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Home My WebLink About20201463.tiffCOLORADO Department of Public Health b Environment Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 April 22, 2020 Dear Sir or Madam: RECEIVED APR 2 7 2020 WELD COUNTY COMMISSIONERS On April 23, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for Noble Energy, Inc. - GUTTERSEN/GUTTERSEN STATE D29 -22-A T3N-R64W-S29 L01. 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. Public Rev;ei 5/2.0/2.0 Colorado Dept. of Public Health &t Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Jared Polis, Governor I Jill Hunsaker Ryan, MPH, Executive Director CC : FL crP), H L4 -u), Pw (3 'VE t/cH/cK) ogvC) 5/13110 2020-1463 NE, AN fi j©ig �icin�; y Condensate Storage Tank(s) 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. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or tacks payment for the filing fee. The re -submittal will require payment for a new filing fee. 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.stov/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: f c'(,tfgolos AIRS ID Number: /23 '4 '1 j 001 [Lea'e blank unless APCD his all assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Noble Energy Inc. Site Name: GUTTERSEN/GUTTERSEN STATE 029-22-A T3N-R64W-529 Lot Site Location Site Location: SWNE SEC29 T3N R64W County: Weld Mailing (include Address: Code1625 Broadway, Zip Code) Suite 2200 Denver, CO 80202 NAICS or SIC Code: 1311 Contact Person: Janessa Salgado Phone Number: 303-228-4196 E -Mail Address2: janessa.salgado@nblenergy.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes wilt require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. ,PEN R visi r - _ 2 t« 415020 ] VW COLORADO 1 Permit Number: AIRS ID Number: _tank . E _5s APIJ has a_ e h a: sn a pern;tt ., arc. A ;D Section 2 - Requested Action El NEW permit OR newly -reported emission source ▪ Request coverage under traditional construction permit ❑ Request coverage under a General Permit 0 GP01 0 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 ownership' 0 Other (describe below) - OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDmONAL 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: Pilot emissions from enclosed combustors are included in heater treater and surge drum calculations. 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: Condensate Tanks (Off -Spec Tanks) 06/05/2019 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week (] Exploration & Production (E&P) site 52 weeks/year 0 Midstream or Downstream (non E&P) site Witt this equipment be operated in any NAAQS nonattainment area? r4 Yes N No Are Flash Emissions anticipated from these storage tanks? 0 Yes 17 No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? Yes 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 U GI Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No II f2 2 I �j c asrac eggs , Permit Number: AIRS ID Number: [Leave ht3 ‘, ,:Ih is APC D has ahrea07 s,;1 •�,. a perm iz 4 Pa Section 4 - Storage Tank(s) Information Actual Annual Amount (bb(/year) Condensate Throughput: Requested Annual Permit Limits (bbl/year) From what year is the actual annual amount? Average API gravity of sates oil: 48.50 degrees Tank design: }]+ Fixed roof O Internal floating roof 257,617 RVP of sates oil: •.93. iMOW ffi 8) O External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bb) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) Tanks 3 1,500 05/2019 Wells Serviced by this Storage Tank or Tank Battery's (EDP Sites Only) API Number Name of Well Newly Reported Well SEE ATTACHED ■ . ■ - - O ■ • ■ s Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1976, -104.5698 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) p Upward 0 Downward ❑ Horizontal 0 Other (describe): Indicate the stack opening and size: (check one) 2 Circular Interior stack diameter (Inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): 0 Upward with obstructing raincap interior stack depth (inches): 31 ADC Permit Number: AIRS ID Number: Leave Ward-, ;l1k $ APCD n S , Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 83 MMBtu/hr Type: Enclosed Combustor(s) Make/Model: Zeeco, H REC Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: Waste Gas Heat Content: Constant Pilot Light: (] Yes 0 No Pilot Burner Rating: Btu/scf MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 3 psig Describe the separation process between the welt and the storage tanks: Liquids go from well to HP separators, then to LP separators (heater treaters), then to surge drum, then to LACT. These tanks only take off -spec oil rejected from the LACT. Note, the enclosed combustor pilot emissions are accounted for in the heater treater/surge drum APEN because the combustors are shared. CO't 04iADO Permit Number: AIRS ID Number: 1 / untess A2(0 has .1{sc: ' iS ---Tled a perm2 4, and A R.€Dj 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 - - Enclosed Burner 95% NOx CO HAPs Enclosed Burner - 95% Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor1 Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions8 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) VOC 0.1218 lb/bbl HYSYsfranss 4.09e 15.69 0.78 NOx 0.068 lb/MMBtu AP -42 0.03 0.03 CO 031 Ib/MMBtu AP -42 0.12 0.12 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CM) Number Emission Factor? Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, M12., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions8 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.0040 lb/bbl HYSYS,T4O4 4 094 1,020 51 2,2,4- Trimethyipentane 540841 5 Requested values wilt 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. 59 �t Permit Number: AIRS ID Number: / o.; es.3 APCD has a !re:.ff 3 5t „j 3 r'z :1,,`' AiRS iDI 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. 08/29/2019 Sigjature of Legally Authorized Person (not a vendor or consultant) Date Janessa Salgado Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: QQ 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.coloredo.eovfcdphe/aped , c c� . 6 I AV' . E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Noble Energy, Inc. Source Name: GUTTERSEN/GUTTERSEN STATE O29 -22-A T3N-R64W-S29 L01 Emissions Source AIRS ID2: / / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 48050 GUTTERSEN D29-722 • 05 - 123 - 48048 GUTTERSEN D29-730 0 05 - 123 - 48045 GUTTERSEN D29-738 0 05 - 123 - 48043 GUTTERSEN D29-746 • 05 - 123 - 48044 GUTTERSEN D29-754 • 05 - 123 - 48040 GUTTERSEN D29-770 0 05 - 123 - 48038 GUTTERSEN D29-778 0 05 - 123 - 48042 GUTTERSEN D29-786 10 05 - 123 - 48049 GUTTERSEN STATE O29-714 • - - ■ - - ■ - - ■ - - 0 - - ■ - - ■ - - ■ - - • - - 0 - - U - - 0 Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 Form APCD-212 E&P Storage Tank APEN Addendum-Ver. 7-29-2014 Produced Water Storage Tank(s) 3 u zoo APEN — Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for 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.eovlpacific/cdphelair-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: l ci AiE l P AIRS ID Number: (2_3 /j}1)$7'6C 2 - [Leave blank unless APCD has already assigned a permit and AlPS ID) Section 1 - Administrative Information Company Name': Noble Energy Inc. Site Name: GUTTERSENIGUTTERSEN STATE 029-22-A T3N-R64WS29101 Site Location: SWNE SEC29 T3N R64W Mailing Address: (Include Zip 1625 Broadway, Suite 2200 Code) Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Janessa Salgado Phone Number: 303-228-4196 E -Mail Address2: janessasalgado@nblenergycom 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. 415021 207 ` vi, l ; iat r Storage t i,'1[ is l APENRevi.3m1 }.. Permit Number: AIRS ID Number: / / PCD has already z3>5; _. a pcfr-t* -c ALRS ₹3i Section 2 Requested Action 0 NEW permit OR newly -reported emission source 0 Request coverage under traditional construction permit O Request coverage under a General Permit O GP05 ❑ GPM 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 O Change company name3 ❑ Change permit limit O Transfer of ownership4 O Other (describe below) -OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT AcrioNs - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional info E Notes: Pilot emissions from enclosed combustors are included in heater treater and surge drum calculations. 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): Produced Water Storage For existing sources, operation began on: 06/05/2019 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 Storage tank(s) located at: 0 Exploration & Production (E&P) site days/week 52 weeks/year O Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? p Yes O No Are Flash Emissions anticipated from these storage tanks? (9 Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes Q No • Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? • Yes ❑ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes ❑✓ No • Are you requesting t 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions : 6 ton/yr (per storage tank)? Yes O No 4 Tani. 2 I A Vaoo Q Upward O Horizontal Permit Number: h ink 1r t .. tPCD has a'rU Sys= 24 AIRS ID Number: Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limits (bbUyear) Produced Water Throughput: 1,450,000 From what year is the actual annual amount? Tank design: 0 Fixed roof O Internal floating roof 0 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) Date of First Production (month/year) PW Tanks 4 2,000 06/2019 06/2019 Wells Serviced by this Storage Tank or Tank Battery(' (E&P Sites Only) API Number Name of Well Newly Reported Well - - SEE ATTACHED ■ - - ■ - • ■ . S Requested values will become permit limitations. Requested limit(s) should consider future growth. (' The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all welts that are serviced by the equipment reported on this APEN form. Section 5 - Stack information Geographical Coordinates (Latitude/Longitude or UTM) 40.1976, -104.5698 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) O Downward El Other (describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): Square/rectangle Interior stack width (inches): 0 Other (describe): 0 Upward with obstructing raincap Interior stack depth (inches): tTh 3I COLCAA00 Permit Number: AIRS ID Number: 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. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC and HAPs Rating: 83 MMBtu/hr Type: Enclosed Combustorls) Make/Model: Zeeco, H REC Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: gg Minimum Temperature: Constant Pilot Light: El Waste Gas Heat Content: Yes O No Pilot Burner Rating: Btu/scf MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (EQP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? - 300, 25, 3 psig Describe the separation process between the well and the storage tanks: Liquids from the wells go to HP separators, LP separators (heater treaters), and surge drums and all feed into the produced water storage tanks. Note, the enclosed combustor pilot emissions are accounted for in the heater treater/surge drum APEN because the combustors are shared. 4 1 AV Permit Number: AIRS ID Number: / V ._ a:;mu . a assignee a Per ,1t :. acid APS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN formr. 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 Enclosed Combustor 959E NOx Co HAPs Enclosed Combustor 95% Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor7 Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions$ (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) VOC 0.2620 lb/bbl CDPHE 189.95 9.50 NOx 0.068 Ib/MMBtu AP -42 2.66 2.66 CO 0.310 Ib/MMBtu AP -42 12.10 12.10 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service CAS (CAS) Number Emission Factor7 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissionse (pounds/year) Benzene 71432 0.0070 lb/bbl CDPHE 10,150 508 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.0220 lb/bbl CDPHE 31,900 1,595 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. 5 AV Permit Number: AIRS ID Number: [ a. ;i PC D atreaaJ assvg eu a permit 4 end AIR'S ?D 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. S 08/29/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Janessa Salgado Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑� Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 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.cotorado.Rovicdphe/apcd A,/ Aug 3020,9 Hydrocarbon Liquid Loading APENtcb Form APCD-208 Jib Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal: Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphefapcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, Ii.C. for revised APEN requirements. Permit Number: �W E�A998' AIRS ID Number: /Agr7/iiO3 Section 1 - Administrative Information Company Name1: Noble Energy Inc. Site Name: GUTTERSEN/GUTTERSEN STATE 029-22-A T3N-R64W-S29101 Site Location Site Location: SWNE SEC29 T3N R64W County: Weld Mailing Address: (include zip Code) 1625 Broadway, Suite 2200 Denver, CO 80202 NAICS or SIC Code: 1311 Contact Person: Janessa Salgado Phone Number: 303-228-4196 E -Mail Address2: janessa.salgado@nblenergycom 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. 415022 Permit Number: AIRS ID Number: Section 2 - Requested Action 0 NEW permit OR newly -reported emission source 0 Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 ❑ Change permit limit O Transfer of ownership's O Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Pilot emissions from enclosed combustors are included in heater treater and surge drum calculations. 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: Condensate Truck Loadout Company equipment Identification No. (optional): For existing sources, operation began on: 06/05/2019 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? 0 Yes No ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? O Yes No p Does this source load gasoline into transport vehicles? O Yes No ® Is this source located at an oil and gas exploration and production site? Yes O No V If yes: Does this source toad less than 10,000 gallons of crude oil per day on an annual average? Yes O No 4 Does this source splash fill less than 6750 bbl of condensate per year? Yes ❑ No p Does this source submerge fill less than 16308 bbl of condensate per year? O Yes 0 No 2� Permit Number: AIRS ID Number: Section 4 - Process Equipment Information Product Loaded: Q Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 257,617 bbl/year This product is loaded from tanks at this facility into: (e.g. "rail tank cars" or "tank trucks") Actual Volume Loaded: bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: .6 Average temperature of bulk liquid loading: 5 7925 . , F True Vapor Pressure: 4.2957 Psia ® 60 °F Molecular weight of displaced vapors: 67 V lb/lb-mot If this APEN is being filed for vapors displaced from pressurized loading tines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 3I A Permit Number: AIRS ID Number: / / Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1976, -104.5698 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) Ej Upward 0 Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular 0 Other (describe): Interior stack diameter (inches): 0 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. 0 Loading occurs using a vapor balance system: Requested Control Efficiency: ❑ Combustion Device: Used for control of: VOC and HAPs Rating: 83 MMBtu/hr Type: Enclosed Combustor(s) Make/Model: Zeeco, HREC Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 'F Waste Gas Heat Content: Btu/scf Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: MMBtu/hr 0 Other: Pollutants Controlled: Description: Requested Control Efficiency: Permit Number: AIRS ID Number: 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 (% reduction in emissions) PM SO, NO, CO VOC Enclosed Burner 95% HAPs Enclosed Burner 95% Other: ❑ Using State Emission Factors (Required for GP07) V0C Benzene n -Hexane ❑ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM 7.60 lb/MMscf AP -42 0.00 0.00 SOX 0.60 Ib/MMscf AP -42 0.00 , 0.00 NOx 0.068 lb/MMBtu AP -42 0.02 0.02 CO 0.310 lb/MMBtu AP -42 0.11 0.11 VOC 0.1766 lb/bbl AP -42 22.74 1.14 Non -Criteria Reportable Pollutant Emissions inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42. Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 Toluene 108883 0.0011 lb/bbl AP -42 287 14 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.0050 lb/bbl AP -42 1,283 64 2,2,4- Trimethylpentane 540841 Other: 5 Requested values wilt become permit limitations. Requested timit(s) should consider future process growth. 6 Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank. cG .D-3 Permit Number: AIRS ID Number: / Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. 08/29/2019 Sign ture of Legally Authori ed Person (not a vendor or consultant) Date Janessa Salgado Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance Ei 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.cotorado.gov/cdphe/aixd 61 m`' 4 1114:7 a zoo Gas Venting APEN - Form APCD-2 Air Pollutant Emission Notice (APEN) and Application for Construction Permit AU sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs wilt be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, btowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid. loading, condensate storage tanks, etc.). in addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt 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.gov/cdphelapcd. 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: f wralog MRS ID Number: 173 / } 7/ tw q - [t vcs Mink un:ir APCD has afroady assOnod a permit =' and AIRS ID Section 1 - Administrative Information Company Name1: Noble Energy Inc. Site Name: GUTTERSEN/GUTTERSEN STATE O29 -22-A T3N-R64W-S29 101 Site Location: SWNE SEC29 T3N R64W Mailing Address: 1625 Broadway, Suite 2200 (Include Zip Code) Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1311 Contact Person: Janessa Salgado Phone Number: 303-228-4196 E -Mail Address2: janessa.salgado@nblenergy.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. ao,m Art;:.Y I1 t„ r, trr>rttlaa APEN - Revision ;/201 415023 AA` Permit Number: AIRS ID Number: / APCD Its already assigned a permit t and AIR; I[)1 Section 2 - Requested Action 0 NEW permit OR newly -reported emission source - OR - O MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' O Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. ' 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: Heater treater and surge drum gas streams Company equipment Identification No. (optional): For existing sources, operation began on: 06/05/2019 For new, modified, or reconstructed sources, the projected start-up date is: ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment area? hours/day Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? i} .' 11 ion J days/week weeks/year O Yes O Yes ✓❑ Yes ❑ No 0 No ❑ No Permit Number: AIRS ID Number: .l�r� Lir;r;l trllr�--� APCI) ir.iS already assigned a permit and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min # of Pistons: Leak Rate: Scf/hr/gist. Volume per event: MMscf/event 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? ❑ Yes Gas Venting Process Parameters: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ No Vent Gas Heating Value: 2894 BTU/SCF Requested: 8.89 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 51.79 VOC (Weight %) 88.47% Benzene (Weight%) 0.44% Toluene (Weight %) 0.77% Ethylbenzene (Weight %) 0.02% Xylene (Weight %) 0.33% n -Hexane (Weight %) 3.25% 2,2,4-Trimethylpentane (Weight %) 0.00% Additional Required Information: • Attach a representative gas analysis (including BTEX & n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX ft n -Hexane, temperature, and pressure) 0 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 3IAr ^i'CO 211 APEN - Revision :/201° Permit Number: AIRS ID Number: APCI) has aUcady assEaned a permit and Ally; 1()I Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1976, -104.5698 Operator Stack ID No. Discharge Height Above t(FeeI d Level Temp. ('F) Flow Rate (ACFM) Velocity (t/sec) Indicate the direction of the stack outlet: (check one) Q Upward O Horizontal O Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular O Other (describe): Interior stack diameter (inches): O Upward with obstructing raincap 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. ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed: 0 Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 83 MMBtu/hr Type: Enclosed Combustor(s) Make/Model: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: Zeeco, HREC Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes O No Pilot burner Rating: 0.195 MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Vert ttr : tJ :E! • Revision /201'; 4 1 Any Permit Number: AIRS ID Number: / tall(“.,; ARCD has aalrCady assigned ra l,•.'ra t 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 (% reduction in emissions) PM SOx NO. CO VOC VOC Burner 95% HAPs VOC Burner 95% Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM 7.6 Ib/MMscf AP -42 0.01 0.01 SOx 0.6 lb/MMscf AP -42 0.00 0.00 NO. 0.068, 100 AP -42 1.04 1.04 CO 0.31,84 1WWW. 6"4.d AP -42 4.13 4.13 VOC 120,954.3359 Ib/MMscf HYSYS, AP -42 537.75 26.90 Non -Criteria Reportable Pollutant Emissions inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 598.0110 Ib/MMscf HYSYS/AP-42 5,317 266 Toluene 108883 1,045.9836 IbIMMscf HYSYS/AP-42 9,301 465 Ethylbenzene 100414 Xylene 1330207 448.4452 lb/MMscf HYSYS)AP-42 3,987 199 n -Hexane 110543 4,437.1164 Ila/MMsef HYSYS(AP-42 39,454 1,978 2'2'4- Trimethylpentane 540841 30.1572 Ita/MMscf HYSYS/AP-42 268 13 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. Gas 1'cntug<_+ M1'FIl - Revision J201 5I RIFcctop.na Permit Number: AIRS ID Number: / lank APCI) has already as fined a permit r, and AIRS IDI Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. (mudyU, S SignaEure of Legally Authorized Person (not a vendor or consultant) Janessa Salgado Name (please print) 08/29/2019 Date Environmental Engineer Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https //www.colorado.eov/cdphe/aped Venue ,\PEN Revisi /201'` Rectiv AU63n?©j Fugitive Component Leak Emissions APEN s4 Form APCD-203 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for fugitive component leak emissions only. If your emission source does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdpheincd. 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, 11.C. for revised APEN requirements. Permit Number: AIRS ID Number: j 23 /41A37 / 0C.5 L av blank i k unk .s APCD has already assigned a permit if and AIRS ID] Section 1 - Administrative information Company Name': Noble Energy Inc. Site Name: GUTTERSEN/GUTTERSEN STATE 029-22-A T3N-RR64W-529 LAS Site Location: SWNE SEC29 T3N R64W Mailing AddresCodey s: 1625 Broadway, Suite 2200 (Include Z#p ) Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1311 Contact Person: Janessa Salgado Phone Number: 303-228-4196 E -Mail Address2: janessa.salgado©nblenergy.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 415024 Amy ea cr s;aO Foul + +'t'D U l LOt.ive Component Leak Emissions APEti Revision :1201` p Permit Number: AIRS ID Number: / / ln.rve dates; APCD his already assigned a permit n and AIIP ID) Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) -OR - ❑ MODIFICATION to existing permit (check each box below that applies) o Change process or equipment O Change company name3 ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership4 O Other (describe below) - OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID 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: Estimated emissions include separators to be installed in the future. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information Company equipment Identification No. (optional): For existing sources, operation began on: Fugitives 06/05/2019 For new or reconstructed sources, the projected start-up date is: J Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Facility Type: Q Well Production Facilitys o Natural Gas Compressor Stations ❑ Natural Gas Processing Plants ❑ Other (describe): hours/day days/week weeks/year 5 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. kuOtivc Component Leak Emissions APEII - Revision ';/201, 2 A ' •' ir?R nLica Permit Number: AIRS ID Number: / / h,,s ralrc-adv as.Igi d a permit , as?cf AIRS ini Section 4 - Regulatory Information What is the date that the equipment commenced construction? Will this equipment be operated in any NAAQS nonattainment area? Will this equipment be located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seat centrifugal compressors or reciprocating compressors located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? Is this equipment subject to 40 CFR Part 60, Subpart 0000? Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? Is this equipment subject to 40 CFR Part 63, Subpart HH? Is this equipment subject to Colorado Regulation No. 7, Section XII.G? Is this equipment subject to Colorado Regulation No. 7, Section XViI.F? Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? 06/05/2019 0 Yes O Yes 0 Yes Yes Yes 0 Yes ❑ Yes ❑ Yes 0 Yes 0 Yes ❑No 0No ❑ No O No ❑No O No 0 No ❑ No No Section 5 - Stream Constituents The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight % content of each applicable stream. Stream VOC (wt %) Benzene (wt %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 2,2,4 Trime (ntane wt %) (wt %) Gas 40.00 0.10 0.05 0.05 0.05 0.20 0.05 HeavY(or Heavy q°iiuid) 100 0.25 0.13 0.13 0.13 0.50 0.13 Light O (or Light Liquid) 100 0.25 0.13 0.13 0.13 0.50 0.13 Water/Oil 100 0.25 0.13 0.13 0.13 0.50 0.13 Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UM) 40.1976, -104.5698 Attach a topographic site map showing location Component Leak Emissions APEN - Revision ?/201 3 i Al COLOF ADO Permit Number: AIRS ID Number: / / APC,D t a5 alraady assigned a permit ;i• aricl A'R ti)1 Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: 0 LDAR per 40 CFR Part 60, Subpart KKK ❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% tight liquid pump Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump 0 WAR per 40 CFR Part 60, Subpart OOOO/OOOOa Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81% connectors 0 LDAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: 0 No LDAR Program 6 Attach other supplemental plan to APEN form if needed. APCD 103 stive•Ceemponont Leak Emissions APEN • Revision s/201'' 4 I cccOR.4r>>< Permit Number: AIRS ID Number: / / 'Leave lilank unless APCL) has already assigned a permit ti and AIRS I©] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. include the units related to the emission factor. ❑ Table 2-4 was used to estimate emissions. El Table 2-8 (< 10,000ppmv) was used to estimate emissions7. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: ® Estimated Component Count Actual Component Count conducted on the following date: Service Equipment Type Connectors Flanges Open -Ended Lines Pump Seals Valves Other 9 Gas Counts 5,854 784 11 0 2,462 665 Emission Factor 1.00E-5 5.70E-6 1.5E-5 2.50E-5 1.20E-4 Units kg/hr/source kg/hr/source kg/hr/source kg/hr/source kg/hr/source Heavy Oil (or Heavy Liquid) Count& 353 0 0 0 118 0 Emission Factor 7.50E-6 8.40E-6 Units kg/hr/source kg/hr/source Light Oil (or Light Liquid) Count8 1,830 456 0 3 1,936 119 Emission Factor 9,70E-6 2,4E-6 5.10E-4 1.90E-5 1.10E-4 Units kg/hr/source kg/hr/source kg/hr/source kg/hr/source kg/hr/source Water/Oil Count8 971 28 0 0 333 118 Emission Factor 1.00E-5 2.90E-6 9.70E-6 5.90E-5 Units kg/hr/source kg/hr/source kg/hr/source kg/hr/source 7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The "other" equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seals, or valves, APC.0 U3 f u Alive Component Leak Emissions APEN - Revision J20I 5 J L l► Permit Number: AIRS ID Number: APC1) liar all assigned a permit and AIRS ID] Section 9 - Emissions inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: Use the data reported in Section 8 to calculate these emissions. Chemical Name CAS Number Actual Annual Emissions Requested Annual Limit(s)11Permit Emission Uncontrolled (tons/year) Controlled ,o (tons/year) Uncontrolled (tons/year) Controlled (tons/year) VOC 1.70 1.70 Does the emissions source have any actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name CAS Number Actual Annual Emissions Requested Annual s Permit Emission O" Uncontrolled abs/year) Controlled 10 (lbs/year) Uncontrolled (lbs/ ear) Controlled (lbs/year) Benzene 71432 Toluene 108883 Ethytbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4 Trimethylpentane 540841 Other: 10 Annual emissions fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. 1t Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability, and gas composition variability. proponent Leak Emissions APEN - Revision /201 6 1 Permit Number: AIRS ID Number: / / ;Lt avt. Mat& unlrrss APCD has atrcady assigncd a permit {tad AIR'S IDj Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. citokitt 08/29/2019 Signature of Legally Authorized Person (not a vendor or consultant) Date Janessa Salgado Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692.3150 Or visit the APCD website at: httos: / /www.colorado.Rov/cdphe/apcd rr APCD-?03 rustitive Component Leak Emissions APEN - Revision /201'') �T� {°�- 7I _ - 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 CONSTRUCTION PERMIT Permit number: 19WE0908 Issuance: 1 Date issued: Issued to: Noble Energy, Inc. Facility Name: Guttersen/Guttersen State D29 -22-A T3N-R64W-S29 L01 Plant AIRS ID: 123/A087 Physical Location: SWNE SEC 29 T3N R64W County: Weld County Description: Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Tanks 001 Three (3) 500 barrel fixed roof storage ' vessels used to store condensate Enclosed Combustor Produced Water Tank 002 Four (4) 500 barrel fixed roof storage vessels used to store produced water Enclosed Combustor Liquid Loading 003 Truck loadout of condensate by submerged fill Enclosed Combustor Separator Venting 004 Heater Treater and Surge Drum Separators Enclosed Combustor Fugitive Component Leaks 005 Equipment Leaks (fugitive VOCs) from a natural gas exploration and production facility None 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. Page 1 of 16 a COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 must be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit must 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 must complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section iII.E.) 5. The operator must 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 6. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO Tanks 001 --- --- 0.8 --- Point Produced Water Tank 002 --- 2.7 9.5 12.1 Point Liquid Loading 003 --- --- 1.1 --- Point Page 2 of 16 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Separator Venting 004 --- 1.1 26.9 4.1 Point Fugitive Component Leaks 005 --- --- 1.6 --- Fugitive 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 must not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants must apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, must 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 must calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 8. The owner or operator must track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations must be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II.E.) Total emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, must be less than: • 50 tons per year of VOC 9. Point 005: The operator must calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator must maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records must be provided to the Division upon request. 10. The emission points in the table below must be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Page 3 of 16 a PROCES COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Facility Equipment ID AIRS Point Control Device Pollutants Controlled Tanks 001 Enclosed Combustor VOC and HAP Produced Water Tank 002 Enclosed Combustor VOC and HAP Liquid Loading 003 Enclosed Combustor VOC and HAP Separator Venting 004 Emissions from the Separators are routed to an Enclosed Combustor during Vapor Recovery Unit (VRU) downtime VOC and HAP 11. This source must be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates must 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 Tanks 001 Condensate throughput 257,617 barrels Produced Water Tank 002 Produced Water throughput 1,450,000 barrels Liquid Loading 003 Condensate throughput 257,617 barrels Separator Venting 004 Natural Gas Venting 8.9 MMSCF The owner or operator must monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits must 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 must calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 12. Point 004: The owner or operator must continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The owner or operator Page 4 of 16 a COLORADO Air Pollution Control Division Department of Public Wealth & Environment Dedicated to protecting and improving the health and environment of the people of Colorado must use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of these sources. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. R 4.) 14. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 15. This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 16. Points 001 it 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 must 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 combustiondevice has been authorized by permit prior to May 1, 2014. The source must 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. 17. Points 001 ,a' 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. 18. Points 001, 002, 004: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it must be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. Page 5 of 16 a 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 19. Points 001, 002, 003, 004: The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) must be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 20. Point 001: This source is subject to Regulation Number 7, Section XII. The operator must comply with all applicable requirements of Section XII and, specifically, must: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate storage tanks; and • Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 21. Point 003: No owner or operator of a smokeless flare or other flare for the combustion of waste gases must allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) ) 22. Point 003: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks must be conducted by submerged fill and emissions must be controlled by a flare. (Reference: Regulation 3, Part B, III.D.2) 23. Point 003: All hydrocarbon liquid loading operations, regardless of size, must be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 24. Point 003: The owner or operator must follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation Number 3, Part B, III.E): a. The owner or operator must inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections must occur at least monthly. Each inspection must be documented in a log available to the Division on request. b. All compartment hatches at the facility (including thief hatches) must be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers must be weighted and properly seated. d. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs must be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. e. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. Page 6 of 16 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 25. Point 003: For this controlled loading operation, the owner or operator must follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation Number 3, Part B, III.E): a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 26. Point 004: The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas welt,; must either be routed to a gas gathering line or controlled from the date of first production by 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. 27. Point 005: M nor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference. Regulation No. 3, Part B IIID.2.a). Leak Detection and Repair (LDAR), as required by Condition 28 of this permit, shall satisfy the requirement to apply RACT. 28. Point 005: Fugitive component leaks at this well production facility are subject to the Leak Detection and Repair (LDAR) program requirements, including ,but not limited to: monitoring, repair, re -monitoring, recordkeeping and reporting contained in Regulation 7, Section XVII.F. In addition, the operator shall comply with the General Provisions contained in Regulation 7, Section XVII.B.1. B.1. OPERATING £t MAINTENANCE REQUIREMENTS 29. Points 001, 002, 003, 004: Upon startup of these points, the owner or operator must follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) 30. Point 005: This source is not required to follow a Division -approved operating and maintenance plan. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 31. Points 001, 002, 004: The owner or operator must demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the Page 7 of 16 a COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) 32. Point 005: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self -certification process to ensure compliance with emissions limits. Periodic Testing Requirements 33. Point 004: On an annual basis, the owner/operator must complete a site specific extended gas analysis ("Analysis") of the natural gas vented from the surge drum(s) in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analysis must be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis must be used to demonstrate that the emissions factor established through the Analysis are less than or equal to, the emission factor submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factor submitted with the permit application and established in the "Notes to Permit Holder" the operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). ADDITIONAL REQUIREMENTS 34. A'; revised Air Pollutant Emission Notice (APEN) must 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 NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. Page 8 of 16 1� COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 35. Federal regulatory program requirements (i.e. PSD, NANSR) must apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source must not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 36. 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. 37. 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 wilt 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. 38. 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. 39. 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. 40. 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 must constitute a rejection of the entire permit and upon such occurrence, this permit must 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 Page 9 of 16 COLORADO Air Pollution Control Division Department of Public Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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. 41. 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. 42. 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. DRAFT Ben Fischbach Permit Engineer Permit History Issuance Date Description Issuance i This Issuance Issued to Noble Energy Inc. Synthetic Minor Facility Page 10 of 16 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder must 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 must notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set, forth in Part II.E.1 of the Common Provisions Regulation. See: https: //www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 148 7 Toluene 108883 187 9 Ethylbenzene 100414 6 0 Xylenes 1330207 100 5 n -Hexane 110543 990 50 002 Benzene 71432 10,150 508 n -Hexane 110543 31,900 1,595 003 Benzene 71432 173 9 Toluene 108883 287 14 Ethylbenzene 100414 9 0 Xylenes 1330207 114 6 n -Hexane 110543 1,283 64 004 Benzene 71432 5,317 266 Toluene 108883 9,301 465 Page 11 of 16 a COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Ethylbenzene 100414 249 12 Xylenes 1330207 3,987 199 n -Hexane 110543 39,454 1,978 2,2,4- Trimethylpentane 540841 268 13 005 Benzene 71432 18 18 Toluene 108883 8 8 Ethylbenzene 100414 0 0 Xylenes 1330207 0 0 n -Hexane 110543 80 80 2,2,4- Trimethylpentane 540841 2 2 Note: ' All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year ( b/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 2.06 * 10"4 2.06 * 10-4 AP 42 Ch. 13.5 CO 9.38 * 10"4 9.38 * 10'4 VOC . 0.1218 0.0061 HYSYS/Tanks 4.0.9d 71432 Benzene 5.76 * 10-4 2.88 * 10"5 108883 - Toluene 7.27 * 10-4 3.64 * 10"5 100414 Ethylbenzene 2.15 * 10 5 1.08 * 10-6 1330207 Xylene 3.88 * 10-4 1.94 * 10-5 110543 n -Hexane 3.84 * 10-3 1.92* 10-4 Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 002: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0037 0.0037 CDPHE CO 0.0167 0.0167 VOC 0.262 0.0131 71432 Benzene 0.007 3.5 * 10-4 110543 n -Hexane 0.022 0.0011 Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Page 12 of 16 a Point 003: 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 Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 1.91 *10-4 1.91 * 10' AP -42 Ch. 13.5 CO 8.69 * 10-4 8.69 * 10-4 VOC 0.177 0.0088 AP -42 Chapter 5.2, Equation 1 71432 Benzene 6.71 * 10-4 3.36 * 10-5 108883 Toluene 1.11 * 10-3 5.57 * 10-5 100414 Ethylbenzene 3.53 * 10"5 1.77 * 10-6 1330207 Xylene 4.42 * 10"4 2.21 * 10-5 110543 n -Hexane 4.98 * 10"3 2.49 * 10-4 The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service P (true vapor pressure) = 4.2957 psia M (vapor molecular weight) = 67 lb/lb-mol T (temperature of liquid loaded) = 511.4625 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the condensate tank vapors by the VOC emission factor. C ontrolled emission factors are based on a flare efficiency of 95% and a collection efficiency of 100%. Point 004: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source NOx 235.2 235.2 AP -42 CO 929.4 929.4 AP -42 VOC 120,954.3 6,047.7 HYSYS 71432 Benzene 598.0 29.9 108883 Toluene 1,046.0 52.3 100414 Ethylbenzene 28.0 1.4 1330207 Xylene 448.4 22.4 110543 n -Hexane 4,437.1 221.9 540841 2, Trimethylpentane 30.2 30.2 1.5 Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Page 13 of 16 a 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 The emission factors listed above are based on the HYSYS-modeled emission profile for the Surge Drum Separator(s) only. The Surge Drum was modeled at a temperature of 120 °F and separator pressure of 15.12 psig. Point 005: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2,347 0 2,414 497 Flanges 1,097 0 1,037 300 Open-ended Lines 0 0 0 0 Pump Seals 0 0 36 0 Valves 881 0 1,385 279 Other* 474 0 427 89 VOC Content (wt. fraction) 0.2750 1.00 1_.00 1.00,:.; Benzene Content (wt. fraction) 1.57 * 10-3 5.70 * 10-3 5.70 * 10-3 5.70 * 10-3 Toluene Content (wt. fraction) 7.45* 10-4 2.70 * 10`3 2.70 * 10"3 2.70 * "10-3 Ethylbenzene (wt. fraction) 5.00 * 10-6 0.00 0.00 0.00 Xylenes Content (wt. fraction) 2 80 5 10" 1.00 1 0' - 1.00 * 10-4 1.00 * �10 n'hexane Content .. fraction) 7.03 * 10-3 2.55 * 10.2 2.55 * 10-2 2.55 * 1'0-2 2,2,4-„ w Trimethylpentane Content (wt. fraction) 1.71 * 10-4 6.00 * 10-4 6.00 * 10-4 6.00 * 10"4 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Oil Service Connectors 1.0 * 10-5 7.5 * 10-6 9.7 * 10-6 1.0 *10-5 Flanges 5.7 * 10-6 3.9 * 10-' 2.4 *10-6 2.9 *10-6 Open-ended Lines 1.5 * 10-5 7.2 * 10-6 1.4 * 10-3 2.5 * 10"4 Pump Seals 3.5 * 10-4 NA 5.1 * 10"4 2.4 * 10-5 Valves 2.5 * 10-5 8.4 * 10-6 1.9 * 10-5 9.7 * 10-6 Other 1.2 * 10-4 3.2 * 10-5 1.1 * 10-4 5.9 * 10-5 Source: EPA -453/R95-017 Page 14 of 16 NANSR It 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 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. 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 must be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This source is subject to 40 CFR, Part 60, Subpart 0000a Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification, or Reconstruction Commenced after September 18, 2015 (See June 3, 2016 Federal register posting - effective August 2, 2016.) This rule has not yet been incorporated into Colorado Air Quality Control? Commission's Regulation No. 6 A copy of the complete subpart is available at the Office of the Federal Register website at: https://wv v. federalregister.gov/documents/:2016/06/03/2016-11971/oil-and-natural-gas- sector-emission-standards-for-new-reconstructed-and-modified-sources 9) This facility is classified as follows: Applicable Requirement Operating Permit Synthetic Minor Source of: VOC, NOx, HAPs (n -Hexane, Total) Synthetic Minor Source of: VOC Synthetic Minor Source of: VOC, NOx 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://www.ecfr.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart UUUU 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 Page 15 of 16 a COLORADO Air Pollution Control Division Department al Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 16 of 16 Colorado Air Permitting Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details Review Engineer: Ben Fischbach Package#I: 415031 Received Date: 8/30/2019 Review Start Date: 10/28/2019 Section 01-Facility Information Company Name: Noble Energy Inc Quadrant Section Township Range H County AIRS ID: 123 SWNE 29 3N 64 Plant AIRS ID: A087 Facility Name: Guttersen/Guttersen State D29-22-A T3N R64W 52 .. AN-"` ''i.'�;,: Physical Address/Location: SWNE quadrant of Section 29,Township 3N,Range 64W County: Weld County Type of Facility: Exploration&Production Well Pad What industry segment? Oil&Natural Gas Production&Proiessing Is this facility located in a NAAQS non-attainment area? Yes If yes,for what pollutant? 111 Carbon Monoxide(CO) El Partimlate Matter(PM) ✓ ozone(N0x&V0C) Section 02-Emissions Units In Permit Application Emissions Self Cert Engineering AIRS Point R Emissions Source Type Equipment Name Control? Permit it Issuance 9 Required? Action Remarks Permit Initial 001 Condensate Tank Tanks Yes 19WE0908 1 Yes Issuance - - Permit Initial 002 Produced Water Tank PW Tanks Yes 19WE0908 1 Yes Issuance Permit Initial 003 `.Liquid Loading. ,` Loadout Yes 19WE0908 1 Yes 'Issuance;.-. Permit Initial - 004 - Separator Venting LP&Surge Drums Yes 19WE0908 1 Yes Issuance; - - - Permit Initial 005 Fugitive Component Leaks Fugitives Yes 19WE0908 1 - Yes Issuance Section 03-Description of Project New synthetic minor E&P facility located in NAA(Syn Minor for VOC,NOx,n-Hex,Total HAPs).Facility has not yet started operating at time of analysis.This facility-wide permit will cover condensate tanks,produced water tanks,condensate Loadout,separator venting,and fugitive equipment leaks. Points 001,002,003,and 004 are all controlled by a bank of two common combustor(s),with those pilot emissions apportioned to the separator venting point(004). Per Fugitives APEN,facility utilizes wet seal centrifugal compressors and/or reciprocating compressors,and that equipment is subjectto 0000a.Therefore,will include 0000a language in notes to permit holder. i. - �s - - n ,mss z i " x ` f t a Section 04-Public Comment Requirements Is Public Comment Required? Yes If yes,why? Requesting Synthetic Miner Permit. Section 05-Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? No' If yes,for what pollutants? If yes,attach a copy of Technical Services Unit modeling results summary. 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: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(PSD) C _ - �.'f _ ❑ ❑ Title V Operating Permits(OP) It-. +j ✓ Non-Attainment New Source Review(NANSR) ✓ ✓ Is this stationary source a major source? No_ If yes,explain what programs and which pollutants here: 502 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(PSD) _ _ Title V Operating Permits(OP) ❑ Non-Attainment New Source Review(NANSR) • Condensate Storage Tank(s)Emissions Inventory 001 Condensate Tank Facility AlRs ID: .r .:3 -A087 --'1.;)...,A01.+._"; County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Three(3)SOO bill Condensate Storage Tank "zt '' '.,,:. 5t�y.:,5 tt LM ,t,^$. Description: ... . xni ..',.:.,.:::':... �'s�•sy° .z Fz°L..:.,b Description: "';':,;:l..,:xjt:,V....f.... .. if!.::•:„.,4';`).N-:.5)":°- . •. • ,.. .. ., t'Pt.. <S'.'=; a:. Requested Overall VOC&HAP Control •:2.:'„%W.>Nt Efficiency%: (J5'A'r` Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tank(s) Actual Condensate Throughput= 'S..r,reagd'Barrels(bbl)per year Actual Condensate Throughput While Emissions Controls Operating= tcat r?-0 Barrels(bbl)per year Requested Permit LimitThroughput= `?3-f6I7 Barrels(bbl)per year Requested Monthly Throughput= 21880 Barrels(bbl)per month Potential to Emit(PTE)Condensate Throughput,.,rx.:Orl = •.,,,,^.: '61T Barrels(bbl)per year Secondary Emissions-Combustion Devlce(s) Promax model shows zero flash emissions(and:provides no GOR).Annual heat content routed to combustion devices.calculated Heat content of waste gas= "+" 04•Etu/stf y g py /yr y. ( y t , a b converting.annual VOC emissions from a t basis to a scf basis,and finally into an MMBtu/yr basis see technical analysis Volume of waste gas emitted per BBL of liquids f f notes for equation used).Using that calculation predicted 666 MMBTU/yr,but operator calculates 771 MMBTU/yr which is more produced= P.t,.; �`i ANN conseravative-and was used in permitting. Actual heat content of waste gas routed to combustion device= O MMBTU per year Requested heat content of waste gas routed to combustion device= 771 MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= 771 MMBTU per year Section 04-Emissions Factors&Methodologies Will this storage tank emitflash emissions? ,, Emission Factors Condensate Tank Uncontrolled Controlled Pollutant (lb/bbl) (lb/bbl) Emission Factor Source (Condensate (Condensate Throughput) Throughput) VOC 0.1218:.; 00061 .wa 1'" "y;2 Benzene ,5.76E-04 2.88E-05 4.0))4411140'41,104L-1,1.4 — Toluene 7.27E-04. 's- 3.64E-05 onliorliagarlitimagati Ethylbenzene 2.159-0S 1.08E-06 — Xylene 3.88E-04 1.94E-05 ': n-Hexane 3:84E-03 1.92E-04 us- 224TMP 0.000 0.000 M )1" _ I.—*--..&'tlaTNI.***1"TFM Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source (waste heat (Condensate combusted) Throughput) PM10 '''14'..,3f,":;''''..-°'; '::: 0.0000sr r E ., PM2.5 e „`. 0.0000 > Operator requested Permit Values NOx 0.0680.' 2.04E-04 S °>1 6"^' 2.06E-04 lbjbbl CO .0.3100- 9.28E-04 i;k ,_„ e va t. .. 9.38E-04 lb/bbl Section OS-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) VOC 15.7 0.0 0.0 153 0.8 133 PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0.0 0.0 0.0 0.0 0.0 0 NOx 0.0 0.0 0.0 0.03 0.03 4 CO 0.1 0.0 0.0 0.12 0.12 20 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (Ibs/year) (Ibs/year) (Ibs/year) (Ibs/year) Benzene 148 0 0 148 7 Toluene 187 0 0 187 9 Ethylbenzene 6 0 0 6 0 Xylene 100 0 0 100 5 n-Hexane 990 0 0 990 50 224TMP 0 0 0 0 0 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a permit Regulation 7,Section XILC,D,E,F Storage tank is subject to Regulation 7,Section XII.C-F Regulation 7,Section Xll.G,C Storage Tank is not subject to Regulation 7,Section Xll.G Regulation7,Section XVILB,C.1,C.3 Storage tank is subject to Regulation 7,Section XVII,B,C.1&C.3 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,NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 Regulation 8,Part E,MACE Subpart HH Storage Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) 2 of 10 K:\PA\2019\19W E0908.CP1 • Condensate Storage Tank(s)Emissions Inventory Section 07-Initial and Periodic Sampling and Testing Requirements - - Does the company use the state default emissions factors to estimate emissions? If yes,are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? - T -- - If yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in P5 Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? - - - - - If yes and if there are flash emissions,are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted?This sample should be considered representative which generally means site-specific and collected a: - - withinoneyearoftheapplicationreceiveddate.However,if the facility has not been modified(e.g.,no new wells a brought on-line),then it may be appropriate to use an older site-specific sample. t ±? i . , 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 combustiondevice? 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 HYSYS model shows zero flow rate for flash emissions stream'rain tanks. Operator based W&B on a Tanks 4.0.9d using'Gasoline(RVP 9)as the modeled component(based on HYSYS model showing"RVP 8(65 for condensate/off spec liquids stream):Choice of RVe 9 as id, - modeled liquid was further demonstrated to be conservative rle based on operato prey d d stabilized oil sample for the liquids stored r this tank battery. >i Whsle facility servicesmnesepur to weds the Pr mao modell u d to estimate emission f ctors are b s d on amodel which reaches back to only three of the wellheads servicing tit e brwggh several O f .('a t"S" l Svt "gfore require t and t p f sampling and analysts of the liquid which is routed from the separators and to the storage tanks to verify SSEF r= 4ekting _ • . IRIIIIIiiItSt d'9'''''''‘9.49-4`94999 _ - -_ a g 91•°:4-• 3..z.. • Section 09-lnventoniSCC Coding and Emissions Factors Uncontrolled - - - - Emissions AIRS Point# Process# SCC Code Pollutant Factor Control% Units 001 01 =a «a - ti. `A_«igr,.+,e° ,;(.;, �.,' _ _ % PM10 0.00 0 Ib/1,000 gallons condensate throughput PM2.5 0.00 0 15/1,000 gallons condensate throughput NOx 0.00 0 lb/1,000 gallons condensate throughput VOC 2.9 95 lb/1,000 gallons condensate throughput - - CO 0.02 0 15/1,000 gallons condensate throughput Benzene , 0.01 95 15/1,000 gallons condensate throughput ' - Toluene 0.02- -95 Ib/1,000 gallons condensate throughput Ethylbenzene - 0.00 95 lb/1,000 gallons condensate throughput Xylene 0.01 95 lb/1,000 gallons condensate throughput .-n-Hexane _ -.0.09 95 -lb/1,000 gallons condensate throughput. 224 TMP 0.00 95; lb/1,000 gallons condensate throughput • 3 of 18 • • Kr\PA\2019\19W E0908.CP1 Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B-Apes and Penn? 