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Home My WebLink About20191839.tiffPub1� c Plev‘e COLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 May 8, 2019 Dear Sir or Madam: RECEIVED MAY 1 3 2019 WELD COUNTY COMMISSIONERS On May 9, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Summit Midstream Niobrara, LLC - Brahma Compressor Station. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. 'Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., 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 Cr.; PLGTP),1%L-U O, PW(Lki CHicYi) 5120J►Ct 5/13/1CA 2019-1839 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Summit Midstream Niobrara, LLC - Brahma Compressor Station - Weld County Notice Period Begins: May 9, 2019 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Summit Midstream Niobrara, LLC Facility: Brahma Compressor Station Compressor Station SW SEC 28 T12N R63W Weld County The proposed project or activity is as follows: Tanks, Dehy, Engines, Blowdowns associated with natural gas compressor station 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 Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 19WE0169 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 COLOFiADd tto-annacmuimnreana Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Summit Midstream Niorbrara, LLC Brahma Compressor Station SW SEC28 T12N R63W GE -01 Permit No. AIRS Review Date Permit Engineer 19WE0169 123/A029/005 03/17/2019 Timothy Sharp Requested Action Issuance No. New permit/newly reported emission 1 Emission Point Description One (1) Caterpillar, Model G3512B, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1035 horsepower. This engine shall be equipped with an oxidation catalyst and air - fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 58.10 Requested (mmscf/m) 4.93 Fuel Heat Value (btu/scf) 1134 BSCF (Btu/hp-hr) 7268 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx manufacturer manufacturer VOC manufacturer manufacturer CO manufacturer manufacturer Formaldehyde manufacturer manufacturer SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 5.0 5.0 5.0 0.0% VOC 13.8 7.0 13.8 49.0% CO 26.4 1.8 26.4 93.0% SOx 0.0 0.0 0.0 0.0% TSP 0.3 0.3 0.3 0.0% PM10 0.3 0.3 0.3 0.0% PM2.5 0.3 0.3 0.3 0.0% Total HAPs* 0.0 0.0 5.8 73.2% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 10392 2494 10394 76.0% Acetaldehyde 551 275 551 50.0% Acrolein 339 169 339 50.0% Methanol 165 50.0% n -Hexane * * 73 50.0% Benzene * * 29 50.0% Toluene * * 27 50.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected Public Comment Public Comment Required MACT ZZZZ - Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B (Ozone NAA requirements) applies? No MACT ZZZZ (area source) Is this engine subject to MACT ZZZZ area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes -Initial test required to verify emission factor. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Summit Midstream Niorbrara, LLC Brahma Compressor Station SW SEC28 T12N R63W CE -01 Permit No. AIRS Review Date Permit Engineer 19WE0169 123/A029/006 03/17/2019 Timothy Sharp Requested Action Issuance No. New permit/newly reported emission 1 Emission Point Description One (1) Caterpillar, Model G3608, Serial Number XH70092, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 2500 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 131.00 Requested (mmscf/m) 11.13 Fuel Heat Value (btu/scf) 1134 BSCF (Btu/hp-hr) 6757 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx manufacturer manufacturer VOC manufacturer manufacturer CO manufacturer manufacturer Formaldehyde manufacturer manufacturer SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested . PTE Proposed Control Efficiency NOx 12.1 12.1 12.1 0.0% VOC 25.4 17.0 25.3 33.0% CO 61.3 4.3 61.1 93.0% SOx 0.0 0.0 0.0 0.0% TSP 0.7 0.7 0.7 0.0% PM10 0.7 0.7 0.7 0.0% PM2.5 0.7 0.7 0.7 0.0% Total HAPs* 0.0 0.0 7.0 70.7% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/vr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 11148 2675 11105 76.0% Acetaldehyde 1242 621 1237 50.0% Acrolein 764 382 761 50.0% Methanol 371 186 370 50.0% n -Hexane * 164 50.0% Benzene * * 65 50.0% Toluene * * 60 50.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected (see details of modeling analysis) Public Comment Public Comment Required MACT ZZZZ - Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B (Ozone NAA requirements) applies? No MACT ZZZZ (area source) Is this engine subject to MACT Z777 area Yes source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes -stack tests are required to verify claimed emission factors. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Summit Midstream Niorbrara, LLC Brahma Compressor Station SW SEC28 T12N R63W CE -02 Permit No. AIRS Review Date Permit Engineer 19WE0169 123/A029/007 03/17/2019 Timothy Sharp Requested Action Issuance No. New permit/newly reported emission 1 Emission Point Description One (1) Caterpillar, Model G3608, Serial Number TBD, natural gas -fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 2500 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 131.00 Requested (mmscf/m) 11.13 Fuel Heat Value (btu/scf) 1134 BSCF (Btu/hp-hr) 6757 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx manufacturer manufacturer VOC manufacturer manufacturer CO manufacturer manufacturer Formaldehyde manufacturer manufacturer SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 12.1 12.1 12.1 0.0% VOC 25.4 17.0 25.3 33.0% CO 61.3 4.3 61.1 93.0% SOx 0.0 0.0 0.0 0.0% TSP 0.7 0.7 0.7 0.0% PM10 0.7 0.7 0.7 0.0% PM2.5 0.7 0.7 0.7 0.0% Total HAPs* 0.0 0.0 7.0 60.4% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 11148 2675 11105 76.0% Acetaldehyde 1242 1242 1237 0.0% Acrolein 764 764 761 0.0% Methanol 371 371 370 0.0% n -Hexane * 164 0.0% Benzene * * 65 0.0% Toluene * * 60 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected Public Comment Public Comment Required MACT Z777 #VALUE! Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B (Ozone NAA requirements) applies? No MACT ZZZZ (area source) Is this engine subject to MACT ZZZZ area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes -stack tests are required to verify claimed emission factors. Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Sharp Package #: 393317', ., Received Date: 2/12/2019 Review Start Date: 3/20/2019 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: P curalGasCompressorStation What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? No If yes, for what pollutant? ❑ Carbon Monoxide (CO) ❑ Particulate Matter (PM) Summit Midstream Niobrara, LLC 123 A029 Brahma Compress. sw quadrant of Section 28, Township 12n, Range 63wW Weld County Section 02 - Emissions Units In Permit Application Quadrant Section Township Range 63w SW 28 12n Ozone (NOx & VOC) AIRs Point Emissions Source Type Equipment Name Emissions Control? Permit 9 Issuance 9 Self Cert Required? Action Engineering Remarks 001 Condensate Tank TK-Q1 Yes 19WE0169 1 - Yes Permit Initial Issuance 002 Produced Water Tank TK02-05 Yes 19WE0169 1 Yes Permit Initial Issuance 003 Maintenance Blowdowns BD -01 No 19WE0169 1 Yes Permit Initial Issuance 004 Dehydrator DU -01 Yes 19WE0169 ;' 1 Yes Permit Initial Issuance 005 Natural Gas RICE GE -01 :-- Yes 19WE0169 _ 1 a Yes Permit Initial ' Issuance 006 Natural Gas RICE ' CE -01 : Yes 19WE0169 1 - Yes Permit Initial Issuance. 007 Natural Gas RICE CE 02 Yes 19WE0169 1 yes Permit Initial Issuance Section 03 - Description of Project Natural Gas compressor station in the ozone attainment maintenance area. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 50 tons per year in an Attainment Area Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? INo If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? No Is this stationary source a synthetic minor? Yes If yes, indicate programs and which pollutants: 5O2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration (PSD) ❑ ❑ ❑ Q ❑ ❑ Title V Operating Permits (OP) O O 2 O ❑ ❑ ❑ O Non -Attainment New Source Review (NANSR) ❑ ❑ Colorado Air Permitting Project Is this stationary source a major source? If yes, explain what programs and which pollutants henso2 Prevention of Significant Deterioration (PSD) ❑ Title V Operating Permits (OP) ❑ Non -Attainment New Source Review (NANSR) NOx O CO VOC PM2.5 PM10 TSP HAPs ❑ El ❑ ❑ ❑ O ❑ ❑ ❑ ❑ Condensate Storage Tank(s) Emissions Inventory 001 Condensate Tank 'Facility Al Rs ID: County ,r'Ap,9 s=001 .s.f Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit 1-400/>bl fixed roof condensate storage tank Description: Emission Control Device VRO with 5% downtime Description: Requested Overall VOC & HAP Control _ Efficiency %: 95 Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating Requested Monthly Throughput = 3,466, Barrels (bbl) per year 0' Barrels (hbl) per year 310 Barrels (bbl) per month I Potential to Emit (PTE) Condensate Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = sef/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 49 Barrels (bbl) per year Btu/scf Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04- Emissions Factors & 0lethodologies Will this storage tank emit flash emissions? 0 MMBTU per year 0 MMBTU per year 0 MMBTU per year Pollutant Uncontrolled Controlled (Ib/bbl) (lb/bbl) (Condensate Throughput) (Condensate Throughput) Emission Factor Source ISaiMMIMISIMEBBEIMIEICIMD Pollutant 0.000 0.000 0.000 0.000 0.000 Control Device Uncontrolled Uncontrolled (6/MMBtu) (waste heat combusted) (lb/bbl) ENESIMMil (Condensate Throughput) 0.0000 0,0000 0.0000 0.0000 Emission Factor Source Section 05 - Emissions Inventory &P Tanks (tpy) 0.006 0.001 4.646 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 45.0 37.5 3.7 37.5 1.9 318 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0,0 0 0.0 0.0 0.0 0.0 0.0 0 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 14 12 1 12 1 2 2 0 2 0 0 0 0 0 0 0 0 0 0 0 11150 9292 906 9292 465 0 0 0 0 0 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 XII,C-F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section X11 -G Regulation 7, Section XVII.B, C.7, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & CO Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NIPS Subpart 0000 Storage Tank is not subject to NIPS 0000 Regulation B, Part E, MACT Subpart HH Storage Tank is not subject to MACE HH (See regulatory applicability worksheet for detailed analysis) 3 of 16 K:\PA\2019\19 W E0169.CP1xlsm Condensate Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodicnampling 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 05-0 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 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 based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Applicant used an, unverified sample to request emission factors that are greater than the state default emission factors This methodology is conservative according to current policy specifying state' default factors as a starting point. Since using either state-defalut or the suggested emission factors does not exceed 80tpy.VOC uncontrolled emissions, the division will not require a site -specific Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 001 01 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 489.2 95 lb/1,000 gallons condensate throughput CO 0.00 0 lb/1,000 gallons condensate throughput Benzene 0.08 95 lb/1,000 gallons condensate throughput Toluene 0.01 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 lb/1,000 gallons condensate throughput Xylene 0.00 95 lb/1,000 gallons condensate throughput n -Hexane 60.61 95 lb/1,000 gallons condensate throughput 224TMP 0.00 95 lb/1,000 gallons condensate throughput 4 of 16 K:\PA\2019\19 W E0169.CP1.xism Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts Aand B -APEN and Penult Requirements ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greaterthan 2TPY(Regulation 3, Part A, Section ll.Dl.a)7 (Source Is in the Attainment Area 2. Is the construction date (service date) priorta 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 112 and1.14 and Section 2foradditional guidance on grandfather applicability)? 