The URL can be used to link to this page

Browse Search

Home My WebLink About20182157.tiffCOLORADO Department of Public Health ft Environment 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 July 2, 2018 Dear Sir or Madam: RECEIVED JUL 0 9 2018 WELD COUNTY COMMISSIONERS On July 3, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Elevation Midstream LLC - Badger Central Gathering Facility. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer 0 7-i6-18 CC*. pLLMM ITP), t{L.LTT', Pw C cR//Jev./CK) O 7- 2018-2157 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Elevation Midstream LLC - Badger Central Gathering Facility - Weld County Notice Period Begins: July 3, 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: Elevation Midstream LLC Facility: Badger Central Gathering Facility Oil Et Gas Wellsite SEC 31 T5N R66W Weld County The proposed project or activity is as follows: Oil Et Gas separation and liquid storage 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 Permits 18WE0028 and 18WE0031 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.cotorado.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 43O0 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us OR Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: ChristopherKester,'- 372957 4/15/2019 9/2019 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: Natural Gas Compressor Station What industry segment? Ctii & Natural Gas Production & Processing Is this facility located in a NAAQS non attainment area? Yes If yes, for what pollutant? ❑ Carbon Monoxide (CO) Elevation Midstream EFS6 Buffalo Compressor St Section 31, Township SN, Range 56W Weld County Section 02 - Emissions Units In Permit Application ❑ Particulate Matter (PM) Quadrant Section Township Range 5N 65 EOzone (NON 5 VOC) AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 Dehydrator D-1 - - Yes 18WE0031 3 Yes Permit Initial Issuance 004 Dehydrator D-2 Yes 18WE0031 1 Yes Permit Initial -r fssuance 002 Separator Venting SC -1 Yes 18WE0031 1 Yes Permit Initial 'Issuance Pressurized Surge Vessel Section 03 - Description of Project Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? ,Requesting Synthetic Minor Permit Section 05 - Ambient Air Impact Analysis Requirement: Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Yea Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (P50) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? 502 NOx CO VOC PM2.5 PM10 TSP HAPs ❑ ❑ Colorado Air Permitting Project If yes, explain what programs and which pollutants here SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) NOx Co VOC PM2.5 PM10 TSP HAPs ❑ ❑ Glycol Dehydrator Emissions Inventory 001 Dehydrator (Facility AIRS ID: Plant Section 02- Equipment Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Recirculation Pump information Number of Pumps Pump Type Make: Model: Design/Max Recirculation Rate: Dehydrator Equipment Flash Tank Rehaller Burner Stopping Gas Dehydrator Equipment Description Emission Control Device Description: MMscf/day , flash tank, and reboiler burner Stripping gas is injected into the reboiler. One ill Triethylene giycol;TED)nature( dos dehydration unit Intake:YID, PutuduI:TIP, Serial Number:FBI) with a design capacity of ISO MMscf par day, This emissions unit is equipped with 1(Mode: ":6D, Model: TBD) electric driven glycni pump with a design capacity of 30 gallons per minute. This dehydration unit is equipped with a stilt vent, flash tank. and reboiler burner. Stripping gas is injected into the reboiler, Emisslans from the stili vent are routed to an air-cooled condenser, and then to the Enclosed Flare. AS a sccrmd=m y control device, tilt vent emizstnrss are routed 4.6 r to Emissions from the flesh tank are routed directly to Ma Eneiusad Flare. Section 03: Processing Rate Information for Emissions Estimates Primary Emissions - Dehydrator Still Vent and Flash Tank (If present) 'Requested Permit Limit Throughput Potential to Emit (PTE) Throughput a 5s.:%00 MMscf per year 6 MMscf per year Requested Monthly Throughput a 5500 MMscf per month 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 Waste Gas Vent Rate: Flash tank Control Primary control device: Primary control device operation: Secondary control device: Secondan/ control device operation: Flash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: Section 04 -Emissions Factors & Methodologies Dehydrator Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate equestedCondenser Outlet Temperature: Mia.a'<. Control Efficiency % hr/yr Requested TO Temp .'4;:i1MOINNEcor,troi Efficiency % hr/yr Btu/scf scfh hr/yr Btu/scf seek SIC Control Efficiency % Control Efficiency % STILL VENT Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC •k9S.S57d 5.27837 105.5674 Benzene %'{g: f046 ' s 0.409205 59.]241 Toluene •: •D3.7135�'.:• 0.5g568 13.7156 Ethylbenzene '- 2,521d'. :' p.10007 2.5214 Xylenes : &1849 ^'.°•. ` 0.'09245 1.1510 n -Hexane ":" tells ;jl: s31 0.09155 1.6272 224-TMP ... „'0,0017"._- l.: 6.5E-05 0.0017 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC ': gli):46466gedie 2.46051 45.7662 Benzene 07985 �si'8' 0.00032'7 0,1485 Toluene ..C:Q92, ,�..., 0.00400 0.0916 Ethylbenzene ii`.0ue ( 0.0004,'.5 0.0085 Xylenes ` ,6S4 r'_= 0,00103.3 0.0219 n -Hexane ,,,,,aifmo,,. A -' : 0.02701 0.5532 224-TMP , [7.04§5�/9;:E; ''. 0.000015 0.0050 Dry Gas Throughout: Still Vent Primary Control: 65,700.0 MMscf/yr Still Vent Secondary Control 0.0 MMscf/yr Waste Gas Combusted: Still Vent Primary Control: /0.0 MMscf/yr Still Vent Secondary Control: 0.D MMscf/yr Dry Gas Throughpnt: Flash Tank Primary Control: 65,700.0 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr Waste Gas Combusted: Flash Tank Primary Control: 55.3 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr 5,580.0 L1 Glycol Dehydrator Emissions Inventory Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer (°6): i% Criteria Pollutants Potential to Emit Uncontrolled (tens/year( Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOC NOx CO VOC 0.0 0.0 0.9 0.0 0.0 0 0,0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 3.0 0 1.0 1.6 1.6 1.55 1.55 204 7.1 7.1 7.08 7.00 7,03 1202 600.4 020.4 94.0 080.4 54.02 577E Hazardous Air Pollutants Potential to Emit Uncontrolled ((bs/yeer) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) tpy 10.02 09,47 9.93 30.40 10,49 0.00 Benzene Toluene Ethylbenzene Rylene n -Hexane 224 TMP 175046 170048 9767 470040 0700 124583 129944 6047 120434 6047 10085 10450 933 10459 935 71392 71092 5595 70892 3595 212002. 20832 3.043 20007 1040 19 10 1 14 1 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section 0011.0,0 Regulation 7, Section XVII.B.2.e Regulation 7, Section 011.9 Regulation 8, Part E, MACT Subpart HH (Area) Regulation 8, Part E, MACT Subpart HH (Major) Regulation 8, Part E, MACT Subpart HHH (See regulatory applicability worksheet for detailed analysis) tpy 5..36 3.02 0.47 1,£0 a.;2. 9.00 Source requlres a nemdt Dehydrator is subject to Regulation 7, Section nth 0, 0.3 The control device for this dehydrator is not subject to Regulation 7, Section 009,B.2.0 Pehyd00190 is Leery is subject to area source MALT NN, You have indicated that this facility [s not aubject to Maier Source requirements of MACT HH. Y90 have indicated that this f 7, Snotio 63.764(4(12) ject to?stACT }014. Glycol Dehydrator Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample used in the GlyLaic model/Process model site -specific and collected within a year of application submittal? If no, the permit will contain en "Initial Compliance" testing requirement to demonstrate compliance with emission limits Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, yes, the permit will contain end initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling If the company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it? If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer No 1 Is the company using a thermal oxidizer AND requesting amnimum combustion chamber temperature lower than 1,400 degrees F? If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer. Section 09 - Inventory SCC Coding end Emissions Factors AIRS Point R 001 Process R 01 5CC Code Uncontrolled Pollutant Emissions Factor Control % Units PM10 0.000 0.0 b/MMscf PM2.5 0.000 0.0 b/MMscf so. 0.000 0.0 b/MMscf NOx 0.047 0.0 b/MMscf VOC 20.7 95.0 b/MMscf CO 0.215 0.0 b/MMscf Benzene 2.664 95.0 b/MMscf Toluene 1.841 95.0 b/MMscf Ethylbenzene 0.284 95.0 b/MMscf XYlene 1.094 95.0 b/MMscf n -Hexane 0.317 95.0 b/MMscf 224 TMP 0.000 95.0 b/MMscf Glycol Dehydrator Emissions Inventory 001 Dehydrator 'Facility AIRS ID: 9Foo?J>_ Plant Point Section 02 - Equipment Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Recirculation Pump Information Number of Pumps Pump Type Make: Model: Design/Max Recirculation Rate: Dehydrator Equipment Flash Tank Reboiler Burner Stripping Gas Dehydrator Equipment Description Emission Control Device Description: MMscf/day gallons/minute , flash tank, and reboiler burner Stripping gas is injected into the reboiler. One (11 Tretiylene glyso3 (TEEG) natural yes dehydration unit (Make: TOD, Model: TOO, Serial Number: TBO3 with a design capacity of 130 Ili Msc: per day. This emissions u noq uiirped'with t {Make: TOO, Madei:100) electrco driven giycnl pump with a design capacity of 35 golions per minute. This dehydration unit in equipped with a stdl vent. flash tank, and reboiler burner. Stripping gas is injected into the reboiler. Emisslons front the still• vent ore routed to an al0coolnd condenser, and then to the Enclosed Hare. As a secondary control devic.e,.stili vent enccccMns are routed to the. Emissions from ,he Pest, tank are routed directlyto the Enclosed Rare. Section 03 - Processing Rate Information far Emissions Estimates Primary Emissions - Dehydrator Still Vent and Flash Tank (H present) 'Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = 65,700:0.: :I MMscf per year 65.700 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 Waste Gas Vent Rate: Flash tank Control Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Flash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: Section 04- Emissions Factors & Methodologies Dehydrator Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate Requested Monthly Throughput= ReTO Tp'"""1"1"""M"''.": 1: �•,. "' Contrequol Efflstedcienry Aem STILL VENT Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC x00 5074:'..'. 5.27837 105.5570 Benzene ,,,$3.784I,,'':''.� 0.969205 19.7045 Toluene '� ..1T/D3.Yi06 1'/l 0.F,dcog 13.7135 Ethylbenzene i(' 24204'x':•;ii,: 0.1000: 2.1214 Xylenes .oG6SBHH /' 0."05245 0.1550 n -Hexane t4272 '(. } O,ev156 1.0272 224 -IMP - 0,0017 ; iii 3.5£-05 0.0017 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC _ .........................___. -08J. 2.49031 49.7662 Benzene A.3985 •' 0.909925 0.1385 Toluene 4.0006' ,'shr 000453 00016 Ethylbenzene MONS*BSKOM 0.000425 9.0035 Xylenes ,0.0225 s? - 0.001035 0.0210 n -Hexane MilgOIMUiNge 0.02756 0.5532 224-TMP `M4.040S :'., 0,000025 0.0035 5530 MMscf per month Degrees F Dry Ges Throughput: Still Vent Primary Control: 05.709.D MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Waste Gas Combusted: Still Vent Primary Control: 10.5 MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Dry Gas Throughput: Flash Tank Frimary Control: 55,700,0 MMscf/yr Flash Tank Seondary Control: 0.0 MMscf/yr Waste Gas Corn busted: Flash Tank Primary Control: 15.0 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr 5,500.0 1.1 Glycol Dehydrator Emissions Inventory Emission Fa ylhenzene 14199 Pollutant Benzene Toluene xylene n -Hexane 224 TMP 942 Glycol Dehydrate Uncontrolled (Ih/MMscf) (Dry Gas Throughput) (Dry Gas Throughput) Controlled (Ib/MMscf) Emission Factor Source 0929 0.954012 91 Still Vent Primary Control Device Uncontrolled Uncontrolled (Ih/MMscf) Emission Factor Source (Waste Gas Combusted) Pollutant (Ib/MMBtu) (Waste Heat Com busted) PM10 PM2.5 SO NOx CO 00.120 442.90188 Pollutant Still Vent Secondary Control Device Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Uncontrolled (Ib/MMscf) Emission Factor Source (Waste Gas Combusted) PM10 PM2.5 So NOx CO 8.80 a _ Flash Tank P Uncontrolled mary Control Device Uncontrolled (Ib/MMscf) Emission Factor Source (Waste Gas Com busted) Pollutant (Ib/MMBtu) PM10 PM2.5 SO (Waste Heat Combusted) 0.0000 0009 CO .0 Flash Tank Secondary Control Device Uncontrolled Pollutant (Ib/MMBtu) (Waste Heat Combusted) NO Uncontrolled (Ib/MMscf) (Waste Gas Combusted) .8 Emission Factor Source Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer (Vt II Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tans/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tens/year) Requested Monthly Limits Controlled llbs/month) PM10 PM2.5 500 NOx CO VOC 0.0 0,0 DA 0.0 0.0 0 0.0 8,0 0.0 0.0 8.0 0 0.0 0.0 0.0 0.0 0.0 0 1.5 1.6 1.55 1.50 204 7.1 7.1 7,1 7,03 2.09 1202 684,4 000.4 34.0 588.4 04,0 5778 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Pe mit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) tin 01.92 "50.47 9.33 30,95 10.43 0.06 Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 105040 128048 0752 135018 8'752 120934 120034 6047 120954 6047 38558 10600 933 19658 903 710+92 71092 3595 71092 3590 31i852 20852 11149 20842 1043 19 19 3. 19 1 Section O6. Regulatory Summary Analysts Regulation 3, Parts A, Regulation 7, Section XVII.B,D Regulation 7, Section XVII.B.2.e Regulation 7, Section X11.0 Regulation 8, Part E, MACT Subpart HH (Area) Regulation 8, Part E, MACT Subpart HH (Major) Regulation 8, Part E, MACT Subpart HHH (Sae regulatory applicability worksheet for detailed analysts) 199 4..38 3.02 0.40 1.00 0212 4.94 Source requires a 8001111 Dehydrator is subject to 009010tion 7, Section Mi. 0, 8.3 The control device for :has dehydrator 10 not subject to Regulation 7, Section 0011,0.2.? Dehydrator is zableat to Regulation?, Section XU.H Deily is subject to area source MALT RH, per the requirements in 63.264(di(2) You have indicated that this taclliry iv not subject to Maler Source requirements of MACT HR. 0811 have indicated that this ;agility le not subject to MACT HHH. Glycol Dehydrator Emissions Inventory Section 07- Initial and Periodic Sampling 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? If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limits £dS If the company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it? If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F7 If yes, the permit will contain an "Initial Compliance testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point q 002 Process 0 5CC Code 01 Uncontrolled Pollutant Emissions Factor Control% Units PM10 0.000 0.0 b/MMscf PM2.5 0.000 0.0 b/MMscf 50x 0.000 0.0 b/MMscf NOx 0.047 0.0 b/MMscf VOC 20.7 95.0 b/MMscf CO 0.215 0.0 b/MMscf Benzene 2.584 95.0 b/MMscf Toluene 1.841 95.0 b/MMscf Ethylbenzene 0.284 95.0 b/MMscf 0ylene 1.094 95.0 b/MMscf n -Hexane 0.317 95.0 b/MMscf 224 TMP 0.000 95.0 h/MMscf Dehydrator Regulatory Analysis Worksheet Re ulation 3 Parts A and B - APEN and Permit Requirements Colorado Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation3, Part B, Section lI.D.3)? You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section 11.0.1.0)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II,D.2)? `Source requires a permit Colorado Regulation 7, Section XII.H 1. Is this glycol natural gas dehydrator located in the B -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Reg 7, Section XII.H.1 and 2)? 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation', natural gas compressor station, natural gas drip station or gas -processing plant (Reg 7 Section 3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy (Reg 7, Section XII.H.3.b)? 4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section Xll.H.3.a)? !Dehydrator is subject to Regulation 7, Section XII.H Section XII.H — Emission Reductions from glycol natural gas dehydrators MACT Analysis 1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final b. end user' (63.760(a)(3))? 2. Is the dehydrator located at a facility that is a major source for HAPs? !Go to MACT HH Area Source Requirement section to determine MACY HH applicability Yes Yes yes Ym Yes 40 CFR, Part 63, Subpart MAR HH, Oil and Gas Production Facilities Area Source Requirements 1. Is the dehydrator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))? Exemptions 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.764(e)(1)(i)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.764(e)(1)(ii)? 3. Is the unit located inside ofa UA plus offset and UC boundary area? Yes Dehy is subject to area source MACT HH, per the requirements in 63.764)d)(2) Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards Do Not Apply §63.773 - Monitoring Standards Do Not Apply §63.774 - Record keeping §63.775 - Reporting Major Source Requirements 1. Does the facility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility -wide actual annual average hydrocarbon liquid throughput less than 249.7 Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.761)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.761)? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B) and (C )? 4. For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation? You have indicated that this facility is not subject to Major Source requirements of MACT HH. Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards §63.773 - Monitoring §63.774 - Record keeping §63.775 - Reporting 40 CFR, Part 63, Subpart MAR HHH, Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source (63.1270(1))? Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day (63.1270(b)(2))? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.1270(b)(2))? Small Deity Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(6)(2) and (3) )? 4. For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicable equation? I You have indicated that this facility is not subject to MACT HRH, Subpart A, General provisions per §63.1274 (a) Table 2 §63.1275 - Emissions Control Standards §63.1281 -Control Equipment Standards §63.1283 - Inspection and Monitoring §63.1284 - Recordkeeping §63.1285 - Reporting Colorado Regulation 7, Section XVII.D 1. Is the dehydrator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)? 