The URL can be used to link to this page

Browse Search

Home My WebLink About20163574.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 November 15, 2016 Dear Sir or Madam: On November 17, 2016, the Air Pollution Control Division will begin a 30 -day public notice period for Discovery DJ Services LLC - Discovery Fort Lupton Plant. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 1;c RN Q L& ) It(ag1t(o 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer Gc:PLCnrtmlTP), t-lLCPQ,), Pr�ICtR/CH/zTM/0c) /c91/ (Q) 2016-3574 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Discovery DJ Services LLC - Discovery Fort Lupton Plant - Weld County Notice Period Begins: November 17, 2016 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Discovery DJ Services LLC Facility: Discovery Fort Lupton Plant Natural Gas Processing Facility Section 11, Township 1N, Range 66W Weld County The proposed project or activity is as follows: Discovery DJ Services LLC is requesting permit coverage for the proposed installation of a new natural gas processing plant in the ozone non -attainment area. The proposed sources at this facility include six (6) natural gas fired reciprocating internal combustion engines, compressor blowdowns, compresssor rod packing emissions, two (2) ethylene glycol dehydration units, fugitive component leaks, a plant wide enclosed flare, hydrocarbon liquid loadout and condensate storage tanks. 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 16WE0773 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 wilt receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Harrison Slaughter Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us COLORADO 1 I A kUF . m. x3fxal Colorado Air Permitting Project Version No. 1.00 Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information Harrison Slaughter 349866 6/13/2016 9/9/2016 Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: Type of Facility: What industry segment? Is this facility located in a NAAQS non -attainment area? Yes If yes, for what pollutant? ❑ Carbon Monoxide (CO) ❑ Particulate Matter (PM) Discovery Di Services LLC 123 9E99 Discovery Fort Lupton Plant Section 11, Township 1N, Range 66W Natural Gas Processg Plant 00, qcNattirat Gas Production & Processcn Section 02 - Emissions Units In Permit Application ❑� Ozone (NOx & VOC) AIRs Point # Emissions Source Type Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 ` Natural Gas - RICE Yes;:. 16WE0773 1 Permit Initial -' . Yes Issuance ..:. 002 ._ Natural Gas RICE Yes 16WE0773 1 Permit Initial..; Yes . , Issuance 003 Natural GaSRICE Yes 16WE0773 1 Permit Initial :~ Yes Issuuaa( 004 Natural Gas RICE ".. Yes 16WE0773 1 Pehilit Niliia ;..: Yes Issuance 005 MaintenanceBludowns , No 16WE0773 1 Perri Initial Compressor . Yes issuance Slowdowns 006 tither•(Explain); d,. , Nkt,„: 16WE0773 1 et Initial Compressor Rod Yes; tss ce.. Packing (Fugitive) 007 IGG'Deh rator Yes 16WE0773 1 Permit Initial,, `les Issuance' 008 a drato Yes ; 16WE0773 1 Permit Initial � rrce Yes,.. :. Issue4. 009 r Fugitive Compo tent Leaks .. No 16WE0773 1 Pet it Initial 010 Conderisata storage Tank. Yes„ ., :. 16WE0773 1 t'g',ermit.initiai;, Yes Issuance 011 IaturalGasRICE Yes: :_ 16WE0773' 1 Perrrrll Initial Yes .. rI uance, 012 NaturallGas RI Yes : ', 16WE0773 1 Peri it initial Yes Is ahce 013 Process Pyre M1 : No 16WE0773 1 Emissions control Permit Initial, ' device for points 007- Yes Issuance - 008 and 010. 014 H drorarbon l icptrt rd loading ` No 16WE0773 1 Permit Initial Yes Issua Ice "' Section 03 - Description of Project Discovery DJ Services LLC is requesting permit coverage for the proposed installation of a new natural gas processing plant in the ozone non - attainment area. The proposed sources at this facility include six (6) natural gasfired reciprocating internalcombustion engines, compressor blowdowns, compresssor rod packing emissions, two (2) ethylene glycol dehydration units, fugitive component leaks, a plant wide enclosed flare,, hydrocarbon liquid loadout and condensate storage tanks. A facility wide perrnit will be issed to cover these sources. Public comment will -be required fnr this irro haraeieamaw c ,nthatir minnr:m,mieeinn limite arm, actahlichari in tha normit and narmittari. VrlC amiecinne ara.vraator than lc.Mal Colorado Air Permitting Project Version No. 1.00 IUl 11113 JUUl VC IJCtOUDc I lCW 3y1 Ill lCUl. II C1+.IIJJ+U1 I 11111+0 alc CJLGUl13h1CU 211 U1C. IJC+lill,. P1 +U 1JC6+111LLCU- V V4 Cl C g1COLC+ C+ +Q+1 L.J Cpy._ Section 04 - Public Comment Requirments Is Public Comment Required? If yes, why?" Requesting Synthe Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required?2 If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. e Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, explain what programs and which pollutants here: Title V Operating Permits (OP) : VOC, CO, Formaldehyde, Benzene, n -Hexane and Total l4APs Non -Attainment New Source Review (NANSR): VOC Is this stationary source a major source? If yes, explain what programs and which pollutants here: Stationary source is classified as synthetic minor as described above. Section 01 - Adminstrative Information Facility AIRS ID: 123 9899 '. 001-004x:': County Plant Point Points 001-004 cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions are identical from each. Section 02 - Equipment Description Details One (2) Caterpillar Model:035168 SN:TBO natural gas fired, turbocharged, 451B reciprocating Internal combustion engine, site rated at 1,380 HP and 1400 RPM. This engine Detailed Emissions Unit will be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is Description: used for natural gas compression. Emission Control Device Description: Requested VOC Control Efficiency %: Requested CO Control Efficiency %: Requested HCHO Control Efficiency %: This engine is equipped with car oxidation catalyst and air -fuel ratio co 111/: Engine Manufacture Date: Manufacturer: Model Number: Serial Number: RPM: Site -rated RPM: Engine Function CaterpiBarl. 93516$ 0 1 berating Mfg's Max. Rated Horsepower @ sea level: 1380 Horsepower used for calcuations: 1380 BSCF @ 100% Load (btu/hp-hr): 7301 Site - Rated BSCF @ 100% load (btu/hp-hr): 7301 Other Parameters Engine Type Aspiration Electrical Generator Max Site Rating (kw) 0 Max hrs/yr of Operation 8760'. Section 03 - Processing Rate Information for Emissions Estimates Fuel Use Rate @ 100% Load 9166.666667 scf/hr ACTUAL Annual Fuel Consumption O MMscf/yr MAX POTENTIAL Annual Fuel Consumption 80.237 MMscf/yr REQUESTED Annual Fuel Consumption 80.300 MMscf/yr Fuel Heating Value -11001. btu/scf Section 04 - Emissions Factors & Methodologies Since this is a new facility, actual fuel consumption data is not available. Requested fuel consumption rounded up. Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source NOx CO 2430 VOC 0.480 PMc s 9.987E-03 PMto 9.987E-03 SO2 5.880E-04 Formaldehyde 5.280E-02 0.500 g/hp-hr 6.65 tpy 6.65 tpy Manufacturer 0.501 g/hp-hr 32.38 tpy 6.66 tpy Manufacturer'. 0.480 g/hp-hr 6.38 tpy 6.38 tpy Manufacturer 9.987E-03 lb/MMBTU 0.44 tpy 0.44 tpy 4P-42 Chapter 3 Table 3.2-2 9.987E-03 lb/MMBTU 0.44 tpy 0.44 tpy AP -42 Chapter 3 Table 3.2-2 5.880E-04 Ib/MMBTU 0.03 tpy 0.03 tpy AR42 Chapter 3 Table 3.2-2 3.421E-02 Ib/MMBTU 4663.82 lb/yr 3022.16 lb/yr AP -42 Chapter. 3 Table 3.2-2 1.749E-01 16WE0773.CP1.xlsm Acetaldehyde 8.360E-03 8.360E-03 Ib/MMBTU 738.44 lb/yr 738.44 lb/yrAP-42Chaptef. 3 Table 3.2 2 Acrolein 5.140E-03 5.140E-03 lb/MMBTU 454.02 lb/yr 454.02 lb/yr AP -42 chapter 3Table 3.2-2': Methanol 2.500E-03 2.500E-03 Ib/MMBTU 220.83 lb/yr 220.83 lb/yr RP -A3 e Chaptr 3 Table 3.2.2 Benzene 4.400E-04 4.400E-04 Ib/MMBTU 38.87 lb/yr 38.87 lb/yr AA -42 Chapter 3 Table 3.2.2'; Toluene 4.080E-04 4.080E-04 Ib/MMBTU 36.04 lb/yr 36.04 lb/yr Chapter 3Tabl 3 Table 3.2.2;: Ethylbenzene 3.970E-05 3.970E-05 Ib/MMBTU 351 lb/yr 3.51 lb/yr AP.42 ,Chaptef, 3Table3.2.2"'. Xylene 1.840E-04 1.840E-04 lb/MMBTU 16.25 lb/yr 16.25 lb/yr AP-42 Chapter Table 12-2 n -Hexane 1.110E-03 1.110E-03 Ib/MMBTU 98.05 lb/yr 98.05 lb/yr AP"12Chapter 3 Table 3.2 2'+` 2,2,4-TMP 2.500E-04 .�� 2.500E-04 Ib/MMBTU 22.08 lb/yr 22.08 lb/yrChapter. 3 Tablel. Z 2'. 1,3 -Butadiene 2.670E-04 4. 2.670E-04 lb/MMBTU 23.58 lb/yr 23.58 lb/yr AP -42 chapter 3 Table 3.2-2 0.027686 0.017022 0.008279 16WE0773.CP1.xlsm Regulatory Requirements Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2 Section I.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 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. Regulation 3 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 and NOx. 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.13.2.a) Regulation 7 Section XVI.B: These engines have a design rate greater than 500HP (reported as 1380HP) and are located in the ozone non -attainment area. As a result, the engines are subject to the air pollution control technology requirements of Section XVI.B.2 for lean burn engines. The APENs submitted indicate the engines are equipped with an Air/fuel ratio controller and an oxidation catalyst to control emissions. As such, the engines are complying with this part of the regulation. Section XVII.E: According to Regulation 7 Section XVII.B.5: "internal combustion engines that are subject to an emissions control requirement in a federal maximum achievable control technology ("MAR") standard under 40 CFR Part 63, a Best Available Control Technology ('BACT") limit, or a New Source Performance Standard ("NSPS") under 40 CFR Part 60 are not subject to Section XVII., except for the leak detection and repair requirements in Section XVII.F." These engines are subject to MACT ZZZZ and NSPS JJJJ. As a result, they are not subject to the requirements of Regulation 7 Section XVII.E. MACT 7777 The engines at this facility are subject to MACT ZZZZ. The facility is an area source of HAPs, so engine is not subject to major source requirements. Since this engine is located at an area source of HAP emissions and commenced construction after June 12, 2006, it is classified as a "New Stationary Rice." According to §63.6590)c(: "An affected source that meets any of the criteria in paragraphs (c)(1) through (7) of this section must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart IIII, for compression ignition engines or 40 CFR part 60 subpart JJJJ, for spark ignition engines. No further requirements apply for such engines under this part. This engine meets the criteria of §63.6590(c)(1) "A new or reconstructed stationary RICE located at an area source." As such, it will meet the requirements of MACT ZZZ2 by meeting the requirements of NSPS JUL NSPS JJJJ Is this engine subject to NSPS JJJJ? I I, -- Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Additional Notest 1. An initial compliance test for each of these engines will be required for the following reasons: (I) The engines have a contr ai device and a -name -plate rating greater than 500 HP; (if) The = facility is synthetic minor for CO; and (iii) Thefacility is synthetic minor for formaldehyde. This initial compliance test is consistent -with the requirementsin the general permit 02 for natural gas fired reciprocating internal:combustion eegines. - - 16WE0773.CP1.xlsm AIRS (County/Plant) 123/9E99 Permit No. 16WE0773 Date 9/9/2016 Point # SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)* Controlled Requested Emissions (tp))* PTE (tpy)* Ctrl. Eff% NCRP = reportable ? 