3. Are total facilityummntrolled VOC emissions greater than 5 TPY, NO0 greater than lOTPY or CO emissions greaterthan 30 TPY (Regulation 3, Part 0, Section ILD.3)? 'source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutantsfrom this individua l source greaterthan l TPY (Regulation 3, Part A, Section ll.D.1.a)? 2. Is the construction date (service date) priort012/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and114 and Section 2for additional guidance on grandfather applicability)? 3. Aretotal facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5TPY or CO emissions greater than 10 TPY (Regulation 3, Part B,Section 3.D.2)7 'you have indicated that source Is in the Attainment Area Colorado Regulation 7. 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. is thh storage tank located at an an and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is thb storage tank located upstream of a natural gas proc sing plant? 'Storage Tank is not su Neck to Regulation 7, Section 011.e -E Section X0.0.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Section XII.C.2—Emission Estimation Procedures Section 00.0 —Emissions Control Requirements Section XII.E—Monitoring Section XII.F—Recosdkeeping and Reporting Colorado Regulation 7.5ection XII.G 1. Is this storage tank boated 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 thb storage teak exhibit "Flash" (e.g. storing nun -stabilized liquids) emssions and have uncontrolled actual emissions greaterthan or equal to 2tons per year VOL? IStorageTank is not subject to Regulation 7, Section 00.0 Section X8.G.2 - Entssions Control Requirements Section XII.0.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Section XII.O.2—Emission Estimation Procedures Colorado Regulation 7, Section MI 1. Is this tank located at a transmission/storage facility? 2. Is thb 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 sforagetank a fixed roof storage tank? 4. Are uncontrolled actual emissions" of this storageta nk equal to or greaterthan 6 tons peryear VOC? 'Storage tank is subject to Regulation 7, Section XVII, 0, 01 a C.3 Section 551re—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section IMI.C.1- Emssions Control and Monitoring Provisions Section XVII.C3-Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? IStoragetank is subject to Regulation 7, Section 000.0.2 Section 1MI.C.2- Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greaterthan or equal to 75 cubic meters (m') (-472 BBB)? 2. Dom thestorage vessel meet the following exemption m 60.111b(d)(4)? a. Does the vessel has a deign capacity lass than or equal to 1589.874 m' (-10,000 BBL] used for petroleum or condensate stored, processed, ortreated priorta custody transfer' as defined in 50.1110? 3. Was this condensase storage tank constructed, reconstructed, or modified( see definitions 40 CFR, 60.2) after July 23, 1984? 4. Dos the tank meetthe definition of "storage vessel"' in 60.11lb? 5. Dos the storage vase(store a "volatile organic liquid (VOL). as defined in 60.1110? 6. Dos the storagevssel meet any one 0fthe fallowing additional exemptions: a. Is the ssnrage vessel a pressure vssel designed to operate in excess Of 204.9 Spa [29.7 psi] and without emissions to the atmosphere (o0.110b(d)(2))?; or b. The design capacity is grsterthan or equal in 151 m' ['950 BBL] and stores a liquid with a maximum true vapor pressure° less than 35 kPa (6o.11ob(b))?; or c The design capacity u greaterthan or equal to 75 M° [-472 BBL] but less than 151 m' r950 BBL] and storm a liquid with a maximum true vapor pressures less than 15.0 kPa(60.11ob(b))? W 0???? np"si/n"GNipii No Yes YIM No No Yes X ounce Req Go to next, Source Regr Storage Tar Source is so SttrageTar Storage Tar Continue Go to the m Go to then Source 550 ff4p i'ritleT?mnnurce Isau Storage Tar StorageTank Is not subject to SOPS Kb Subpart A, GeneralProvisions §60.1126- Emisioas ContmlStandards for VOC §601130 -Tasting and Procedures 46011Sb- Reporting and Recordkeeping Requirements §60.1160- Monitoring of Operations 40 CFR, Part60, Subpart 0000, Standards of Performance far Crude On and Natural Gas Pmductlon.Transmission and Distribution 1. Is thh condensate storage vessel located at a facility In the onshore nil and natural gas production segment, natural 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, to1)between August 23, 2011 a nd September 18, 2015? 3. Are potential VOC emissions' from the individual storagevessel greaterthan or equal to 6 tans per year? 4. Domthy condensate storage vessel meet the definition of "storage vessel" per 60.5430? 5. Is the storage vessel subjectnc and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? 'Storage Tank is not subject to NSPS 0000 Subpart', General Provisions per 4605425 Table 3 460.5395 - Emissions Control Standards for VOC 460.5413-Testing,and Procedures 460,5395(g) -Notification, Reporting and Recordkeeping Requirements 4605416(c) -Cover and Closed Vent System Monitoring Requirements 0605417 - Controtfesce Monitoring Requirements [Note: If a stoagevessel is previously determined to he subject to N5050000 due to emissions above 6 tons per year VOC on the applicability determination date, ft should remain sublectto NSP50000 per 60.5365(0)(2) even if potential VOC emkslons drop below 6 tons per year) 40 CFR. Part 63. Subpart MALT Hu. 00 and Gas Production Facilities 1. Is the storage tanklocated at an oil and natural gas production facility that meets either ofthe following criteria: a. Afacility that processes, upgrades or storm hydrocarbon liquids' (63.750(')(2)); OR b. A facility that processes, upgrades or storm natural gas priorta the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end users (63.760(a)(3))? 2. Is theta nk locatedlat a facility that Is major' for HAPs? 3. Does the tank meet the definition of "storage vessel"° In 63.7617 4. Dos the tank meet the definition of"storage vessel with the potential forflash emissions' per 63.761? 5. Is the tank subjectto control requirements under 40 CFR Part 50, Subpart Kb or Subpart 0000? 'Storage Tank is not subject to MALT HH Subpart A, General provisions per 463.764 (a) Table 2 §63.766- Emissions Control Standards 463.773 Monitoring §63.77$- Recordkeeping §63.775 -Reporting RACT Review RACT review Is required If Regulation 7 does not apply AND lithe tank is In the ran -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This oftcument assists operators with determining applicability of certain iequirements of the Clean Air Act, its implementing regulations, and Air Duality 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 otherlegal& binding requirement and is not legally enforceable. In the event of anyconilict between the language of this document and the language of the Clean Air Act, its implementing regulations, andAr 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 APCO interpreta6'ons 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 ['liftoff Yes forage Tar 'Yes 'Continue storage Tar Produced Water Storage Tank(s) Emissions Inventory 002 Produced Water Tank Facility AIRs ID: County Plant Point Section 02- Equipment Description Details Detailed Emissions Unit 4x400bb1 fixed roof storage vesseles for produced water storage. Description: Emission Control Device rVRU with 5% annual downtime Description: Requested Overall VOC & HAP Control Efficiency %: 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = :Requested Permit Umit Throughput= Potential to Emit (PTE) Produced Water Throughput = 150 Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = WPM 3410 Barrels (bbl) per month 40,150 Barrels (bbl) per year Requested Monthly Throughput= Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = acf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year Btu/scf 0 MMBTU per year 0 MM BTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year Section 04- Emissions Factors& Methodologies Will this storage tank emit flash emissions? Pollutant Pollutant Produced Water Tank Uncontrolled Controlled (Ib/bbi) (lb/bbl) (Produced Water Throughput) 0.110 0.000 0.000 0.000 0.002 (Produced Water Throughput) Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) Section 05 - Emissions Inventory (Produced Water Throughput) 0.0000 0.0000 0.0000 0.0000 Emission Factor Source Emission Factor Source 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 2.6 2.2 0.2 2.2 0.1 19 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene. Xylene n -Hexane 224 TMP 8 6 1 6 0 2 1 0 1 0 0 0 0 0 0 0 0 0 0 0 96 80 8 80 4 0 0 0 0 0 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 not 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 Storage Tank is not subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis) 6 of 16 K:\PA\2019\19 W E0169.CP1.xlsm 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 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. 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? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 002 Process # SCC Code 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 0.00 0 1b/1,000 gallons liquid throughput VOC 2.6 95 lb/1,000 gallons liquid throughput CO 0.00 0 lb/1,000 gallons liquid throughput Benzene 0.00 95 lb/1,000 gallons liquid throughput Toluene 0.00 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 7 of 16 K:\PA\2019\19WE01'69.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 Regulation, 3 Parts A and B- APEN and Permit uirernents Source is in the Attainment Area ATTAINMENT 1. Are uncontrolledactual emissions from any criteria pollutants from this Individual source greater than 2TPY (Regulation 3, Part A,Sectlon ll.onel7 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 0, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 5TPY, NOx greater than 10TPY or CO emissions greater than 1OTPY (Regulation 3, Part B, Section 11.0.3)7 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutantsfrom this individual source greater than 1TPY (Regulation 3, Part A, Section ll.