'tremens Source Is in the Non-Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions front any criteria pollutants from this Individual source greater than 2 TPY(Regulation 3,Part A,Section ll.D.i.a)i 2. Is the constrvction date(service date)prior to 12/30/2002 and not modified after 12/31/2002(See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 far additional guidance on grandfather applicab'ility)? 3. Are total facilityuncontrolled VOC emissions greaterthan STPY,NOx greater than 10TPV or CO emissions greater than 10 Try(Regulation 3,Part B,Section ll.D.3)? '-. You have indicated that source Is in the Nan-Attainment Area NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater thane TPY(Regulation 3,Part A,Section 11.0.12)? Y. Source Req 2. Is the construction date(service date)prior to 12/30/2002 and not modified after 12/31/2002(See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 far additional guidance on grandfather applicability)? No Go to nest 3. Are total facility uncontrolled VOC emissions greater than 2 TPY,NOx greater than 5 TM/or CO emissions greater than lO TPY(Regulation 3,Part B.Section 11.0.2)7 Yes'.:". ,:Source Req 'Source requites a permit Colorado Regulation 7,Section%II.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? Yes Continue-' 2. Is this storage tank located at en oil and gas exploration and production operation`,natural gas compressor station or natural gas drip station? Yes Continue-' 3. Is this storage tank located upstream of a natural gas processing plant? list&&A%%Source is st 'Storage tank is subject to Regulation 7,Section>01C-F Section XII.C.1—General Requirements for Air Pollution Control Equipment—Prevention of Leakage Section XII.C2—Emission Estimation Procedures Section MID—Emissions Control Requirements Section Xll.E—Monitoring Section XII.F—Recordkeeping and Reporting Colorado Regulation 7.Section MG . 1. Is this storage tank located ln the r-hr ozone control area or any ozone non-attainment area or attainment/maintenance area? Yes Continue-' 2. Is this storage tank located at a natural gas processing plant? No Storage Tar 3. Does this storage tank exhibit"Flash"(e.g.storing non-stabilized liquids)emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? „Yn6}`"£f Source isu 'Storage Tank Is not subjectto Regulation 7,Section oO.G Section XII.G2-Emissions Control Requirements Section 10I,C1—General Requirements for Air Pollution Control Equipment—Prevention of Leakage Section IGI.C2—Emission Estimation Procedures Colorado Regulation 7,Section XVII 1. Is this tank located at a transmission/storage facility? No Continue-' 2. Is this condensate storage tank`located at en oil and gas exploration and production operation,well production facility•,natural gas compressor stations or natural gas processing plant? Yes Go to then 3 Is this condensate storage tank a fixed roof storage tank? yS... Go tethers 4. Are uncontrolled actual emissions'of this storage tank equal to or greater than 6 tons per year VOC? Y,e9`4} S ce is st 'Storagetank is sub)ett[q Regulation 7,Section XVII,B.C.O&C.3 Section XVII.e—General Provisions for AR Pollution Control Equipment and Prevention of Emissions Section XVII.G1-Emissions Control and Monitoring Provisions Section XVII.C.3-Recordkeeping Requirements 5. Does the condensate storage tank contain only"stablzed"liquids? INo` :"{Source is st Storage tank Is sab)aee to Regulation 7,5esden XVR.C.2 Section XVR,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, Isthe'Individual storage vessel capacity greater than or equal to 75 cubic meters(ms)(-472 BM? VV p) c Go to then 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? y43'jfq`/// Storage Tar a..Does the vessel has a design capacity less than or equal to 1,589.874 m•P10,000 MIL]used for petroleum or condensate stored,processed,or treated prior to custody transfer'as defined in 60.1116? 3. Was this condensate storage tank constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after July 23,1984? 4. Does the ank'meet the definition of"storage vessel"s in 60.1116? 5. Dces the storage vessel store a"volatile organic liquid(VOL)"s as defined In 60.11137 6. Do the storage vessel meet any one of the following additional exemptions: y Do. "?"yrrc/a a.Is the storage vessel a pressure vessel designed to operate In excess of 204.9 kPa["29.7 psi]and without emisslons to the atmosphere(60.110b(d)(2)I?;or ff°2s`€ b.The design oapaclry Is greater than or equal to 151 m'[`950 BBL]and stores a Squid with a maximum true vapor pressure°less than 3.5 kPa(60.110b(b))7;or c The design apaclty is greater than or equal to 75 Me P472 BBL)but less than 151 ma P950 BBL]and stores a liquid with a maximum Nue vapor pressure•less than 15.0 kPe(60.110b)b))? 'Storage Tank is not subject to NSPS Kb SubpartA,General Provisions 560.1126-Emissions Control Standards for VOC 560.113b-Testing and Procedures 460,1156-Reporting and Recordkeeping Requirements 460.1160-Monitoring of Operations 40 CFR,Part 60,Subeart0000,Standards of Performance for Crude elf and Natural Gas Production,Transmission and Distribution 1. Is this condensate storage vessel located ate facility in the onshore call and natural gas production segment,natural gas processing segment or natural gas transmission and storage segment of the Industry? Yes Continue-' 2. Was this condensate storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)between August 23,2011 and September 18,2015? N&:-StaageTar 3. Are potential VOC emissions.from the individual storagevessei greater than or equal to 6 tonsperyear? 4. Does this condensate storage vessel meet the definition of"storage vessel.'per 60.5430? 5. Is the storagevessel subject to and controlled In accordance withrequirements far storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? 3%4 `. 'Storage Tank Is not subject to N5Ps 0000 Subpart A,General Provisions per 060.5425 Table 3 560.5395-Emissions Control Standards for VOC 560.5413:Testing and Procedures 4605395(g)-Notification,Reporting and Recordkeeping Requirements 660.5416(c)-Cover and Closed Vent System Monitoring Requirements 5605417-Control Device Monitoring Requirementt Note:if a storage vessel is previously determined to be subject to NSP50000 due m emissions above 6 tons per year VOC on the applicability determination date,k should remain subject to NSPS 0000 per 6053651ey2)even if potential VOC emissions drop below 6 tans per year] 40 CFR.Part 63.Subpart MAR HH,Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: 'yes 'Continue-' •a.A facility that processes,upgrades or stores hydrocarbon liquids`)63.760)a)(2));OR b.A facility that processes,upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or Is delivered to a final end user'(63.760(a)(3))? 2. Is the tank located at a facility that Is major'for HAPs? �,x .Storage Tar 3. Does the tank meet the definition of"storage vessel"`in 63.7617 "yy,ki 4. Dces the tank meet the definition of"storage vessel with-the potential for flash emissions"' per 03J61? """`" trS. 5. Is the tank subject to control requirements under 40 CFR Part fi0.5ubpart Kb or Subpart 00007 {% 'StorageTank is not subject to MAR NH SubpartA,General provisions per 563.764(a)Table 2 563.766-Emissions Control Standards 663.773-Monitoring 663.774-Recordkeeping 563.775-Reporting PAR Review RACT review is required if Regulation 7 does not apply AND if the tank is In the non-attainment area.It 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 if 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 Afr Act„its implementing regulations,and Air Quality Control Commission regulations,the language of the statute or regulation will control.The use ofnon-mandatary language such as`recommend,"'may,"should,"and"can,"is irrtended to describe APCD interpretations and recommendations.Mandatory terminology such as"must"end"required"are intended to describe controlling requirements under the tens of the Clean Air Act and Air Q,054'Control Commission regulations,but this document does not establish legaly binding requirements In and of itself. Produced Water Storage Tank(s)Emissions Inventory 002 Produced Water Tank - - Facility AIRs ID: 123 A087 002 County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Four(4)S00 bbl Produced Water Tanks Description: Emission Control Device ECDs Description: Requested Overall VOC&HAP Control Efficiency%: 95 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tank(s) ActualProducedWaterThroughput= Barrels(bbl)per year Actual Produced Water Throughput While Emissions Controls Operating= Requested Permit Limit Throughput= 1,450,000 Barrels(bbl)per year Requested Monthly Throughput= - 123151 Barrels(bbl)per month Potential to Emit(PTE)Produced Water Throughput= 1,490,000 Barrels(bbl)per year - Secondary Emissions-Combustion Device(s) - Heat content of waste gas= 1496 Btu/scf - - Volume of waste gas emitted per BBL of liquids produced= 36scf/bbl -Actual heat content of waste gas routed to combustion device= - 0 MMBTU per year Requested heat content of waste gasTouted to combustion device= 78,091 MMBTU per year - - Potential to Emit(PTE)heat content of waste gas routed to combustion device= 78,091 MMBTU per year Section 04-Emissions Factors&Methodologies .. Will this storage tank emit flash emissions §,-z,;..w;., Emission Factors Produced Water Tank -Uncontrolled Controlled .. - (lb/bbl) (lb/bbl) Emission Factor Source - - Pollutant (Produced (Produced Water Water Throughput) Throughput)VOC 0.262 0.0131 („ ced lidnters t P v:Oldes➢1 Benzene 0.007 3.50004 4ti Wv.e dr..tt- Toluene 0800 Ethylbenzene 0.000 Xylene n-Hexane 0.022 0.0011 Arjfil Water State 1.P.(iicf"+- - 224TMP 0.000 r A- Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) - - Pollutant - Emission Factor Source (Produced (waste heat Water combusted) Throughput) PM10 0.0000 -n - $ r - .. - ® 0.0060 1 1 NOx 0.0600 0.0037 - - - CO 0.3100 0.0167 0'-* g,, Section 05-Emissions Inventory I Potential to Emit • Actual Emissions Requested Permit Limits Requested Monthly Limits • _ Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) VOC 190.0 0.0 0.0 190.0 9.5 1613 PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0,0 0.0 0.0 0.0 0.0 0 NOx 2.7 0.0 0.0 2.7 2.7 451 CO • 12.1 .0.0. 0.0 12.1. 12.1 2056 Potential to Emit Actual Emissions Requested Permit Limits - HazardousAirPollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 10150 0 0 10150 508 Toluene "0 0 0 0 0 - Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n-Hexane 31900 0 0 31900 1595 224 TM 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 subject to Regulation 7,Section XVII,B,C.1&C.3 Regulation 7,Section XVII.C.2 Storage tank is 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) - - 5 of 18 K:\PA\2019\19WE0908.CP1 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 t to estimate 4emissions? If yes and if there are flash emissions,are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis?This sample should be considered representative which generally means site-specific and collected within one year of the application received date. However,if the facility has not been.modified(e.g.,no new wells brought on-line),then it may be appropriate to use an older site-specific sample. - -. If no,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor.See P5 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 State default values used for PWT emissions calculations. Section 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions - •AIRS Point# Process# SCC Code Pollutant Factor Control% Units 002 01 - 4-04-003-15 Fixed Roof Tank,Produced Water,working+breathing+flashing losses -PM10 0.00 -0 16/1,000 gallons liquid throughput PM2.5 0.00 0 16/1,000 gallons liquid throughput - NOx 0.09 0 lb/1;000 gallons liquid throughput VOC 6.2- 95 16/1,000 gallons liquid throughput CO 0.40 0 16/1,000 gallons liquid throughput Benzene 0.17 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 0.52 - - 95 lb/1,R00 gallons liquid throughput 224 TMP- 0.00 95 lb/1,000 gallons liquid throughput 6 of 18 K:\PA\2019\19WE0908.CP1 • 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 Requirements (Source is in the Non-Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,PartA,Section ll.D.1.a)? -. 2. Is the operator claiming less than 1%crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater?(Regulation 3,Part B,Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOx greater than 10 TPY or CO emissions greater than 10 TPY(Regulation 3,•Part B,Section ll.D.3)?• [You have indicated that source isinthe Non-Attainment Area - NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than S TPY(Regulation 3,Part A,Section ll.D.1.a)? Yps, .' Source Req • 2 is the operator claiming less than 1%crude oil ands the tank located at a noncommercial facility for processing oil and gas wastewater?(Regulation 3,Part B,Section II.D.1.M) lie" -Go to next • • 3 Are total facility uncontrolled VOC emissions greater than 2TPY,NOx greater than SIPS or CO emissions greater than 10 TPY(Regulation 3,Part B,Section II.0.2)? Ykp •'Source Req • '• [Source requires a permit• _ Colorado Regulation 7,Section%VI I 1. Is this tank located at a transmission/storage facility? No Continue-' • 2. Is this produced water storage tank'located at an ail and gas exploration and production operation,well production facility,natural gas compressor stationer natural gas processing plant? Yes Continue-' . .3..li this produced water stdrage tank a fixed roof storage tank? Go to then 4. Are uncontrolled actual emissions'of this storage tank equal to or greater than 6 tons per year VOC? ?2- Source is st Storagetank is subject to Regulation 7,Section)(VII,B,C,1&C3 Section%VII.B-General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section X6m.C.1-Emissions Control and Monitoring Provisions ' . Section%VII.C.3.-Recordkeeping Requirements • 5. Does the produced water storage tank contain only"stabilized'liquids?lino,the following additional provisions apply. R•..a$ wSource isst •• 'Storage tank is subject to Regulation 7,Section llVli.C.2 Section XVII.C.2-Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment • 40 CFR,Part60,Subpart 0000,Standards of Performance for Crude Oil and Natural Gas Production,Transmission and Distribution ' • . • 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment,natural gas processing segment or natural gas transmission and storage segment of the industry? Yes• Continue-'. . 2. Was this produced water storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)between August 23,2011 and September 18,2015? :YCY'' Storage Tar • •3 Are potential VOC emissions'from the Individual storage vessel greater than or equal to 6 tons per year? • 4. Does this produced water storage vessel meet the definition of"storage vessel"'per 60.5430? • .�; Storage Tank is not subject to NSPS0000 Subpart A,General Provisions per§60.5425 Table 3 • §60.5395-Emissions Control Standards for VOC §60.5413-Testing and Procedures §60.5395(g)-Notification,Reporting and Recardkeeping Requirements §60.5416(c)-Cover and Closed Vent System Mon-daring 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 subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] • RACT Review • RACT review is required if Regulation 7 does not apply AND if the tank is in the non-attainment area.If the tank meets 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 ciroumstances..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 mecommend,""may," . ' .' "should,"and"can,"is intended to describe APCD Interpretations and recommendations.Mandatory terminology such as'must"and hdquired"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. Hydrocarbon Loadout Emissions Inventory 003 Liquid Loading 123 A087 003 Facility AIRs ID: County Plant Pont - - Section 02-Equipment Description Details - - Detailed Emissions Unit Hydrocarbon loadout to tank trucks Description: •Emission Control Device ECDs Description: Is this loadout controlled? Yes Collection Efficiency: 100.0 Control Efficiency: 95 Requested Overall VOC&HAP Control Efficiency%: 95.00 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Actual Volume Loaded= `Barrels(bbl)per year Actual Volume Loaded While Emissions Controls Operating= Barrels(bbl)per year Requested Permit Limit Throughput= 257,617 Barrels(bbl)per year Requested Monthly Throughput= 21880 Barrels(bbl)per month Potential to Emit(PTE)Volume Loaded= 257,617 Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heat content of waste gas= 2804 Btu/sd , Volume of waste gas emitted per year= 25748554/year Actual heat content of waste gas routed to combustion device= 0 MMBTU per year Requested heat content of waste gas routed to combustion device= 722 MMBTU per year Potential to Emit(PIE)heat content of waste gas routed to combustion device= 722 MMBTU per year Section 04-Emissions Factors&Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility [ s being permitted? - �<s. sxi,The stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors. Loading Loss Equation L=12.46.5*P•M/T Factor Meaning Value Units Source - 5 Saturation Factor 0.6 _ _ +q.,RP;iocraRo, � P True Vapor Pressure 4.2957 psia AP-42 Table 7.1-2—Gasoline(RVP9)(Custorncomponent=see TAnotesbefow] _ M Molecular Weight of Vapors `.67 Ib/Ib-mol AP-42 Table 7.1-2--Gasoline MVP 9)[Custom component-see TA notes below] - T Liquid Temperature -.:511.4625 ?Rankine- AP-42 Table 7.1-2—Gasoline(RVP 9)[Custom component—see TA notes below) Loading Losses 4.20691989 lb/1000 gallons 0176690635 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.0038 0.000671424 lb/bbl HYSYS Model(See TA notes below) Toluene 0.0063 0.001113151 lb/bbl HYSYS Model(See TA notes below) Ethylbenzene 0.0002 3.53381E-05 lb/bbl : HYSYS Model(See TA notes below) Xylene 0.0025 0.000441727 lb/bbl HYSY5 Model(See TA notes below) n-Hexane 0.0282 0.004980909 lb/bbl HYSYS Model(See TA notes below) 224 TMP 0 8 lb/bbl -- HYSYS Model(See TA notes below) Emission Factors Hydrocarbon Loadout Uncontrolled Controlled Pollutant - (16/661) - - (lb/bbl) Emission Factor Source (Volume - - (Volume Loaded) Loaded) VOC 0.177 0.008834532 SitesPY'.'ILI E .7j41-01,-`n Benzene 6.71E-04 3.36E-OS 5Rc spa i,v6`or°` er 5.2,Fqu6 . Toluene 1.11E-03 557E-05 Site 5p cfc AP r2 Chapters?;'Eq -r' Ethylbenzene 3.53E-05 1.77E-06 Site Dye is,AP-42:Chapter 5.2,Eqq Xylene - 4.42E-04 - 2.21E-05 Site Sp Ch pt 5.2,Eq n-Hexane - 4.98E-03 2.49E-04 Site Sp ,,,chapter 5.2,Eqn untnip, 224 TMP 0.00E+00 0.00E+00 Site Specific,Alt-1)2:Chapter 5.2,Sept* r f,, Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source (Volume (waste heat combusted) Loaded) PM10 0-OOE+00 PM2.5 0.00E+00 " 5Ox - 0.00E+00 NOx 0.0680 1.91E-04 CO 0.3100 8.69E-04 ... . �`.t 1-- a 4 8 of 18 K:\PA\2019\19WE0908.CP1 Hydrocarbon Loadout Emissions inventory ' Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled 'Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) . PM10 0.00 9.00 . 0.00 0.00 0.00 0 - PM2.5 0.00 .0.00 0.00 0.00 0.00 0 . SOx" - - 0.00 - 0.00 - 0.00 ..0.00 0.00 - 0 NOx . ' '0.02 - 0.00 = .0.00 0.02 0.02 4 VOC - 2276 0.00 - -0.00 22.76 1.14 193 **Uncontrolled VOC limit slightly differs from APES value,but ' CO 0.11 0,00 0.00 - 0.11 0.11 . . . 19 APES value is within rounding error and acceptable.." Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 173 0 :0 173 9 Toluene -287 - 0 - 0 287 14,` Ethylbenzene 9 . • 0 . ' 0 9 0__ . Xylene 114 0' - 0 . 114 . 6 n-Hexane 1283 ."0 .. 0 1283 64 224TMP 0 . 0 0 ' - 0 0 Section 06-Regulatory Summary Analysis - Regulation 3,Parts 4,B Source requires a permit RACT-Regulation 3,Part B,Section II I.D.2.a - The toadoatmust operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95%for a flare or combustion device? �.,, , , ,Jt{ 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 Values of P,T,&M were chosen based on a conservatively assumed Gasoline(RVP 9)model fluid from Tanks 4.0.9d(note:Gasoline(RVP 9)was a custom component specified by the operator and input into Tanks 4.0.9d).Verified accuracy of custom component ano:model results:by re-creating custom RVP 9 component in my own Tanks 4.0.9d model,and by comparing results to other model runs using standard components (Gasoline(RVP 8.3)and Gasoline(RVP 10)) Results for Gasoline(RVP.9)custom.component agree within rounding error of operator's results,and land between those results for RVP 8.3 and RVP 10 models.Will therefore accept methodology and resulting parameter value estimates. To, zyses assnnpto.s,operator provdcd a cedi stabilized tank liquid sample from the Guttersen State 029 facility for a sample collected on'//5/2019 and analyzed on 7/9/2019.Analysis shows an RVP of4.834- therefore,the assum7otion/cholce o`Gasol no(RVP 9)as a model fluid is conservative,and is acceptable. HA,Mass fractions are based on the HYSYS model which was used to estimate emissions from the off spec liquid tanks at this tarility.HAP Mass fractions taken from"Flash"stream which comes off of"Off Spec Tanks"vessel.As the flash emissions profile associated mini the tank butte,y will closely resemble the emissions profile associated with loadout for this facility,will permit based on that modeled gas composition.. Section 09-Inventory SCC Coding and Emissions Factors - - -• ' Uncontrolled -- . Emissions -. AIRS Point 0 Process 0 SCC Code - Pollutant Factor Control% Units 003- 01 4.06-001-32 Crude Oil:Submerged Loading Normal Service(S=0.6) - PM10 0.00 0 lb/1,000 gallons transferred - PM2.5 - 0,00 0 lb/1,000 gallons transferred SOx 0,00 0 lb/1,000 gallons transferred , . NOx 0.00 - -S lb/1,000 gallons transferred ' • VOC 4/ 95 lb/1,000 gallons transferred- ' CO 0.02 . 0 lb/1,000 gallons transferred. Benzene 0.02 95 lb/1,000 gallons transferred Toluene 0.03 95 lb/1,000 gallons transferred Ethylbenzene 0.00 - - 95 lb/1,000 gallons transferred. Xylene. - 0.01 95 lb/1,000 gallons transferred : - ' n-Hexane - 0.12 95 lb/1,000 gallons transferred 224TMP 0.00 95 lb/1,000 gallons transferred • • • 9 of 18 K:\PA\2019\19WE0908.CP1 Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B-APEN and Permit Requirements Source is In the Non-Attainment Area - - • ATTAINMENT • 1. Are uncontrolled actual emissions from any criteria pollutants from this individual sourcegreater than 2 TPY(Regulation 3,Part A,Section ll.D.1.a)? 2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Section 11.0.1.1(7 3. Is the loadout operation loading less than 10,000 gallons(238 BBLs)of crude all per day on an annual average basis?' ' • 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year ofcondensate via submerged fill procedure? ' 6. Are total facility uncontrolled VOC emissions greater than 5TPY,NOx greater than 10TPY or CO emissions greater than 10 TPY(Regulation 3,Part B,Section 11.D.3)? • You have indicated that source Is in the Non-Attainment Area NON-ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than l TPY(Regulation 3,Part A,Section ll.D.1.a)? 4Go to next. .2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Section II.0.1.1)? n Go to then . - 3. Is the loadout operation loading less than 10,000 gallons(230 BBLs)of crude oil per day on an annual average basis? Go to next 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? tio Go to next . 5. Isthe loadout operation loading less than 16,300 bbls per year of condensate via submerged fill procedure? "° Go to next 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY,N0x greater than 5 TPY or CO emissions greater than Sa TPY(Regulation 3,Part B,Section 11.3.2)? '. sF The loadou. -I Source requires a permit . . - 7. RACT-Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy(Regulation 3,Part B,Section llI.D.2.a)? ,.@°n"•s•IThe lcailou ITf+e loadout must Aperata with submerged fill and loadout en:hushons must he routed to flare to satisfy RACT. . 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 orregulalion,and the analysts 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 otany 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,""shduld,"and"can,"is intended to describe APCD interpretations and recommendations.Mandatory terminology such as"must"and required"are intended to describe controlling requirements under the terms of the Clean Air - • Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and Of itself. • • • • • • • • Separator Venting Emissions Inventory Section 01-Administrative Information Facility AIRS ID: ' 123 4087 County Plant Paint Section 02-Equipment Description Details 9fentingof Heater Treater and Surge Drum Gas Streams. Detailed Emissions Unit Description: " '-- ' - .. • Emission Control Device Description: _ - - - Requested Overall VOC&HAP Control Efficiency Vs -95 Limited Process Parameter e Gas meter g Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Separator Actual Throughput= -MMscf per year Requested Permit Limit Throughput=' . `'$,9 MMscf per year Requested Monthly Throughput= 0.8 MMscf per month Potential to Emit(PTE)Throughput= 8.9 MMscf per year Process Control(Recycling) Equipped with a VRU:+ a n Is VRU process equipment:i. .Uncontrolled and controlled emissions used to establish requested permit limits are based only on when the VRU is bypassed(i.e.waste gas volume that is routed to the flare) Secondary Emissions-Combustion Device(s)for Air Pollution Control Separator Gas Heating Value: .2894.0 Btu/scf Volume of waste gas emitted per BBL of Winitale liquids throughput: 94151.,t scf/bbl Control Device Pilot Fuel Use Rate: : - : ,',e :$90 scfh 3.4 MMscf/yr l i J7 MA MR6j a 11j;j1 Pilot Fuel Gas Heating Value: . :1020 Btu/scf Section 04-Emissions Factors&Methodologies Description MW '- : , 510 lb/Ib-mol Displacement Equation MW 45,23 HPSY9 Results-Heater Treater Vapors Ex=Q°MW.Xx/C MW 40.3 Weight% Helium - VOC(excludingHAPs) 70.29 CO2 61.fi CO2 0.5034 CO2 2,51 52 0.0 N2 08127 52 0.07 methane 1:4 methane 3.4553 Methane 9.03 ethane 9,9 ethane 15.0299 Ethane 18.1 propane 25.7 propane 29,7255 isobutane - $.3 isobutane 8.3958 n-butane ''23.1 n-butane 19.9817 isopentane E.1' isopentane 7.0848 n-pentane 9:7 n-pentane 78893 cyclopentane cyclopentane 0,4209 n-Hexane $,3 n-Hexane 1.9975 cyclohexane - cyclohexane 0.532 Other hexanes 4:3 Other hexanes 2.2988 heptanes 2.9 heptanes 01957 methylcyclohexane methylcyclohexane 0.1954 224-TMP ' 0,022 224-TMP 0.0253 224-IMP 0 Benzene - -6.4 Benzene 03167 Benzene 0.28 Toluene 0.8 Toluene 0.0598 Toluene 0.49 Ethylbenzene .6,0 Ethylbenzene 0,0007 Ethylbenzene 0.01 Xylenes - - - -0.3 Xylenes 0,0929 Xylenes 0,21 C8*Heavies 1.6 C8+Heavies 0.0768 Total 100.0 Total 109 Total 100.09 VOC Wt% 88.5 VOC Wt% 80,1987 VOC Wt% 70,29 11 of 18 K:\PA\2019\19WE0908.CP1 Separator Venting Emissions Inventory Emission Factors Separator Venting APEN Listed Em ssion Factors Uncontrolled Controlled Uncontrolled Controlled Emission Factor Source Pollutant (Ib/MMscf). . (Ih/MMscf) (lb/MMscf) (lb/MMscf) . (Gas Throughput) (Gas Throughput) VOC _ 1208999972 6044.9999 i Y 1 ' P ' '.2vg, ` $ 120954.3 6047.7 Benzene 597.8762 29.8938 g 598.0 29.9 Toluene 1045,6008 52.2800 2' a .. 1046.0 52.3 • Ethylbenzene 27.3003 196504areio•44, rj .28.0 1.4. Xylene 448.1341 22,4067 - - - 4484 22.4 n-Hexane 4436.9783' '- 221.9489 - st -�- •� ;e _g 4437.1. 221 9 224TMP 30.0303 1.5015 'rg ,a.,,g _ , _ 30.2 1.5 ., Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) Ib/MMscf Emission Factor Source (Waste Heat Combusted) (Gas Throughput) PM10 0.0000 612 V.'4 4 PM2.5. 0.0000 SOx . 