2. Is this dehydrator located at a transmission/storage facility? 3. Is this dehydrator located at an oil and gas exploration and production operation, natural gas compressor station or gas processing plant (Reg 7, Section XVII.D.3)? 4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)? If constructed prior to May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 tpy VOC if the 4a. dehydrator is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)? 5. If constructed on or after May 1, 2015, am uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC (Regulation 7, Section XVII.0.4.a)? I Dehydrator is subject to Regulatio VII, 8, D Section XVII.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.D.3 - Emissions Reduction Provisions Alternative Emissions Control (Optional Section' 6. Is this glycol natural gas dehydrator controlled bya back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? IThe control device for this dehydrator is not subject to Regulation 7, Section XVil.8.2.e Section XVII.B.2.e —Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it 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 binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ 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," "should,"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 terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Separator Venting Emissions Inventory 004 Separator Venting 'Facility AIRs ID: County 4£88;•. � . Plant 004 :, ---,- Point Section 02 - Equipment Description Details ensateSorge Con Detailed Emissions Unit Description: bn , Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = Requested Permit Limit Throughput =:r"' T MMscf per year Requested Monthly Throughput = MMscf per month Potential to Emit (PTE) Throughput = Process Control (Recycling) Equipped with a VRU: s/ytr ��^-r%' Is VRU process equipment: 0,97 MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL of liquids throughput: Section 04 - Emissions Factors & Methodologies Description Em OR Helium Weight % CO2 N2 methane ethane propane isohutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 3.10 2,10 5 0',12 4 Total VOC Wt % 39.04 Btu/scf scf/bbl Ib/Ib-mol Displacement Equation Ex=Q°MW'Xx/C Emission Factors Separator Venting Pollutant Uncontrolled Controlled (lb/MMscf) (lb/MMscf) (Gas Throughput) (Gas Throughput) VOC 27137.4382 1356.8719 Benzene 280.2433 Toluene 112.4705 14.0122 5.6235 9.8677 Ethylbenzene 17.3537 Xylene 25,0928 n -Hexane 429.4217 224 TMP 2.4957 .2046 21.4712 0.1248 Emission Factor Source Emission Factor Source Pollutant Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Primary Control Device Uncontrolled lb/MMscf (Gas Throughput) PM10 PM2.5 11.194 11.194 0.884 500 NOx CO 102.159 460,725 11 of 14 K:\PA\2018\18W E0031.CP1.xlsm.xlsb Separator Venting Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controled (Ibs/month) PM10 PM2.5 505 NOx VOC CO 0.01 0,01 0.01 0.01 0.01 1 0.01 0.01 0.01 0.01 0.01 1 0.00 0,00 0.00 0.00 0.00 0 0.05 0.05 0,05 0,05 0.05 8 13,16 13.15 0.60 13.16 0.00 112 0.23 0.23 0,20 0,23 0,23 .38 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits ' Uncontrolled Controlled (lbs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224TMP 272 272 14 272 14 109 10.9 a 109 17 17 1. 17 1 24 24 .1. 24 7. 413 4..7 :?S. 417 2.t. 2 2 0 3 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.0, G Regulation 7, Section XVII.B.2.e (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance This is not a separator and is not subject or Tins s000rator i5 n lotion 2, Section 151133.2.e Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRs ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? If yes, the permit will contain: -An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. RiktIEIEgl -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? N0 If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. 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 12 of 14 K:\PA\2018\18WE0031.CP1,xlsm.xlsb Separator Venting Emissions Inventory Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 004 01 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units PM10 11.19 0 lb/MMSCF PM2.5 11.13 0 ib/MMSCF 500 0.88 0 lb/MMSCF 500 102.10 0 ib/MMSCF VOC 27137.44 95 lb/MMSCF CO 465.73 0 Ib/MMSCF Benzene 280.24 95 Ih/MMSCF Toluene 112.17 95 lb/MMSCF Ethylhenzene 1.735 95 ib/MMSCF Xylene 25.04 95 Ib/MMSCF n -Hexane 429,42 95 lb/MMSCF 224 TMP 250 95 16/MMSCF 13 of 14 IC\PA\2018\ 18WEOO31.CP1.xlsm.xlsh Separator Venting Regulatory Analysis Worksheet Colorado Re, ulatlen 3 Parts A and B - APEN and Permit Requirements ISnnree is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section ll.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)7 riot enough information NON -ATTAINMENT 1. Are uncontrolled emissions from any enter a pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D 1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPV or CO emissions greater than 5 TPV (Regulation 3, Part B, Section 11.0.2)7 'Source requires a permit Colorado Regulation 7, Section XVII 1. Was the well newly constructed, hydraulically fractured, ar recampleted on or after August 1, 2014? IThis is not a separator and is not subject Section 0011.0.2— Genral Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.G - Emissions Control Alternative Emissions Control (Optional Section' a. Is this separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? The control device for this venerator is not subject to Reguioliurl 1, Section X.Vn.6.2.n Section XVII.B.2.e —Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it 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 binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language suck as "recommend,"'may,"'should,"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 terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Yes S arcs Req Source Req The control DO ontrol Division Department of Public Health Er Environment Permit number: Date issued: Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: STRUCTION PERMIT Issuance: 1 Elevation Midstream, LLC Badger Central Gathering Facility 123/9F85 SEC 31 T5N R66W Weld County Oil Stabilization Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Tanks 21751 and 21752 001 Two (2) 38,700 barrel internal floating roof condensate storage tanks Internal Floating Roof Tanks 21851 and 21852 003 Two (2) 5,000 barrel fixed roof condensate storage tanks Enclosed Combustor Tanks 21901 and 21902 004 Two (2) 750 barrel fixed roof condensate storage tanks Enclosed Combustor Tanks 41751 and 41752 005 Two (2) 24,000 barrel fixed roof produced water storage tanks Enclosed Combustor This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/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. COLORADO Air Pollution Control Division I Department Ji Cubiie MetOth & Envimnrtent Page 1 of 10 2. q n1 u ed a ty d ('=80) of the latter of commencement of operation or issuance permit, • '.nce .'th try conditions contained in this permit shall be demonstrated to e Division. It is e 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. on Number 3, Part B, Section IILG.2.) 3. This permit shall pire if the owner or operator of the source for which this permit was issued: (i) does not com -nce construction/modification or operation of this source within 18 months after either, th date of issuance of this construction permit or the date on which such construction or vity 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.) I. F.4. ) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit atone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) ) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type PM2.5 NO„ VOC CO Tanks 21751 and 21752 001 --- --- --- --- Point Tanks 21851 and 21852 003 --- --- 2,548 308 Point Tanks 21901 and 21902 004 --- --- 4-49 --- Point Tanks 41751 and 41752 005 --- 346 5,547 1,575 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. Annual Limits: COLORADO Air Pollution Control Division Department t or Puivt e Hee:th Environment Page 2 of 10 ac ty ' • ui t ' " Al Po' Tons per Year Emission Type M2.5 NO), VOC • CO Tanks 21751 and 21752 001 --- --- 4.1 --- Point Tanks 21 and 21852 003 --- --- 15.0 1.9 Point Tanks 21901 and 2190 004 --- --- 2.7 --- Point Tanks 41751 and 41752 005 --- 2.1 32.7 9.3 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 both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Tanks 21751 and 21752 001 Internal Floating Roof VOC and HAP Tanks 21851 and 21852 003 Enclosed Combustor VOC and HAP Tanks 21901 and 21902 004 Enclosed Combustor VOC and HAP Tanks 41751 and 41752 005 Enclosed Combustor VOC and HAP COLORADO Air Pollution Control Division Uep ltnerff of Public Health G E.ilvirortritent Page 3 of 10 8. ' our at it (lowing maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facilit %` Equipment ID : ;RS Point Process Parameter Annual Limit Monthly Limit (31 days) Tanks 21751 and 21752 001 Condensate Throughput 21,900,000 barrels 1,860,000 barrels Roof Landing Events 2 events --- Tanks 21851 and 21852 003 Condensate Throughput 9,995,884 barrels 848,965 barrels Tanks 21901 and 21902 004 Condensate Throughput 1,825,000 barrels 155,000 barrels Tanks 41751 and 41752 005 Produced Water Throughput 18,250,0O0 barrels 1,550,000 barrels The owner or operator shall monitor monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. 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) 10. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. This source is subject to the applicable requirements of Regulation Number 7, Section VI.B.2. 13. Points 001, 003, £t 004: This source is subject to the New Source Performance Standards, Standards of Performance for Volatile Organic Liquid Storage Vessels for which construction, reconstruction or modification commenced after July 23, 1984, Subpart Kb. This facility shall be subject to all provisions of this regulation, as stated in 40 C.F.R Part 60, Subparts A and Kb. (Regulation Number 6, Part A, Subparts A and Kb) OPERATING £t MAINTENANCE REQUIREMENTS 14. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OFtM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to !COLORADO Air Potiutior't Control Division Page 4 of 10 oil approval prior to implementation. (Regulation Number 3, COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 15. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state o equirement. Periodic Testing equirements 16. This source is not equired to conduct periodic testing, unless otherwise directed by the Division or other state • =eral requirement. ADDITIONAL REQUIREMENTS 17. All previous versions of this permit are cancelled upon issuance of this permit. 18. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NQ) 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 For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • 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 19. 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. 20. 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 - COLORADO Mr Pollution Control Division Depertinrd of Public Heuith v E;nirmrnert Page 5 of 10 ultion Number 3, Part B, Section III.G. Final authorization it th ion or activity commences and has been verified by the APCD as conforming in a respec s wit 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. 21. This permit i the owner or o installation and representations the equipment reliance upon the accuracy and completeness of information supplied by rator and is conditioned upon conduct of the activity, or construction, peration of the source, in accordance with this information and with de by the owner or operator or owner or operator's agents. It is valid only for perations or activity specifically identified on the permit. 22. 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. 23. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 24. 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. 25. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Elevation Midstream, LLC COLORADO Mx Pollution Control Division Wth & 'tYR/Jr me :C Page 6 of 10 Notes mit issuance: 1) T `""it h is for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production based on the consum upon request of the control regulation or and complete appli terial processing limits and emission limits contained in this permit are ion rates requested in the permit application. These limits may be revised ner or operator providing there is no exceedance of any specific emission y ambient air quality standard. A revised air pollution emission notice (APEN) form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 63 63 Toluene 108883 28 28 Ethylbenzene 100414 9 9 Xylenes 1330207 3 3 n -Hexane 110543 239 239 2,2,4- Trimethylpentane 540841 2 2 003 Benzene 71432 4,619 231 Toluene 108883 2,100 105 Ethylbenzene 100414 660 33 Xylenes 1330207 240 12 n -Hexane 110543 17,638 882 2,2,4- Trimethylpentane 540841 120 6 004 Benzene 71432 814 41 Toluene 108883 370 19 Ethylbenzene 100414 116 6 Xylenes 1330207 42 2 n -Hexane 110543 3,110 155 COLORADO Air Pollution Control Division Dvir went ut PLear, NeWth 6 Emronrtert Page 7 of 10 Ethylbenzene Benzene Toluene 540841 21 1 71432 48,187 2,409 108883 21,993 1,100 100414 990 50 1330207 3,181 159 n -H= ane 110543 34,515 1,726 2; Trimethylpentane 540841 36 2 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: Point 001 (working and breathing): CAS # Pollutant Uncontrolled Emission Factors lb/bbl Source V0C 0.000343 TANKS 4.0.9d Point 001 (roof landings): CAS # Pollutant Uncontrolled Emission Factors lb/event Source V0C 307.357 AP -42 Chapter 7 Point 003: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source CO 0.000363 0.000363 TANKS 4.0.9d V0C 0.060017 0.003001 71432 Benzene 0.000462 0.000023 108883 Toluene 0.000210 0.000011 100414 Ethylbenzene 0.000066 0.000003 110543 n -Hexane 0.001764 0.000088 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 004: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source V0C 0.057956 0.002898 TANKS 4.0.9d 71432 Benzene 0.000446 0.000022 108883 Toluene 0.000203 0.000010 110543 n -Hexane 0.001704 0.000085 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. COLORADO Air Pollution Control Division pas— tmert -,f PUbir: tfeu th G lRrnorr:-tent Page 8 of 10 CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source • 4: 0.000215 0.000215 AP 42 CS 0.000979 0.000979 OC 0.071579 0.003579 Flash Liberation and EPA TANKS 4.0.9d 71432 nzene 0.002640 0.000132 108883 � ene 0.001205 0.000060 100414 Ethylbenzene 0.000054 0.000003 1330207 Xylene 0.000174 0.000009 110543 n -Hexane 0.001891 0.000095 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This source is subject to 40 CFR, Part 60, Subpart 0000a - Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification, or Reconstruction Commenced after September 18, 2015 (See June 3, 2016 Federal Register posting - effective August 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: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC and HAP NANSR Synthetic Minor Source of: VOC 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 COLORADO Air Pollution Control Division Dep'..Ament Qf Public Heut , & Emnonment Page 9 of 10 MACT 63.1-63.599 Subpart A - Subpart Z ds for Hazardous Air Pollutants for Source Categories MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63. _` . 5,175 Subpart QQQ- Subpart YYYY MACT 63.658 1< • 3.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.898 End Subpart NNNNN - Subpart XXXXXX ICOLO A O Air Pollution Control Division " (vrtment d Public He 4th &Envimnrrent Page 10 of 10 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Christopher;xester Packages: '.372557 Received Date: 4/112018 Review Start Date: 5/15/2018 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: ',Oil Stabilization ;Exploration &Production -. What industry segment? '.Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non attainment area? Yes If yes, for what pollutant? ❑ Carbon Monoxide (CO) ❑ Particulate Matter (PM) Elevation Mids'eam, LLC 9585 Badger Central Gathering Facility Section 31, Township SN, Range 65W Weld County Section 02 - Emissions Units In Permit Application Quadrant Section Township Range SN Ozone (NOx & VOC) AIRs Point N Emissions Source Type Equipment Name Emissions Control? Permit N Issuance it Self Curt Required? Action Engineering Remarks 001 Condensate Tank IFR Tanks 18 W E0028 Yes Permit Initial Issuance Condensate Tank Off -spec Tanks Yes 18 W E0028 ermit Initial Issuance 004 Tank Truck -in Tanks 18 W 80028 1 Permit Initial Issuance Permit Initial Issuance 005 Produced Water Tank PW Tanks yes 18W E0028 Yes 010 RICE Boilers 18WE0492.XP APEN Required / Permit Exempt <16MMBTU/hr 011 Diesel Emergency Generator 18WE0028 Permit Initial o Issuance Section 03 - Description of Project New Central Gathering Facility proposed Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Requesting 55 Inor Permit Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Yes 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) SO2 Na Non CO VOC PM2.5 PM10 TSP HAPs e❑ ❑ ❑ Colorado Air Permitting Project 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 (P5O) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) SO2 NOx CO VOC PM2.5 PM10 TSP HAPs El Condensate Storage Tank(s) Emissions Inventory Section 01- Adminstrative Information Facility AIRs ID: 123 County BFSS 001 Plant Pain Section 02 - Equipment Description Details Detailed Emissions Unit Two (2)30,700barrel internal floating roof condensatestaiage vessels Description: Emission Control Device Emissions are controlled usingan internal floating roof. Description: Requested Overall VOC & HAP Control Efficiency %: .-;The internal floating roof is considered an integrated control device. Please see Section 08 - Technical Analysis Notes section for additional information. Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Condensate Throughput = Secondary Emissions- Combustion Device Heat t content of waste gas.: Volume of wart. ;:;us emitted per 081 of flyui pro:iuied'_ la henit cooler :-.i' waste gas routed 'to c0mbustioo device Request heat „° e.:c: t of wastegas routed to combustion device 21,900,000'. Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = 21,900,000'.. Barrels (bbl) per year 21,300,000'. Barrels (bbl) per year **This facility does not utilize a combustion device to control emissions. cl// bbl 0ivINIffrij per year 0 MMETU ,e. -year 1,t-ncial to Emit 01 :h-rut'onent of music g:-....:eo to <Orribtst r,+°.._ = 0 _M pc•-r•c::r Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Standing & Withdrawal Losses Total Number of Vessels Total Emissions: Pollutant VOC Benzene Toluene Ethylbenzene Xylenes n -Hexane 2,2,4-TMP Process 01:Internal Floating Roof Emissions During Normal Operations 77 lb/year EPA Tanks 4.0.9d emissions report for internal floating roof tank w/gasoline RVP Weight % Ibs/year Source 7510,54 AP -42 0:0077 57.009658 .Mass Balance 0:0030 26.30403 (Mass Balance 0.0011 8.26709,2 Mass Balance 0.0004 3.005216 Mass Balance 0.0294 '. 2209563 75 Mass Balance 0.0002 1.503108 Mass Balance Process 02: Roof Landing Emission Calculations for IvterrsuI Floating Roof with Full Liquid Heel Parameters Value Units Source True Vapor Pressure (P) 4.4591 psia EPA Tanks 4.0,9d - Average Vapor pressure so! gasoline RVP 12 Average Temperature of vapor and liquid below floating roof (T) `509.9 °R EPA Tanks 4.0.9d -Liquid Bulk Temp Ideal Gas Constant ('R') 10,731 (psi'fts)/(Ib mol'R) Meal Gas Law Constant. Number of days tank stands idle with floating roof landed (nd) 1 days Engineer Estimate Stock Vapor Molecular weight,(M°) 66 Ib/Ihmol - EPATanks 4.0.9rS--Vapor molecular weight for gasoline RVP 12 Saturation Factor (0) 06 �.,_ AP-42Table 7.1.17 -Value for full liquid heel Height of vapor space under floating roof (h„) - -.. 1 ft --- Operator estimated value Tank Diameter (D) .100 ft Operator provided value Daily maximum ambient temperature (T,„) 523.97 °R AP-42Tab1e 7.1.7* Annual average value for Denver, CO Daily minimum ambient . temperature (T,,,) 48587 'R AP -42 Table 2.1.7 - Annual average value for Denver, CO Daily Total Insulation Factor (I) - 1568 Btu/ftuuday AP -42 Table 7.1-7- Annual average value for Denver, CO Tank paint solar absorptance (n) 0.17 ' ��, "' a AP -42 Table 7.1-6 - Tan paint in good condition .. ,.. 21,900,000 Barrels (bbl) per year 3 of 27 K:\PA\2018\18W E0028.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Atmospheric pressure (P,) Reid Vapor Pressure Volume of Vapor Space (V0) Vented Vapor Saturation Factor (K,) 7853.981534 0.80584403 Vapor Pressure Constant B for Crude Oil Stocks (B) 5237.432894 Daily Ambient Temperature Range (AT0) 23..1 Daily Vapor Temperature Range (AT„) 27,69568 Vapor Space Expansion Factor (Kr) 0.222652664 Event Standing Losses (100) psia ft' °R °R 53.89865127 lb/roof landing event Event Filling Losses (LF5) 253.4186238 event Estimate AP -42 Cha AP•42 Ch -.2 Figu , 722-112 AP -42 Chapter 7. E -is lb/roof andsg AP 12 ChaSCer Total Landing Loss Emissions (Ln= Lrr+Ls/ lb/roof landing 307.3572753 event AP-42G(ia)ster7 Egvati Total Number of Roof Landing events Total Emissions: Pollutant VOC Benzene Toluene Ethylbenzene Xylenes n -Hexane 2,2,4 -IMP Weight % lbs/year Source 614.7145505 AP -42. 5.733302039 2.101500927 0.676186006 0,24588582 18.07260778 0.12294291 ass Oa€ante;' sOS:Ipi tnai FIeating3tg6tEiir"' orlebtri (ig' i rma! fY Condensate Storage Tanks Control Device 5237.432894 (what I am acutally getting far this value, used their value to check the res Good once we confirm B Good once we confirm B Good once we confirm B Good once we confirm B Pollutant PM10 PM2.5 NOx VOC CO Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Uncontrolled E.F. (lbs/bbl Condensate Throughput) Controlled E.F. Uncontrolled E.F. Uncontrolled (lbs/bbl (Ibs/MMBtu E.F. (lbs/bbl Condensate waste heat Condensate Throughput) combusted) Throughput) 0.0003432 - 0.0003482 0.0000026 ::..: 0.0000012 .. 0.0000004 0.0000001 0.0000101 0.0000001 Process 02: 0.0000026 0.0000012 0.0000004 0.0000001 0.0000 0.0000 0.03004 ending Emission Calculations for Internal Floa Condensate Storage Tanks Control Device Emissions Factor Source Citation Pollutant PM10 PM2.5 NOx n -Hexane •: 1(11 i9: .0 Benzene Toluene Ethylbenzene Xylene Uncontrolled E.F. Uncontrolled E.F. Controlled E.F. (Ibs/MMBtu (lbs/roof landing (lbs/roof waste heat event) landing event) combusted) Uncontrolled E.F. (lbs/bbl Condensate Throughput) 0. 0 00 307.357 0.0020 LO76`i:>. 224 IMP 0 Section 05 - Emissions Inventory ';� �r-: ,., ,,%,. Process bit[rrterna[ fEoattagfioaf Emissions Dur)ng Normal Operations Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 D.0 0.0 0.0 0,0 3.0 0,0 0.0 I 0,e) 0.0 0.0 Emissions Factor Source Citation 4 of 27 K:\PA\2018\18W E002S.CP1.slum Condensate Storage Tank(s) Emissions inventory NOx VOC CO 0.0 0.0 0.0 0.0 0.0 3,758 3.758 3.758 3.758 3.758 0.0 0.0 0.0 0,0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 0.028935 0.023935 0.028935 0.028935 0.020933 0.013152 0.013152 0.013152 0.013152 0.013152 0.004134 0.004134 0.004134 0.004134 0.004134 0.001503 0.001003 0.381303 0.001003 0.001503 0.110478 0.110478 0.110478 9,110478 0.110478 0.000752 0.000752 0.300752 0.000752 0.000752 opt Air4tiaiv Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0,0 0.0 0,0 0,0 0.0 0.0 3.0 0.1 0.0 0.3 0.0 0.0 0.0 0.0 0.0 0.307 0.307 0307 0.307 0307 0.0 0.0 0.0 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) - Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 0.0024 0.0024 0,0024 0.0024 0.0024 0,0011 0.0011 0.0011 0.0011. 0.0011 0,0003 0.0003 0.0003 0,0003 0.0003 0.0001 0.0001 0.0001 0,0301 0.0001 0,0090 0,0090 0.0093 0,0090 0.0393 0.0001 0.0001 0.0001 0,3001 0.0001 R nd II m zh Mat fi fn a iota missions from intern( F oatnig Roof'lacik • Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0.0 0.0 3.0 0,0 0.0 0.0 0.0 0,0 0.0 0.0 0.0 0.0 0.0 - 0,0 0,0 4.065 4,060 4,065 4.065 4,065 0.0 0.0 3.0 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Urnits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224TMP 0,0313 0,0313 0.0313 0.0313 0.0313 0,0142 0.0142 0.0142 0,0142 0.0142 0.0045 0.0045 0.0045 0,0045 0.0045 0,0016 0,0016 0.0015 0.0016 0.0016 0.1105 0.1195 0.1195 0.1155 0.1195 0.0008 0,0008 0,0308 0.0000 3.0338 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Facility attainment -area status has not been established yet. Regulation 7, Section XII.C, 0, E, F Storage Tank is not subject to Regulation 7, section XII.C-f Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7. Section 511.10 Regulation 7, Section XVII.B, C.1, C.3 Storage Tank is not subject to Regulation 7, Section XV€I Regulation 7, Section XVII.C.2 Storage Tunic is not subject to Regulation 7, Section XVii.e2 Regulation 6, Part A, NSPS Subpart Kb Storage tank is subject to N18S N€t. including but not limited to, thi Regulation 6, Part A, NSPS Subpart 0000 Storage Tank is not subject to N1830000 Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to 1/ACT HH (See regulatory applicability worksheet for detailed analysis) 58 26 8 3 221 5 2 1 0 18 0 0.000371245 690.51477 63 0.000002859 28 0.000001299 9 0.000000408 3 0.000000148 239 0.000010915 2 0.000000074 5 of 27 K:\PA\2018\ 18WE0028.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 envisions 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 modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. Ant; 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. N/A - Operator developed site specific emission factors Does the company request a control device efficiency greater than 95%for a flare or combustion device? :1@fi.'-- N/A - A combustion device is not used to control emissions. If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes AIRS Point # 001 Section 09 - Inventory SCC Coding and Emissions Factors Process # SCC Code 01/02 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.000E+00 lb/1,000 gallons condensate throughput PM2.5 0.000E+00 lb/1,000 gallons condensate throughput NOx 0.000E+00 16/1,000 gallons condensate throughput VOC 8.839E-03 lb/1,000 gallons condensate throughput CO 0.000E+00 lb/1,000 gallons condensate throughput Benzene 6.806E-05 lb/1,000 gallons condensate throughput Toluene 3.094E-05 lb/1,000 gallons condensate throughput Ethylbenzene 9.723E-06 lb/1,000 gallons condensate throughput Xylene 3.536E-06 lb/1,000 gallons condensate throughput n -Hexane 2.599E-04 lb/1,000 gallons condensate throughput 224 TMP 1.768E-06 lb/1,000 gallons condensate throughput '"Note - Emission factors for process Oland 02 have been combined here solely for inventory purposes. When calculating actual emissions, the operator will calculate emissions for process 01 and 02 independently using separate emiss factors as described in the preliminary analysis above. 6 of 27 K:\PA\2018\ 18WE0028.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and a -OPEN and Permit Requirements I'Jnli has Indicated that source it in the taorrnttiinn'.ent Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants horn this Individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a(? ' 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPV or CO emissions greater than UMW (Regulation 3, Part B, Section 11.0.3)? (You h.,vc indicated that scarce is in the Non.Attaloment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section I I.D.1.a), 2. IS the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOL emissions from the greater than 2 TPV, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0,2)? ISourrm „n,q:ma a permit Colorado Regulation ',Section %II.C-F 1, Is this storage tank located in the B -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation", natural gas compressor station or natural gas drip station? 3. is this storage tank located upstream of a natural gas processingplant? Ixerage Tan's. is. onu. sul/cur to Semilatinn 7, 5ectiun XII.C-F Section XI1.C1 —General Requirements for Air Pollution Control Equipment —Prevention of leakage Section %ILG2 — Emission Estimation Procedures Section %ILO —Emissions Control Requirements Section %ILE— Monitoring Section %1LF—Recordkeeping and Reporting Colorado Regulation 7. Section %II.G 1. Is this storage tank located In the B -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash"(e.g.storing nonstabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? 'Sucnonc Tankis not subject to RnguRs?inn 7; Section %IlG Section %II.G,3- Emissions Control Requirements Section 011.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of leakage Section %II.C.e— Emission Estimation Procedures Colorado Regulation 7, Section %VII 1. Ls this tank located at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation, well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions° of this storage tank equal to or greater than 6 tans per year VOC? ISksage Tank is nut nui'ioci?u s egul utlun 7, Saclion XVII Section %VII.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section %VII,G1- Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? Storage Yank is not sublmt to Regulation?, Se. tlms X`d31,C2 section %VIkG2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part CO, subpart Kb. Standards of Performance for Volatile Organic Llquld Storage Vessels 1 is the individual storage vessel capacity greater than or equal to 75 cubic meters (m') 1'472 BMA? 2. Does the storage vessel meet the following exemption in 60,111b(d)(4)? a, Does the vessel has a design capacity less than or equal to 1,589.8]4 m3 [-10,000 BBL] used for petroleum' en condensate stored, processed, or heated Odor to custody transfer' as defined in 60,111b? 3. Was this condensate storage tank constructed, reconstructed, or modified [see definitions 40 CFR, 60,2) afterlulc 23, 1980 4. Does the tank meet the definition of "storage vesselxe in 60.1116? 5. Does the storage vessel store a 'volatile organic liquid (VOW' as defined In 60.1116? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa ('"29.7 psi) and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity is greater than or equal to 151 m3 ('950 BBL) and stores a liquid with a maximum true vapor pressure' less than 3.5 kPe (60.110b(b))?; or c. The design rapacity is greater than or equal to 75 Ms ("472 BBL) but less than 151 m3 ("'950 BBL) and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(b()? ',ammo for -k is suhitct' to NSPS fib, InGodinp Hut not iirnised to, Ito' taliscveie; n:uv:sinna Subpart A, General Provisions §60.112b- Emissions Control Standards for VOC §6o.113b - Testing and Procedures §60,1156 -Reporting and Recordkeeping Requirements §601156- Monitoring of Operations 40 CFR, Part EA, Subpart 0000. Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, sutural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, so.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage Vessel meet the definition of "storage vessel"' per 605430? S. Is thestorage vessel subject to and controlled In accordance with re ulrements for Store a vessels in 40 CFR Part 60 Sub art Kb or. CFR Part 33 Sub art HH? ISmrage Tacau oet su6la-t so NSPS Ori0O Subpart A, General Provisions per 460.5425 Table 3 §60.5395- Emissions Control Standards for VOC §60.5413 -Testing and Procedures §60.5395(8) - Notification, Reporting and Recordkeeping Requirements 360.5416(c) -Cover. and Closed Vent System Monitoring Requirements §60.5417 -Control Device Monitoring Requirements [Note: Ha storage vessel Is previously determined to be subject to NSPS O00O due to emisslons above 6 tons per year VOC on the applicability determination date, It should remain subject to NSP5 0000 per 60.5365(e)(2( even If potential VOC emissons drop below 6 tons por year) 40 CFR, Part 63, Subpart MAR OH. Ill and Gas Production Facilities 1 Skrtintillt Source Requires an APEN. Go to the next question Go to next question Source Requires a permit Continue - You have indicated thesite attainment status on the project summary sheet. Storage Tank is not subject to Regulation T, Section X11 -You have Indicated the facility type on the project summary sheet. Continue - You have determined facility attainment flatus on the Project Summary sheet. Storage Tank is not subject to Regulation], Section 011,0 -You have indicated facility type on project summary sheet. Storage Tank is notsubject to Regulation 7, Section 011.5 Continue - You have indicated the source category on the Project Summary sheet. Storage Tank is not subject to Regulation 7, Section XVII - It does not meet the storage tank definition -You have indicated facility type on project summary sheet. Storage Tank is not subject to Regulation 7, Section XVII c intillstorage Tank is not subject to Regulation 7, Section XVR.C.2 '' G t the next question „.: Go to the next question Go to the next queston Go to the next question Go to the next question Source is subject to NSPS Kb Continue -You have indicated the source category on the Project Summary sheet. Storage Tank is not subject NSPS 0000- This tank was constructed prior to the applicability date. Storage Tank is not subject NSPS 0000. 1. Is the storage tank located at an oll and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.750la1R1L OR b. Afacillry thatprocesses, upgrades or Stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user' 163.760la113)l, 2 Is the tank located at a facility that is major' for HAPS? 3. Does the tank meet the definition of "storage vessel' In 63.761, 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions' per 63.761, 5. Is the tank subject to control requirements under 40 CFR Part 60 Subpart Kb or Sub art 0000, 1137L see rank it notcordurt:o nduh? NH Subpart A, General provisions per 463.7641x1 Table 2 §63.766 -Emissions Control Standards §63.773 -Monitoring §63.774-Recordkeeping 463.775 -Reporting RACY Review RACT review Is required If Regulation 7 does not apply AND It the tank is In the non-attalnment area. If the tank meets both criteria, then review RACr requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and dmumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. la the event of any conflict between the language of this document and the language oflhe Clean Air Act,, its Implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use ofnon-mandatory language such as "recommend,""may,""should, 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 terms Ogre Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Definitions far Drop Down Lists Yes No NA lint 'The facility N not an affected source under MAR HH- You have Indicated the source category on the Project Summary sheet. Storage Tank is not subject MALT HH -There are no MACK HO requirements for tanks at area sources Condensate Storage Tanks) Emissions Inventory 003 Condensate Tank Facility AIRs ID: County Plan Poin Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Condensate Throughput �/i 4i'¢ Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = $,1 Barrels (bbl) per year Requested Monthly Throughput = 848965 Barrels (bbl) per month Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquid produced = scf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Btu/scf 11,716 MMBTU per year 11,716 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 11,716 MMBTU per year Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Pollutant Uncontrolled Controlled (lb/bbl) (Ib/hhl) (Condensate Throughput) (Condensate Throughput) VOC 0.00'3001 0.0000023 0.000€L11 0.000003 0.000501 0.000€788 0.000001 Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP -s;0aatia 2i Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Condensate Throughput) PM10 PM2.5 NOx CO 0.00€70 0.0000 0,00W 0.400363 Section 05 - Emissions Inventory Emission Factor Source Emission Factor Source Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ms/month) VOC 209.96149 300,0 15.0 300.0 150'0 25,15 PM10 0.0 5.0 0.0 0.0 0.00 0 PM2.5 0.0 0.0 (i.il 0.€l 0,150 0 NOx 0.4 0.4 0.4 0.4 0.40 6S CO 3..;d 1.8 .9..8 .I..B 1.52 :308 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 4619 4619 231 4619 231 Toluene 3100 2.160 .:115 2.100 105 Ethylbenzene 660 _ 660 33 660 33 Xylene 240 240 12 240 12 n -Hexane 17032 176:38 882 9.7038 882 224 TMP 120 120 6 120 6 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage Tank is not subject to Regulation 7, Section Xli.C-F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section X0.6 Regulation 7, Section XVII.B, C.1, C.3 Storage Tank is not subject to Regulation 7, Section KV7€ Regulation 7, Section XVII.C.2 Storage Tank is not subjevt to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NIPS Subpart Kb Storage tank Is subject to NIPS Kb Regulation 6, Part A, NIPS Subpart 0000 Storage Tank is not subject to NSW 0000 Regulation 8, Part E, MACT Subpart HH Storage Tank is not sntzjoct to MACT Hit (See regulatory applicability worksheet for detailed analysis) 13 of27 K:\PA\2018\18 W E0028.