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 e, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2TPY, NOx greater than 5TPY or C0 emissions greater than 10 TPY (Regulation 3, Part B, Section 11.D.2)7 'You lave indicated that source Is In the Attainment Area Colorado Regulation 7, Section %VII 1. Is this tank located ate transmission/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 station' 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 equalto or greater than 6 tons peryear VOC? 'Storage Tank Is not subject to Regulation 7, Section KVII Section XVILB —.General Provisions for Air Pollution Control Equipment and Prevention of Emissions Scones XVII.C.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 Regulation 7, Section XVII.e.2 Section XVIl.C.2- Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CPR, Part RD. Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production. Transmission and Distribution 1. Is this producedwater storage vessel located ate 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 40CFR,60.2) between August 23, 2011 and September 18, 20157 3. Are potential VOCemissions' 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 60.5430? 'Storage Tank is not subject to NSPS 0000 Subpart A, General Provisions per §605425 Table §60.5595 - Emissions Control Standards for VOC §60.5413 -Testing and Procedures §00.5395(g)- Notification, Reporting and Remrdkeeping 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 on the applicability determination date, it should remain subjectto NSPS 0000 per 60.5365(e)(2) even If potential VOC emissions drop below 6 tons per year] RACE Review PAR review is required if Regulation 7 does not apply AND If the tank Is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air 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„ ds implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use ofnon-mandatory language such as ecommend," '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 vs, No Yes tiONSTil Yes Source Req Go to next i Source Req Continue-` Continue-` Go to then Storage Tar ¢IS Continue Storage Tat Section 01- Adminstrative Information Facility AIRs ID: 123 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Natural gasventing from compressor blowdowos. Emissions from thisnource are ventedto tha Description; Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: bma3phaYe ( xt ' '.• Entissronsfrom this. pour Section 03 - Processing Rate Information for Emissions Estimates '1.00EOZ MMscf 104:events/year `8: events/year 0 MMscf per year 1.04E+00 MMscf per year 1.04E+00 MMscf per year Compressor Blowdown Volume= Requested Compressor Blowdown Events= Actual Compressor Blowdown Events= Actual Gas Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = ontralled. Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex=Q* MW *Xx/C Ex = emissions of pollutant x 4= Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 6OF and 1 atm Throughput (CO MW 1.04E+00 MMscf/yr Ib/Ib-mol 1.19E+02 scf/yr MMscf/d 23.9 0.002849315 mole % MW Ibx/Ihmol mass fraction lb/hr lb/yr tpy Helium . +^'.'»y', 0:00 !4.0026 0.000 0.000 0.00 0.00 0.00 CO2 . r. 2.68 : `;: 44.01 1.179 0.049 0.37 3236.53 1.62 N2 S�:y aa:'•'^3 .*, -.1.21 ;;, 28.013 0.339 0.014 0.11 930.12 0.47 methane (:'..'`"1' hhg 69.96 Ss�'"16.041 11.222 0.470 3.52 30794,66 15.40 ethane 10.76 ' - 30.063 3.235 0.135 1.01 8876.44 4.44 propane 9.21 44.092 4.061 0.170 1.27 11143.29 5.57 isobutane 0.94 '.58.118 0.546 0.023 0.17 1499.11 0.75 n -butane 3.21 58.118 1.866 0.078 0.58 5119.29 2.56 isopentane 0.57 ::; 72.114 0.411 0.017 0.13 1127.95 0.56 n -pentane 0.67 72.114 0.483 0.020 0.15 1325.83 0.66 cyclopentane 0.00 . '. 70.13 0.000 0.000 0.00 0.00 0.00 n -Hexane '/ 's;1 0.42 ':„86.18 0,362 0.015 0.11 993.23 0.50 cyclohexane ').::+' ,' 0.07 ''_ 84.16 0.059 0.002 0.02 161.66 0.08 Other hexanes - .',. 0:00 86.18 0.000 0.000 0.00 0.00 0.00 heptanes '' 0.07 i<'s100.21 0.070 0.003 0.02 192.49 0.10 methylcyclohexane 0 00 °""98.19 0.000 0.000 0.00 0.00 0.00 224-TMP 0.00 :' 114.23 0.000 0.000 0.00 0.00 0.00 Benzene t *;z 0.02 78.12 0.016 0.001 0.00 42.87 0.02 Toluene 0.01 92.15 0.009 0.000 0.00 25.29 0.01 Ethylbenzene 0.00 106.17 0.000 0.000 0.00 0.87 0.00 Xylenes 0.00 ~.;'106.17 0.000 0.000 0.00 0.29 0.00 C8+ Heavies 0.01 114 0.016 0.001 0.00 43.48 0.02 VOC mass fractic 0.3309 MW 23.875 Total VOC(Uncontrolled) 10.84 Notes Mole %, MW, and mass fractions are based on a representative gas sample . Emissions are based on 104 blowdown events per year. The MW of C8+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 208.42 lb/event 208.42 lb/event 10.84 tpy 10.84 tpy Gas Analysis Benzene 0.412 lb/event 0.412 lb/event 42.9 lb/yr 42.9 lb/yr Mass Balance Toluene 0.243 lb/event 0.243 lb/event 25.29 lb/yr 25.29 lb/yr Mass Balance Ethylbenzene 0.008 lb/event 0.008 lb/event 0.87 lb/yr 0.87 lb/yr Mass Balance Xylenes 0.003 lb/event 0.003 lb/event 0.29 lb/yr 0.29 lb/yr Mass Balance n -Hexane 9.550 lb/event 9.550 lb/event 993,23 lb/yr 993.23 lb/yr Mass Balance 2,2,4-TMP 0.000 lb/event 0.000 lb/event 0.00 lb/yr 0.00 lb/yr Mass Balance Section 06 - Regulatory Summary Analysis AQCC Regulation 1 19WE0169.CP1.xlsm Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." _ Section 07 - Technical Analysis Notes 1. To demonstrate compliance with blowdown permit limits, each blowdown event will be recorded and emissions will be estimated by multiplying the number of events by the emission factor provided in the notesto permit holder (lb/event). This supports the use of an event basis for the process limit contained in the permit. 19WE0169.CP1.xlsm Glycol Dehydrator Emissions Inventory 004 Dehydrator 'Facility AIRS ID: 123 county A029 Plant 004 Point Section 02- Enulpmeot Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Recirculation Pump reformation 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 reboller burner One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: tbd, Model: 30MMSCFD TEG DEHn, Serial Number: tbd) with a design capacity 0030 MMscf per day. This emissions unit is equipped with tbd (Make:tbd, Model: tbd) electric driven glycol pump with a design capacity of 12 gallons per minute. This dehydration unit Is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are routed so an air-cooled condenser, and then to the Enclosed Flare. As a secondary cemrol device, still vent emissions are routed to the Enclosed Flare . Emissions from the flash tank ere routed directly to the closed -loop system. Section 03 - Processire Rate Information for Emissions Estimates Primary Emissions -Dehydrator Still Vent and Flash Tank (if present} Requested Permit Limit Throughput= Potential to Emit (PTE) Throughput= MMscf per year Requested Monthly Throughput= 930 MMscf per month 10,550 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 Verit 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: AtvroatOtriVfiZt4.;• Requested Condenser Outlet Temperature: 95%Control Efficiency % hr/yr Requested TO Temp '^ 3 .100% Control Efficiency % 322 hr/yr .Btu/scf scfh a Section 04- Emissions Factors & Methodologies Dehydrator Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate hr/yr hr/yr Btu/scf scfh pig deg F gym 10096 Control Efficiency % Control Efficiency% STILL VENT Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (R/hr) VOC 44.7317. 2.236505-.. , d Benzene AY1.545Q'.' 0:57725 .,. `la . . Toluene 3.896 0.1948 "0 - Ethylbenzene 201498.. ,0 Xylenes ` 0,173&"' 0.00869 0 n -Hexane 3.6307 0,181535 224-TMP ...., .::' 0 .. 0 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC 45.3042 ,0 " 41.3042 ' Benzene ...0.3699= 0 0.3699 Toluene "`0.0059; .7`0 0.0859.'. Ethylbenzene 0.0041 -. 0 0.0041 Xylenes "'0,0017' "`.-.0 - 0.0017 , n -Hexane 2.7451 0 224-TMP .. .: 0 .. ... 9 160 Degrees F Degrees F Dry Gas Throughput: Still Vent Primary Control: 10,950.0 MMscf/yr Still VentSecandary Control: 10,902.5 MMscf/yr Waste Gas Combusted: Still Vent Primary Control: 0.0 MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Dry Gas Throughput: Flash Tank Primary Control: 10,950.0 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr Waste Gas Combusted: Flash Tank Primary Control: 0.0 MMscf/yr Flash Tank Secondary Control: e.g MMscf/yr 930.0 0.0 Glycol Dehydrator Emissions Inventory Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer (%): Emission Factors Still Vent Primary Control Device Pollutant Benzene Toluene Ethylbenzene Xyfane Hens 224TMP Pollutant PM2.5 Sox NO CO Pollutant PM10 CO Pollutant PM10 Pollutant 0800 CO Glycol Dehydrate Uncontrolled (Ib/MMsct) (Ib/MMscf) Emission Factor Source (Dry Gas Throughput) (Dry Gas Through put) Controlled 0.24296 0.006952 0.145228 Uncontrolled Uncontrolled (Ib/MMBtu) (Ib/MMscf) Emission Factor Source (Waste Heat Com busted) 0.0000 0.0000 (Waste Gas Combusted) 0.0000 0.0000 0.0000 0.0000 Still Vent Secondary Control Devic Uncontrolled Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) (Ib/MMscf) (Waste Gas Combusted) 0.0000 0.0000 0.0000 0.0000 0.0000 Flash Tank Primary Control Device Uncontrolled Uncontrolled (Ib/MM6tu) (Ib/MMscf) (Waste Heat Combusted) 0`0000, (Waste Gas Combusted) 0.0000 0.0000 0.0000 Flash Tank Secondary Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) (Ib/MMscf) (Waste Gas Combusted) 0.0000 0.0000 0.0000 0.0000 Emission Factor Source Emission Factor Source Emission Factor Scums 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 0.0 0.0 0.0 0.0 0.0 _ 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 376.8 376.8 9.8 376.8 9.8 1664 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Etlsylbenzene 0(ylene rFHexane 224 IMP , 104375 104375 5057 104375 5057 34881 34881 1706 34881 1706 20060 2660 131 2660 131 1537 1537 76 1537 76 55852 55852 1590 55852 1590 0 0 0 0 0 Section 06 - Regulatory Summary Anal 5,15 Regulation 3, PartsA, 8 Regulation 7, Section XVII.B,D Regulation 7, Section XVII.B.2.e Regulation 7, Section X11.11 Regulation 8, Part E, MACT Subpart HH (Area) Regulation 8, Part E, MACT Subpart OH (Major) Regulation 8, PartE, MACT Subpart HHH (See regulatory applicability worksheet for detailed analysts) Source requires a permit Dehydrator is subject to Regulation 7, Section XVII, 0, 0.3 The control device for this dehydrator Is not subject to Regulation 7, Section X011.8.2.5 Dehydrator is not subjectto Regulation 7, Section 011.0 Oehy is subject to area source MACT HH, per the requirements in 63,764(d)(1( You have indicated that this facility is not subject to Major Source requirements of MACT OH. You have indicated that this facility'is not subject to MALT HHH, Glycol Dehydrator Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample used in the Olycaic model/Process model site -specific and collected within a year of application submittal? ts. If no, the permit will contain an "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, 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 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 F? If yes, the permit wlllcontaln en "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer. No w - Section CS - Technical Analysis Notes -Applicant has requested condenser credit.. Applicant has also requested VRU control with downtime (5/) as primary control VRIJ do time monitoring will b roqu red. enclosed flan selection for still vent control has been used instead ot VFW selection, not available. Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point # 004 Process # SCC Code 01 Uncontrolled Pollutant Emissions Factor Control% Units PM10 0.000 0.0 b/MMscf PM2.5 0.000 0.0 b/MMscf SOX 0.000 0.0 b/MMscf N0x 0.000 0.0 b/MMscf VOC 68.8 97.4 b/MMscf CO 0.000 0.0 b/MMscf Benzene 9.532 95.2 b/MMscf Toluene 3.186 95.1 b/MMscf Ethylbenzene 0.243 95.1 b/MMscf Xylene 0.140 95.0 b/MMscf n -Hexane 5.101 97.2 b/MMscf 224 TMP 0.000 #DIV/OI b/MMscf Dehydrator Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements 'Source is in the 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 (Regulation 3, Part B, Sec 'Source requires a permit NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria 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 TPY or CO emissions greater than 10 TPY (Regulation 3, Pat 'You have indicated that source is in the Attainment Area Colorado Regulation 7, Section XII.H 1. Is this glycol natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Reg 7, Sec 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operations, natural gas compressor station, natural gas drip 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 tt 4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section XII.H.3.a)? 'Dehydrator is not 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 liquids1 (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 b. source category or is delivered to a final end user2 (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 MACT HH applicability 40 CFR, Part 63, Subpart MACT 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 (63.7 3. Is the unit located inside of a UA plus offset and UC boundary area? 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 - Recordkeeping §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 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 (63.7 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? IYou 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 - Recordkeeping §63.775 - Reporting 40 CFR, Part 63, Subpart MACT 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 (6. 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 (63.1 Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(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? IYou have indicated that this facility is not subject to MACT HHH. 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 (RE 4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)? • tons per year VOC or 2 tpy VOC if the dehydrator is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, 4a. Section XVII.D.4.b)? 5. If constructed on or after May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC (F IDehydrator is subject to Regulation 7, Section XVII, B, D.3 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 by a back-up or alternate combustion device (i.e., not the primary control device) that is not en 'The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e Section XVII.B.2.e — Alternative emissions control equipment Disclaimer 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 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 19WE0169 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Summit Midstream Niobrara, LLC Brahma Compressor Station 123/A029 SW SEC 28 T12N R63W Weld County Natural Gas Compressor Station Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TK-01 001 One (1) 400 barrel fixed roof storage vessel used to store condensate Vapor Recovery Unit TK 02-05 002 Four (4) 400 barrel fixed roof storage vessel(s) used to store produced water Vapor Recovery Unit BD -01 003 Natural gas venting from facility blowdowns. Emissions from this source are vented to the atmosphere. None DU -01 004 One (1) Triethylene glycol (TEG), natural gas dehydration unit (make, model, serial number: TBD) with a design capacity of 30 MMscf per day. This emissions unit is equipped with one (1) electric -driven glycol pump with a design capacity of 12 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Emissions from the still vent are routed to an air-cooled condenser and then to a VRU. Emissions from the flash tank are recycled to plant inlet. Page 1 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado GE -01 005 One (1) Caterpillar, Model G3512B, Serial Number To Be Determined, natural gas - fired, turbo -charged, 4SLB reciprocating internal combustion engine, site rated at 1,035 horsepower. This emission unit is used for power generation. Oxidation catalyst and air -fuel ratio control. CE -01 006 One (1) Caterpillar, Model G3608, Serial Number: XH70092, natural gas -fired, turbo- charged, 4SLB reciprocating internal combustion engine, site rated at 2,500 horsepower. This emission unit is used for natural gas compression. Oxidation catalyst and air -fuel ratio control. CE -02 007 One (1) Caterpillar, Model G3608, Serial Number: TBD, natural gas -fired, turbo- charged 4SLB reciprocating internal combustion engine, site rated at 2,500 horsepower. This emission unit is used for natural gas compression. Oxidation catalyst and air -fuel ratio control. Point(s) 005: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3512B engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point(s) 006, 007: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3608 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to 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/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be Page 2 of 28 COLORADO Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 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. Point(s) 004: The following information shalt 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.) 6. Point(s) 005, 006, 007: 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. manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 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.) ) Page 3 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type PM2.5 N0X V0C CO TK-01 001 --- --- 318 --- Point TK 02-05 002 --- --- 19 --- Point BD -01 003 --- --- 1,840 --- Point DU -01 004 --- --- 1,664 --- Point GE -01 005 --- 849 1,195 314 Point CE -01 006 --- 2,058, 2,896 729 Point CE -02 007 - 2,058 2,896 729 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 emissionsof total hazardous air pollutants shall not exceed 3,398 month. pounds per 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 N0X VOC CO TK-01 001 --- --- 1.9 --- Point TK 02-05 002 --- --- 0.2 --- Point BD -01 003 --- --- 10.9 --- Point DU -01 004 --- --- 9.5 --- Point GE -01 005 --- 5.0 7.0 1.9 Point CE -01 006 --- 12.1 16.9 4.3 Point CE -02 007 --- 12.1 16.9 4.3 Point Page 4 of 28 COLORADO Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 9. Point(s) 004: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent extended wet gas analysis and recorded operational values, including: dry gas throughput, lean glycol recirculation rate, vapor recovery unit (VRU) downtime, condenser outlet temperature, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 10. Point(s) 004: On a monthly basis, the owner or operator shall monitor and record operational values including: vapor recovery unit (VRU) downtime, condenser outlet temperature, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 11. Point(s) 004: The condenser outlet temperature shall not exceed 160 degrees F, on a rolling twelve month average. The owner or operator shall calculate the rolling twelve month average temperature by averaging all recorded condenser outlet temperature values as specified in this permit. 12. 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.) E. ) 13. Facility Equipment ID AIRS Point Control Device Pollutants Controlled TK-01 001 Vapor Recovery Unit VOC and HAPs Page 5 of 28 COLORADO Air Pollution Control Division Department of Public Heath 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado TK 02-05 002 Vapor Recovery Unit VOC and HAPs DU -01 004 Still Vent: Vapor Recovery Unit/Condenser VOC and HAPs GE -01 005 Oxidation catalyst and air/fuel ratio controller VOC, CO, HAPs CE -01 006 Oxidation catalyst and air/fuel ratio controller VOC, CO, HAPs CE -02 007 Oxidation catalyst and air/fuel ratio controller VOC, CO, HAPs 14. The owner or operator shall operate and maintain the emission points in the table below as a closed loop system and shall recycle 100% of emissions as described in the table below. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Emissions Recycling Description Pollutants Recovered DU -01 004 Flash Tank: Recycled to Inlet VOC and HAP PROCESS LIMITATIONS AND RECORDS 15. 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) TK-01 001 Condensate Throughput 3,650 barrels 310 barrels TK 02-05 002 Produced Water Throughput 40,150 barrels 3,410 barrels BD -01 003 Number of Events 104 events --- DU -01 004 Dry Gas Throughput 10,950 MMscf/yr 930 MMscf/month GE -01 005 Consumption of natural gas as a fuel 58.1 MMscf/yr 5.0 MMscf/month CE -01 006 Consumption of natural gas as a fuel 131.0 MMscf/yr 11.2 scf/month Page 6 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Consumption of 11.2 CE -02 007 natural gas as a fuel 131.0 MMscf/yrscf/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. 16. Point(s) 004: The owner or operator shall 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. 17. Point(s) 005, 006, 007: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. 18. Point(s) 004: This unit shall be limited to the maximum lean glycol circulation rate of 12 gallons per minute. The lean glycol recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (Loft) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 19. 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) 20. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 21. Point(s) 001, 002: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. Page 7 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 22. Point(s) 001, 002: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. 23. Point(s) 004: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas - processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. 24. Point(s) 004: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) Page 8 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado MACT HH Applicable Requirements Area Source Benzene emissions exemption 863.764 - General Standards §63.764 (e)(1) - The owner or operator is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). §63.764 (e)(1)(ii) - The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under §63.764(e)(1). §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. §63.772(b)(2)(i) - The owner or operator shall determine actual average benzene emissions using the model GRI-GLYCaIc TM, Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc`TM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or §63.772(b)(2)(ii) - The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. Page 9 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado §63.774 - Recordkeeping Requirements §63.774 (d)(1) - An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). MACT HH Applicable Requirements Area Source Outside UA/UC boundary §63.760 - Applicability and designation of affected source ' §63.760 (f) - The owner or operator of an affected major source shall achieve compliance with the provisions of this subpart by the 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. Page 10 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado §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: LOFT =1.15*3.0gal TEG*(F*(I—O)) 1b H2O 24hr/day Where: LOPT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) O = 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 sates 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). Page 11 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado §63.774 - Recordkeeping Requirements 563.774 (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) 563.774 (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. 