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Home My WebLink About20180259.tiffPLA 6tVieu1 O/-29 -18 COLORADO Department of Public Health b Environment t Dedicated to protecting and improving the health and environment of the people of Colorado -Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 January 18, 2018 Dear Sir or Madam: RECEIVED JAN 2 2 2018 WELD COUNTY COMMISSIONERS On January 25, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Discovery DJ Services LLC - Discovery Lochbuie Compressor and Pump Station. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Deriver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer PI-C1NMAITP) L( pw LE of 4i3 IS e.K) 2018-0259 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Discovery DJ Services LLC - Discovery Lochbuie Compressor and Pump Station - Weld County Notice Period Begins: January 25, 2018 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: Discovery DJ Services LLC Facility: Discovery Lochbuie Compressor and Pump Station Compressor Station SEC 21 TIN R65W Weld County The proposed project or activity is as follows: Applicant proposes a compressor station and a pump station at the same location in the non -attainment area 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 17WE1195 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us Colorado Air Permitting Project 014 Project Details Review -Engineer. Package #: Received Date: Review Start Date: Section 01 - Facility Information Company Name:. Discovery Di 5ervi es.i. County AIRS ID: Plant AIRS ID: -Facility Name: Physical Address/Location: Type -of Facility: W hatindustry-segment? Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? ❑ Carbon Manaade (Co)._ Section 02 - Emissions Units In Permit Application 123 Weld Discovery LachbuieCompreslef�5 'ra�mp Section 21, Township 15, Range 65W, in Weld County, Colorado Natural. Gas 0:impresserStattan Ef Particulate Matter (PM) Quadrant Section Township Range L2' Ozone (NOx n VOC) - 21 AIRS Point '# Emissions Source Type Equipment. Name Emissions Control? Permit# Issuance # Self Cert Required? Action Engineering Remarks C-210 1JWE.5 nit' Initial:' 007 -. 006 Yes- - 17WE1195- Per mit.Initial Natuis4'GuS-.PcICE C-212 Yes 17WEI195 Permit Initial-' Issuance Permit Initial Ins Uance x1"213 Yes 17W E1195 TEs= Deis D-3101 Yes 17W51195 Yes srmit initial. Issuance TE-'- 0envd 0-3111 Yes 17W51195 Permit Initial Issuance Permit Initial Issuance Permit Initial issuance Process €iara -- - -F-4101 Yes 17WE1195 -O xpleini:. - CO RP - (7 W E1195 Yes Compressor Blowdo Cancelled before pe Cancelled before permit issuance No ce Fugitive Commonen-tient& FUG1' PUG? T. No 17 W E 1195 -rmit Initial Issuance Fugitives a he, Pump Station:,,.,,, Crude Tank; 17WE1195 it'Imtlal.. 17WE1195' Yes - Per lnitIhl Tank Roof Landing_ 0 Pigging 17W E1195 Permit Initial Issuance Pipeline Pigging - Section 03 - Description of Project al' 1e:;operator propose a new synthetic minor rempressoY-(and pump station) In the NAA. The pump s urinal when the terminal is at- maximum capaetty_ - -Points 009 and 010 were ca nce Ned before permit 3ss0anee.. /1E/21117 Crestonc sabmiteo a revised arzp1 atton'slightly changing Mello 0749 and'120 EPSO) on (ooirieS -014) exists to store excess crude oil ₹prom a nee^byOil Section 04 - Public Comment Requirements - of this facility. A new permrt=number and AIRS Owes assigned to this facility=(previousiy Is Public Comment. Required? II If yes, why? - €'{eque5ting3 Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? If yes, for what pollutants? - >3 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 (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? - If yes, explain what programs and which pollutants here: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) • 502 NOx CO' VOC PM2.S5 PM10 TSP HAPs ❑ ❑ ❑ ❑ - ❑ ❑ ❑ Li S02 NOx CO I. VOC PM2.5 PM10 TSP HAPs 100000 ❑ . One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural 001 gas compression. Engine Information Max Rated Horsepower @ sea level: Derating 1875 IMfg's Horsepower used for calcuations: 1875 BSCF @ 100% Load (btu/hp-hr): 7500 Site - Rated BSCF @ 100% load (btu/hp-hr): 7500 Other Parameters Engine Type 4SLB Aspiration • turbo -charged • Electrical Generator Max Site Rating (kw) Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 12444.69027 scf/hr ACTUAL Annual Fuel Consumption MMscf/yr MAX -'v I tN I IAL Annual. i-uel Consumption 109.015 MMscf/yr REQUESTED Annual Fuel Consumption 109.015 MMscf/yr .. Fuel Heating Value 1130 btu/scf Emission Control Information This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 g/tip-hr 0.500 g/hp-hr 9.03 tpy '9.03 tpy Manufacturer CO 2.720 g/hp-hr 0.150 g/hp-hr 49.14 tpy 2.71 tpy Manufacturer VOC 1.500 g/hp-hr 0.300 g/hp-hr 27.10 tpy 5.42 tpy Manufacturer Formaldehyde 0.200 g/hp-hr 0.020 g/hp-hr 7227 lb/yr 723 lb/yr Manufacturer Acetaldehyde 0.00836 lb/MMBTU 0.008 lb/MMBTU 1030 lb/yr 1030 lb/yr AP -42 Acrolein 0.00514 - Ib/MMBTU 0.005 Ib/MMBTU 633 lb/yr 633 lb/yr AP -42 Methanol 0.00250 Ib/MMBTU 0.003 Ib/MMBTU 308 lb/yr 308 lb/yr AP -42 1534.5 460.35 920.7 17WE1195.CP1.xlsm 001 Requlatory Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines MACT 7777 Facility is an area source of HAPs, so engine is not subject to major source requirements. Engine is new Reg 7 XVII.E.2 Standards (g/hp- hr) The engine is not subject to Reg 7 because it is subject to MACT Z777 and NSPS JJJJ, per XVII.B.5 Reg 7 XVII.E.3 The engine is not subject to Reg 7 because it is subject to MACT 7777 and NSPS JJJJ, per XVII.B.5 Reg 7 XVI.B (Ozone NAA requirements) applies? Not located in NAA. so not subject to Reg 7 XVI.B .. MACT 7777 (area source) Isthis enginesubject to MACT 7777 area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? I Yes Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6, One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at. 1875 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. 17WE1195.CP1.xlsm 1.xlsm 002 One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Engine Information berating Mfg's Max. Rated Horsepower @ sea level: 1875 Horsepower used for calcuations: 1875 BSCF @ 100% Load (btu/hp-hr): 7500 Site - Rated BSCF @ 100% load (btu/hp-hr): 7500 Other Parameters Engine Type 4SLB Aspiration turbo -charged Electrical Generator Max Site Rating (kw) Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 12444.69027 scf/hr ACTUAL Annual Fuel Consumption MMscf/yr MAX I'U f tN I IAL Annualiuel Consumption - 109.015 MMscf/yr REQUESTED Annual Fuel Consumption 109.015 MMscf/yr Fuel Heating Value 1130 btu/scf Emission Control Information This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 g/hp-hr 0.500 g/hp-hr 9.0 tpy 9.0 tpy Manufacturer CO 2.720 g/hp-hr 0.150 g/hp-hr 49.1 tpy 2.7 tpy Manufacturer VOC 1.500 g/hp-hr 0.300 g/hp-hr 27.1 tpy 5.4 tpy Manufacturer Formaldehyde Q.200 g/hp-hr 0.020 g/hp-hr 7227 lb/yr 723 lb/yr Manufacturer Acetaldehyde 0.00836 Ib/MMBTU 0.008 Ib/MMBTU 1030 lb/yr 1030 lb/yr AP -42 Acrolein 0.00514 lb/MMBTU 0.005 Ib/MMBTU 633 lb/yr 633 lb/yr AP -42 Methanol 0.00250 Ib/MMBTU 0.003 Ib/MMBTU 308 lb/yr 308 lb/yr AP -42 17WE1195.CP1.xlsm One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural 002 gas compression. Regulatory Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines MACT ZZZZ Facility is an area source of HAPs, so engine -is not subject to major source requirements. Engine is new Reg 7 XVII.E.2 Standards (g/hp- hr) The engine is not subject to Reg 7 because it is subject to MACT 7777 and NSPS JJJJ, per XVII.B.5 Reg 7 XVII.E.3 The engine is not subject to Reg 7 because it is subject to MACT ZZZZ and NSPS JJJJ, per XV11.B.5 Reg 7 XVLB (Ozone NAA requirements) applies? Not located in NAA so not subject to Reg 7 XVI.B MACT 7777 (area Is this engine subject to MACT ZZZZ area source requirements? Yes source) NSPS JJJJ Is this engine subject to NSPS JJJJ? I - Yes - Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. 17WE1195.CP1.xlsm One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural 003 gas compression. Engine Information berating Mfg's Max. Rated Horsepower @ sea level: 1875 Horsepower used for calcuations: 1875 BSCF @ 100% Load (btu/hp-hr): 7500 Site - Rated BSCF @ 100% load (btu/hp-hr): 7500 Other Parameters Engine Type 4SLB Aspiration turbo -charged - Electrical Generator Max Site Rating (kw) Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 12444.69027 scf/hr ACTUAL Annual Fuel Consumption MMscf/yr MAX I'u I tN I IAL Annualruei Consumption 109.015 MMscf/yr REQUESTED Annual Fuel Consumption 109.015 MMscf/yr Fuel Heating Value 1130 btu/scf Emission Control Information This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 g/hp-hr 0.500 g/hp-hr 9.0 tpy 9.0 tpy Manufacturer CO 2.720 g/hp-hr 0.150 g/hp-hr 49.1 tpy 2.7 tpy Manufacturer VOC 1.500 g/hp-hr 0.300 g/hp-hr 27.1 tpy 5.4 tpy Manufacturer Formaldehyde 0.200 g/hp-hr 0.020 g/hp-hr 7227 lb/yr 723 lb/yr Manufacturer Acetaldehyde 0.00836 lb/MMBTU 0.008 lb/MMBTU 1030 lb/yr 1030 lb/yr AP -42 Acrolein 0.00514 Ib/MMBTU 0.005 lb/MMBTU 633 lb/yr 633 lb/yr AP -42 Methanol O.00250 Ib/MMBTU 0.003 lb/MMBTU 308 lb/yr 308 lb/yr AP -42 17WE1195.CP1.xlsm One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural 003 gas compression. Regulatory Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines MACT 7777 Facility is an area source of HAPs, so engine is not subject to major source requirements. Engine is new Reg 7 XVII.E.2 Standards (g/hp- hr) The engine is not subject to Reg 7 because it is subject to MACT 7777 and NSPS JJJJ, per XVII.B.5 Reg 7 XVII.E.3 The engine is not subject to Reg 7 because it is subject to MACT 7777 and NSPS JJJJ, per XVII.B.5 Reg 7 XVI.B (Ozone NAA requirements) applies? Not located in NAA so not subject to Reg 7 XVI.B MACT ZZZZ (area source) Is this engine subject to MACT 7777 area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? I Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has hot been adopted into Reg 6. 17WE1195.CP1.xlsm 004 One (1) Caterpillar, G3516J A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped with a non- selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Engine Information Max. Rated Horsepower @ sea level: Derating 1380 'Mfg's Horsepower used for calcuations: 1380 BSCF @ 100% Load (btu/hp-hr): 8256 Site - Rated. BSCF @ 100% load (btu/hp-hr):. 8256 Other Parameters Engine Type 4SLB Aspiration turbo -charged Electrical Generator Max Site Rating (kw) Max hrs/yr of Operation 8760 Calculations Fuel Use Rate @ 100% Load 10082.54867 scf/hr ACTUAL Annual Fuel Consumption 0 MMscf/yr MAX F U I tN I IAL Annual huel Consumption 88.323 MMscf/yr REQUESTED Annual Fuel Consumption 88.323 MMscf/yr Fuel Heating Value 1130 btu/scf Emission Control Information This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx 0.500 g/hp-hr 0.500 g/hp-hr 6.65 tpy 6.65 tpy Manufacturer CO 2.430 g/hp-hr 0.200 g/hp-hr 32.31 tpy . 2.66 tpy Manufacturer VOC 0.910 g/hp-hr 0.360 g/hp-hr 12.10 tpy 4.79 tpy Manufacturer Formaldehyde 0.430 g/hp-hr 0.035 g/hp-hr 11436 lb/yr 931 lb/yr Manufacturer Acetaldehyde 0.008 Ib/MMBTU 0.008 Ib/MMBTU 834 lb/yr 834 lb/yr AP -42 Acrolein 0.005 Ib/MMBTU 0.005 Ib/MMBTU 513 lb/yr 513 lb/yr , AP -42 Methanol 0.0025 Ib/MMBTU 0.0025 Ib/MMBTU 249.51 lb/yr 250 lb/yr AP -42 1129.392 451.7568 813.1622 17WE1195.CP1.xlsm One (1) Caterpillar, G3516J A4, SN: TBD, naturalgas-fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1380 horsepower. This engine shall be equipped.with a non- selective catalytic reduction (N.SCR) system and ar-fuel ratio control. This emission unit is used for natural gas compression. . 004 Regulatory Requirements Ambient Air Imps Source is not required to model based on Division Guidelines MACT ZZZZ Facility is an area source of HAPs, so engine is not subject to major source requirements. Engine is new Reg 7 XVII.E.2 Standards (g/hp- hr) The engine is not subject to Reg 7 because it is subject to MACT 7777 and NSPS JJJJ, per XVII.B.5 Reg 7 XVII.E.3 The engine is not subject to Reg 7 because it is subject to MACT 7777 and NSPS JJJJ, perXVII.B.5 Reg 7 XVI.B (Ozone NAA requirements) applies? Not located in NAA so not subject to Reg 7 XVI.B MACT 7777 (area source) Is this engine subject to MACT 7777 area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? I Yes Note: JJJJ requrrements are not currently included as permit conditions because the req has not been 17WE1195.CP1.xlsm Glycol Dehydrator Emissions Inventory ' Section 01 -Administrative Information 1Fad sty AIRS ID: Co. • Plant L 5". H3P fi::i3i ;z t Point Section 02- Equipment Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Oedrculatian Pump Information Number of Pumps Pump Type Make: Model: Design/Max Recirculation Rate: Dehydrator Equipment Flash Tank Reboiler Burner Stripping Gas Dehydrator Equipment Description MMscf/day gallons/minute , Rash tank, and reboiler burner One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 20 MMscf per day. This emissions unit is equipped with 2 (Make: TED, Model: TOO) electric driven glycol pump with a design capacity of 4.2 gallons par minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are routed to en aincoolad condenser, and then to the Enclosed Flare. Emissions from the flash Emission Control Device Description: tank are routed directly to the Enclosed Flare. Section 03- Processing Rate Information for Emissions Estimates Primary Emissions -Dehydrator Still Vent and Rash Tank (R present) Requested Permit Limit Throughput= :7,300.9. MMscf per year Potential to Emit (PTE) Throughput = 7,300 MMscf per year Secondary Emissions -Combustion Device(s) for Air Pollution Control Still Vent Control Condenser. Condenser emission reduction claimed: Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Still Vent Gas Heating Value: Still Vent WasteGas Vent Rate: Flash tank Control Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Rash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: ,_e`. --„Yd Control Efficiency% hr/yr Control Efficiency% r/yr r/y hr/yr Btu/scf scfh Control Efficiency % Control Efficiency % Wet Gas Processed: Still Vent Primary Control: 7,300.0 MMscf/yr Still Vent Secondary Control: 0.5 MMscf/yr Waste Gas Combusted: Still Vent Primary Control: 15.0' mMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Wet Gas Processed: Flash Tank Primary Control: 7,300,0 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr Waste Gas Combusted: Flash Tank Primary Control: 3,1 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr Glycol Dehydrator Emissions Inventory Section 04 -Emissions Factors & Methodologies Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate STILL VENT Control Scenaro Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC 602360;";'i;LJ"�i' 0.691795 0 Benzene ': A'2S00 'T''. 0.12125 0 Toluene >i:. ,...,. Wi7„ / jfryt,,. 0.1369] 0 Ethylbenzene ,b€64t13�,fji$7+''„� 0.03401_ 0 Xylenesn3C0..Iif 0.056015 0 h -Hexane 0.013795 0 224-TMP Ui0ii<i iyU'14 1 0.000005 0 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (Ib/hr) Controlled (lb/hr) Controlled (lb/hr) VOC __,______.__............ .,,.; 12-034]7 0.601735 0 Benzene «;9.07 {8 0.00324 0 Toluene rfi/0_l49i J 0.00246 0 Ethylbenzene i,1 1(7I„tl'.-0974 0.00037 0 Xylenes " 0 0: 0.0005 0 n -Hexane _ :,_ 0.131? 0.009585 0 224-TMP ,,......... 0.0001 : 0.000005 0 Emission Facto Pollutant Glycol Dehydrator Uncontrolled (Ib/MMsci) (Wet Gas Throughput) Benzene 2.98776 Toluene 3.34632 Ethylbenzene 0.82512 Xylene t59636 n -Hexane 0.56112 224TMP 0.00024 Controlled (lb/MM (Wet Gas Throughput) 1.55 0,149388 0, 0.041256 0.079818 0.028056 0.000002 16 Mill Vent Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu( PM10 PM2.5 NO CO (Waste Heat combusted) Emission Factor Source (Ib/MMsct) Emission Factor Source (Waste Gas Combusted) Mal Vent Secondary Control Device 0.0000 Pollutant Uncontrolled Uncontrolled (Ib/MM9tu) (Waste Heat Combusted) (Ib/MMscf) (Waste Gas Combusted) Emission Factor Source PM10 PM25 NOx CO 0.0000 0.0000 0.0000 0.0000 Flash Tank Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (Ib/MMscf) Emission Factor Source (Waste Heat Combusted) (Waste Gas Combusted) 0.0000 0.0000 Flash Tank Secondary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MM6tu) (Ib/MMscf) Emission Factor Source (Waste Heat Combusted( PM2.5 NO CO Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer(%): (Waste Gas Combusted) 0.0000 0.0000 0.0000 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Penult Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 0.0 0.0 - 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 0.0 0.0 Nox 0.0 0.0 0.0 0.0 0.0 CO 0.0 0.0 - 0.0' 0.0 0.0 VOC 113.3 113.3 5.7 113.3 ' 5.67 Potential to Emit Actual Emissions Requested Pe stilt Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled ' Uncontrolled Controlled (Ibs/year) (Ibs/year) - (Ibs/year) (Ibs/year) (Ibs/year) Benzene 21811 21811 1091 21611 1091 Toluene 24428 24428 1221 24428 .1221 Ethylbenzene 6023 6023 301 6023 301 Xylene 11653 11653 583 11653 583 n -Hexane 4096 4096 205 4096 205 224TMP 2 2 0 2 0 10.9053 122141 3.0117 5.8267 2.0481 0.0009 0.5453 0.6107 0.1506 0.2913 0.1024 0.0000 062.38632 Glycol Dehydrator Emissions Inventory Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B,D Regulation 7, Section XVII.8,2.e Regulation 7, Section XI I.H Regulation 8, Part E, MACT Subpart HH (Area) Regulation 8, Part E, MACE Subpart HH (Major) Regulation 8, Part E, MACE Subpart HHH (See regulatory applicability worksheet far detailed analysis) Source requires a permit Dehydrator is subject to Regulation 7, Section XVII, 8, 0.3 The control device for title dehydrator is not subject to Regulation 7, Section XVII.B.2 Dehydrator Is subject to Regulation ],Section X8.11 The dehy unit meets the benzene exemption You have indicated that this facility is not subject to Mater Source requirements of M You have indicated that this facility is not subject to MAC? HHH. Section 07 - Initial and Periodic Semolina and Testing Requirements Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a year of application submittal? lino, the permit will contain an 'initial compliance" testing requirement to demonstrate compliance with emission lim Does the company request a control device efficiency greater than 95% for atlare or combustion device? ,. 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 Section au -Technical Analvs6 Notes 1T7 soucvnwsedtiRF 5lycaln4,U₹ stuaateemin ous,V to nsuresifa=speelflazmissfonsatehcfosnytIgmittedklim There Isrnot:permitted dts!,vfiklmefortfie caiifdul AIRS Paint 8 005 Section 09 - Inventory SIC Coding and Emissions Factors Process 4 SCC Code 01 Uncontrolled Pollutant Emissions Factor Control % Units PMSO NOIV/01 0.0% b/MMscf PM25 BDIV/01 0.0% b/MMscf NON 0.000 0.0% b/MMscf VOC 31.0 9500.0% b/MMscf CO 0.000 0.0% h/MMscf Benzene 2.988 9500.0% b/MMscf Toluene 3.346 9500.0% b/MMscf Ethyibemene 0.825 9500.0% b/MMscf Xylene 1.596 9500.0% b/MMscf n -Hexane 0.561 9500.0% b/MMscf 224 TMP 0.000 9500.0% b/MMscf Glycol Dehydrator Emissions Inventory - Section 01- Administrative Information Facility AIRS ID: County Section 02 - Equipment Description Details Dehydrator Information Dehydnitor Type: Make: Model: Serial Number. Design Capacity: Recirculation Pump Information Number of Pumps Pump Type Make: Model: Design/Max. Recirculation Rate: Dehydrator Equipment Flesh Tank Reboiler Bumer Stripping Gas Dehydrator Equipment Description MrcDscf/day gallons/minute flash tank, andrehoiler burner One -(1) Triethylene glycol (TEN) natural gas dehydration unit (Make: TED, Model: TBD, Serial Number. TOD) with a design capacity of 20 MMscf per day. This emissions unlis equipped with 2 (Make: TED, Model: TOD) electric driven glycol pump with a design capacity 014.2 gallons per minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are muted to an air-cooled condenser, and then tothe Enclosed Flare. Asa secondary control Emission Control Device Description: device, still vent emissions are routed to the . Emissions from the flesh tank are routed directly to the Enclosed Flare: Section 03 - Processing Rate Information far Emissions Estimates Primary Emissions - Dehydrator Still Vent and Flash Tank (If present) Requested Permit Limit Throughput= l MMscf per year Potential to Emit (PIE) Throughput= 7,300 MMscf per year Secondary Emissions -Combustion Device(s) for Air Pollution Control Still Vent Control Condenser: Condenser emission reduction claimed: Primary control device: Primary control device operation: Secondary control Revise: Secondary control device operator: . Still Vent Gas Heating Value: Still Vent Waste Gas Vent Rate: Flash sank Control Primary control device: Primary control demise operation: Secondary control. device: Secondary control device operation: Hash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: Wet Gas Processed: Still Vent Primary Control: 7,300.0 MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Waste Ges Combusted: Still Vent Primary Control: 15.0 MMscf/yr Still Vent Secondary Control: D.0 MMscf/yr Wet Gas Processed: Flash Tank Primary Control: 7,300.0 MMscf/yr Flash Tank Seconder/ Control: 0.0 MMscf/yr Waste Gas Combusted: Flash Tank Primary Control: 3.1 MMscf/yr Flash Tank Secondary Control: 0.0 MMsd/yr Glycol Dehydrator Emissions Inventory Section 04- Emissions Factors & Methodologies Dehydrator Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate STILLVENT Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC - 49 0.691795 13.8359 Benzene 9i81011030030MINTS 0.12125 2.425 Toluene 4559 0.13697 2.7394 Ethylbenzene OlitiarMigliRr 0.03401 0.6802 Xylenes bE' hya ;;;t „ 0.066015 13203 n -Hexane EI1t - -........ _. .. Off2�l�.5:1-: $f3I 0.013795 0.2709 224-TMP L'?'(''??'"^. 0.000005 0.0001 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled(Ib/hr) Controlled (lb/hr) VOC 0,601735 12.0347 Benzene IIIIIIIIIIIIIIU8481 0.00324 0.0648 Toluene " S0454:E e.,_ 0.00246 0.0492 Ethylbenzene kii?riili'I9 Jy45 v:'m r. 0.00037 0.0074 Orients i,'0.1/i;Q217WT;?i ^'-'"'r 02005 0.01 n -Hexane 1 3 100917IIIIII':.;dy 0.009585 0.1917 224-TMP 0.000000 0.0001 Emission Fa VOC Pollutant Glycol Dehydrator Uncontrolled (Ib/MMsct) (Wet Gas Throughput) (Wet Gas Throughput) Controlled (Ib/MMscf) 31.04 1.55 Benzene Toluene 2.98776 0,149388 632 0.167 Ethylbenzene 0.82512 0.041256 Xylene Hexane 59636 0.07981 0,56112 0.028056 0.00024 0.000012 Still Vent Primary Control Device 224 TMP Pollutant Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/MMscf) Emission Factor Source (Waste Heat Combusted( Emission Factor Source (Waste Gas Combusted) Still Vent Secondary Control Device Uncontrolled Uncontrolled Pollutant (lb/MMBtu( (lh/MMscf( Emission Factor Source (Waste Heat Combusted) (Waste Gas Combusted( PM10 PM2.5 Non CO 0.0000 0.0000 0.0000 0.0000 Pollutant CO Flash Tank Primary Control Device Uncontrolled Uncontrolled (Ib/MM0tu) (Ib/MMscf( )Waste Heat Cam busted) (Waste Gas Combusted) Emission Factor Source Flesh Tank Secondary Control Device Pollutant Uncontrolled (Ib/MMBtu( )Ib/MMscf) (Waste Heat Combusted) Uncontrolled (Waste Gas Combusted) Emission Factor Source PM10 PM2.5 NOx CO 0.0000 0.0000 0.0000 0.0000 Section 05- Emissions Inventory Did operator request a buffer? Requested Buffer (%): Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (eons/year) PM10 PM2.5 Nox CO VOC 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 0.0 113.3 113.3 5.7 113.3 5.7 Hazardous Air Pollutants Potential to EmS Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 21811 21811 1091 21811 1091 24428 24428 I221 24428 1221 6023 6023 301 6023 . 301 11053 11653 583 11653 583 4096 4096 205 4096 205 2 2 0 2 0 10.9053 12.2141 3.0117 5.8267 2.0481 0.0009 0.5453 0.6107 0.1506 0.2913 0.1024 0.0000 Glycol Dehydrator Emissions Inventory Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B,0 Regulation 7, Section XVII.B.2.e Regulation 7, Section XII.H Regulation8, Part E, MACTSubpart HH (Area) Regulation 8, Part E, MACrSubpart HH (Major) Regulation 8, Part E, MAC( Subpart HHH (See regulatory applicability worksheet for detailed analysis)_ Source requires a permit Dehydrator is subject to Regulation 7, Section XVII, B, 0.3 The control device for this dehydrator is not subject to Regulation 7, Section XVRI.6.2 Dehydrator is subjectto Regulation 7, Section X11.14 The dehy unit meets the benzene exemption You have Indicated that this facility Isnot subject to Major Source requirements of N You have indicated that this facility is not subject to MALT HHH. Section 07 - Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sampleused in the olyCalc model/Process model site -specific and collected within a - year of application submittal? If no, the permit will contain an "Initial Compliance. testing requirementto demonstratecompliance with emission limits Does the company requester -control device efficiency greater than 95% fora flare or combustion device?' If yes, thepermit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08= Technical Analysis Noteess $₹'C t2Ge spu,ge gses4 GRI fxlycalr.;,, ,,,,. AIRS Point tt Dos Section 09 - Inventory SCC Coding and Emissions Factors Process 01 SCC Cade Pollutant PM10 PM2.5 NOx VOC CO Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP • Uncontrolled Emissions factor 0010/01 IMIV/01 0.000 31.0 0.000 2.988 3.346 0.825 1.596 0.561 0.000 Control % 0.0% 0.0%- 0.0% 9500.0% 0.0% 9500.0% 9500.0% 9500.0% 9500.0% 9500.0% 9500.0% Units b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf Dehydrator Regulatory Analysis Worksheet ColoradoRegulationhaw Mknteed Mot souse PEN and Permit in thervnfntainment Aron ATTAINMENT Are anal emissions from any criteria pollutants from Nis 124411mum greater Men TM( 2(Reguation 3. Part A, 3eceln 11.0.1..11 1 Mu uncontrolled 1al tMn 10 ?Plot CC colons greater man SDySY 'Regulation 3, Part 5, Section il.03)? 'Tatham Indicated that sourlm'n intheaNwMadimmemama 1 MMTTA�MFMb . .individual saus greeora.n C4?1TIMlRegubdn 3, part0.5ecun 11.0.La1r - sours Requires an permit Meraxtqueznn 2. Are MlefadOrytamucited VOCe...sfion cis greater Nan 2TPY, Noagreater Ilan S TPYorCO emissions greater IMn s TPr(Regubdn3.Part B. semen HMI)? Source RegWresapenit l Colorado Regulation ].Section XII H COb glycol n dehydrator loomed In Neff -hr ozoneemnmr area orammonme nnartelnmena area oroAnpsseossoAoenaan eras (Reg nd 2)5 cars glycol tuwralms dehydrator located Man oil and gas exploration and produmcnoperationt,natual gas compressor meson, natural gas drip station 5 (nsgyi Seod•nt(Reg76emon 3. Is Ne sum of cmelanmontroiad emissions ofVoe'Torn any singe dehydrator group of dehydramrsat asitdsllatlararywvm egwim or greaaermanl5 tpy Meg 7, Seaton XII.H3.b1] 4.. Are ad uncontrolled emissions ofvoc lrom.the iMMNal glycol natural msdehydrator equal to or greater Nan l Ny ISeg].seNdn XII.H3a)i IDehydrator b,ableet to Regulation 7. Section511.4 Section XI(.H—Emission Reductions from glycol natural gas dehydrators MACTAnalysis 1. lathe dehydrzmriated aeon oil at. natural gas production faceiry Nat meats either of ice following Nigeria: a. Afacletyalat process., upgrades orsNreshydraakonlfgmdse (63.760(a)(2)); OR f eetlymaa processes, upgrades or sores natural gas price to do point at whim natural gasenmrs N0,oswal Ps 050015 b4 and storage sourcearege yot Is delivered toe final b. end use?(63.26u1a1(A))? 2 Cthedehydrataalomtediota facility Nat's. majorsourskr HAP, I0oro MRCS Am•SeursRenuiremeteedwntadetenine Magi' eopllubilM OIIand'au Medutlse Pada . Area Souscssamiiirmnants Is Ne dehydrator a Methylene glycol (TE3) dehydagm unit (63.76o(b)(2() P mmlea 1e. Ismeamral annualRowrateofnaturei gas to No giyml dehydration Chit less tMn3.00174TMMse' per day(63.764(e)(11(pr awl annul average ernMions of benzene from the era unit dehydrationp s veMN No egeospM(63 releaaNan 1,3g4.3N/yr.7effM(1)(Oll Is Me unitloated amide of a VA plus offset and IX boundaryeree? IThe del, unit mootsNo6o ono ommolien wrta General provisions per 463.]64 AtAn lee 03 -76s -Emission Control sdnaerdsoo Not Apply 463.773 -Monitoring Standards 0o Not apply §63.7/4-Rmm ?ogle,ng §G3.ns-RepordngsaMatds Oa ISotapply Conenue-Youhagelcelangd the attainmentscevs on the Project Sunmaryslaec Conti nuo n have indicated Ne facility rspe n Ne Pmjecesummasysheet o to Ne neatquesidon Dehydrator) subject m Regulation 7, lemon Ml.H ?Continue -Source is subleat m M AR HH rey urem en. You have indla ted Me source category angle 0sl000summ ary sheet. ramie. so MAR HH ores mars cepPosasnwsemss 'Yes !Continue-Youha4eindlated Nedehydrator type on the dehydrator Invenot,sheet Malorguincegaenharnems Does fwliry M1aw a.Gliry-wide actual annual average natural Ps dvoughput less Nan 0.65 MMatl/day ANC a famirymMe actual annul average hydaoorWm liquid Nrouptput leas than 249.] Small es LargeDehs. n5_Deteninwbq 25, Is the annual average mown'. of natural gas to Ne glycol dehydration Unit less than 3.601]4] MIN. per gay (63. 1)r lb. Ara actualannual average embslons of benzene horn Na glycol dehydration unitpraess vase to Ne ebnsphefelessman 1,984.2 IbM(63.761)7 Small Dishy Regaireenema 3. Del consCuctIon of the small glyaal dehydration unitcommence on or before August 2.3,, 1011 (63.760141(110)(B) and (e )r 4. ForWssmall dishy, lea control device required tomeetNe ffIX emlssbn Omit given by the applicable equation? ltaciameimikoct that MO facility suMactsoMaimSomee meuimmerM 1u4partA, General provisions per §43.]14 (5) Tabb 2 463.]gs-EmisbmComml Standards 463.773 -Monitoring 543.7M-Remrdkeeping 463.775-Repa0'ng 40Cfg. Pert...boars MAO —MM. Natural Gas Transmission end Morals. PaciMles 1 Is e facility vide actual annual average natural gas Nroughv lam Nan 05994%1MMuf/day and glycol dehydrators Ne only HAP emission sours (63.1270(X)] gm•Ilor large MAY Dmarminatlo0 2a. lithe .l nualaverage lowate of retool gash Ne glycol dehydration unit less then9994031 MMscf per day 163.12]0(6)12111 15. Are average emissions°, from Ne glycol dehydration unit process ventto the ansphereiess then 1,9114,2 lb/yr(e3.270'blRl)? mall Dons R•ovi nlannual ents 3. OM consruction ofinesmall glycol dehydration unitmmmence on or before August 13, 2011 (63.127111121 and 33111 4. fw.b small defy. Is a control device required to meetthabTExemlsslortllmlt(a.ndard7) given by tic apPllab6 equation? Mau hemendicsted that Mk featlyb natstmiac.MA404HN. subrat0.6eneral provisions per §633.12]4(a) Tail! 52 4.3.3C7S-Emisala' Control Standards §6.31.7.11-Condul Equpmerhst.Ms32 4633233 -Inspection and Monitoring §6.3.3384-tocool Being tes.R6s-Repartee Colorado Regulation 7 Section XNs 14 IS Nedehydatar subject roan emissionsmnrrol.a facility? MAR HH or HHH(Regulation 7, lemon XV1195)? 2 Is Ws dehydrator lomNd et a bartmlasln/sorage facility? 3. Is this dehydrator loafed at an oil and gas exploration and production operation, natural gas compressors -.Ion. gas processing plant (Reg 7, Section XVII.D.S)? 4. Was this Mimi natural gasdehydator constructed before May 1,2015 (Reg] sealer, 92I.0.4.61, If constructed prism° May 1, 2015, are n...Maly., ache' emissions hem a y., al gas dehndor aqual.Not grea.,t ss 6 tore peryearVOCor?NO/DC.. dehydrator's looted within 1.320 bet of abundingnitor desig and outside aaflry area ((Reg T,sectlon x4II.0Ab11 If asinglet glycol natural gas dehWrater equal Nor gae.rthanatpvvoc(Regulation 7. Sectbnlsfl.D.aa r IDeMdubr Ie,2blatt to Rtonile vn 7, Settee XI5, 403 nual Prvabbs fs Alrpoludn can EgWpmentandPmx Section XVII.D.3-Enifsslcm Reduceco Provisions M .meths Emsba csnmcl Matte. tealnl 6Is NNesml natural tax dehydrator controlled by a hark -up or alternate combustion device (Le, notNo primary contrddedce) NatIsntendsed5 of Imo coat. aawcadorthb echsdn.rb not sublet to Ileeubtiun 7, 5erdnavll.e.2.e Section =Leta -Mosinee emOgommntrol equipment Disclaimer This dowdier, assists coeditors with detemifnirg applkabll4yofcanaln regldremenfs Nfle Liea7ANPa, Ifs Implemenllrg repuhlbns. a.CAtrquelly Con. Cornmksbn depukbbna. Thu dpcumeniis rroca rusko'mgula'4n, and the anaysis4nMains may rctappy to aparticu ysilua(C5 based upri the IrdivkLal Nch acct circumstances. Ms does oafcYmrge 0'substlhI4SteranYlaw, sputa., drany45,l, legally]4M1nOrssubamenf and Is rN OASAC en.. Ole. In the eventof an y ccaltat doh..tlreknguegs or'Ns dxunad and the larg1egsorthe Lkn24AcC, its snpkmengng regulagas, and AlrAlagycom5Canmisaon rayukbhn.. Ile krguageartha slat.legubfbn WI contra( fiouse0,1C.menWklykrgtsegasrch as'asmmend,' Way, arld,laM1-.....lOclaccr.APCL i lerpreluhassandavmmerc8fbrsc MaMatorytelm4rd ]y such en 'mustard 'required 'cm inland. .°describe cont.., 59120404545akrb. krma on. Okon Acl ardA4 Quality Control Commis. reyulffi'ns. Out Mb document does 7otes100sh legaf*blm0g requ4a0Mh hanwdset No N ['sanest estlon the dem unit meets the benzene exemption Continue -You have previousllndbodthislnNe MAR section Con.. You have previously Indicated this C Ce beynningafthe MAC'Isemon Cone nue -You have previously Indented Nis in Ne Reg], Section XII determination o to question S • Source 1smbkm 007 Process Flare Equipment Description: One process flare to control VOC and HAPs for the TEG Dehydrator and the slop tanks Table 9.a. Process Flare - Maximum Design Rating PafaWi Vapor Flow Rate, scfh 5,833 Vapor Heat Value, Btu/scf 1,500 Pilot Burner, scfh 22 Purge Fuel, scfh Pilot/Purge fuel Heat Value, Btu/scf Design Rating,_M MBtu/hr Note: Process flare based on a maximum design rating of 140,000 scfd (5,833 scfh) of vapors with a heat content of 1,500 Btu/scf. Process is also equipped with two 22 scfh pilot burners and 4 scfh of purge fuel which combusts treated plant gas (1,130 Btu/scf). 4 1,130 8.80 Table 9.c. - Process Flare - Criteria Pollutant Emissions ' t ', A�gisR �s��rt�tar, r Sl n i m►ssion Ib/MMBtu Emission Rake, Emi sion Rate, tpy '. NO, _ 0.138 1.21 5.32 CO 0.276 2.43 10.62 CO2 120,000 130.334 1147.43 5,025.75 1 Based on EPA AP -42, Section 1.4, Natural Gas Combustion (Tables 1.4-1 and 1.4-2). 2 NO, and CO emission factors for Flares from TCEQs Air Permit Division's Technical Guidance for Flares and Table 9.b. - Process Flare - Process Simulation Design Rating Parameii Dehy Flash Gas Flow Rate, scfh aces 350 From GRI-GlyCalc run Flash Gas Heat Value, Btu/scf Dehy Regenerator Flow Rate, scfh Vapor Heat Value, Btu/scf Slop Tanks Vapor Flow Rat, Vapor Heat Value, Btu/scf Pilot Burner, scfh Purge Fuel, scfh Pilot/Purge fuel Heat Valuf 1,433 Calculated from GRI-GlyCalc run outputs 1,710 From GRI-GlyCalc run Calculated from GRI-GlyCalc run outputs From E&P Tanks run for 2 slop tanks From E&P Tanks run Design specifiation provided by Discovery Design specifiation provided by Discovery Treated plant gas heating value 163 5 3,926 22 4 1,130 Design Rating, MMBtu/hr 0.8542 903.8975933 1804.520195 Note: This point is being permitted at the maximum design rating for this flare which is over 10 times the estimated MMBtu/hr that will be sent to this flare 008 Compressor Blowdown Events for a total of 4 compressor engines pRF,s4r14Ser VOC wt% 33.57% benzene wt% 0.09147% toluene wt% 0.15560% " ethyibenzene wt% 0.03740% nylons wt% 0.08484% n -Hexane wt% 1.30081% 2,2,4-Trimethylpentane wt 0.00103% MW of Gas (lb/lb-mole) 24.3 Inlet Gas composition obtained from the average of five individual samples. 3 3 •-•,.E 7YNc ,z 1 'etl laxi�xcmn NlHniMnF Ntftlt 4rof _ 3 Gaq q,ps lslre5 ...1100 l iIMRA . ;; ErFl04kalP; s!"kltplKr�rl, , tons...�41ant 0. .71,K,k, 1NR!llahely. F4tlfpjNFl6 �1iYAF'tEMlyat" IYCs6ERr ... CA 'INDOivir .l)6ihri3....., Flair it 't /yr) 11ii , Anihe Andbi} F i fib/yrr VM „?'0. X15/ht}, Aib/Ary)' Compressor Slowdowns 24 4 4.2 403.2 0.99 4.34 0.00 23.65 0.00 40.23 0.00 9.67 0.00 21.93 0.04 336.31 3.05E-05 2.67E-01 TOTAL - - 4 - - -403.2 0.99 4.34 0.00 23.65 0.00 40.23 0.00 9.67 0.00 21.93 0.04 336.31 3.05E-05 2.67E-01 Uncontrolled Emission Factor (Ib/MMscf) _ Emissions (tpy)' Emissions pb/hr) 21,527 58.655 99.774 23.979 Number of events per year' Gas Volume iscf/event)' Molecular Weight of Gas Ib/Ib-moll' Weight Fraction of Pollutant 54.402 834.104 0.663 Emissions (ton/year)' 2000 (lb/ton) 8760 (hr/year) Density of Natural Gas (379 scf/Ib-mol) ' 2000 (lb/ton) 737.1896 011 Regulation 7 Information Operating Hours: Fugitive equipment leaks These are the fugitives from only the pump station at this facility. The fugitives from the rest of the compressor station facility are APEN exempt through the use of table 2-8 emission factors. -• 8760 hours/year Emission Factor Source Standard EFs - EPA -453/R-95-017 Table 2-4 Control Efficiency Source: Calculations None Service -. Component Type Count Emission Factor (kg/hr- source). Table 2-4 Table 2-8 Control (%) Pollutant Mass Fraction Emissions (tpy) Reg. 3 Connectors 0 2.00E-04 1.00E-05 0.0% VOC 0 - 0 Flanges 0 3.90E-04 5.70E-06 0.0% Benzene 0 0 Open -Ended Lines 0 2.00E-03 1.50E-05 0.0% Toluene 0 0 Gas Pump Seals 0 2.40E-03 3.50E-04 0.0% Ethylbenzene 0 0 Valves 0 4.50E-03 2.50E-05 0.0% Xylenes 0 0 Other 0 a.aoE-03 1.20E-04 0.0% n -Hexane 0 0 Connectors 0 7.50E-06 7.50E-06 0.0% VOC 0 0 Flanges 0 3.90E-07 3.90E-07 0.0% Benzene 0 0 Heavy Oil Open -Ended Lines 0 - 1.40E-04 7.20E-06 0.0% Toluene 0 0 Pump Seals 0 0.00E+00 0.00E+00 0.0% Ethylbenzene 0 0 Valves 0 8.40E-06 8.40E-06 0.0% Xylenes 0 0 Other 0 3.20E-05 3.20E-05 0.0% n -Hexane 0 0 Connectors 10 2.70E-04 9.70E-06 0.0% VOC 1 2.3618938 Flanges 100 1.10E-04 2.40E-06 0.0% Benzene 0.0038 0.0089752 Light Oil Open -Ended Lines 0 1.40E-03 1.40E-05 0.0% Toluene 0.0096 0.0226742 Pump Seals 3 1.30E-02 5.10E-04 0.0% Ethylbenzene 0.0043 0.0101561 Valves 50 2.50E-03 1.90E-05 0.0% Xylenes 0.0043 0.0101561 Other 9 7.50E-03 1.10E-04 0.0% n -Hexane 0.026 0.0614092 Connectors 0 1.10E-04 1.00E-05 0.0% VOC 0 0 Flanges 0 2.90E-06 2.90E-06 0.0% Benzene 0 0 Water/Oil Open -Ended Lines 0 2.50E-04 3.50E-06 0.0% Toluene 0 0 Pump Seals 0 2.40E-05 2.40E-05 0.0% Ethylbenzene 0 0 Valves - 0 9.80E-05 9.70E-06 0.0% Xylenes 0 0 Other 0 1.40E-02 5.90E-05 0.0% n -Hexane 0 0 Emissions Summary Table Pollutant Uncontrolled Emissions Controlled Emissions Source VOC 2.3619 tpy 2.3619 tpy Standard EF: Benzene 17.95 lb/yr 17.95 lb/yr " Standard EF: Toluene 45.35 lb/yr 45.35 lb/yr Standard EF: Ethylbenzene 20.31 lb/yr 20.31 lb/yr Standard EF: Xylenes 20.31 lb/yr 20.31 lb/yr Standard EF: n -Hexane 122.82 lb/yr 122.82 Ib/yr Standard EF: - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R -95-O17 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 .. Condensate Storage Tank(s) Emissions Inventory Section 01- Administrative Information Facility AIRS ID: 2 County 4F74 ,,r Plant Pain Section 02- Equipment Description Details Detailed Emissions Unit =Description: Emission Control Device Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions- Storage Tank(s) Actual Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquid produced = • Barrels (bbl) per year Actual Crude Oil Throughput While Emissions Controls Operating= Barrels (bbl) per year Barrels (bbl) per year Btu/scf cf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 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? Pollutant Pollutant ®' 4 Uncontrolled Controlled (Ib/bbl) (lb/bbl) (Condensate Throughput) :i Sa (Condensate Throughput)• 0.00114 0.00000231 0.00000160 0.00000023 0.00000019 0.00001628 0.00000154 Control Device Uncontrolled Uncontrolled (Ib/MMBtu( (waste heat combusted) (Ib/bbl) (Condensate Throughput) 0.0000 0.0000 0.0000 0.0000 Emission Factor Source Emission Factor Source 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) VOC PM10 PM2.5 NOx CO 10.4 10.4 10.4 10.4 10.4 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 (Ibs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 42 42 42 42 42 29 29 29 29 29 4 4 4 4 4 4 4 4 4 4 297 297 297 297 297 28 28 28 28 28 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section Xll.C, D, E, F Regulation 7, Section XICG, C Regulation 7, Section XVII.B, C.1, C.3 Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Regulation 6, Part A, NSPS Subpart 0000 Regulation 8, Part E, MACE Subpart HH (See regulatory applicability worksheet for detailed analysis) Facility attainment -area status has not been established yet Storage tank is subject to Regulation 7, Section 011.0-F Storage Tank is not subject to Regulation 7, Secion XII.G Storage Tank is not subject to Regulation 7, Secion XVII Storage Tank is not subject to Regulation 7, SecSon XVII.C2 Storage tank is subject to NSPS Kb Storage Tank is not subject to NSPS 0000 Storage Tank is not subject to MACF HH 0.002028482 0.001402917 0.000201147 0.000169258 0.014278561 0.001353929 ligidERWIDA 20 of 24 K:\PA\2017\17WE1195.