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? zPfa_ 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 faders 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 modified (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? RNs:_ ,,,a'�'"v'=•>'sf 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 09 - Inventory SCC Coding and Emissions Faders AIRS Point It Process 0 5CC Cade 003 01 1 4'A_ Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 lb/1,000 gallons condensate throughput NOx 0.00 0 lb/1,000 gallons condensate throughput VOC 1.4 95 lb/1,000 gallons condensate throughput CO 0.01 0 Ib/1,000 gallons condensate throughput Benzene 0.01 95 lb/1,000 gallons condensate throughput Toluene 0.01 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 16/1,000 gallons condensate throughput Xylene 0.00 95 lb/1,000 gallons condensate throughput n -Hexane 0.04 95 lb/1,000 gallons condensate throughput 224 TMP 0.00 95 lb/1,000 gallons condensate throughput 14 of 27 K:\PA\2018\18W E0028.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts Aand a - APEN and Permit Requirements kno.et. Is ,n the Nan'A.rtainmant Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TM' (Regulation 3, Part A, Section 11.0.1.a(? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Merin 05.01 Definitions 1.12 and1.14 and Section ?for additional guidance on grandfather applicability(? 3. Are totalfaciltty uncontrolled VOC emissions greater than 5 TP?. NOx greater than 10 TPY or CO emissions greater than lO TPY (Regulation 3, Part B, Section 11.0.3)4 Nat enonek info , ..for: NON ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than l TPY (Regulation 3, Part A, Section 11.0.1.a)? 2. Is the construction date (seance date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Meng 05-01 Definitions 1.12 and1.14 and Section 2 far additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions from the greaterthan 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2? ISuomro ',points eneon?. Colorado Regulation?. Section gll.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor Marion or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? 'Sterago Tani, i° net sols;eor w negela0on 7, 500000?0A Section tll.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Section g0I.C.2—Emission Estimation Procedures Section 101.13 —Emissions Control Requirements section l(II.E—Monitoring Section NILE—Recordkeeping and Reporting Colorado Regulation 7. Section 011.0 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Isthb storage tank located et a natural gas processing plant, 3. Does this storage tank exhibit "Flash"(e.g.storing non -stabilized liquids) embsions and have uncontrolled actual emissions greaterthan or equal to 2 tons per year VOC? Int'or037 Tony is net subject to Ilagulailuo e„seation 011.:E Section 101.0.2 - Emissions Control Requirements Section KII.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Section RII.C.2 —Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tanks located at an oil and gas exploration and production operation , well production facility', natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank fixed roof storage tank? 4, Are uncontrolled actual emissions of this storage tank equal to or greater than 6 tons per year VOC? ISto, ne Tank is netsub(ert to Regulation 7, Section 3011 Section 0Vll.a—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1- Emissions Control and Monitoring Provisions Section 0011.1.3 - Recordkeeping Requirements 5. Does the condensatestorage tankcotta in only "stabilized" liquids? ISoorage rank is not subjeRte Regulation I, Section 2011...2 Section %NI.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR. Part 65, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m) (0372 BBlsl? 2. Does the storage vessel meet the following exemption In 60.111b(d)(4(? a. Dog the vessel has a design capacity less than or equal to 1,589.874 ms ['10,000 BBL) used for petroleum' or condensate stored,processed, or treated prior to custody transfer' as defined in 60.1110? 3. Was this condensate storage tank constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank meet the definition of"storage vessel"' in 60.111b? 5. Does the storage vessel stare a"volatile organic liquid (VOU' as defined in 50.1110? 6. Does the storage vessel meet any one of the fallowing additional exemptions: a. Is thestorage vessel a pressure vessel designed to operate in excess of 204.9 kPa [-29.7 psi] and without emissions to the atmosphere (60.110b(d((2)(?; or b. The design capacity b greaterthan or equal to 151 e° [^950 BBL] and stores a liquid with a maximum true vapor pressure" less than 3.5 kPa (60.110b(b)l?; or c. The design capacity is greater than or equal to 75 Ma [-472 BBL] but less than 151 ma (-950 BBL] and storm a liquid with a maximum true vapor pressure' less than 15.0 kPa(fi0.110b(b))? letarage took Is snlsjectts? lent, Or, Subpart A, General Provisions §60.1126- Emissions Control Standards for VOC §60.113b -Testing and Procedures §60.115b- Reporting and Recordkeeping Requirements §60116b- Monitoring of Operations 40 CFR, Part 60. Subpart 0000, Standards of Performance for Crude Oil and Natural One Production, Transmission and Oishibution 1. h this condensate storage vessel located at afacility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission andetorage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOCemissions' from the Individual Storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel' per 605430? 5. b the storage vessel sublectto and controlled in accordance with re mrements forstoa a vessels in 40 CFR Part 60 sub art Kb or 40 CFR Part 63 Subpart HH? 'Stow ,e Tank is net subject to floor 0:1041 Subpart a, General provisions per 4605425 Table 3 §60.5395 - Emissions Control Standards for VOC 460.5413 -Testing and Procedures §60.5305(s)- Notification, Reporting and Recordkeeping Requirements 4605416(0 -Cover and Closed Vent System Monitoring Requirements §60.5417- Control Device Monitoring Requirements gdote: If storage vessel is previously determined to be subject to NSPS O000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS O0OO per 60.5365(e((2)even if potential VOC emissions drop below a tons per year) CSubpart MAR.., Oil and Gas Production Facilities I. bnthe storage tank located at an oil and natural gas production facilPythat meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids" (63.760(a)(2p; DR b. A faolity that processor, upgrades or storm natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end users (63.700(a((3((? 2. Is the tank located at a facility that is major' for HAP'? 3. Does the tank meet the definition of ^storage vessel"a in 63.061? 4. Does the tank meet the definition of"storage vessel with the potential for flash emissions' per 03.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Sub art Kb or Sub art 0000? IShoragtTenk is race soh*echo MACE NF: Subpart A, General prousions per 463.764 (a) Table] §63.766- Emissions Control Standards 463.7/3 - Monitoring §63.774-Recordkeeping §65.0/5 -Reporting RAU Review' RACr review is required if Regulation 2 does not apply AND If the tank Is in the non -attainment area. If the tank meets both criteria, then review RAR requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it 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 binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ 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 7ecommend°"may,"should° and 'can," is intended to describe APCD interpretations and recommendations. Mandatary terminology such as "must and °required are intended to describe controlling requirements under the terns of the Clean Air Act and Air Quality Control Commission regulations, but this document does net establish legally binding requirements in and of itself. Yes Nn No ten Source Req Go to next Source Req Continue -' Storage Tar ontinue-' Storage Tai ontinue Storage Tar (i storage Tar Go to the n Go to the n Go to then Go to then Go to then Source is cat Continue-' Storage Tar Ga to the n I ret I Continue-' Storage Tar Condensate Storage Tank(s) Emissions Inventory 004 Condensate Tank Facility AIRs ID: County Plan Section 02- Equipment Description Details Detailed Emissions Unit ' 1 Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = 25 Barrels (hbl) per year Barrels (bbl) per year Requested Monthly Throughput = Actual Condensate Throughput While Emissions Controls Operating = 'Barrels (bhp per year Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughpu !) Barrels Dahl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquid produced = scf/hhl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Btu/scf 2,066 MM BTU per year 2,066 MM BTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device= 2,006 MM BTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Pollutant Uncontrolled Controlled (lb/bbl) (Ib/bbl) (Condensate Throughput) (Condensate Throughput) Emission Factor Source VOC Benzene Toluene iNtt h579S 0.002598 0.000022 Ethylbenzene 0.090003 0.000001 0,000€,085 0.000091 Xylene n -Hexane 224 TMP Emission Factor Source Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/bbl) (waste heat combusted) (Condensate Throughput) PM10 PM2.5 NOx 0.0010 0.0000 0,0000 0,0900 Section 05- Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC PM10 PM2.5 NOx CO 52.9 52.9 2.6 52.9 2.64 440 0.0 0.0 0.0 0.0 0.0 0 0,0 0,0 9.€1 0.0 5.1 0.1 0.1 0.1 0,1 12 0.1 0.3 13.3 0.3 0.3 54 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (Ihs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 814 8'14 41 314 41 :3311 170 19 ;370 19 116 116 6 116 6 42 42 2 42 2 3110 :3120 1.01 32.10 1.50 21 21 1 21 1 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, 5, E, F 010rage Tank €s not subject to Regulation 7, Section 311.C -F Regulation 7, Section XII.G, C Storage Iced is not subject to Regulation 7, Section Xt€.G Regulation 7, Section XVII.B, C.1, C.3 Storage funk is not subject to Regulation'?, Section XV₹€ Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVll.C.2 Regulation 6, Part A, NSPS Subpart Kb Storage tank is sub(cvt to NIPS Kb Regulation 6, Part A, NIPS Subpart 0000 Storage Tank is not subject to FlIP5 0000 Regulation 8, Part E, MACPSubpart HH Storage Tank is not subject to MALT 110 (See regulatory applicability worksheet for detailed analysis) 16 of 27 K:\PA\2018\18W E0028.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 moddied (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. ;Fhsctoppttsahf 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? s = 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 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 004 01 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 Ib/1,000 gallons condensate throughput NOx 0.00 0 lb/1,000 gallons condensate throughput VOC 1.4 95 lb/1,000 gallons condensate throughput CO 0.01 0 lb/1,000 gallons condensate throughput Benzene 0.01 95 lb/1,000 gallons condensate throughput Toluene 0.00 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 lb/1,000 gallons condensate throughput Xylene 0.00 95 Ib/1,000 gallons condensate throughput n -Hexane 0.04 95 lb/1,000 gallons condensate throughput 224 TMP 0.00 95 lb/1,000 gallons condensate throughput 17 of 27 K:\PA\2018\18WE0028.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Reeuletlan 3 parts A and B - APEN and Permit Requirements In m the tioryAttalea... Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section 11.0.1.a)? 2. Is the construction date (service date) prior to 12/30/1002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 far additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOX greater than to Ton or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.03)? kat eamixii totes xian NON -ATTAINMENT 1. Areuncontrolled emissions from any criteria pollutantsfrom this individual source greater than 1 TPY (Regulation 3, Part A, Sectionil.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total lean/uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TRY (Regulation 3, Part B, Section 11.0.2? IS:.. Sal -require apm. eolarado Regulation 2, Section XII.C-F 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Ls this storage tank located at an oil and gasexploration and production operation', natural gas compressor station or naturalga5 drip station? 3. isths storage tanklooated upstream of a natural gas processing plant? I5tara€eTonC in not 'shied to Rc£uiatian 4,301140111.10 Section XII.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of leakage Section XII.C3 —Emission Estimation Procedure Section XII.D— Emission Control Requirements Section MI5 —Monitoring Section (Ulf — Recordkeeping and Reporting Colorado Regulation ]. Section XII.G 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibt"Flash" (e.g. storing non -stabilized liquids)emissions and have uncontrolledactual emissions greater than or equal to 2 tons per year VOC? ISiorage Tank is m;l.:uhiec-t:o Data:laaan 7, Sin.iikai 011.. Section X11.G.2 - Emissions Control Requirements Section XII.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Section XII.C.2 —Emission Estimation Procedure Colorado Regulation], Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor stations or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storagetank? 4. Are uncontrolled actual emissions" of this storage tank equal to or greater than 6 tons per year VOL? 'Storage Tank is not subj. tto fieguiatinn], SectimnlVll Section XVILB —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section IMl.C.1- Emissions Control and Monitoring Provisions Section IMI.C3 - Recordkeeping Requirements 5. Doethe condensate storage tank contain only 'stabilized"liquids? ISbrrago Tank in net sui;ecttn Renal-ativ7 0, SalTun XVII.2,4 Section XVIl.C.2 - Capture and Monitoring far Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb. Standards of Performance far Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m) (-472 BBL'.? 2. Does the storage vessel meet the following exemption In 60.1116(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,5e0.874 ms 1-10,000 BBL] used for petroleum' or condensate stored, processed, or treated poor to custody transfer' as defined in 60.1111? 3. Was this condensate storage tank constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Doe the tank meet the definition of "storage vessel"' In 6o.111b? 5. Does the storage vessel store a"volatile organic liquid(1011"as defined in 60.111b? 6. Doethe storage vessel meet any one of the following addeional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 ea (^29.7 psll and without emissions to the atmosphere (60.11ob(d)(2))?; or h. The design capacity Is greater than or equal to 151 re 1-950 BBL] and stare a liquid with a maximum true vapor pressure lass than 35 kPa (60.110b(b)l?; or c The design capacity is greater than or equal to 75 M' ('072 Bel) but less than 151 me (•950 0014 and stores a liquid with a maximum true vapor pressure less than 15.0 kla(60.110b(b)l? I.,to ar,k ix x:rh t20 NSac Subpart A, General Provisions 4601126- Emissions Control Standards for VOC 4601136 -Testing and Procedures 460.115b- Reporting and Recordkeeping Requirements 4601166- Monitoring of Operations 40 CFR, Part 60. Subpart 0000. Standards of Performance for Crude Wand Natural Ges Production, Transmission and Distribution 1. Is this condensate storage vessel (orated at a fadlity in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? z. was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August's, 2011 and September IS, 201'7 3. Are potential VOC emsslonsz from the individual storage vessel greater than or equal to 6 tom per year? 4. Dots this condensate storage vessel meet the definition of "storage vessel") per 605430? 5. Is the storage vessel subject to and controlled in accordance with requirements for story a vessels In 40 CFR Part 60 Sub art Kb or 40 CFR Part 63 Sub art NH? 'Stars, T.sa To Subpart A, General Provisions per 460.5425 Table 3 4605395- Emissions Control Standards for VOC 460.SdTesting and Procedures 4605395(g) - Notification, Reporting and Recordkeeping Requirements 4605416(c) - Cover and Closed Vent System Monitoring Requirements 4605417- Control Device Monitoring Requirements (Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year 000 on the applicability determination date, itshould remain subject to SOPS 0000 per 60.5365(e)(2) even If potential VOC emissions drop below 6 tans per year] 40 CFR, Part 63, Subpart MAR HH. 011 and Gas Production Facilities 1. IS the storage tank located at an oil and natural gas production facility that meets either of the fallowing criteria: a. A facility that processes, upgrades or store hydrocarbon liquids' (63.760(a)(2)); OR b. 41001110, that processes, upgrades orstores natural gas prior to the point at which naturalgas enters the natural gas transmission and storage sou rtes category ors delivered to a final end users (63.76o(a)(31)? 2. Is the tank located at a facility that is major' for Hans? 3. Does the tank meet the definition of "storage vessel" in 03.7617 4. Doesthetank meet the definition of "storage vessel with the potential for flesh emissions' per 63.761? 5. Is thetank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? 'Storage Tank Is not suhlecttT 40 HH Subpart A, General pmvsions per 003.764 (a) Table 2 463.]66- Emissions Control Standards §63.7]3 - Monhodng §63.774- Recardkeeping §63.775 - Reporting RACT Review RAG] review Is required It Regulation 7 does not apply AN0 lithe tank Is in the non -attainment area. If the tank meets both cnteda, then review RACT requirements. Disglalmer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and AD Qualify Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change orsubs2tute far any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language at the Clean Air Act„ 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,"should,"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 terms of the. Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of dself. Yes Continue-' isse "fa, No Nn Source Req Go to next Source Req Continue-' StorageTaI Continue Storage Tar Continue-' Storage Tar 1?:; , ;1 0orage Tar Go to the n Go to then Go to the n Go to then Go to then Storage Tar (Yea (Continue Storage Tar Produced Water Storage Tank(s) Emissions Inventory 005 Produced Water Tank Facility AIRS ID: Plan Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = )Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput = OHS, Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = 0f{ Barrels (bbl) per year Requested Monthly Throughput = 1550000 Barrels (bbl) per month Barrels (hbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= 1409,0 Btu/scf Volume of waste gas emitted per BBL of liquids produced = scf/bbl Actual heat content of waste gas routed to combustion device Requested heat content of waste gas routed to combustion device = 59.828 MMBTU per year (includes pilot fuel gas for the whole facility) 59,828 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 59.828 MMBTU per year Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (lb/bbl) (Ib/bbl) (Produced Water Throughput) (Produced Water Throughput) VOC Benzene Toluene 0,1/715711 0.002640 0,003079 0.0001.32 00 0.000060 Ethylbenzene Xylene ..........:0000004 0.000003 0,000009 :,:,0,000174 n -Hexane 224 TMP `i}10„001391 0.000095 "0.000002 0,000000 Emission Factor Source Emission Factor Source Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/bbl) (waste heat combusted) (Produced Water Throughput) PM10 PM2.5 0.0000 0,0000 NOx CO 0.000215 0.000979 noifixocia Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC PM10 PM2.5 NOx CO 653.2 613.2 32.7 653.2 32.06 5547 0.0 0.0 0.0 0.0 0.00 0 0.0 0.0 0.0 0,0 0,00 0 2.0 2.0 2.0 2.0 2.03 346 9,3 9.3 9.3 9.3 9.27 1175 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) )lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 43187 40137 2409 48187 2409 21993 21993 1100 21993 1100 990 990 50 990 50 3181 3101 159 3101 159 345.111 34515 1726 34515 1.720 36 36 2 35 2 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage Tank is nut subject to Regulation 7, Section XVII Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart 0000 Nat enough information (See regulatory applicability worksheet for detailed analysis) Flash lb/bbl W&B total lbs W&B lb/bbl 0.0714 2581.7 0.000141463 0.002635175 95.233334 5.21826E-06 0.001202725 43.46561865 2.38168E-06 5.41648E-05 1.W7477014 1.07259E-07 0.000173963 6.286898017 3.44488E-07 0.0018875 68.21289589 3.73769E-06 1.9515E-06 0.07052581 3.86443E-09 19 of 27 K:\PA\2018\18 W E0028.CP1.xl sm Produced Water Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? efdY , 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 Anals is Notes Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point H Process 0 5CC Code 005 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons liquid throughput PM2.5 0.00 0 lb/1,000 gallons liquid throughput NOx 0.01 0 lb/1,000 gallons liquid throughput VOC 1.7 95 lb/1,000 gallons liquid throughput CO 0.02 0 lb/1,000 gallons liquid throughput Benzene 0.06 95 lb/1,000 gallons liquid throughput Toluene 0.03 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput Xylene 0.00 95 lb/1,000 gallons liquid throughput n -Hexane 0.05 95 lb/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput 20 of 27 K:\PA\2018\18WE0028.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Re lation 3 Parts A and B-APEN and Permit Requirements amine is in the Non•Atteinmont Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPV (Regulation 3, Part A, Section lI.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located eta non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part 0, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, 500 greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.31? 'you have indicated that source is in the Non :Attainment Anna NON -ATTAINMENT 1. Are uncontrolled emissions from any cetera pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section ll.D.1.a)? 2. Is the operator claiming less than 1% crude oil and Is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section 11.0.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2 Teal, N0x greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.217 (Source requires a permit Colorado Regulation 7, Section XVII 1. Is this tank located at a transmisslon/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility, natural gas compressor statian3 or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions of this storage tank equal to or greater than 6 tons per year VOC7 'Storage Tank is not subject to Regulation '7, Section 3VII Section XVII.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.0.1- Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. Storage Tank is not subject to Vegulatiu,, 7, Section Xtll.C.2 Section XVIl.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR. Part 60, Subpart 0000, Standards of Performance for Crude Oil end Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the Industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.54307 loot enough information Subpart A, General Provisions per§60.3425 Table 3 460.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §eu.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417- Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC an the applicability determination date, it should remain subject to NSPS 0000 per 60.5365je)(2) even if potential VOC emissions drop below 6 tons per year] RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets bath criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a ale or regulation, and the analysis it contains may not apply toe particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ 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," 'should,"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 terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Source Req %dcv Go to next• Yea,, > Source Req Continue -' Storage Tar Continue Storage Tar Natural Gas Heater Emissions Inventory 010 NG Heater 'Facility AIRS ID: County Plant Point Section 02- Equipment Description Details Heater Information Fuel Type Number of Heaters Purpose Make: Model: Serial Number: Design Heat Input Rate: Equipped with Low-NOx burners: Equipped with Add -On Control Equipment: MMBtu/hr 6 natural gas heater(s) (Make: 7AD, Model: TBD, Serial Number: TAO) each with a design heat input rate of 6 MMBtu/hr. Each unit io a hot vii heater. Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency % NO add-on control equipment Section 03- Processing Rate Information far Emissions Estimates Design Heat Input Rate = Heat content of waste gas= Actual Hours of Operation = Requested Hours of Operation = Requested heat input rate = Actual Fuel Consumption = 6 MMBtu/hr Btu/scf 1 hrs/year hrs/year SOS MMRTU per year 24.>.15 MMscf/year Requested Fuel Consumption = 243,15 MMscf/year Requested Monthly Throughput = 21. MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04- Emissions Factors & Methodologies 243.15 MMscf/year Section 05 - Emissions Inventory Ib/MMBtu Ib/MMscf Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx NOx CO VOC 1,17 1.17 1.77 1.17 1.1.7 2110 1.17 1.17 __1.17 L':7 _+..17 200_ 0.09 0.09 0.09 0.09 0.00 16 15.46 15.96 10.46 11.46 15.46 2626 12,99 12,84 12.99 12,99 12.99 3206 0.05 9.35 0.85 0,35 0.55 144 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (tics/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) Ohs/year) Formaldehyde 23 23 23 23 23 Benzene Toluene n -Hexane 557 557 557 557 557 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Source is permitexenpt per Regulation 3, Port B, Unction 11.0.1.1. Regulation 1, Section VI Based on the requested n,40cions and emission factor, compliance is pre.s::c n4. Regulation 1, Section III & Regulation 6, Part B, Section II Based on the design heat input rate, the source is SUbje!t iv Regulation 1 Section Ill.A.1 r. and Regulation 6, Part U. Section ll.C:3. Rased on the requested e Regulation 6, Part A, Subpart Db, SO2 Standards Source is not subject to MPS Db. Regulation 6, Part A, Subpart Db, NOx Standards Source is not subject to IPSP5 Oh. Regulation 6, Part A, Subpart Sc Scurce is not subject to NIPS Sc. Regulation 7, Section %VI.D Source is riot subject to Regulation 7, Section 310.11. Regulation 8, Part E, MAR Subpart DDDDD Source is not: a:;bject r1: MAC-FDOD0O. 22 of 27 K:\PA\2018\18W E0028.CP1.xlsm Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodk Sampling and Testing Requirements Is the project close to the 40 tpy modeling / NANSR threshold for NOx? If yes, stack -testing should be required for NO0, as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes, stack -testing should be required for NOx, as well as for CO. Is the project close to the 5 tpy modeling threshold for PM 2.5? If yes, stack -testing should be required for PM 2.5 Does the company use AP -42 emission factors (or more conservative factors)? If no and testing hasn't already been required due to proximity to modeling thresholds, testing should be required for any pollutants for which alternative emission factors have been used. If testing is being done for only NOx or only CO, the other should be included as well. Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point g Process ft SCC Code 010 Uncontrolled Emissions Pollutant Factor Control % Units 01 13-10-004-04: Industrial Prccess; O0 & ties Production Process Heaters: Natural 0 -au (Mllleen PM10 9.66 0 lb/MMscf Burned PM2.5 9.66 0 le/MMscf Bumed SOx 0.76 0 lb/MMscf Burned NOx 127.16 0 Ih/MMscf Burned CO 106.81 0 lb/MMscf Burned VOC 6.99 0 lb/MMscf Burned Formaldehyde 9.54E-02 0 lb/MMscf Burned Benzene 2.67E-03 0 lb/MMscf Bumed Toluene 4.32E-03 0 lb/MMscf Burned n-Hexarc 2.3 0 Ib/MMscf Burned 23 of 27 K:\PA\2018\18W E0028.CP1.xlsm Natural Gas heater Regulatory Analysis Worksheet ATTAINMENT 1. Are unturned actual megatons from any criteria pollutants 1 tom Mg inglivguat moue greater than Tag (Regulation, part A. Reagan 1Lola)? 2. gem the heater haven dmign heat input rate (ma Man erequal Me eto/hrt lRegr oeameneatee255525252255115522,5255552255due, 2.11,,,52.22...equaltulg WARM., Megw1R9law R, Pan R,Rearoalr.D..el 2. om the haterhave dmgn tos nnNeto/hrx(Regulationg, vann.Yrsion rl.o.v.k.l .. Are total twigwowontreged emr„ion,hem the graterthanO2Pe,NO, greater than 5 Pe(ea emr„tans greater Man 5ere waohtwn g, van g.Reetronrl.0.11t 1. What gn heat Input rate of roe hewer? (Regulation r.c.l 2 Dem thesaurus awl., a t lb/mm.0heat input? (Regulation onh....a. anaxeamanan6, Part e.:etion u.ud 3. Dm the,anrceeecharaewmwute matter In teems,therarroma equ on PE-ns/Pal""1(Regulation l, Sectlon Meta,. and Regulation e, Pan e, ,14 1. Is the natural gas Med heater Warted at an eilsting Mullin/that Is [Imager( 5552major soiree 5(202 as listed In Regula110572atlan =AM (Regulation 0 Raglan VIAL) a. Does the t lgas Sired heater have unmmmlid actual emissions of Non equal tow grater.. s teat Meeulatlan'Secant, vtn.0.1.1 NSRS Analysis 1. gees Me natural gas fined (water have a maximum reign heal n3ut catic5r of as megawatts (Nw)ls0o At3atu/nrlwless. him pewee Manutegualto2.2 an,/ 105Nragtu/2,/2lgag202/51/ 2. Does the natumlea,frrd heaterhave; magamum deign heat Inoutowrny greater than 29 megawatt lNWluaouNetumrltlge0_.0hlall Subpart Aaewrtingand w�mleepin eegormmeM, 1. Did cartstructIon, dmoton,o reconstruction &Ms steam genererngunrtcommelmafierlune 19, 1566] 1460.40bpll 2. Com Me natural gas fret! heater have a potental soz errassfen mte 64 '5(1 (43313140817 Ilea Input orles1(362.6273((4)( 3. Ord Me fealle commerce construction monsinelener mdmotbn after Febme, 1e, a403]feao.0614,110 Nowsmmlerds 4, Dem Me natural gas fire.sater haw neatS. Dom Me Imatermeel aff &Me fallowing mi;i432,7(p.,0 73 MN, (2.34 MMet um,l or Its a 1460.52413() 3>. Cambmt, alone or M oaablmtloe, any natural ps,r.iluteal,c,residual 'Awns nnm¢en menmt af03 weight pecent rim 14.2,4131a11: aubfacltoa federally 1d„rcmbleapwreme62 eminng operationd the affected f6191 to theh6ngd natural pa. amulee4I,and/o relaualal with a nhlv§en comsat of 0.3o, Pre ercent or less anaumm 600.(3nan.r 3)(5(( dfacilnvtoa rm„wnmamwal awertvfaaterxlo percent erle.farnatual gaa.alzmia1eat and residual oil wnna nitmg cement w3( 84 percent or im,14s4.aan 41411 e. OHMe affected mty c�mmerce mnstmmm, remercllen recalnmtwn .4.'1a/09,19970 060.4,4111) Is the natural gas ',red erzaa..t e.,enf requirement 460 operation wtMfealty toan annual mmalynct2,ef10 percent (0.1.orless for 7. coal,oll, encl natural as lRa hare)] 1464.66401111, e. Dem the ueplianfi�neates naewar heat release rate and combust mammal gas ordlatnlate ell In exams permm of the n Input ma3dav ug average from the MMwnren,.fall 4.5 4642433.) 11- standard for sulfur dioad. Ism, §.0.46aal or21I.03 IN end or N.snderd for nitrogen odaas.NO.. 4.0.456 -compliance and performance tort methods and procedures.. sulfur amema 460.45b-Dniwon monnonngforsuxur dlodd. 460.4 naag.moera.. 4ov.46b-9epamngand r.mrdb.gn w amaru•• MAR Analysis 6a6e, rue 63.5ubwn K4PROD0up, N6INI.1m Mafe,.sowws. Industrial mmmar.I.L and Institutional Boilers 3(M pmmp. Hover. 1, Is Me Mater ',valor source .](463,661 1. on14631]a501bl,o50erMm lon1463.]a471(3of ere aflerlu . 3. Is the Mat Input ms,' less Man orequal to 3 M M etu/n,] 1463.75001.11 mm 6. Is Me Mat Input mead, greater Mani WOW. but less then ereouel taro MASI,. I6mns0u(ep 363,555(.(.66 Table3-wort pima0(..60,3 463.'76101.1-Idbl repwmmemsro vlsting source.16.7510',Mr new source 4e3.7515(NI•subsevuem tests, fuel analysis oreneum 463.7330 b, ad lfl-oemn aratmg MMl compliance 463,535(>,(ml and (a11131 0,3-73strnmgw((mwas16(..(ence 463.1su (al. roe far anim or a - far nswL 1.l. la N11, d61. ep 6 Nal -42(19,64614 463.5564 (al, L kl, Id11l,.o31..meMns 463,393(a).01111•d14and 63.7560 fa),lbl>d lcl-eemrelln.plry Disclaimer Ms ...anent assists operators mlh determining bilityof certain repairemnls ago Clean Air Ant its implementing regulations, ands.Quliy Canon/ Commission regOations, Ms document is riots e or regulation, and the analysis i1 omelets may not superb a partkularsi 19305 based Lunn the Madrigal lasts and secures fences. Thls document sloes not F60232r06233fNelr any law, rags/akin, era, other legally beide,g seNdamme amisrnl'repy enMeaabre. coIna event of 52y contac10.76634 ere l6(0116ge of ma document ad the language or the Clean Arest, its implementing mutations, anlea-Quality Control Commission regulations, ulations the language eft statute or regulatonw➢I control The use ofnon-mandel72 language such as lecomend"rreY."thud; end'un,' is Wended CD interpretarov and recommendations. Mandalay Mrmia...estr 2 ea "muse 'restart are intended to describe controlling racurameints Ina terms',Msg.'s An Act and AN Quality Control Commission regulations, but this document aces not establish legaly binding requiems. m and of "Meg Diesel Engine - Preliminary Analysis Facility Equipment ID: 123 9F85-0.11, Attainment/Non-Attainment: Non-Attainmen Mfg Date: TBD. Date of original entry to Colorado: NSPS IIII applicable? Yes Engine Specifications Make: TBD Model: TBD SN: TB©. HP• 268 Fuel usage (gal/hr): 13.693431 Fuel usage (gal/yr - Permit): 3423.3577 Fuel usage (gal/yr - PTE): 3423.3577 Brake Specific Fuel Consumption: Emission Factors Units Diesel Fuel Properties 0.137 M M Btu/gal 0.0015 Sulfur Content (% wgt) Conversion Factors 1 gram = 0.0022 lb 1 ton = 2000 lb Req. usage limit (hrs): 1250 250 PTE usage (hrs): 7000.00 Btu/HP-hr Source NOx: 6.031 Ib/HP-hr AP 43 Table 3.3-1 SOx: 0.00205 lei/HP-hr AP"43 Table 3.3-1 VOC• 0.0{247 P -hr AP 43 Table 3.3-1. CO: 0.00668.. lb/HP-hr AP 43 Table 3.3 PM10: 0.0022 tb/HP-hr AP 43 Table 3 Emisson Totals (Permit Limits): NOx: 1.0385 SOx: 0.068675 VOC: 0.082745 CO: 0.22378 PM10: 0.0737 Emission Totals (PTE): NOx: 1.0385 SOx: 0.068675 VOC: 0.082745 ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr ton/yr Emission Totals (lb/hr): NOx: 8.308 SOx: 0.5494 VOC: 0.66196 CO: 1.79024 PM10: 0.5896 CO: 0.22378 ton/yr PM10:0.0737 ton/yr Emission Factors for inventory (lb/1000 gal): NOx: 606.7142856 SOx: 40.12142856 VOC: 48.34142856 CO: 130.7371428 P M10: 43.05714285 Emission Factors for permits (lb/gal): NOx: 0.606714286 SOx: 0.040121429 VOC: 0.048341429 CO: 0.130737143 PM10: 10: 0.043O57143 Additional comments: Permit number: Date issued: Issued to: rol Division h & Environment CONSTRUCTION PERMIT 18WE0031 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Elevation Midstream, LLC Buffalo Compressor Station 123/9F86 SEC 31 T5N R66W Weld County Natural Gas Compressor Station Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description D-1 001 One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: TBD) with a design capacity of 180 MMscf per day. This emissions unit is equipped with one (1) Make and model TBD electric driven glycol pump with a design capacity of 30 gallons per minute. This unit is equipped with a flash tank, electric reboiler, still vent, and a condenser. Emissions from the still vent are routed to an air-cooled condenser and then to an enclosed flare. Emissions from the flash tank are routed directly to an enclosed flare. SC -1 002 One (1) condensate surge control pressurized process vessel Enclosed Flare D-2 004 One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: TBD) with a design capacity of 180 MMscf per day. This emissions unit is equipped with one (1) Make and model TBD electric driven glycol pump with a design capacity of 30 gallons per minute. This unit is equipped with a flash tank, electric reboiler, still vent, and a condenser. Emissions from the still vent are routed to an air-cooled condenser and then to an enclosed flare. Emissions from the flash tank are routed directly to an enclosed flare. Point 001 £t 004: The glycol pump may be replaced with another pump of the same design capacity in accordance with the provisions of the Alternate Operating Scenario (AOS) included in this permit. COLORADO Air Pollution Control Division De Dartrnent of P:41,lie iieaich & onvtr emeett Page 1 of 13 This p it is g ntct to a -s andtlons E the Colorado Air Quality Control Commission and th olora. Alr , . �ion Pre =.Y and > n Fol Act ( R.S. 25-7-101 et seq), to the specific general terms �_ d con.A$ ion ncl�4 ed ln. his • " ume f and the f..,�.wing specific terms and conditions. REQ -S T c FO' 7 THORI;::: I N 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/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 (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. 