563.774 (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. Page 12 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 563.775 - Reporting Requirements 563.775 (c) - Except as provided in paragraph (c)(8), each owner or operator of an area source subject to this subpart shall submit 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). 563.775 (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. 563.775 (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 source's location relative to the nearest UA plus offset and UC boundaries. This information 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). 563.775 (c)(7)(iii) - If applicable, documentation of the alternate glycol circulation rate 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 Page 13 of 28 COLORADO Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 &r MAINTENANCE REQUIREMENTS 25. Point(s) 001, 002, 004, 005, 006, 007: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (0&tM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the 0&tM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 26. Point(s) 001, 002: The owner or operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and, if necessary for emission factor development, a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine site -specific emissions factors for VOC and Hazardous Air Pollutants using Division approved methods. Results of site -specific sampling and analysis shall be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 27. Point(s) 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 Page 14 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 III.E.) 28. Point(s) 005, 006, 007: A source initial compliance test shall be conducted to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 29. Point(s) 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. 30. Point(s) 005, 006, 007: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (0&tM) plan as approved by the Division. Revisions to your 0&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 31. 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 (NOr) 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 Page 15 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 • sexisting APEN expires.i Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. GENERAL TERMS AND CONDITIONS 32. 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. 33. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 34. 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. Page 16 of 28 COLORADO Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado 35. 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. 36. 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. 37. 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. 38. 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. Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Summit Midstream Niobrara, LLC. Page 17 of 28 COLORADO Air Pollution Control Division Department of Pubf c Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part lI.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) TK-01 001 Benzene 71432 12 1 n -Hexane 110543 9,292 906 TK 02-05 002 Benzene 71432 6 1 n -Hexane 110543 80 8 BD -01 003 Benzene 71432 43 43 n -Hexane 110543 994 994 DU -01 004 Benzene 71432 104,380 5,000 Toluene 108883 34,880 1,660 Ethylbenzene 100414 2,660 120 Xylenes 1330207 1,540 80 n -Hexane 110543 55,860 1,580 GE -01 005 Formaldehyde 50000 10,394 2,543 Acetaldehyde 75070 551 275 Acrolein 107028 339 169 Page 18 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Methanol 67561 165 82 n -Hexane 110543 73 37 Benzene 71432 29 14 CE -O1 006 Formaldehyde 50000 11,105 2,665 Acetaldehyde 75070 1,237 619 Acrolein 107028 761 380 Methanol 67561 370 186 n -Hexane 110543 164 82 Benzene 71432 65 33 CE -02 007 Formaldehyde 50000 11,105 2,665 Acetaldehyde 75070 1,237 619 Acrolein 107028 761 380 Methanol 67561 370 186 n -Hexane 110543 164 82 Benzene 71432 65 33 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) Point(s) 001: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 20.55 1.03 E&tP Tanks 110543 n -Hexane 2.546 0.127 EEtP Tanks Note: The controlled emissions factors for this point are based on a control efficiency of 95% due to 5% annual VRU downtime. Point(s) 002: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.110 0.01 ProMax Note: The controlled emissions factors for this point are based on a control efficiency of 95% due to 5% annual VRU downtime. Page 19 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Point(s) 003: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source VOC 20842 ProMax 110543 n -Hexane 955 ProMax Point(s) 004: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Controlled emissions are based on a condenser control of 95% and VRU annual operation -minus -downtime of 95%. Flash tank emissions are rerouted to inlet at assumed 100% collection. No combustion emissions are expected from this point. CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Source VOC 68.83 GlyCalc 71432 Benzene 9.53192 GlyCalc 108883 Toluene 3.18552 GlyCalc 100414 Ethylbenzene 0.24296 GlyCalc 1330207 Xylenes 0.1404 GlyCalc 110543 n -Hexane 5.10064 GlyCalc Point 005: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors - g/bhp-hr NOx 0.1517 0.50 0.1517 0.50 CO 0.8008 2.64 0.0561 0.18 VOC 0.4186 1.38 0.2135 0.70 50000 Formaldehyde 0.1577 0.52 0.0379 0.12 75070 Acetaldehyde 0.0084 0.03 0.0084 0.03 107028 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n -Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Page 20 of 28 COLORADO Air Pollution Control Division Department of Public Health t Environment Dedicated to protecting and improving the health and environment of the people of Colorado Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7268 Btu/hp-hr, a site -rated horsepower value of 1035, and a fuel heat value of 1134 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx manufacturer Catalyst CO manufacturer Catalyst VOC manufacturer Catalyst 50000 Formaldehyde manufacturer Catalyst 75070 Acetaldehyde AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 67561 Methanol AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 110543 n -Hexane AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 71432 Benzene AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 108883 Toluene AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Point 006 &t 007: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors - g/bhp-hr NOx 0.1631 0.50 0.1631 0.50 CO ` 0.8255 ' 2.53 0.0578 0.18 VOC 0.3426 1.05 0.2295 0.70 50000 Formaldehyde 0.0750 0.23 0.0180 0.06 75070 Acetaldehyde 0.0084 0.03 0.0084 0.03 107028 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n -Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 6757 Btu/hp-hr, a site -rated horsepower value of 2500, and a fuel heat value of 1134 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx manufacturer Catalyst CO manufacturer Catalyst VOC manufacturer Catalyst 50000 Formaldehyde manufacturer Catalyst Page 21 of 28 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado CAS Pollutant Uncontrolled EFSource Controlled EF Source 75070 Acetaldehyde AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 67561 Methanol AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 110543 n -Hexane AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 71432 Benzene AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 108883 Toluene AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Point(s) 004: 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) Point(s) 005, 006, 007: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf 9) Point(s) 005, 006, 007: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html Page 22 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 10) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs, CO PSD or NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Applicable MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 11) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT ` 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 23 of 28 COLORADO Air Pollution Control Division Department of Public Health 5 Environment Dedicated to protecting and improving the health and environment of the people of Colorado ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count, as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. 2.1.2 The owner or operator may permanently replace the existing engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all Page 24 of 28 COLORADO Air Pollution Control Division Department of Public Health S Environment Dedicated to protecting and improving the health and environment of the people of Colorado permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at www.colorado.gov/cdphe/air/AOS. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: www.colorado.gov/cdphe/portable-analyzer- monitoring-protocol Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. Page 25 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII E — State -only requirements Page 26 of 28 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500≤Hp July 1, 2007 July 1,2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60 Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JUL An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The Page 27 of 28 COLORADO Air Pollution Control Division Department of Public Health ft Environment Dedicated to protecting and improving the health and environment of the people of Colorado AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. Page 28 of 28 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 res 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. RECEIVED FEB 1 2 r�2019 1PCD StatioQury Scrurcc.,5 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: 1g we. o AIRS ID Number: 3 /' 1 Q Z1/ 00 t 2. [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: Summit Midstream Niobrara, LLC Brahma Compressor Station SW 1/4 Sec 28 T12N R63W Mailing Address: (Include Zip Code) 999 18th Street, , Suite 2500S Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Address2: aparisi@summitmidstream.com Andrew Parisi (303) 626-8269 i Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 393310 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 1 "c t.oR:A DO tiimitOMEitelioNniie I 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 ❑✓ 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 $312.50 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment 0 Change company name3 ❑ Change permit limit 0 Transfer of ownership4 ❑ Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-1O6) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Condensate Storage Company equipment Identification No. (optional): TK-01 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 07/01/2019 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: 0 Exploration Et Production (E&P) site El Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? ■ Yes SI No Are Flash Emissions anticipated from these storage tanks? 