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. 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 sample drawn at the facility being permitted? 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 mollified (e.g., no new wells brought on-line), then it maybe 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 based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? 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 Section 08- Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 012 Process# SCC Code 01 33 Uncontrolled Emissions Pollutant Factor Control% Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 16/1,000 gallons condensate throughput NOx 0.00 0 16/1,000 gallons condensate throughput VOC 0.027 0 lb/1,000 gallons condensate throughput CO 0.00 0 16/1,000 gallons condensate throughput Benzene 0.00 0 lb/1,000 gallons condensate throughput Toluene 0.00 0 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 0 lb/1,000 gallons condensate throughput Xylene 0.00 0 l6/1,000 gallons condensate throughput n -Hexane 0.00 0 lb/1,000 gallons condensate throughput 224 TMP 0.00 0 l6/1,000 gallons condensate throughput 21 of 24 K:\PA\2017\17WE1195.CP1xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 parts A and 9- APEN and Permit fleouirements 'Source is In the Non,Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from anycriterie pollutants from the individual source greater than 2 TPY (Regulation 3, Part A,Section 11.0.1.a)? 2. Is the construction date (service date) pdorto 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 foradditi0nal guidance on grandfather eppliobiity)? 3. Aretotal facility uncontrolled VOL emissions greateCthan 5TPY, NOx greater than 101PY or CO emissions greaterthan SO TPY (Regulation 3, Part 0, Section 11.03)2 INot enough Information NON -ATTAINMENT 1. Are uncontrolled emisilonsfrom any criteria pollutants from this individual source greaterthan 1TPY (Regulation3, Part A, Section ll.D.1.a)? 2. Is the construction date (service date) priorto 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2foradditionel guidance on grandfather applicability)? 3. Are totalfacllkyuncontrolled VOC emissions from the greater than 2 TPY, NOx greaterthan 5TPr or CO emissions greater than S TM/ (Regulation 3, Part R, Section ll.D2)? 'Source requires a permit Colorado Regulation 7, Section XII.C-F 1. Otitis storage tank located In the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. k this storage tank located at an oil and gas exploration and production operatl0n',natural gas compressor station or natural gas drip station? 3- Is this storage tank looted upstream of a natural gas processing plant? - WIMM Yes 'Storage tank is subject. Regulation 7, Section XII.C-F Section Xil.C.1 -General Requirements for Air Pollution Control Equipment -Prevention of Leakage Section XII.C2-Emission Estimation Procedures Section Xll.O-Emissions Control Requirements Section Oil.E- Monitoring Section XILF- Recordkeeping and Reporting Colorado Regulation 7. Section XII.G. I. Isthis storage tank located in the 8 -hr ozone control area ar any ozone non -attainment area or attainment/maintenance area] 2. Otitis storage tank located ata natural gas processing plant? 3. Does this storage tank exhibit "Flash" le.g_storing non -stabilized liquids) emissions and have uncontrolled actual emissions greaterthan or equal to 2 tons per year VOC? Intonate Tank is not subject to Regulation 7, Section XII.G Section XII.G2-Emissions Control Requirements Section Xll.C.1 -General Requirements for Air Pollution Control Equipment -Prevention of Leakage section 011.0 0 - Emission Estimation Procedures Colorado Regulation 7. Section kni 1. Is this tank looted ate transmission/storage facility? 2. Is this condensate storage tank' looted at an oil and gas exploration and production operation , wen production fedlityz, natural gas compressor station' or natural gas processing plant? 3. 6th is condensate storage tank a fed roof storage tank? 4. Are unc0mrolled actual emiselons°pf this stooge tank equal to or greater than 6 tons peryear VOC? 'Storage Tank is not subjeatto Regulation 7, Section 11MI Section XVII.B- General Provisions fon Air Pollution Control Equipment and Prevention of Emssions Section %YMC.1- Emissions Control and Monitoring Provisions Section XVII.C3 - Recerdkeeping Requirements 5. Does the condensate storage tank contain only "stabilized' liquids? IStorege Tank is not subject. Regulation 7, Section 1MI.C.2 Section XVII.C2-Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR. Part60, Subpart Kb. Standards of Performance for Volatile Organic IAquid Storage Vessels 1. Is the Individual storage vessel capacity greater -than or equal to 75 cubic meters (m) [-472 enLo)? 2. Does the storage vessel meet the following exemption in 60.111b)d))4)7 a. Dots the vessel has a design capacity less than or equal to/,589874RO [-10,000 80L) used for petroleum'o condensate stared,processed, or treated priorto custodytransfers as defined in 611116? 3. Was this condensate storage tank constructed, reconstructed, Or modified (b a definitions 40CFR, 60.2) after/uN 23, 1904? 4. Does The tank meet the definition of"storage vessel' in 60.0101? 5. Does the stoagevesel store a "volatile organic liquid (VOL).' as defined in 60.1116? 6. Does the storage vessel meet any one of the following additional exemptions: a. Isthestorage vessel a pressure vessel designed to operate in excess of 2049 kPa [-29.7 psi] and without emissions to the atmosphere (60.110b(d)[2))?; or b. The design capacity is greaterthan or eremite 151 m' ("950881] and star. a liquid with a maximum true vapor pressures less than 3.5 BPS (60,110b(b))?; or a. Thedeslgn capacity is greater than or equal to 75 Ma ('472 BBL( but less than 151 m' ''900 any and stores a liquid with a maximum true vapor presure` less than 15.0 kPa(60.11obgaf)? Yes No No Yes Source Reg Go to next Source Req Continue-' Continue-' Source Ost Continue-' Storage Tar Continue-' Go tat hen Storage Tar Intonate Tar WIN 0o m the Nana Go to then Go Lather Go to then Go to then Source k st Storage tank Is subject. ASPS Kb Subpart A, General Provisions 160.1125 - Emisslohs Control Standards forVOC §60.113b -Testing and Procedures 660.115b -Reporting and necordkeeping Requirements §60.1066- Mon Rodng of Operations - no CFR. Part60. Subpart 0000. Standards of Performance for Crude On and Natural Gas Production, Transmission and Distribution b this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gastransmksion and storage segment of the industry? 2. Was this condensate storage vessel constructed,reconstructed, or modifed(see definitions 40 CEO, 60.2) between August 23, 2011 and September 18, 2015? 3, Are pmemlal UDC emksions'from the individual storage vessel greaterthan or equafto 6 tons per year? 4. -Does this condensate storage vessel meet the definition of"storage vessel' per 605430? 5. is the storage vessel subject to and controlled in accordance with re uirements for storage vasek In 40CFR Part 60 Subpart Kb 0r 40 CFR Part 63 Sub art HH? 'Storage Tank Is not subject to NSPS 0000 Subpart A, General Provkions per 6605425 Tabie 5605395 -Emissions Control Standards for VOC 5605413 -Testing and Procedures §6U53a5(g)-Notification, Reporting and Recordkaeping Requirements 6605416(c) -Cover and Closed VentSystem Monitoring Requirements 6605417 Control Device Monitoring Requirements [Note: If a storage vessel Is preNouslyde.rmined to be subject to NSPS 0000 deem emissions above 6tons peryeervOC on the applicability determination date, itshould remain subjecrb NSPS 0000 per 6,0.5365(e)(2) even if potential VOC emissions drop below tors peryearl 40CFR, Part 63. Subpart Moor RH, Oil and Gas Production Facilities 1. is the storage tank looted at an on and naturaigas, production facility that meets either of the following criteria: a. Afacility that processes, upgrades or store hydrocarbon Iiquids' (63.760(a)(2)); OR b. Afacility that processes, upgrades or stores natural gas priorto the point at which natural gas enters the natural gas transmission and storage source category orb delivered to aflnal end user' (63.760(a)(3))? 2. Is the tank located at a facility that is majo2 for HAPs? 3. Do. the tank meet the definition of 'storage easels in 63.761? 4.- Do. the tank meet the definition ofstoragevesselweh the parental forflash emissions'' per63.7617 5. kthetank subject to controlrequirements under 40CFR Part 60, Subpart KhorSubpart 0000? IIt rage Tank is not subject to mAcr NH • Subpart A, General dr0visions per 563.764 (a) Table 2 663.266 -Emissions Control Standards 663.773 -Monitoring 663.774- Recordkeeping ' 663.775 -Reporting RACT Review FACT review Is required If Regulation 7 do. not apply AND If the tank Is In the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Ad its implementing regulations, and Air Quality Control Commission regulations. This document is nota rule or regulation, and the anaysis to contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally bindng requirement and is not legally erdorceable. In the event of any confiichbebveen the language of this document and the language afthe Clears AirAct„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as'recommend,,"may;'-"sheuld,"'and "can,'is intended to describe APCD interpretations and recommendations. Mandatory terminology such as 'must' and 'required* are intended to describe controlling requirements under the ferns of the Clean Ajr Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. ves Yes Storage Tar patinae-' g,ia� Storage Tar 1�, Its WAWA 013 External Floating Roof Tank Roof Landing Emissions One (1) 50,000 bbl External Floating Roof Crude Oil Storage Tank Roof Landing Emissions Table 14.a. -Tank Landing Emissions -Parameter Calculation ....-T0 NaTietyE -fr f -....n ,. �� T Xkl. ,., y , lik'h gnu b% � Y .. Ideal Gas Constant (R), peia cu ft/lb-mold R -' 30.73 Ideal Gas Constant TenkType Err From OPS Content (Worst -case scenario) Crude Oll Assumes worst -case scenario Diameter (0), ft 87.00 From PL -1497 or Facility Tracker Area of Tank (A),ft0 5,944.68 =pi/4*0^2, derived from Eq. 2-12 Effective Ht. of Stock Liquid )hp*), ft AP -42, 7.1.3.2.3.1 Standing i01e Losses Limit on standing idle losa(ISLmax),Ib/event - 0.00 AP -42, 7.1.3.2.2.1 Standing Idle Losses Leg Ht. (h),ft - 6.50 From OPS Liquid Heel HE (hl), ft 0.00 From OPS Number of hours Roo(Off-Float ft), bra 72.00 From OPS No. days tank stands idle )r1),days 3.00 00/24 True vapor pressure of the stock liquid IP), pole " 5.25 RVP Is from AP -42 Figure 7.1-13a for crude oil Density of liquid (W1), Ib/gal 7.10 From product MOOS, gravity, or AP -42, Table 7 Daily minimum ambient temperature (TAO, F 58.70 From AP -42 -Table 7.1-7- Denver, CO luly Daily minimum ambient temperature (T,w), R 518.70 =TAN +460 Daily maximum ambient temperature (T„a), F 88.00 From AP -42 -Table 7.1-7- Denver, CO July Daily maximum ambient temperature (Tad, R 548.00 =TAX+460 Daily average ambient temperature Mu), F - 73.35 =(TAN+TArl/2, From AP -42 Eq. 1-27 Daily total solar Insolation (actor L BTU/se ft -day 2,273.00 From AP -42 -Table 7.1 -7 -Denver, CO July Tank paint solar abeorptence (alpha), dlmenssionless 0.17 From APd2. Table 7.1-6 based on paint condlt Liquid bulk Temperature (T.), F 71.51 From EPATanks maximum liquid temperature Daily average liquid surface tempeature(T0), F 75.37 =0.44T+0.56T8+(0,0079 x alpha x I), AP -42 Daily avenge liquid surface temperature)Tx), ft. 535.37 =TLA+460 Vapor space outage (Hvo), ft ' 6.50 =h - hl Volume ofyapor space 10,I, ft' - - 38,634.47 =)PV4)00020 HOD Stock vapor molecular weight)M,), ib/Ib-m6le " 68.00 APJ2, Table 7.1-2 Stock vapor density (W,), Ib/fta 0.06 =Mv`P/R`TLA, Eq. 2-15 Clingage factor (C.), bbl/1,000 ft2 0.60 From 4P -42 -Table 7.1-10Average Clingage Fa Clingage loss from the drainrdry tank (L.), 1b ' 1,063.62 =42*Cs*WI*A/1000, Eq. 2.20 Maximum standing idle loss fordrain-dry tanks due to clingage )Lsu;,,,), lb - 1,445.91 =0.60*(P*Vv/R.T)*MU 04.2-23 Refilling Saturation Factor (5), dimensionless - 0.11 From Era 2-25(0.15 for a drain -dry tank) Filling loss during roof landing)I.J, lb - 361.48 =(P`Ve/R*T)`Mv*5, Eq. 2-26 for drain -dry tar Standing Idle loss, (Lr), lb 1,063.62 Filling Loas, (Lir). lb - 361.48 Table 14.b. -Filling Losses !pI1If'IpT, ✓ v,. .l n S e {, I i! ��' .Iled Vn FGIm&r..... S (tpyi traG'tidd Hjigepd�: ` IgtAS '{Ill ;se' 3gi K?i. PAI 1 . 361.48 3,333.33 6,882.15 2,06'V ' 2 175.08 0.36 0% - 175.08 0.36 Total: - 0.36 Table 14.c -Tank Landing emissions -Von Emissions a:^ tAnklO Via, .6''iM4t1) ,P -tee k (�. .C� a :ii!Y. It�dr � . ip�� - 1 1064. 361 2 2,850 1.425 0% 175.08 1.423 2,850.20 1:43 - 1.43 Table 14.d. -Tank Landing Emissions -Controlled HAP Emissions '• ,.W =<§f -":.'g�pN 49 HAP in n -Hexane - 0.00% 0.00000 Benzene 2.23% 003175 Toluene - 0.00% 0.00000 Ethylbenzene ' - 0.02% 0.00033 %ylene 0.02% " 0.00029 2,G,4-Trimethylpentane 0.00% 0.00000 Total: 2.27% 0.03237 Aeeumpgona: t. ore ian4lne am era facility prayaar tending emissions...a calculated for Me month oriWy(hottestonthor the year) es a worst case annarlo NAP `peciannniromonexaemraeadaaron Pronieror.crude on Ine0PTenkc for. 51),IvoaaLrnk. r max from breakavmen maealnann 3.33 aeheiaaa 6. No 11,14 heal d 2:33333 luG, maximum Wilt ate form.. 8.082.15 IAA to refloat Wk. Uncontrolled Basis (lb/event) 0.00E+00 6.35E+01 0.00E+00 8.53E-01 5.73E-01 0.00E+00 242.071771 Total: 0.36 'fit sEc010rtkoe yulmdif*3 0.00175 000001 0.00001 Total: 14 Crude Oil Pigging Pipeline Pigging MSS Activity Pigging Emissions Table 16. - Pigging Emissions Pipe D arneter: Pipe 'Lang 12 in 11 ft ( 11.23 ft3 ;Pipe Su ice Area 0.03456 103 ft2 rxratron E,) 8 hr/event Events ;(Ey) 120 events per year releases/e vent BBL/103 Release to_. Density of Crude Oil= (p) s.:° per event (R) 3 0.6 ft2 7.1 lb/gal VOC Emissios Per'# 18.5491 lb/event Hourly Vii rssrarrs ,ual VOC Ernass 2.3480 1.1129 lbs/hr tpy 0.00002 lb/hr VOC Annual; 0.00001 tpy Hour nzen, 0.0035 lbs/hr nl wenzer 0.0017 tpy 1 Pig catcher is 1 foot in diameter obtained from Discovery facility information. 2 Pig catcher length obtained. from Discovery facility information. 3 Q=7tPD2PL x 1.3 4=rr*D*L/1,000 5 Based on AP -42 Chapter 7.1, Table 7.1-10 for crude oil 6 Obtained from AP -42, Table 7.1-2 for crude oil. =Sp*C*42ga1/BBL*p*R 8 = VOC lb/event / Eh 9 = VOC lb/event * Ey / 2,000 lb/ton 365 events assumed per year 0.001 wt% based on TCEQ standard. Benzene content of 0.15 wt% based 189.0483 rot Division h & Environment CONSTRUCTION PERMIT Permit number: Date issued: Issued to: 17WE1195 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Discovery DJ Services LLC Discovery Lochbuie Compressor and Pump Station 123/9F74 SEC 21 T1 N R65WE Weld County Natural Gas Compressor Station and Crude Oil Storage Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description C-210 001 One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio control C-211 002 One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired„ Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio control C-212 003 One (1) Caterpillar, G3606 A4, SN: TBD, natural gas -fired, Turbocharged aspiration, 4SLB reciprocating internal combustion engine, site rated at 1875 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. . Non -selective catalytic reduction (NSCR) system and air -fuel ratio control Page 1 of 23 One (1 C. ;; rpilla 16J A4 N: TBD, natural, gas -fir . boch ge aspira n, 4SLB ecip,,cati inter 1 combust' 4 engine, site =tet at 138 ors ower. Thinine shall be equipped wi a non -selective ca a ytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air -fuel ratio control D-3101 005 One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: TBD) with &design capacity of 20 MMscf per day. This emissions unit is equipped with two (2) Make and model TBD, glycol pump with a design capacity of 4.2 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Emissions from the still vent are routed to an enclosed flare (Point 007). Emissions from the flash tank are routed to an enclosed flare (Point 007). D-3111 006 One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: TBD) with a design capacity of 20 MMscf per day. This emissions unit is equipped with two (2) Make and model TBD, glycol pump with a design capacity of 4.2 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Emissions from the still vent are routed to an enclosed flare (Point 007). Emissions from the flash tank are routedtoan enclosed flare (Point 007). • F-4101 007 One (1) enclosed process flare to control VOC and HAPs from the TEG dehydrators (Points 005 and 006) Enclosed Process Flare CB 008 Compressor blowdowns for the 4 compressor engines (Points 001-004) None FUG -2 011 Fugitives component leak emissions from the pump station None TK-1 012 One (1) 50,000 bbl external floating roof condensate storage tank None TL 013 Emissions associated with external floating roof tank landings for MSS activity None SR 014 Emissions associated with pipeline pigging MSS activity None (Points 001-004): These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with the manufacturer and model submitted to the Division per Requirements to Self -Certify for Final Authorization in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. COLORADO Air Pollution Control Division ^ rtrn tO Pubfx Heah`.n erriy6nmert Page 2 of 23 of Division 'he Division) no later than fifteen days of the or issuan `' of this permit, by submitting a Notice of fo t •n ipmen red by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (1B0) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. 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/pacific/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 008: Upon commencement of operation, the operator shall install a dedicated flow meter to monitor and record volumetric flow rate of natural gas vented from the compressor blowdown events covered by this permit. 5. 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.) 6. Points 001-006: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • The reciprocating internal combustion engines manufacturer name, model number and serial number • The dehydrator manufacturer name, model number and serial number • The glycol circulation pump manufacturer name and model number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, 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. COLORADO Air Pollution Control Division of Pettit` Heatm Eweanntet;t Page 3 of 23 8. ing limitations. (Regulation Number 3, Part Facility Equipment ID AIRS Point Pounds per Month Emission Type PM2.5 NOX VOC CO C-210 001 --- 1,535 921 461 Point . C-211 002 -- , 1,535 921 461 Point C-212 003 --- 1,535 921 461 Point C-213 004 --- 1,130 814 452 Point D-3101 005 --- --- 963 --- Point D-3111 006 --- --- 963 --- Point F-4101 007 --- 904 --- 1,805 Point CB 008 --- --- 738 --- Point FUG -2 011 --- --- 401 --- Fugitive TK-1 012 --- --- 1,767 --- Point TL 013 --- --- 243 --- Point SR 014 --- --- 190 --- Point Note: Monthly limits are based on a 31 -day month. The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds per month. Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per month. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. COLORADO Air Pollution Control Division 6zpa,tosent or Pub*: Hisin , t'awazvorunert Page 4 of 23 Hi • me ID •oint • ns per Year Emission Type IR P. - VOC CO C-210 001 --- 9.1 5.5 2.8 Point C-211 002 --- 9.1 5.5 2.8 Point C-212 003 --- 9.1 5.5 2.8 Point C-213 004 --- 6.7 4.8 2.7 Point D-3101 005 --- --- 5.7 --- Point D-3111 006 --- --- 5.7 --- Point F-4101 007 --- 5.4 --- 10.7 Point CB 008 --- --- 4.4 --- Point FUG -2 011 --- --- 2.4 --- Fugitive TK-1 012 --- --- 10.4 --- Point TL 013 --- --- 1.5 --- Point SR 014 --- --- 1.2 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall 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. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for 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. COLORADO Air Pollution Control Division dc€ HeWsi, ErNtr(oiil'Ptent Page 5 of 23 9. • oints + 5 CompC with ission its in this permit shall be demonstrated by or hig " r on a monthly basis using the most recent operation. , alues, including: gas throughput, lean glycol ure, flash nk temperature and pressure, wet gas inlet mperatu -, . nd w- • as - - `sure. • - `. ded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 10. The owner or operator shall operate and maintain the emission points in the table below with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. The owner or operator shall operate this dehydration unit so as to prevent any emissions directly to the atmosphere. (Regulation Number 3, Part B, Section III .E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled C-210 001 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control VOC, CO, Formaldehyde C-211 002 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control VOC, CO, Formaldehyde C-212 003 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control VOC, CO, Formaldehyde C-213 004 Non -selective catalytic reduction (NSCR) system and air -fuel ratio control VOC, CO, Formaldehyde D-3101 005 Still Vent: Enclosed Flare VOC and HAP Flash Tank: Enclosed Flare VOC and HAP D-3111 006 Still Vent: Enclosed Flare VOC and HAP Flash Tank: Enclosed Flare VOC and HAP COLORADO Air Pollution Control Division lent of pubtt: tieWtn a Enve'e'sttert Page 6 of 23 maxi ;_ m processing rates as listed below. Monthly hall be m `: tained by the owner or operator and made on req (Regulation Number 3, Part B, II.A.4_) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) C-210 001 Consumption. of natural gas as a fuel 109.1 MMscf/yr 9.3 MMscf/month C-211 002 Consumption of natural gas as a fuel 109.1 MMscf/yr . 9.3 MMscf/month C-212 003 Consumption of natural gas as a fuel 109.1 MMscf/yr 9.3 MMscf/month C-213 004 Consumption of natural gas as a fuel 88.4 MMscf/yr 7.5 MMscf/month D-3101 005 Natural Gas Throughput 7,300 MMscf/yr 620 MMscf/month D-3111 006 Natural Gas Throughput 7,300 MMscf/yr 620 MMscf/month F-4101 007 Natural Gas Throughput 51.6 MMscf/yr 4.4 MMscf/month CB 008 Blowdown Events 0.41 MMscf/yr --- TK-1 012 Condensate Throughput 18,250,000 bbl/yr 1;550,000 bbl/month TL 013 External Floating Roof Landing Events 2 events/yr 1 event/month SR 014 Pigging Events 120 events/yr 11 events/month Points 001 - 004: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter or facility -wide fuel meter attributed to fuel consumption rating and hours of operation. Points 005 Et 006: The owner or operator shall monitor monthly process rates based on the calendar month. The volume of gas processed shall be measured by gas meter or by assuming the maximum design rate of the dehydrator unit of 20 MMscf/d. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. 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. 12. Points 005 ft 006 This unit shall be limited to the maximum lean glycol circulation rate of 4.2 gallons per minute. The lean glycol recirculation rate shall be recorded weekly 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 (Lope) provisions under MACT HH. (Reference: Regulation Number 3, Part B, iI.A.4) COLORADO Air Pollution Control Division 13. • oints : e 5 •: On thly. the •<; ; ner or operator shall monitor and record re and pressure, wet gas inlet temperature a period of five years. 14. tion, t ner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the compressor blowdowns using the 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 15. 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) 16. Points 001 - 004: Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shalt have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. a 4.) 17. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 18. Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Regulation No. 3, Part B, Section II.D shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection a Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a quarterly basis. ii. For each leak found in the AVO inspection, a gas detector may be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. Component leaks less than 10,000 ppm shall not require repair. For such component leaks that require a shutdown to be repaired, repair shalt occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re -screened using AVO to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. COLORADO Air Pollution Control Division Page 8 of 23 0 ins •' tions, gas detector calibrations, attempted ful re. rs, repair delays, and post -repair screenings. shall re• , red as soo :: s practicable, but no later than 15 calendar fte unles technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. 19. Points 005 ft 006: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling oper'ations, regardless of size, shall be designed, operated and maintained so as to minimize leakageof volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 20. Points 012 Et 013: This source is subject to Regulation Number 7, Section XII. 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 condensate storage tanks 21. Points 005 & 006: This source is 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; 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 basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.11.1.) 22. Points 001 - 004: This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. 23. Points 005 & 006: 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.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other. convenient means approved by the Division, determine whether it is operating properly. 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. 24. Points 005 Et 006: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section 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% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. COLORADO Air Pollution Control Division ed Pubiz Wetiltq v :r O merit Page 9 of 23 25. , art A, u...rts T: b) o the i• torage 3, 1984, 40 C.F.R Source Performance Standards, Standards ssels for which construction, reconstruction part Kb. This facility shall be subject to all 60, Subparts A and Kb. (Regulation Number 26. Points 005 & 006: 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. (Regulation Number 8, Part E, Subpart A and HH) MA::: HH Atic quire; n e.,` F rea Source P� EE, nzenmissions exemption §63.764 - General Standards §63 r:' 64 (e ) - owner or " erator is exempt from the requirements of • •aph ection 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 - Test Methods, Compliance Procedures and Compliance Demonstration §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under §63.764(e)(1). §63.772(b)(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(b)(2)(i) - The owner or operator shall determine actual average benzene emissions using the model GRI-GLYCaIc TM, Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc TMTechnical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or §63.772(b)(2)(ii) - The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to 563.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. §63.774 - Recordkeeping Requirements §63.774 (d)(1) - An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). OPERATING a MAINTENANCE REQUIREMENTS 27. Points 001 - 006: 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 COLORADO Air Pollution Cc*ttmt Division Departtne r2.,t Pu€ tc Math 6 Er.,6616•66 Page 11 of 23 Division approval prior to implementation. ni ial Tes ing equirements 28. Points 005 £t 006: The owner or operator shall complete the initial extended wet gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or 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 resultsto the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.) 29. Point 007: The owner or operator shall demonstrate compliance with opacity. standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) 30. Point 011: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the owner or operator shall complete the initial extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the liquids analyses and emission calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. 31. Points 012 £t 013: The owner or operator shall complete site specific sampling including a compositional analysis of the condensate routed to these storage tanks and an analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine site -specific emissions factors for VOC and Hazardous Air Pollutants using Division approved methods. Results of site -specific sampling and analysis shall be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. Periodic Testing Requirements 32. Points 005 a 006: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit 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. ADDITIONAL REQUIREMENTS 33. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30t11 whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a diange in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO„) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change 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 COLORADO Air Pollution Control Division povne.^.t ui Pule, i-3eatt, s E-Nrormev:e Page 12 of 23 more, a change in actual emissions of five ver is less, above the level reported on the Fo no - n na • • e pollut If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • 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. GENERAL TERMS AND CONDITIONS 34. 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. 35. 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. 36. 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. 37. 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. 38. 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 abinitio. 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. 39. 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. COLORADO Air Pollution Control Division .atmet Puti _ Heaish. & Lwronment Page 13 of 23 40. ns of the Colorado Air Pollution Prevention y result in administrative, civil or criminal forcemeat), -121 (injunctions), -122 (civil By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Discovery DJ Services LLC of nv (Regulation Number 3, Part A, Section VI.B.) ing time for this permit. An invoice for these t holder shall pay the invoice within 30 days will result in revocation of this permit. 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. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) C-210 001 Formaldehyde 50000 7,242 724 Acetaldehyde 75070 1,030 1,030 Acrolein 107028 633 633 Methanol 67561 308 308 C-211 002 Formaldehyde 50000 7,242 724 Acetaldehyde 75070 1,030 1,030 Acrolein 107028 633 633 Methanol 67561 308 308 C-212 003 Formaldehyde 50000 7,242 724 Acetaldehyde 75070 1,030 1,030 Acrolein 107028 633 633 Methanol 67561 308 308 C-213 004 - Formaldehyde 50000 11,460 933 Acetaldehyde 75070 834 834 Acrolein 107028 513 513 Methanol 67561 250 250 D-3101 005 Benzene 71432 21,810 1,091 Toluene 108883 24,428 1,221 COLORADO Air Pollution Control Division Page 15 of 23 Benzene 71432 13302 6,023 301 11,654 583 4,096 205 D-3111 006 21,810 1,091 Toluene 108883 24,428 1,221 Ethylbenzene 100414 6,023 301 Xylenes 1330207 11,654 583 n -Hexane 110543 4,096 205 CB 008 n -Hexane 110543 336 336 TK-1 012 n -Hexane 110543 298 298 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. 5) The emission levels contained in this permit are based on the following emission factors: Points 001 - 003: CAS Pollutant Emission Factors lb/MMBtu - Uncontrolled g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx --- 0.500 --- 0.500 CO --- 2.720 --- 0.150 VOC --- 1.500 -- 0.300 50000 Formaldehyde --- 0.200 --- 0.020 75070 Acetaldehyde 0.008 --- 0.008 --- 107028 Acrolein 0.005 --- 0.005 --- 67561 Methanol 0.0025 --- 0.0025 --- Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7500 Btu/hp-hr, a site -rated horsepower value of 1875, and a fuel heat value of 1130 Btu/scf. Point 004: CAS Pollutant Emission Factors lb/MMBtu - Uncontrolled g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx --- 0.500 --- 0.500 CO --- 2.430 --- 0.200 VOC --- 0.910 --- 0.360 50000 Formaldehyde --- 0.430 --- 0.035 75070 Acetaldehyde 0.008 --- 0.008 --- 107028 Acrolein 0.005 --- 0.005 -- 67561 Methanol 0.0025 --- 0.0025 --- Emission factors are based on a Brake -Specific Fue Consumption Factor of 7500 Btu/hp-hr, a site -rated horsepower value of 1380, and a fuel heat value of 1130 Btu/scf. COLORADO Air Pollution Control Division e paifrx.�^.t �₹ Pcit't1~. bicw; ca Frvmmme t on information provided in the application an based on a flare control efficiency of 95%. ustion emissions rom ese poin s are accounte• or in Point 007, the process flare controlling these points. Point 007: CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source NOx 0.138 TCEQ Flare Emission Factors C0 0.276 Point 008:. CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source VOC 21,527 Engineering Calculation 110543 n -Hexane 834.1 Point 011: The emission levels contained in this permit are based on the following emission factors: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors --- --- 10 --- Flanges --- --- 100 --- Open-ended Lines --- --- 0 --- Pump Seals --- --- 3 --- Valves --- --- 50 --- Other* --- --- 9 --- VOC Content (wt.--- fraction) --- 100 Benzene Content (wt. fraction) --- 0.0038 - Toluene Content (wt.--- fraction) --- 0.0096 Ethylbenzene (wt.--- fraction) --- 0.0043 Xylenes Content (wt. fraction) _ _ __ 0.0043 n -hexane Content (wt. fraction) --- _ 0.0260 *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 COLORADO Air $cliution Control. Division pkr:rxng x Pubk Heahn 6 E^.vvortxei Page 17 of 23 en -en d - 2. -03 1.4: )4 1.4E-03 2.5E-04 mp Se 2.4 03 N , 1.3E-02 2.4E-05 4. . 8. `°' 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent liquids analyses. Point 012: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Source VOC 0.00114 EPA TANKS 4.0.9d 110543 n -Hexane 0.0000163 Point 013: CAS # Pollutant Uncontrolled Emission Factors lb/event Source VOC 1,425.1 AP -42 Point 014: CAS # Pollutant Uncontrolled Emission Factors lb/event Source VOC 18.55 AP -42 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692- 3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration unit and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(B) when applicable. 8) This source is subject to 40 CFR, Part 60, Subpart OOOOa - 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 2, 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 at the Office of the Federal Register website at: https: //www.federalregister.gov/documents/2016/06/03/2016-11971 /oil -and -natural -gas - sector -emission -standards -for -new- reconstructed -and-modified-sources 9) This facility is classified as follows: COLORADO Air Pollution Control Division atmeit U: Pubtez Health v E'TYi(On1'rtent Page 18 of 23 A. ic. Re.., re , . n Status nth-. i ajorS•- -of: NANSR Synthetic Minor/Major Source of: VOC MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.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 COLORADO Mr Pollution Control. Division marrn nt 1 P,Ftr Fke0. -o Erroronte;t Page 19 of 23 CHME ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES 1. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No., 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 1.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 1.1.2 and make them available to the Division upon request. 1.1.1 The owner or operator may temporarily replace an existing 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 forth in section 1.2. 1.1.2 The owner or operator may permanently replace the existing 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 1.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement COLORADO it Pattution Control Division Pubti= Hee,'th a es>sonrrea Page 20 of 23 engine 'by the operati for the Repo .e fo v/pacif e/alternate-operating-scenario-aos-reporting- forms. 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". of the r lacement engine. The APEN shall be accompanied ing tha he owner or operator is exercising an alternative ent eng , and a copy of the relevant Applicability Reports 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. 1.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: 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 unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 1.3 Applicable Regulations for Permanent Engine Replacements COLORADO ion Control Division f c. Htd h.i, E„vistriment Page 21 of 23 All per Went •laces ent gine that . loc. d in an ar that is classified as attainment/maintenance or nona ust R Av.' .l Tech (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 1.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 1.1.2. Emission Standards: Section XVII.E - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 500≤Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant App icability Reports required under Condition 1.1.2. COLORADO Aix Pollution Control Division aynent c ftbtx Heahn.b E^vvanrrw:t Page 22 of 23 s: 40 CFR Part 60, Subpart JJJJ A perm Vent rf '.ce t e" net t is ufac ` ed on or a ! •r 7/1/09 for emergency engines greater than 25 hp, 7 fi•'<- r en '' . es i0 h for eng eater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,35O hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 1.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 1.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 1.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part 8, S I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 1.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 1.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 1.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 1.2. 1.4 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. COLORADO A#rPattution Control Division ' 'R#r'. rlS �t Iota 4aEiit"^..'J,Ee r'IIonment Reciprocating, Internal Combustion 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. 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. RECE IVZN 62011 cD Stationary This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may a more specific APEN for your source (e.g. diesel 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 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: 17 WE t l vl S AIRS ID Number: 123 /'7 F-7+/ 001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Discovery DJ Services LLC Discovery Lochbuie Compressor and Pump Station Site Location Section 21, T1 N, R65W County: Weld Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Portable Source Home Base: N/A NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (517)455_5799 E -Mail Address2: mnorton@discoverymidstream.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 APCD via e-mail to the address provided. 371976 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 leyCOLORADO 1 I AIRS Number: ID Number: [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 0 Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas ,Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. - OR - ❑ MODIFICATION to existing permit (check each box below that applies) e companyname ❑ Add point to existing permit Change fuel or equipment 0 Change 0 Change permit limit ❑ Transfer of ownership4 0 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 s Notification of Alternate Operating Scenario (AOS) permanent replacement Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 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)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: C-210 Inlet gas compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.colorado.Rov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year 01/01/2018 Seasonal use percentage: Dec -Feb: E Yes ❑ No Mar -May: June -Aug: Sept -Nov: COLORADO 2 IAN o,,,.,,mmi�nmu� Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Hrltl� 6 FJ1NFd1�M�n, Permit Number: AIRS IDNumber: / / [Leave blank unless APCD has already assigned a permit 7 and AIRS ID] Section 4 Engine Information Engine Function: D Primary and/or Peaking ❑ Pump D Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar — Engine Model: 3606 A4 — Serial Number6: What is the maximum designed horsepower rating? 