001 20200254 NOx 1.5098E-01 Ib/MMBTL Manufacturer 6.65 6.65 0% Yes 001 20200254 CO 7.3377E-01 lb/MMBTL Manufacturer 6.66 32.38 79.4% Yes 001 20200254 VOC 1.4494E-01 Ib/MMBTL Manufacturer 6.38 6.38 0% Yes 001 20200254 PM25 9.9871E-03 Ib/MMBTL AP -42 0.44 0.44 0% No 001 20200254 PM10 9.9871E-03 lb/MMBTL AP -42 0.44 0.44 0% No 001 20200254 SO2 5.8800E-04 lb/MMBTL AP -42 0.03 0.03 0% No 001 20200254 Formaldehyde 5.2800E-02 Ib/MMBTL AP -42 3023.00 4664.00 35.2% Yes 001 20200254 Acetaldehyde 8.3600E-03lb/MMBTL AP -42 739.00 739.00 0% Yes 001 20200254 Acrolein 5.1400E-03lb/MMBTL AP -42 453.66 453.66 0% Yes 001 20200254 Methanol 2.5000E-03 Ib/MMBTL AP -42 220.65 220.65 0% No 001 20200254 Benzene 4.4000E-04 Ib/MMBTU AP -42 38.83 38.83 0% No 001 20200254 Toluene 4.0800E-04 Ib/MMBTL AP -42 36.01 36.01 0% No 001 20200254 Ethylbenzene 3.9700E-05 lb/MMBTL AP -42 3.50 3.50 0% No 001 20200254 Xylene 1.8400E-04lb/MMBTL AP -42 16.24 16.24 0% No 001 20200254 n -Hexane 1.1100E-03 Ib/MMBTL AP -42 97.97 97.97 0% No 001 20200254 2,2,4-TMP 2.5000E-04 lb/MMBTLAP-42 22.07 22.07 0% No 001 20200254 1,3 -Butadiene 2.6700E-04 Ib/MMBTL AP -42 23.57 23.57 0% No "HAP emissions have units of lbs/year. 002 20200254 NOx 1.5098E-01 lb/MMBTL Manufacturer 6.65 6.65 0% Yes 002 20200254 CO 7.3377E-01 Ib/MMBTL Manufacturer 6.66 32.38 79.4% Yes 002 20200254 VOC 1.4494E-01 Ib/MMBTU Manufacturer 6.38 6.38 0% Yes 002 20200254 PM2.5 9.9871E-03Ib/MMBTUAP-42 0.44 0.44 0% No 002 20200254 PM10 9.9871E-03lb/MMBTL AP -42 0.44 0.44 0% No 002 20200254 SO2 5.8800E-04 lb/MMBTLAP-42 0.03 0.03 0% No 002 20200254 Formaldehyde 5.2800E-02 lb/MMBTL AP -42 3023.00 4664.00 35.2% Yes 002 20200254 Acetaldehyde 8.3600E-03Ib/MMBTLAP-42 739.00 739.00 0% Yes 002 20200254 Acrolein 5.1400E-03 Ib/MMBTL AP -42 453.66 453.66 0% Yes 002 20200254 Methanol 2.5000E-03 Ib/MMBTL AP -42 220.65 220.65 0% No 002 20200254 Benzene 4.4000E-04 Ib/MMBTL AP -42 38.83 38.83 0% No 002 20200254 Toluene 4.0800E-04Ib/MMBTUAP-42 36.01 36.01 0% No 002 20200254 Ethylbenzene 3.9700E-05 Ib/MMBTL AP -42 3.50 3.50 0% No 002 20200254 Xylene 1.8400E-04 Ib/MMBTU AP -42 16.24 16.24 0% No 002 20200254 n -Hexane 1.1100E-03 lb/MMBTU AP -42 97.97 97.97 0% No 002 20200254 2,2,4-TMP 2.5000E-04 lb/MMBTL AP -42 22.07 22.07 0% No 002 20200254 1,3 -Butadiene 2.6700E-04 lb/MMBTL AP -42 23.57 23.57 0% No **HAP emissions have units of lbs/year. 003 20200254 NOx 1.5098E-01 lb/MMBTL Manufacturer 6.65 6.65 0% Yes 003 20200254 CO 7.3377E-01 lb/MMBTL Manufacturer 6.66 32.38 79.4% Yes 003 20200254 VOC 1.4494E-01 Ib/MMBTL Manufacturer 6.38 6.38 0% Yes 003 20200254 PM2.5 9.9871E-03Ib/MMBTUAP-42 0.44 0.44 0% No 003 20200254 PM10 9.9871E-03Ib/MMBTUAP-42 0.44 0.44 0% No 003 20200254 SO2 5.8800E-04 Ib/MMBTU AP -42 0.03 0.03 0% No 003 20200254 Formaldehyde 5.2800E-02 lb/MMBTL AP -42 3023.00 4664.00 35.2% Yes 003 20200254 Acetaldehyde 8.3600E-03lb/MMBTL AP -42 739.00 739.00 0% Yes 003 20200254 Acrolein 5.1400E-03 lb/MMBTL AP -42 453.66 453.66 0% Yes 003 20200254 Methanol 2.5000E-03Ib/MMBTLAP-42 220.65 220.65 0% No 003 20200254 Benzene 4.4000E-04 lb/MMBTL AP -42 38.83 38.83 0% No 003 20200254 Toluene 4.0800E-04lb/MMBTL AP -42 36.01 36.01 0% No 003 20200254 Ethylbenzene 3.9700E-05 lb/MMBTLAP-42 3.50 3.50 0% No 003 20200254 Xylene 1.8400E-04 lb/MMBTUAP-42 16.24 16.24 0% No 003 20200254 n -Hexane 1.1100E-03 lb/MMBTU AP -42 97.97 97.97 0% No 003 20200254 2,2,4-TMP 2.5000E-04Ib/MMBTU AP -42 22.07 22.07 0% No 003 20200254 1,3 -Butadiene 2.6700E-04 Ib/MMBTU AP -42 23.57 23.57 0% No **HAP emissions have units of lbs/year. 004 20200254 NOx 1.5098E-01 Ib/MMBTU Manufacturer 6.65 6.65 0% Yes 004 20200254 CO 7.3377E-01 Ib/MMBTU Manufacturer 6.66 32.38 79.4% Yes 004 20200254 VOC 1.4494E-01 Ib/MMBTL Manufacturer 6.38 6.38 0% Yes 004 20200254 PM25 9.9871E-03lb/MMBTL AP -42 0.44 0.44 0% No 004 20200254 PM10 9.9871E-03Ib/MMBTLAP-42 0.44 0.44 0% No 004 20200254 SO2 5.8800E-04Ib/MMBTUAP-42 0.03 0.03 0% No 004 20200254 Formaldehyde 5.2800E-02 Ib/MMBTU AP -42 3023.00 4664:00 35.2% Yes 004 20200254 Acetaldehyde 8.3600E-03 Ib/MMBTU AP -42 739.00 739.00 0% Yes 004 20200254 Acrolein 5.1400E-03 Ib/MMBTU AP -42 453.66 453.66 0% Yes 004 20200254 Methanol 2.5000E-03 Ib/MMBTL AP -42 220.65 220.65 0% No 004 20200254 Benzene 4.4000E-04 Ib/MMBTL AP -42 38.83 38.83 0% No 004 20200254 Toluene 4.0800E-04lb/MMBTL AP -42 36.01 36.01 0% No 004 20200254 Ethylbenzene 3.9700E-05lb/MMBTL AP -42 3.50 3.50 0% No 004 20200254 Xylene 1.8400E-04 lb/MMBTLAP-42 16.24 16.24 0% No 004 20200254 n -Hexane 1.1100E-03 Ib/MMBTU AP -42 97.97 97.97 0% No 004 20200254 2,2,4-TMP 2.5000E-04 lb/MMBTUAP-42 22.07 22.07 0% No 004 20200254 1,3 -Butadiene 2.6700E-04 Ib/MMBTU AP -42 23.57 23.57 0% No "HAP emissions have units of lbs/year. I - Section 01 - Adminstrative Information Facility AIRs ID: 123 9E99 005 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Natural gas venting from compressor blowdowns. Emissions from this Source arevented to the Description: Emission Control Device Emissions from this source are not controlled. Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Compressor Blowdown Volume= 4.20E-03! MMscf Requested Compressor Blowdown Events= Actual Compressor Blowdown Events= Actual Gas Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = 144 events/year 0 events/year 0 MMscf per year 6.05E-01 MMscf per year 6.05E-01 MMscf per year Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex=O*MW*XX/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas • MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (0) MW 6.05E-01 MMscf/yr Ib/Ib-mol 6.90E+01 scf/Yr MMscf/d 22.9 0001656986 mole % MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0:00 4.#1624: 0.000 0.000 0.00 0.00 0.00 CO2 0.48 44,01 0.652 0.028 0.12 1039.69 0.52 N2 0.56 28.013'. 0.158 0.007 0.03 251.63 0.13 methane 70.73 16.641', 11.346 0.496 2.07 18105.66 9.05 ethane 15.37 30.063'. 4.620 0.202 0.84 7372.15 3.69 propane 7,60 44.092'. 3.351 0.146 0.61 5346.67 2.67 isobutane 0.84 58.1181 0.485 0.021 0.09 774.41 0.39 n -butane 2.52 X118 1.231 0.054 0.22 1965.14 0.98 isopentane 0.39 72.114 0.282 0.012 0.05 450.30 0.23 n -pentane 0.34 72.114 0.283 0.012 0.05 451.80 0.23 cyclopentane 0.00'. 70.13 0.000 0.000 0.00 0.00 0.00 n -Hexane 0.07 86.18. 0.064 0.003 0.01 102.18 0.05 cyclohexane 0.00 84.16. 0.000 0.000 0.00 0.00 0.00 Other hexanes 0.17 86!18'. 0.149 0.007 0.03 238.47 0.12 heptanes 0.16. 100.21. 0.156 0.007 0.03 249.46 0.12 methylcyclohexane 0.00 98.19 0.000 0,000 0.00 0.00 0.00 224-TMP 0.02 114,23 0.023 0.001 0.00 36.46 0.02 Benzene 0.03 78.12. 0.024 0.001 0.00 37.52 0.02 Toluene 0.02, 92.15'. 0.016 0.001 0.00 25.59 0.01 Ethylbenzene 0.00 106.17 0.004 0.000 0.00 6.61 0.00 Xylenes 0.01 106.17 0.011 0.000 0.00 17.28 0.01 C8+ Heavies 0.1341 114 0.042 0.002 0.01 66.58 0.03 VOC mass fractio MW 22.896 Notes 0.2674 Total VOC (Uncontrolled) 4.88 Mole %, MW, and mass fractions are based on a representative gas sample collected from the Sharp 24-3-11 HC well operated by Ward Petroluem. This sample was obtained on 01/23/2015. Emissions are based on 144 compressor blowdown events per year.' The MW of C8+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 67.84 lb/event 67.84 lb/event 4.88 tpy 4.88 tpy Gas Analysis Benzene 0.261 lb/event 0.261 lb/event 37.5 lb/yr 37.5 lb/yr Mass Balance Toluene 0.178 lb/event 0.178 lb/event 25.59 lb/yr 25.59 lb/yr Mass Balance Ethylbenzene 0.046 lb/event 0.046 lb/event 6.61 lb/yr 6.61 lb/yr Mass Balance Xylenes 0.120 lb/event 0.120 lb/event 17.28 lb/yr 17.28 lb/yr Mass Balance n -Hexane 0.710 lb/event 0.710 lb/event 102.18 lb/yr 102.18 lb/yr Mass Balance 2,2,4-TMP 0.253 lb/event 0.253 lb/event 36.46 lb/yr 36.46 lb/yr Mass Balance Section 06 - Regulatory Summary Analysis 16WE0773.CP1.xlsm AQCC Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." Section 07 Technical Analysis Notes 1. The operator expressed that the compressorvolumewascalculatedbased i rie compressor. on thepipingand-instrumentationdiagramsfortheArieiJGE42. The operator specifications for the Ariel JGE4-2 compressor but expressedthatthe volume used in this application is consistent other applications submitted in Wyoming in the past. I confirmed this assertion by referencing the permit application for the Clarkelen Central Compressor Station (2016) in Wyoming, which contains identical calculations for compressor [slowdowns. In this application the tompressor volume was calculated and then converted to standard conditions. After reviewof the calculations, I determined the calculated volume was a reasonable estimate and acceptable for permitting purposes. - - - 2. The operator expressed that to demonstrate compliance with blowdown permit limits, each blowdown event will be recorded and emissions will be estimated by multiplying thnumber of events by the emission factor provided in the notes to permit holder (lb/event). This supports the use of an event basis for the process limit contained in the permit. 16WE0773.CP1.xlsm AIRS (County/Plant) 123/9E99 Permit No. 16WE0773 Date 9/9/2016 Point # SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)" Controlled Requested Emissions (tpy)" PTE (tpy)" Ctrl. Eff% NCRP = reportable ? 005 31000203 VOC 16151.56 lb/MMscf Gas Analysis 4.9 4.9 0% Yes 005 31000203 Benzene 62.04 lb/MMscf Gas Analysis 38 38 0% No 005 31000203 Toluene 42.31 lb/MMscf Gas Analysis 26 26 0% No 005 31000203 Ethylbenzene 10.93 lb/MMscf Gas Analysis 7 7 0% No 005 31000203 Xylenes 28.57 lb/MMscf Gas Analysis 18 18 0% No 005 31000203 n -Hexane 168.95 lb/MMscf Gas Analysis 103 103 0% No 005 31000203 2,2,4-TMP 60.28 Ib/MMscf Gas Analysis 37 37 0% No *HAP Emissions have units of lbs/year SCC code is for compressors in natural gas production. Section 01- Adminstrative Information Facility AIRS ID: 123 9099: 006 County Plant Point Section 02 - Eauipment Description Details Detailed Emissions Unit Natural gas venting from compressor rod packing. 0missipnsfrdm this source are vented to the Description: atmosphere. - Emission Control Device Emissions from this source are not controlled. Description: Requested Overall VOC & HAP Control Efficiency %: 0 Compressor rod packing vent rate= Number of compressors= Actual rod packing vent rate= Actual Gas Vent Rate = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = 50 scf/hr 6 0 scf/hr 0 MMscf per year 2.628 MMscf per year 2.628 MMscf per year Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex =Q*MW*Xx/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas . MW of air Xx = mass fraction of x in gas C= molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (Q) MW 2.63E+00 MMscf/yr Ib/Ib-mol 3.00E+02 scf/yr MMscf/d 22.9 0.0072 mole % MW Ibx/Ibmol 4.0026 mass fraction lb/hr lb/yr tpy 0.00 Helium 0,00 0.000 0.000 0.00 0.00 CO2 44.01. 