0.0000 NOx - 0 0680 - 196.7920 4- CO ' 0•3200, 5P.17, 697.1400 ..y,cu i.0,31,.:..),,"t.. ,...Pilot Light Emissions -- - Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source (Waste Heat Combusted) (Pilot Gas Throughput) - PM10 0.0000 ' f 'ig°4' a 1"t _ ;'l.. PM2.5 0.0000 6.` e SOx 0.0000 °i ,i NOx _0.0900 100.0000 `w an . . . CO 0.0824 84.0000 - 1 .,>.. .,yx • Section 05-Emissions Inventory - - Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits - Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled ' (tons/year) . (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) ,• ( . PM10 0.0 0.0 0.0 0.0 0,0' 0 - PM2.5 0.0 0.0 0.0 0.0 0.0 0 SOx 6,0 0.0 0.0 0.0 0.0 0 , NOx 3,0 0,2 0.0 LOS 1.05 179 Overall Nos EF 235.2 lb/MI91%14. ' ' • VOC 537.7 0.0 0.0 537.75 26,9 4567 CO 4-1 0.1 0,0 4.13 4.13 702 Overall CO EF f`.929.4 ib/MMF .' Potential to Emit Actual Emissions Requested Permit Limits HazardousAirPollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled , (Ibs/year) (Ibs/year) (lbs/year) (lbs/year) (lbs/year) • Benzene 5317 0 0 5317 266 • Toluene 9301 0 0 9301 465 Ethylbenzene 249 0 0 . 249 12 Xylene 3987 0 0 3987 199 n-Hexane 39454 9 0 39454 1978'r H9 Coritre(led C6 set Rimt eflect59,5,6cgntrcLg6Syatga9405:neddctlonal.0 lyr4`'6 224 TMP 268 .0 0 268 13 t'r -PILL Flig))pn bpertIF)'`„. - „ Section O6-Regulatory Summary Analysis. Regulation 3,Parts A,0 Source requires a permit Regulation 7,Section XVII.B,G Source is subject to Regulation 7,Section 3011.B.2,G Regulation 7,Section XVll.B.2.e - The control device for this separator is not subject to Regulation 7,Section XVR,H.2.e (See regulatory applicability worksheet for detailed analysis) • 12 of 18 X:\PA\2019\19WE0908.CP1 Separator Venting Emissions Inventory --Section 07-Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based.on a gas sample to estimate emissions? - This sample should represent the gas outlet of the equipment covered under this AIRS ID,and should have been collected within one year of the application received date.However,if the facility has not - - been modified(e.g.,no new wells brought on-line),then it maybe appropriate to use an older site-specific sample. - If no,the permit will contain an"Initial Testing Requirement"to collect a site-specific Pis sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. - - ..Are facility-wide permitted emissions of VOC greater than or equal to 90 tons per year?. If yes,the permit will contain. - - -An"Initial Testing Requirement"tocollect a site-specific -gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. - - - - -A"Periodic Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? - Yes If no,the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational(not to exceed 180 days). This condition will use the"Volume of waste gas emitted per BBL of liquids throughput"(scf/bbl)value in section 03. -Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes,the permit will contain compliance testing requirements to demonstrate the destruction efficiency of the combustion device based on - Inlet and outlet concentration sampling you have indicated above that the monitored process parameter is natural gas vented.The following questions do not require an answer. � ,0 � :rEtaXYPWAW er w.x tItttt5, a"ittPttAtitUttegtttAttOts s *i4414WA �i ,1 & f ''1 ", i gag.o.'a mopjiSt ralieYx X g040 I d„ - N.. l ..r. Section 08-Technical Analysis Notes Cells 874-C80 are based on the Surge Drum vapors stream from the submitted HYSYS model results,and were used to verify emission factors listed on APEN(found in cells H74-180).APEN-listed values:were compared to PA calculated values,and then used to estimate annual emissions.Emission factors calculated by this PA were left in cells 874-C80 for reference,but were not used in further calculations. This point covers venting for both the Heater Treater(s)and Surge Drums)at this facility.Emission factors were estimated by HYSYS model,and based on the Surge Drum vapor stream composition alone,as it provides the most conservative emission factors for VOC and all HAPs,which is acceptable: Operator provided a surge drum gas sample analysis on 2/18/2020.Sample was collected on 7/5/2019 and analyzed en 7/1/2019(per sample analysis,though i believe this may be a typo)at a pressure of 4 psig and a temperature of 71F.Cells F42-F68 provide gas analysis results off of surge drum separators'Surge drum gas analysis shows that HYSYS model results provide a conservative estimate for VOC,and BTU while slightly under-estimating 224-TMP.At this time,facility-wide emissions of 224-TMP are essentially negligible at 272 lb/yr across a®sources.Furthermore,periodic sampling of this waste gas stream will be required by permit,and the submitted gas sample was recently collected. Will therefore approve APEN emission factors,and will not require initial gas sampling of this point. Section 09-Inventory SCC Coding and Emissions Factors AIRS Point# Process# SCC Code Pollutant Uncontrolled Emissions Factor Control% Units 004 01 3-10.001-60 Flares PM10 0.0 0 lb/MMSCF SCC coding withpilotli PM2.5 0.0 0 lb/MMSCF emissions in lbsdivide SOx 0.0 0 lb/MMSCF NOx 196.8 0 lb/MMSCF VOC 120900.0 95 lb/MMSCF CO 897.1 0 lb/MMSCF Benzene 597.9 95 lb/MMSCF Toluene 1045.6 95 lb/MMSCF Ethylbenzene - 27.3 95 lb/MMSCF - - Xylene - 448.1 95 lb/MMSCF - n-Hexane 4437.0 95 lb/MMSCF 224 TMP 30.0 95 lb/MMSCF 13 of 18 - K:\PA\2019\19WE0908.CP1 • • • Separator Venting Regulatory Analysis Worksheet • The regulatory requirements below are determined based on requested emissions. • • • Colorado Regulation 3 Parts A ands-APES and Permit Requirements • Source is In the Non-Attainment Area • ' • ATTAINMENT 1. Are uncontrolled actual emissiansfrom any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section ll.0.l.e)? & 2. Are total facility uncontrolled V0C emissions greater than SIPS,NOx greater than 10 TPY or C0 emissions greater than lO TRY(Regulation 3,Part 0,Section 11.0.3)7 • You have indicatestthet source is in the Man-Attainment Area NON-ATTAINMENT ' 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than l TPY(Regulation 3,Part A,Section ll01.al? - Source Re ' 2. Aretotalfacilty uncontrolled VOC emissions from the greater than 2 TPY,NOx greater than 5 TPY or C0 emissions greater than lO TPY(Regulation 3,PertB,Section 11.0.2)? - Source Re •'Source tegUIresa permit . Colorado Regulation 7,Section XNI • 1. Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? ragallilSourceis • 'Source is subject to Regulation 7,Section XVII.S.2,G Section XVII,B.2—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.G-Emissions Control • Alternative Emissions Control!Optional Section) a. Is this separator controlled by a back-up or alternate combustion device(i.e.,not the primary control device)that is not emitted? ,'�:^„ 'Thecontn - - IThaeontrol device for this separator is not subject to Regulation 7,Section XVl3-8.2.e Section XVII.B.2.e—Alternative emissions control equipment Disclaimer • This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This document Is not a rule or regulation,and the analysis it contains niay 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 anynther legally binding requirement and is not legally enforceable.In the event of any conflict between the language of this document and the language of the Clean Air Act„its implementing regulations,and Air Quality Control Commission regulations,the language of the statute or regulation will control.The use of non-mandatory language such as"recommend,""may,""should"and"can,"is intended to describe APCD interpretations and recommendations.Mandatory terminology such as"must"and"required"are intended to describe controlling requirements under the terms of the Clean Air • Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself. • • • • • • Colorado Department of Public Health Environment ' Air Pollution Control Division Operation(hrs/yr) 8760 The default list of TOC emissions factors are based on Table 2-4"Average Emissions Factors"of the EPA Protocol for Fugitive SCC Code:31000220:All Equip Leak Fugitives(Valves,flanges,connect.,seals drains) Equipment Leaks.If the company qualifies to use Table 28 L h 10000 pp f based on provisions of - Regulation 7,Section%VILE,you must update and manually enter the Table 28emlssions factors Into column"E"below. • -. Fugitive Component Counts&Emissions - - 00C - Benzene - Toluene Ethylbenzene. Octane - n-Hexane 2.2,4-TMP - - TOC O€ ' Component Ib/hr- TOC EF. Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled.Controlled Service Type Count stoma kg/hr-source control(%) (tpyl (tpy) (lb/yr) (lb/yr) (lb/yr) (Iblyr) (lb/yr) (lb/yr) (lb/yr) 0b/yr) (lb/yr) (ib/yr) (lb/yr) (lb/yr) Valves 881 5.51E_00 250E-05 0:0% 0.06 0.1 0.7 0.7 0.3 0.3 0.0 0.0 0.0 0.0 3.0 30 0.1 0.1 'u01FSeals9TFW.a..e. 7.72E-O4»,3,50E-04,, 410""-,,,,,,000 0:0 00 00 00 VA 001`^s 00 ::co - 00'7, r'°,°'VA : . D0 ;.00 00 s' mss Others 474 2.65E-04 1.20E-04 0.0% 0.15 02 1.7 1.7 0.8 0.8 0.0 00 00 00 7.7 7.7 0.2 0.2 Connectors 2347 2,20E-00 1.00E-05 0.0% 0.06 0.1 0.7 0.7 0.3 0.3 0.0 0.0 00 0.0 3.2 3.2 0.1 0.1 Flanges 1097 1.26E-05 570E-0B 00% 002 0.0 0.2 02 01 0.1 00 00 00 0.0 08 08 C0 00 A,(feRertded-l000 `Y., ' .3131E-CE 150E-05,6,60.d%fl"a, s.i 000 VA 00 00 00 0:0 0.0 00 00 0:03: 0 00 =00 - 001 Valves 1385 4.19E-000 1.90E-05 00% 0.25 0.3 2.9 2.9 1.4 1.4 0.0 0,0 0.1 0.1 13.0 13.0 0.3 - 03 PumpSeale 36 1.12E-24 5.10E-04 0,0% 0.18 0.2 2.0 2.0 1.0 I0 00 00 0,0 00 9.0 9.0 0.2 0.2 Light Oil Others 427 2.43E-01 1,10E-04 0,0% 0.45 0.5 5.2 5.2 2.4 24 0,0 CO 0.1 01 23.1 23.1 05 0.5 Connectors 2414 214E-05 9.70E-08 0.0% 023 0.2 28 28 1.2' 12 0.0 0.0 00 0.0 11,5 11,5 03 0.3 Flanges 1037 529E-000 2.40E-06 00% 0.02 0.0 0.3 0.3 0.1 0.n 00 0.0 0.0 0.0 1.2 1.2 00 0.0 Op d dl 3092.00 140E-03 C0% .000 00 00 00 "00 00" 00 00 00 I 00' 00 00 00 00 iL j B,v C; 04"__ 00h 0.0_ CO I GO CO 00 00 00 � 00 00 0_ J l pC 00� OI Heav Oh 705E-0i4 00 00 00 00 00 I 00 —'--- 0 00 0 -rt JO OJ HX00 I 00 y Co t I: 0E0.7 OE06 00/ 000 00 00 CO 0 00 I OC 00 0.0 Of 30 OC C0 V0 Flag 5OE{N B.., 3_Ot0) 00°F 0 0 0.0 00 CO 00 0.0 v0 1 00 I 00 C..—HOC CC ACC +0.0 I _Val dtll cs: 1.59E-0-u 720E-O6 00% 000 0.0 00 CO 00 0.0 0 0. 00 00 0.0 00 00 00 L 00: Pumps /r9 2.14E-0i 9.70E-05 VV, 0.03 0.0 0.3 0.0 0.1 0.1 00 0 0.0 0.0 0.0 00 1.3 C0 IA Pump Seals'. 5.20E-0 5,40E-05 Coe 000 ':0.0 00 0.0 00 0.0 C.O. 00 ::00 0:0'. 26 00 -:-CC COQ:": Water/Oil Others 89 1.30E-04 1.00E-05 00% 0 0 0.1 0.6 0.6 03 0.3 00 0.0 0.0 0.0 26 26 0.1 01 Connectors 497 2.20E-05 1,00E-05 0.0',5 0.05 0.0 0.5 0.5 0.3 0.3 0.0 0.0 0.0 0.0 24 2.4 0.1 0.1 Flanges 300 6.39E-06 2.90E-06 00',5 001 00 0.1 01 00 Oa CC 00 00 0.o 04 0 04 00 0.0 006,anded Ines -5.51E-04 2 50E-04 0G% .::000 O0 C.V 00 00 0:0: 00 00 00 :0.0 00...:: 00 00 00.:. TOTALS(tev) 1.6 1:6' 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.04 0.04 0A0 0.00 With safety factor: 1 I TOTALS)tpyl 1. �1:. 0.01 0,01 0.00 000 0,00 0.00 0,00 0,00 0,04 0,04 TOTALS ib/r 80 80 Emission Factor Source: EPA-453/R-85-017,Table 2-4 i VOC 259467258 Iblmonth:i , Roundedt080!Won Stream VOC Fraction(wt) : Stream HAP Components(wt fraction) perm t per operator talcs • -- --Gas 0.2750 HAP Gas Light CH Heavy Oil Water/O) Light Oil 1,0000 Benzene 1.57E-03 5,70E-03 5,70E-03 5:70E-03 Heavy Oil 1.0000 Toluene 7.45E-04 2.70E-03 2.70E03 2.70E-03 Water/Oil 1,0000 - Ethylhenzene 5.00E-0B 0A0E+00 0.00E+00 0.00E+00 Xylene 280E-05e 1,00E-04. 1.00E-04 1.00E-04 - .. .n-Hexane 7.03E-03 255E-02 2.55E-02 265E-02 2,2,4-TMP itkl#M### 600E-04 6.00E-04 600E-04 - Regulator/Considerations - Is this ea source located in an Dne non-attainment area or attainment maintenance area? ' Yes Reg,3 Ifyes,is this sourcesubjeot to leak detection and repair(LOAR)requirements per Regulation 7,Section XVII,F00911.0 or 40 CFR,Part 80,Subparts KKK or 0000? Yes If you repond'yes.to the fits/question and'no"tome second.this source Is subject to Regulation 3,Part B,Section 111.0.2,Reasonably Available Control Technology(RAG?)requirements and must Implement a leak detection and repair program.The engineer should work with the supervisor to craft an LDAR requirement that mirrors the provisions of Regulation 7,Section XVII,F, _ Is this source at an onshore"natural gas processing plant"as defined in 40 CFR,Part 60,631? No Did this source commences construction,reconstruction,or modification after January 20.1994,and on or before August 23,2011? No If you answer'yes.to both questions above,this source is subject to the provisions of 40 CFR,Part 30,Subpart KKK"Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants"contained in Regulation 6,Part P. Reg.6 Did this source commences construcion,reconstruction,or modification after August 23,2011, Yes If you ansueryee t0 question#1 and#3 this source is subject to the provisions of 40 CFR,Part 60,Subpart 0000'Standards of Performance for Crude Oil and Natural Gas Production,Transmission and Distribution".Specifically,review subpart 60.5400 for fugitive component leaks and 60,5380 and 60.5385 if the operator reports compressors, It is passible for an onshore natural gas Focesting plant to have portions of the facility subject to NSPS KKK and portions subjectto NSPS 0000 based on the spedfic dates of construction of those portions of the facility,If this is the case.the operator will need to report each of those.respective fugitive component emissions en separate APENsand obtain unique emissions points from the Division. Is this source located to an ozone non-attainment area or attainment maintenance area? Yes • - . Reg.7 is this source at.onshore"natural gas processing plant"as defined In 40 CFR,Part 60.631? No I1 you answer yes"t0 both questions above,this source Is subject to the provisions of Regulation 7,Section X11.0 regardless of the date of construction • ' Is this scarce at a"natural gas pmcesing plant'as defined in 40 CFR,Part 63,]61, No • R¢g.a Is this facility considered a"major source of HAP asepecllcalty Osbned in 40 CFR,Part 63.761 for sites mat are not predcuti0n field facilities? No .- - If you repoed"yes.to both questions above,further review if the provisions of 40 CFR.Part 63.769"Equipment Leak Standards"apply? No Operator provided a site-speci3c sales gas sample on 2/18/2020,sample was collected from the sales meter ate pressure of 178 psg and temperature of 60P on 2/7/2020 and analyzed on 2/10/2020 by SPL Inc Sample was collected from the faclry being permitted wthna year of permit apohcation.NMI therehre not there-a requre initial gas sampling for the punt • Printed 4/9/2020 Page 15 01 18 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name County AIRS ID Plant AIRS ID Facility Name Noble Energy Inc. 123 A087 Guff ersen/Gu0ersen State P29 -22-A T3N-R64W-929 L01 History File Edit Date Ozone Status 4/3/2020 J Non -Attainment EMISSIONS - Uncontrolled (tons per Year EMISSIONS With Controls (tons per Year POINT AIRS ID PERMIT Description PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL 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 New Facility - NO Previous Total Previous Permitted Facility total 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 0.0 001 19WE0908 Three (3) 500 bbl Condensate Storage Tanks 0.0 15.7 0.1 0.7 0.0 0.8 0.1 0.0 NEW 002 19WE0908 Four (4) 500 bbl Produced Water Storage Tanks 2.7 190.0 12.1 21.0 2.7 9.5 12.1 1.1 NEW 003 19WE0908 Truck Loadout 0.0 22.7 0.1 0.9 0.0 1.1 0.1 0.0 NEW 004 19WE0908 Heater Treater and Surge Rum Gas Venting 1.0 537.8 4.1 29.3 1.0 26.9 4.1 1.5 NEW 005 19WE0908 Fugitive Component Leaks 1.7 0.0 1.7 0.0 NEW 006 0602 Caterpillar G3408TA, 400hp, 4SRB, (sn: 6N001563) 0.2 0.2 101.5 2.7 7.7 0.9 0.2 0.2 3.9 2.7 7.7 0.3 NEW 007 0602 Caterpillar G3408TA, 400hp, 4SRB, (em 6NB02099) 0.2 0.2 101.5 2.7 7.7 0.9 0.2 0.2 3.9 2.7 7.7 0.3 NEW 008 0602 GM 5.7L, 92hp, 4SRB, (sn: 10L59M710240057) 0.1 0.1 12.4 0.6 9.8 0.1 0.1 0.1 0.9 0.6 1.8 0.1 NEW 009 0602 GM 5.7L, 92hp, 4SRB, (sn: 10L59M711220025) 0.1 0.1 12.4 0.6 9.8 0.1 0.1 0.1 0.9 0.8 1.8 0.1 NEW 010 0602 GM 5.7L, 92hp, 4SRB. (sn: 10L59M7112200511 0.1 0.1 12.4 0.6 9.8 0.1 0.1 0.1 0.9 0.6 1.8 0.1 NEW 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ADEN ExempllnsigniRcants 0.0 0.0 XA (2) Heater Treaters 0.100 0.100 1.8 0.10 - 1.5 0.0 0.100 0.100 1.8 0.1 1.5 0.0 From APCD 102 XA (9) HP Heaters 0.200 0.200 3.0 0.2 2.5 0.1 0.200 0.200 3.0 0.2 2.5 0.1 From APCD 102 0.0 0.0 0.0 0.0 FACILITY TOTAL 1.0 1.0 0.0 0.0 248.9 773.8 1.7 65.2 54.1 1.0 1.0 0.0 0.0 19.0 45.9 1.7 41.2 3.7 VOC: Syn Minor (NANSR and OP) NOx: Syn Minor (NANSR and OP) CO: True Minor (PSD and OP) HAPS: Syn Minor n -Hex, Total HH: NIA -Area Source ZZZZ: Area Source Permitted Facl0v Total 0.7 0.7 0.0 0.0 244.1 773.5 1.7 61.2 54.0 0.7 0.7 0.0 0.0 14.2 45.6 1.7 37.2 3.6 Excludes units exempt from permAs/APENs (d) Charge in Permitted Emissions 0.7 0.7 0.0 0.0 14.2 45.6 1.7 37.2 Pubcom & modeling required based on requesting Synthetic Minor Limb, and Project Emissions Note 1 Total VOC (A) Change in Total Permitted Facility Emissions (point and fugitive) VOC emissions (point end fugitive) 476 Facility Is eligible 1010602 because < 90 Ipy Project emissions greater than 25 Spy 473 While facility -wide VOC emissions exceed 90.4 try, the 0602 applications were received before the effective re -designation date for the NAA. Therefore, facility still qualifies for these 0602 permits. Note 2 Page 16 of 18 Printed 4/9/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name Noble Energy Inc. County AIRS ID 123 Plant AIRS ID A087 Facility Name Guttersen/Guttersen State D29 -22-A T3N-R64W-329 L01 Emissions - uncontrolled (lbs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylhenzene Xylenes n -Hexane McOH 224TMP H2S TOTAL(tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 19WE0908 Three (3) 500 bbl Condensate Storage Tanks 155 180 6 103 979 0.7 002 19WE0908 Four (4) 500 bbl Produced Water Storage Tanks 10150 31900 21.0 003 19WE0908 Truck Loadout 173 287 9 114 1283 0.9 004 19WE0908 Heater Treaterand Surge Drum Gas Venting 5317 9301 249 3987 39454 268 29.3 005 19WE0908 Fugitive Component Leaks 11 5 2 2 37 5 0.0 006 GP02 Caterpillar G34D8TA, 400hp, 4SRB, (sn: 6NB01563) 1468 69 65 39 76 0.9 007 GP02 Caterpillar G3408TA, 400hp, 4SRB, (sn: 6NB02099) 1468 69 65 39 76 0.9 008 GP02 GM 5.7L, 92hp, 4SRB, (sn: 10L59M710240057) 149 20 19 11 - 22 0.1 009 GP02 GM 5.7L, 92hp. 4SRB, (sn: 10L59M711220025) 149 20 19 11 22 0.1 010 GP02 GM 5.7L, 92hp, 4SRB, (sn: 10L59M711220051) 149 20 19 11 22 0.1 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 XA (2) Heater Treaters 63 0.0 XA (9) HP Heaters 106 0.1 0.0 0.0 0.0 TOTALStpy) 1.7 0.1 0.1 8.0 4.9 0.1 2.1 36.9 0.1 0.1 0.0 0.0 54.1 `Total Reportable = all HAPs where uncontrolled emissions > de minimus values Red Text: uncontrolled emissions < de minimus 17 19WE0908.CP1 4/9/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY- HAPs Company Name Noble Energyinc. County AIRS ID 123 Plant AIRS ID A087 Facility Name Guttersen/Guttersen State O29.22 -A T3N-R64W-529 L01 Emissions with controls (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL ((iv) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 19WE0908 Three (3) 500 bbl Condensate Storage Tanks 8 9 0 5 49 0.0 002 19WE0908 Four (4) 500 bbl Produced Water Storage Tanks 508 1595 1.1 003 19WE0908 Truck Loadout 9 14 0 6 64 0.0 004 19WE0908 Heater Treaterand Surge Drum Gas Venting 266 465 12 199 1978 13 1.5 005 19WE0908 Fugitive Component Leaks 11 5 2 2 37 5 0.0 006 GP02 Caterpillar G3408TA, 400hp, 4SRB, (sn: 6NB01563) 386 69 65 39 76 0.3 007 GP02 Caterpillar G3408TA, 400hp, 4SRB, (sn: 6NB02099) 386 69 65 39 76 0.3 008 GP02 GM 5.7L, 92hp, 4SRB, (sn: 10L59M710240057) 149 20 19 11 22 0.1 009 GP02 GM 5.7L, 92h0. 4SRB, (sn: 10L59M711220025) 149 20 19 11 22 0.1 010 GP02 GM 5.7L, 92hp. 4SRB, (sn: 10L59M711220051) 149 20 19 11 22 0.1 0.0 0.0 0.0 0.0 0.0 APEN Exempt/Insignificants 0.0 XA (2) Heater Treaters 63 0.0 XA (9) HP Heaters 106 0.1 0.0 0.0 0.0 TOTAL (tpvl 0.6 0.1 0.1 0.5 0.2 0.0 0.1 1.9 0.1 0.0 0.0 0.0 3.7 18 19WE0908.CP1 4/9/2020 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - GUTTERSEN/GUTTERSEN STATE D29 -22-A T3N-R64W-S29 L01 - Weld County Notice Period Begins: April 23, 2020 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy, Inc. Facility: GUTTERSEN/GUTTERSEN STATE D29 -22-A T3N-R64W-S29 L01 Exploration Et Production Well Pad SWNE SEC29 T3N R64W Weld County The proposed project or activity is as follows: The applicant proposes the construction of a new E&tP Well Pad facility. Permitted equipment/sources include: a Condensate storage tank battery, a Produced Water storage tank battery, Condensate loadout to trucks, Separator gas venting/flaring, fugitive component leaks, in addition to five engines on GP02s. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 19WE0908 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: Ben Fischbach Colorado Department of Public Health and Environment IcotoRADO 1 ae Department of Public Health Et Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 2 I atelcoLoRADo Department of Public Health 6 Environment Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - GUTTERSEN/GUTTERSEN STATE D29 -22-A T3N-R64W-S29 L01 - Weld County Notice Period Begins: April 23, 2020 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy, Inc. Facility: GUTTERSEN/GUTTERSEN STATE D29 -22-A T3N-R64W-S29 L01 Exploration Et Production Well Pad SWNE SEC29 T3N R64W Weld County The proposed project or activity is as follows: The applicant proposes the construction of a new E&tP Well Pad facility. Permitted equipment/sources include: a Condensate storage tank battery, a Produced Water storage tank battery, Condensate loadout to trucks, Separator gas venting/flaring, fugitive component leaks, in addition to five engines on GP02s. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 19WE0908 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: Ben Fischbach Colorado Department of Public Health and Environment COLORADO 1 Department of Public H a1th B EnairpnrMr t 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 2 I gel COLORADO Department of Public Health & Envircnnunt Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: DCP Operating Company, LP - Godfrey Bottom Compressor Station - Weld County Notice Period Begins: April 23, 2020 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: DCP Operating Company, LP Facility: Godfrey Bottom Compressor Station Natural gas compressor station Sec 10 T4N R66W Weld County The proposed project or activity is as follows: DCP is requesting to modify existing equipment at an existing compressor station. DCP is requesting to modify the existing dehy (Point 005) by increasing throughput, decreasing glycol recirculation rate and accounting for supplemental fuel at the enclosed combustor. DCP is requesting to modify the existing turbines (Points 009 and 010) by adjusting throughput and emissions based on a revised manufacturer specification sheet and to account for startup and shutdown emissions. DCP is requesting revise the emissions methodology for the existing pressurized loadout (Point 012). DCP is requesting to add fugitive equipment leaks, which were previously APEN-exempt, as a permitted point (Point 013). DCP is also requesting to add compressor blowdowns (Point 015) and compressor purging (Point 016). 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): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 11WE1479 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: (COLORADO Department of Public Health 0 Environment Carissa Money Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 is eicoLoRAD0 Department ot Public 2 I Health & Environment Colorado Air Permitting Project PRELIMINARY ANALYSIS-PROJECT SUMMARY Project Details For Division Use Only Review Engineer: Carissa Money Package 6: 414597 Received Date: 8/23/2019 Review Start Date: 11/19/2019 Section 01-Facility Information Company Name: DCP Operating Company,LP Quadrant Section Township Range County AIRS ID: 123 - 10 4N 66 Plant AIRS ID: 9010 - - Facility Name: Godfrey Bottom Compressor Station Physical Address/Location: Section 10,Township 4N,Range 66W County: Weld County Type of Facility: Natural Gas Compressor Station Whatindustrysegment?Oil&Natural Gas Production&Processing Is this facility located in a NAAQS non-attainment area? • Yes If yes,for what pollutant? Ozone(NOx&VOC) Section 02-Emissions Units In Permit Application Leave Blank-For Division Use Only Permit# AIRS Point 6 Emissions (Leave blank unless Issuance Self Cert Engineering (Leave blank unless APCD Emissions Source Type Equipment Name Action Control? APCD has already # Required? Remarks has already assigned) assigned) Permit 005 Dehydrator D-1 Yes 11WE1479 4 Modification Permit 009 Turbine TURB-1 No 11WE1479 4 Modification Permit 010 Turbine TURB-2 No 11WE1479 4 Modification DCP requested to cancel this point.It was not originally included in the Aug 2019 application. DCP provided a cancellation notice and supporting calculations on 011 Produced Water Tank PW Tank No 17WE0001 Cancellation 3/19/2020. Permit 012 - Liquid Loading L-1 No 11WE1479 4 Modification Fugitives listed in Issuance 1 as Point 006,then cancelled and removed from Issuance 2 as APEN exempt (15WE0147.XA) .Now reporting Permit initial as APEN- 013 Fugitive Component Leaks FUG No 11WE1479 4 Issuance required. Colorado Air Permitting Project ;0CFrequested, to separately :.. permitturbine: k L startup/'_ r � shutdawn emissions _ However these, must be ` s, mduded w th ;'° � r the turbines, , This point Was ��.cancelle`dandx` startup(shutdn we emissions are includes . with '014 F hfn ,n, TURK SUSD �:turbines,.,.. . Turbine' 015 MairltnanceBfriwdawns';„. TURB-BD ida; 11W61479 4 tssilance' ','.`blowdawns- ern) imtr - - 016-' Mslnt flsnce'titowdowns ;..TORB-Ritrge cr 11W61479 4 63s)ancd` i,Turbine purging Section 03-Description of Project DCP is requestingto modify an existing compressor statio€,DCP is not modifying any equipment.The changes are primarily changes to methods,for emissions calculations.DCP is requesting to'modify the existing dehy(Point 005)by increasing throughput,decreasing glycol recirculation rate and accounting for supplemental' fuel at the enclosed combustor.DCP is requesting to modify the existing turbines(Points 009 and 010)by adjusting throughput and emissions based,on.a revised,„ _. manufacturer specification sheet and to account for startup and shutdown emissions.DCP is requesting to-modify emissions for`the existing pressurized laadout, (Point 012)by revising emissions methodology.DCP is requestingto add fugitive equipment leaks,which were previously APEN-exempt,as-a permitted point 013).DCP is also requesting to add compressor blowdowns,(Point 015)and compressor purging(Point 016). - - - ; ' With these changes,total facility VOC emissions are decreasingbut NOx and CO emissions are increasing.The emissions increase is less than 25 spy. Sections 04,05&06-For Division Use Only Section 04-Public Comment Requirements Is Public Comment Required? If yes,why? 9equeati g5ysrthetic Mrnor Permtt Section 05-Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? Na 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? ,z,aiirt Is this stationary source a synthetic minor? G _ If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(I3SD) 0 0 0 0 0 0 Title V Operating Permits(OP) El 0 0 Q 0 0 0 21 Non-Attainment New Source Review(PbANSR) ❑ Is this stationary source a major source? - x If yes,indicate programs and which pollutants: 502 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration(PSD) 0 ❑ 0 0 ❑ 0 Title V Operating Permits(OP) 0 0 0 0 ❑ 0 0 ❑ Non-Attainment New Source Review(NANSR) ❑ 0 Glycol Dehydrator Emissions Inventory Section 01-Administrative Information Facility AIRS ID: " 9➢1000S County Plant Point Section 02-Equipment Description Details Dehydrator krlormation Dehydrator Type: '.3£1' 44, Make: ..0Le 0.01'YocatS5ynYeins_y , Model: Serial Number. Design Capacity: Recirculation Pump Information Number of Pumps '. .a ^^^^��EE Pump TYPe Rm 3 R u^nw € f 0 Make: Model: - - ',M1218- Desgn/Max Recirculation Rate. 75 .',gallons/minute Dehydrator Equipment Flash Tank °eP"'. - `,flash tank, Reba her Burner and rebo her burner Stripping Gas . ....