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 002: Upon commencement of operation, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas vented from the pressurized surge vessel 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 E: 004: 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 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. EMISSION LIMITATIONS AND RECORDS 8. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Monthly Limits: 'COLORADO Air Pollution Control Division ui h i Em'hmruamnt Page 2 of 13 SC -1 002 D- 1 P .5 nds per Month x VOC CO Emission Type 5,779 1,202 Point 112 Point D-2 004 264 5,779 1,202 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 1,529 pounds per month. Facility -wide emissions of total hazardous air pollutants shall not exceed 3,568 pounds per month. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO D-1 001 --- 1.6 34.1 7.2 Point SC -1 002 --- --- 0.7 --- Point D-2 004 --- 1.6 34.1 7.2 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 9.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 21.0 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 Ueta'rrrissc ,i ct Ribt_ Page 3 of 13 9. 'oints t 1 � ! Compl'r with tq y ission . its in this permit shall be demonstrated by or higr on a monthly basis using the most recent w gay Holy and -cord•u operatio l values, including: dry gas throughput, lean ecir.�b atio eat- flash nk t •erature d pressure, wet gas inlet temperature, and we gas inl- • -ssu e " e ord opera Tonal valu-s, `-xcept for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 10. Points 001 & 004: On a monthly basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 11. 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 D-1 001 Still Vent: Enclosed Combustor VOC and HAP Flash Tank: Enclosed Combustor VOC and HAP SC -1 002 Enclosed Combustor VOC and HAP D-2 004 Still Vent: Enclosed Combustor VOC and HAP Flash Tank: Enclosed Combustor VOC and HAP PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) D-1 001 Dry Gas Throughput 65,700 MMscf/yr 5,580 MMscf/month SC -1 002 Natural Gas Vented 1.0 MMscf/yr 0.1 MMscf/month D-2 004 Dry Gas Throughput 65,700 MMscf/yr 5,580 MMscf/month The owner or operator sha l monitor monthly process rates based on the calendar month. The volume of dry gas throughput shall be measured by gas meter at the outlet of the dehydrator. 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. COLORADO Air Pollution Control Division par er5t ka;e;s `u•-.1rr�Y'J'=r�*r. Page 4 of 13 13. "'oints ,`a 1 hese � fi�hall b .'n led to maximum lean glycol circulation rate of 30 n rate shall be recorded weekly in a log ad_ ,vail. 'ae to the =vision for inspection upon request. Glycol moni ed • one of the Mowing methods: assuming maximum design ump rate, ing . "'flo e - , or re • g strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (Loot) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4) 14. Point 002: Upon commencement of operation, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the pressurized surge vessel 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. Point 002: No owner or operator of a smokeless flare orother flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) 17. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 18. Points 001 £t 004: These source are subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators; 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.H.1.) 19. Points 001 & 004: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2 General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.17; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other 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. 20. Points 001 a 004: The glycol dehydration units covered by this permit are 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 Air Pollution Control Division uvssr..nent Gf Public Heehn G eniirOrimet:I Page 5 of 13 as ationroduc $ • ,• perati g .'.. ubject trot qu F ement lle• ct r emi ions y, hyd arbons b the e o - co enser air d=.ttution co , natural gas compressor station, or gas - pursuant to Section XVII.D.4., shall reduce t least 95% on a rolling twelve-month basis rot equipment. 21. Points 001 Et 004: The glycol dehydration units at this facility are 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) ICOLORAD© Air Pollution Control Division 1 =J�pr�rsxnt at Rib$: Health E-svorrkrt Page 6 of 13 ,THHA 'hca equire ' nts r � Area Source �� Out The UA/UC boundary §6 . i`` ". plicabi designation of affected source §63. 60 (f) e ow or operator r an affected major source shall achieve compliance pr. .' " subpart . """' `dates specified in paragraphs (f)(1) and (f)(2) of this section. The owner or operator of an affected area source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(3) through (f)(6) of this section. §63.764 - General Standards §63.764 (d)(2) -Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with the provisions specified in paragraphs (d)(2(i) through (iii) of this section. §63.764 (d)(2)(i) - Determine the optimum glycol circulation rate using the following equation: Lon 3.0 gal TEG* F * (I - 0) =1.15* lbbHZ0 24hr/day Where: LOPT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) 0 = Outlet water content (lb/MMSCF) 3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/lbH2O) 1.15 = Adjustment factor included for a margin of safety. §63.764 (d)(2)(ii) - Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with paragraph (d)(2)(i) of this section. If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate determined in accordance with paragraph (d)(2)(i), the owner or operator must calculate an alternate circulation rate using GRI-GLYCalcTM, Version 3.0 or higher. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate and submit this documentation with the initial notification in accordance with §63.775(c)(7). §63.764 (d)(2)(iii) - Maintain a record of the determination specified in paragraph (d)(2)(ii) in accordance with the requirements in §63.774(f) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with paragraph (d)(2)(i) or (ii) of this section and submit the information specified under §63.775(c)(7)(ii) through (v). §63.774 - Recordkeeping Requirements §63.774 (b) - Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section §63.774 (b)(1) §63.774 (b)(1) - The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. §63.774 (b)(1)(i) - All applicable records shall be maintained in such a manner that they can be readily accessed. §63.774 (b)(1)(ii) - The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request. §63.774 (b)(1)(iii) - The remaining 4 years of records may be retained offsite. §63.774 (b)(1)(iv) - Records may be maintained in hard copy or computer -readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche. §63.774 (f) - The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. COLORADO Air Pollution Control Division Doper ^u..nt of Puba Hea; t & Frnvnrr:Kic Page 7 of 13 T HH Ar Require ica _; _� � nts % Area Source � �� °' `" j y Out e UA/UC boundary tiz §63 5 (c) cept provided in . Pagraph (c)(8), each owner or operator of an area ub1 fr,.art shal ;-'t the information listed in paragraph (c)(1) of this section. If the source is located within a UA plus offset and UC boundary, the owner or operator shall also submit the information listed in paragraphs (c)(2) through (6) of this section. If the source is not located within any UA plus offset and UC boundaries, the owner or operator shall also submit the information listed within paragraph (c)(7). §63.775 (c)(1) - The initial notifications required under §63.9(b)(2) not later than January 3, 2008. In addition to submitting your initial notification to the addressees specified under §63.9(a), you must also submit a copy of the initial notification to EPA's Office of Air Quality Planning and Standards. Send your notification via e-mail to CCG-ONG®EPA.GOV or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Coatings and Chemicals Group (E143-01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711. §63.775 (c)(7) - The information listed in paragraphs (c)(1)(i) through (v) of this section. This information shall be submitted with the initial notification. §63.775 (c)(7)(i) - Documentation of the sources location relative to the nearest UA plus offset and UC boundaries. This informdtion shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the names of the nearest urban cluster with 10,000 people or more and nearest urbanized area. §63.775 (c)(7)(ii) - Calculation of the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i). §63.775 - Reporting §63.775 (c)(7)(iii) - If applicable, documentation of the alternate glycol circulation rate Requirements calculated using GRI-GLYCalcTM, Version 3.0 or higher and documentation stating why the TEG dehydration unit must operate using the alternate glycol circulation rate. §63.775 (c)(7)(iv) - The name of the manufacturer and the model number of the glycol circulation pump(s) in operation. §63.775 (c)(7)(v) - Statement by a responsible official, with that official's name, title, and signature, certifying that the facility will always operate the glycol dehydration unit using the optimum circulation rate determined in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. §63.775 (f) - Notification of process change. Whenever a process change is made, or a change in any of the information submitted in the Notification of Compliance Status Report, the owner or operator shall submit a report within 180 days after the process change is made or as a part of the next Periodic Report as required under paragraph (e) of this section, whichever is sooner. The report shall include: §63.775 (f)(1) - A brief description of the process change; §63.775 (f)(2) - A description of any modification to standard procedures or quality assurance procedures §63.775 (f)(3) - Revisions to any of the information reported in the original Notification of Compliance Status Report under paragraph (d) of this section; and §63.775 (f)(4) - Information required by the Notification of Compliance Status Report under paragraph (d) of this section for changes involving the addition of processes or equipment. OPERATING Et MAINTENANCE REQUIREMENTS 22. Points 001, 002, and 004: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the COLORADO Air Pollution Control Division Dep,;;rif rd Pits#,z %t I£01. tez Page 8 of 13 ongoing basis with the requirements of this Division approval prior to implementation. Initial Testing Requirements 23. Points 001 £t 004: 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 results to the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section'II.E.) Periodic Testing Requirements 24. Points 001 £t 004: 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 25. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30t'' whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NOX per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: 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 26. 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 COLORADO Mr Pollution Control Division r. peri;aenl ,.Y Public Fl uth i. E;mirnnr:ten:t Page 9 of 13 ransfer of ownership and the submittal of a 27 f this, rmispe:-ical statthat al autho F tion has been granted, then the remainder con licise, t ance 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. 28. 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. 29. 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. 30. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 31. 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. 32. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Elevation Midstream €COLORADO Air Pollution Control Division t. potinent ,t putt 4eWth ereirormem Page 10 of 13 1) Th .;,, is-.:•uire•• •:'fees tproc- ing time for this permit. An invoice for these fe:� .wlll • ssu�, of ..;, they ermi a issu---• The per t holder shall pay the invoice within 30 days of nvilur ; he in will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (Ib/yr) Controlled Emissions (lb/yr) D-1 001 Benzene 71432 175,048 8,752 Toluene 108883 120,934 6,047 Ethylbenzene 100414 18,658 933 Xylenes 1330207 71,892 3,595 n -Hexane 110543 20,852 1,043 SC -1 002 Benzene 71432 272 14 n -Hexane 110543 417 21 D-2 004 Benzene 71432 175,048 8,752 Toluene 108883 120,934 6,047 Ethylbenzene 100414 18,658 933 Xylenes 1330207 71,892 3,595 n -Hexane 110543 20,852 1,043 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) Points 001 Et 004: The emissionlevels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Controlled emissions are based on an enclosed combustor control efficiency of 95%. Total actual flash tank and still vent combustion emissions are based on the sum of the emissions for the still vent primary control and flash tank primary control. Total combustion emissions are based on the following emission factors: COLORADO Air Pollution Control Division paexnem of Rd511; HeaEt' & erro,3mAent Page 11 of 13 Po NOx o"'`trolled Em ion Facto Btu W - Gas Combusted Source 0.068 AP -42 CO 0.310 AP -42 Note: The combustion emission are based on a heating value of 1590 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the waste gas flow from the regenerator overheads stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this Flash Tank Primary Control: CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Waste Gas Combusted Source NOx 0.068 AP -42 CO 0.310 AP -42 Note: The combustion emission are based on a heating value of 1497 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the waste gas flow from the flash tank off -gas stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this control device. Point 002: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source NOx 102.16 102.16 AP -42 CO 465.73 465.73 AP -42 VOC 27,137.44 1,356.87 Promax 71432 Benzene 280.24 14.01 Promax 110543 n -Hexane 429.42 21.47 Promax Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692- 3150. 7) This 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 facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC and HAP NANSR Synthetic Minor Source of: VOC =COLORADO 3 Air Pollution Control Division pr:me t- f Pub 3 tea R 3 em;nor;rnxr' Page 12 of 13 http://ecfr.gpoaccess.gov/ tronic Code of Federal Regulations can be site liste. •e ow: 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 Alternative Operating Scenario for Glycol Pumps (Points 001 and 004) Points 001 £t 004: The electric glycol pumps may be replaced with another electric glycol pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. The maximum glycol recirculation rate of a replacement pump shall not exceed the glycol recirculation rate as authorized in this permit. Points 001 £t 004: The owner or operator shall maintain a log on -site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. Points 001 a 004: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with alt terms and conditions of this construction permit. COLORADO IAir Pollution Control Division Pan+nrst sf p tb }tev k s l•`rnirenx l Page 13 of 13 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 available if 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: C Oc)t 4 AIRS ID Number: IZI /9 cKC/UQ [Leave blank unless APCD has already assigned a permit— and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: Elevation Midstream, LLC Badger Central Gathering Facility Section 31, Township 5N, Range 66W Mailing Address: (Include Zip Code) 370 17th Street, Suite 5300 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact, Kelli Cox Phone Number: (720) 354-4597 E -Mail Address2: kcox@extractionog.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. P\-\-\ctrnm\- Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO �e��M Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source ❑✓ 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 Et Motes: 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: Two identical stabilized oil IFR tanks liquid manifolded together For new or reconstructed sources, the projected start-up date is: TBD; construction late spring 2018 Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 weeks/year ❑ Exploration Et Production (E&P) site (] Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? o 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: TBD m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • D Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No t7 • Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 2I COLORADO ay..a..,n of Public Has.6 EnvlronrtuN Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amours 40.4l/a0. Condensate Throughput:• equested Annual Permit Limit4M (bbl/year) 21,900,000 (both tanks) From what year is the actual annual amount? Average API gravity of sales oil: TBD Tank design: ❑ Fixed roof degrees ❑ Internal floating roof RVP of sales oil: TBD ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage` Vessels in Storage Tank , otal Volume of orage Tank (bbl) Installation Date of Most Recent Storage Vessel m Storage Tank (month/year)_` )ate of First Production (month/year) 21751 21751 and 21752 are liquid 38,700 TBD TBD 21752 manifolded with shut down 38,700 TBD TBD valves at inlet/outlet each tank Wells Serviced by this Storage Tank'or,Tank Battery5 (E&P Sites Only) K API Number - .. Name of Well 1 Newly Report' ed Well`? - - ■ - - ❑ - - ❑ 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. b The EaP 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 eographicalCoordinate_ Latitude/Longitude wUTIVIJ. 40.024/ -104.931 -, Operator.