0.652 0.028 0.52 4517.69 2.26 N2 methane 0.56 28,013' 0.158 0.007 0.12 1093.39 0.55 70.73 15.37. 11.346 0.496 8.98 78673.41 39.34 ethane 30.063.. 44.092'.. 4.620 0.202 3.66 32033.73 16.02 propane isobutane 7.60 f.84 2₹ 0. 0.39 3.351 0.146 2.65 23232.54 11.62 118' 0.485 0.021 0.38 3364.99 1.68 n -butane 5&118' 72.114 72.114 1.231 0.054 0.97 8539.01 4.27 isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes 0.282 0.012 0.22 1956.66 0.98 0.283 0.012 0.22 1963.16 0.98 0. 0. MOO 70.13 86.18 0.000 0.064 0.000 0.000 0.00 0.00 0.00 0.002797 0.05 0.00 444.00 0.22 0.00 0.000 0.00 R1 0,16' 0. 002 36.18: 0.149 0.007 0.12 1036.20 0.52 heptanes methylcyclohexane 224-TMP 21 19 0.156 0.000 0.023 0.007 0.000 0.001 0.12 0.00 0.02 1083.98 0.54 0.00 0.00 158.42 0.08 Benzene Toluene Ethylbenzene Xylenes C8+ Heavies VOC mass fractio MW 22.896 12 0.024 0.001 0.02 163.05 0.08 402 0.016 0.001 0.01 111.18 0.06 .:1:....,,.0.00 0.004 0.000 0.00 28.71 0.01 0.0. 0.04 7 0.011 0.000 0.002 0.01 75.09 0.04 114 0.042 0.03 289.32 0.14 Notes 0.2674 Total VOC (Uncontrolled) 21.22 Mole %, MW, and mass fractions are based on a representative gas sample collected from the Sharp 24-3-11 HC well operated by Ward Petroluem. This sample was obtained on 01/23/2015. Emissions are based on a total of 6 compressors each with an assumed vent rate of 50 scf/hr. The MW of C8+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable. Section 05 - Emissions Inventory Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 16151.56 lb/MMscf 16151.56 lb/MMscf 21.22 tpy 21.22 tpy Gas Analysis Benzene 62.043 lb/MMscf 62.043 lb/MMscf 163.05 lb/yr 163.05 lb/yr Mass Balance Toluene 42.306 lb/MMscf 42.306 lb/MMscf 111.18 lb/yr 111.18 lb/yr Mass Balance Ethyl benzene 10.925 lb/MMscf 10.925 lb/MMscf 28.71 lb/yr 28.71 lb/yr Mass Balance Xylenes 28.573 lb/MMscf 28.573 lb/MMscf 75.09 lb/yr 75.09 lb/yr Mass Balance n -Hexane 168.949 lb/MMscf 168.949 lb/MMscf 444.00 lb/yr 444.00 lb/yr Mass Balance 2,2,4-TMP 60.280 lb/MMscf 60.280 lb/MMscf 158.42 lb/yr 158.42 lb/yr Mass Balance Section 06 - Regulatory Summary Analysis 16WE0773.CP1.xlsm AQCC Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." AQCC Regulation 3 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.a) Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT 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 fugitives will be in service after the date above, this source is considered "new or modified." This source is subject to the reciprocating compressor requirements of NSPS 0OOOa, which requires replacement of compressor rod packing at specified intervals. These requirements satisfy the RACT requirements under Regulation 3. Regulation 6 Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? Yes Did this source commence construction, reconstruction, or modification after January 20, 1984, and on or before August 23, 2011? No This source is not subject to NSPS KKK because the facility will commence construction after August 23, 2011. Did this source commences construction, reconstruction, or modification after August 23, 2011 and on or before September 18, 2015? No Source is not subject to NSPS 0000 because this Is a new that facility will commence construction after September 18, 2015. Regulation 7: Section XII: Is this source located in an ozone non -attainment area or attainment maintenance area? Yes Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? Yes Facility is located in the non -attainment area and classified as a natural gas processing plant. Therefore, this source is subject to Regulation 7 Section XII.G. Section XVII: Is the reciprocating compressor located at a natural gas compressor station? No The reciprocating compressors are located at a natural gas processing plant and are therefore not subject to Regulation 7 Section XVII.B.3.c. Regulation 8 Is this source at a "natural gas processing plant" as defined in 40 CFR, Part 63.761? Yes Is this facility considered a "major source" of HAP as specifically defined in 40 CFR, Part 63.761 for sites that are not prodcution field facilities? No Source is not subject to MACT HH because the facility is classified as a synthetic minor source of HAPs. NSPS 0OOOa Did this source commence construction, reconstruction, or modification after September 18, 2015? Yes Is this source at a well site, compressor station or onshore "natural gas processing plant" as defined in 40 CFR, Part 60.5430a? Yes This facility meets the definition of onshore "natural gas processing plant" as defined by 40 CFR, Part 60.5430a. Therefore, the emissions of this source are subject to the reciprocating compressor affected facility requirements under §60.5385a of NSPS OOOOa. Since NSPS OOOOa has not been adopted by the State of Colorado, the requirements will be referenced in the notes to permit holder. Section 07 - Technical Analysis Notes 1..- According to the application, the "compressor rod packing seals leak a small amount of gas almost continuously at very low pressures making this type of emission source very difficult to apply any type of emission control-.' The NSPS 0000 backrgound technical support document reviewed the following control techniques for limiting the leaking of natural gas past the piston rod packing: (I) Replacement of compressor rod packing, (ii) Replacement of the piston rod, and (III) Refitting or realignment of the pistor rod, This supports the operator`scfaim that. _.. the emissions from this source would be difficult- to route to an -add-on control device (i.e. combustor-VRU, etc). Based on this information, along with the definition of fugitive emissions in the this emission source wouldthe, -C:otorada:Cammon Provisions, .Fdetermirtedresult, applicable NSPS OOOOa compressor packingevery requirements this source. replace the reciprocating rod cki 26,000.hours:ar3f�montFrswasdeterminedtgheanaueptab[emechanismforminimizingtheemissionsfmmthissautde. -- 2. According to the Natural gas STAR lessons learned document "Reducing Methane Emissions from Compressor Rod Packing Systems," leakage typically occurs from four areas: (i) Around = the packing case through the nose gasket. (fi) Between =the packing cups, which are typically mounted metal -to -metal against each other. (iii)Around-therings, from ' slight movement in the cup groove as the rod moves back and forth. (iv) BetWeen the rings andshaft. "This indicates _new packing 11 to 12 standard cubic feet per hour(scfh(." 3. Typically rod packing emissions associated with compressors are accounted for with the "other" category under the fugitive emission source at a facility. This is supported by note "C" '-.under Table 2-4 of the EPA Protocol forEquipment Leak Emission Estimates (EPA -453/R-95-017) which states "The 'other' equipment type was derived from compressors, diaphrazns, drains, -_ dump arms, hatches, instruments, meters,polished packing ,emission -factor -of pressure relief valves, o8shad rods, relief valves, and venter "!f this method were _usad to estimate rod in emissions, an 0:0088 kg/hr-source would be utilized. Using this value along with six (6) compressors and a VOC weight fraction of 0.2673, the VOC emissions were estimated to be 0.14 tpy. As such, the operator estimated value of 21.22 tpy of VOC is a conservative estimate of emissions. Further, the NSPS 0000 technical support document estimates baseline emissions of VOC from - reciprocating compressorsin the gatheringand boosting industry and gas processing industry segment at 3.42 ton/compressor-year and 6.48 ton/compressor-year respectively, These values scale to 20.52tpyand- 38.88 tpy with six compressors. Thus the operator estimated value is within this range. - - 4. As discussed above, this facility is subject to NSPS 00OOa. However,this federal regulation has not in the notes to permit holder. 5. As determined above, this facility is subject to, regulation :7 Section XIl.G. This regulation indicates the facility must allow NSPS KICK to demonstrate compliance_.Smce this facility is, subject to more stringent equirements under NSPS 0000ait was determined that following the requirements of tails 0000a would satisfy the requirements of Regulation 7 Section M.G. =j The conditionin the permit referencing Regulation 7 Section Xll.G will indicate that by meetingthe requirements of NSPS OO0Oa, the so irse will be in compliance. > ": 6 The operator confirmed that each of the compressors at this facility will be classified asredprotatibg compressors. en adopted into Colorado state regulation. As such, this regulatio 16WE0773.CP1.xlsm 7. Colorado Regulation 7 SectionsXI1.G.1 requires the source to comply the leak detection andrepair program (LOAR) Per : NSPS KKK for the fugitive VOC emissions at the facility. However, this source is subject to NSPS O00Oa based on the construction date of the facility; This federal regulation is more stringent as compared to NSPS; KKK. As a result, I determined the source would demonstrate compliance with Regulation 7 Section;XlI,G.1 by complying with NSPS 00OOa. The permit will contain an appropriate condition pertaining, to thiscletermination. €urther„ it was determined unnecessary for the source to comply with two different WAR programs when ane Rrogrem (NSPS OOOOat is mare stringent than the other (NSPS KKK), 16WE0773.CP1.xlsm AIRS (County/Plant) 123/9E99 Permit No. 16WE0773 Date 9/9/2016 Point # SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)' Controlled Requested Emissions (tpy)* PTE (tpy)* Ctrl. Eff% NCRP = reportable ? 006 31000309 VOC 16151.56 Ib/MMscf Gas Analysis 21.3 21.3 0% Yes 006 31000309 Benzene 62.04 lb/MMscf Gas Analysis 163 163 0% No 006 31000309 Toluene 42.31 Ib/MMscf Gas Analysis 112 112 0% No 006 31000309 Ethylbenzene 10.93lb/MMscf Gas Analysis 29 29 0% No 006 31000309 Xylenes 28.57 lb/MMscf Gas Analysis 75 75 0% No 006 31000309 n -Hexane 168.95 lb/MMscf Gas Analysis 444 444 0% Yes 006 31000309 2,2,4-TMP 60.28 lb/MMscf Gas Analysis 159 159 0% No **HAPS have units of lbs/year SCC Code is for compressor seals Section 01 - Adminstrative Information 'Facility AIRS ID: 'Emissions for points 007-008 were estimated through the same method. As such, this spreadsheet provides an aneiysis for each EG dehydration unit as emissions are !dental from each. Section 02 - Equipment Description Details 123 BE99 007.008. Plant Point Detailed Emissions Unit Description: One (1) Baffles Ethylene Glycol (EG) natural pa dehydration unit (Model & Serial Number-TBD) with N desisscepecily of 20 MMsd per d.y.ThIo arnissi000 aeB Iu.elsdpp.d with on. (1)g.e.pypw pump (Make, Modal, Sits TOD) with design capacity of 7-.5 p1t.,. wrminufe. Thls urdtts egulpped:.watha rebolee.stIB Welt end*** tank. Emtssia.a from tire s68..rttern ropt.d too rood.nsw and than to en .nelos.d flare. Emissions feorathe flash took are used es fo.I pifor the rogon.retee rebaper or rnttt.dtoth..ndoaM Em scion Control Device Still V.nt.Condanser..d Enclosed flue Description: FlatBYak Recycledtor gesseratornbdlerOTanplosedHero Requested Overall VOC & HAP Control Efficiency %: 95% This control efficiency is requested for both the enclosed flare and robotics. Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Dehy Actual Gas Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Secondary Emissions - Combustion oevice(s) for Ai Pia0h'_znk ,0V,t1r1, tark was, g, hea-... _...,_ vent wa_ at content- ,.0- - heaz_.,nTent ct coat' gas= T0rl -mmme at waste 3ar r0000c Actual c.-_te0ta'aa _ rhe1cdt0 00,00000n device- -nee. of was- 701.170d tO con, 0.0000n devc_ • MMsct per year MMsct per year MMscf per year ion Contro iBt Actual Gas Throughput While Emissions Controls Operating = u Mraea 0 per y03,- 0 MMIMh- -r tinitc0 P._, hoot cwaste ,,oted.a:: on d507 - 0 Vh18T' per r Secondary emissions associated with the combustion of still vent and flash tank waste gas are accounted for under point 013. See Technical notes for more information. Section 04- Emissions Fallon & Methodologies Rebaa.r Burner Heater Design Rate 0.5 MMBtu/hr per heater Fuel Heating Value 1100 Btu/scf No. of Healers 2 Hours of Operation 8760 hr/yr Fuel Consumption 4.0 MMscf/yr per heater 0.3 MMsd/month per heater 8.0 MMscf/yr for all heaters 0.7 MMscf/month for all heaters Estimated emissions based on rating of heaters Pollutant Emission Factor Emissions lb/MMsof Source Ib/yr tpy NOx 100 AP -42 796.4 0.398 CO 84 AP -42 668.9 0.334 VOC 5.5 AP -42 43.8 - 0.022 PM Total 7.6 AP -42 60.5 0.030 002 0.6 AP -42 4.8 0.002 Formaldehyde 0.075 AP -42 0.60 0.000 Benzene 0.0021 AP -42 0.02 0.000 Toluene 0.0034 AP -42 0.03 0.000 n -Hexane 1.8 AP -42 14.33 0.007 Total HAP 0.007 EG Dehydrator EXEMPT PER REG 3, PART A, II -D -1-K: <5 MMBtu/hr The reboiler emissions are auount.d for in the APEN exempt portion of the facility wide inventory and history file (123909! The source used ProMax 4.0 to estimate emissions. Wet gas composition, pressure and temperature are based on a representative extended wet gas analyses collected 01/23/2015. The model was based on the following parameters: Inlet Gas Pressure Inlet Gas Temperature Glycol Recirculate Rate Flash Tank Pressure Flash Tank Temperature ProMax Results (in tons oar veer) Still Vent Pollutant Uncontrolled (lb/hr) Uncontrolled (I6/yr) Uncontrolled (tpy) Controlled (Ib/hr) Controlled (Ib/yr) Controlled )tpy) Uncontrolled EF (Ib/MMsof) VOC 0.745603495 : 6,531,57 3.27 0.037280675 326.58 0.16 3.947E-01 Benzene 0.4632- 4,057.35 2.03 00231584 202.37 0.10 5.558E-01 Toluene 0.158389. 1,387 19 0.69 0.00791945 69.37 003 1.901E-01 Ethylbenzene 0.0166585'. 163.45 0.08 0000932925 9.17 0.00 3.239E-02 Xylenes 0.0525647': 723.27 0.36 0.004128235 36.16 0.02 9.9080.02 n -Hexane 7.82749305 0.69 000 3.91375E-06 0.03 000 9.393E-05 224-TMP 239465E-05;gy 0.25 0.00 1 44733E-06 001 0.00 3 474E-05 800 psig 100 °F 7.5 gpm 60 rang 90 °F 20 MMsdd 620 MMscf/month 7300 MMscf/yr 1825.0 MMscf/quarter Flash Tan Pollutant Uncontrolled (Ib/hr) Uncontrolled (Ib/yr) Uncontrolled (tpy) ( Controlled (lb/hr) Controlled (Ib/yr) Controlled (tpy) Uncontrolled EF )lb/MMsd) VOC 0.159501344 1,395 18 0.70 0.007965067 69.77 003 1.912E-01 Benzene 0.0622 19,12 0.01 0000109147 0.96 0.00 2.620E-03 Toluene 0.000499465.... : 4.32 0.00 2.46733E-05 0.22 0.00 5.922E•04 Ethylbenzene 3.808859.115 -: 0.34 0,00 1.93195E-06 0.02 0.00 4,637E-05 Xylenes 8.7(!9981-00 0.76 0.00 4.35499E-06 004 000 1045E-04 n -Hexane 0.000190119 1.67 0.00 9.50645E-06 0.08 0.00 2.282E-04 224-TMP 445528305:: 036 0.00 2.06762E-06 0.02 0.00 4.962E-05 14 of 37 K:\PA\2016\16 W E0773.CP1.xlsm Facility AIRs ID: 223 County Total Dehydrator Emissions - Still vent plus flash tank with 100% safety factor Uncontrolled Pollutant (lb/hr) (Ib/yr) (spy) (Ib/hr) (Ib/yr) GPO Uncontrolled EF (Ih/MMscf) Controlled lb/31 day VOC 1.809829677 15854.11 7.93 0.090491484 792.71 0.40 2.17 67 Benzene 0.93070188 8152.95 4.08 0.046535094 407.65 0.20 1.117 35 Toluene 0.31776493 2783.62 1.39 0.015888247 139.18 0.07 0.381 12 Ethylbenzene 0.037394278 327.57 0.16 0.001869714 16.38 0.01 0.045 1 Xylenes 0.1653036 1448.06 0.72 0.00826518 72.40 0.04 0.198 6 n -Hexane 0.000536808 4.70 0.00 2.68404E-05 0.24 0.00 0.001 0 2,2,4-trimethylpentane 0.000140598 1.23 0.00 7.02988E-06 0.06 0.00 0.000 0 Controlled emissions are based on flash tank and still vent emissions controlled by an enclosed comb star with a 95% control efficiency. Pollutant Dehydrator Uncontrolled E.F. (Ibs/MMacf) Controlled E.F )Ibs/MMscf) IIIIIMIZIWNLN.N.NA WOO MINME7MMIII%:%7%.N.N.A.N.N.'40 IIIIIMEEMMINIIMMTUICEIEWVWV 6 MEM= A:NV%:%74‘1.- Control Device Uncontrolled E.F. (lbs/MMBtu waste heat combusted) Uncontrolled E.F. )Ibs/MMscf) Emissions Factor Source Citation Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NM VOC CO 0.00E+00 0.00E+00 0.00E+00 0.0 0.0 0.00E+00 0.00E+00 0.00E+00 0.0 0.0 0.00 0.00 0.00 0.0 0.0 7.93 7.93 0.396 0.0 0.0 0.00 0.00 0.00 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tom/year) (tons/yearl Benzene Toluene Ethylbenzene Xylem n -Hexane 224 TMP 4.08E+00 4.08E+00 2.04E-01 0.00E+00 0.00E+00 1.39E+00 1.39E+00 6.96E-02 0.00E+00 0.00E+00 1.64E-01 1.64E-01 8.19E-03 0.00E+00 0.00E+00 7.24E-01 7.24E-01 3.62E-02 0.00E+00 0.00E+00 2.35E-03 2.35E-03 1.18E-04 0.00E+00 0.00E+00 6.16E-04 6.16E-04 3.08E-05 0.00E+00 0.00E+00 ...The tables above represent emissions from one dehydrator at this facility. Thera are two total dehydrators at the facility. As a result, these omissions need to be doubled to account for both dehydrators at the facility. Section 06 - Regulatory Summary Analysis lb/yr 8152.95 407.fi5 2783.62 139.18 327.57 16.38 1448.06 72.40 4.70 0.24 1.23 0.06 Regulation 1 Section IIA.1- Except as provided in paragraphs 2 through 6 below, owner r operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section 11A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 Section I.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 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. Regulation 3 Part A APEN Requirements: APEN is required since uncontrolled VOC emissions exceed 1 tpy in a non -attainment area. Part B - Construction Permit Requirements: A permit is required since facility wide actual uncontrolled VOC emissions from all APEN required points are greater than 2 Spy. Regulation 7 — Volatile Organic Compounds XII.H VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS: (i) Is Mis source located in the ozone non -attainment area? Yes (0) Are actual uncontrolled VOC emissions from the glycol natural gas dehydrator > 1 tpy? Yes (Hi) Is the sum of actual uncontrolled VOC emissions from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year? Yes Since the answer to all the above questions is yes, this source is subject to Regulation 7, Section XII.H. Uncontrolled actual emissions of volatile organic compounds front the still vent and vent from any gas-condensate-glyeol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment XVII.D STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS: (I) Per Regulation 7, Section XVI I.5 5, dehydrators subject to an emission control requirement under 40 CFR Part 63 are exempt from Section XVII. However, as discussed below in MACT NH, these dehydrators are not subject to area source requirements under MACT HH because they are classified as ethylene glycol (EG) dehydration units. Thus the dehydration units must sell be evaluated under Regulation 7 Section XVII. D. (ii) These dehydrators are subject to Section XVII.D.1 because actual uncontrolled VOC emissions from the dehydrator are greater than 2 tpy and the sum of actual uncontrolled VOC emissions from the group of dehydrators at this source are greater than 15 tpy. (iii) These dehydrators are subject to Section XII.D.3 because the dehydrators will be constructed after May 1, 2015 and uncontrolled actual VOC emissions from the dehydration unit are greater than 2 tpy. As such, emissions of hydrocarbons shall be reduced by at least 95% on a rolling twelve month basis through the use of a condenser or air pollution control equipment Regulation 8 - Control of HAP% Part E - MACE HH Since this facility is anatural gas processing facility, it does not qualify as a production field facility as defined in MAR HH. Asa result, all HAP emitting units are included when determining major source status. Total facility HAP emissions are 14.9 tpy. Thus, the site is a synthetic minor source of HAPs and is then considered an area source of HAPs per MACT HH. As specified in 63.760(6)(2), the only affected sources for area sources are TEO dehydrators. Since the dehydrators at this facility are ethylene glycol (ED) dehydration units, area source requirements under MACT HH are not applicable. Section 07 - Initial and Periodic Sampling and Testing Requirements 15 of 37 K:\PA\2016\ 16WE0773.CPt.xlsm (Facility AIRS ID: 123 County Plant 007-008. Point Does the company use a site specific extended gas analysis to estimate emissions? If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limits Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and Intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes 1. In the application, the operator expressed that emissions from the flash tank will primarily be routed to the regenerator reb oiler to beused as fuel gas. However, the emissions from the flash tank may also be routed to the enclosed combustion device used to control still vent emissions. The operator assumed a 9S% control. would be achieved with either operating scenario. Asa result it was determined unnecessary to haoe the operator tack the operation of the reboiler or the enclosed combustion device independent it should be further noted that the Division typically assumes depen ly. LYP ty 700%:, control when emissions are routed to the reboller, so assuming 95% for this operating scenario is conservative and therefore acceptable. This determination it consistent with PS Memo 15-02 which states that it "the operator determines both the primary and backup nntsusicnn control device will achieve the same control efficiency then th.epermit will not likely need to reflect monitoring of the emitsions unit operations independently during periods when emissions are routed to the printery versus the backup emissions control device. This is due to the fact the same emissions reduction will be applied foe calculating actual emissions for demonstrating compliance with the emissions limit in the permit, This approach will be the most straightforwardfor permittingpurposes and provide the greatest operational flexibility to she epfrator. 