- n., One(1)methylene glycol MEG)natural gas dehydration unit Make:Dickson Process Systems,Model:TEE Unit,Serial Number:2460)with a design capacity of 140 MMscf per day.This emissions unit is equipped with 2(Make:FMC,Model:M1218)electric driven glycol pump with a design capacity of 25 gallons per minute.This dehydration Dehydrator Equipment Description unit is equipped with a still vent,flash tank,and remoter burner. Emissions from the still vent are routed to an air-cooled condenser,and then teethe Enclosed Flare.Emissions from the flash tank are routed directly teethe Vapor Recovery Emission Control Device Description: Unit(VRU).As secondary control device,flash tank emissions are routed to the Enclosed Flare. Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Dehydrator Still Vent and Flash Tank kf present) Requested Permit Limit Throughput= 53400.0 .'.MMscf per year Requested Monthly Throughput= 4340 MMscf per month I Potential to Emit(PTE)Throughput= 51,100 MMscf per year Secondary Emissions-Combustion Device(s)for Air Pollution Control Still Vent Control Dry Gas Throughput: Condenser: NORMAVerte Still Vent Primary Control: 51,100.0 MMsef/yr 4,340.0 MMscf/month Condenseremwinn reduction claimed: 41t -Requested Condenser Outlet Temperature: Degrees F Still Vent Secondary Control: 0.0 MMsef/yr Primary control device: j.,.. _ ,*.y` ,Control Effiiency% Waste Gas Combusted: Primary control device operation: ''8760 hr/yr Requested TO Temp • Degrees F Still Vent Primary Control: 7.4 MMsef/yr 0.6 MMscf/month Secondary control device: f',i. „v ' '','.' Control Efficiency% Still Vent Secondary Control: 0,0 MMsef/yr Secondary control device operation: Still Vent Gas Heating Value: 3343 fitu/scf Still Vent Waste Gas Vent Rate: - .8.48E+02 scfh,BASED ON CONDENSER VENT GAS STREAM Flash tank Control Dry Gas Throughput: Primary control device: Ar-7 All&t 100%Control Efficiency% Flash Tank Primary Control: 51,100.0 MMscf/yr Primary control device operation: 8760 hr/yr Flash Tank Secondary Control: 2,5555.0 MMsef/Yr Secondary control device: • . 95%Control Efficiency% Waste Gas Combusted: Secondary control device operation: _438.hr/yr Flash Tank Primary Control: 0.0 MMsef/yr Flash Tank Gas Heating Value ,2566 Btu/scf Flash Tank Secondary Control: 0.8 MMsef/yr Flash Tank Waste Gas Vent Rate: .2,740002 sdh 'The flash tank waste gas vent rate did not change when the Glycale run waschanged from 136 MMscfd to 140 MMscfd but the stream composition did change slightly. Primary Control Device I Enclosed Flare I Secondary Control Device 'Not applicable Pilot Fuel Use Rate: " ;65 scfh 0.6 MMsef/yr Pilot Fuel Use Rate: sdh 0.0 MMsef/yr Pilot Fuel Gas Heating Value: .960 Btu/scf Pilot Fuel Gas Heating Value: Btu/sct Supplemental Fuel '3000 scfh 17.5 MMsef/yr Supplemental Fuel Gas Heating Value: ',899 Btu/scf 18.1 Total MMsef/Yr 1.5 Enclosed Flare Fuel Gas Composition Molecular Weight 19.19 Ib/Ib-cool Mole% Component MW IboSb-md Mass Fraction Mass Fraction(100%HC) Helium 1.OOOE-02 4.00 0.00 2.09E-05 0 CO2 1850E#00 - 43.94 0.81 4.24E-02 0 672 3.400E-01 28.02 0.10 4.07E-03 0 Hydrogen Sulfide 0.000E+00 3410 0.00 0.00E+00 0 methane "8230E.+Ot 16:01 13.18 6.87E-01 7.21E-01 ethane ;"1.298E+09 - 30.02 3.90 2.03E-01 0.213159475 Propane '':2.013E+00 44.03 0,89 4.62E-02 0.048507482 aobutane 1.248E-01 - 58.04 0.07 3,78E-03 0.003963437 _n-butane 2,637E-01 58.04 0.15 7.08E-03 0,008374660 Iacpentene 4.020E-02 72.051 0,03 1,74E-03 0.001821403 n-pentane 4.770E-02 72.05 0.03 1.79E-03 0.001880539 Cyclopenrene: 1.500E-03 84.16 0.00 8.33E-05 8.74962E-05 Methanol "1.600E-03 ;32,04. 0.00 2,67E-05 2.80506E-05 n-Hexane 6.800E•03 86:16 0.01 0.0003 0.000320586 cyclohexane 1,3➢0E-03 84.10 0.00 5,70E-05 5,98658E-05 Other hexanes 1 230E-02 80.16 0,01 6,52E-04 0,000579984 heptanes - 2.5000.00 -,100,21 0.00 1.31E-04 0,000;37082 methylcyclohexane 6.000E-04 - 90.19 0.00 3.07E-05 3.22365E-05 224-TMP 0.000E+00 114.23 0.00 0.00E+00 0 Benzene 1 000E-03 70.10. 0,00 0.00004 0.00004 Toluene * 4.000E-04 92.10, 0.00 1.92E-05 2.01581E-05 Ethyibenzene ..0.000E+00 " -106:10 0,00 0,00E+00 0 Xylenes 'Ao000000 106.10' 0,00 0.00E+00 0 CB+Heavies ` 4.000E-04 - '114.20. 0.06 2.38E-05 2.49952E-05 Total(Uncontroled) 1.00 1.000024995 Total VOC(Uncontrolled) ➢,0628 0.065080616 Section 04-Emissions Factors&Methodologies Dehydrator Thntoaeseliod any Glycaic atto estimate.etrdssions.Wetgastornposftiocn isbasedon a TEG inlet 5ampecabected'fromTrpudt Cgmpressdr0tatian on, SD/4}2016,Far 60 10.51 permit f uatse(CP3(,DCF,used.the same gas.5dmpleanthe Oasts for theGlycaic.6lycalc wasaisnbeced onthesamo8estttaok-' pressureuF60psfgbut a,lower temperetceeaflos deg E.The.previous Glycalc run was based on an inlet pressure of 1056pslgand temperature of110.deg6, gtycPFreriecnate:of40gpmandgasthrauglr0it0ft30MMSC/day; ' . .. Input Parameters Flash Tank Inlet Gas Pressure 1000 psig Pressure 60 prig Inlet Gas Temperature 120 deg F Temperature 130 deg F Requested Glycol Recirculate Rate 25 - gym Control Scenario. STILL VENT Primary Secondary Pollutant Uncontrolled(lb/hr) Controlled(Ib/hr) Controlled(lb/hr) Vac -12,9864 • 353432 0 Benzene ?03023 OS15105 0 Toluene 9,6146- ' ' 0.48074 0 Ethylbenzene ' 0375 0,00065 0 Xylenes . 2,8807'. 0.144035 0 • Glycol Dehydrator Emissions Inventory • n Hexane ;46;4333#."a 0.071221667 0 224-TMP .'..-O,10;654OM 0.000446 0 Methanol 47@7: 166667KS 0.356106333 0 Control Scenario FLASH TANK - Primary Secondary Pollutant Uncontrolled(lb/hr) Contrail d(lb/hr) Controlled(Ib/hrl VOC "Lek'-'57.584 2.87926 Benzene ,1'','L, 1911„ - 0.0096 Toluene tar aDai*YilA 0.005895 • Ethylbenzene iu 0'082 ,,4 0.0001 XYleneo 40- fii0 .NUUN„ 0.00071 n-Hexane =''115625 0.038125833 224-TMP • 06A 0.00024 . Methanol 4 #a. 0.190629167 Glycol Dehydrator Emissions Inventory Emission Factors Glycol Dehydrator - Uncontrolled Controlled Pollutant (lb/MMsd) (Ib/MMscf) Emission Factor Source - - - (Dry Gas Throughput) (Dry Gas Throughput) VOC 22.20 11098 `4 - "s 0 Bemene 1.80 00900 .'880M,D*C5APTDX,0451,00,155,80,45-rv,V00W084,. Toluene - 1.67 00834 Ethylbenzene 0.05 0.0024 '-s Xylene 0.50 0.0248 - n-Hexane 0.37 0018] 224 TMP 0.00 0.0001 Methanol 1.87 0.0937 t .cn Still Vent Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtui (Ib/MMscf) Emissi rEact r5ource (Waste Heat (Waste Gas • Combusted) Combusted) PM10 ''8 09075. 14.0143 b < PM :2.5 5 0.0075 14.1643 '-414°':"66".W.'"'41'-'• 1.1182 • C;'„Ac $ Nay 01.`"5.00699 a 1292680 { CO ,.,, 0,3100s,E.,-6 5893100 'A S r: Still Vent Secondary Control Device - Uncontrolled Uncontrolled - Pollutant (Ib/MMBtu) (Ib/MMscf) Emissi tract r5 urce (WasteHeat (Waste Gas - - Combusted) Combusted) PM10 0:0000 A PM2.5 000 • p g.. 0.0 - - - - - - SOx 0.00M .e, :g , NOx 0.9000 CO @.9009 m ,r s,p tr.a v�°"k. a - - _ .- Flash Tank Primary Control Device Uncontrolled Uncontrolled ' Pollutant (ib/MMBtu) (Ib/MMscf( Emissi rFac[r5aurce(Waste Heat (Waste Gas Combusted) Combusted) PM10 0.0000 .t. y,, :s - - PM2.5-- 00000 .." NO5 .. 3 ,„S 0.0009 - - - CO ;,rx.f..c. 0O009 - Flash Tank Secondary Control Device - - Uncontrolled Uncontrolled - - - - - Pollutant (Ib/MMBtu) (Ib/MMscf) (WasteHeat (Waste Gas • Combusted) Combusted)PM10 0'0W 0.0075 11.6582 PM2.5 00075 11-6682 SOx 0.0006 - 09212 NOx 0.0680 106.4880 • -; - tt CO 0.3100 485,4600 ..° -° "f" i a . ,r... Primary Pilot Light Emissions Uncontrolled Uncontrolled Pollutant lib/MMBtu) (Ib/MMscf) Emissi tract r5 urce • (Waste Heat Combusted) (Pilot Gas Throughput) t --PM10 0.0070 79415 .:a,°e t � , ;"xr., ;xt `° PM2.5 0.0975 70435 ;4 SOx 00006 0.8086 ' — - 800 0,0380 9].9412 CO ,, "524 82.2706 ; • .,t• t m Secondary Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (Ib/MMsct) Emission Factor Source (Waste Heat Combusted) (Pilot Gas Throughput) PM10 re a'6 0.0000 ti • ,, ye PM2.5 a o S 00000 y k ) 500 0.9W0 0 '3 000 M F>r 00000 6 y` CO 9' - 0.0000Ii5848,581'5841,1FAV aY .v Supplemental Fuel Emissions Uncontrolled Uncontrolled Pollutant (lb/MM tu) (Ib/MMscff Emissi rFa15 r5 urce (Waste Heat (Supplemental Fuel - Combusted) Throughput) PM10 $ 00075 7.4435 {'P C .'`.t di ; PM2.5 90075 7.4435 500 80006 058]9 a 3` NOx 0,0680 679320TATATAT.A44.4,AT, AvITATATAAAAAAAA '• CO 03300 309.6909 .4,1,I, ^.,, 'ilot/Assist Gas Combustion(Primary Emission. Pollutant Uncontrolled Controlled Emissi eFact r5 u - - Ib/MMscf lb/MMsof VOC )33349622 166.7401 k".. ( "' - - - Benzene 00633 0.1082 Toluene "s 00204 0.0510 ( t Ethylbenaene ATTAAAAAAA•TAT 0.0000 ([ XYI `' 0'0000 0.0000 • f - n Hexane ^S'`7,6228S 0.8114 `$ g:,224 TMP ?w95000, 00000 'ym L O - Section 05 Emissions Inventory' 0 d operator request a buffer] - -R q e d Buffer(%)' — - - Requested Monthly Potential to Emit Actual Emissions Requested Permit Limits Limits Criteria Pollutants - Uncontrolled Uncontrolled Controlled Uncontrolled Controlled ' Controlled (tons/year) (tons/year) (tons/Year) (tons/year) Itonslyea0 (Ihs/month( PM10 - 0.1 0.1 0.1. 0.1 0.1 23 PM2.5 0.1 0.1 01 0,1 0.1 23 - - 505 0.0 00 0.9 0.0 0.5 .2 .. NOx 1.3 1.3 1.3 1.3 1.3 214 CO - 5,6 56 5,6 5.6 1.6 955 VOC 625.3 6253 19,5 625.3 145 3316 Potential to Emit Actual Emissions Requested Permit Limits Glycol Dehydrator Emissions Inventory Hazardous Air Pollutants- Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (Ibs/year) (lbs/year) (lbs/year) (Ibs/year) Benzene 101125 101125 4970 101125 4970 Toluene 93785 93789 4036 93785 4636 Ethylbenzene 2708 2708 134 2708 134 Xylene 27555 27895 1388 27895 1388 n-He,,ane 21088 21088 719 21088 719 224 IMP 132 132 4 132 4 Methanol 105367 105357 3523 105367 3523 Section 06-Regulatory Summary Analysis Regulation 3.Parts A,a Source requires apermit Regulation 7_Section XVII.B,o Dehydrator Is not subject to Regulation 7,Sectoa MVII.B,8.3 Regulation 7_Section XVII.B.Ze _ _ The control device far this dehydrator is not subject to Regulation 7,Section XVl1.3.2.e Regulation 7_Section Xll.H Dehydrator is sub)eetto.Regulation 7,Section Xtl.H Regulation S.Part E MACT Subpart HH(Area) Oehy is subject to area source MACY'HO-Control requirements in 63.765 per 63.764(d)(1) Regulation B_Part E,MAR Subpart HH(Major) You have indicated that this facility is not subject to Major Source requirements of MALT HH. Regulation B.Part E,MACT Subpart HHH You have indicated that this facility is not subject to MAR HHH. (See regulatory applicability worksheet far detailed analysis) � 1 • • Glycol Dehydrator Emissions Inventory Section 07-Initial and Periodic Sampling and Testing Requirements WastheexteededwetgassampleusedintheGlyCalcmodel/Process model site-specific and collected within a year of - - application submittal? ))-7,046-0,W))'See Section 08 for explanation.NO initial sampling since the wurce has been sampling and will continue annual sampling. If no,the pernit will contain an"Initial Compliance"testing requirement to demonstrate compliance with emission limits Does the con%any request a control device efficiency greater than 95%fore 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? - No -If yes,the peanit will contain an"Initial Compliance"stack testing requirement AND the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer based an the - O&M plan are application.Once a stack test Is approved by the division,the minimum combustion chamber temperature will be based on the most recent stack test results. is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F? If yes,the permit will contain an"Initial Compliance"testing requirement AND a permit condition specfying the minimum combustion chamber temperature for the thermal oxidizer based on the O&M plan and application.Once a stickiest is approved by the division,the minimum combustion chamber temperature will be based on the most recent stack test results. Section 08-Technical Analysis Notes OCP Is requesting to update parameters M the Glycalc model;refer to Section 04 fore description of the basis for the Glycalc model and changes from the previous permit issuance,DCP will he requiredtomonitorandrecord Inletgastemper tore and pressure and flash tank temperature and pressure and use the actual average monthly values in the model for actual emissions soft is acceptable to alter the model inputs to estibllsh permit limits. DCP is also requesting to increase the gas throughput from 130 MMscfd to 135 MMscfd but decrease the glycol recirculation ratefrom 40gpmto 25 gpm.These changes ultimately reduce the controlled VOC limit from 46:5tpy to 24,4 spy, DCP is using the same inlet wet gas composition a previously used in the last permit issuance.This sampleisn't site specified and was collected more than a year prior to the application,However,DCP is applyinga10%buffer to. count for variation.Also,.DCP H using this sample because it believes its conservative.Further,DCP Will be required to sample the gas annually and to use the most recent sample in the actual emissions calculations..Asa. result,the operators estimate of emissions is likely conservative and therefore acceptable for permitting purposes.- DCP included methanol emissions from the dehydrator.V yCaalc does not Include methanol so DCP included the mail%of alcohols present In the referenced gas analysis with the n-Hexane mole%specified in the GINCalc simulation.The n-Hexane emission rates predicted by the ulyCalcsimulation bre then multiplied by the ratio of the Inlet alcohol moleh concentration to the inlet n-Hexan mole%concentration Typceliy,the weght.%values from the inlet g mlton would be used in the ratio to determine emissions.However,the mole if values provide a conservative estimate of emissions and are acceptable for permitting purposes.Thesmulaton used to estimate methanol e sons is ru separately from the simulation used to demonstrate compliance With VOC and other HAP emissions The emissions from the still vent are routed to a rond ser.prior to being routed to the enclosed flare.However,the operators not taking credit for any control achieved by the condenser,'Nus is demonstrated in the calculations by using the"uncontrolled regenerate s stream from the GlyCale model to calculate uncontrolled emissions and using a 95%control associated with the flare to calculate controlled emissions As a result, neither the permit nor the 0&M plan will seta maximum outlet condenser temperature.However,the operator is taking account for the ondenser in the combustion calculations in order to calculate stilt-vent combustion emissions.Tie operator used the compesition and throughput associated with the"Condenser Vent Stream"in the GlyCaicsmulation to estimate waste gas combustion emissions.While the perator is nut taking credit for the condenser ontiol device,the use of the condenser vent stream to calculate still vent combustion emissions is acceptable as it is likelya better representation of actual emissions.As a result,the permit will requirethe operator to monitor the condenser outlet temperature for usein the monthly GlyCaic simulation DCP estimated combustion emissions from waste gas and pilot light Pilot light emissions are based on a constant pilot fuel flow rate of 65 scf/hr.DCP will estimate actual waste gas combustion emissions by using the condenser vent stream and flash tank off gas stream flows in the monthlyGlyCalcsimulations. With this application,DCP is now requesting to account for assist fuel ate eoteof2,000scf/hr.The operator expressed that assist gas:was necessary for the enclosed combustor be.use the flow rate of gas gong.the enclosed. flare is notenaugh for proper air to fuel ratio needed for complete combustion to avoidsmoking at the enclosed flare DCP also stated the supplemental fuel rate of 2,000.icf/hr is an engineering estimated calculated by DCP plus a 25%buffer.DCP confirmed a supplemental fuet meter is currently installed so the permit will require flow monitoring to demonstrate compliance, Thecalcuiatlan n&VOC and HAP emissions associated with the combustion of assist gas and pilot light fuel is based on a site-specific fuel gas sample obtained on September 12,2015.in conjunction with the EPA Emission Inventory Irryrovement Program Publcation:Volume II,Chapter 10-Displacement Equation(10A-3).This information is used to establish lb/MMscf emission factors.The permit will require the operators obtain an annual sample of fuel gas in order to demonstrate ongoing compliance with the emission factors established through this analysis.In order to calculate actual HOC and HAP emissions,the emission factors estahlshed through this analysis are multiplied by the actual assist gas and pilot light fuel use.These emissions are added to the HOC&.HAP emissions calculated through the monthly GlyCelc simulations inorder to determine total VOC and HAP emissions.Itshould be noted that only the controlled emission factors are used to estimate HOC and HAP emissions associated with combustion of assist gas and pilot light fuel.This is due to the fact that-he fuel gas(i.e.assist and pilot light)is only combusted when the combustion'device 7 operational There Is no scenario In which fuel gas invented to atmosphere.In the event the combustion devices not operas oval the fuel gas flow is shut down. The controlled VOC and bAIP emissions associatedwth combustion of assist gas and pilot fuel were added to both the uncontrolled and controlled columns shave,. :_.According tothe operator,the heat content of the waste g sstreams flash tank and still vent waste gas)will be calculated based on the monthly Glycalc run.By calculating the heat value each month,raiser than bulking the heat value used for permitting Into the emission factor,the operator will be able to determine actual emissions more accurately..Three separate tables associated with the combustion processes(flash tardu controlled by ECD, still vent controlled by ECO,&Assist/pilot fuel combustion)ore contained inthe notes to permit holder to clearly demonstrate the methods used to calculate emissons.The notes under each table clearly indicatehow the heat content of the still vent andflashtank waste gas streams will be calculated one monthly basis and used along with the calculated flow rate and monitored hours of operation to determine the combustionem ssions.: Under the existing permit,the dehy was allowed 0%control device downtimeto vent the still vent to atmosphere.With this application,DCP originally requested to decrease the downtime to 2%and then to 1%.(In the original application rated 0/23/2019,DCP requested 2%downtime.However,the total facility VOC emissions were greater than 50 toy.On1/22/2020,DCP requested to reduce the downtime to1%.)I notified DCP'on 3/28/2019 that since the dehy Is subject to MACE HH requirements,it could not have any control device downtime.MACT HH control requirements apply at all times.DCP stated the dehy automatically shuts down when the flare goes off line,. It's unclear then why downtime was needed but the permit will be modified to remove any downtime allowance.The permit will continue to allow 5%downtime of the VRU on the flash tank and route the flash tank emissions to flare during to VRU downtime. This dehydration unit is equipped with a 3.0 MMBt/hrreboler.Since this reboiler has a design rate less than 5 MMBtu/hr,it is APEN exempt per Colorado Regulation 3 Part ASection 11.0th, Based on actual benzene emissions reported on the APEN(dated 08/23/2019),the operator meets the area sourcebenzene exemption of MA CT asked DCP If they will comply with the benzene exemption.DCP stated they would like the flexibility to complywiththe benzene when actual emissions are below the threshold..As a result,the permit will continue to reflect the requirements of MACT HH.for this source when actualemissions of benzene are below 1984.2 lb/year(MACE Ha Benzene Exemption)and when actual emissions of benzene are greater than 1984.21b/year.This structure helps to Inform the operator and inspector of lie potential MACTHH requirements for this source that will be based on the recorded actual average benzene emissions. - - This regulatory flexibility impacts compliance with state requirements,Asindicated in the regulatory analys sfor this source,the glycol dehydration unit is subject to Regulation?Section Xll H..The unit is not subject to requirements under Reg 7 Section XVII.D because section foilO.S.exemptsdehys subject toe MACTstandardfrom the state rrequirements.Since DCP is requesting the flexibility to meet the benzene exemption when possible, the permit ail require compliance with Reg 7,Section XVI 1.D when the dehy is meeting the MACT HH benzene exemption. The actual emissions reported on the APEN do not match with the actual emissions listed in the table in Section 05 above This is due to the fact that the operators required to calculate actual emissions using e simulation on a monthly basis tether than through the use of emissions factors.As a result,I do not have all the calculations used to estimate actual emissons.Due to this,the actual emissions for this source should be referenced on the most recent APEmsubmitted on 06/23/2019. The Nov andCO emissons associated with the combustion of pilot fuel and assist gas are based on a heat content of 999 Htu/scf.While the value does not match with the heat content calculated on thefuel gas analysis (1087.4 Btu/scf),the operator will have to use the measured value for actual emissions calculations.DCP clarified that the fuel gas sample from asmlar site was used since nospecated fuel gas sample was available for this site. This spectated fuel gas sample was then used to estimate VOC and HAP.however,DCP suggestthat the fuel gas heat content used for the turbine calculations is more representative of the expected heat content of fuelgasat this facility. On March 1%2020,DCP provided revised emission calculations for the debate increase the requested throughput from 135 MMscf/dto140 MMscf/d.All other parameters remained asdiscussed above.DCP also provideda recent site-specific fuel analysis sampled 3/5/2020 at Godfrey Bottoms to estimate the composition for supplemental fuel for the dehy.Thus,the combustion emissions were adjusted based on the revised waste gas flows(the flash tankflow was the same in both runs but the stream composition changed)and composition and updating the supplemental fuel composition based on the more recent fuel gas sample This fuel gas sample resulted in a higher HOC weight%(now at 6.6 ACS instead of5.5 wt46)so this sample Is more conservative. Section 09-Inventory SCC Coding and Emission Factors - - Uncontrolled AIRSPointO Process II SCC Code - Pollutant Emissions Factor Control% Units 005 01 ��"+ PM30 0,005 0,0 b/MMscf PM2.5 0,005 0.0 b/MMscf SOx 0.000 - 0.0 b/MMscf - NOx - 0,049 _ 0.0 b/MMscf VOC 24.5 96,9 b/MMsef CO 0.220 0.0 b/MMscf Benzene 1979 95.1 b/MMscf Toluene 1,835 951 b/MMscf' Ethylbenzene 0,053 95.0 b/MMscf Xylene' 0.546 95.0 b/MMscf. n-Hexane 0.413 96.6 b/MMscf Glycol Dehydrator Emissions Inventory 224 TMP 0.003 96.1 Ib/MMs<f Dehydrator Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B-OPEN and Permit Requirements Source Is in the Non-AttaInment Area ATTAINMENT • 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2TPy(Regulation 3,Part A,Section II.D.1.a)? 2. Are total faci6tyuncontrolled VOC emissions greaterthan 5 TPY,NOx greater than 10TPY or CO emissions greater than 10TPY(Regulation 3,Part B,Section 11.0.3)? (You have indicated that source is in the Non-Attainment Area NON-ATTAINMENT 1. Are uncontrotled.etnissions from any criteria pollutants from this individual source greater than 1TPY(Regulation 3,Part A,Section ll.D.S.a)7 2, Are total facility uncontrolled VOC emissions from the greater than 2TPY,NOx greater than 5 TPY or CO emissions greater than 1OTPY(Regulation 3,Part B,Section 11.0.2)? (Source requires a permit Colorado Regulation 7,Section 511.6 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?,Section Xll.H.1 and 2)7 Yes 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation',natural gas compressor station,natural gas drip station or gas-processing plant(Reg 7 Section Yes 3. Is the turn of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy(Reg 7,Section XII.H.3.6)? 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 subject to Regulation 7,Section Xll.11 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: Yes a.Afacility that processes,upgrades or stores hydrocarbon liquids'(63.760(a((2((;OR Afacility that processes,upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end b.user'(63.760(x)(3))7 2. Is the dehydrator located at a facility that is a major source for HAPs? 'Go to MACT lie Area Source Requirement section to determine MAR HH applicability 40 CFR,Part 63,Subpart MAR HH,011 and Gas Production Facilities Area Source Requirements • 1. Is the dehydrator a triethylene glycol(TES)dehydration unit(63.760(6)(2))7 Yes Exemptions 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747MMscf per day(63.764(e((1)(I)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(63.764(e((1)(ii)? 3. Is the unit located inside of a UA plus offset and UC boundary area? achy is subject to area source MALT HH-Control requirements in 63.765 per 63.7641d)(11 5.bpart A,General provisions per§63.764(a)Table 2 §63.765-Emissions Control Standards §63.773.-Monitoring Standards §63.774-Recordkeeping §63.775-Reporting • • Major Source Requirements Does the facility have a facility-wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility-wide actual annual average hydrocarbon liquid throughput less than 249.7 1. bbl/d(63.760(e)(2))? Small or Large Dehy Determination 2a. Isthe actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day 163,761)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr(63.761)7 Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23,2011(63.760(b)(1)(1(s)and(C)? 4. For this small dehy,is a control device required to meet the BM(emission limit given by the applicable equation? Ina have.Indicated that this facility is hot subject to Major Source requirements of MACT HH. Subpart A,General provisions per§63.764(a)Table 2 §63.765-Emissions Control Standards §63.773—Monitoring §63.774-Record kee ping ' §63.775-Reporting 40 CFR.Part 63,Subpart MAR HHH,Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source(63.1270(1))? Smaller Large Dehy Determination 2a. Isthe 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)33.1270)b)(2))? Small Dehy Requirements 3. Did construction of the.small glycol dehydration unit commence on or before August 23,2011(63.1270(6)(2)and(3))? 