`, Stack , ID"No''. i DischH arge eight Above Ground Level (feet) , • �` Temp. (°F) , Flow, Rate (ACFM)'° Velocity (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap NA; IFR tanks not designed to vent Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): NA; IFR tanks not designed to vent Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 IAyCOtORA00 fir, Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit g 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. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: % Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: Btu/scf scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: VOCs, organic HAPs Description: internal floating roofs Control Efficiency Requested: NA Section 7 -Gas/Liquids Separation Technology Information (E&P 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 4 COLORADO oepem w Amin Waal Envvunmem Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit A 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 = Pb1tutant � � � ` � Descn�tton of Lontrol a ocl s ti yeral( Re uesstted eri of Efficiency, reduction-inemtssrons w- VOC Internal floating roof NA NOx CO RAPS Internal floating roof NA Other: From what year is the following reported actual annual emissions data? w ; _. Criteria Pollutant -Emissions Invento, R a - ,: Pollutant' "� p Emission Factor j`� � ' Actual Annual f Emissio s -t �r� x `om R guested Annual Permit, , on -- Emission L�tmtt s) 1, xR� Uncontrolled Basis pmts Source (�'42> Mfg etc) Uncontrolled so Emissions ; (Tons/year) Controlled n 7 Em s5 ons.� (Tonslyedrr) Uncontrolled missions?. (Tons/yearj - Controlled s:s. ,,,4F f7 onyear) VOC NA Tanks 4.09d 2.72 4.07 2.72 4.07 - NOx NA CO NA i-,-;.,,.=',-,,-N :;; has ,�w Nor GritsReportable P.-oliutant, Emissions Inventory Chemical Name 4 r vF is '^ x � Chemxal�- hh . 1s -64C' Abstract Service (CAS) Number -s �.�! A , npY .4.,-, �a M2` �_ �� +,Emission Factor y „ d P'^%'"" i`:-. . - cttuual Annual Emissions s v � � d Unco��ntrolled ` �=� : Unit ' a S t rce (APP --42 Mf `etc g ) Pa'�_` Uncontrolled r.r` Emissions P (oundsiyear} ,. Con oiled Emissions � (Pounds/year). .. Benzene 71432 Tanks 4.09d Toluene 108883 and Ethylbenzene 100414 weight fraction Xylene 1330207 from hlYSYS n -Hexane 110543 for all 2,2,4 Trimethylpentane 540841 HAPs 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. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5 COLORADO Department el Pubtic Hea4N b Envirenmev 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 compliance with each condition of the applicable General Permit. 4/13/2018 Sigciature of Legally Authorized Person (not a vendor or consultant) Date Kelli Cox Air Quality Coordinator 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 $152.90 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-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-2O5 - Condensate Storage Tank(s) APEN - Revision 07/2017 6 COLORADO ,b Pablic HuiC1 b Envbenme.0 Ruo.pa. cel 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 available if 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.Rov/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: (z3 I GIR 'SI CO 3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Elevation Midstream, LLC Site Name: Badger Central Gathering Facility Site Location Site Location: Section 31, Township 5N, Range 66W County: Weld Mailing Address: (Include Zip Code) 370 17th Street, Suite 5300 Denver, CO 80202 NAICS or SIC Code: 1321 Permit Contact: Kelli Cox Phone Number: (720) 354-4597 E -Mail Address2: kcox@extractionog.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. NO.rtr,ir 1O y c) (pH Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1 I 'COLORADO. u.n.md Piet" Raul EmbeemaN 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 ❑✓ 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 £t,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: Two identical off -spec oil tanks liquid manifolded together For new or reconstructed sources, the projected start-up date is: TBD; construction late spring 2018 Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑ Exploration a Production (E&P) site weeks/year 0 Midstream or Downstream (non EaP) site Will this equipment be operated in any NAAQS nonattainment area? p Yes • No Are Flash Emissions anticipated from these storage tanks? • Yes SI No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? 19 Yes ■ No If "yes", identify the stock tank gas -to -oil ratio: TBD m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • SI 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 pp COLORADO �ra�b� Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 4 - Storage Tank(s) Information ctual AnnuatAmount (tbUyear) Condensate Throughput: From what year is the actual annual amount? Average API gravity of sales oil: TBD degrees ❑ Internal floating roof Tank design: ❑✓ Fixed roof equested Annual Permit Limit4 (bbll year) 9,995,884 (both tanks) RVP of sales oil: TBD ❑ External floating roof Storage Tank ID 21851 #of Liquid Manifold Storage Vessels in Storage Tank 21851 and 21852 are liquid Total Volume of Storage Tank (bbl) 5,000 Installation Date of -Most, Recent. Storage Yessel ir Storage Tank'(month/year) TBD Date of First Production (month/year) TBD 21852 manifolded with shut down 5,000 TBD TBD valves at inlet/outlet each tank PI Number ells Serviced by this Storage Tank or"Tank Battery5' (E&P Sites,Only) - Newly Reported Well Name of Well: CI CI 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EEP 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 Geographical Coordinates Latitude/Longitude`or VTAV 40.024/ -104.931 Operator, Stack IDrNo. ' _ Discharge_Height :-- Ground'Level-(feet)` , Temp: (°F)- Flow Rate - �`(ACFAI) Velocity (ft/sect ECD-1 TBD Indicate the direction of the stack outlet: (check one) ❑ Upward El Downward ❑ Horizontal ❑ Upward with obstructing raincap El Other (describe): Will discharge through enclosed combustor, ECD-1 Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle El Other (describe): Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Will discharge through enclosed combustor, ECD-1 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 I A_ COLORADO �,.. of Public Permit Number: AIRS ID 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. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOCs, organic HAPs Rating: -250 (LHV) MMBtu/hr Type enclosed combustor Make/Model: Zeeco Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: 1400 of 95 99 % Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑✓ No Pilot Burner Rating: 1400-2230 (HHV) 3@-0.19 (LHV) Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (EEtP 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 4 , A® COLORADO i HeaHLbEnH�en�vea VOC Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit A 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 (or combined) control efficiency (% reduction): Description of Control Method(s)? • enclosed combustor Overall Requested Control. Efficiency (% reduction in emissions) 95 NOx CO HAPs enclosed combustor 95 Other: From what year is the following reported actual annual emissions data? Pollutant VOC NA Tanks 4.09d Uncontrolled Basis Criteria Pollutant__ Emissions Inventory Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Requested Annual Permit Emission Limit(s)4 Uncontrolled Emissions (Tons/year); Controlled Emissions (Tons/year) 205.12 300 (both tan ksy15.0 10.26 (both NOx 0.068 Ib/MMBtu AP -42 13.5 NA 042 0.4 (both tan CO 0.31 Ib/MMBtu AP -42 13.5 NA 0-561.82 (both tan tilot C iteria Reportable_Pollufan E'''''Mp,'-' - ' a��`ai adN7� "� 'v��c rnkae v l c �� SAP Icy (CAS) Number 6" Emtssiou Fac or x. ::41 tnfl3Enis.s _ ns� �bn t� toI d fir.. Units Source: (AP 2' Mfg. etc) VA o tro le micrREL . `(Paunds/year) . Cont 1 e - � Essions, mi `(Pounds/year)`3`* Benzene 71432 Tanks 4.09d Toluene 108883 and Ethylbenzene 100414 weight fraction Xylene 1330207 from HYSYS n -Hexane 110543 for all 2,2,4-540841 Trimethylpentane HAPs 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. tanks) ks)— ks) - Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5 I ,COLORADO Ay I De(ynmcn!nIPabt. 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 compliance with each condition of the applicable General Permit. 4/13/2018 Signture of Legally Authorized Person (not a vendor or consultant) Date Kelli Cox Air Quality Coordinator 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 $152.90 and the General Permit 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 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 - Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO - 6IA°"'""`ate i it..nw b EnNnamart� &&ucmL 61111t 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 available if 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: k,VCWz.p AIRS ID Number: f C.," /9 '5/ 0C> lil [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Site Location: Elevation Midstream, LLC Badger Central Gathering Facility Site Location Section 31, Township 5N, Range 66W County: Weld Mailing Address: (Include Zip Code) 370 17th Street, Suite 5300 Denver, CO 80202 NAICS or SIC Code: 1321 Permit Contact: Kelli Cox Phone Number: (720) 354-4597 E -Mail Address2: kcox@extractionog.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. A"\--kruY\rAtf\k- lv 310VCoS COLORADO Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1 I A®I° Hubbb Enwhement 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 El Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 0 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) El Change in equipment ❑ Change company name El Change permit limit ❑ Transfer of ownership3 El Other (describe below) OR 0 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 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: For existing sources, operation began on: Two identical trucked in oil tanks liquid manifolded together For new or reconstructed sources, the projected start-up date is: TBD; construction late spring 2018 Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑ Exploration Et Production (EEtP) site weeks/year 0 Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ■ No Are Flash Emissions anticipated from these storage tanks? IN Yes 0 No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? 0 Yes ■ No If "yes", identify the stock tank gas -to -oil ratio: TBD m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)• 805 series rules? If so, submit Form APCD-105. Yes No 0 Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No 0 ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 ,COLORADO 2 I AVY!I��` N Ab FnH�oe�N Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbU y"ear) Condensate Throughput: From what year is the actual annual amount? Average API gravity of sales oil: TBD degrees ❑ Internal floating roof Tank design: ❑r Fixed roof Requested Annual Permit Limit4 (bb(/year) 1,825,000 (both tanks) RVP of sales oil: TBD ❑ External floating roof Storage Tank ID '# of.Liquid Manifold Storage Vessels in Storage Tank Total;;Volume of Storage Tank (bbl) llation Date of Most Insta: Recent Storage Vessel in '. Storage Tank (month/year) Date_ of First _ Production (months/year) 21901 21901 and 21902 are liquid 750 TBD TBD 21902 manifolded with shut down 750 TBD TBD valves at inlet/outlet each tank API Number Wells Serviced by this Storage Tank or. Tank Batte 5 (EEP Sites Ont Y � rY Yl ' Newly Reported Well aine of Well -f 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The E&P 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 eographical Coordinate Latitude/Longitude orUTM 40.024/ -104.931 Operator Stack , ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM). Velocity_, (ft/sec) ECD-1 TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Will discharge through enclosed combustor, ECD-1 ❑ Upward ❑ Horizontal Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Will discharge through enclosed combustor, ECD-1 <a� Form APCD-2O5 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 I COLORADO N e(_vnme,u t P.Mlc Envuoenrtnt Permit Number: AIRS ID 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. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): % ❑ Combustion Device: Pollutants Controlled: VOCs, organic HAPs Rating: -250 (LHV) MMBtu/hr Make/Model: Zeeco Type enclosed combustor Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 99 % Minimum Temperature: 1400 Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑✓ No Pilot Burner Rating: 1400-2230 (HHV) 3@-0.19 (LHV) Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E6tP 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 4 I A® 'COLORADO oepne ene d wbbc Enrbonmrnl Benzene 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 (or combined) control efficiency (% reduction): enclosed combustor VOC verall ,Requested : Contra Efficiency o reduction in emissions 95 NOx CO HAPs enclosed combustor 95 Other: From what year is the following reported actual annual emissions data? NA Tanks 4.09d Uncontrolled Basis ritena.Pollutant Emissions Inventory...;'. ctualAnnual Emission nco`ntrolled Emissions ons/year') 36.1'1 52.9 (both ta VOC nks)°2.6 1.81 (both NOx 0.068 Ib/MMBtu AP -42 13.5 NA 0.02 0.07 (both ta CO 0.31 Ib/MMBtu AP -42 13.5 NA 0.10 0.32 (both ta on Criteriia Reportable Pollutant Emissions; Inventor emical abstract_ Service (CAS)" Number mission' Factor:' Tanks 4.09d ctual Annual Emissions, ncont'blle missions b oundslyear) 71432 Toluene 108883 and Ethylbenzene 100414 weight fraction Xylene 1330207 from HYSYS n -Hexane 110543 for all 2,2,4- Trimethylpentane 540841 HAPs 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. tanks)' ks) ' ks) Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5 I A_ COLORADO Department of Pun, Hemline Em:roewrnt 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 compliance with each condition of the applicable General Permit. 4/13/2018 Signature of Legally Authorized Person (not a vendor or consultant) Kelli Cox Date Air Quality Coordinator Name (print) Title Check the appropriate box to request a copy of the: 2 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 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-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.cokorado.gov/cdphe/apcd Form APCD-205 --Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO 6 ii�� ii w.en u cnv�a�ee n &Laval 4110 Produced Water Storage Tank(s) APEN - Form APCD-207 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 produced water 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, condensate storage tanks, hydrocarbon liquid loading, 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 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: I � W G c)O7 AIRS ID Number: lZJ 19 TS / OS [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Elevation Midstream, LLC Site Name: Badger Central Gathering Facility Site Location Site Location: Section 31, Township 5N, Range 66W County: Weld Mailing Address: (Include Zip Code) 370 17th Street, Suite 5300 Denver, CO 80202 NAICS or SIC Code: 1321 Permit Contact: Kelli Cox Phone Number: (720) 354-4597 E -Mail Address2: kcox@extractionog.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. N4ctavvv4- io 3�g0 HG Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 COLORADO 1IAy Ruhr b Enrhenmmt Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source ✓❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ 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 El 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 O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t 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: For new or reconstructed sources, the projected start-up date is: TBD; construction late spring 2018 Two identical produced water tanks liquid manifolded together Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑ Exploration Et Production (E&P) site weeks/year 0 Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ■ No Are Flash Emissions anticipated from these storage tanks? • Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No II D Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? • Yes • No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • FA Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No 0 • Form APCD-2O7 - Produced Water Storage Tank(s) APEN - Revision 07/2017 21. AV COLORADO D.puun.nt n+ PaMlc Waft 6 EmtnnmwN Permit Number: AIRS ID Number: / I [Leave blank unless APCD has already assigned a permit n and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount, (bbliyear) - Produced Water Throughput: Requested Annual. Permit Limit4 (bbl/year) . 18,250,000 (both tanks) From what year is the actual annual amount? Tank design: ❑ Fixed roof ❑ Internal floating roof ❑ External floating roof Storage Tank ID ` # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (monthlyear) Date of First Production (monthlyear) 41751 41751 & 41752 are liquid 24,000 TBD TBD 41752 manifolded with shut down valves 24,000 TBD TBD at inlet/outlet each tank Wells Serviced by this Storage Tank or Tank Battery(E&P„Sites On y) API' Number ame of.Well Newly Reported Well 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 Geographical Coordinates (Latitude/Longitude or UTM)_, 40.024/ -104.931 Operator Stack ID No. arge harge Height Above Disch Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD-1 TBD Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Horizontal ❑ Upward with obstructing raincap ❑ Other (describe): Will discharge through enclosed combustor, ECD-1 Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Will discharge through enclosed combustor, ECD-1 Form APCD-2O7 - Produced Water Storage Tank(s) APEN - Revision 07/2017 3 1 COLORADO b Gv(.antoma Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information 0 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: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % Combustion El Device: Pollutants Controlled: VOCs, organic HAPs Rating: —250 (LHV) MMBtu/hr Type: enclosed combustor Make/Model: Zeeco Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 99 % Minimum Temperature: 1400 of Waste Gas Heat Content: 1400-2230 (HHV) Btu /scf Constant Pilot Light: ❑ Yes ✓❑ No Pilot Burner Rating: 3@-0.19 (LHV) MMBtu/hr ❑ Closed Loop System Description of the closed loop system: 0 Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E&P 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-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 4 L Y COLORADO oR..mo,�dv,au� NubAb&a[roemt�u VOC Permit Number: MRS ID Number: [Leave blank unless APCD has already assigned a permit A 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 (or combined) control efficiency (% reduction): Description of Control Methods enclosed combustor Overall Requested; Contro Efficiency ; (°/e reduction in':emissions, 95 NO5 CO HAPs enclosed combustor 95 Other: From what year is the following reported actual annual emissions data? riteria.Pollutant Emissions Inventory,. VOC Flash liberation/TANKS nested Annual Permit:; Emission Limt(s)4 ncontrollei Emissions onsiyear) 652 -75 653.2 (both t anks)-'32.6'] 32.7 (b NOx 0.068 lb/MMBtu AP -42 13.5 NA oth tanks)' 2442 2.0i CO 0.31 lb/MMBtu AP -42 13.5 NA 92 9.22 TANKS 4.09d Benzene ion=Criteria Reportable Pollutant Emissions Inverto 71432 issiory. ,acto1i ctual nnual Emissions Toluene 108883 and Ethylbenzene Xylene 100414 1330207 weight fraction from HYSYS n -Hexane 110543 for all 2,2,4- Trimethylpentane 540841 HAPs 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water 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. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 ,COLORADO 5 I� ocan,..emof Pub, hc.wn a...ormem 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 GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 4/13/2018 Sigature of LegFally Authorized Person (not a vendor or consultant) Kelli Cox Date Air Quality Coordinator Name (print) Title Check the appropriate box to request a copy of the: E 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 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-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 -- - -- ,,COLORADO n.9.a.edwsric Form APCD-2O7 - Produced.. Water Storage Tank(s) APEN - Revision 07/2017 6 I . ,,...,,b�.,.�...� Rtaioul 6(1./IT 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 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: WG.UU� AIRS ID Number: `Z /9CY" / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: D-1 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Namel: Site Name: Elevation Midstream, LLC Buffalo Compressor Station Site Location: Section 31, Township 5N, Range 66W Mailing Address: (Include Zip code) 370 17th Street, Suite 5300 Denver, CO 80202 E -Mail Address2: kcox@extractionog.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Kelli Cox Phone Number: (720) 354-4597 IPlease 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. Nr\ca.L'r-yJ - kcd(.0 Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 1 I A® COLORADO Department of PobUs Hui. B. Env[re uesm 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) ❑ Change fuel or equipment ❑ Change company name 0 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: TEG dehydration unit for water removal Facility equipment Identification: D-1 - TEG Dehydration Unit For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: TBD / / O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 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 days/week Yes Yes Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 2 I weeks/year No No COLORADO Permit Number: AIRS ID Number: f / (Leave blank unless APCO has already assigned a permit # and AIRS IDI Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: TBD TBD Ethylene Glycol (EG) Glycol Pump Drive: O Electric Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Lean Glycol Water Content: ❑ Gas Model Number: TBD Reboiler Rating: 2.50 ❑ (DEG) DiEthylene Glycol If Gas, injection pump ratio: MMBTU/hr TriEthylene Glycol (TEG) # of pumps: Max: 30 1.0 Wt.% Requested: 30 Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 180 MMSCF/day Requested: 65,700 MMSCF/year Actual: MMSCF/year Inlet Gas: Water Content: Flash Tank: Cold Separator: Pressure: Wet Gas: Pressure: 100 Pressure: 1,000 9q9 psig Ib/MMSCF psig psig Stripping Gas: (check one) Q None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Temperature: 425- 13° ' F El Saturated Temperature: Temperature: Dry gas: 125 6.7 'F 'F lb/MMSCF O NA ✓❑ NA Additional Required Information: El Attach a Process Flow Diagram Attach GRI-GLYCaIc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) I Attach the extended gas analysis (including BTEX Et n•Hexane, temperature, and pressure) Form APCD•2O2 Glycol Dehydration Unit APEN • Revision 02/2017 p COLORADO 3(m I-: Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit d and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude. or UTM) 40.0236 / -104.931064 Operator :: "Stack ID Hoe Discharge Height Above Ground Level (Feet) . Temp, (�F) Flow Rate (ACFM) Velocity " (ft/sec) D-1 25 Indicate the direction of the stack outlet: (check one) O Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap ❑ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 4 I AV COLORADO Depamnem of PuhL] Heal. Er Emhonmmi Permit Number: AIRS ID Number: I f [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information Used for control of: -..601p f " Type: _Tie Make/Model: - El Condenser: UtitCifirCK Maximum Temp 150 Average Temp ..-Th$' Requested Control Efficiency O VDU: Used for control of: Size: Requested Control Efficiency VRU Downtime or Bypassed Make /Model: ❑ Combustion Device: Used for control of: Flash Tank Off Gas, Still Vent Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: IES / IES-48-O2 Requested Control Efficiency: 95.0 Manufacturer Guaranteed Control Efficiency 99.0+ Minimum Temperature: Waste Gas Heat Content Constant Pilot light: r❑ Yes O No Pilot burner Rating 1,500 0.16 Btu/scf MMBtu/hr Closed O Loop System: Used for control of: Description: System Downtime ❑ Other: Used for control of: Description: Control Efficiency Requested Form APCD-202 Glycol Dehydration Unit APEN • Revision 0212O17 5 COLORADO o.w*�e+r.we PM Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit k 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? QQ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Requested Control Efficiency, (!G reduction in emissions) SC ( NO„ CO V0C Ccrtttencer! Enclosed Combustor 95% tlAPs Condoner / Enclosed Combustor 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: (Use the data reported In Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor-._ Emission Factor Units - Emission Factor Source (4p-.42 May: etc) 5 F ,z ,; l on : quested Annual Permit t Fmissioinilimit(s) 'P Uncontrolled .' (Tons/year) Controlled - (Tons/year) : Uncontrolled' _ (Tonstyear) " Controlled (ronslyear) PM SO,. NO. 0.068 ib/MMBtu AP -42 / s-8 - /_ .5 rR 1.54 1.54 - CO 0.31 lb/MIVIBtu AP -42 7. /9 - 1., lc( 7.00 7.00 VOC tall Ib/MMscf GLYCaIc 680, 36 3'-f. oz ' 1,009.75 31.44 30.74 Benzene Z. big Ib/MMscf GLYCalc 8 7 -CZ - 6f. '5 - 109.67- 1.62 3.94 • Toluene I. g lb/MMscf GLYCalc 60. yam- 3, O2 - 68.82 2.30 i 2.10 Ethylbenzene C? Ib/MMscf GLYCalc q. 23 ' 6. e/ 7-- — 17.39• 0.42 2B 0.53 Xylenes /. C9 lb/MMscf GLYCalc 3,c qS - /, gp - 0.76 1.05 —34..;8 n -Hexane 0,32 Ib/MMscf GLYCalc /0. Y3 - 0 . S2 ' 0.04 0.39 -11.71 2,2,4- O.OZ,3� Trimethylpentane ^^- Wit- Ibfti/iMsc€ GLYCaIc 0.0 ( d_ oct c. 0.05 0.092 Other: 4 Requested values will become permit limitations. Requested limits) 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-2O2 Glycol Dehydration Unit APEN - Revision 02/2017 6 AV COLORADO 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. 4/12/2018 Si nature of egally Authorized Person (not a vendor or consultant) Date Kelli Cox Air Quality Coordinator 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) 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 AV COLORADO Department mpnaic Heal,. Er Emfeonmenl 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/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: igvw&oo 3 AIRS ID Number: ( Z 3 /'1F '(/ o p2, [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: SC -1 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Elevation Midstream, LLC Site Name: Buffalo Compressor Station Site Location: Section 31, Township 5N, Range 66W Mailing Address: (Include Zip code) 370 17th Street, Suite 5300 Denver, CO 80202 E -Mail Address2: kcox@extractionog.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Kelli Cox Phone Number: (720) 354-4597 '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-211 - Natural Gas Venting APEN - Rev 03/2017 378062 1AV COLORADO Demrcemeed of P k Na11Jl b EmNrunmeM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action El 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 0 Transfer of ownership3 0 Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: 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: Condensate Surge Control Process Vessel Venting emissions from condensate flashing For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: TBD / / ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 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 days/week weeks/year El Yes 0 No 0 Yes El No Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 pp� COLORADO AV 21 !DI i= V 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: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event ❑✓ Other Description: Condensate Surge Control Process Vessel If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? O Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑✓ No Maximum Vent 110.53 SCF/hr Vent Gas -1 500 BTU/SCF Requested: 0.97 MMSCF/year Actual: MMSCF/year Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: SC -1 overheads speciation was derived rom representative facility wide Promax lode'. The supporting stream report, long with the gas analysis used to levelop the Promax model, have been icluded with this application. Molecular Weight: VOC (mole %) 19.77 VOC (Weight %) 39.15 Benzene (mole %) 0.14 Benzene (Weight %) 0.40 Toluene (mole %) 0.05 Toluene (Weight %) 0.16 Ethytbenzene (mole %) 0.01 Ethylbenzene (Weight %) 0.02 Xylene (mole %) 0.01 Xylene (Weight %) 0.04 n -Hexane (mole %) 0.19 n -Hexane (Weight %) 0.62 2,2,4-Trimethylpentane (mole %) 0.001 2,2,4-Trimethylpentane (Weight %) 0.004 Additional Required Information: * ❑� Attach a representative gas analysis (including BTEX a n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 (COLORADO 3 I ®V!==U Wen O Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.0236 / -104.931064 Operator c ti o , SEaID hl. ck Discharge Hei ght Above Ground, Le �elr (Feel) Temp d' ( � Flow Rate (A FM) Velocity (ft/sec) TBD 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): O Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed O Combustion Device: Pollutants Controlled: VOC, HAPs Rating: Type: Enclosed Combustor Make/Model: IES / IES-48-02 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating MMBtu/hr 95.0 % 99.0+ % Waste Gas Heat Content -1,500 Btu/scf 0.16 MMBtu/hr O Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 4I COLORADO Depancroent. H0TTE EmUCTme. Permit Number: AIRS ID Number: PM [Leave blank unless APCD has already assigned a permit A 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 ❑ No b h t l ui ment AND state the overall control efficiency (% reduction): IT yes, please descn Pollutant e t e con ro eq p Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO, VOC Enclosed Combustor 95% CO HAPs Enclosed Combustor 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: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual, Annual Emissions; Requested Annual Permit Emission Limit(s) Uncontrolled (Tons/year) '. Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) SOX NO„ VOC 2.99E-02 I b/scf Eng. Est. 13.16 - 0.66 CO Benzene 3.08E-04 Ib/scf Eng. Est. 0.14 0.01 Toluene Ethylbenzene Xylenes n -Hexane 4.72E-04 Ib/scf Eng. Est. 0.21 - 0.01 - 2,2,4- Trimethylpentane 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-211 -Natural Gas Venting APEN - Rev 03/2017 5 1 I COLORADO I DPyummt u1 Publ. Hen. E EnwcnmeN 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. 4/13/2018 Si nature of L gaily Authorized Person (not a vendor or consultant) Date Kelli Cox Air Quality Coordinator Name (please print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance ✓❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) 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-211 -Natural Gas Venting APEN - Rev 03/2017 6 I (COLORADO tab& lam irEnvtromwac Ruda GIHitt 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 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: ytiJC- oU51 AIRS ID Number: 1 --us i9Wr ioi [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: D-2 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name1: Elevation Midstream, LLC Site Name: Buffalo Compressor Station Site Location: Section 31, Township 5N, Range 66W Mailing Address: (Include Zip Code) 370 17th Street, Suite 5300 Denver, CO 80202 E -Mail Address2: kcox@extractionog.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Kelli Cox Phone Number: (720) 354-4597 '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. 3—k€4vice COLORADO Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 1 I AV'°r"� "�"� 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 -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 (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: 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: TEG dehydration unit for water removal Facility equipment Identification: D-2 TEG Dehydration Unit 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: Normal Hours of Source Operation: hours/day days/week weeks/year / TBD / / Will this equipment be operated in any NAAQS nonattainment Yes ❑ No area Is this unit located at a stationary source that is considered a ❑ Yes ❑✓ No Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 2 1 Haab,. Permit Number: AIRS ID Number: I / [Leave blank unless APCD has already assigned a permit a and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer TBD Model Number: TBD Dehydrator Serial TBD Reboiler Rating: 2.50 Number: ❑ Ethylene Glycol ❑ DiEthylene Glycol Glycol Used: (EG) (DEG) Glycol Pump Drive: 0 Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Max: 30 Lean Glycol Water Content: 1.0 Wt.% MMBTU/hr TriEthylene Glycol (TEG) Requested: 30 f/ of pumps: Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 180 MMSCF/day Requested: 65,700 MM5CF/year Actual: MMSCF/year Inlet Gas: Pressure: -1, 000- 99 psig Water Content: Wet Gas: Flash Tank: Pressure: 100 Cold Separator: Pressure: Temperature: Ib/MMSCF 0 Saturated psig Temperature: psig Temperature: Stripping Gas: (check one) 0 None ❑ Flash Gas O Dry Gas ❑ Nitrogen Flow Rate: scfm 125 ' `F Dry gas: 125 6.7 F `F lb/MMSCF O 0 NA NA Additional Required Information: ❑r Attach a Process Flow Diagram El Attach GRI-GLYCaIc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) j+ Attach the extended gas analysis (including BTEX & n -Hexane, temperature, and pressure) COLORADO Form APCD-202 Glycol Dehydration Unit APEN - Revision 02/2017 3 1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information eographical'Coordinatesl Latitude/Longitude or,UTM) 40.0236 / -104.931064 Op[e�ra a sc ate et`�� o� B } 1 _ ° �� ' b 1 at ID Ci. } 7 "+! ₹ *' ¢e�[e L.- Sd'�.arv' -„ -a `-5' �" '�` --. �p i -4 G tlse D-2 25 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑✓ Upward ❑ Horizontal ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): AVIV,COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 Permit Number: AIRS ID Number: ! I [Leave blank unless APCD has already assigned a permit a and MRS ID] Section 6 - Control Device Information 0 Condenser: 011G6(K0C Used for control of: Still Vent. Type: - TBD Maximum Temp...46e— Requested Control Efficiency Make/Model: TBD Average Temp ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion E Device: Used for control of: Flash Tank Off Gas, Still Vent Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: IES / IES-48-02 Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Constant Pilot Light: +❑ Yes 95.0 99.0+ Waste Gas Heat Content No Pilot burner Rating 1,500 Btu/scf 0.16 MMBtuthr Closed ❑ Loop System: Used for control of; Description; System Downtime O Other: Used for control of: Description: Control Efficiency Requested Form APCD-242 Glycol Dehydration Unit APEN - Revision 02/2017 5 I AV COLORADO D.. PM Permit Number: AIRS ID Number: 1 / [Leave blank unless APCD has already assigned a permit # and AIRS ID1 Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (fa reduction): Overall Re 4,uested Control, Efficiency, (% reductfan in emfssions) Control Equipment Description SO,, NOx CO VOC •Condencsr I Endosed Combustor 95% HAPs Condenser/ Enclosed Combustor 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: (Use the data reported fn Sections 4 and 6 to calculate these emissions. Pollutant' Uncontrolled Emission Factor_;. .,__:._7:::::_.,,r,„ Emission Factor Units Emission Factor source (Ap-42 Mfi:'etc): uallAnnual Emissions . �. Requested Annual r Eilission -Li Permit �mitis)� s' ' Uncontrolled (Tonslyear) Controlled (Tons/year).- Uncontrolled` - T(Tonstyear)` . "Controlled - `(Tonslyear) PM 50,, NO„ 0.068 lb/MMBtu AP -42 1. ,S8 ' I- c5 1.54 -1.54 CO 0.31 lb/MMBtu AP -42 .P- /' - Z.• )cf -.Mk -` VOC 2O..7/ 30.74 IbIMMscf GLYCaIc 686.36 - _i1/4/ 02 1,009.75 —34 44 — Benzene 2-66 lb/MMscf GLYCaic 87. .57 S7 - y 3P, 10D.67 4.62 - - 3. t Toluene / g.7 lblMMscf GLYCaic 60. y-7 - 3 • CZ - 68.82- 2.30 • 2.10 Ethylbenzene f 28 <-8.53 Ib/MMscf GLYCaIc 9 • 3 3 - ' 0-6/-7- - 0.42 17.39 Xylenes 1-c? -4x05- Ib/MMscf GLYCaIc 3C. c(,,c - LBO - 0.76 - 34.58 n -Hexane 0,.,P Ib1MMscf GLYCaIc 0,53 . 0,5-2 - -41,7-1- "�•- Trimethylpen one �'O.3G � lb/MMscf GLYCaIc • 1 O. 000 •$ 0.002 0.05 Other. Requested values will become permit limitations. Requested limitls► should consider future process growth. ;Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2O2 Glycol Dehydration Unit APEN • Revision 02/2017 6 1 RIF COLORADO fdille 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. Air Quality Coordinator nature of gaily Authorized Person (not a vendor or consultant) Kelli Cox 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-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 [� COLORADO 7 I /Y1 ens wwnuc L'i:�. Nam W 6...onme. Hello