2. The regenerator reboilers-have a design rate of DS MMgtuihr. As a result, the reboilers- are exempt from APEN requirementspe r oeguiation 3 Part A Section 1I.D.1.k, exemption: "Each individual piece of fuel burning equipment, other than smokehouse generators and internal combustion engines, that uses gaseous fuel, and that Ease design ra floe million British thermal units per hour." The operator scaled the emissions from the dehydrators predicted by aromas bye factor of two (100%). This safety factor was applied to the emissions to account for variability in the inlet gas composition. This safety factor providesa conservativeestimateemissions and therefore was determined to he acceptable forpei math, purposes, 4: Ongoing compliance withaemission lbnds in the permit will be demonstrated by running. Prom. one monthly basis. Asa'. result, emission factors will not be included Inn the permit. The aperatorused* -representetlyewet -gas sample front the Ward Petroleum Sharp 24-3.11 CC well site as the input to the proMee simulation usedto calculate dehydrator emissions. This lad higher VOC content than the outlet of the third compressor in the ProMas compression simulation used to determine condensate and produced wasen tank emisirons. Since the sample used has; higher VOC.concentratiun,the simulation used'tocalculate dehydrator emissions is:e wnservativeestimate. It should be fort notedthat an initial wet gas analysis wilt be required to verify actual site. specific emissions since a.representative sample was used In the Initial analysis. - - - - - S. The representative gas sample provided did not include information regarding the ',Hexane and 2,2,4-1MPcontent m the ample. As such the operator estimated the content ofthese HAPs In the sample. Ideterminedthis was acceptabl esince .an.initial extended: wet gas analysis wilt he required in the permit to determine the concentration of these HAPs in the inlet gas.: 7. The original APEN submitted listed an Inlet pressure of 900pslgi however, the ProMassimulation was run at 800 psig. The operator expressed that usingth a moreconservativeesuhute because a higher concentration of tIOCwill remain In the in the gas if the inlet pressure to the dehydration unit Is lower, this fact, along! concentration belrwenn the sample and the simulation led me to accept the operator calculation as being conservativc plan for this source indicates' that "Direction of waste gas to the enclosed flare during times not required by th e burner will be inherent to process logic."this means that the process w designed see valve wilt be actuated automatically to send flash tank waste gas to the enclosed flare during times in whit the reboiler is not operating: The operator confirmed assertion. 9. The operator is requesting a- controlefficiency of 95% for the enclosed gate used to control emissions from the glycol dehyd rater. Since this us the olcision approved standard for can initial testing will not be required In the permit to demonstrate compliance with this control percentage its. TheAPENs submitted for the the dehydrators initially represented NOn and CO emissions from the reborter burner. Since these are APEN exempt sources and combustion gas from the dehydrators is accounted for under Point 013,1 suggested removing the reboiler emissionsfromthe glycoi dehydrator APEN and simply accounting'. for them on the facilifywide bwentoryform.The operator agreed with this assertion, As such, the NOn and CO omissiaos were removed :from -the -dehydrator APENs. 16 of 37 K:\PA\2016\16WE0773.CP1xlsm 'FaciIINAIRs ID: -9E94 Section 09 - Inventory 5CC Coding and Emissions Factors County Plant 007-0o!'t Point AIRS Point g 007-008' Process* 5CC Coda 01 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.0 0.00 b/MMsd PM2.5 0.0 0.00 b/MMsd NOx 0.000 0.00 b/MMscf VOC 2.172 0.95 b/MMsd CO 0.000 0.00 b/MMsd Benzene 1.117 0.95 b/MMsd Toluene 3.813E-01 0.95 b/MMscf Ethylbenzene 4.487E-02 0.95 b/MMsd Kylene 1.984E-01 0.95 b/MMscf n -Hexane 6.442E-04 0.95 b/MMsd 224 TMP 1.687E-04 0.95 b/MMsd 17 of 37 K:\PA\2016\16 W E0773. CP 1.xism Section 01 - Adminstrative Information Facility AIRs ID: 123 9E99 009 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Emissions from this source are not controlled. Description: Requested Overall VOC & HAP Control Efficiency %: 0 Equipment leaks (fugitive vacs) from a natural gas processing Section 03 - Processing Rate Information for Emissions Estimates This section is not applicable to fugitives. Section 04 - Emissions Factors & Methodologies Regulation 7 Information Operating Hours: 8760', hours/year Emission Factor Source Standard SFs-GPA4531 G;9SAi Tabte2-I Control Efficiency Source: Table 54 Monthly Mond Service Component Type Count Emission Factor (kg/hr- source) Table 2-4 Table 2-8 Control (%) Pollutant Mass Fraction Uncontrolled Emissions (tpy) Controlled Emissions (tpy) Connectors 7500 ! 2.00E-04 1.00E-05 0.0% VOC 0.266235 -.: 20.0286499 7.364249626 Flanges 959 " 3.90E-04 5.70E-06 0.0% Benzene 0.00102204'. ! 0.076887266 0.028270354 Open -Ended Lines 1 2.00E-03 1.50E-05 0.0% Toluene 0.000696906 0.052427691 0.019276916 Gas Pump Seals 0 2.40E-03 3.50E-04 0.0% Ethylbenzene 0.000119982 0.013539904 0.00497843 Valves 1244 4.50E-03 2.50E-05 88.0% Xylenes 0.000470723 :'. 0.035412121 0.013020533 Other 36 8.80E-03 1.20E-04 0.0% n -Hexane 0.00278328 0.209383968 0.076987506 --- --- --- -- --- 2,2,4-TMP 0.000993091 0.074709456 0.027469604 Connectors 2658 :'. 7.50E-06 7.50E-06 0.0% VOC 1 0.229029829 0.229029829 Flanges 325 3.90E-07 3.90E-07 0.0% Benzene 0 0 0 Open -Ended Lines 0 1.40E-04 7.20E-06 0.0 % Toluene 0 0 0 Heavy Oil Pump Seals 32 0.00E+00 0.00E+00 0.0% Ethylbenzene 0 0 0 Valves 382 ! 8.40E-06 8.40E-06 0.0% Xylenes 0 0 0 Other 14 3.20E-05 3.20E-05 0.0% n -Hexane 0 0 0 -- -- -- --- --- 2,2,4-TMP 0 0 0 Connectors 404 =: 2.10E-04 9.70E-06 0.0% VOC 0.9981741 8.285654616 3.215216447 Flanges 230 .': 1.10E-04 2.40E-06 0.0% Benzene 0.0221205 ! 0.183618091 0.071252295 Open -Ended Lines 0 1.40E-03 1.40E-05 0.0% Toluene .0.0343418! 0.285064793 0.110618298 Condensate (Light Oil) Pump Seals 9 '- 1.30E-02 5.10E-04 68.0% Ethylbenzene 0.0134018 0.11124581 0.043168509 Valves 235 '' 2.50E-03 1.90E-05 76.0% Xylenes ::0.0368144 0.305589379 0.118582785 Other 6 7.50E-03 1.10E-04 0.0% n -Hexane 0.0597842 :- 0.496257349 0.192570758 -- --- --- -- -- 2,2,4-TMP '.0.0452904; 0.375947054 0.14588481 Connectors 11 rr 1.10E-04 1.00E-05 0.0% VOC 1 0.036299392 0.036299392 Flanges 68 '.'. 2.90E-06 2.90E-06 0.0% Benzene 0 0 0 Open -Ended Lines 0 2.50E-04 3.50E-06 0.0% Toluene 0 0 0 Water/Oil Pump Seals 0 2.40E-05 2.40E-05 0.0% Ethylbenzene 0 0 0 Valves 24 9.80E-05 9.70E-06 0.0% Xylenes 0 0 0 Other 0 1.40E-02 5.90E-05 0.0% n -Hexane 0 0 0 --- --- -- --- -- 2,2,4-TMP 0 0 0 Connectors 9465 -;;: 2.10E-04 9.70E-06 0.0 % VOC - 0.530414 i 53.14037052 24.87462791 Flanges 1437 '' 1.10E-04 2.40E-06 0.0% Benzene 0.00243537 0.243991418 0.11421064 Open -Ended Lines 318 4; 1.40E-03 1.40E-05 0.0% Toluene 0.00168782 0.169096932 0.079153066 NGL (Light Oil) Pump Seals 4 `- 1.30E-02 5.10E-04 68.0% Ethylbenzene 0.000438958 0.043977706 0.02058565 Valves 2886 '.. 2.50E-03 1.90E-05 76.0 % Xylenes 0.00114691 0.114905003 0.053786211 Other 89 7.50E-03 1.10E-04 0.0 % n -Hexane 0.0067'1983 0.67323686 0.315137366 --- _- _- --- -- 2,2,4-TMP 0.00241493 0.241943604 0.113252073 Emissions Summary Table Pollutant Uncontrolled Emissions Controlled Emissions Source VOC 81.72 tpy 35.72 tpy Standard EF Benzene 1008.99 lb/yr 427.47 lb/yr Standard EF Toluene 1013.18 lb/yr 418.10 lb/yr Standard EF Ethylbenzene 337.53 lb/yr 137.47 lb/yr Standard EF Xylenes 911.81 lb/yr 370.78 lb/yr Standard EF n -Hexane 2757.76 lb/yr 1169.39 lb/yr Standard EF 2,2,4-TMP 1385.20 lb/yr 573.21 lb/yr Standard EF - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 Regulatory Applicability Reg. 3 Reg. 6 Reg. 7 Review Regulation 3, Part B, Section III.D.2 to determine is RACT is required? Review 40 CFR, Part 60, Subpart KKK to determine if applicable to this source? Review 40 CFR, Part 60, Subpart OOOO to determine if 60.5380 and/or 60.5385 is applicable? Review Section XVII.F to determine is LDAR is applicable? Additional Regulatory Considerations Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2 Section I.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 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. Regulation 3 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.a) Is this source located in an ozone non -attainment area or attainment maintenance area? Yes If yes, is this source subject to leak detection and repair (LDAR) requirements per Regulation 7, Section XVII.F or XII.G or 40 CFR, Part 60, Subparts KKK, OOOO, or OOOOa? Yes Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT 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 fugitives will be in service after the date above, this source is considered "new or modified." This facility is subject to NSPS OOOOa. Following the leak detection and repair program per NSPS OOOOa satisifies the RACT requirements of Regulation 3. The permit will contain a condition reflecting this determination. Regulation 6 Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? Yes Did this source commences construction, reconstruction, or modification after January 20, 1984, and on or before August 23, 2011? No This source is not subject to NSPS KKK because the facility will commence construction after August 23, 2011. Did this source commences construction, reconstruction, or modification after August 23, 2011 and on or before September 18, 2015? No Source is not subject to NSPS OOOO because this is a new that facility will commence construction after September 18, 2015. Regulation 7 Is this source located in an ozone non -attainment area or attainment maintenance area? `,es Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? Yes Facility is classified as a natural gas processing plant. Therefore, this source is subject to Regulation 7 Section XII.G. Is the facility classified as a well production facility or natural gas compressor station? No Since this facility is not classified as a well production facility or natural gas compressor station, it is not subject to Regulation 7 Section XVII.F. Regulation 8 Is this source at a "natural gas processing plant" as defined in 40 CFR, Part 63.761? Yes Is this facility considered a "major source" of HAP as specifically defined in 40 CFR, Part 63.761 for sites that are not prodcution field facilities? No If you repond "yes" to both questions above, further review if the provisions of 40 CFR, Part 63.769 "Equipment Leak Standards" apply? Source is not subject to MACT HH because the facility is classified as a synthetic minor source of HAPs. NSPS 0000a Did this source commence construction, reconstruction, or modification after September 18, 2015? Yes Is this source at a well site, compressor station or onshore "natural gas processing plant" as defined in 40 CFR, Part 60.5430a? Yes This facility meets the definition of onshore "natural gas processing plant" as defined by 40 CFR, Part 60.5430a. Therefore, the fugitive emissions at this facility subject to NSPS OOOOa. Additional Notes: The operator calculated VOC emi VOC, i"determined it was unnecessary for the o ate: light oil service based on a VOC weig ratorto obtain a condensate sample to verify the VOC content. 