4. Far this small dehy,is control device required to meet the BTEX emission limit given by the applicable equation? IVou have indicated that this facility is not subject to MAC?HHH. Subpart A,General provisions per§63.1274(a)Table 2 463.1275-Emissions Control Standards §53.1281-Control Equipment Standards §63.1253-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 MAC?HH or HHH(Regulation 7,Section XVII.B.5)? Yes 2. Is this dehydrator located at transmission/storage facility? No 3. Is this dehydrator located at en oil and gas exploration and production operation,natural gas compressor station or gas processing plant(Reg 7,Section XVII.D.3)? Yes 4. Was this glycol natural gas dehydratarconstructed before May 1,2015(Reg 7 Section XVII.D.4,6)? If constructed prior to May 1,2015,are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 6 tans per year VOC or 2tpy VOC?the dehydrator., 4a. is located within 1,320 feet of a building unit or designated outside activity area(Reg 7,Section XVILD.4.h)? leiee 5. If constructed on or after May 1,2015,are uncontrolled actual emiaslonsfrom a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC(Regulation 7,Section XVII.D.4.a)? ,� Dehydrator is not subject to Regulation 7,Section)0111.8,113 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. Isahis glycol natural gas dehydrator controlled by a back-up or alternate combustion device(i.e.,not the primary control device)that is not enclosed? 'The control device for this dehydrator Is not subject to Regulation 7,SectionXVil.B.2.e Section XVII.B.2.e—Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This document Is not a rule or regulation,and the analysis it contains may not apply to a particular situation based upon the individual facts end 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 gay conflict between the language of this document and the language of the Clean Air Act„its implementing regulations,and Air Qualify 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 ofthe'Clean Air Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself. Turbine Emissions Inventory IFaa Section el-Administrative County pant PU. 6mt Section 02-Equipment Description OCails (1)Sp n( 0),rased at 65.63 gtu/hr ileac Input(UM • o0,On na 60.fiocsvisower 661.Tnrs J Ast l mpJbi- O ytG .Vd;., Ea...Control 0es0ce Equipped ufisis combustion system for snininsis,ernircioisr or dirroiicruitclpilig4:1400,ftp, Description: m mnstl and not an ado of deus Request.Overall vo5&HAP Control Efficiency. SotoxOr Is suns.. Integral control device. Section -Processing Rate Information for Emissions ESIllnateS Meat n p at emt on — BNN based on spec s sheet tent of waste gas= 94�:gtu/scf based on spec sM1eet Actual Nours of a �.q$ ,,,,Mar Requested Hours of Operation= "' Y�q M1rs/year [ualheat Input rate= 0.00 FOAM per year Requested heat Input rate= 613.]1060 MMM per year Potential m Emit(PTO heat input rate= 611,)]080 MMBTu per year Actual Fuel Consumption= 0.00 MMsf/year Req ested PIA Cowmption= 673.5 MMscf/ear 5]20493163 MMsef/montS Potential to Emit(PTE)Peel Consmptinm= 6 35410 MM./year no 02T ¢;Std 01 5a, Plumber of turbines-tart-up is Time per startevent timlnutes 555630660 5010/1661 Process Turbine N• permemown shutdown events — N Number eve even1656566651 bours/year BEEMOEM n o6Cov:'set - (W/6+MAStn/ 0b/MM61H Pollutant Fatmrmeme (Feel (uel lnpuo) Co umptlon) on34 ppm an670O0 L��'e' , .ea 6n:s ppm permanpraap er.pe<snm MEEPEEMZUE=MIIIIII=EMEMMUNIVAtrii4Y4P04141 lizamimeizemminnlin=glimmuimMEMENI.,.'",t0yr.,1,13044.0.101 PinSeo 02'Turbine Ptcrt.up Events Emission faders Turbine Uncontrolled tin e.. 70111 67 lie/event) MPH 661130n Factor 56606 (start-.P=went) (srznwP my WIC 1a06 0&000 70/10 by CO 77065,21.020. /7 rt7. Emission Fa.<101, Turbine Pollute. Omen.. tin 15/1ea fibiessentil 30161011 Factor source (start-up event) (Start-up event{ t/ 116131 C/users/0600,1,/0 0060ts0Pacpa36410597017W50470.774 Turbine Emissions Inventory Section 05 Fmi5mn Invent., Pmrass0l:steadystatedpae11dv. _ Paten.",Emit Monthly amts Caged Pollutants ntolledai Em ontrvlldPeOn glad uncontroued 1..1,r) (tons/vealIvn/mad hansryearl (too.ayead fibs/m..1 M VOC 0.68 0.5, 1s 2.1909070 PNI2.5 2.02 0.00 0.00 2.6136 2.02 sea SO. MOO 0.0I 1039 1. 177 NOvv.95 0.00 0.00 2.7.3333 17.36 3030 co 10.590.w 10.5112 19.52 0.00 Potential m ctual Emission Segues.Permit Urn. Hazardous Air Pollutants Uncontrolled wnhq. Controlled Iron. Uncontrolled Controlled 133555Aaad Um... /0�onhead 1r Uncontrolled I3ohmr/ Mishear] nthear) Formaldehyde 0100-Mat 0.0002500 72901 950 Acetaldehyde 9000E.00 0.01900 1 727.2 1.723902 Amaiem 0.000E. 1367CO3 1957.3 a a Benzene 9670.3 0.000.00 0.000EMa 3.6213093 3.8700.03 1,3-Butadlene 1.3.153.04 0.00.900 0,0003401 2315E. 13.E. Thylbenaene 20 Toluene 3.976.7 0.006M00 3.376.2 3976.1 80 80 PAH 6.729E. 0.000390 0.0000E+0a %Meng 1917E. 0.000 0 0.0000500 3.957302 1.957.2 39 39 ;03aaeSs02ITuI01h0511#0p 100001.' . Potential to Emit Actual Emissions Requested Perms Umlt ulteda Pollutant Uncontrolled Umontfolled Contrdd Controlled Imnsbead (tons/year) Mons/rad (tonhzarl I(gnS/vearl Wes eta am 0.00 eta aeu NOx 095 55/51/156 time , Potentially e Actual EmissionsRequested Permit Umit [whree Pollutant Uncontrolled Uncontrolled trolled Controlled (tons/year] I s/year] (Mosh001/ (t ns/ye51/ (1.SM/ VOC 0.00 0.00 9.d0 0.90 NOM 0.45 0.00 0.00 OAS 0.05 co 3.10 0.00 0.00 3.10 210 • • 010a4.6�egu/atom 515,55 acv Angles Section M Tlu 1ded in paragraphs 2ough 6 bemw,no owner or1peatorof asource shall allow w ause the emisdanlnto the atmosphereofanyaz pollwnt whirl,is M vim of 2.cmaachy.Thisstandad is based on 14 ronsmNyeopamryr adingstaken M19 rorond maihf7r six minutro.The approved torertn meThd for em cans measurement Is EPA Iget.d 9099 CFR,Part 60, AppendhaMluly.lg9p)In an...Ions of Section ILA and O of this regulation. Section No multer or or shall cause or hero. he emNted into the atmosphere from any. homing equipment,particulate • er Id thexisd which a ithe following: M.A.1.h.Fm fuel burning equipment with designed heat Inputs greater..lxlos BTU per hour,but less than or equal to 500x10°BTU per hour,the following equation will be used to determine the allowable partlnlate emleslan limitation. PEm.5(Ni`a Where: Regulation PE=Particulate Emission In Pounds per mill.BTU heat input 99 Fuel Input in Mlllfon BTU per Foul. ▪ turhine.sdesign heatmpm rate of6B.03MMSv/nr.As a result,The turbine Is sublet to this pardon afore regulation.using The...egoaaon.The allowable PaMwiate emission Ii0haaon 10.1638Ib/MMgtu.The AP-42 emlaion factor of 66x10''Ib/MMBM used in thaalcuM.ns above Is Below.particulate em.on threshold. 0165775 of sulfur dioxide shall net emit our route.he emitted1,5011551 dioxide In excess of Me following process.specinc fnitatiods.vat input rates shall he the manufacturer's guaranteed maximum heat input rates./ • .1.c]..mbustIon Tod..MTha heat input al less than 250 million BTU per hour:o.a pounds of sulfur dioxide per million BTU of heat Input.. Th.turbine has a design Mat 1Put am of 60.33MM5ex/hn As a resuh,the turbine Is sub/era to this pardon of the regulation...AP. 42 emlssioo factor of3.4x10'16/MMeu used M The olalations above is below This sulfur dioxde emission threshold. gee aaon2 Section LA-No person,wherever located,shall cause or allow Them..of odorous air contaminants from urge.e source a ssch to raultin detectable odors Them..which are measured In armorollo.Nn5 mice For areas used predwni:antlyforrevdemial or commercial Porpo..aMarin Hod.are detected after Thedora57..has hmn diluted vdTh seven(7)or moreedumrod..M.Pl, Part A-APSliftectuirements aria pollutants,Air Pollutant Emission Notices are required for:each InIMdual emission point in a talnment area with um ontrolled actual emissions of one ton per year or mom dam individual alter.pollutant(pollutant are not summed)for Regulation which the arm is nonattalnment. Applicant M required to Olean Ai.since emissions exceed 1 ton per year NO.Part 3— ...lamPermi...lamAppliami pined to obtain a permit since uncontrolled NOx emissions from this fealty are greater than the 2.0 TPT Threshold(Peg.3, Part e,SeRivn Il.0.xa1 Part 555.On lied 505/25/2 of Performance for New Fuel Burning Equipment soh/mstandamt Mr PardcoUre ramen On andafter The dateanwhich the required 7205,ma:ce test Is competed,no owner or operator .o.pr.:dons of this regulation may discharge,or muse the discharge into the atmosphere of am particulate matter whld0 Is it.C.2.Varied homing equipment generating ac Than rote mill In but less Than 250 million Btu per hour hot input,the following equation oslnVSh used to detenina The allowable particulate emmen Omiation. Where: PE is the allowable particlate emission In pounds per mlllion B.hmt input. Fl is the Mellon.In million Btu per hour. If or mom unroconn.to am open.,the maximum allowable emission ate shall he the sum or the...dual emission rates. II.G3.Greamr Than 20 percent opacro, 0 standard mrsugur olodde:on and after the doe on which The required performance test is completed,no owner of operator sublet to the provisions of this regulation may discharge,or rouse the discharge into the atmospbee sulfur elniaeln roc.of: M.A.5omces with a Mat Input of less than 250 Milton Btu..ur:08.Ihs.501/mMlbn Stu h turhinehas a da¢n heat Input rate of 69.03 MMBN/Iv and v.be cansmoed after01/30/79.As a resuh,Ne turbine Is sutivt Poeulation6 Th to This w - Using 9 P SSSlb/MM0to. llteAp42enissin factorf 6.6x10'IbpM/MMBtu used 0 the calculations 855085 below This particulate mission Threshold. 030175nalb1The0wu emission factor 013.4500'lb508/MM2.used in The oioladanz above Is below Mss sulfurdmdde emission Threshold of 0.8 lb 5ax/MMgto. NSPS GCThe provision of This subpart are appllable to the following affected facllMes:Ail stationary gas turbines with a heat input at peak mach equal to or greater Than 102 Blgalomn(10 million litu]per hour,based an the loaves heating value of'The fuel fired. The heat Input at peak gad for this turbine(point 000]Is 59%3MMaw/hrwhlrh Is greater Than C0 MMeu/hr.As a result,the turbine would be ct thIS N5P5i1oviever,The turbine hobo subject lo N5P50005 pee applicability citscu .sslon below).According NSP51.33 stationary combusaonu0mm regulated under This subpart are exempt from to requirement of subpart GG of this52050at 520159 team generators and ductbumen regulated under this subpart are exempted from the requirements or subverts 0i cab,and Oc of This pare Marmot,ram GG does notapply ro painc0o9. NSPS 33.:Ifyou are the owner or operatorwith a heal input at peak load equal to or greater than 10.7 es(n atul per on the higher her] mineof the fuel',which commenced construction,modification,or reco.rucdon after February 1e,2005,your turbine is subject this subpart. Thlsturbine/Pomt 5091 has a heat input a1 peak lo.of65.03 MMO./M/15MMeta/hrl and will commence construction after February 1M 2005.Asa result N5P5 NEES applies to thlz turbine.The applicable requirements have been included In the permit. Seaton 3.72.6 Camhnaon Process Aafustmnt Amiga 50.Except as provided in Section 205050,As of 52p,8 ry5,x057,theserfmn 2551 appnesto hollers,duct homers,process her] urMnes,and stations reciprocating internal combustion uncontrolled aural emltbns fiegidution of NOx eq.]to orgreater than five(Sl tans per year that misted at major sources of Noma oflune 3,2016 The torhfnesm.red under ts permitted with NO2 emission greater Than 5 tpm however,The turbine will be Th ailed after rvuh,[he turbine Is not subject to th is portion or the regulation.Additionally,the facility was tint chasffied a a l aimso%Qa Naxos oflune3.2016. 12 of 31 C\Umz/dmoney'0awnenn/Paciage414551/11WE0400.0P9 Turbine Emissions Inventory MALT VW, You am subpau Ms subpart If you own or operate a stedonanomhusden turbine looted n. map, source of HAP MAR This turbine [Point 0091 Is not subject to MAUI/WV heause h is looted at an area source el Nee engss.ns. 13 0,31 c \used\wmonM9oummu\ram9e ues9T\IIwebn9.as Turbine Emissions Inventory �^A 3' rya b B t / ,yTIc,I � ppil a —S I b}otax°^ at`f eg,,,osti f5g 2,hb fr fB h / - - - - d 2 f �qd 1 n kit`m! 4io ( 1 M1h F( 1 t"db B P I. ,,„„d„,,,,,,,..,,„,„,—,-,,,,,,,,,„m,„,,,,.,,,,,,,,„.— ,. P 2 A Yd.,.‘ri�,,� S ' g t Wf'1 I t h Rexpll Iv n s t. t ₹,f (;a P b a / sgnr rEere P 2 �na ,„ '1 5rs1 - a me .ttsat5 a w� manure bin n sswr the peer al tN '"Sst a ote ttacta ton a,tat e a nattans, p a.ot woba aoretaa r st �tnanamutdoy7 na.<wa.,td p as tom ormo ee,e',,"i aowne'eM1mo mro'atxst v n an;m:.] dS Se', ra na.nden¢ ptlpa snot aaaatar p alom,;� ::no.r namr,�e:a nnm aFo[� h e': pIi'r:: r2tzwe: eowmtd.boi am[oprm ooatanvm� :a:epaare .no,a.tept >en t'eb�brt p/ ow�aT t:ont ;....'''';'..g..---e � :I i t n. / h a a o h u,,[9 k aontne h myur 1�gp g�a �. i n itl' e�tre t ,; d !"$chh�,8'w& JSho alU ' h' € r ear p 1 to tin � r a 9 •�• I t 1' vt uomows � wmme N5 a .. a evoav `:',fig a FAI • � .',,,-A-. } ,,. fit .. e her �gC '� 'Y` ��`? ;action¢e-mwntop/5a coding ana Emra�mna raeors _ _ - . Uncontrolled Emissions u -_ 009 01 — � b/MMBtu,no 560001 b/MMOtu Inert b/MMetu Input b/MMetu volt M.N.Input - - Comm... 10.01 b/MUSS lnpm etaldehyde 4.09¢4 b/MM b/MMBtaInput b/MMetu Input 1,9-9Wtlene WNW.Input Ethylhenaene h/MM9tu Input - -- -- Toluene 6/.4.0VP. b/MM %ylene 6. 0 b/MM9tu Input 02 ...VelmaN. '11° b/start CO AB 30 b/start-upeven[ 'a b/snutdaun event - - - W 6L¢o 0 1o/shutdown event 144/31 C:\Users\ctlmaney\Documents/054Ss 414593t11WE14]9k34 • . Turbine Emissions Inventory - • 1,‘,,,,,,,,,,,,,, s x'u son r. Pont . .ry 91 h)R`-0,4 i 7 1 (txv) ['eta,.Emissions Unit to t ,;+un erpxnn ''° °^ 9,439.. ,IxPl rn msonm oer'c Pp tF,:'al4-.. .44,4 ustloq: oesvlPt an, n I IE 2 1 ,4 EfR e• ency.:ed al x Control SL yg 5 ox Isconsd g control deuce Se..03-Proves,.Rate Information...MOM Estimates - _ • Process 01:Steady5tate Heat Input p on Rate. 7,4_,..49,S13 MINetuilar based on saes sheet Hear content°, etu/td based on spec meet xtPa Hours orooe 'k�* Requested ashra/vaar rayon q5�' ed Hours of Operation E, ,. jQ2hrs/year Actual Feat input rate= 1.1B711 per year . . Requested beat Input rate= 691.710.60 MIABIll per year Potential to Emit EPrEl Feat input rate= 691,.10.00 MM P y . • Actual Fuel Consumption= 0,0 MMscrhear • . . • . .. . Requested Fuel Consumption= 630 IVIA4scf/year 5)10493103 MMsef/m0ntf - •• Po.enhal to Emit(PIT)Fuel eansmptian= m.-r/var •Number of turbine sra-on` events vwy`3r,R 36006600 flours/Year . • N eshu "�+&kLILa • cnts . .. ,rne per shutdownett •it'a;En... 16.6696666]hours/year - - seal0n m-6mtssanz Faaorsa Meth.doo a Isston Factors rb Uncontrolled uncontrolled (Ib/Mbwtul Ilb/M Mscfl MN.. Factor Source (Fuel (Fuel lroutl Consurnpeoni 66o6L31f . ased...PP.per manuhFMFEF spec sheet CO 00Ea2 l y ..�- on 25 ppm per manutaaurerspec'beet Formal.•e ]30Ea4'.o Ji AcendehF. 4...' 3Ea1 0 -.. • PAH',Elena bolas. .Ji € - - . Pollutant Uncontrolled Uncontrolled ea Emission Factorsoume - - - lsoevent) (Stsevent) edQ CO a.60.r 18000tb. 'Tro ers rheN.' ErnIsspan Factors Turbine ncontrolled Pollukant c ed • ite/0000061 uo llh/M1rl Emission Fodor sours . (Startup evene) Isart-up event] . o b Co .61,M 372-000 • • • • 1500 e\Users\cdmoney\Documents\Package 414597\11.14J9,[P4 Turbine Emissions Inventory section OS -Emissions Inventm,l Presso1: stew,y 5M.Opeedon Criteria Pollutants Potential ID Uncontrolled n Ifon:Marl Actual Emissions Controlled ItmsAmalrd icons/year) Requested Pent. Umits uncontrolled Controlled Irons/year) Imnshearl Monthly lime Uncontrolled Ps/month) idoc PP.410 Pli32.5 50a NOr COProential 0.64 0.00 0.00 0.6423 109 0.00 0.00 2.0186 102 343 2.02 0.00 0.00 000 0.0 10399 1.77 3710 0.00 170559 17.56 3050 Hazardous Air Pollutants to Emit Uncontrolled Itmss/vom) Aclual Uncontrolled immAwarl missions Controlled (tons/year) Requroted Permit limits Uncontrolled Controlled (terse/year) Pons/year) Requested Permit Omits Uncontrolled 11mMad Obs/searl Formaldehyde 22Ee1 2.172E-01 434 434 Acetaldehyde 12214-02 0.0004400 0000E-00 1.223E-02 1.223E-02 24 24 AwmIn 1.957203 000.400 0.0004400 19374.03 1.957E-03 Benzene 3.670f 03 0.000140 0.00.400 3070E-03 3.670443 1.9 -Butadiene 1.3150.04 0.000E. 0.0000400 2.313E.04 1.3153.64 Ethylbemene 9.737E-03 0.000.00 0.000003 9.797E-03 9.707E433 20 Tollient 3.976E-02 0.0004400 0.0.10.02 3.576002 3.176002 SO SO PAM 3.7234.4 0.00.00 0.0004400 6.7290.04 6.7294414 Xe... 03 50005.300.0001400.0.00 0.0001400.1.15]E 0-00 1.957002 39 39 Proems OatTobbia SIMPupEMMs Criteria Pollutants uncontrolled ms/swr Actual 1l ons/year) misslons Controlled rollea (tom/year) Requested Permit limits Uncontrolled Controlled (tons/yeari (tons/marl VOC 000 0.00 0.00 0.40 0.20 NOs COO. 0.00 0.00 I 025 0.1 .w 0.00 o.op coca e.eo Process 06 Turbine Shutdowns Events uteda Pollutants Potential to Emit Uncontrolled IfomA..) Actual Emissions Controlled (tons/marUncontrolled itoro/yearl Requested Remit limits d Controlled (IonsAearl(tom/wart OM 0.00 0.00 1140 0.40 NOir 0.0 0.06 0.00 005 0 05 Rervlatlon]PE Seaton -Emept . pr.idw, 5 paragraphs through 6 below, no owner or orator of a source shall animal. cause the 3,512000 Into the atmosphere of envoi, pollutant which AM exams 002044 opacity. Tips standard is based on le cwnautise opacity readings taken at l5- second linerrols far sh approved reference test method for visible emission] measurement b EPA Method 9 (en CPR, Part 60. Appmrt[ auuN.199111 mail minutes. subsections 04ns of section A and 9 of togs regulation. Section III.A. No owner or for shall rouse or permit to be emitted Into the atmosphere from any fuel -homing equipment particulatewhich ceM the following matter in the flue gases III.A.134. For fuel burning with de9gned heat Inputs greater than 1410' BTU per hour. MA less than or equal to 500410° BTU per hour, the fallowing equation PObe usw, to determine the allowable particulate emission llmlla Iron. SIEII"a - Naito,. Emission in Pounds per million lino hat input has a design heat Input ram of 3023 4.3.43awihr. Asa result, the turbine b subject 0 fhb potion of Me regubt6..Using the abode equation. the abwable 9.30 slab emission limitation Is 0.1352 6MM9N. TM AM43 emission faces 00 6btl0 s 0/1414397 used In Mealomaons abode Is below lib pooch. emission threshold. Section 54.3.4. flew murices of our dlplm shall not emit or cause 0 be emitted sulfur dioxide In excess of the mllwing proms -specific Ilmd bons Mat Input rates shall per the manufacture s guaranteed maximum heat Input rates.) .m7lbrambustbn Turbines with a heat input of less than 250 minion IOU per hour: 0.8 pounds of sulfur Moelde per million BTU of heat Input. This turbine has a design heat Moue rate 0169.83 MMBO/b. As a result, the turbine Is subject to tub portion of the agulatMe. The AP - 42 emiales factor of 1.12,10. 0/yx.0. Mw, 6 th.0lrvbdo0.50 . b below MN sulfur di ado emission threshold. Regummnl Section a -Nn person, wherever located. shall muse orallow the emission of Moro. al1anamwnte horn arysingle source su. as to nu. in delectable odors which are measured. maxis of the following limits: For me.aw, predominantly for redenml ornemrnerdal purposes N is. MPon If own are dewed after the odorous air has been dilutei with seven (7) or more volumes of odor free air. MguWon3 Part APEB Requirements Criteria Poltroon. For criteria pollutants. Air Pollutant Emission Notion are required for each individual emission point ma inn -attainment are -AM. uncontrolled actual nmentemissions alone ton per year m more of any Inmwldel [Melia pollutant (pollutants are not summed, M whim Mewed nodal is . Me n ANN emBaler exceed It P m 1101. — rwNonApplicant Exemptions Part 3 Appllcant wired 0 obtain a permit since uncontrolled Nona emissions from tbs feat, are greater than the SA TIN threshold (Reg. 3, Part Et Sedpn n.0.aal "U.... Pert B Sect. Ili Standards of Performance for New fuel Boning Equipment MC Standard for Pammb. Mauer: en and after the dare m winch the requi,edperformance trot Nmmpnm, no 03mer or 0007100 subject to tie pro Mons of the regulation may discharge, or rouse the 20d oo.e into lie atmosphere of any pats° late matter whom Is: laming350 millionmillion Btu per hoer heat input. the following equations. tamed to demon. the allowable particulate etr.don limitation. PE00.51900.26 PE sthe elk:wattls1)0 fuel Mput IIn million Btu perparticulate lon in pounds ho25. per million Stu heat input. El II.C3.Oreaer than 20percent opadry. p'f emaumwm.11nwadewmamon.w0el1 ere 0esum of0emrmmmmdwal.mamnn non.. 11.0 Ronda. for Sulfur Mauldin On and ahem. date on worm lie required performance test Is cormplew,, no owner or openta sugw to the provisions of this regulation may discharge, m muse the discharge into the atmosphere sulfur dioxide in ewes of: ii.via. Swarms with a 'walloping( less than 250 million Btu per lour. OS lbs. 502/mildon g0 Tits 0rbae has a design heat Input rata of 69.83 33336uM and ma be constructed Mir 01/30/29. As a mufti tie turbine ismb)w to Mk portion of. regulation. Wag ...a equationtt1.C2m , lie aaobk 9004M6Mg6b6533300 01 particulate na.165g 1. Ile AP -13 emission faMor 6.10'0 PM/MMetu used in theulw*Oons above le below015 pallorlate emiwro00r.hed. Mdimnalla, the AP4I3 smlrsbn factor of 3..100' 6 501/hlugw used in the olcubtm.. above is below lib sulfur db0e emission thmh0ldd 5O8/MMBm. N5P5 GA: The provisions of this subpart are appilroble to the ollowing af rotted turbines with a Peak load equal 0 o.mer than 10.7gigolo°. 110 mIIllonfMul pull., based ontitthhe lower Al stationary gas of the fuel fired.tmnP at 00 rot Input at peak low, lard. turbine (m7.7009)3% 63.B3MM mu /hr sub. Is greater than 10 PRAWN/hr. As a result, the tuAme old he subject to OP MPS; however, the turbine babe subject to MPS WNW (see epplimb3By discussionbebw4 A.0Ning0 Nirs g1o0 gsu..3as(bon ) Sty arnburf Inn turbines regulated under this subpw p an eremIrani the requirements of subpart 66 of Wiped_ pit Nee re0.erysham ...rotors and duct burners regulated under MN Subpa0 me eaempted (000038 equkeme nut el subparts w, oh. * a of pat Asa result. NSP5 66 does not app)0 to point m9. ASPSowner f with a heat Input a peak law d equal to greater than 10.2 ajoules 110 MMeper r hour, based based on the higher heat value of the fuel, which commenced construction, modification, or reamrctmn after February 39.2005, your turbine Is subject to this subpart. This tuAlne (Point 009) has a heat Input at peak load 2069.83 MMBM/hr(313MM3./br) and will commenceanstos0lon after February 1L 3005. As a mutt, NSP5 MOM applies tothb turbine. The applicable requirements have been Included In the permit. Re.uMNalt7 Section nIY.6. Combustion Prue. Ad)u0ment Applleabmry. erupt es prated. In Hetbn 30.4.61.3..As of lama 1,1012, tub YNon 00.0.6. applies m hollers, dud burners, poste. heaters, stationary combustion Orb Fe; and.F7..0 ymep,om.ng 3mraimnburt0nen0lees wish uneenuelkd a aW"alum.. of Nona equal 0.geater Man Ow(5)ans per year Mat eels. at major sources of Ways oflune 32016. greater than S toy; hoa4Mr. Me.rbmewm be Ins0lbd afterresult,m lune 3,2016. Asa the crie snot subject tothis portion of Me reguwron. Addmorsam Me McOWuresmtel.slOed. e The turbine covered under point OM result, the major muree of N00 as of lune 3.1016 2,03870 0)165775 16 of 91 .\Osom momet\omuntenD Pxmge 41,59T110.1e70.va Turbine Emissions Inventory You ore subject so Mk subpart you own or operate asauonary combustion eurbine loured a e major source m HAP MAR Ills turbine ‘Point OW k not subject to anerrvrr because bis looted x an area source or HAP emissions. 170(31 oWsers\eamoney\oosumeneWamee uesslWw[sns.O6 Turbine Emissions Inventory �vfli h: "A"'°. 072",„'"-.":„,, e*a " evil, t aQ a 'ept t i'4n ., a p £5 li :� p pas` ₹.. � 1 P� t =lira r ppl tna*'�e < reYs a ming v a n 1. =n y ea a a" ' � r� r � k a � o fa ly Sl p $ff S d h tM1 :h r 41 h fore b WbPt.Pe d d�6 mllar oa t a ceda oIle �l ,c 045 8flb iv 6 A b /A d 'r-�aa5M✓+��Fk�pN tl tc tl L A Ih< . �� 5 rS'dwkT w �' 6 �f g let rZPL� �e �,o fA tl t t {� - [� d g rt d 5.„„ 4:� �, E 9 d Y'r $d f�gt,Pa,? yd/Y C -. a �""w'. ' "a b�" x. S' y F!Rs sep ea In s 11.1461714""° a e rwaa � amPa�d 00 a �� a w e �� i a + �" 0 ? an t t z a x 04 e „,„1: „,1: dbg d b - 11 h d tl b etl d...e Em�ssm�;d 0,0 bimMfiw input h/MMdtu Nput h/MMfitu input - _ . uacO2 0 h/MMemsoy 2 202.02 input b/MMatu Nput h/MM9m lnpirt 4(000l0Me b/MMetulnput ' aldeM1yde 00ELE M....P. - - b/MMetu lnvu[ b/MMBtu Input 230utn pop b/MMetu Input EtM1ymensene - b/MMetu Input - "0'00 130E 06 b/MMetu Input - - rAH 0 b/MMetu Input - Mv�ene fi.40Fd5� 0 6/MM0tu Input 02 b/start-uv euxn[ hhtarrtZe2ent - 8200 0 b/start-up euxnt 03VOCb/sM1�ntlown event -- - W. 0. a la/shutdown event - - [o fii.➢0 0 h/sM1uetlown vent. 12 02 21 c Users\edmoney\ourumenta\Package 014sev\uwEl<rs.CPA AIRS ID 123-9010-011 Permit 17WE0001.XP Water Through 30,000 bbl/yr Gas Water Rati 0.6 scf/bbl Gas Molar volu 379 scf/mol if this is adjusted for local temp and pressure, it would be 450 scf/mol which would decrease emissions Gas MW 32.21 lb/lb mol VOC 32.56 wt% Benzene 1.0956 wt% Hexane 0.9451 wt% VOC 623 lb/yr Benzene 21 Hexane 18 Working and B 164 lb/yr Total VOC 787 lb/yr 0.393307 tpy DCP had not originally included the produced water tank as part of the Aug 2019 application. The tank was listed in Form 102 with emissions of 3.9 tpy VOC. These two 215 bbl tanks were first identified as APEN-required in the Dec 2016 application. DCP estimated emissions using state default emission factors for produced water and an assumed throughput of 21,000 bbl/yr. In the Dec 2016 application, DCP stated the tanks were APEN-required but categorically permit exempt since the tanks contained less than 1% crude oil. The division removed this categorical permit exemption effective 2/14/2020. Thus, DCP provided emission calculations on 3/19/2020. These calculations are based on a site -specific flash liberation analysis to establish a gas volume produced per bbl of liquid. This sample was collected 3/2/2020 from Godfrey Bottom and resulted in a gas water ratio of 0.6 scf/bbl. At the requested volume of 30,000 bbl/yr, this resulted in 623 lb/yr VOC emissions. DCP also created a mixture in EPA Tanks 4.0.9d to estimate working and breathing emissions so total emissions (F+W+B) are 0.4 tpy. The tank is then APEN- exempt. DCP submitted a notice of cancellation 3/19/2020. The EPA Tanks model submitted 3/19/2020 was based on an incorrect throughput. DCP provided the revised run on 4/6/2020. I also asked DCP about methanol since they have included methanol in the dehy run. DCP stated that they followed the PS Memo 17-01 guidelines for the flash liberation analysis sampling which does not include methanol or mention using a methanol test method. DCP spoke with Alliance about performing methanol testing and they said they have not done it for other clients and are not sure if they could. It's not clear if methanol would be present in the produced water. I set up an EPA Tanks run and added 1% methanol to the mixture. The EPA tanks run resulted in 51b/yr methanol emissions, so the tank would still be APEN-exempt. Hydrocarbon Loadout Emissions Inventory Section 01-Administrative Information Facility Allis ID: 1239010 012 - - County Plant Point Section 02-Equipment Description Details Loading out of condensate from pressurized condensate tanks ba pressurized tank trucks.Loadout occurs via vapor balance and Detailed Emissions Unit Description: emissions are only released to the atmosphere during hose disconnect. Emissions from this source are not controlled. Emission Control Device Description: Is this loadout controlled? No Requested Overall VOC&HAP Control Efficiency%: 0.00 Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Truck Loa clout Capacity _ 7006'gallons/load • Condensate Unloaded +..