12 Yes • No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? IN Yes I5I No If "yes", identify the stock tank gas -to -oil ratio: 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 actualIN emissions ≥ 6 ton/yr (per storage tank)? Yes No ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 21 COLORADO MAUI b GreUarmml 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 (bbllyear) Requested Annual Permit'Limit5 :Condensate Throughputso 3,650 From what year is the actual annual amount? Projected Average API gravity of sales oil: 80.16 degrees ❑ Internal floating roof Tank design: ❑✓ Fixed roof RVP of sales oil: 10.48 ❑ External floating roof ,Storage Tank ID of Liquid Manifold Storage ,essels in Storage Tan Tdtal Volume of Storage,Tank (bbl) ista{lation Date -of Most Recent Storage Vessel in Storage Tank (month/ year) Dateof First Production `. (month/year),::; TK-01 1 400 TBD TBD 111 Number, Wells Serviced t y this Storage Tank or Tank Battery6 (E&P Sites Only) Name of Well Newly Reported Well 0 0 0 0 0 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 The EFtP 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) 40.9801601, -104.4285920 Operator; Stack ID No Discharge Height Above ,,.Ground Level (feet) _ Temp. 9 - (F);: w . Flow Rate '(ACFM) i . ,Velocity., (ft/sec): Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO IiBatiMjiEnvU W tmtinl 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. Pollutants Controlled: VOC & HAPs Vapor ❑✓ Recovery Unit (VRU): Size: TBD Make/Model: TBD Requested Control Efficiency: 95 VRU Downtime or Bypassed (emissions vented): 5 ❑ 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 MMBtu/hr hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (EftP 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 7/2018 4 COLOR A Wwinfar 4i xn .e 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 form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC VRU 95 NOx CO HAPs VRU 95 Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory, Pollutant Emission Factor 7 Actual Annual Emissions Requested Annual Permit Emission Limit(s)5: Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions .(Tons/year) Controlled Emissionss (Tonslyear). Uncontrolled Emissions (Tons/year) Controlled Emissions .(Tons/year),,, VOC 20.546 lb/bbl E&P Tanks 37.50 1.87 NOx CO Non -Criteria Reportable Pollutant Emissions Inventory . . Chemical Name . .. Chemical Abstract Service (CAS) Number ` Emission Factor? : Actual Annual Emissions Uncontrolled Basis Units , Source (AP -42, Mfg, etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions 8 (Pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2.546 lb/bbl E&P Tanks 9,293 465 2,2,4- Trimethylpentane 540841 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 7 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. 8 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 7/2018 5 ICOLORADO= �fi at hBkn MtA�ilcnt 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. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (print) Title Check the appropriate box to request a copy of the: j✓ Draft permit prior to issuance Q✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 43OO Cherry Creek Drive South Denver, CO 80246-153O Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 6 COLORADO DcpwarsziorPulac tc.n: s anvirenmaet RECEIVED FEB 1 2 2019 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, inclu updates. An application with missing information may be determined incomplete and may be returned or res 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. APCD Stationary 3n1B B'ti per„„�. 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.Qov/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. AIRS ID Permit Number: � lei U�t E O I (.Q Number: 123 IA.02q/ 2Q" L 002' [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Site Location: Summit Midstream Niobrara, LLC Brahma Compressor Station Site Location SW 1/4 Sec 28 T12N R63W County: Weld Mailing Address: (Include Zip Code) 999 18th Street, Suite 2500S Denver, CO 80202 NAICS or SIC Code: 1311 Contact Person: Andrew Parisi Phone Number: (303) 626-8269 E -Mail Address2: aparisi@summitmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 393311 COLORADO Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 1 I 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 0 GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. OR - ▪ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 ❑ Change permit limit ❑ Transfer of ownership4 0 Other (describe below) - OR • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air, Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Company equipment Identification No. (optional): For existing sources, operation began on: Produced Water Storage TK 02-05 For new or reconstructed sources, the projected start-up date is: 07/01/2019 Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑ Exploration & Production (E&P) site weeks/year ❑✓ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? • Yes A No Are. Flash Emissions anticipated from these storage tanks? Ol Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? ❑ Yes No ✓ Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? 151 Yes ❑ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series wrest If so, submit Form APCD-105. ❑ Yes No ✓ Are you'requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? ❑ Yes No ✓ Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 21 COLORADO, of Public }bath 6 bovlmnment 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 (bbll year) Produced Water Throughput: Requested Annual Permit Limits (bbl /year) 40,150 From what year is the actual annual amount? Tank design: ❑ Fixed roof Projected ❑ 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.(month/year) ate of First Production (monthlyear) TK 02-05 4 1600 TBD TBD Wells Serviced by this Storage Tank or Tank Batter/ (EttP Sites On y) API Number Name of Well Newly Reported Well 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 The EfrP 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) 40.9801601, -104.4285920 Operator Stack ID No. Discharge Height 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): 0 Upward with obstructing raincap Indicate the stack opening and size: (check one) O Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ['Other (describe): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 3I coL0RAno< Hontii siRa�i9renent 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: VOC & HAPs Size: TBD Make/Model: TBD Requested Control Efficiency: 95 VRU Downtime or Bypassed (emissions vented): 5 ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: 0/0 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 7/2018 4 COLORADO. 5 h0F.0J lluncnk keulllsBF ui�rtnmrtmt 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 form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) : Overall Requested Control Efficiency (% reduction in emissions) VOC VRU 95 NOx CO HAPs VRU 95 Other: From what year is the following reported actual annual emissions data? Criteria PollutantEmissions Inventory Pollutant VOC Emission Factor7. Actual Annual Emissions Requested Annual Permit Ernission:Limit(s)s Uncontrolled Basis 0.11 Units lb/bbl • Source (AP -.42, ':Mfg., etc.) Eng. Est. Uncontrolled Emissions_ (tons/ year) ,,: Controlled Emissions ,(tons/year) Uncontrolled Emissions (tons/year). 2.21 Controlled Emissions - ftonsiyear).; 0.11 NOx CO Non -Criteria Reportable Pollutant Emissions Inventory . . Chemical Nellie' Chemical Abstract Service (CAS) Number Emission Factor? Actual Annual Emissions,.. Uncontrolled Basis Units Source (AP -42, mfg., etc. g ) Uncontrolled Emissions (pounds/year) y ) Controlled Emissions$' .. . (pounds/year): Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4- Trimethylpentane 540841 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 7 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. 8 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 7/2018 5 COLD Rfl DO MCA= wa�c��w�,��: n 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. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (print) Title Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.Rov/cdphe/apcd Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 6j COLORADO. ..._.m sE„wemOwni cI1UEI) Fro 2 2019 iP r 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 gas venting only. Gas venting includes emissions from gas/liquid separator casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.aov/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: `a vvE--'Q DI AIRS ID Number: t 23 /p-02.1/ C70 3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Namet: Summit Midstream Niobrara, LLC Site Name: Brahma Compressor Station Site Location: SW1/4 Sec 28 T12N R63W Mailing Address: 999 18th Street, Suite 2500S (Include Zip Code) Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO Contact Person: Andrew Parisi Phone Number: (303) 626-8269 E -Mail Address2: aparisi@summitmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 7/2018 1 333303 COLO:RAD'O- o.p.,®,eaPublic xwroscnm,.n Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership' 0 Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Facility blowdown emissions 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Natural gas venting during facility downtime Company equipment Identification No. (optional): BD -01 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 07/01/2019 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: TBD hours/day TBD days/week TBD weeks/year 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? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Yes Yes Yes Form APCD-211 - Gas Venting APEN - Revision 7/2018 2 ❑✓ No ❑✓ No ❑✓ No COLORADO wtOvum. Nftsn nM 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 Serial #: Capacity: gal/min Make: Model: # of Pistons: Leak Rate: Scf/hr/pist ❑✓ Blowdown Events # of Events/year: 104 Volume per event: 0.01 MMscf/event ❑✓ Other Description: Maintenance, Startup, Shutdown, Upset, and Emergency Conditions If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ Yes ❑✓ No Vent Gas Heating Value: 1,221 BTU/SCF Requested: 1.04 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 23.95 VOC (Weight %) 32.99 Benzene (Weight %) 0.08 Toluene (Weight %) 0.02 Ethylbenzene (Weight %1 0.0013 Xylene (Weight %) 0.0006 n -Hexane (Weight %) 1.52 2,2,4-Trimethylpentane (Weight %) 0.00 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) E 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 31 :CO L0:St;k'C Q, uq�raums, �P,.]2ic ht�il Ssr.Nx9vnitC Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information e®raphical Coordinate: (Latitude/Longitude or LITM) 40.9801601, -104.4285920 k • a ® w� � C n Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap. Section 6 - Control Device Information ❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑ VRU: Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed: Make/Model: ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-211 - Gas Venting APEN - Revision 7/2018 AVM L ItA Any?, 4 I MYm Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (X reduction in emissions) . PM SOX NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? Projected Criteria Pollutant Emissions Inventory .. Pollutant Emission Factor Actual Annual Emissions Requested Annual.Perniit Emission Lim Uncontrolled Basis Units Source (AP 42, Mfg., etc.) Uncontrolled Emissions' (tons/year) Controlled Emissionss. (tons/year), Uncontrolled Emissions (tons/year) Controlled Emissions (tonslyear) PM SOX NO. CO VOC 20.827 Ib/Mscf Promax 10.83 10.83 Non-CriteriaReportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service(CAS) Number Emission Factor :. Actual Annual Emissions. Uncontrolled Basis Units source (AP -42; Mfg., etc.) Uncontrolled Emissions . (pounds/year) Controlled Emissions 6 (pounds%year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.961 lb/Mscf Promax 1000 1000 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 7/2018 51 COLORADO c�xm:mar ue: 3i Pntl M `m Ei1k1'mnmsnt 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. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (please print) Title Check the appropriate box to request a copy of the: ID Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.Rov/cdphe/apcd Form APCD-211 - Gas Venting APEN - Revision 7/2018 6J COLORADO Dup.:mantllatc Warn, 6 EnaJtomnael RECEIVED FEB 1 2 2019 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, includin updates. An application with missing information may be determined incomplete and may be returned o s longer application processing times. You may be charged an additional APEN fee if the APEN is filled ou 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 (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.i;ov/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. AFCT) Permit Number: iq Aja-c) ( ( AIRS ID Number: 23 /king/ (1Q4 - [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Summit Midstream Niobrara, LLC Site Name: Brahma Compressor Station Site Location: SW 1/4 Sec 28 T12N R63W Mailing Address: (Include Zip Code) 999 18th Street, Suite 2500S Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Andrew Parisi Phone Number: (303) 626-8269 E -Mail Address2: aparisi@summitmidstream.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 393312 Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 1 I Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit ft 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 O Change company name3 ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' O Other (describe below) OR - ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info &t Notes: Flash tank emissions routed to facility inlet for 100% control 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Dehydration of natural gas Company equipment Identification No. (optional): DU -01 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 07/01/2019 ✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment area? hours/day days/week Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions? ❑ Yes Yes l Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 2 weeks/year No No COLORADO. Health 6 L` aimonnad Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Dehydrator Serial Number: Glycol Used: Glycol Pump Drive: TBD Model Number: 30MMSCFD TEG Dehy Reboiler Rating: 1 .5 ❑ Ethylene Glycol (EG) O DiEthylene Glycol (DEG) 0 0 Electric O Gas Pump Make and Model: TBD If Gas, injection pump ratio: MMBTU/hr TriEthylene Glycol (TEG) Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 12 1.0 Wt.% Requested: 12 Acfm/gpm # of pumps: TBD Dehydrator Gas Throughput: Design Capacity: Requested5: 30 MMSCF/day 10,950 MMSCF/year Actual: MMSCF/year Inlet Gas: Water Content: Flash Tank: Cold Separator: Pressure: 800 psig Wet Gas: 69.37 lb/MMSCF Pressure: 60 psig Pressure: psig Stripping Gas: (check one) O None ❑ Flash Gas O Dry Gas O Nitrogen Flow Rate: scfm Temperature: ❑ Saturated Temperature: Temperature: 100 Dry gas: 160 °F °F 5.0 °F lb/MMSCF ❑ NA ❑✓ NA Additional Required Information: O Attach a Process Flow Diagram O Attach GRI-GLYCaIc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results) O Attach the extended gas analysis (including BTEX n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 3 1 Permit Number: AIRS ID Number: / I [Leave blank unless APCD has already assigned a permit €t and AIRS ID] Section 5 - Stack Information 40.9801601, -104.4285920 - �L r 4, " e - ci r Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): O Upward with obstructing raincap Interior stack width (inches): Interior stack depth (inches): Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ® Condenser: Used for control of: Still Vent Type: TBD Make/Model: TBD Maximum Temp: 160 °F Average Temp: Requested Control Efficiency: Variable °F ❑✓ VRU: Used for control of: Condenser, Storage Tanks Size: TBD Make/Model: TBD Requested Control Efficiency: 95 VRU Downtime or Bypassed: 5 ❑ Combustion Device: Used for control of: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: MMBtu/hr Make/Model: Minimum Temperature: °F Waste Gas Heat Content: Btu/scf Constant Pilot Light: O Yes O No Pilot Burner Rating: MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime: O Other: Used for control of: Description: Requested Control Efficiency: Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 4 COLORADO rom` em Daimm nsot t Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Methods) : 0 I e uested venal Requested Control Efficiency. (%.reduction in emissions) PM SOX NO. CO VOC VRU/Condenser -97.5 HAPs VRU/Condenser -95.8 Other: From what year is the following reported actual annual emissions data? pollutant PM Source (AP -42 = Mfg., etc.) Criteria Pollutant Emissions Inventory_ Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 .. Uncontrolled Basis Units Uncontrolled Emissions' (tonslyear) Controlled Emissions6 (tonslyear) Uncontrolled Emissions (tonstyear) Controlled. Emissions (tons/year) SOX NO. CO VOC 86.04 lb/hr GRI-GLYcalc 376.84 9.44 Non -Criteria Reportable Pollutant Emissions. Inventory Chemical Name Chemical : Abstract Service (CAS) Number Emission Factor Actual Annual Emissions.. Uncontrolled Bass ` Units Source AP -42, ( Mfg., etc) . Uncontrolled Emissions _ . (poundslyear) Controlled Emissions 6 (pbunds/year) . 5000 Benzene 71432 11.92 lb/hr GRI-GLYcalc 104380 Toluene 108883 3.98 lb/hr GRI-GLYcalc 34880 1660 Ethylbenzene 100414 0.3 lb/hr GRI-GLYcalc 2660 120 Xylene 1330207 0.18 lb/hr GRI-GLYcalc 1540 80 n -Hexane 110543 6.38 lb/hr GRI-GLYcalc 55860 1580 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 5I coLo_R A fin ag . 7amm•.;e Kw{�h bEF.vvtfwlment 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. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-.202 - Glycol Dehydration Unit APEN - Revision 7/2018 6 I COLORADO Grtatthfr n5NP�: a !`.oatlhfF .m,un S Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including A updates. An application with missing information may be determined incomplete and may be returned or re 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 spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. 4s Permit Number: I q w e o q AIRS ID Number: I,25 0.02,q1 2!1/ 00 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Summit Midstream Niobrara, LLC Site Name: Brahma Compressor Station Site Location: SW 1/4 Sec 28 T12N R63W Mailing Address: (Include Zip Code) 999 18th Street, Suite 2500S Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Andrew Parisi Phone Number: (303) 626-8269 E -Mail Address2: aparisi@summitmidstream.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. z Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 1 393313 COLORADO Waft,° "`yam 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 (check one below) O STATIONARY source O PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Add point to existing permit O Change permit limit O Transfer of ownerships O Other (describe below) - OR ▪ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. GE -01 Yes General description of equipment and purpose: Power Generation For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.eov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year 07/01/2019 ❑ Yes ✓❑ No Seasonal user percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 21 COLORADO DEparattans avaaie Heal%b Lnairokune }t Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Engine Information Engine Function: ❑✓ Primary and/or Peaking Power ❑ Emergency (max. 500 hrs/year) ❑ Compression ❑ Pump Jack ❑ Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Caterpillar Engine Model: G3512B Serial Number7: TBD What is the maximum designed horsepower rating? 1035 hp What is the maximum manufacturer's site -rating? 1035 hp 772 kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7268 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑✓ Lean Burn ❑ Rich Burn Aspiration: O Natural ® Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes O No If yes, what type of AFRC is in use? ❑ OZ Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? p Yes O No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GPO2 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 3 I :y COLORADO AeallhffiASWMnin6t Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information eographicaI Coordinates Lotitude!Lor.2iWde or'1JT/A) 40.9801601, -104.4285920 t'. 3 t 'n•G` C e N F x GE -01 TBD 980 6681 TBD Indicate the direction of the Stack outlet: (check one) O Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information 6�"t�wlJ� i. .;�� v,. I a-i n...>i3£G��,F/ye a.i+� F 4lx+ Gr iPil ^5y��.�S'Y .. i _ 5 :. 4 g..` � 11fr 7375 S -e. d From what year is the actual annual amount? Projected Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) D Field Natural Gas Heating value: 1134 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): � •`/ (-i/ifi z 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I COLORADO 0:Feranmtnt Pa He e.emm sznmeanmani Permit Number: AIRS ID Number: I / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Rul�utant PrlrnaryfiControl Equi pent Description Overall Requested Control Efficiency f�breduetipn in. emissions) .. _ . TSP (PM) PM 10 PM2.5 SOx NOx VOC Oxidation Catalyst 49 CO Oxidation Catalyst 93 Other: Oxidation Catalyst (HCHO/iotal HAPs) 76 / 50 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Vin.tens Polt0, 40 Ei*sian , Ti$:. )D Pollutants .. ELriissipp Factor Actual Annual Emisstonsi° `:.d "' pp. -t,, `` r eLluested rntlal`p anti ErnlSS1Un 1_lmil (s) lnconed Basis Umts Source ( P 42, . Mfg ete)y. Uncontrolled d Emissions v..