1875 — hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 1875 - hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7500-- BTU/hp-hr Engine Features: C cle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: 0 Lean Burn ❑ Rich Burn Y ✓ Turbochar ed Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural ❑ g Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? 0 OZ Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? 0 Yes ❑ No Engine Dates: What is the manufactured date of this engine? 1017 What date was this engine ordered? hours/year What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? 2018 What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 �1® mom: Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] - Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Latitude 40.035762797/Longitude -104.672510761 TBD Indicate the direction of the Stack outlet: (check one) ❑ Downward ❑ Other (describe): 0 Upward ❑ Horizontal Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): TBD ❑ Square/Rectangle Interior stack diameter (inches): D Other (describe): TBD TBD TBD ❑ Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information #ctual Annual Fie: (MMSCFJyea Fuel Use Rate ® 100% Load (SCF/ hour) 12,444.69 eques e ®grail" eini .ear 109.02 From what year is the actual annual amount? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1,130 , BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf Heating Value (give units): ❑ Other (describe): Requested values will become permit limitations, Requested limit(s) should consider future process growth. s if fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO =6 Fhv4ammt Permit Number: AIRS ID Number: [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? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency %reduction in emissions) TSP (PM) PM10 PM 2.5 SOX NOX NG/Diesel Conversion Catalyst 0 ,-- VOC NG/Diesel Conversion Catalyst 80.0 CO - - NG/Diesel Conversion Catalyst 94.5 — Other: Formaldehyde NG/Diesel Conversion Catalyst 90.0 i Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 tocalculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions g Requested Annual Permit 7 - Ern[cclnn l:irnit(sI..- Pollutant Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) :. Controlled Emissions (Tons/year) ? Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons] year) TSP (PM) 9.91 E-03 lb/MMBtu AP -42 0.61 0.61 PM90 7.71E-05 lb/MMBtu AP -42 0.0048 0.0048 PM 2.5 7.71E-05 lb/MMBtu AP -42 0.0048 0.0048 SOX 5:88 E-04 lb/MMBtu AP -42 0.04 0.04 NOx 0.5 r g/bhp-hr Mfg. 9.05 " 9:05 -' VOC 1.5 / g/bhp-hr -- Mfg. 27.2 i 5.43 .. CO 2.72 - g/bhp-hr mfg. - 49.2 - 2.72 -- Does the emissions source have any uncontrolled actual emissions of non -criteria ❑✓ Yes 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: ❑No ' Non Cnte,_r_aa Reportable Pollutant Emissions Inventory ;_ Chemical Name Chemical �.,. Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Gents Source (AP -42,A- Mfg. etc)6, Uncontrolled - Emissions , .(Poundsl year) Controlled Emissions (Pounds7year Formaldehyde 50000 .- 0.2 i g/bhp-hr Mfg. _ 7.242.2 724.2 ' Acetaldehyde 75070 0.00836 i lb/MMBtu AP -42 1,029.8 - 1,029:8 - Acrolein 107028 0:00514 — Ib/MMBtu AP -42 633.2 - 6332 -- Benzene 71432 Other: Methanol 67561 0.0025 .' lb/MMBtu AP -42 307.97 . 307.97 - 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ---• - -- -W COLORADO �m��mar evn�ic Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision .1 /2017 5 I. a..m�srmne u..a Permit Number:, Cory G. Jordan Name (please print) AIRS ID Number: [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 h condition of general permit GP02. Signature of gaily Authori , d Person (not a vendor or consultant) EVP Operations // /6 ►7 Title Date 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 $152.90 and the General Permit registration fee of $1,500, 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 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-201 —Reciprocating Internal Combustion Engine APEN Revision 1/2017 COLORADO 6i�'n�.1:Zr 1 NMItX'E Fi�Ntonmant Reciprocating Internal Combustion 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. 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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel 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 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: fl 5 AIRS ID Number: 12 3 /0 F1¢/ 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: Mailing Address: (Include Zip Code) Discovery DJ Services LLC Discovery Lochbuie Compressor and Pump Station Site Location Section 21, TIN, R65W County: Weld 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Portable Source Home Base: N/A NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817)455_5799 E -Mail Address2:mnorton@discoverymidstream.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 APCD via e-mail to the address provided. 371977 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 I/ COLORADO Health & fl,.Thal c Health 6 Ewan:mo n, Permit Number: AIRS ID Number: [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) E STATIONARY source ❑ PORTABLE source 0 Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment E Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transferof ownership4 ❑ 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 E Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary, 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for ADS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-211 General description of equipment and purpose: Inlet gas compression For existing sources, operation began on: 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 /attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 01/01/2018 0 Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: ------ --- COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 I�®`°`�""` NYII� 6 FavlemAw1. Permit Number: AIRS. ID Number: [Leave blank unless APCD has already assigned a permit # AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Emergency Back-up P Compression ❑ Pump ❑ Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: 3606 A4 Serial Number': hours/year What is the maximum designed horsepower rating? 1875 hp What is the engine displacement? What is the maximum manufacturer's site -rating? 1875 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7500 - BTU/hp-hr l/cyl Engine Features: Cycle Type: El 2 -Stroke El 4 -Stroke Combustion: p Lean Burn ❑ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes ❑ No If yes, what type of AFRC is in use? ✓❑ Oz Sensor (mV) ❑NOX Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOX design? ❑✓ Yes El No Engine Dates: What is the manufactured date of this engine? 2017 What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? 2018 What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Reyision 1/2017 4017 COLORADO DaptgraIAA Public EmbminW Permit Number AIRS ID Number [Leave blank unless APCD has_already assigned a permit # and AIRS ID] Section 5 - Stack Information s Geographica('Coordinates, r 3 ,i - (Latrtud/Longrtude "or UTM) a` ` � Latitude 40 035621125/Longitude -104 672512481 ltir, "'y-'7" "ss T',V,'� 4 ze'l„:"4, ..A , i~ ,;� =,--- z- � ,. � erator� ;:� �,.;; r ; r' `�- `-'�,rAfiove-Grou�id'Levl t'-- StacklD,No: ' r '. cte„, , w . t -2`YJ'.Ynk ai�.}r�S.,- � :4''-w,'="SSo r '` :-tea' uti',{.-, 4.vr1Discharge k�eigtitz, -� z � �� -;'��. ��-x �r�� Tw 1 rig Y �� 1b-� k�,61reeey-a `-.�... �Ey- G1M'C�. — �'�^"ii Pr .-- . g.�; .4'.'" . d�,."414,-,—, x;, ..;� =e. { � �.f- .S..z � �Tem t�,,,...,:::4,, _ F:7-''' ,,_ x- y s' '•7`L. t Q ).' Tr �w b; i'w -_'" a� �a �C� f� Div'A", " t %'�i.4✓t'4`�w 41-.C" j'"' ;;i '� �'�4 , o, --` a��lo��ate�s-��'�---�-�.Ve ...4_ - y-: ' '-,,t5 ' � -' YS _ ,. , .4,. sr,,,,,m;;----, a, hr .Ff��,'''z.'-'0,-14%r--4-'4-ar,T .. x '°v. �'�'�u i'""�%,f t' t" - r x'= _ .' ocit�r��. r .3,,7f. i ; �•I S�`r �Y"Y1-... f` > � (f, n-, �� ..S t.,<« '.,x TBD TBD TBD TBD TBD - Indicate the direction of the Stack outlet (check one) ❑✓ Upward ❑ Downward D Horizontal ❑ Other (describe) Indicate the stack opening and size (check one) 0 Circular ❑ Square/Rectangle ❑ Other (describe) Interior stack diameter (inches) ❑ Upward with obstructing raincap TBD Interior stack diameter (inches) Interior stack depth (inches) Section 6 - Fuel Data and Throughput Information 4 ' i fFiiet%Use:Ra e_ C�?'100%"Loads ~ [+ .. �y� ^`1L ^^_J '-SL n =.T4 Y i �S Y_,�`.�_ Y?--,;LI' C -T - ).-a- ,,,,, , ..I .w y ,f.�.,4,-,,,—.. hourawq -" ,--.-.. }w?. SSWR�+��..'��. ` FACttaa Ffrivar-ruet11Use. s _ L°'i",,,,,71.-L-,-,"�J,'As , $ 4 i9 .z 4,T- _ °S��i -^„„,,e5 MINSCF/year�� sT sxs �T��"=�' �{'� +wt�� - �K<c Reques`ted Annual-Permitlimit £`.•� '...Ps -'F -1-1 - ;- �1-1,4.5-C-.-7: Y'�'.� z'-7- Q: ." S='mil r .n81t:' '2?�4 (M7YISCFJyea '_ � � _,.-„,..,7a-- � _Sw �wnF.4,r�= Fwz 12,444 69 - 109 02 - From what year is the actual annual amount? Indicate the type of fuel used' ❑ Pipeline Natural Gas n Field Natural Gas ❑ Propane ❑ Landfill Gas ❑ Other (describe) Heating Value (assumed fuel heating value of 1,020 BTU/scf) Heating value 1 130 - BTU/scf (assumed fuel heating value of 2,300 BTU/scf) BTU/scf Heating Value (give units) 7 Requested values will -become permit limitations Requested limit(s) should consider future process growth 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field Form APCD 201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 IAV COLORADO XWabFnvwnm�M i Permit Number _ Is*any emission control' equipment or practice used to reduce emissions? AIRS ID Number - [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 O Yes ❑ No cnbe the control equipment AND state the overall control efficiency (% reduction) - -� '` = T� : r -4 "� s - s � � _r` „ _- nc:.n.a s; r= *x _`, .1rY t , "Oyera"Il°Re ueste Conf of ,rte 4 --',--cm--,,,,-. C tebt y"4 f�+ ;a Po7tant `Y', s` ['s4,,6 '�"p+�is�'��,�5� / , `4tAi pd {ayt`;"4•ya "'r�"_.+1 ..n.fnL -..^ �iG.�� F`-��. i �p„��,'�l.a �Pnmary Control Equlpment`Descn tor► -,-L :i' ,Y'�> 5y -' '!c --,C, a�,i�r 4=- �'-"`_- .wf r,l"-< .,-/4 `�',..'",--".t-47:4_.4"1,gyc�'k�_ � at A �..a � ' ' �,. _,-�� w - k ;'-t, .�n ' y- --r=`� .��,ea,�' _ty'{. ��915 .. u,r1J'P'3 Al.,---' wm; -, Efficient.Ate, 7t ��.-�,-��'reduct�on rn em/ssrons �.,�a,.. ._ ti )fi ^r F ., 'TSP (PM) , PM10 ,PM25 - NO NG/Diesel Conversion Catalyst - ' L 0 VOC NG/Diesel Conversion Catalyst 80 0 - CO NG/Diesel Conversion Catalyst 94 5 Other Formaldehyde - NG/Diesel Conversion Catalyst 90 0 - Use the following tables to report critena and non -criteria pollutant emissions from source '(Use the data reported in Section 6 to calculate these emissions ) ' From whatyear _ is the following reported actual annual emissions data? �1+t Irv,• 14.r caµ r. �""z .,---g.M;* -�,� r,:_., . Cr,�tenaf�P,,ollutant�Emtssions�lnvento -w"'� '' ice" 2 }.", �t e .ti --4' r, . Requested' Atmual'Qerrm�ry,.. ` `-= Emrssron.Limrt(s) .4 ;: Pellutant TSP (PM) PM10 PM25 SOX NOX VOC a Emission Factof=< �tource;� Uncontrolled}« '� AP ?I2;n fg'etc') 991E 03 �s Unit3�� lb/MMBtu AP -42 Y Actual AnnuaLEmiss1onsy ,-' +. r _ *.4Uncontrolledc` sy-K"•Y-� �i f,EmissionS1 ".,a„� - x(Tonsiyear):.`'' d ,Conttrro-lled r, p Emission�s� _ e (Toni ear)A^ �:Uncor�tr°�ewrr} (missions (Ions1year -, 061 R, r=ControlledF EmissionsF_r] 5,5;4_ ons/year) _ _ 061 7 71E-05 7 71E-05 Ib/MMBtu Ib/MMBtu AP -42 AP -42 - 0 0048 0 0048 0 0048 0 0048 5 88 E-04 05� Ib/MMBtu g/bhp hr AP -42 Mfg 0 04 -9 05 - 0 04 T CO 150 272 g/bhp-hr g/bhp-hr Mfg Mfg 272-/ 49 2 9 05 543' 272 - 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 ❑� Yes ❑ No _;} a�--..�r^ti- •-c..{?��{(a. m::k��. ��e:.'�T.�'�,�„'nF' jN,y =n'GT E`.'7`'s-!-=-7,7-''3-*":=J �- �� —✓r_ 9 "�4.r !" y.-�{'c4�[��.�'5=�Tr :��; �a = �,�,,�_��.IVonzCntena=_Repor_tab'le..o"Ilutant�Emissions �lnventory-,:�� , ,_� 1ti,W; ^ 4+`P� ,._ '-^ �' t . � � ,-. ,�� - � �="? �3°l3 � �, x' ✓.�"� {frir X'a�C " " Cheg,p, rName, �k,�,,, � * _ �- _-..'„-;,,..ii`*�^>^`s(��raJ`' �.. ygln } .� �qr �i��s'J-��+�-"-�F'r�" ��52�'tut'��, .4 7"3r Ch�micaly y_ �S-'vY"'^ 'rF.2�.. Abstract ="-" 5ervrce# CA5 Dr �r��[�"k�� +,. ,,, t+ ^?a r t •�'1V.-T Zr ., -'4 y i t �.��..:,��Emission,Factotx �,�"� �:,�� r Z' �W-��Ac�ua'l:Annaals.Emtssrons�,.,,��;_- i�'ri zw'.'+Z3ig. , �j% ' fR 2Uncontro1Kcl...s.. y Emissions s�"..� - ��--�� (Pommels/year),F,,.i( L 4 µ: _. ^^ '�' � Y.. -`" _ Controlled Emrss ons; ' Pounds! ear 3 .. .k��ra(.. 'mss-v.-rw rS a"= 3' ncontrollec�� u_ 0;T�Uni �`Basis'��v� a ;:- �'�'� tl4a �rA'`..1J -. -a ° " v � „ r�.y ,� , ry.`� r'._'^-1'�i. h ma? �_ +S�.`sk.�F source AP442 q;,�l.,e { "") tiVit `etc . �i S"r_ ,_,Y ,��_- ,:'-.,�+e-,-.-w,u<�' Formaldehyde - 50000 02- g/bhp-hr Mfg 72422' 7242 / Acetaldehyde 75070 0 oo63s Ib/MMBtu AP -42 1 029 8 . - _ 1 029 8 -Acrolem 107028 0 00514 ' Ib/MMBtU AP 42 633 2 ' 633 2 / Benzene - 71432 Other Methanol i 67561 00025 ' Ib/MMBtu AP -42 307 97 - 307 97 i ,7 Requested values will become permit limitations Requested limit(s) should consider future process growth 9 Annual emissions fees, will be based on actual controlled emissions reported If source has not yet started operating, leave blank Form APCD-201--Reciprocating Internal Combustion Engine APEN,- Revision 1/2017 _ 5IA® Muth COLORADO 6 UWU %Mm, Permit Number: AIRS ID Number: [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 witch condition of general permit GP02. v ' � Signature of Legally Auth zed Person (not a vendor or consultant) Date Cory G. Jordan Name (please print) EVP Operations 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 $152.90 and the General Permit registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 Or visit the APCD website at: 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: https://www.cotorado.gov/cdphe/aped Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 6�A®== N�IN h F�+vuanm�e� Reciprocating Internal Combustion 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. 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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel 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 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: �� w {1615 AIRS ID Number: ) Z3 /61 F74-/ 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID], Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Lochbuie Compressor and Pump Station Site Location Site Location: Section 21, T1 N, R65W County: Weld Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Portable Source Home Base: N/A NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: E -Mail Address': (817) 455-5799 mnorton@discoverymidstream.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 APCD via e-mail to the address provided. 371978 COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source O Request coverage under a Construction Permit ❑ Request coverage under General. Permit GPO23 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 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 name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑ 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 replacements Additional Info a Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 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)? Yes If yes, provide the Company Equipment Identification No. C-212 General description of equipment and purpose: Inlet gas compression For existing sources, operation began on: 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/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 01/01/2018 ❑✓ Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2O17 2 I AV COLORADO Depu.&I PublicPublicXnNeed,6 EA•traamMm Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine ❑ Primary and/or Peaking ❑ Emergency Back-up Function: ❑ Pump ❑ Water Pump ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: 3606 A4 - Serial Number6: hours/year What is the maximum designed horsepower rating? 1875 - hp What is the engine displacement? 1/cyl What is the maximum manufacturer's site -rating? 1875 - hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7500 — BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑� 4 -Stroke Combustion: ❑✓ Lean Burn ❑ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes E No If yes, what type of AFRC is in use? ❑✓ OZ Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑✓ Yes ❑ No Engine Dates: What is the manufactured date of this engine? 2017 What date was this engine ordered? ❑ Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? 2018 What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GPo2 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 COLORADO Departaterd Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit rY and AIRS ID] Section 5 = Stack Information Geographical Obrclmates (Labtude/Lon tude 4- 1r'. f 3s Latitude 40 035448076/Longitude -104 672514582 :---,..,t,------„.,'mv=� 2 --- -'.{i� 12,-,- ' ,� 'tT =>vj=- � Y Operator z '' ,x ' Y _« Stack lU No. 5.%� "' Yr r.w'x�d `1 �z 4 'i rY ' ��, 4 j -ii � vwe,V+dry,•�1�lr�^raS+�'A`14:.it�fi>;+'�r'f,[x��'Ih�"-,..+`r�'�'+w c'Y _s-c� gr ..,t ""C z t-Dischz- erH-- -- �- -. , 4" >' .Above Ground l.eveit- yk c ^. +� k{ "i1`7+r'L`= yrt[l�f�' , `t'` " '(FeetAz .—q„, �(7.e's. k"' `+ S M �`irC nx ," ,,a^ rv`1"3-7x-4+,«r �'4y µ lYr �� t �� too-- � ..em r-1 n 3 x rr i _ � ;, , I 5�; _ d (,F'� r A. :iF� .i� ` z- ^' -,='�y,, ^.j ,' ,, 4 �-4- .r : -" �3. 'L -'b-� .,�S`ld �� c�.4•--—�ib.J�"'y;sa 4 �1r- Tc *1.- ,Y} i . ' ", F ow Rate^ fi :.� i r,'� = z (AtF.I,11 Z �;- ^ �e..� �.n3"+ „ .'3" �"' rt %;$14 �.'=-e= 7,,01%;$144=-e= r.,4, --4,-- ' 'n^?,•,,..,..-,.; -`• "r ..�- pL l JY„�rt 3. _� Velocity q ¢ '�-4 ,1 -# - f, y s- t/sec (/ Y� S� ��' � t 'k.� /' �i'r - f .t""_..t TBD TBD TBD TBD TBD Indicate the direction of the Stack outlet (check one) 0 Upward ❑ Downward ❑ Horizontal ❑ Other (describe) Indicate the stack opening and size (check one) E Circular ❑ Square/Rectangle ❑ Other (describe) Interior stack diameter (inches) ❑ Upward with obstructing raincap TBD Interior stack diameter (inches) Intenor stack depth (inches) Section 6 - Fuel Data and Throughput Information �s"�'F l U"se Rate".C�'100%L_oa"d'b �' s t ue ,. x.;-'�-X Y`s�'a'"r 'r-,7 ti a.�'�ywp 7'=.--17, -s � a u(SCEMbirif q'4 -}� - _ - "t ActualAnnual°Fuel4Us'e 4r = :. rt - i,-'Y.�^.-x.� �;� ;7} "5� n#• (MMSGFJzPar% "c•--2--,-----0f�t -k-2`-7 a' yen, -t^ = - Y4=-., -•� Requested-Annual'Per,mrt',L-imit''Y _ I�v - r ^ �_ � 3,� �',. '?W � r'�x � --4.,„ (MMSCFlyear) r ..`.�+ .Lw.«ctr--. : —L 12,444 69 '- 109 02 - From what year is the actual annual amount? Indicate the type of fuel used8 O'Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) E Field Natural Gas Heating value 1,130 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value BTU/scf ❑ Other (describe) Heating Value (give units) 7 Requested values will become permit limitations Requested limit(s) should consider future process growth 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field Form APCD 201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 4 I AV He�IjN b Frmavnem Permit Number AIRS ID Number [Leave blank unless APCD has all eady assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emissi factor asdocw h doecumentation to calculationsAPEN form The APCD website has a Natural Gas Fired Engines Calculator available � No Is any emission control equipment or practice used to reduce,emissions7 ! Yes reduc❑tio o ) If yes, describe the control equipment AND state the overall control efficiency (% _edu Overall Rquested-Copt% ,� ,-- _,,,.p,,,..