-. stY`500b "gallons/month _ 714,286.00 bbl/year Loadouts/month 357.143 loadout/month Loadouts/year 4,285.72 loadout/year Secondary Emissions-Combustion Device(s) - MMBTU per year .MMBTU per year a � • >ve.,..s..'•�......fi a,a? sa3aa a_ate ., .. > MMBN per year • Section 04-Emissions Factors&Methodologies Loadout Hose Parameters Liquid Hose Diameter 0.166665667 feet - • VaporHoseDiameter 0.166666667 feet Notes: Liquid Hose Length' 1.0 feet 'Length accounts for length of isolation valve on pressurized hose. Vapor Hose Lenth' 1.0 feet There are two hoses connected to each truck during loadout. Liquid Hose Volume 0.0218 cubic feet ,--"---------------_— -- - _ _ Vapor Hose Volume 0.0218 cubic feet • Tank and Truck Pressure _ Tankandtruckpressure 97 Pig 109.2 psis PV=nRT - - Where:P=pressure in hose at time of disconnect=storage tank pressure(psia) - - V=volume of hoses(cubic feet) n=number of lb-moles of product in hoses R=Universal gas constant=10.73 ft^3'psi/Ibmale/degR T=average loadout temperature=60 7=519.6711 • Vapor Density Liquid Density n 0.000427251 Ibmol SG :0.7396 - - -Density of - - n/V 0.019583724 Ibmol/ft^3 Water .8.33 lb/gallon MW „�„.; t- „_m 116.5 Ib/Ibmol - Liquid Density 6.160868 lb/gallon • Vapor Density - '' 2.281307958 Ib/ft03 -' 46.08329264 Ib/ft^3 Notes: - - - 11.All liquid lines'contain squid products at individual specific gravity. - - 2.All vapor return lines contain products that behave as ideal gases at 60°F and storage tank pressure. - - Uncontrolled VOC Emissions: 213.30 lb/year 1738 lb/month Vapor Emissions mai tpy 0.188420058 total tons per month 4,308.78 lb/year 359.06 lb/month _Liquid Emissions 2:15 tpy To+_=I Emlcn oes 2.2"v .' _ DCP requested Total 2.26 tpy • Component Mass Fraction Source Representative Sample(See Section Benzene 0.854% US for notes) Representative Sample(See Sector Toluene 2.327% US for notes) • Representative Sample(See Section Ethylbenzene 0.277% 08 for notes) Representative Sample(See Section Xylene 1.740% 08 for notes) Representative Sample(See Section n-Hexane 6.595% 08 for notes) _ - Representative Sample(See Section 224 TMP 0.577% :08 for notes). • 20 of 31 - - C:\Users\cdmoney\Documents\Package 414597\11WE1479.CP4 H• ydrocarbon Loadout Emissions Inventory • - Emission Factors - Hydrocarbon Loadout - • - - Uncontrolled Controlled - (Ib/loadout Emission Factor Source • - Pollutant (lb/loadout event) vent) - - -- • (Volume (Volume Loaded) Loaded) -. VOC 1.0552E+00. 1.061-coo 1' xr .r: =i Benzene 9.01E-03 - 0,0090 -` - - Toluene 2,46E-02 0.0246 Ethylbenzene 2.92E-03 0.0029 ' Xylene 1.84E-02 0.0184 $ n-Hexane 6.96E-02 0.0696 t/. '.f 224 IMP 6,09E-03 0.0061 r:"'t $.4..,..,.- ..wl . Control Device Uncontrolled • Uncontrolled Pollutant (lb/MMBtu)- (lb/bbl) Emission Factor Source (Volume - (waste heat combusted) Loaded) PM30 a 0.00E+00 etaPM2,5 ... �' 0.00E+00264 .,- SOx "Y 0.00E+00 NOx oacc.o0 ~ „ CO - - 0.00E+00 - - . Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits. Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tans/year) (tons/year) (tons/year) PM10 0.00 0.00 0.00 0.00 0.00 - .. SOx 0.00 -0.00 0.00 0.00 0.00 - NOx 0-W - ..0.00 .0.00 0.00 0.00 . . VOL .. 2,26 2.26 2,26 2.26 2.26 384 •- - . - Co 0.00 0.00 0,00 0.00 0.00 - - - Potential to Emit Actual Emissions Requested Permit Limits - • .- ' Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled , • , (lbs/year) (lbs/year) (lbs/year) (Ibs/year) (lbs/year) - i - - Benzene 36.60 38,60 38.60 39 39 Toluene 105.23 103.23 105.23 105 105 - - - Ethylhenzene 12.52 12,52 12.52 13 13 - -- - ,- Xylene 78,68 78.68 78.68 79 79 (', n-Hexane 296.24- 298.24 .. 298,24 298 298 „ . 224 IMP 26.08 26.08 26.08 26 26 • Section 06-Regulatory Summary Analysis - - - - - Regulation 3,Parts A,B - Source requires a permit - , - , .. • RACT-Regulation 3,Part B,Section 111.1,2,0 The loadout operation must satisfy RACT. (See regulatory applicabiity worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements YOU have indicated above the source is not controlled.The following question does not require an answer. a,,. � ,f ,.„ ,.,,t'als l ¢.,r, sg:,a,rl x ,, .cabs,,, ,z: , „ „ ,:nom ,A i Section 08-Technical Analysis Notes This operation is an existing operation for pressurized loading out of condensate Based on the information provided in the application,emissions only occur from a pressurized loadout operation when the hoses used to transfer fluids are disconnected mad vented to the atmosphere.Loadout occurs fro pressurized storage vessels to a pressurized tank truck vessel operating at the same pressure.DCP is requesting to change the basis for emissions calculations to be more consistent with other per nuts.Basically,DCP used the same emissions talcolafar approach as for the prior issuance(and the same approach that has been used at Big Horn Gas Plant,Permit 1SW E0465 and: Icy Lucerne,Permit 12WE2024)but DCP is updating the vapor and condensate properties to be more consistent with the properties used at the other gas plants.With this change,DCP requesting to increase VOC emissions from 1.0 to 2.0'py while maintaining the same throughput. The moiecolar we ghtof the gas density of the liquid arid mass fractions or HAPs used to estimate the HAP emissions were obtained from a representative sample of stabilized condensate taken from DCP's SLW compressor stators on 9/24/14,This sample was used to conservatively estimate HAP emissions.While the sampleis not site specific and more than one year old,it was determined 2n.r,.al compliance test requiring a site-specific sample he. obtained was not required since the condensate being trucked in will be of varying composition and composition Is not expected to van/significantly from the representative sample In addition,DCP is conservatively report rig VCC from this source based on the assuming the entire volume of hose is emitted Requiring an initial site specific sample be obtained and used to estimate emissions from this source would not have asgnificant impact on the permit oi emissions ands riot warranted„this time This H a new source(came into service after 11/20/07)located in the o,.o ra non-attainment area As a result,this sources subject to TACT.Based on information provided,the loadout operation transfers fluid from pressurized storage vessels to pressurized tank trucks.As the roadout operation is conducted,the vapors displaced from the pressurized trucks is routed back no the pressurized storage vesse s As a result,emissions only occur when the liquid and vapor hoses are disconnected after completion of the toadout operation Based on this information,the operator is using vapor balance with pressurized vessels This method of operations satisfies RAC,. A0CC Regulator 7 Section V indicates No person s null dispose of volatile oi ganic compounds by evaporation or spillage unless RACT Is utilized.Emissions that result from the h se disconnect,as covered by this emissions point, are less than 20 tp'y VOC..The Pin's onion used 20 spy as a cutoff for requiring further RACT analysis on loadout points at similar facilites,Therefore,no furtner RACT analysis is necessary for the point. Section 09-Inventory SCC!Coding and Emissions Factors - " - Uncontrolled - Emissions AIRS Point# Process 5CC Code Pollutant Factor Control% Units . 012 US ,x #6 tint` `,„.,.. 'ciallir-51 VOC 1.51E-01 0 lb/1,000 gallons transferred 21 of 31 C:\Users\cdmoney\Documents\Package414597\11WE1479.CP4 Hydrocarbon Loadout Emissions Inventory n -Hexane 9.94E-03 0 lb/1,000 gallons transferred 22 of 31 C:\Users\cdmoney\Documents\Package 414597\11W E1479.CP4 • • Hydrocarbon Loadotrt Regulatory Analysis Worksheet • Colorado Regulation 3 Parts A and B-OPEN and Permit Renuirements [Source Witt the Non-Attainment Area ' ' ' ATTAINMENT -1. Are uncontrolled actual emissions from any criteria pollutants from thls individual source greater than 2 TPY(Regulation 3,Part A,secti0n 11.0,1.x)? • 2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part 3,Section 11.0.1.1)? a • .. 3. _. Is the loadout operation loading less than 10,000 gallons(23BWks)of crude oil per day on an annual average basis? C"'S''i - . . 4,. Is the loadout operation loading less than 6,750 bbls per year of condensate via splashfill? 5. Is the loadout operation loading less than 16,30g bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC'emissions greater than5TPY,NOx greater than lO TPVorCO emissions greater than lO TPY(Regulation 3,Part B,Section 11.0.3)7 y Not en0ugb Intonmatlon . .. NON.ATrAINMENT 1. Are uncontrolled emissons from any criteria pollutants from this individual source greater than 1T?(Regulation 3,Part A,Section Il.D.l.a)? Yes Co to next question. 2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part 6,Section 11.0.1,1)? No CA t ques:ion6 -- 3. Is the loadout operation loading lessthan 10,000 gallons(235 Wks)of rude oil per day on an annual average basis? NA' 4. Is the loadout operation loading less than 6,750 bbls peryear of condensate via splash till? NA 5. Is the loadout operation loading lessihan 16,308 bblsper year of condensate via submerged fill procedure? NA 6, Are total facility uncontrolled VOC emissions from the greaterthan2 TPY,NOx greater than 5 TPY or CO emissions greater than 5 Tr,(Regulation 3,Part B,Section ll.D.2)? • Yes x The loadout requires a permit -' 'Source requires a permit - 7. RACT Are uncontrolled VOC emissions from the loadout operation greaterthan 20 tpy(Regulation 3,Part B,Section 111.0.2.x1? No -:.¢Ithaleadout operation must sarisry PACT. • [The loadout operation must satisfy RACT: . Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air AG,its implementing regulations,and Air Quality Control Commission regulations.This document is not a rule'or regulation,and the analysis it contains may not appyto a particularslluallen based upon the individual facts end circumstances.This document does not change or substitute forany law, regulation,or en yother legally binding requirement and notlageup enforceable.In the eyentbfanyconflict between the language of this document and the language of the Clean Air Act„its implementing regulations,and Air Quality Control Commission regulations,toe 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 interpretations and recommendations.Mandatory terminology such as'must'and"required"are Intended to describe controlling requirements under the terms of the Clean Alr Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and of Itself. • Fugitive Emissions Inventory SeNon 01-Adminshative Informaton 'Facility AIRS ID: 123. P:: 013'-.=' County loot nt Section 02-Equipment Oescripdon Details Detailed E n 44005 Unit 4004004"arrtsulAefaFOp.-g6ncigaksl5s4a ORnn yl-4#sooarre{mi(ff ,,,Kg 4(4f30 0- Description: 4pq,n ars73ar4304 541)40......, .'. -i'),. t Emission control De Section o3 Procersieg Rate Information for Emissions Estimates 316,}.11,.,f5-M ppTigabi t 7411es•. Section 04-Emissions Factors&Methodologies Regulation 7 information Operating Hours: g50-M1ourstyear Emission Factor Source 67;,WA9M..='.`JW�'7, R ,si Control Efficiency Source E .w,g�.ram See Section 07 n01es,.2.83 for additional information Calculations Emission Factor(kgMr- Service Component Type Countsource) Control(%)Pollutant Mass Fraction Uncontrolled c00,12d Taate24 Table 2R Emhsl0ns MN) Emissions fray) OAS Connectors 046,E 2.00E-04 1,00E-05 0,0% VOC 28:.]0% 0.69933749 0.09333745 220E-0516fnrlsource 0.023 Flanges '91%71 3.90E-04 5.70E-06 0,0% Benzene 0300% 0.000173032 0.000173062 126E-05 lb/hrlsource 0.079 Open-Ended lines ,4'.'. 2.00E-03 1.50E-05 0.0% Toluene • 004% 0.000138444 0,003178440 3.31E-05 Ib41rlscurce Pura Pu Seals 532".:, 2.40E-03 350E-04 0.0% Ethylhenx Gam/source 0 3.46124.06 3.46124E-01 7,72E-04 Gam/srce Gas(Ruler valves Include 4 valves 6TA,,. 4.50E-03 250E-05 0.0% Xylene5 0,01% 3.46124E05 346124E-05 5.51E-0s Ibffir/saffice compressor seals) Other 4d 0.03 1.20E-04 0.0% n-Hexane - 0.001349382 0.001349802 2,65E-04101r1saurce Relief Valves ...:W.:' 8.80E-03 1.20E-04 0.0% 2,2,4-TOP 0.074% 1.39449E-05 1.38449E-00 2.65E-0b 160r/source — — — — — Methand .00% 3.46124E-06 3.41124E-06 - - - — — H2s 6n% 0 0 — — — Methyl Maedptar;::...,'..0.07% I 0 Connectors 750E-06 750E-06 0.0% VOC Flanges 3.90E-07 3.90E-07 CC% Benzene 0.00% Open-Ended Lines 1.40E-04 7.20E-06 0.0% Toluene 000% TOTAL Pump Seals O00Ea00 0.00.00 0.00 Ethylhenz ;0.00K 0,193 Heavy CI Valves 8,40E-05 8,40E-06 0.0% 0440735 ;Qi03)& 0250 Other 3,20E-05 3.20E-05 00% 8000200 6,:00%' Reran/elves — — — — 2,24-rEF :00°G — — — — Methanol 0.00% — — — — — H25 — — — Methyl Mercaplar .900% 0 LIQUID 0011 2000 ':6241`. 210E-04 9.70E-06 00% VOC -.10000% 0.747126105 0,747126105 2.14E-0515710source 0.171 Flanges .7,754''' 1.10E-04 2.40E-06 0,0% Benzene 0.1300% 0.001044327 0.001344827 529E-06 I07mrlsource 0.171 open-Ended lines ,":d+., 1.40E-03 0.0% Toluene 0.13% 0.000371264 0000971264 3.09E-05 Ib010001ce Pump Seals ''5' 130E-02 5.10E-04 0,0% Ethylbenzen1 003%' 424131.03 224138E-05 1.12E-03100,120urce Light CI Valves ':1409 250E-03 19cf-05 0.0% Xylenes 0.100224130 000022414 4.10E-05Ib4sr1s0urca 0101, 'a 750E-03 1.10E-04 00% n-Hexane .37°h 0.010233628 001023562 2.43E-04 16/hr/source ReIle7Velves '1%%, 750E-03 1,10E-04 00% 2,2.4-TMP 001% 7,47126E-05 747126E-03 243E-04 10017/souros — — — — — Methanol 7.4712605 7,47128E-0 — — — — — 020 0 c0°A — — — — Methyl Mercaptar:'7, 000%... 00111000 f 1,6. 1.10E-04 1,00E-05 0.0% VOC Flanges 2,30.06 290E-0fi 0.0% Benzene 0 0010/0402 Lines 2,50E-04 330E-06 00% Toluene ',;'F:,: 72%mass dad benzene Pump Seals *'S, 2.40E-05 2,40E-05 -00% Elhylbenzene -'/4.'. 7.2%mess tad benzene Water/Oil Valves 9.60E-05 3.70505 00% Xylenes ,,./,..".j0.::77;,,,,..,: Olher 1.40E-02 5.90.,05 0.0% n-Hexane `;_14' 42.6%mass tract 0413 02113G/dyes — — .".k:'11..,' 42.5°b mass tact n-hex _ — _ — — Methanol ': .':.:'0, — — — — — Methyl Mercaptar::'....6...,.. Section 05-Em12on inventory Old operator request abu.er? gouqugmumiu Requested 40=21141: ........-43„< 1`4:m Pallut0nt Uncontrolled Emissions Controlled Emisslons Source VOC 4.10 toy 12 ktv Screening EFs-EPA-4532245-017 Table 2-a 201 TPY - Benzene 425 I0Nr 425 leNr Screening EFs-EPA453/S-95-017 Tablet-8 000212504 0,002125 Toluene 3.11 IbM 3.111b/yr Screening EFS-EPA-45715-95-017 Table 2A 00015536 00015056 621710enzene 0,070/' 0.07 16/4 Screening EFs-EPAJ53R-05-017 Table 2-8 3.0225E-05 3,623E-05 Xylen1 0.72 lb/l 0,7210/yr Screenng EFs-EPPe4531R-95-017 Table 20 0.00036225 0.0003623 n-Hessne 32,441bM 32,44 lb/r Screening EFs-EPA453R-95-0t7 Table 2-80.01621971 00162197 2,24-147 0,2511/yr 0,247101yr Screening EFs-EPA.455/R-95-017 Table 20 0,00012398 0,000124 Methanol 0.031b4O 003107,0 Screening EFs-EPA-4534i-95-017 Table 2-0 1.5305E-05 1.531E-05 H25 2.00 lb/or 0,00 GM Screening EFs-EPA-053R-95-017121112-4 0 0 Mehyl Metcaplan 0.001bryr 0,06 Iblyr Screening EFs-EPA-45332-95-017 Table 2A 0 0 Section 06-Regulatory Summary Analysis Reg.3 Review Regulation 3,Part B,Sec3en11L02to determine is,ACT is required, Red 6 Review 40 CFR,Parr 60,Subpar(l00(todelermine if applicable to this source, 400 Review 4o CPR,Fart60,Su1pert 0000 t0determtde if 60.56.80 and/0f 60.6385 ie applicable, 000 8e&7 R0Mex Section XVILF 10 deferable is LBAR is applicable? ;toes ' Addltlonal Regulatory Considerations Seo05n IIA1-Except as provided In paragraphs 2 through 3 below,no owner or operator of 8 source shall ellowar cause the emission into rise atmosphere of any air polletantwhich is in excessof20%opaclty.This standard is Regulatlon� based on 24 consecutive opacity readings taken at l5-second intervals for six minutes,The approved reference test method for visible emissions measurement Is EPA Method 9(40 CFR,Part60,Appendix (July,1922))In all subsections of Section IL A and B of Ibis regulation. SeNon IA-No person,wherever located,shall cause or allow the emission of Nor0usah eente/nin2nts from any sing0 source such as to result in detectable odors which are measured in crows of the following limits:For areas o a Re9ulation2 used predominantly(redden,.o commercial purposes it Is 04101260,If odors are detested after the odorous alt has bean diluted with seven(7)ormarevolumesaf odor free air. Part A-APEN Requirements Criteria Pollutants:For criteria pollutants,Air Idlutant Emission Notices are required far:each individual emission point In a non-attainment area/v.1 0l unconvdled actual emissions of one ton per year.'note dray individual c0 criteria pollutant(pollutants are not summed)far which the area A14 t men Applicant Is required to file an APEN since emissions exceed 1 1 00,ton per year VOC Part Et—Construction Permit Exemptions Applicant Is required to obtain a permit since uncontrolled VOC emissions from this facility are greabr Man the 1 TPY threshold(Reg.3,Part S) Ls this source located In an ozone non-626nmem area or attainment maintenance area'? If yes,Is this source subject to Mak detection and repair(LOA,)requirements per Regulation 7,Section XVII.F or Regulation XII.G a40 CFR.Part 60,5000e7s KKK,0000,.r 000087 - Part B,IIL62-RACY requirements for new or modified minor sources This section of Regulation 3 requires RACE far new or modified minor sources located in nanattainment or attainment/maintenance areas.This source is located In-the 8-hour ozone 00686anment area, The date of interest for determining whether the source A new or modified Is therefore November 20,2007 (the date of the 8-hour ozone NA area 4602320on).Since the fug0ves will be In service after the date above,MIS source Is considered"now or modified." This facllity Is subject to NIPS 0000a as wall as Regulation 7,Secdon)Nll.F,Following the leak detection and repair program per Reg 7 satisifies the,ACT requlfements of Regulation 3,The permit will cont40 a candid.reflecting this determination, • • • Fugitive-Emissions Inventory • - ' • • la this scarce al an onshore ral gas processing planl`asdefined in 40 CFR,Part60.631? ,y. Did Nis source commencescosimoCon,reconstruction ormedfico0on after January 20.1984,and onarbfu • _- - . August PS,2011? • Thisa source Is subject NSPS KKK because the new covered byahis fugitive sourcewill - our of - .. commence construction after August 23,2011 andls atolllocated eta natural gas processing plant( Regulalion8 - - technbal analysis notes, • aptelmber18 20i6?encesconsWNon taco b 8u or modification oNsr August 232011 and on or before °4 • - - • Source is not subject to NSPS 0000 because the new equipment covered by this fugitive source will • l • commence construction after September 18,201S. • IS this source located In an ozone non-attainment area or attalnmentmanl0nance area? is this source at ananshore t 1ral gas processing plant`as defined m4o CFR Part60.631?• Facility is not classified as a natural gas processing plant.Therefore,this source is not subject to Regulation l Regulation]Section OII.G. LS thefadlity classified asawll production fadlity ornalrai gas compressor station? _., Yes .. Since this facility Is classified as a natural gas compressor station,is Is subject to Regulation 7 Section Is this source et a'natural gas processing plant-as defined In 40 CFR,Pad 63.161? Is this facility considered a`malor source,'HAP es specifically defined in 40 CFR.Pal 63.761 for sites that aie (t. • 11J production field"sedges? -11 _, Regulation 0 if you repond es roboth questions above,fudher renew if the provisions of 40 CFR,Part 63.760"Equlpmenl Leak Standards. Source Is not subject to MACTHH because the facility Is classified as a epithetic minor source eS CAPs. Did this source commence construction,reconstruction,or modification after September 18.2015? KNie source ate well site.compressor station or onstwreYlatral gas processing plant.as defined In 40 CFR.Pad NSPS 00000 60.54000? "" • This facility meets the definition of a compressor statoin as defined by40 CFR,Part 60.64300.Therefore, the fugitive emissions et this facility ere subject to NSPS 00000. • Section 0]-Technical Analysts Notes • —The it contain t;Ir lccomptedb donengneehta agmell haFiCrd oloomponle nband nbeentlairt etreletslted titTEOlnlet,sampled 11J4/20167.A aresulr,the permit ll contain niaS[lal compliance requiringtha actual hard cob f components and an petrel attended Rasanalysz.. As discussed above,this source Ts subject to NIPS 0000a.-However.this NSPS has yet been adopted into Colorado Regulation 6 Asa result,the condition referenfng NSPS 0000a will be addressed m the notes to permit holder sect mn ofihe permit. The gag,/is 0110 r station so its subject to Regulation 7,Section 051]F as well as NIPS 0000x. Source gonna em o factorsfom table 38 Iscreenng factors)from EA document Protocol for Equipment Leak Emission Estimates.This nos appnspriate since components will • - • b cared nac rdancew[h Sett on%V L - Section 08-Inventory SCCCodina and Emissions Factors Uncontrolled AIRSPaints Process() SCC Cade Pollutant Emissions Factor Control% Source iVaries by bariesbycemponent <, VOC component type • type Screening EFs-EPA453/R-95-011 Table 2-13 • Varies by Varies by component eenzene co c%%Pe type Screening EFs-EPA-4531?-91-01]Table 2-O• Varies by Varies by component Toluene component type type Screening EFs-EPA-4S3/P-95-017 Table 2-8 Varies by Varies by component - - Ethylbensene component type type Screening Us-EPA453/R-tS-01]Table l-0 - ' - -- Varies by Varies by component - • - Xylene comPooeM type type Screening EFs-EPA456/R-95-01]Table 2-e Varies by Varies by component n-Hesane component type type Screening EFs-EPA450/R-95-017Table2-R Varies by Varies by component • 224ThiP component type type Screening EFs-LPA455/0-95-01]Table2-8 Compressor Blowdown Venting Emissions Inventory Section 01-Administrative Information 'Facility APIs ID: 123 9010 OSS County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Description. 4Rafurz,'Tg 5 ling from turbine compressor blowdowns during turbineshotdown.events Emission Control Device Description: None- _. Requested Overall VOC&HAP Control Efficiency%: 0 " Limited Process Parameter ._, Section 03-Processing Rate Information for Emissions Estimates Primary Emissions Compressor Blowdown V m �s 3 ,0O275 MMscf Requested Compressor Blowdown ,q. fi a "v Events= 0A41.;33, 0..4"events/Year Actual Compressor Blowdown Events= 0tri eilt £ ,R events/Year - _. _ _ _ - Actual Throughput= 0.6 MMscf per year RequestedPermitLimitThroughput= 1.10 MMscf per year Requested Monthly Throughput= - 0.0934 MMscf per month I - Potential toEmit(PTE)Throughput= 1.10 MMscf per year - - - - Process Control(Recycling)Equipped with VRU ,y "T Y Is VRU process equipment 4It . Secondary Emissions-Combustion Device(s)for Air Pollution Control Separator Gas Heating Value: Btu/scf Volume of waste gas emitted per BBL of - liquids throughput: scf/bbl Section 04-Emissions Factors&Methodologies Desoiption - i'�.t specific inlet gas analysis obtained from the Troudt facility t 11/4/2016.This analysis d along with the displacement equation shown below d t estimate Ezi�lyo 'Asa' it }sYessbcisl downs were calculated based onasites �ip ,,K n4 il.pl �� ` ...ms=s-6-v.-.1.:-.41;,--7. 4::',',..Ae,n.,:Mr 7.441.41:4:71,9,247:::,,,. ..ri e..z_kr_v_.... ,141 .z t-,..ar..� ...--f,..a4-,w.". MW l 22.92793624 lb/lb-mol Displacement Equation • Ex=Q'MW'Xx/c - . Corroded Mole% Molecular Weight lb/lb-mole Mass% Mass% Helium 0.00.... 4 0 0 - •. CO2 1.99 43.99 0.875401 3.818054058 - , 92 - 0.42 28.02 0.117684 0.233277771 - methane 71.42 16.01 11.43443806 49.87120489 52.1290987 ethane 14.01 30.02 4,20493142 16.13977283 19.17009317 - ' propane 7,36. 44.03 324219308 14.1407977 14,78101239 ' isobutane 0.90 58.04 0.51969016 2.266624238 2,36924406 ' n-butane 2.40 58.04 1.39069644 6.065510761 6.340122501 . isopentane 0,49 72.05 0,913045 1.539802782 1,609116272 ' n-pentane 0.55 72.05 0.39980545 1.743748089 1.82269506 ryclopentane 0:03 70.1 0.0205393 0,009501983 0.093637745 n-Hexane 0.10 86.16 0.08616 0.375786111 0.392799564 • - ryelohexane 0.02 84.16 0.01859936 0.081120951 0.064793645 Other hexanes 0.17 86.16 0.14036752 0.647103694 0.676400849 ' heptanes 0.06 100.2 0,0570138 0.248665207 0-259923349 - methylcyclohexane 0.02 98.19 0.01659411 0.07237507 0.075651801 224-TMP 0.00 114.23 0.00079961 0.003487492 0.003645386 Benzene - 0.01.. 78.1 0.0111683 0.048710446 0.050915777 Toluene - 0.01 92.14 0.00847688 0.03697184 0.038645715 Ethylbenzene 0.00 92.1 0.0001842 0.000803387 0.00083976 Xylenes 0.00 106.17 0.00159255 0.006945893 0.007260364 CB+Heavies 0.02 114.2 0.020556 0.08965402 0.093713879 Total 99.98 TOC% 95.67 - -VOC Mole% 12,14 VOCWt% 28.70081812 Emission Factors - Compressor Slowdowns Emission Factors - Compressor Blowdowns Uncontrolled Controlled Uncontrolled Controlled (lb/MMscf) (lb/MMscf) Emission Factor Source lb/event lb/event Pollutant Pollutant (Compressor (Compressor (Gas Throughput) (Gas Throughput) Slowdown) Blowdown) VOC - 1736?8108 17362,8108 -'j i4 ,'* .sxm,.% . ,'.