(tons/year) , Controlled Emissions (tons/year) Uncontrolled Emissions ;:`(tons`/year) i4iontrolle'd emissions (₹ons)yeai j TSP (PM) PM 10 PM2.5 SOx NOx 0.5 g/bhp-hr Manf. 5.00 5.00 VOC 1.38 g/bhp-hr Manf. 13.79 7.00 CO 2.64 g/bhp-hr Manf. 26.38 1.85 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 ® Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non Criteria Reportable Pollutant Emissions Inventory nCheinical Name Chemical Abstract � � Sernc� (CAsj umber Emission Factor Actual nnual Eni)sstons1° Uncontrolled Basis- Units rr Source � (AP-4�; Mfg: etc) U c nt � n o rolled �� s r Ern�issioras`� # (Pounds/year) . � Cyonti Alled Emissions ., fpounds/year)G ... Formaldehyde 50000 0.52 g/bhp-hr Manf. 10,394 2,543 - - Acetaldehyde - - 75070 --" 8.36E-03 - lb/MMbtu AP -42 - -- - 551 - -- -275 - Acrolein 107028 5.14E-03 lb/MMbtu AP -42 339 169 Benzene 71432 Other: 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 51 LO:RR lib. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (please print) Title Check the appropriate box to request a copy of the: p✓ Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.Qov/cdohe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 6I COLORADO, Hain; (A Eaviemmr a Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including AP 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 spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdohe/ancd. 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 C V U u O AIRS ID Number: t 2:5 /�.� 2�/ 0069 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Summit Midstream Niobrara, LLC Site Name: Brahma Compressor Station Site Location: SW1/4 Sec 28 T12N R63W Mailing Address: (Include Zip Code) 999 18th Street, Suite 2500S Portable Source Home Base: Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Andrew Parisi Phone Number: (303) 626-8269 E -Mail Address2: aparisi@summitmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 393314 COLORADO Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source O PORTABLE source El Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit O Transfer of ownerships O Other (describe below) - OR APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info ft Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 5 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CE -01 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Hpurs of Source Operation: 24 hours/day 7 07/01/2019 ❑ Yes ❑✓ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 21 'COLORADO WWII*WWII* oer.eam [mlKTmaM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power ❑ Emergency (max. 500 hrs/year) 0 Compression ❑ Pump Jack ❑ Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Caterpillar Engine Model: G3608 Serial Number: XH70092 What is the maximum designed horsepower rating? 2500 hp What is the maximum manufacturer's site -rating? 2500 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 6757 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: 0 Lean Burn O Rich Burn Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? ❑ Oz Sensor (mV) ❑NOX Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? 0 Yes ❑ No Engine Dates: What is the manufactured date of this engine? 05/2018 What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 3 _COLO:e,k 0O 1YoaSu�5.fuaiecdnncat Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information raaphical Coordinate; (Latitude1Laiig�tude pr liT 40.9801601, -104.4285920 rator .,,t,. ' Ti°1, Di r e qy" 1 d�'i`{ J4?3�... �r�.`o tpe ''fi F 2,a ' 3 ,"I� .rr' i' VII+. CE -01 TBD 840 15958 TBD Indicate the direction of the Stack outlet: (check one) p Upward O Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) E Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): O Other (describe): O Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information RR a;��...:£4.a...e�4 14897 131 From what year is the actual annual amount? Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1 134 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf O Other (describe): Heating Value (give units): 8 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 COLORADo. ce en9=rucic }I IAA tr F.r, Vinannoibt Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0✓ Yes D No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 Sox NOx VOC Oxidation Catalyst 33 CO Oxidation Catalyst 93 Other: Oxidation Catalyst (HCHO/Total HAPs) 76 / 50 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? .Criteria Pollutant Emissions Inventory - Pollutant Emission Factor. • Actual Annual Emissions D Requested Annual Permit Emission Limit(s)e ...; Uncontrolled ` Basis ,. Units. Source ' (AP -42, , Mfg. etc) • Uncontrolled Emissions . (tons/year) • Controlled: Emissions (tons/year) . Uncontrolled Emissions (tons/year) Controlled ,Emissions (tons/year), TSP (PM) PM10 PM2.5 SOX NOx 0.5 g/bhp-hr Manf. 12.07 12.07 VOC 1.05 g/bhp-hr JJJJ 25.35 16.90 CO 2.53 g/bhp-hr Manf. 61.08 4.28 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 ❑✓ Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria .. , l... .. . . ... Reportable. Pollutant Emissions Inventory .:: Chemical Name Chemical :. Abstract (CAS) t ) Number. . Emission Factor Actual Annual Emissions" Uncontrolled Basis Units Source . (AP -42, : Mfg. etc) _ � ....:.(poundal Uncontrolled Emissions ear .. (pounds/year) Controlled Emissions (pounds/year) 2,665 Formaldehyde 50000 0.23 g/bhp-hr Manf. 11,105 Acetaldehyde 75070 - - 8.36E-03 Ib/MMbtu AP -42 1,237 - - - - -619 Acrolein 107028 5.14E-03 Ib/MMbtu AP -42 761 380 Benzene 71432 Other: Methanol: 67561 2.50E-03 lb/MMbtu AP -42 370 185 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark ignition Engine APEN - Revision 7/2018 5J COLO;&A1E3O Y a tulT¢. 1' • Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (please print) Title Check the appropriate box to request a copy of the: E✓ Draft permit prior to issuance 0✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: ' Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.Rov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 6I COLORADO, o.nrnallsm Fcl:ie' HeAlhb F.Wremnael Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, includir EN updates. An application with missing information may be determined incomplete and may be returned longer application processing times. You may be charged an additional APEN fee if the APEN is filled o incorrectly or is missing information and requires re -submittal. RECEIVED FEB 1 2 2019 APCD Stss6i6490R1ry ��uurGv�� This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: IcWvO[(9 AIRS ID Number: 25 /4.02i/0o1 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Summit Midstream Niobrara, LLC Site Name: Brahma Compressor Station Site Location: SW1/4 Sec 28 T12N R63W Mailing Address: (Include Zip Code) 999 18th Street, Suite 2500S Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Andrew Parisi Phone Number: (303) 626-8269 E -Mail Address2: aparisi@summitmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 1 I 393315 c,4l.oenDa- Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source O PORTABLE source O Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownerships O Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GPO2, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CE -02 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.Rov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 07/01/2019 ❑ Yes ❑✓ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 2 ® COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power ❑ Emergency (max. 500 hrs/year) ❑✓ Compression ❑ Pump Jack ❑ Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Caterpillar Engine Model: G3608 Serial Number7: TBD What is the maximum designed horsepower rating? 2500 hp What is the maximum manufacturer's site -rating? 2500 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 6757 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑✓ Lean Burn O Rich Burn Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes ❑ No If yes, what type of AFRC is in use? ❑ OZ Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: is this engine equipped with a Low-NOx design? ❑✓ Yes O No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 3 C:OLO;t3;A U'O, NNFIhEEm4kiakip,t Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information 40.9801601, -104.4285920 erator t^ .u^ ➢^ @ �' "=�1 ,} yt l . bA S��Y-, '4, i; 13 P q �i.` } 1Kvr e ay w CE -02 TBD 840 15958 TBD Indicate the direction of the Stack outlet: (check one) 0 Upward ❑ Horizontal O Downward Other (describe): Indicate the stack opening and size: (check one) 0✓ Circular Interior stack diameter (inches): O Square/Rectangle Interior stack diameter (inches): O Other (describe): O Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information 14897 From what year is the actual annual amount? Indicate the type of fuel used9: Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0✓ Field Natural Gas Heating value: 1134 BTU/scf Propane (assumed fuel heating value of 2,300 BTU/scf) Landfill Gas Heating Value: BTU/scf Other (describe): Heating Value (give units): 131 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I C 0.1,9 RADO Heanh B£ir#tiimam Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM). PM10 PM2.5 SOx NOx VOC Oxidation Catalyst 33 CO Oxidation Catalyst 93 Other: Oxidation Catalyst (HCHO7rotal HAPs) 76 / 50 Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Pollutant TSP (PM) PM10 PM2.5 Source ,Mfg. etc); Uncontrolled. Basis Units Criteria Pollutant Emissions Inventory.'_ Actual Annual Emissions°. Uncontrolled Emissions (tons/year) ,. Controlled Emissions (tons/year) Requested Annual Permit Emission Limit(s)8 Uncontrolled Emissions (tons/year) Controlled. Emissions (tons/year) SOx NOx VOC CO 0.5 g/bhp-hr Manf. 12.07 12.07 1.05 g/bhp-hr JJJJ 25.35 16.90 2.53 g/bhp-hr Manf. 61.08 4.28 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 0 Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non Criteria Reportable Pollutant Emissions Inventory Chemical Name . Chemical • Abstract• Service (CAS) Number Emission Factor Actual Annual-Emissions1D Uncontrolled Basis Units Source: (AP -42,: Mf Mfg.. etc) Uncontrolled Emissions ,( oud year p nsl ) Controlled . Emissions: (pounds/year) 2,665 Formaldehyde 50000 0.23 g/bhp-hr Manf. 11,105 Acetaldehyde - 75070 8.36E-03 lb/MMbtu AP -42 1,237 619 Acrolein 107028 5.14E-03 lb/MMbtu AP -42 761 380 Benzene 71432 Other: Methanol: 67561 2.50E-03 lb/MMbtu AP -42 370. 185 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 5I cO Lo'rt'A no ate% xe-ims&rnwnmrm Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. 02/11/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Zak N. Covar Vice -President HSE&R Name (please print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance 0✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303)692-3150 Or visit the APCD website at: https: / /www. colorado. gov/cdphe/ apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 6I COLORADO, 'foam5FnrF[Rf(mmaT Hello