„,,,,, Efficiency-- ;" = , t (%-reduction m emissions) Use the following tables to report cnteria and non -criteria pollutant` emissions from source a (Use the data reported in Section 6 to calculate these emissions ) From what year is the following reported actual annual emissions data? � fissions lnve itpr � Y �Criter�iraPollytant=Em M1 -Actual AnnuakEmiss ons_,Tzz ° i4 ti..d ' . COntrplea y -on' lo No Does the emissions ce have any uncontrolled actual a oremissions of than non -criteria year? pollutants (e g HAP - hazardous air pollutant) equal greater source If yes, please use the following table to report the non-cnteria pollutant (HAP) emissions from soe on,Crateria,Reportable"Pollutant Emissions_ Inventoryy, Y- s�-9E,� m s:--z,---,'.,t-nac o, - -4? -r f -`,,x:, Actua_ Annual.Emissions..;— ctor� ; , - _ T" �, _ , _ ,ter- `, , , 'Emission Fa P, a ,fir-- �, r.`�;-t-'�".�� rzr-'r �.`e""+*�+. :mm Uncontrolled F µ Controll"ed`Em9ssions" :ontvolled, F " Y - `�Emissioris -Y u (Poundslyear� :J , Mfg:et )x ,1-,.T.(Poundsl_yeAr)�, I El Yes Requested values will become permit limitations Requested limit(s) should consider future process growth leave blank 9 Annual emissions fees will be based on actual controlled emissions reported If source has not yet started operating, _ _ _ _ _ _ _ COLORADZ Form APCD 201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Permit Number: AIRS ID Number: [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 eachndition of general permit GP02. // f6 -Y7 `r � Date Signature Cif Leg Authorized P on (not a vendor or consultant) Cory G. Jordan EVP Operations Name (please 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 $152.90 and the General Permit registration fee of $1,500, 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 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 tow, COLORADO 6 I Li'�, - ==k Reciprocating Internal Combustion 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. 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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel 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 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: I- E-11°15 AIRS ID Number: 123 113F7+/ 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Lochbuie Compressor and Pump Station Site Location Site Location: Section 21, Ti N, R65W County: Weld Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Portable Source Home Base: N/A NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817)455_5799 E -Mail Address2: mnorton@discoverymidstream.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 APCD via e-mail to the address provided. 371979 1Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1 l e = Permit Number: AIRS ID Number: [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 0 Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. - OR - ❑ MODIFICATION to existing permit (check each box below that applies) company Change name ❑ Add point to existing permit Change fuel or equipment ❑ g p y ❑ Change permit limit ❑ Transfer of ownership" ❑ - 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 replacements Additional Info Et Notes: Other (describe below) 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary, -4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 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)? Yes If yes, provide the Company Equipment Identification No. C-213 General description of equipment and purpose: Inlet gas compression For existing sources, operation began on: 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/attainment) hours/da days/week 52 weeks/year Normal Hours of Source Operation: 24 Y 7 Mar -May: June -Aug: Sept -Nov: 01/01/2018 Seasonal use percentage: Dec -Feb: ❑✓ Yes ❑ No - -------_-� ---- COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN Revision 1/2017 2 IAN' H.a Enw.onw.n, Permit Number: AIRS ID Number: / > [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine ❑ Primary and/or Peaking ❑ Emergency Back-up Function: 0 Pump ❑ Water Pump ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? N/A Engine Make: Caterpillar Engine Model: G3516 J Serial Number6: What is the maximum designed horsepower rating? 1380 ' hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 1380 — hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8256 BTU/hp-hr, Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: 0 Lean Burn ❑ Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No hours/year If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes ❑ No Engine Dates: What is the manufactured date of this engine? What date was this engine ordered? ❑ Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 AYCO L'OR ADO NYIN 6 F rleonmM� m�d Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 5 - Stack Information - - v .Geograph1cal`,Coordinates ,, ''. (Latitude/Longitude or UIM)m Latitude 40 035309479/Longitude -104 672516300 SFr Operator z�. tu�scJ TBD • Discharge lietg � Atiove Ground Level4 (Feet TBD TBD 1-wRt ACFM ` TBD TBD Indicate the direction of the Stack outlet (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe) Indicate the stack opening and size (check one) 0 Circular ❑ Square/Rectangle ❑ Other (describe) Interior stack diameter (inches) Interior stack diameter (inches) ❑ Upward with obstructing raincap Intenor stack depth (inches) Section 6 - Fuel Data and Throughput Information Filel;Use Rate`@1007 Loe (SCRhour), 10,082 55 e Ac ual?An 1 u lltire User" t k 5'��tt/v1A?5CFea� `�� j 5 88 32 From what year is the actual annual amount? Indicate the type of fuel usede (assumed fuel heating value of 1,020 BTU/scf) Heating value 1,130 " BTU/scf (assumed fuel heating value of 2,300 BTU/scf) Heating Value ❑ Pipeline Natural Gas ❑✓ Field Natural Gas ❑ Propane ❑ Landfill Gas ❑ Other (describe) BTU/scf Heating Value (give units) Requested values will become permit limitations Requested limit(s) should consider future process growth 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field Form APCD-201 - Reciprocating Internal Combustion Engine APEN Revision 1/2017 --� COLORADO I 4 m{�'1 0,�.,,o,;,� Hulce b Env4enweN Permit Number AIRS ID Number / / [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? El Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction) TSP (PM) PM10 PM25 nmaryyControl-Equipment Description_ - _�' � Overall;Requested,Control v w= Efficiency?„ eYt�. n.-% � ma=,=- r'educhorfit; emissions) SOX NOx VOC NG/Diesel Conversion Catalyst 0 CO NG/Diesel Conversion Catalyst 60 4 Other Formald ehyde NG/Diesel Conversion Catalyst NG/Diesel Conversion Catalyst 918 91 9 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? Pollutant= TSP (PM) PM10 PM25 ear SAP d,�1.1-‘7,7"3 ,Cntez na,,Pollutant,Emtssions;Inventory- % „w,-,� -•-Emission' Facto: .Uncontrolle3:, Basis --'= 9 91E 03 SOX NOx VOC CO lb/MMBtu 43- Source'-"-- - (AP42W, TAfigg etc) `p AP -42 Actual.Annual Em�ssions- -Uncontrolled Emiss5o'n 4ronsiyear) Controlled _Emtssions• 4 7(TonslyearF spa^: -_..'+x343 F"- equestel,Annual Permit -41,t Emission'Ltm 1 Unco i rotted„ ,}� Einisrs�ions�ti 0 49 "`,= Controlled � ` ',Emissrons�-- 5�' ,(tons/year)„,, 7 71E-05 7 71E-05 lb/MMBtu lb/MMBtu AP -42 AP -42 0 0039 0 0039 0 49 0 0039 0 0039 5 68 E-04 05 lb/MMBtu AP -42 0 03 0 03 091 -- 243 g/bhp-hr g/bhp-hr Mfg 6 66 Mfg 1213 - 6 66. 4 80 g/bhp hr Mfg 32 38 267 i 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-cnteria pollutant (HAP) emissions from source 0 Yes ❑ No Formaldehyde Acetaldehyde Acrolein -N`on=''Criteria"Rep stable Pollutant,Emsons_IiiventorV x =. 34-0, Chem ca9 r Abstract YIt �Servtce l(CAS)` 50000 w"Emtssion:Factor-m,. On ontrolled 0 43 "Units' glbhp-hr *s (AP~c42, Mfg^etc). Mfg • Act al -Annual Emtssions Controlled Emissions , �- Emissions i_ ry�� LYncontrolled (Pound /y ) 11460 75070 107028 71432 0 00836 - 0 00514 lb/MMBtu lb/MMBtu AP -42 AP -42 8344 ' 5130 9327- 834 4 . 513D r - Benzene Other Methanol 67561 0 0025 lb/MMBtu AP -42 250 0 r 250 0 7 Requested values will become permit limitations Requested limit(s) should consider future process growth' 9 Annual emissions fees will be based on actual controlled emissions reported If source has not yet started operating, leave blank Farm APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 �®COLORADO d.,..,,. Permit Number: AIRS ID Number: - [Leave blank unless APCD has already assigned a permit # and ARS 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 e. h condition of general permit GP02. Itj• Signature of ally Authori -': Person (not a vendor or consultant) Cory G. Jordan Name (please print) EVP Operations // -16-17 Title Check the appropriate box to request a copy of the: Q 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 $152.90 and the General Permit registration fee of $1,500, 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 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd COLORADO Depaem�mtol AiEllc Form APCD-201 - Reciprocating Internal Combustion Engine APEN Revision 1/2017 Nulty b EneWn�bvM CDPHE //------\ 1 -- ,V E %Di le 91 APCD (..,0,1, ces Glycol Dehydration Unit APEN - Form APCD-202 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. This r on unit does not fall into this APEN is r be d for Glore APEN for your source. In additDehydration (Dehy) Units only. If ion, theiGe General APEN (Form APCD 200) is category, there may be a more specific 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/aped. is uired 30 ays r to on of t emission aotee is valid for reportable rs. change issmade (significant emion of a revised issions increase, ncreasoe production, of the five-year term, or when new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1-1JE1115 [Leave blank unless APCD has already assigned a permit # and AIRS ID] AIRS ID Number: 123 i°1 F741 005 Company equipment Identification: D-3101 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] ,p Section 1 - Administrative Information Company Name: Site Name: Site Location: Discovery DJ Services LLC Discovery Lochbuie Compressor and Pump Station Site Location Section 21, T1 N, R65W County: Weld Mailing Address: 7859 Walnut Hill Lane, Suite 335 (Include Zip Code) Dallas, TX 75230 NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton@discoverymidstream.com 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt 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 APCD via e-mail to the address provided. 371980 Form APCD-2O2 - Glycol Dehydration Unit APEN - Revision 02/2017 1IACOLORADO °z== Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action 0 NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) Add oint to existing permit ❑ Change fuel or equipment ❑ Change company name ❑ P ❑ Transfer of ownership3 ❑ Other (describe below) Change permit limit ❑ -OR- ❑ APEN submittal for update only (Please 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 a Notes: 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. Facility equipment Identification: For existing sources, operation began on: 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: days/week Yes Yes TEG dehydrator for the removal of water from D-3101 Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS ainment Is this unit located at a stationary source that is considered a area Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 01 /01 /2018 O weeks/year No No fl AIRS ID Number: Permit Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: Glycol Pump Drive: TBD TBD DiEth lene Glycol TriEthylene Glycol ❑ Ethylene Glycol y ❑ (EG) (DEG) (TEG) Electric O Gas If Gas, injection pump ratio: Acfm/gpm # of pumps: 2 -- Model Number: TBD Reboiler Rating: 0.6 0 Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 4.2 �- 0.15 ' Wt.% Requested: 4.2 i MMBTU/hr Dehydrator Gas Throughput: Design Capacity: 20 MMSCF/day 7,300 Requested:MMSCF/year Actual: MMSCF/year Inlet Gas: Water Content: Wet Gas: Flash Tank: Pressure: 1100 Pressure: 65 Cold Separator: Pressure: Stripping Gas: (check one) ❑✓ None O Flash Gas ❑ Dry Gas O Nitrogen Flow Rate: scfm Additional Required Information: psig Temperature: lb/MMSCF 0 Saturated psig Temperature: psig Temperature: 120 Dry gas: °F 7 lb/MMSCF 145 - °F O NA °F 0 NA O 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) 3I Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO **lth&.mm am ildla 6 ...am., TBD Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 5 - Stack Information eokap, tiicalLCoordinates- LatitudelLangrtode, orUTM,)Y� Latitude 40 035325592/ Longitude -104 672803144 ;�, � r - �;,-uiscnarge_Fleignt 4 Above, Grou, d'eve (Fee k ; r TBD Indicate the direction of the stack outlet (check one) ❑ Downward ❑ Other (describe) 0 Upward ❑ Horizontal TBD Indicate the stack opening and size (check one) Intenor stack diameter (inches) 0 Circular ❑ Square/rectangle Interior stack width (inches) FloRat`e'. TBD (ft/se>, 4.4 TBD - ❑ Upward with obstructing raincap TBD Interior stack depth (inches) ❑ Other (describe) Form APCD 202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 4 ANY Nu1Nb Gevmn 1 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information Used for control of: Regenerator Condenser: Type: BTEX Make/Model: TBD Maximum Temp 400 Average Temp 125 Requested Control Efficiency 0 ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed % Combustion Device: Used for control of: Regenerator Vent & Flash Gas Rating: 6.27 MMBtu/hr Type: Process Flare Make/Model: TBD Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency 95 % Minimum Temperature: Waste Gas Heat Content 1500 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.0456 MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime ❑ Other: Used for control of: Description: Control Efficiency Requested 0 Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO Gepuimal d Pub& x..� tr,.mr,.,w Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit It and AIRS ID] 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? E Yes ❑ No es, please describe the control equipment AND state the overall control efficiency (% reduction) k".Z� '"1'-5r _ y� f---,--z-...---d:,Poll taut. ^; ; !-„_- iu^ f�� -_ �h�{`�`� ��_i''�'^'^ a- ��r..0 �- 'rte i\`� " r -� - } Cantrol_Equipment Description`' _ _=' == ,L't _ __ waj _ z .+_...,";i j - +. .. _4',_ ->r . , - - .-} > - ,' , _ -_ - -- l- -- i __ _ - _ - ovef-all Request`e'd"CotitfoP 1----,-k.,,,,,-.�. :- Efficiency_ ,-ti1c �� r '_ _ (%reductron 3n emissions] �; PM SOX - NO„ CO VOC BTEX Condenser and Flare 95% HAPs BTEX Condenser and Flare 95% Other - - From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source -- _ r r mss= r +ss � ;- + iy---g-,,� : - r." :tea , - ,` r vc 4 „ ;Pollu'tant's - , i c _ ^�„ Uncontrolled _, -`>` T Emission a Rte_ f __�, ,= _,Factor v_ _ s "Emission' 'f ' Factor ,_ _ ��,�Sour•ce..-, s _Units=- f �- K c.` _ Factor ;, �� „1 (AP -4f ^;, JMfgt etc)a_ _ActualAnnualsEmissions�;y- -,,,,...,;-_,,,t,•" rY e �y� `i.-" ^s.'hv e-'<� i '_'`�T �'r+�S�c'kr_ €Em ss ion_ Y4�``` n � �f �`. 7.�. � "��.:�"��`+_�J-_ - FUncortrolled_ (Tons/year) r "Confrolleds r (Tons%year) F Uncontrolled= :_(Tons/}fear).;a ;Controlled ' '`(Tons/year)'; PM SOx NOx , - CO VOC 31 04 Ib/MMSCF GRI-GLYCaIc 113 31 i 5 7 - Benzene 2 99 lb/MMSCF GRI-GLYCaIc 10 91 c 0 55 Toluene 3 35 Ib/MMSCF GRI-GLYCaIc 12 21 --- 0 61 Ethylbenzene 0 83 Ib/MMSCF GRI-GLYCaIc 3 01 ' 0 15 - Xylenes 1 60 Ib/MMSCF GRI-GLYCaIc 5 83 , 0 29 ' n -Hexane 0 56 Ib/MMSCF GRI-GLYCaIc 2 05 '0 10 2,2,4- Tnmethylpentane 4 , Other 4 Requested values will become permit limitations Requested limit(s) should consider future process growth 5Annual emission fees will be based on actual controlled emissions reported If source has not yet started operating, leave blank Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 6 I �®COLORADO HWtl, b Fn �tNv unwu Permit Number: AIRS ID Number: [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 Ll ally Autho/fzed Person (not a vendor or consultant) Cory G. Jordan Date EVP Operations Name (please 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) Send this form along with $152.90 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 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 • 7 1 AVX...,K�„ !M NI bEnwmmam Glycol Dehydration Unit APEN - Form APCD-20 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. 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. 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: 11WE(1Vt5 _ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: D-3111 AIRS ID Number: 12.3 /gF74-/ 006 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Lochbuie Compressor and Pump Station Site Location Site Location: Section 21, Ti N, R65W County: Weld Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 E -Mail Address2: mnorton@discoverymidstream.com NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 '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 APCD via e-mail to the address provided. 371981 Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 1 I COLORADO D.pulmml of Public • HAWN', EA.omn,m AIRS ID Number: l ' Permit Number. [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action I NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 -OR ❑ APEN submittal for update only (Please 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: O Add point to existing permit Other (describe below) 3 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. Facility equipment Identification: For existing sources, operation began on: TEG dehydrator for the removal of water from 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: days/week Yes Yes D-3111 01 /01 /2018 Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN -Revision 02/2017 weeks/year No No /CD.4D'RADo mien s.F: woeun+n+ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit #.and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model Number: TBD Dehydrator Serial TBD Number: Ethylene Glycol DiEthylene Glycol TriEthylene Glycol Glycol Used: (EG) ❑ (DEG) ILI (TEG) Glycol Pump Drive: D Electric ❑ Gas If Gas, injection pump ratio: Acfm/gpm Pump Make and Model: TBD Reboiler Rating: 0.6 MMBTU / hr # of pumps: 2 Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 4.2 0.15 - Wt.% Requested: 4.2 Dehydrator Gas Throughput: Design Capacity: 20 ' MMSCF/day' Requested: 7,300 - MMSCF/year Actual: MMSCF/year Inlet Gas: Water Content: Wet Gas: Flash Tank: Pressure: 1100 psig lb/MMSCF Pressure: 65 psig Cold Separator: Pressure: Stripping Gas: (check one) ❑✓ None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Temperature: 120 ❑✓ Saturated Dry gas: Temperature: 145 °F 7 lb/MMSCF ❑ NA psig temperature: °F 0 NA _ Additional Required Information: Attach a Process Flow Diagram Attach GRI-GLYCaic 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) Attach the extended gas analysis (including BTEX & n -Hexane, temperature, and pressure) Form APCD-202 -Glycol. Dehydration Unit APEN - Revision 02/2017 COLORADO Departmental Pb& Halal. 6 £nuftnvwv p Permit Number - AIRS ID Number [Leave blank unless APCD has already assigned a permit q and AIRS ID] _ Section 5 - Stack Information G eoographical Coordinates y= ti4Lahtude7LoRg�t[ie`_or UTM) Latitude 40 035188339/Longitude -104 672804810 Yr 1 "� »•- -r w.,5w ,:,-,c r4 -e- .te a ''-,, ie,4 -. z n r a -,4,....A,,,,,,,^- F1nr tac D=t o r . a �. ..'..,..,•-`�))"� fy Zed-'Yyy �^t ,y, 'w7 ,- -..>4 a '. . 'tom• m C �L er ss- �"�SE t ,Discharge,}leshtz rw ,3 k ;�<- t , Above Ground,L'evel :r �;`:�t,.,:-. �, � � ' � ^ 44r1 � ra (Feet) -,.' b.. " ay_�: $ i:a k..: c rr.ii' � ,.. r T".a�_�.Fw ,--,•,...r,,s� ��m--fZ,w...y- �R= a_ ,,s,--4 y ,, ; F em .. et --z tea ' „ wry, �� F � «:A r; (� ) ... �,��e�=��" rte•. r �4�, �Lx`.. ..`�i..i a x 2-a^",",,-i; i VAS tFye•. 'y r Flow Rates __ �� ,, �,�, = y � F� ACFM ..�. ��r,. x (v J< �' o-� --3*tiTa.�Fz".