2. As discussed above, this facility is subject to NSPS 00OOa. However, this federal regulation has not been adopted into C will be addressed in the notes to permit holder. do state regulation. As such, this regulation 3. Colorado Regulation 7 Section XII.G.1 requires the source to comply the leak detection and repair program (WAR) per NSPS KKK for the fugitive VOC emissions at the facility. However, this source is subject to NSPS 0000a based on the construction date of the facility. This federal regulation is more stringent as compared to NSPS KKK. As a result, I determined the source would demonstrate compiiance:with Regulation 7 Section .Xll.G.i by complying with NSPS OOOOa. The perrnitwill contain an appropriate condition pertaining tothis determination. Further, it was determinedunnecessary for the source to comply with two different IPAR programs whenone. program (NSPS OOOOa) is more stringent than the other (NSFS KKK). 4. Since the operator is assuming less than 100%VOG to estimate emissions from the gas service and NM. light oil service, initial testing will be included in the permit requiring samples be obtained from these services to demonstrate compliance with the limits contained in the permit. Annual testing will also be required for these service contributing to the overall fugitive emissions at the facility. 5. According to Colorado Regulation 3 Part A Section I.B.25.b, "Fugitive emissions shall notbe considered in determining whether a source is a major source for the purpose of this Section.I.B.25.b., unless the source belongs toone of the following categories of stationary sources." This facility is not included in the listed sources and therefore fugitive emissions are notincluded when determining whether or not this facility is a majorsource. AIRS (County/Plant) 123/9E99 Permit No. 16WE0773 Date 9/9/2016 Point # SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)* Controlled Requested Emissions (tpy)* PTE (tpy)* Ctrl. Eff% NCRP = reportable ? 009 31000220 VOC Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 35.8 81.72 0% Yes 009 31000220 Benzene Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 428 1009 0% Yes 009 31000220 Toluene Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 419 1014 0% Yes 009 31000220 Ethylbenzene - Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 138 338 0% Yes 009 31000220 Xylenes Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 371 912 0% Yes 009 31000220 n -Hexane Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 1170 2758 0% Yes 009 31000220 2,2,4-TMP Screening Efs - EPA -435/R-95- 017 Table 2-4 -- 574 1386 0% Yes **HAP Emissions have units of lbs/year Condensate Storage Tank(s) Emissions Inventory Section 01- Adminstrative Information Facility AIRs ID: 123 County 9E99 Plant 010 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Ten (10) 400 bbl fired roof condensate storage vessels connected via liquid manifold. Emission Control Device Endsslonsfrom this source are a function of vapor recoveryunit (VRU) downtime. 10% VRti downtime it assumr Description: Emissions, are controlled by an enclosed flare during VRU downtime, Requested Overall VOC & HAP Control. Efficiency %for VRU (Process 01): ', 100 Requested Overall 11CC & HAP Control. Efficiency %for enclosed flare (Process 02): Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Total Requested Permit Limit Throughput = Requested Permit Limit Throughput while VRUR. is operational (Process 011= Requested Permit Limit Throughput during VRU downtime (Process 02) _ Potential to Emit (PTE) Condensate Throughput = 37,0781 Barrels (bbl) per year 41,1981 Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= Btu/scf Volume of waste gas emitted per BBL of liquids produced = ?scf/bbl Actual heat content of waste gas routed to combustion device = Request heat content of waste gas routed to combustion device = Actual Condensate Throughput While Emissions Controls Operating = Barrels (bbl) per year 0 MMBTU per year 0 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Flash Emissions: ProMax Condensate Throughput: Pollutant Flash Emissions Emission Factors VOC _... 311.x69491; -:; lb/hr 72.75798545 lb/bbl Benzene 2.6526" ',, lb/hr 0.622772138 lb/bbl Toluene 1.19887 lb/hr 0.28041119 lb/bbl Ethylhenzene 0.147641 lb/hr 0.034532675 lb/bbl Xylene 0.323909 lb/hr 0.075761098 lb/bbl n -Hexane .7 57821 i lb/hr 1.772514852 lb/bbl 224 TMP 1.85011. ', Ib/hr 0.432747813 lb/bbl 452 bbl/year Working and Breathing Emissions: Tank Loss Stencil Throughput: 4745 bbl ear Pollutant Working and Breathing Emissions Emission Factors VOC 3627 -?ton/year 1.528767123 lb/bbl Benzene 0.183 ton/year 0.007713383 lb/bbl Toluene 0.07878 I ton/year 0.003320548 lb/bbl Ethylhenzene 0.909999' l ton/year 0.000417239 lb/bbl Xylene Z 0.0777.... ton/year 0.000746048 lb/bbl n -Hexane 0.8183 :ton/year 0.034491043 lb/bbl 224 TMP 0,1899 '. ton/year 0.008004215 lb/bbl Note: The representative gas sample from Ward Petroleum Sharp 24-3-11HC site was used as an input for the ProMax simulation used to estimate the condensate storage tank emissions as indicated above. Pollutant PM2.5 Condensate Storage Tanks Uncontrolled E.F. (lbs/bbl Condensate Throughput) Controlled E.F. while emissions. are routed to. the VRU (lbs/bbl Condensate Throughput) ControlledE.R;.. while emissionss. are routed to thee.. enclosed flare (lbs/bbt Condensate Throughput), Control Device Uncontrolled E.F. (lbs/MMBtu waste heat combusted) X 0.6305 0.000 ®' NNON®\Nx.1.% MIIIIIIENINICEIBIN 0.000®' rr \ONrX NN Uncontrolled E.F. (lbs/bbl Condensate Throughput) 0.0000 0.0000 0.0000 0.0000 Emissions Factor Source Citation 22 of 37 K:\PA\2016\16W E0773.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Ethylbenzene 0.03495 0.000 1.825E 'ill‘kti‘llis Xylene 0.000 -747E-0303 3. n -Hexane 1.8070 1.8070 0.000 9.035E-02 224 TMP 0.4408 0.000 2.204E-02 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) PM10 0.0 0.0 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 0.0 0.0 NOx 0.0 0.0 0.0 0.0 0.0 VOC 1530.2 1530.23 7,65 0.0 0.0 CO 0.0 0.0 0.0 0.0 0.0 Potential to Emit Requested Permit Limits Actual Emissions Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) Benzene 1.3E+01 12.987 6.49E-02 0.0E+00 0.0E+00 Toluene 5.5E+00 5.845 2.92E-02 0.0E+00 0.0E+00 Ethylbenzene 7.2E-01 0.720 3.60E-03 0.0E+00 0.0E+00 Xylene 1.6E+00 1.576 7.88E-03 0.0E+00 0.0E+00 n -Hexane 3.7E+01 37.223 1.86E-01 0.0E+00 - 0.0E+00 224 TMP 9.1E+00 9.079 4.54E-02 0.0E+00 0.0E+00 ection 06 - Regulatory Summary An Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage Tank is not subject to Regulation 7, Section XII Regulation 7, Section XII.G, C Storage tank is subject to Regulation 7, Section XII.G, as provided belo Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3, as pr Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2, as provided b 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 NSPS OOOOa Storage Tank is not subject to NSPS OOOOa Regulation 8, Part E, MAC Subpart HH Storage Tank is not subject to MALT HH See regulatory applicability worksheet for detailed analysis) Requested Emissions Uncontrolled Controlled (lb/year) (lb/year) 25974.742 129.880 11689.180 58.449 1439.867 7.200 3151.941 15.760 74445.029 372.243 18158.102 90.795 23 of 37 K:\PA\2016\16WE0773.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emisions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. N/A - Source calculated site -specific emission factors. Does the company request a control device efficiency greater than 95% for a flare or combustion device? - t:--- If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes 1. As indicated above,the operator utilized a representative gas sample from the Ward Petroleum Sharp 24-3- site as an input for the ProMax simulation used to calculate emissions from the condensate storage vessels. Since the sample is representative rather than site -specific, the permit will contain initial -compliance testing requiring the source obtain a she-specificsample in order to : demonstrate compliance with the emissions factors utilized inthis permit application.. 2. The condensatetanks are controlled by an enclosedflare which is covered- by point 013. As such, the secondary emissions associatedwith the combustion of the condensatetank waste gas are accounted for with point 013.: It should benoted that this enclosed flare is used to control both the condensate tanks and the dehydarator still vent and flash tank. - - - - - - 3. In the application, the operator indicated that tank vapors are typically captured by a vapor recovery unit (VRU} and recycled within the processing plant. It is assumed that the VRU isnot operational 10% annually When the VFW is not operational, the emissions from the condensate tanks will be routed to the enclosed flare. A control efficiency of_100% is assumed when emissions are captured by the VRU. A - control efficiency of 95%is assumed when emissions are routed to the enclosed flare. With regards to condensate tanks, VRUs, like enclosed flares, are considered add on control devices. As a resultof this and the fact the control devices achieve different control efficiencies the "two emissions control systems will need babe permitted and the emissions unit monitored to beable to calculate actual emissions reflecting periods of operation during which emissions are -routed to each independent emissions control device" (P5 Memo 15-02). The permit will appropriately reflect the use of the two different.., operating scenarios to control the condensate tanks in addition to including appropriate: conditions outlining the need to mon hoc the condensate production during periods whileemissions are routed to either the VRU or enclosed flare. 4. The amount of condensate that may collect as a result of the inlet slug catcher and three -stages of compression was modeled using ProMax. The operator scaled this modeled throughput value by 10%to account for inletgas composition variability. Itwas determined that this was a conservative estimate and therefore acceptable for permitting purposes..: -- ---- 5:. As indicated in the tank regulatory analysis tab, condensate storage vessels at natural gas processing plants are not subject to Regulation 7 recordkeeping or reporting requirement under this section of the regulation. - - - - 6. The emission factorforthis source (74.2871b/6bl} is significantly higherthan typicalemission factors for condensate star age vesselsatnatural :gas processing. plants. This: result is likely due to the large pressure drop (340 psi to atmosphere}from the slug: catcher and compressor liquids drop out to the ::atmospheric storage vessels; The large pressure drop in the simulationresults in a significant amount of. flash emissions (3111b/hr) which account for the majority of emissions from the condensate tanks.. Since this result higher than typical, I determined it was a. conservative estimate of emissions and therefore acceptable for permitting purposes,. 