«.s VOC 477,4773 477.4773 Benzene • 30.8019 30.8019 �4.t om, Benzene 0.8471 0.8471 _ Toluene 73.3791 - 23.3791 —`8i 16 - Toluene 0.6429 0-6429 Ethylbenzene 0,5080 0.5080 {n. S, - Ethylbenzene- 0.0000 0.0140 Xylene - 4.3922 4.3322 _ - Xylene 0,1208 0.1208. n-Hexane ' - 237.6275 237.6275 n-Hexane 6.5348 6.5348 224TMP - - 22053 2.2013 }6:, . t ,.e. 224TMP. 0.0606 - 0.0606 Primary Control Device Uncontrolled Uncontrolled Pollutant (15/MM0tu) Ib/MMscf Emission Factor Source (Waste Heat Combusted) (Gas Throughput) -- PM10 0.000 Y. , 4 ,rf. „g�` PM2.3 0,000 - - - - SOX 0,000 & v NOx 0,000 t 26 of 31 C:\Users\cdmoney\Documents\Package 414597\11WE1479.CP4 Compressor Slowdown Venting Emissions Inventory Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tans/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0,00 0.00 0.00 0.00 0.00 0 PM2,5 0.00 0.00 0.00 ORO 0.00 0 SOx 0.00 0.00 0.00 0.00 0.00 0 NOx 0,00 0,00 0.00 0.00 0.00 0 VOC 9.55 0.00 0.00 9.55 9.5 1622.11 CO 0.00 ROB 0.00 0,00 0.00 0 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (Ibs/year) (Ibs/year) (Ibs/year) (lbs/year) Benzene 33.88 0.00 0.00 33.88 34 Toluene 25.72 0.00 0.00 25.72 26 Ethylbenzene 0.56 0.00 0.00 0.56 1 xylene 4.83 0,00 0.00 4,83 5 n-Hexane 261.39 0,00 0.00 260.39 261 224 TRIP 2.43 0.110 0.00 2.43 2 Section 06-Regulatory Summary Analysis 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 Regulation t which is in excess of 20%opacity.This standard 0 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. Section LA-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are Regulation 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. Part A-APEN Requirements Criteria Pollutants:For criteria pollutants,Air Pollutant Emission Notices are required for:each individual emission point in a non-attainment area with uncontrolled actual emissions of one tan per year or more of any individual criteria pollutersgsollutants are not summed)far which the area Is non-attainment. Applicant is required to tile an APES since emissions exceed 1 ton per year VOC Part B—Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPV threshold(Reg.3,Part B,Section II.D.2.a) Part 0,111.0.2-RACTrequirements for new or modified minor sources Regulation This section of Regulation 3 requires RACT for new or modified miner sources located in n0nattainment or attainment/maintenance areas.This source is located in the 8-hour ozone nonattainment area. The date of interest for determining whether the source is new or modified is therefore November 20,2007(the date of the 8-hour ozone NA area designation).Since the turbine compressor blowdowns will be in service after the date above,this source is considered"new or modified? The operator indicated RACT is satisfied through goad maintenance practices.These include the following:"These include practices such as avoiding"flat"blowdowns or completely blowing down equipment for every single maintenance event.The proposed blowdowns/yr limit takes these practices into account."The operator further explained that"A"flat"blowdown is the removal of all pressure from tie system.A sudden"flat"blowdown would be result in a higher emission event,therefore this practice Is avoided to the extent possible for turbine blowdowns."Please see additional information regarding RACT in the Technical Analysts notes In Section a8 below. Section 07-Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to MonitorCompliance Does the company use site specific emission factors based one gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRS ID,and should have been collected within one year of the application received date.However,if the facility has not been modified(e.g,no new wells brought on-line),then it may be appropriate to use en older site-specific sample. If no,the permit will contain an"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. • Are facility-wide permitted emissions of VOC greater than or equal to 90 tons per year? If yes,the permit will contain: -An"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A"Periodic Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factor's are less than or equal to the emissions factors established with this application on an annual basis. Does the company request a control device efficiency greater than 95%for a flare or combustion device? ibillgt,4"44,1""fighgaiN/A-source is not controlled. Ifyes,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 You have indicated above that the monitored process parameter is natural gas vented:The fallowing ouesfir/ont do not require an answer. ya /..., r 4 27 of 31 C:\Users\cdmoney\Documents\Package 414597\11WE1479.CP4 • . Compressor Blowdown Venting Emissions Inventory Section OS-fechnical Analysis Notes DCP is requesting to add a sewoont for the compressor statio to account for blowing down the dry-seal centrifugal compressors as part of turbine shut downs To estimate emissions,the operator dsedz gas sample from a sender site to es[ ate stream co posron.Ths sample was obtained f,0,9 the Troudt Compressor Station on 11/4/2016 Since the sample is not site specific and was obtained more than one year pror the application,the operator will to revw.d to obtain ante specific sample representative of compressor blowdowns as part of the initial compliance demonstration for this facility Ths sanplewll be used to demonstrate the ems son factors established through this analysis are eitheraccurate or conservative. Typically,emissions assodated with natural gas venting associated with compressor hlowdowns are calculated usng the weight%vales directly from the sample analysis provided in the applicator Instead of s x he weght%soda 6'0011,from the sample,the cpef afor chose to use:the mole%values and convert to weight%.This methodology lead to minor difference in weight%values The operatorfurther adjusted the calculated weight alues by assuring the sampled s composed entirely of hydrocarbons. at.L he ce carbon dioxide and nitrogen content in the samples assumed to be zero This methodology leads to aslghtly more conservative estimate of emissions since the sample dates roman minor fractrons of components that are not considered hydrocarbons this calculation methodology may be reviewed in Section 00 above.The operator's calculations are conservative compared to the Division's practice of estimating emss ons from compressor blowdown.As a result,the operator's calculations are accedtab e for permitting purposes In order to calculate actual emissions,the operator will track the,umher of events and multiply the events by the emss on factors The emission factors have been converted to nineJnits of lb/event and are available for reference in Section 04 above The operator used compressor volume of 27,500 cubic feet/blowdown.According to the operator,the volume l based on an engineering estimate of the turbine volume and piping volume at Godfrey The operator provided the following information with regards:so RACI The only constructed and operating conorol deuce at Godfrey is the TES ECO,which is specifically designed to control the waste gas off the dehydration regenerators,,ysbern,aims system operates at low pressures for the TOG and cannot handle she ia00 ohortermvolumes produced by compressor and purge blowdowns New add controls are expensive and also require significant redesigns to-facility layout,when adds to Ohs overall expense.In general,in plants where hlowdowns are captured,these systems have been specfca'ly designed for this operatic,.At the gas processr plants like lucerne 2 and Mewbourn,these kind of blowdown:activities areiyprcaly handled by the plant/emergencyrare. TVp cc ly,GOP considers good work practice requirements as RAcT far blowdown s hose include practices such as avodng'flat blowdowns or completely blowing down equipment for every single maintenance event A flat blowdown ie when all the gas in the. compressor issent to the blowdown vent.DEP prefers pressurized hold blowdo s becaseanlp some of the gas is sent to the blowdown vent.in that case and most of itmaintained in the pressurized hold mode so that it is not sent to atmosphere.Flat blowdowns are typically the result of unexpected upset conditions that trip the turbine and then there sot time to go too peseserzed hold or for a planned plant shut down for maintenance approximately every 5 years In addition,DCP makes an effortro avoid blowdowns:and purges during everyday operations and to keep the booster StatION dnning as smoothly as possible The proposed hlowdowns/yrl pit takes these practices into account Idscussed With DCP that the blowdown and purgng emissions should be look. at collectively when evaluating BACf.Due to the recent Dec 2019 rulemakng,DCP ill be required to provide total venting ems ons but per the division fAO i,DCP has until On 2020 to update these ems.ons DCP stated they will be re evaluating total emissions and nACf as per the recent,blemaling.It is appropciate topemt tie'missons and RAGE as g od maintenance pr rheas at rho time.'; Monthly limits are rot included since maintenanceale not esenl,a ttr buteo c-nshout the year.- - - • Section 09-Inventory SCC Coding and Emissions Factors • Uncontrolled Emissions AIRS Pointe Process SCC. Code Pollutant . _ Factor Control°6 Units • 015_ _ Ol * � o- . PM10 _ 0.00 0. 'Ib/MMSCF . PM2.5 0.00• 0 Ib/MMSCF - - - - - - - 50a .. 0.00 A- Ib/MMSCF - NOx- - 0:00 - 0 Ilf/MMSCF -- - VOC- 17362.81 - 0 Ib/MMSCF CO 0.00 0 ib/MMSCF Benzene 30.80 - 9- IC/MMSCF - Toluene 2398 0 Ib/MMSCF - - - - Ethylbenzene 0,51 0 Ib/MMSCF • Xylene 4.34 0 Ib/MMSCF n-Hexane 237.63 0 ib/MMSCF - _ - 224 TMP 2.21 0 Ib/LNMSCF • • • • • • • • • • • • 28 of 31 - C:\Users\cdmoney\Documents\Package 414597\11WE1479.CP4 Compressor Blowdown Venting Emissions Inventory Section 01-Administrative Information - ' • 'Facility AIRS ID: 1'244. 4,RI. 3'-v`.1. ,: 9010 AY6,,•'> ' County Plant Point Section 02-Equipment Description Details -- Detailed Emissions Unit Description: NatUlatgpsy3 ntt g)A41Uf5nE(Tt1,FE,Lp;IdAOR&Z)by p?,smpOriieVegtsduff9g.kIrh wsfiar l-'r"'tk„9)._"„."„ 4.4.7.:.;,_-c.a Emission Control D ce Description: None' h o, m16 1z, Wd _ 1:. S_, ... Requested Overall VOC&HAP Control Efficiency 36: ' Limited Process Parameter = F a. Section 03-Processing Rate Information for Emissions Estimates - - - Primary Emissions - - - i Compressor Blowdown Volume ,O 0 fI S 6 MMscf 5560 Requested Compressor Blowdow 0,. b '">1 Events= 'v"''L"y:t ,44 events/year Actual Compressor Slowdown Events= k,fyti •' „'„�„0events/year - - ActualThroughput= 0.0 MMscf per year Requested Permit Limit Throughput= 0.22 MMscf per year - Requested MonthlyThroughput= 0.0189 MMscf per month Potential to Emit(PTE)Throi.9hput= 0.22 MMscf per year Process Control(Recycling)Eq ipped with a VRU ;NW'2T¢ ₹44rz'_ - - - _- - - Is VRU process equip t. - - Secondary Emissions-Combustion Device(s)for Air Pollution Control Separator Gas Heating Value: Btu/scf Volume of waste gas emitted per BBL of liquids throughput: ..scf/bbl 'Section 04-Emissions Factors&Methodologies Description Emissions associated with turbine compressor blowdo n t calculated based on a site specific inlet gas anaiyss obtained from the facility inlet)pre-dehy)on 10/5/2018.This analysis was used along with'th,d(npiacement equation shown below in order to s were estimate emission n factors andemissions. .. MW I 22.927936241lb/Ib-mol Displacement Equation Ex=CI.MW''Xx/C Corrected Mole% Molecular Weight lb/lb-mole Mass% Mass% Helium 0.00 4 0 0 - CO2 1.99 43.99 0.875401 3.818054058 - N2 0.42 28.02 0.117684 0.513277771 - methane 71.42 16.01 11.43443806 49.87120489 52.1290887 ethane 14.01 30.02 4.20493142 18.33977283 19.17009317 propane 7.36 44.03 3.24219308 14.1407977 14.79101239 Isobutane 0.90 - 58.04 0.51969016 2.266624238- 2.36924406, n-butane 2.40 58.04 1.39069644 6.065510761 6.340122505 kdpentane 0.49 72.05 0.353045 1.539802782 1.609516272 n-pentane 0.55 72.05. 039980541 1.743748089 1.82269506 cyclopentane 0.03 70.1 0.0205393 0,089501983 0.093637745 n-Hexane 0.10 86.16 0.08616 0.375786111 0.392799564 cyclohexane 0.02 84.16 0.01859936 0.081120951 0.084793645 Other hexanes 0.17 86.16 0.14836752 0.647103684 0.676400849 heptanes 0.06 100.2 0.0570138 0.248665207 0.259923349 methylcyclahexane 0.02 98.19 0.01659411 0.07237507 0.075651801 _. 224-IMP 0.00 '.'114.23 0.00079961 0.003487492 0.004645386 Benzene - 0.01 78.1 0.0111683 0.048710446 0.050915777 Toluene 0.01 '..'92.14 0.00847688 0.03697184 -0.038645715 Ethylbenzene 0.00 92,1 0.0001842 0.000803387 0.00083976 Xylenes 0.00 - .106.17 0.00159255 0.008945893 0.007260364 -- - CB+Heavies 0.02 114.2 0.020556 0.08965482- 0.093713079 - Total 99.98 TOC% - 95.67 .. VOC Mole% 12.14 - VOCWt% 28.700818121 - - Emission Factors Compressor Slowdowns Emission Factors Compressor Slowdowns Uncontrolled Controlled Uncontrolled Controlled Emisslon Factor Source Pollutant (lb/MMscf) (lb/MMscf) pollutant lb/event lb/event (Gas Throughput) I (Gas Throughput) (Compressor Purge) (Compressor Purge) VOC 17362.8108 17362.8108 .,'extended gas aril,'Liz VOC 96.5372 96.5372 Benzene 30.8019 30.9019 'Etdp d d `a Benzene 0.1713 01713 e Toluene 23.3791 23.3791 '4 •:. d d g anal'-- Toluene 0.1300- 0.1300 Ethylbenzene . 0.5080 05080 ,431.e d t anal•.- - - Ethylbenzene - - 0.0028 0.0028 Xylene 4.3922 4.3922 -Eate rind ga;ehaiY- - Xylene 0.0244 0.0244' - - e-Hexane 237.6275 237.6275 yA ded gas anaty n-Hexane 1.3212 1.3212 __ 224TMP 2.2053 2.2053 EA:ended gas anal .s,-a tS- .q„'ac 224TMP 0.0123 0.0123 Primary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) lb/MMscf Eeisslon Factor Source (Waste Heat Combusted) (Gas Throughput) PM10 0.000 ! PM2.5 0.000 Lft SOx - 0.000- Nox - 0.000 CO 0.000 , - -veS 29 of 31 C:\Users\cdmoney\Documents\Package 414597\11WE1479.CP4 Compressor Blowdown Venting Emissions Inventory - Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month) PM10 0.00 CIAO 0.00 0.00 0.00 0 PM2.5 0.00 0.00 0.00 0.00 0.00 0 SOx 0.00 0.00 0.00 0.00 0.50 0 NOx 0.00 0.00 0.00 0.00 0,00 0 VOC 1.93 0.00 0.00 1,93 1.9 327.96 CO 0.00 0.00 '0.00 0.00 0:00 0 - Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) (Ibs/year) )Ibs/year) (Ibs/year) Benzene. 6,85 0.00 0.00 7 7 Toluene 5.20 0.00 0.00 5 5 Ethylbenzene 0.11 0.00 0M0 0 0 Oflene 0.98 0.00 0.00 1 1 - - n-Hexane 52.85 0.00 0-00 53 53 224 TMP 0.49 0.00 0.00 0 0 Section 06-Regulatory 5ummaryAnalysis Section II.A.1-Except es 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 en pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 13-second intervals for six minutes.The approved reference test method for Regulation 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. Section l.A-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are • - Regulation2 measured in excess of the following limits:For areas used predominantly!or 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. _ Part A-APEN Requirements Criteria Pollutants:For criteria pollutants,Air Pollutant Emission Notices are required for:each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant]pollutants are not summed)for which the area is non-attainment' - • Applicant is required to file an APEN since emissions exceed 1 ton per year VOC • Part B-Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg,3,Part B,Section II.D.2.e) Part B,III.D-2-RACT requirements far new or modified minor sources Regulafon3 This section of Regulation 3 requires RAC)for new or modified minor sources located in nonattainment or attainment/maintenance areas-This source is located in the 8-hour ozone nonattainment area.-The date of interest for determining whether the source is new or modified is therefore November 20,2007(the date of the 8-hour ozone NA area designation).Since the turbine compressor blowdowns will be in service after the date above,tie source is considered"new or modified." . The operator indicated RACT Is satisfied through good maintenance practices.These include the following:"These include practices such as avoiding"flat"blowdowns or completely blowing down equipment for every single maintenance 550E.The proposed blowdowns/yr limit takes these practices into account."The operator further explained that"A"flat"blowdown is the removal of all pressure from the system-A sudden"flat"blewdewn would be result in a higher emission event,therefore this practice is avoided to the extent possible for turbine blowdowns."Please see additional information regarding RACE in the Technical Analysis notes in Section 08 below, Section 07-Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to MonitonCompliance Does the company use site specific emission factors based on agas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRs ID,and should have been collected within one year of the application received date.However,if the facility has not been modified(e.g,no new wells brought on-line),then it may be appropriate to use an older site-specific sample. • - If no,the permit will contain an"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with-his application. ' Are facility-wide permitted emissions ofnOC greater than or equal ta 90 tons per year? py• If yes,the permit.will contain:. -An"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the •emission factors are less than en equal to the emissions factors established with this application. -A"Periodic Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the • emission factors are less than or equal to the emissions factors established with this application on en annual basis. Does the company request a control device efficiency greater than 95%for a Earn or combustion device? N/A-source is not controlled. If yes,the permit will contain and Initial compliance test condition to demonstrate the destruction efficiency of the combustion device based . - on inlet and outlet concentration sampling You have indicated above that the monitored process parameter is natural gas vented-The following questions do not require an answer. • _ ftfoggsgfoVaggggmraii a 4 s. s z',Au zap �„. ..� 30 of 31 C:\Users\cdmsney\Documents\Package 414597\11WE1479.CP4 Compressor Blowdown Venting Emissions Inventory • • Section 08-Technical Analysis Notes DCP is requesting to add a.new gamy t or thsco pressor station to account-for purging the dry-seal centrifugal compressors as part o turbine startups.To estimate emissions,th operator used a gas sample from a s mla site to estimate stream compostootTh s sample was ob«red from the Troudt Co rnpfssor Station on 11/4/2015..Since the samples not site specific and was:obtained more than one year hot the application,the operator will be required to obtain a she specific sample representative of compessor blowdowns as part of this r,al compliance demonstration for the facley This sample wll be used to demonstrate the emission Factorsestablshecl through the analysis are ether accurate conservative. In order to calculate actual emissions,the operator will track the he number of eventsa d multiply t everts by elm emission actors The emission factors have been converted to units of b/event and are available r reference.rSec on 04 above. The operator used a compressor volume of 5,560 cubic feet/hiuwdown event.According to the operator,this volume s based on an engineering estimate for the length of tine gas is used to purge the sorb ye arcd size of turbine.This vale_S cons,tentwth what DCP has assumed for:-rlar sou-ce types DCP provided tl_following response with regard to RACT for the source: for turbne and purge hlowdo ns,th_,ommon ssues that these blowdowns have a high instantaneous flowrete,but a low oveill annual flowrate,which makes sizing emissions control combustion equpmentdfh,ult The only constructed and operating control deuce at Godfrey is the TEG ECD,which s specifically designed to control the waste gas old the dehydration regeneration system This system operates at low pressures Further FEG and cannot handle the large short-term volumes prodcceo`by cOrilpi essur and Purge.showdowns New add-on controls are expensive and also require significant e=_dnsgns to fan Lty layout,which adds to the overall expense In general,in plans where Slowdowns are captured,these systems have been specifically designed: for this operation.A,the gas processing Wants like Lucerne:2 and Mewbourn,these kind of blowdown activities are typically handled by the plant/emergency flare considers good work qpurges.DCP makes an effort to avoid blowdowns and.purges during everyday operations and to keep the b runningstation as smoothly as possible.For purge,DCP has limited the purge to 5 minutes Typically,DCP practice urr_ments as RACT to limit emissions,but to also clear the turbine of a bold up of oxygen while the turbine is down so that there is not an explosion while trying to restart the turbine The proposed purge/yr limit takes these practices fotoaccounti Upon further discussion OCT provided the following clank cation: "A flotblowdown iswhen all the gas in the compressor'ssent to the blowdown vent DCP prefers pressurized hold blowdowns because only some of the gas is sent to the blowdown vent in that case and most oft is maintainedr the pressurized hold made so that it is not sent to atmosphere.Flat blowdowns are typically the result of unexpected upset conditions that trip the turbine and then there isn't time to go too:pressurized hold..Far purgers,DCP hos limited the time far purging which in turn limits the amount of purge gas that is coed to purge' the system of a buildup of oxygen after the cooepressarhos been down In addition,DCP makes an effort to avoiettilawdowns'ond purges during everyday operations and to keep the booster station running as smoothly as possible I discussed with DCP that the blowdown and purging emissions should be looked at collectively when evaluating RACT.Due to the recent Dec 2019 rulemak rig,DCP will be required to provide total venting emissions but per the d'v s on FAQ 1,:DCP has until Fall 2020 to update these emissions.PCP stated they will be re-evaluating total em.,ions and RACT as per the recent rulemaki ng.Its appropriate to permit the emissions and RACT as good maintenance practices at this time. Monthly Perrot limits are not included since maintenance events are notevenly distributed throughout the year Section 09-Inventory SCC Coding and Emissions Factors • - - • Uncontrolled Emissions AIRS Point# Process U SCC Code Pollutant Factor Control% Units 016 01 r i..+, .dx p I, P5110- 0.00 0 Ib/MMSCF •PMZ.s 0.00 0 Ib/MMSCF SOx 0.00 0 Ib/MMSCF Not 0.00 0 IbjMMSCF .vac- 17362.81 0 lb/MMSCP - CO 0.00 0 16JMMSCF Benzene 30.00 - 0 Ib/MMSCF Toluene • 23.38 ' 0 -' ib/MMSCF Ethylbenzene . 0.51. 0 ' Ib/MMSCF %ylene 4.39 0 - Ib/MMSCF - - n-Hexane .237.53 0 ib/MMSCF 224 TMP- 2.20 - 0 Ib/MMNCF• • • • • • • 31 of 31 C:\Users\edmoney\Documents\Package 414597\11WE1479.CP4 COLORADO DEPARTMENT OF PUBLIC HEALTH .AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name County AIRS ID Plant AIRS ID Facility Name DCP Operating Company, LP 123 9010 Godfrey Bottom Compressor Station History File Edit Date 02une Status 121512019 Non -Attainment EMISSIONS - Uncontrolled (tons per year EMISSIONS With Controls (tons per year) POINT AIRS ID PERMIT Description PM10 PM2.5 H2S 502 NOx VOC Fug VOC CO Total NAPS PM10 PM2.5 H2S SO2 NO: VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL 0.0 0.0 0.0 0.0 35.3 982.0 35.8 212.5 0.0 0.0 0.0 0.0 36.2 57.2 40.6 16.5 Based on March 2017 tab for Points 005, 009-012, 006 and male activities Previous Permitted Facility total 0.0 0.0 DO 0.0 34.6 974.6 00 34.6 212.3 DO 00 E0 0.0 35.5 49.8 DO 39.4 16.2 Rased on March 2017 tab far Points 005, 009, 010, 012 (Ole permitted facility total vas not added correctly in the March 2017 tab, I've corrected the total here) _ 11WE14:9,c:N SVa=Aes^_3L7044GSi.ldtilipn _ _ L.0 0.0 Canned- NotPxia:;e00712%0;2015 I1V.'E1479.CN WOAkes0AL7C{4GSt 16.90 In., 00 00 Canconed- Noise receive:(1220-2016 GOT 1114,E14 /9 CN Waukesha 57144656 '600 hp 0.0 Canoe/. - Nofice ,ecave:d?2'24.20:10 004 IrWE1479.0N Waukesha i_7044GS1. 1080 hp 0.0 Ca 8062- 1101K0 racei;.ed'1217112015 005 11WE1479 TEG Dehy.140 mmscfd 0.1 0.1 1.3 625.3 5.6 176.1 0.1 0.1 1.3 19.5 5.6 7.7 Abdifyto Increase throughput, decrease resin rate and add combustion emissions Tram supplemental fuel i5WE0147,XA.C Fu9!Itros e.c� 00 him. APEN.mmrireeand .Heniifa:1 as Po, 9,2 11WE1479.CN H:keshs i7044(39? tnd0 hp 0.0 Ca NaIKo r.=cahIC 12':12015 ;:.03 tIWC14:ti,',V PAT.r.IR..;1a %:,;701ew,l*Wns• a 0 Caocai:aa 009 11WE1479 TURB-1 Solar Taurus 70 Turbine 2.0 2.0 1.0 18.2 1.9 27.0 0.3 2.0 2.0 1.0 182 1.9 27.0 0.3 Abdity to increase throughput and emissions based on reused spec sheet. Adding startup and shutdowl emissions 010 11WE1479 TURB.2 Solar TauNS 70 Turbine 2.0 2.0 1.0 18.2 1.9 27.0 0.3 2.0 2.0 1.0 18.2 1.9 27.0 0.3 Modify to Moincrease throughput and emissions based on reused spec sheet. Adding startup and shutdown emissions 011 17W E00013(P.C N Two 215 bbl Produced Water Storage Tanks 0.4 0.0 0.4 0.0 DCP submitted cancellation notice 3/1912020. Emissions are based on site-sped6c flash liberation analysis 012 11WE1479 L.1 Ressudzetl Condensate Loadout 23 0.3 2.3 0.3 Modify emissions calculation basis latish increases Tram 1.9 toy but maintain same Ihrmwhout. 013 11WE1479 Fugitives 0.0 1.2 00 Revised fugugitiveemissions sonow they are APEN- reouired permicreauired. 014 014 ff WF.14:9.CN Turbine Startup/Shutdown emissions 0.0 0.0 Source submidtd',PEN to _r,.i1 sapamwy. 13.:2 nor 'nos _ ens'o De e separate unior l 1 ,,ion.; .;a. s; we, the 015 11WE1479 Turbine bbwdowns 9.5 0.2 9.5 0.2 New point 016 11WE1479 Turbine purge 1.9 0.0 1.9 0.0 New point 0n 0.0 Intl ificant activities0.7 4.20 1.1 0.2 0.7 4.2 1.1 0.2 Based on Form 102 In Aug 2019 application and spectated values provided 3/19/2020. 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 FACILITY TOTAL 4.1 4.1 0.0 2.0 38.4 647.4 1.2 80.7 177.4 4.1 4.1 0.0 2.0 38.4 41.6 1.2 60.7 9.0 VOC: Syn Minor (NANSR and OP) NOSY True Minor (NANSR and OP) CO: True Minor(PSD and OP) HAPS: Syn Minor HH: Syn Minor 4 affected Area Permitted Facility Total 4.1 4.1 0.0 2.0 37.7 642.8 1.2 5E6 177.2 4.1 4.1 0.0 2.0 37.7 37.0 1.2 59.6 E8 Excludes oaks exempt frompennit3/APENs (A) Change In Permitted Emissions 4.1 4.1 0.0 20 2.2 -12.8 1.2 20.2 Public comment Is required for syn minor NANSR limits Note 1 Total VOC Facility (At Change I Total Pe,miOed VOC Emissions (point end fugitive amiss urs (point and tool vet 42.6 Facility is eligible for GP02 because < 90 fry Prolecl emissions less then 25160 tow 11.6 Note 2 Page 1013 Printed 4/7/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name DCP Operating Company, LP County AIRS ID 123 Plant AIRS ID 9010 Facility Name Godfrey Bottom Compressor Station Emissions - uncontrolled (Ibs per year POINT(PERMIT (Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 002 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 003 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 004 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 005 11WE1479 TEG Dehy-140 mmscfd 101125 93785 2708 27895 21088 105367 132 176.1 006 15WE0147.XA.CI Fugitives 0.0 007 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 008 11WE1479.CN Pigging/Receiving Blowdowns 0.0 009 11WE1479 TURB-1 Solar Taurus 70 Turbine 434 24 4 7 80 20 39 0.3 010 11WE1479 TURB-2 Solar Taurus 70 Turbine 434 24 4 7 80 20 39 0.3 011 17WE0001.XP.CI Two 215 bbl Produced Water Storage Tanks 21 18 0.0 012 11WE1479 L-1 Pressurized Condensate Loadout 39 105 13 79 298 26 0.3 013 11WE1479 Fugitives 32 0.0 014 11WE1479.CN Turbine Startup/Shutdown emissions 0.0 015 11WE1479 Turbine blowdowns 34 26 1 5 261 2 0.2 016 11WE1479 Turbine purge 7 5 1 53 0.0 0.0 Insigificant activities 14 156 240 0.2 0.0 0.0 0.0 0.0 TOTAL(tpy) 0.4 0.0 0.0 50.6 47.0 1.4 14.0 11.0 52.8 0.1 0.0 0.0 177.4 'Total Reportable = all HAPs where uncontrolled emissions > de minimus values Red Text uncontrolled emissions < de minimus Emissions with controls (Ibs per year POINT IPERMIT 'Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) Previous FACILITY TOTAL - 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 002 11WE1479.CN Waukesha L7044O51, 1680 hp 0.0 003 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 004 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 005 11WE1479 TEG Dehy-140 mmscfd 4970 4636 134 1388 719 3523 4 7.7 006 15WE0147.XA.CI Fugitives 0.0 007 11WE1479.CN Waukesha L7044GSI, 1680 hp 0.0 2 1239010 4/7/2020 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - FIAPs Company Name DCP Operating Company, LP County AIRS ID 123 Plant AIRS ID 9010 Facility Name Godfrey Bottom Compressor Station 008 11WE1479.CN Pigging/Receiving Blowdowns 0.0 009 11WE1479 TURB-1 Solar Taurus 70 Turbine 434 24 4 7 80 20 39 0.3 010 11WE1479 TURB-2 Solar Taurus 70 Turbine 434 24 4 7 80 20 39 0.3 011 17WE0001.XP.CI Two 215 bbl Produced Water Storage Tanks 21 18 0.0 012 11WE1479 L-1 Pressurized Condensate Loadout 39 105 13 79 298 26 0.3 013 11WE1479 Fugitives 32 0.0 014 11WE1479.CN Turbine Startup/Shutdown emissions 0.0 015 11WE1479 Turbineblowdowns 34 26 1 5 261 2 0.2 016 11WE1479 Turbine purge 7 5 1 53 0.0 0.0 Insigificant activities 14 156 240 0.2 0.0 0.0 0.0 0.0 TOTAL ftpy) 0.4 0.0 0.0 2.5 2.5 0.1 0.8 0.8 1.9 0.0 0.0 0.0 9.0 3 1239010 4/7/2020 Hello