- � -�" §rv`q-- , 1oc� e- ale t�! r s, X` '�" tlsec '_ ^�aTf .� i=� ti, t� ,;%� rf�i-'s ^_„i}'Y--- TBD TBD TBD TBD TBD Indicate the direction of the stack outlet (check one) 2 Upward ❑ Horizontal ❑ Downward ❑ Other (describe) Indicate the stack opening and size (check one) ❑ Circular Interior stack diameter (inches) ❑ Square/rectangle ❑ Upward -with obstructing raincap TBD Interior stack width (inches) Interior stack depth (inches) ❑ Other (describe) - - -- - - _ _ _ ,_ _ _ -__—� _— _4 I AVCOLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 ""'"�` Nunn 6 Enwonnunl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information Used for control of: Regenerator Type: BTEX Make/Model: TBD A Condenser: Maximum Temp 400 Average Temp 125 Requested Control Efficiency 0 % Used for control of: Size: Make/Model: IN VRU: Requested Control Efficiency % VRU Downtime or Bypassed % Used for control of: Regenerator Vent & Flash Gas Rating: 6.27 MMBtu/hr Type: Process Flare Make/Model: TBD 0 Combustion Requested Control Efficiency: 95 % Device: % Manufacturer Guaranteed Control -Efficiency -95 Minimum Temperature: Waste Gas Heat Content 1500 Btu/scf Constant Pilot Light: 0 Yes • No Pilot burner Rating 0.0456 MMBtu/hr Used for control of: Closed • Loop Description: System: System Downtime Used for control of: IN Other: Description: Control Efficiency Requested COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 5 I Departmental wwc XWtI, 6 Envlmrunw Permit Number ' AIRS ID Number -[Leave blank unless,APCD has already assigned a permit >i and AIRS ID] Section 7 - Critena 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 2 Yes ❑ No If describe the control equipment. i. r u bLULC LIlC Vv_i a« ,-.LI,," W • • •�•—• •—, •- .- j __ yes, please .p t iy Pollu" tanV �^' " � : F� .�C., ,1.:Lkn}- a-4.ri �i.=—Ka,r, 7!- --,.% a fie, - - - n '.'_.i'[' 1.e ALA t.._?,^ �-et 3'' 5 , -ontrokEquipment-Descnpt on G; a`•- � R„ , .�, , 1-,T r.-3-,-• .- - rr x Y LoveralFRequestea:Contrcol'_ �A..74?.b4„t ,---- + 1YGn.2.y Y„ 4Tri3 I. ; ,- ffacieney, � (�6 reduct7on in emissions), PM SO. . NO, - - CO 4 - - - - -VOC BTEX Condenser and Flare - _ 95% 7' HAPs BTEX Condenser and Flare 95% Other ? From what year is the following reported actual annual emissions date- - ,Usethe following table toyreport the criteria pollutant emissions from source LL • _._ i c t.. �., I -,,Into hhoco om7ccinnc I Jse the aura reporrea in arc uvuz . LA" ti _ r<i�a�n -'z .r s s_9+ w" r ₹47,-. - '-^ - nalss,orl= _� ;,.,-,N,vs. , �a'ctor� ,.s,.vs.. %s' A" u missions- �- -R U�ed Ann q , e�.--.,,.,p` ,- v17L7Avntw^+ TWI I J' t'� .:wt 4.- -= _uncontrolled ^t,-'1"::1:-`'.2; —,,, i T -, .ix u. Poll`ut"annt ',= r„ tixy 4 ` -�- � � '" Emission ~ a-" '�*= �F- � r ;i a , Factor, Omts ,' fry' -=��. «" `-ev Source �- -(AE 2 � s--�� ]Nfgretcj e. l7ncantroil d,' � "t" �, GTons/'year)` _ Controlfe"dam �^ only ear Y(I' _ Y )-: Inconfrolled '4Control(ed � ons ear ( Y ) �(%nsl��enrj," PM _ - SO. NO. - CO CO - - VOC 31 04 Ib/MMSCF GRI-GLYCaic 113 31 ' 5 7 Benzene 2 99 lb/MMSCF GRI-GLYCaic 10 91 0 55 ' Toluene - 3 35 lb/MMSCF GRI-GLYCaic /12 21 ' 0 61 Ethylbenzene - - 0 83 Ib/MMSCF GRI-GLYCaic 3 01 -' 0 15 i Xylenes , - - 1 60 Ib/MMSCF GRI-GLYCaic 5 83 0 29 n -Hexane - 0 56 Ib/MMSCF GRi-GLYCaic - 2 05-0-10 / 224 ` Tnmethylpentane - - Other - Requested values will become permit limitations Requested limit(s) should consider future process growth - 5Annual emission fees will be based on actual controlled emissions reported If source has not yet started operating, leave blank Form APCD-202 -Glycol-Dehydration Unit APEN - Revision 02/2017 6I AY COLORADO Depasiscrnd Public 7Wtp� b EmmO,um,d A :1 Permit Number: AIRS ID Number: / [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. il—/e —17 Signature of L0ally Autho ed Person (not a vendor or consultant) Date Cory G. Jordan Name (please print) EVP Operations 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) Send this form along with $152.90 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 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7 I COLORADO D.punmmmm'veuc Iaal.fr mnewnrN 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. paint booths, mining operations, engines, etc.). A list of specialty APENs is available 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: AIRS ID Number: 12. /a F74 -I 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Lochbuie Compressor and Pump Station Site Location County: Site Location: Section 21, Ti N, R65W Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Portable Source N/A Home Base:. NAICS or SIC Code: Weld 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address': mnorton@discoverymidstream.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 APCD via e-mail tb the address provided. 3719$2 Form APCD-200 - General APEN - Revision 1/2017 COLORADO 1I M- «.W Nrlpi bMmnTuwl E Permit Number: AIRS ID Number: [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 0 PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment 0 Change company name ❑ Add point to existing permit ❑ Change permit limit 0 Transfer of ownership' 0 Other (describe below) -OR- ❑ APEN submittal for update only (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 :II Additional Info £t Notes: Process Flare 3 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: for TEG Dehydrator and Slop Tanks Process Flare to control VOC and HAPs Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): F-4101 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 01/01/2018 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 1/2017 COLORADO 21 Air - lWltivbEmOmnrM Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 4 - Processing/Manufacturing Information Ft Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? ocess ate Specify Units) Material Consumption: Finished Product(s 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Latitude 40.034981304/Longitude -104.672898823 ❑ 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. a r ®a �� es ei o a Flow Rate (ACFM) eloc-) 4°se e t TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack.diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 1/2017 AV COLORADO 3 I elm HIP 6 Envunmm�.0 TSP (PM) Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment a Fuel Consumption Information ❑ Check boxif this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Actual Annual Fuel Use (Specify Units) 8.80 From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas ❑✓ Field Natural Gas ❑ Ultra Low Sulfur Diesel ❑ Propane ❑ Coal Other (describe): Requested Annual Permit Limit f$pecify.Units) (assumed fuel heating value of 1,020 BTU/SCF) Heating value: 1 00. -'BTU/SCF (assumed fuel heating value of 138,000 BTU/gallon) (assumed fuel heating value of 2,300 BTU/SCF) BTU/lb Ash Content: Sulfur Content: Heating value: 51.52 MMscf - Heating value (give units):. - 9 Requested -values -will -become -permit -limitations, Requested limits) should consider future process growth. 5 -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): Overall Collection Efficiency Control Equipment Description PM..0 PM2s- SOX KO. CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 Overall Control Efficiency (% reduction in emissions) © COLORADO 4 1 Av, HuiN b Fiivbvnmera TSP (PM) Permit Number: AIRS lb Number: [Leave blank unless APCD has already assigned a permit .# and AIRS ID] Section .7 (continued) From what year is the following ;reported actual annual emissions data? 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) Emissi®n Factor Source, AP -42 Mf etc) uesfed Annual P mission :Liit ncontrolled .Tons/year), Controlled (Tons year-. PM10 PM2a Sox NOX 0.138 lb/MMBtu RG-109 5.32 5.32 CO 0.276 Ib/MMBtu RG-109 10.62 10.62 VOC Other: 4,Requestedvalues wall becomme_peernitlimitations. Requested limits should consider future process growth. 6 Annual emission 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) emissions equal to or greater than 250 lbs/year? ❑ Yes ✓E No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS utnber$' hemica€ .. atria ..� Overall Control fficiency Efficiency y a at lie a r�tssion Factor hUncontro d� ctu 1 Emissions lbs/year) C-ontrolled c ua E'ITTMS ns, ([bsiyear) �Sr. saq Source.- �- 4z, Mfq et 6 Annual emission fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General AP -EN -- Revision 1/2017 Permit Number: AIRS ID Number: [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. )(rip, //-16 -)7 g y the zed Person (not a vendor or consultant) Date Cory G. Jordan EVP Operations Signature of e alt Au 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 $152.9O to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 43O0 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - General APEN - Revision 1/2017 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: / /www.colorado:gov/cdphe/aped COLORADO 6 I •_ Hcil[h b EnNmeunoN Natural Gas Venting APEN- Form APCD-211 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. This APEN is to be used for Natural Gas Venting only. Natural 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. 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/aped. 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: Vi W E l L C1 GJ AIRS ID Number: 123 /qF74-/ 008 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: CB [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: Discovery DJ Services LLC Discovery Lochbuie Compressor and Pump Station Site Location Section 21, T1 N, R65W County: Weld Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 -E-Mail Address2: mnorton@discoverymidstream.com NAICS or SIC Code: 213112 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 '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 APCD via e-mail to the address provided. Form APCD-205 - Natural Gas Venting APEN = Rev 03/2017 1 I ®V Daparanagst el 'Mc COLORADO Heath unvmmam, 3719'33 Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS !DI 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 name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) - OR ▪ APEN submittal for update only (Please 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 a Notes: 3 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: Compressor Blowdown (total for 4 compressors) For existing sources, operation began on: 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: 01 / 01 / 2018 Normal Hours of Source Operation: 24 hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 7 days/week E Yes ❑ Yes 52 weeks/year ❑ No ❑✓ No COLORADO 2I AVd ,yM6En�hM'MN Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ▪ Blowdown Events # of Events/year: 24 per compressor 'Volume per event: 0.0042 per unit' MMscf/event ❑ Other Description: Serial #: # of Pistons: Leak Rate: If you are requesting uncontrolled VOC emissions greater than 100 tpy for Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Natural Gas Venting Process Pararrieters4: Liquid Throughput Process Parameters4: ❑ Yes ❑ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: 0.4032 - MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) 33.57 Benzene (mole %) Benzene (Weight %) 0.09 Toluene (mole %) Toluene (Weight%) 0.16 Ethylbenzene (mole %) Ethylbenzene (Weight%) 0.04, Xylene (mole %) Xylene (Weight %) 0.08 n -Hexane (mole %) n -Hexane (Weight %) 1:30 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) 0.001 Additional Required Information: Attach a representative gas analysis (including BTEX it n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 :1 COLORADO lieFartemrt of P.& Pmt bF mneH Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Latitude 40.035621125/Longitude -104.672512481, Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp ( F) Flow -Rate ; (ACFM) e of 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): ❑ Other (describe): ❑ Upward with obstructing raincap Sec#ion-6---Control--Device4nfoFinati on ❑ VRU: Pollutants Controlled: Size: Requested Control Efficiency VRU Downtime or Bypassed Make/Model: ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested,Control Efficiency: ManufacturerGuaranteed'Control Efficiency Minimum Temperature: MMBtu / hr Make/Model: Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 4I COLORADO NirlieYiT6 .a.....-^' Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit it and AIRS ID] 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 ✓O No the overall control efficiency (% reduction): IL AND It yes, please describe the control equipmen .3‘....-a- � � -, Overall Reque "Qcty 16 trot. Control E ui men Des i tion - Efficie c Pollutant q P P (% reduction rn -amr sions PM SOx NOx VOC CO HAPs Other: From what year is the following reported actual annual emissions data? 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.) use a ka R Uncontrolled Emission Factor Emission Factor '.nits Emission Factor Source (AP -421:;11 Mf3•. etc)., Actual Annual EmissionsEmission Requested Annual Permit Limit(s)5 01 Ai aii, I n co ntro t led - (Tons/year) Controlled6 3 (Tons/year,)=, , Uncontrolled : (Tons/year) Controlled (Tons/year) PM SO. NOx VOC 90.41 • lb/event Engineering Est 4.34 '- 4.34 CO Benzene 0.25 lb/event Engineering Est. 0.0118 0.0118 Toluene 0.42 lb/event Engineering Est. 0.0201 0.0201 • Ethylbenzene 0.10 lb/event Engineering Est 0:0048 0.0048 Xylenes 0.23 lb/event Engineering Est. 0.011 0.011 n -Hexane 3.50 lb/event Engineering Est. 0.1682 ' 0.1682 2,2,4- Trimethylpentane 0.0028 lb/event Engineering Est. 0.0001 0.0001 Other: 5 -Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If;source has not yet started operating, leave blank. Form APCD-205 -Natural Gas Venting-APEN - Rev 03/2017 5 •Ap cotoenoo iO�a AIRS ID Number: Permit Number: [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 tgaily Author' -d Person (not a vendor or consultant) Date Cory G. Jordan EVP Operations Title Name (please print) Check the appropriate box to request a copy of the: 0 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) Send this form along with $152.90 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 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-205 -Natural Gas Venting APEN - Rev 03/2017 COLORADO 6 I m �� prMbEIWOMMEM 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. 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 but incorrectly or is missing information and requires re -submittal. This APEN is to be used for fugitive component leak emissions. If your emission source does not fall into this category, there may be a different;specialty APEN available for your operation (e.g. natural gas venting, condensate tanks, paint booths, 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 specialty APENs is available on the Air Pollution Control Division (APCD) website at www.colorado.Qov/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: -1V\IEllgS AIRS ID Number: i 2, 3 /6 F7 4-/ O H_ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 Administrative Information Company Name: Site Name: Discovery DJ Services LLC Discovery Lochbuie Compressor and Pump Station Site Location: Section 21, TIN, R65W Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Permit Contact: Matthew Norton E -Mail Address2: mnorton@discoverymidstream.com Site Location Weld County: NAICS or SIC Code: 493190 Phone Number: (817) 455-5799 a 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 APCD via e-mail to the address provided. 37198--'7 Form APCD-203 - Fugitive Component Leak Emissions 4.4 - Revision 5/2017 COLORADO DepanzemsePubl. Ham taftranteant Permit Number: AIRS ID Number: [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 name ❑ Add point to existing permit ❑ Change permit limit E Transfer of ownership3 0 Other (describe below) -OR O APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 ror transfer of ownership, a completed Transfer of Ownershtp`"Certificatibn Form (Foam APCD-104) must be submitted. Section 3 - General Information For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: January 201 9 ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: hours/day days/week weeks/year Normal Hours of Source Operation: Facility Type: ❑ Well Production Facility4 ❑✓ Natural Gas Compressor Station4 ❑ Natural Gas Processing Plant4 ❑✓ Other (describe): Compressor Station and Oil Storage Facility 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5)'2017 ATCOLORADO 2 I Ileprtworrt Rt. Permit Number AIRS ID Number / / [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? TBD Will this equipment be operated in any NAAQS nonattainment area?5 E Yes ❑ No Will this equipment be located at a stationary source that is considered a ❑ Yes No Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors ❑ Yes ❑ No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑ Yes ❑✓ No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑ Yes I No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa7 ❑ Yes - - ✓❑ No Iscthis equipment subject to 40 CFR Part 63, Subpart HH? ❑ Yes ✓❑ No Is this equipment subject to Colorado Regulation No 7, Section XIl G? ❑ Yes 0 No Is this equipment subject to Colorado Regulation No 7, Section XVII P ❑ Yes ❑✓ No Is this equipment subject to Colorado Regulation No 7, Section XVII B 3? ❑ Yes ❑� No 5 See http //www colorado gov/cdphe/state-implementation plans -sips for which areas are designated as attainment/non attainment 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 7..':`,4F,-.,'.4-. .7-- — ,s _,11 Strearr� r� =� � , �.� e� r?�'�� r „ .5 - _ '7--=--7-=1—z-,,,--r, zVCt,- 7 A 4fer,a Y � =r � ,. , - x __y,,,, = Benze, a Ti do , �t�� .� .* t E�-3�a ; .. =3t-1� TolueneL� -q �Ue s�4 e4s\Wt✓,J,-^1� ��r-a�+xs�*;,, � _ _,may,. Ethyibenzenen .1-Eth �A,.._; r1,p�-„o Wt °%) "�^,r Y I ---":"-�,a �,�',r �,� i — m ---,,_ 'X' le_n_e` :, .alwt�� t . ,-ii.-1 ".-,,.'-- a1 n;Hezanew,�= :ti y o ,4. �Wt�)Tz z? s �-,..,Z-:',.t ''':„--..„2,2;4.-,14:1-6,,,-.2„ Tnmetliylpentanes - ,- ,. �,.aari -i ��.-�« (W�tr%) �� ,,� Gas 0 ' 0 0 0 0 0 0 Heavy Oil (or Heavy Liquid) 0 0 0 0 0 0 r 0 Light Oil (or Light Liquid) 99 92 0.38 0.96 0.43 0.43 2.60 0.75 Water/Oil 0 0 0 - 0 0 0 0 Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 * (COLORADO 3 I,ar Foosv Kean6timnrancree Permit Number AIRS ID Number / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Geographical Information S-''��i'�='. .G eographxal,Coordii�ates 1(Laht de/Longrtude� of UT Latitude 40 035374/Longitude -104 671802 Attach a topographic site map showing location 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 0000/0000a / J ❑ Monthly Monitoring - Control 96% gas valve, 95% light liquid valve, 86% light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No 7, Section XVII F ❑� Other6 The owner or operator will perform monthly AVO inspections ❑ No LDAR Program 6 Attach other supplemental plan to APEN form if needed Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision A® 'COLORADO neprm®e& Public ira. bonremmsN 5/2017 4 I Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit I/ 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 O 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 F - ei Estimated Component Count , ❑ Actual Component Count conducted on the following date _ F ."7514.74;-.77:1-� r xj `'�t„'K'vy. iYbjd _ r'.:4''''''''017;';';'''''- �„t 1'CY.r_, ''5L. 'R T ,y 'sue- 'rp' r 'FY-`,, ir„-'`g k ;s ., -. ., ter '' t -e fa,r4: 4^�,r�Ss"s� At e=` e+�,Tr,1Yr,}m1> ,.WL .„-I ,.�5Y` _,,d, _,�.., J ��P +vcG �L M�YSt_ .„ m.---'rr-r,„.1F —E y ' ..>a -". -'' _ .`' + ?'a `ayv^'''.-4.1.1".3.x.'-''''' S�Seryuesi --e '' ,s �'a a r *4a' r s bv"� si" i<t"3,N rr C nnectors0 �^ 3;` »A{ r; ` t" Flan es , t v .i� "$^��, `•aT _' 6q arm p"if-6 4� 91 �'t1r1e5='A ea.�. 'in =sz'� 'Pump Seals :rar t� �¢'' ' "'"a'-�.:-4t ' ,,. t r" , Ualves -a �' »` n •R"se ,. -r _ _ ;' z�` then y f ;'=,V+ 4 x3a s�s,.'.5� .. 'e,`� . a es +c. <-z.s- --r may,,, .. Gz�"h' "'�4 2 ,r 4"�_ i0, `^z"^ �as .'-,;1,-,,i io. ,,�.Y. S -h { . Y lPI -, sCirK'Y+vEA.- _-_,..— �i. R.. T ( - 75 r 1- _ ---1,/:::-....1$-- `� ,-,.moss Cr} i. K'a"tY r .:, --- ft4+" '-v ,asc..