7. Since this is a new f3cgitywithout actual operating information, the actual- through Section 09- Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 010 01 dank in this -analysis LD, As .result,, the storage vessels donothavve Uncontrolled Enclosed Emissions VRU Flare Pollutant Factor Control % Control % Units PM10 0.00 0 0 16/1,000 gallons condensate throu, PM2.5 0.00 0 0 lb/1,000 gallons condensate throu, NOx 0.00 0 0 lb/1,000 gallons condensate throu. VOC 1768.7 100 95 lb/1,000 gallons condensate throu. CO 0.00 0 0 lb/1,000 gallons condensate throw Benzene 15.01 100 95 lb/1,000 gallons condensate throu. Toluene 6.76 100 95 lb/1,000 gallons condensate throw. Ethylbenzene 0.83 100 95 lb/1,000 gallons condensate throu Xylene 1.82 100 95 Ib/1,000 gallons condensate throu. n -Hexane 43.02 100 95 lb/1,000 gallons condensate throw. 224 TMP 10.49 100 95 lb/1,000 gallons condensate throu. 24 of 37 K:\PA\2016\16W E0773.CP1.xlsm Condereate Tank Regulatory Malysis Worksheet Colorado RemdaWn 3 PeUAand a - AMEN a. Permit nauulremanta ARAIMMEMIL -Co an.Mos wonted with mmwaloe a Meta as from Me comc"... tanks n atauMN par molar point 013. As a reach ell dude ia's in Mk swim am rruhvd es N/.1 1. Are unconiroMed actual emissions Ron, any criMrie pollutant& nm PY Meguen 3, ',art 2. Is the constructIon u mcolo mnA.D.lal? d.Mamma noel color to 12/302002 an not modified after 12/31/2002 ism PS Mend 05-010ennpom 132 5.1.14 a. Sece0n z for additional madame on grandfather armlkao3M)? 3. Are Mtal lacRIM unconeolled WC emissions greNan 51n, NOagreamr mm to tar orc0 entoWns year man lO ITV (Regulation 3. Part s, 5ecdonlf0.3)? tl0N#TlAINMyQ 1. Are uncontrolled emissions Morn any titnn. TM' {Regulation 3, Parr, 11.0.1.a)) e lsak daalpnmor740rymxa /em x ry after 12/31z (See P5 Memo OSM10.nnim.. PRIM, 1.125401.14.Section z for additional guidance nce on grandfather apgkaeinnl? 3. Arent Mollify date WIC emission, Prom me greater Man0Tnm r greater than 5 TM' COca emissions greater Nan {Reguan3 Part II, Seeoon D.31?l5w h 1. Is Vs storage late k locoed r m attainment/maintenance aaa or embramn and prMucdon°paragonmuna al gas cmmsor swn or naval gas drip sotlon? 3. Is this stomp fit natural gas nprocessinggmem, 1stor2 o wgua Snotton PM. 1 -General Raqueementa Mr PM n Control Equipment- Prevention ...rage Section MU -Monitoring 5w.. SLF-Record tee ea.5emrmg splorada Papla3on 3 Seaton arty 1. storagmtanyKKated in the gMr wane control area or, ozone non -attainment area or ateinmenVmaintenanCe area) �' atural gas procesang plant, oe mma. ter. ,s subject to Ameulation -Om 3. Wes 4•(e4 Matpap. liquids) ions ter a uncontrolled ec as dma emissions 6 man equal mto ns vOC. salon MUG. • ol Repuiramenn -Generaluvmm Remoremene for tee PoeumnCanod Equipment-Prevemmn of Leakage Colorado Regulation ? Section tilt 1. Is this tank ocaa a mm sionrymrage(minty, located at an al and gin exploration an production operation, well production 4001!10'.natural gas compressoraetien' or rum.( gas processing pnt? 3. link con:bream stomp tangs axed roorsuorage Ong, Are uncontrolled ,Oral emissions of Nnstorage nkequal . Or greater than f. tons per year vat? WILA -General Provialoos for AS Pollution Control Estratrnent and Prevention of Ernasnrs Section Emits.. Control and Sollandmkemi M.U.5Mon.,. arm 5. Does only 'Mad., Ilquid, �s. to Pe,ula Section XVII.. -Capture and monitoring for StOrage ran. !helm. PM Pollution Control Equipment .10 CFR. Ian 60. Ullman gis Mandan:la a aenamanaamNovaaaanto Ltoae sareca,355 a I. Is .IndivOwl storage vessel tinare,a,. mnun to onto an or n?5 cunt oo in) M47255 l? 2. Dog the storage vessel meet Me following exempton M60.1111sidaa), aeclpap43y 4 Man Or equal to 1,S39.04&,-10,0MasSLl used Mr petroleum' or condensam storm, pro...a... tatedaarm custody transfer'n defined In 60.1110 3. Wes Mis condensate storage tank wrotructed,r M.Isee definitions. CFR, O.zl afar lay 23.19.17 a. 5. Does Me Morage yes. Mere a ',WPM oes a n wee e n organ. idud NOW'. defined In O.1110? stores. ma meet any one of the following *Menai uernptIons, s. Doc the a s Me storage vessel a MenUre rev nut s skPa M29 an and m ou emissions on tmospn.W1O{dl{zll?;o The rMmgn rereaMeMa Mager or I' m950 R&1 and son a rant kin a aakn Owe vapor presume' lass Man 3.5 Plre1a0.110MMIP; or cra pacity isareamanor equal m13IA' I'n3and but Ins than 1St nil l'95o Brig and stores a Acrid won a magnum w mop pressure' less than IGOtna(60.10e{Bll? km aMma to NSP5 ate Subpart .0, General Provisfons d� ge11a.E meth ConwlSeneardsfoeyoc 460.1130 -Testing ad Procedures 4ao.11s0-Reporting and Rero.keeping Reauiremnn 440.1110. Monitoring or Operations red• op a. Ntual sM Predueton imsmesion and Dlryiygica sma .m ma laaanmmnsao eeR,5o.31 aau.a.guet n.zovl and p.rms.Mume.r le.3muP A ones tins condentare stone. wry, rnoat the Wanton of 'storage gess,' par 60.54307 3. s Wscat ema ounce weasel boned at a facility ,n no ortnorep and natural gas production nemant.natual as mmesdng momenta nate. gas Manamiaion.msa..p s.grn.nmr..i.usw) 4. Are potential VOC emission' norn the InArklual stomp a {nate. than or *nein Dons per year, 754rattu arank ano aten. to gnat 20 per 46osassn0 gww . - Pmiadom Control Standards nor we 460.5413. Tesme a. Procedures 1193{3 • amellamn, Reporting,. 0ecor4seeping 5.uuema0a §0.543613 • cover a. Closed Vent Staten Monitoring Requirement, question tooze AREA Ycr... ;iRequiresa W m me neat question Go to Ma neer...ion rank is not mom, to Regulation M section Mit 5 age rank is Mt subject. Regulation]. Section Mil ....; swrte s sumect Go M nest quest. Go Po the next questlon Go to Me next rpestion Source is subject to par. of Regulation 7, SeetIons 0.4,C. Go to Me next question 14 ID all provislons. of Regulation 7, Sectors RAC lorarc rant isms subject NSMS in • Tre swage vessel capacity is gene an Anna. Wanton i.e.,: 3. nen...+u.l 1. p.aiaary an.mar.a m e. augaa m rrsrs .00 due to emirabm above 6 tam .er yee. V« on the eppnrenlYy determinwian data. it *Add'amain+W w to revs 0000 per ms3ay elul even potential VOC•mwn.dropb.w6 ten. paryearl 40 CFR. Part 00 SulsoortlI000a Rama., Perlormanorlar Crude eR@AVOW+ pa Facilities for alwncon.wnlon modHbn>, ornammtmewn Comment. Marleptember.H 3015 1. Was bIls condensate storage vessel roes or 'nadir. leesdellnitlons 40 CFR, 60.nalter September la 30151 2. Does Ws condensate storage sessel meet the definition of 'storage vessel... Re, 50.5.0a1 Go to the next puestIon Go IV the nest question 3. a this t n n a production se r..as processing g tormm gasansmssen and storage segment ofm.ndusty nk o e a.a n a. ere VOC ns horn the individual strl,ery Feat. Man or equal to Per Yea, S. Is me store, j;gect na oat accordance repwnmenu for store ate see, in 40 ax part 6o subpart,. or 40 ax Part 63 Subpart seal 'Storage subpart& Generalpovbom per 463.76AIqTable 3 M3.]N • Emiaebns Coned standards 163.]13 • monitoring 16.3.n4.k.ammepng I6a.m-Reporting MT Review Race review ° rptifrocl Re.ulation]dnxn apply sxpM the tank b intha nenaetainment area.N. tank mwb tats exM& than mew wc) npulmnenta DkcYhr�r Th‘scloaffnenf ass. operators MOO tleterminxg applicandryofcertain nepusemantsof.. Chan Air Act. dsimplementing regulations. and Air0331Ry Control Cor 330 regulations. This document is orre00Yto,, and the analysis 0 cantatas may no(.000lo pMoularmma0on based upon Neind0gvallacts&4 cdcumatnces. ih Mbroranylav, repulalon.wenyoNwbgaxybm0N3 requirement andis noting -WV enforceable. In 0etwnen Me language o sdocument nd the language of. Clean krt., As ,rentbgreprlatotls, and Ad 0ua.Hy Conlm100033 son regulatror0IM lanphpe oftlre mature orregulafon wdlwntra0 Th rdatpry larpuage sate aa'xommentl. '0aY Wend.. describe 000030emmhlons and recommentlan0ns. Manda1sry lermirmopy such PS 'must' and'rpuirotl' ate 3.30060 to dawn a 00100300 mpuaements under the bans NNe Chan A V Ad and Air Ouatiy Cwdd Commission regulatons. Wt Nh d0cuma0does not asbdssh legally binding ',w enn. m and of AS. 1101InXICAl. 010. Dawn lists Storaae Tank Is not subject WS 0000. Storage rank is not sugectmner.H Then are no MAR 3x requiremen. for tanks at area sources Section 01 - Adminstrative Information Facility AIRs ID: 123 9699 011-612 '.. County Plant Point Points 011-012 cover the same engine make and model. As such, this spreadsheet provides an analysis for each engine as emissions are identical from each. Section 02 - Equipment Description Details one (1) Caterpillar Model' G35°89 SN: Tao natural gas fired, turbocharged, 454.5 reciprocating Internal combustion engine, site rated at 540 HP and 1405 RPM. This engine !. Detailed Emissions Unit will be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is Description: usedlornatur gas compression. Emission Control This engine is equipped withan oxidation catalyst and air -fuel ratio contra Device Description: Requested VOC Control Efficiency %: Requested CO Control Efficiency %: Requested HCHO Control Efficiency %: 111/2016,', Engine Manufacture Date: Manufacturer: Model Number: Serial Number: RPM: caterpillar'.. 035088 -- -.. TBQ 1400 1400:.....;'......... Site -rated RPM: Engine Function berating Mfg's Max. Rated Horsepower @ sea level: 690 Horsepower used for calcuations: 690 BSCF @ 100% Load (btu/hp-hr): 7254 Site - Rated BSCF @ 100% load (btu/hp-hr): 7254 Other Parameters Engine Type Aspiration Electrical Generator Max Site Rating (kw) Max hrs/yr of Operation 8760 Section 03 - Processing Rate Information for Emissions Estimates Fuel Use Rate @ 100% Load 4554.794521 scf/hr ACTUAL Annual Fuel Consumption ;,.,.. 0 MMscf/yr MAX POTENTIAL Annual Fuel Consumption 39.860 MMscf/yr REQUESTED Annual Fuel Consumption 39.900 MMscf/yr Fuel Heating Value ]1100. btu/scf Section 04 - Emissions Factors & Methodologies Pollutant Uncontrolled Emission Factor NOx CO B ff 2.580 VOC 0,550 PMzs 9.987E-03 9.987E-03 SO2 5.880E-04 Formaldehyde 5.280E-02 Controlled Emission Factor Since this is a new facility, actual fuel consumption data is not available. Requested fuel consumption was rounded up. Uncontrolled Emissions Controlled Emissions Source tpy Maurer 3.32 3.33 tpy ; Manufacturer 3.66 tpy Manufacturer 0.500 0.501 g/hp-hr 3.32 tpy 17.19 tpy 3.66 tpy ':®r Ib/MMBTU 0.22 tpy 0.22 tpy AP -42 Chapter 3 Table 31-2 ':®f Ib/MMBTU 0.22 tpy 0.22 tpy AP -42 Chapter 3 Table 124 5.880E-04 Ib/MMBTU 0.01 0.01 tpy 3.421E-02 lb/MMBTU 2317.39 lb/yr 1501.67 lb/yr AP -42 Chapter 3 Table 3.2-2 AP -42 chapter 3Table 3.2-2 0.151959 0.78411 0.167155 0.151959 0.152117 0.167155 1.737E-01 0.112578 16WE0773.CP1.xlsm Acetaldehyde 8.360E-03 Acrolein 5.140E-03 Methanol 2.500E-03 Benzene 4.400E-04 Toluene 4.080E-04 Ethylbenzene 3.970E-05 Xylene 1.840E-04 n -Hexane 1.110E-03 2,2,4-TMP 2.500E-04 1,3 -Butadiene 2.670E-04 8.360E-03 lb/MMBTU 366.92 lb/yr 366.92 lb/yr AP -42 Chapters 3 Table 3.24 5.140E-03 Ib/MMBTU 225.59 lb/yr 225.59 lb/yr AP -42 Chapter'.. 3 Table 3.2-I'. 2.500E-03 lb/MMBTU 109.73 lb/yr 109.73 lb/yr AP -42 Chapter: Table 3.2-2'.'. 