIRS ID Number: 12.3 / 0090 / 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 10/3►/2DIg Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: �✓ Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 7/2018 61. COLORADO Faig E EfUi O tjUtttl NOV - 1 101 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE1136 AIRS ID Number: 123 /0090/ ( LAC) [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1321 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@DCPMidstream.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-200 - General APEN - Revision 7/2018 389847 COLORADO 1l VI � � x�ambcnmm�mnu Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/ it-t,O [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source O PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 O Add point to existing permit ❑ Change permit limit O Transfer of ownership4 O Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - o Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info £t Notes: APEN being submitted since emissions of NCRP (methanol) are > 250 lb/yr. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: One (1) 300 bbl methanol storage tank PTE throughput = 4,500 bbl/yr Manufacturer: TBD Model No.: TBD Serial No.:, T B D Company equipment Identification No. (optional): For existing sources, operation began on: METHANOL For new or reconstructed sources, the projected start-up date is: TBD 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 7/2018 Jun -Aug: Sep -Nov: COLORADO 2 I lHaan SEnuitennwtl Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/ ty o Methanol - [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information a Material Use O Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units) Actual Annual.:' Amount Specify Units) equested Annual Permit Limits (Specify Units) 4,500 bbl/yr 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information 40.2666 / -104.7553 ❑✓ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator � 4 } £"a D ischarge Height Above Ground Levelt� r ,, `/tf r#�' '1,?" r T byP xfl low ,:4i o METHANOL Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) O Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 7/2018 3 I COLORADO ❑cyrtrccntaf Puk(ic 14,4(11 b Enuttw:unent Permit Number: 09WE 1136 AIRS ID Number: 123 / 0090/ i yG [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment £t Fuel Consumption Information ❑✓ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) " Actual Annual Fuel Use (Specify Umts) Requested Annual Permit Limrt5 (Specify Umfs) From what year is the actual annual fuel use data? Indicate the type of fuel used6: D Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coat Heating value: BTU/lb Ash content: Sulfur content: O Other (describe): Heating value (give units): 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes Q No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description ' Overall Collection Efficiency; Overall Control Efficiency (% reduction m emissions)" TSP (PM) PMso PM2.5 SOX NO. CO VOC Other: Form APCD-200 - General APEN - Revision 7/2018 4I ICOIORA00 I Ka,1U & nt,a0a4k td3liia.. fruttc:u. .I Permit Number: 09WE 1136 AIRS ID Number: 123 /0090/ ND TSP (PM) [Leave blank unless APCD has already assigned a permit #i and AIRS ID] From what year is the following reported actual annual emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Controlled.' (tons/year) uestedn nnnuual°fermi Emission`L``tmit(s)5 2s Uncontrolled (tons/year) Uncontrolled (tons/year) Controlled (tons/year) PMto PM2.5 Sox NO,, CO voc 0.11 lb/bbl TANKS 4.09d N/A N/A 0.25 0.25 Other: 5 Requested values will become permit Limitations. Requested limit(s) should consider future process growth. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ✓❑ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42 Mfg., etc.) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions,_". (lbsryear)S 67-56-1 Methanol 0.11 lb/bbl TANKS 4.09d N/A N/A 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Note that Potential to emit (PTE) emissions for methanol is as follows: Uncontrolled Emissions (Ib/yr): 501. Controlled Emissions (lb/yr): 501 Please include these PTE methanol emissions in the Notes to Permit Holder section of the permit. coLoRADO 5I _ jaZ M�Eu Feumscn�n�zune,a Form APCD-200 - General APEN - Revision 7/2018 Permit Number: Q9WE1 136 AIRS ID Number: 123 / 0090/ \yo [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 10131/203 Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 7/2018 61 fle,rtrnserc -el Patin COLORADO HeurnaFrw-,:ian,a Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and REcErvED Application for Construction Permit JUL 1-2019 All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is ApCD filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will regSi join payment for a new filing fee. Sources This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 09WE 1136 AIRS ID Number: 123 /0090 /1+1 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Mewbourn Natural Gas Processing Plant Site Location: SE 1/4, Section 35, T4N, R66W nlu Address: p Code370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Contact Person: Marie Cameron Phone Number: (303) 605-2029 E -Mail Address2: mecameron@dcpmidstream.