„) -, , 0--',- * """. .�3 u, V '12.1+ l F s 3f 3 ,r- {" Y � i 5 °1 {a a{ Q+'i l{ i'c .�-y�wil'� iv-' �, a�" i.�y, ecM:4,739. wr 67 �F CountB ,' - Emission Factor Units -f Z=.'L ay.!Vyrst�y :�yfY ...__ .,.Ma. + -ter pax fi f 'J 1' y�?��xs. Y3 u."=? T'Ci^k5W-t -` t,"• Y „''-.z r'�„q�a S�',!. _piy. He, �� 6S3 C. 111Ox, Hea'vy� gld�t s - _ ap • 4 „ Lfr y k Counts Emission Factor , Units __ r. .t..': -.=+s n.ri - ti'"-'�"� 1i,htoil'(or Lightl'Tuui—d �t.3.�} -,47-,...--,t J?s..t�"}.'i^-'Pv-�..�-1 : ,: rZ' -- wYz x+ �'�..,�,�rn� -,, -2 a`-E5.gy " ^� F�="Jv-T�.t4 x a }?:. �,-Zge ;a"a�-n �` , �lF '- -',`Yi-,, t°;x.� �- — -� T -;-"-r e.. -. ...- k -_ -,,,,,T-,_----- .e �f=�-r#�+n �a'� '�''a ," Y.F h' -., r , ...x,,.. Count8 10 100 0 3 50 9 ' Emission Factor - Units' A recr{� +�"i' � `..,. rte_ 8'*' aU "^ Nester/Oil , f_ d.r,. .-"r.-", , 5.�-' ",,i^z-,.fit s �-e� _. v "' 'wV2fgt+-":;;;-_,V4-1-4---i Y'; .,. �... '� i r` �3+=+�`' '?° r.. "-.'.'S. a6�'-^ c^3�. 9r- �?' Y4;E•.�� Tl'�i -...r.--Le 'Vt4'�--,„y.� Hk �'�ji J �4�Z -1:rR '�3�w c y 2 w s} -µy 4 Y =SL _—' -^.l\M '4'.1. !' F z v� - CountB - Emission Factor ' , , Units 7 Table 2-4 and Table 2-8 are found in U S EPA's 1995 Protocol far Equipment Leak Emission Estimates (Document`EPA-453/R= 95017) , 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 tines, pump seals, or valves _ ` ' ` Form AP,CD-203 - Fugitive Component Leak Emissions APEN - Revision .5 1 A® (COLORADO Deparbom" a[ PoLYc i Nmt111b 6,euommvu 5 Permit Number AIRS ID Number / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Criteria and, Non -Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form From what year is the following reported actual annual -emissions data? 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 Attu LAn ualuEmision° ncontraYled ° _ ont olled� °,P �ltons/srear);' < Yx'c� (tonslyear)' - ia pollutants s (e g emissions hazardous air pollutant) emissions source have any actual emissions of iequall tolor greater 250 pollutants (e g lbs/year? Yes If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source No i° Annual emission fees will be based on actual controlled emissions reported If source has not yet started operating, leave ii Requested values will become permit limitations Requested limit(s) should consider future process growth, component count vanability, and gas composition vanability Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 6 ®® I GOLORA.DO =7..= 5/2017 fi li Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ti 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. )41- - /4 - -7 Signature of Lega Authorized rson (not a vendor or consultant) Date Cory G. Jordan Name (print) EVP Operations Title Check the appropriate box to request a copy of the: 0 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 $152.90 to: For more information or assistance call: 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 Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 5/2017 71 AV COLORADO ueonenenudty AA mama. emsMven Condensate Storage Tank(s) APEN Form APCD-205 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. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is availableif the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. 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: AIRS ID Number: I23 /61 lfi 012 [Leave blank unless APCD has already assigned a permit # and AIRS ID] cv Section 1 - Administrative Information Company Name1: Site Name: Discovery Lochbuie Compressor and Pump Station Site Location: Section 21, Ti N, R65W Discovery DJ Services Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Site Location County: Weld NAICS or SIC Code: 943190 Permit Contact: Phone Number: E -Mail Address2: Matthew Norton (817) 455-5799 mnorton@discoverymidstream.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 APCD via e-mail tathe address provided. x'71984 M. COLORADO Form APCD-.205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1 I AV ,°"`^ li Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action E NEW permit OR newly -reported emission source E Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ 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 & Notes: 3 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: For existing sources, operation began on: 50,000 BBL Storage Tank For new or reconstructed sources, the projected start-up date is: January 2019 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: ❑ Exploration Et Production (EftP) site weeks/year E Midstream or Downstream (non Ei3P) site Will this equipment be operated in any NAAQS nonattainment area? • Yes • No Are Flash Emissions anticipated from these storage tanks? • Yes • No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? Yes No • ■ If "yes", identify the stock tank gas -to -oil ratio: 0.4666 scf/bbl m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)CI 805 series rules? If so, submit Form APCD-105. Yes No ■ Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No O ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 ,COLORADO 2 I R uyvmae.aaRAW Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information - ��cfu a (sA%�n ua��Am o u nth Condensate 7hcoughput , From what year is the actual annual amount? Average API gravity of sales oil 46 2 degrees - Tank design 0 Fixed roof SStorage'3 L Thnk 1D . T1 ;# of_L1quid:ManifoldyStozagem V� ess�n torag ,T,anki 1 t YRequesled_AnnualtPe - riit�.L'`lmiiff l M r (bRUyear,) 0 Internal floating roof 7-06--fiviqh<oft. ��3 Storage�T�nk,� 50,000 18,250,000 RVP of sales oil 7 0 E External floating roof '� lristall`ation D,ate�ofMos"t �� RecentStorageeVesselfin; 1.StorageTank"(monthlyeac Y N/A - - Da'te ofFarst� f iwProduction.c-eT (morath/ye prw� N/A OWA-Ralia-,eriTacl tT 7w•�-��aJ'�r,TkTjv^�t't ''�'k or Tank=Batte ,' E&R-Sites �eTan �. rY ( zt- risl Reported_ Well ❑ O O 4 Requested values will become permit limitations Requested limit(s) should consider future growth 5 The EEtP Storage Tank APEN Addendum (Form APCD 212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form Section 5 - Stack Information Latitude 40 035374/Longitude -104 671802 �Operator'Stac'k °7IDddo_ N/A 7Di"scliatge eigfitAbave; round..Level (feetk ' 5,79;eR�p fir" Flow Rate's Indicate the direction -5f the stack outlet (check one) O Upward ❑ Honzontal O Downward O Other (descnbe) - O Upward with obstructing raincap - Indicate the stack opening and size (check one)_ ❑ Circular Intenor stack diameter (inches) - , O Square/rectangle Intenor stack width (inches) - ' Intenor stack depth (inches) ❑ Other (descnbe) Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 '=" 3 AV lORAD0 NeJll,b [mbanMN Permit Number: AIRS 1D Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] 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. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % 77 Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: Btu/scf MMBtu/hr ❑ Closed Loop System Desction of the closed loop system: ID Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 -Gas/Liquids Separation Technology Information (E£tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: Form APCD-205 Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO 4 I �� °.`�".�` -Malb FrnbasM fi Permit Number AIRS ID Number [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6 If multiple emission control methods were identified in Section 6, the following table can be used to state the overall a �ry v- w x`,,<r, "• `"- _ " ' y-Kn Pollu ant- ; f -- i ^ Y-,-wwr {r ,_..� m e,5,� " ° 1�+F` • •: v y:,.'��y�,'t�'^ t` 5.2 y `- , s < , .,,.� i-- `M " r7 a, z s {.r° - fir- a mart,, < ; Description`ofControl,Method�s) � - - 4.� _ _ -4�-.` -x "-� �xx,,z =_ �, s_ `�t--.4_y { s : ,�; ti ."" % t yOveFall Requestedleonti-6l :; i -,, , �r7 '.[..` , r -, , ,. ^ .(.y Y '-(%reduction In-emisslo`ns --t< VOC NOx - CO HAPs Other -, From what year is the following reported actual annual emissions data? ..rcF.�. <'�sr _--s`-.G. r-C-_'Yc=3'L''." ' ` �C:. �x �'a +' scr =�.L≥4 •` =-C1�r<t r'�._ ta-....•� `'` .i-�.e'",`•. c41 -'19-.F'... '-. t-` �'4 : ,sF ti,' r,5 :" n� �_ ;,-S.,<r.`:`sy i �,� �'rs s i;Cntena�Pollutant,Emissions'Inventory,--i,.:4--, �s -I`t 3..,f'. F^ Z=- •2 ! +-j; µ ''�'> >�'^ " � r ''= Pollutanr" _ � --,,Y_-�,,,. is r - tom sky cx ' � - �a. ,.-,r,.. - -,--T----,71-' x�`"' � �—i5'— . µnya ' „77-'0" .�C. �-V•�°`,.�-��;��a�r.� ��ti,,�� r 't- 't' EmissionwFactorb° � ' _ �. --.4'''"- �- ;r,'Z''-� `':.' ' y�57S44,';'.5.& _42,- stiyr�y Kiss. t F ^"` r ��S µ.iii..., 4„: 4 9^. " �;-, r��t=rk��a.; -,4«.r ,--Actual Annual Emissions= - ; X%`--: ^y -"L'''.-4'-' - i 7^ '4i —1 t, '"$-"4,g r �4 �' * 4,4 tf :. � i" i fi::g egues�ed�Annual�Permit� y i, s: ---w r vv,—,—, °,-,,),F., r .; .4Emisslon,Limit(s)4,'y ---."."--r9,--',-.' ; _, .-r .r -Uncontrolled) r -„,. T -. '''''''"7-'479-V-,-•-1"-• �� a r r `vh=''z-'.' ,�-_ ... -y y�Y --- ;< *• - - ZJnits s = Nr ',,;^ ; e„Source ,_ - 1L442 - .- r,_ M{e -etc).,,, .-�L X.,-': 'U'ncontrolledY�. „-, — .,;:.._ _ y Emissi ' --- ' ,: BUR ,, � �<y_-, <,--(Tons/year)x n.. ,.� • —_ b 3n --N,Controlledf,yy Emissions - .- , �k; ; onsl ear �u � (r Y '"�' _s;-;;_,..� k r Uncontrolled,: "r_,,,,„ .,�., os� s }. Emission`s = ts - _ onsjyearj z- ='(T �, ,_ , at:rW4 -`Controlled= .t.,v.;, x' = -�_ s��; Emissions � year s fans]year) 1 VOC 0 0011' Ib/BBL EPA Tanks 10 437 - 10 437 NOx ,CO — y r —F •--„-•--rs e_ __y r-•.,_ s-•' �• •,r ,= .s„-- - _� _ _ .F-'� . ��•t.rts a :r „"'- = 9 4 Requested values will become permit limitations Requested limit(s) should consider -future growth 6 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03 7 Annual emissions fees will be based on actual controlled emissions reported If source has not yet started operating, leave blank c Form APCD 205 - Condensate Storage Tanks) APEN - Revision 07/2017 ®®iCOLO RADO 5j b Ennrmumu Signature of gally Authorized Person (not a vendor or consultant) Cory G. Jordan Permit Number: AIRS ID Number: [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. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compere with each condition of the applicable General Permit. //'1-17 Date EVP Operations Name (print) Title Check the appropriate box to request a copy of the: ❑ 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 $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, 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 Telephone: (303) 692-3150 Small Business Assistance Program _ (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 61 Aar NSMbEnoauwN COLORADO Site Location: Section 21, Ti N, R65W Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 7520 I Portable Source N/A Home Base: CDPHE j�, ‘ v, rol 6 General APEN - Form APCD-200°� i 1J� 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. paint booths, mining operations, engines, etc.). A list of specialty APENs is available 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: lvvuttg5 AIRS ID Number: 123 /gF74--/ 013 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Discovery DJ Services LLC Site Name: Discovery Lochbuie Compressor and Pump Station Site Location Weld County: NAICS or SIC Code: 493190 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton@discoverymidstream.com i Use the full, legal company name regttred with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD.-*!changes anges will require additional paperwork. '.. - 2 Permits, exemption letters, and any prgrssing invoices will be issued by APCD via e-mail to the address provided. is, 371985 Form APCD-200 —General APEN - Revision 1/2017 Haden Fr EnvIrerunen1 ' IT COLORADO 1 I Li Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action 0 NEW permit OR newly -reported emission source (check one below) 0 STATIONARY source - ❑ PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (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 It Notes: 3 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: Tank Landing MSS Activity Manufacturer: N/A Model No.: N/A Serial No.: N/A Company equipment Identification No. (optional): TL For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Jan 2019 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 Seasonal use percentage: Dec -Feb: Mar -May: days/week 52 weeks/year Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 COLORADO 2 I AY :"` a 6 .�.M Permit Number: AIRS ID Number: [Leave blank unless APCD'has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use E 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 Limit4 (Specify Units) 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 —Stack Information Geographical Coordinate (Latitude/Longitude or UTM Latitude 40.035374/Longitude -104.671802 E 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. ,c,.J{ iii14. �,y�;C ,r* fi 5 , t �rv:.�tvl G. ''"'1 S +., Indicate the direction of the stack outlet: (check one) ❑ Upward. E Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular • Square/rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing.raincap Interior stack width (inches): Interior stack depth (inches): .Form APCD-200 - General APEN - Revision 1/2017 .COLORADO eorAstie • Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a";pennit # 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) Requested Annual Permit Limit (Specify Units) 2_ ruo ic,41R^ From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ 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) Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Coal ' ❑ Other (describe): Heating value (give units): TSP (PM) RequestedValues ues Wili-become-permit tfmitationsw.Requestedlirnit ) should consider future process growth. 5 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): Overall Control Efficiency (% reduction in emissions) Control Equipment Description PM10 PM2.5 SOX NOX CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 Overall Collection Efficiency O'LORADO 4jo( P,` iii®H�b➢w nte�el Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? 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) ' . actual Annual Emissions Req seed Annual Permit Emission Limit(s), Uncontrolled (Tons/year) Co-nrolled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tonslyear) TSP (PM) PM, PM2.s SOS NO„ CO VOC 1,425.1 lb/event-'AP-42 Chapter 7 1.43 - 1.43 , other:. 4 Re quested-va'luernniit-become permit-limitationrRequested-limit(s)-shovld-consider future process growth. 6 Annual emission fee 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) emissions 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) Uincontrolled Actual Emissions (lbsryear) Controlled ) Actual 6 Emissions (lbs/year) 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 AlprCOLORADO Permit Number: AIRS ID Number: [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. 4. // -1-2_ Signature of Le ty Authorize erson (not a vendor or consultant) Date Cory G. Jordan EVP Operations 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 $152.90 to: For more information or assistance call: 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 Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 1/2017 AV COLORADO 6;I mV °.°`" 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. paint booths, mining operations, engines, etc.). A list of specialty APENs is available 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, ILL. for revised APEN requirements. Permit Number: AIRS ID Number: 123 /1F71-/ 014 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section. Admirustr.atime Information Company Name': Discovery DJ Services LLC Site Name: Discovery Lochbuie Compressor and Pump Station Site Location Weld County: Site Location: Section 21, Ti N, R65W Mailing Address: (Include Zip Code) 7859 Walnut Hill Lane, Suite 335 Dallas, TX 75230 Portable Source N/A Home Base: E NAICS or SIC Code: 493190 Permit Contact: Matthew Norton Phone Number: (817) 455-5799 E -Mail Address2: mnorton®discoverymidstream.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 invices will be issued by APCD via e-mail to the address provided. 371986 Form APCD-200 - General APEN - Revision 1/2017 plow COLORADO NWM 6 Ea�lmurra� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action 2 NEW permit OR newly -reported emission source (check one below) O STATIONARY source ❑ PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR- - ❑ APEN submittal for update only (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 £t Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-1D4) must be submitted. Section 3 - General Information General description of equipment and purpose: Pipeline Pigging MSS Activities Manufacturer: N/A Model No.: N/A Serial No.: N/A Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Jan 2019 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 Seasonal use percentage: Dec -Feb: Mar -May: days/week 52 weeks/year Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 2 Q1® 'COLORADO Hag. Er DM `Material Consumption: Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit ft 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? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested`Annuai Permit Limit4 (Specify Units) 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information 40.035948 N/-104.671823 W .0 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. pera tackID �DIse arse e" Above Ground Le e _ _ 3 o a e. ,� oci •(ft'sec Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): interior stack depth (inches): ❑ Other (describe): Form APCD-200 - General APEN - Revision 1/2017 •ife, 3 _) L7_ .nom ^ al Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment It Fuel Consumption Information 0 Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) s I . ut t � Actual Annual Fuel Uses {Specify Units) q Re uested Annual Permit Limit (Specify Units) z� +� / it From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTUISCF) ❑ 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 2,3O0 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): c, is rr )7-1611 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than thelisted 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 ftcenc ( ed ction in emissro TSP (PM) P'M10 PM2.5 SOX NOx CO VOC Other: Form AP:CD-200 - General APB - Revision 1/2017 COLORADO4 .I . " bn, Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutantemissions from source: e the data reported in Sections 4 and 6 to calculate these emissions. Pollutant Uncontrolled Emission Factor (Specify Units) Emtsst®n Factor Source Mfg. etc) etc) .dual Annual nnual Emissions` .g :. Re nested Annual Per mi `� 4 Emission Lt""mitts) Uncontrolled (Ton -, year) Controlled° ("tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM" PMzs SOX NOx CO VOC 18.55 lb/event - Engineering Estimate 1.11 ' 1.11 Other: 4 Regnested-values-wil{ becorne-permit-limitations=-Regwested-liimit(s) should -consider future -process -growth: 6 Annual emission 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) emissions equal to or greater than 250 lbs/year? ❑ Yes ✓❑ No se the following table to report the non -criteria pollutant (HAP) emissions from source: ®� g� �s - Overall Control - Efficiency_ _ y Uncontrolled Emission Factor (specify units) t Emission Factot�, Source OP. -42, Mfg. etc) ,:)--4-_,;)., _ Uncontrolled �{ - ctual ) tssions• rtOear) Controlled Actual ° Emissions (lbs/year) { 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 OLORADO 5 � CC `., Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit II 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. 4/I -/6-i7 Signature of L llyAutho ed Person (not a vendor or consultant) Date Cory G. Jordan EVP Operations Name (print) Title Check the appropriate box to request a copy of the: • Draft permit prior to issuance O 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 $152.90 to: For more information or assistance call: 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 Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-200 - General APEN - Revision 1/2017 6 I A® COLORADO EiepnmmeK rub& fah 6 EAlmttasat Hello