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 3/2019 401718 COLORADO 1 I r= xaanna enWwnmm,i Permit Number: 09WE1136 AIRS ID Number: 123 /0090 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership' ❑ Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft Notes: Previously classified as an insignificant activity. Pigging blowdown emissions associated with Mewbourn 1\. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Pigging - one (1) 16" receiver, one (1) 16" launcher, one (1) 24" receiver, one (1) 24" launcher, o,O_,) p � �, us' o rc- < <) ►t" rtra:,%veX', to rte- �3) �b" P G vcrs u.yLd cv r�) k‘,"(w ittxxxs. Company equipment Identification No. (optional): For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: TBD ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment area? hours/day Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XviI'.G?4 ( r i �7 Form APCD-211 - Gas Venting APEN - Revision 3/2019 El o days/week weeks/year Yes Yes Yes No No No COLORADO 2 I Ia Mcatllf 6 En.Iwnmenl t oP i%i&S, 1%5 4' k Permit Number: 09 W E 1136 AIRS ID Number: 123 / 0090 / (y' [Leave blank unless APCD has already assigned a permit 1 and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing O Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: Blowdown Events # of Events/year: O Other Description: 1k 52 Serial #: Capacity: gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: 35.5 scf; 123.3 scf; MMscf/event Lk', LS.41,eJtk ') 3 • S% SC -4 If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? 0 Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑✓ No * Requested limit is ‘t1- total pigging events/ year Vent Gas Heating Value: 1271.5 BTU/SCF Requested: i 0.0355 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year sm...t J R%cs, Molecular Weight: 22.15 / 18.3 VOC (Weight %) 22.78 / 7.6 Benzene (Weight %) 0.06/0 Toluene (Weight %) 0.04/0 Ethylbenzene (Weight %) 0.001 / 0 Xylene (Weight %) 0.01 / 0 n -Hexane (Weight %) 0.25 / 0.22 2,2,4-Trimethylpentane (Weight %) O.m3 D Note the receivers will handle inlet gas and the launchers will handle outlet gas Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 3/2019 'rCOLORADO 3 I . ttt xwnnre.mw.m..0 Rc. l`1/4t-.b pc r u,:p13 '& . HDS to 11-3,�(c i Permit Number: 09WE1136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] AIRS ID Number: 123 / 0090 / ►'A' Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2666 / -104.7553 perator Stack ID No Discharge Height �� - Above Ground Level (Feet). Temp ( F) Flow, Rate ,' (ACFM) Velocity (ftlsec2 PIG N/A N/A N/A N/A Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal" ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Other (describe): Interior stack diameter (inches): Upward with obstructing raincap Section 6 - Control Device Information ❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested. Control Efficiency: % VRU Downtime or Bypassed: % ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: % Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-211 - Gas Venting APEN - Revision 3/2019 4Im COLORADO I ate f P,±ki Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / It.k [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Overall Requested Control Efficiency (% reduction in emissions) PM SOx NOx CO VOC HAPs Other: From what year is the following reported actual annual emissions data? N/A Criteria Pollutant Emissions Inventoi Pollutant PM Source (AP -42, Mfg., etc.) Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled. Basin Units Uncontrolled Emissions (tons/year) Controlled -3 Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) SOX NOx CO VOC io. tscl> Ib/blowdown Eng. Estimate 4726 55 >4.26- S.` S - Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract (CA S) C ( ) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg.,etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 3/2019 ,COLORADO 5 A• NuNa6Em4onm.nl J a c,41Wta&ioyl5. ft 4S tok-hi Permit Number: 09WE1136 AIRS ID Number: 123 / 0090 / lL ` [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I, hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 7.0ace 69 /IV‘6\ Signature of Legally Authorized Person (not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ID Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.Rov/cdphe/apcd Form APCD-211 - Gas Venting APEN - Revision 3/2019 COLORADO 6 :Depaof Public j Health& Enelmnmenl Hello