4.400E-04 Ib/MMBTU 19.31 lb/yr 19.31 lb/yr AP -42 Chapter{ 3 Table 3.2-2 4.080E-04 lb/MMBTU 17.91 lb/yr 17.91 lb/yr AP -42 Chapter 3 Table 3.2-2 3.970E-05 lb/MMBTU 1.74 lb/yr 1.74 lb/yr A3 42 Chapter 3 Table 3.2-2': 1.840E-04 Ib/MMBTU 8.08 lb/yr 8.08 lb/yr 1.110E-03 Ib/MMBTU 48.72 lb/yr 48.72 lb/yr .AP -42 Chapter'.. 3 Table 3.2-2 .42 Chapter Table 3.2-2 2.500E-04 lb/MMBTU 10.97 lb/yr 10.97 lb/yr AP -42 Chapter? 3Table 3.2-2.'. 2.670E-04 lb/MMBTU 11.72 lb/yr 11.72 lb/yr AP -42 Chapter.. 3 Table 3.22x'_ 2.751 E-02 1.691 E-02 8.226E-03 16WE0773.CP1.xlsm Regulatory Requirements Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2 Section LA - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in 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. Regulation 3 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 and NOx 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.a) Regulation 7 Section XVI.B: These engines have a design rate greater than 500HP (reported as 690HP) and are located in the ozone non -attainment area. As a result, the engines are subject to the air pollution control technology requirements of Section XVI.B.2 for lean bum engines. The APENs submitted indicate the engines are equipped with an Air/fuel ratio controller and an oxidation catalyst to control emissions. As such, the engines are complying with this part of the regulation. Section XVII.E: According to Regulation 7 Section XVII.B.5: "internal combustion engines that are subject to an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ('BACT") limit, or a New Source Performance Standard ("NIPS") under 40 CFR Part 60 are not subject to Section XVII., except for the leak detection and repair requirements in Section XVII.F." These engines are subject to MACT 7777 and NSPS JJJJ. As a result, they are not subject to the requirements of Regulation 7 Section XVII.E. MACT 7777 The engines at this facility are subject to MACT 7222. The facility is an area source of HAPs, so engine is not subject to major source requirements. Since this engine is located at an area source of HAP emissions and commenced construction after June 12, 2006, it is classified as a "New Stationary Rice." According to §63.6590(c): "An affected source that meets any of the criteria in paragraphs (c)(1) through (7) of this section must meet the requirements of this part by meeting the requirements of 40 CFR part 60 subpart 1111, for compression ignition engines or 40 CFR part 60 subpart.1.1.11, for spark ignition engines. No further requirements apply for such engines under this part. This engine meets the criteria of §63.6590(c)(1( "A new or reconstructed stationary RICE located at an area source." As such, it will meet the requirements of MACT MU by meeting the requirements of NSPS JJJJ. NIPS JJJJ Is this engine subject to NIPS JJJJ? I I /1I Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Additional Notes: 1. An initial compliance test for each of these engines wilt berequired for the following reasons: ji}The engines have a control device and have a name -plate rating greater than -50O HP; (ii) The is synthetic minor for CO; and -(iii} -The facility is synthetic minor for formaldehyde. This initial compliance test is consistent with the requirements in the general permit 02 for natural gas fired reciprocating internal combustion engines. 16WE0773.CP1.xlsm AIRS (County/Plant) 123/9E99 Permit No. 16WE0773 Date 9/9/2016 Point # SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)* Controlled Requested Emissions (tpy)* PTE (tpy)* Ctrl. Eff% NCRP = reportable ? 011 20200254 NOx 1.5196E-01 lb/MMBTL Manufacturer 3.40 3.40 0% Yes 011 20200254 CO 7.8411E-01 Ib/MMBTL Manufacturer 3.40 17.19 80.6% Yes 011 20200254 VOC 1.6716E-01 Ib/MMBTL Manufacturer 3.70 3.70 0% Yes 011 20200254 PM2.5 9.9871E-03Ib/MMBTLAP-42 0.22 0.22 0% No 011 20200254 PM,0 9.9871E-03 lb/MMBTL AP -42 0.22 0.22 0% No 011 20200254 SO2 5.8800E-04Ib/MMBTLAP-42 0.01 0.01 0% No 011 20200254 Formaldehyde 5.2800E-02 lb/MMBTLAP-42 1501.67 2317.39 35.2% Yes 011 20200254 Acetaldehyde 8.3600E-03 lb/MMBTU AP -42 366.92 366.92 0% Yes 011 20200254 Acrolein 5.1400E-03 Ib/MMBTU AP -42 225.59 225.59 0% No 011 20200254 Methanol 2.5000E-03Ib/MMBTU AP -42 109.73 109.73 0% No 011 20200254 Benzene 4.4000E-04 lb/MMBTLAP-42 19.31 19.31 0% No 011 20200254 Toluene 4.0800E-04 Ib/MMBTL AP -42 17.91 17.91 0% No 011 20200254 Ethylbenzene 3.9700E-05Ib/MMBTLAP-42 1.74 1.74 0% No 011 20200254 Xylene 1.8400E-04 lb/MMBTL AP -42 8.08 8.08 0% No 011 20200254 n -Hexane 1.1100E-03 Ib/MMBTL AP -42 48.72 48.72 0% No 011 20200254 2,2,4-TMP 2.5000E-04 Ib/MMBTL AP -42 10.97 10.97 0% No 011 20200254 1,3 -Butadiene 2.6700E-04Ib/MMBTLAP-42 11.72 11.72 0% No **HAP emissions have units of Ibs/year. 012 20200254 NOx 1.5196E-01 Ib/MMBTU Manufacturer 3.40 3.40 0% Yes 012 20200254 CO 7.8411E-01 Ib/MMBTU Manufacturer 3.40 17.19 80.6% Yes 012 20200254 VOC 1.6716E-01 Ib/MMBTU Manufacturer 3.70 3.70 0% Yes 012 20200254 PM2,5 9.9871E-03Ib/MMBTUAP-42 0.22 0.22 0% No 012 20200254 PM10 9.9871E-03 lb/MMBTLAP-42 0.22 0.22 0% No 012 20200254 SO2 5.8800E-04 lb/MMBTLAP-42 0.01 0.01 0% No 012 20200254 Formaldehyde 5.2800E-02 lb/MMBTL AP -42 1501.67 2317.39 35.2% Yes 012 20200254 Acetaldehyde 8.3600E-03Ib/MMBTLAP-42 366.92 366.92 0% Yes 012 20200254 Acrolein 5.1400E-03Ib/MMBTLAP-42 225.59 225.59 0% No 012 20200254 Methanol 2.5000E-03Ib/MMBTLAP-42 109.73 109.73 0% No 012 20200254 Benzene 4.4000E-04Ib/MMBTLAP-42 19.31 19.31 0% No 012 20200254 Toluene 4.0800E-04Ib/MMBTUAP-42 17.91 17.91 0% No 012 20200254 Ethylbenzene 3.9700E-05 Ib/MMBTL AP -42 1.74 1.74 0% No 012 20200254 Xylene 1.8400E-04 lb/MMBTU AP -42 8.08 8.08 0% No 012 20200254 n -Hexane 1.1100E-03 lb/MMBTLAP-42 48.72 48.72 0% No 012 20200254 2,2,4-TMP 2.5000E-04 lb/MMBTLAP-42 10.97 10.97 0% No 012 20200254 1,3 -Butadiene 2.6700E-04 lb/MMBTL AP -42 11.72 11.72 0% No HAP emissions have units of lbs/year. Section 01- Adminstrative Information Facility AIRs ID: 123 County Plant 013 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates CondensateTanks Waste Gas:,... 0.0703175 MMscf/day 2474', Btu/scf One (1} enclosed flare (Make,:: Model, SN: TBD) used to control emissions from the ethyleneglycol dehydration e still vent (point 007 and 008). jThisenclosed Bare also controls emissions from theethylene glycol dehydratlon unit flash tank (point, 007 and 008). when emissions are root routed to the reboiter and from the condensate storage vessels (point010) when emissions are not routed to the VRUF. N/A - As stated above, this source functions as the emission control device for points 007, 008 and 010. HAP Control _.._...._.... Heat Content of waste gas: Requested volume of waste gas routed to combustion device: Actual volume of waste gas routed to combustion device: PTE volume of waste gas routed to combustion device: Requested heat content of waste gas routed to combustion device: Volume of waste gas emitted: Heat Content of waste gas: Requested volume of waste gas routed to combustion device: Actual volume of waste gas routed to combustion device: PTE volume of waste gas routed to combustion device: Volume of waste gas emitted: Heat Content of waste gas: Requested volume of waste gas routed to combustion device: Actual volume of waste gas routed to combustion device: PTE volume of waste gas routed to combustion device: Heat Content of gas: Requested olume of gas routed to combustion device: Actual volume of waste gas routed to combustion device: PTE volume of waste gas routed to combustion device: Requested heat content of gas routed to combustion device: Total Throughput: 25.6658875 MMscf/year 0 mmscf/year 25.6658875 MMscf/year 63497.40568 MMBtu/year 1.759519 MMscf/year 0 MMscf/year 1.759519 MMsd/year 1409.374719 MMBtu/year MMscf/day Btu/sd 21.693848 MMsd/year 0 mmscf/year 21.693848 MMscf/year 0.748063724 MMBtu/year p1rBelallotioasz 0.110012. MMsd/day 1023jj Btu/scf 0.0438 MMscf/year 0 MMsd/year 0.0438 MMsd/year 44.8074 MMBtu/year 2929.895833 scf/hr 100.4291667 scf/hr 1238.233333 sd/hr 5 scf/hr Total Average Heat Content: 1333.942939 31 of 37 K:\PA\2016\16W E0773.CP1.xlsm Total Requested Throughtput (Permit Limit) Actual throughput PTE Throughput 49.1630545 MMscf/year 0 MMscf/year 49.1630545 MMscf/year Section 04 - Emissions Factors & Methodologies Pollutant CondenaateTenicWaate Control Device Uncontrolled E.F. (lbs/MMBtu waste heat combusted) Uncontrolled E.F. (Ibs/MMscf waste gas volume combusted) PM2.5446.74O61SX% i0 0.2755 wyjimm ______ 18.4337 Control Device Emissions Factor Source Citation Pollutant PM10 PM2.5 NOx VOC CO Uncontrolled E.F. (lbs/MMBtu waste heat combusted) Control Device 0.138 0.2755 Uncontrolled E.F. (Ibs/MMscf waste gas volume combusted) Emissions Factor Source Citation Pollutant Uncontrolled E.F. (lbs/MMBtu waste heat combusted) Uncontrolled E.F. (lbs/MMscf waste gas volume combusted) Emissions Factor Source Citation X NAX • 0.2755. ' .. ,',' 0.138 4.0020 Emissions Factor Source Citation Pollutant 11111212 3:1•1111111 =MEM-, \2 Control Device Uncontrolled E.F. (Ibs/MMBtu waste heat combusted) Uncontrolled E.F. (Ibs/MMscf waste gas volume combusted) 141.1740 Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0.2 0.2 4.4 0.2 8.7 0.2 0.2 4.38 0.17 8.75 0.2 0.2 4.38 0.2 8.75 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) PM10 0.0 0.0 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 0.0 0.0 NOx 0.1 0.10 0.10 0.0 0.0 VOC 0.0 0.00 0.0 0.0 0.0 CO 0.2 0.19 0.19 0.0 0.0 Potential to Emit Criteria Pollutants Uncontrolled Actual Emissions Uncontrolled Controlled 32 of 37 K:\PA\2016\ 16WE0773.CP1.xlsm (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) PM10 PM2.5 NOx VOC CO 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.04 0.04 0.0 0.0 0.0 0.00 0.0 0.0 0.0 0.1 0.09 0.09 0.0 0.0 PaebefPilat Gas: Potential to Emit Requested Permit Umits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) PM10 0.0 0.0 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 0.0 0.0 NOx 0.0 0.003 0.003 0.0 0.0 VOC 0.0 0.000 0.0 0.0 0.0 CO 0.0 0.006 0.006 0.0 0.0 Total Emissions (Permit Values) Potential to Emit Requested Permit Umits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) PM10 0.24 0.24 0.24 0.00 0.00 PM2.5 0.24 0.24 0.24 0.00 0.00 NOx 4.53 4.53 4.53 0.00 0.00 VOC 0.18 0.18 0.18 0.00 0.00 CO 9.03 9.03 9.03 0.00 0.00 Section 06 - Regulatory Summary Anal sis Regulation 1 Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 Section I.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 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. Regulation 3 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 NOx Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled NOx emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part 8, Section II.D.2.a) Regulation 7 Section XVll.B.2: Since this enclosed flare is used to control emissions from the condensate tanks and ethylene glycol dehydration units at this facility, it is subject to this section of Regulation 7. This portion of the regulation states: "If a combustion device is used to control emissions of VOCs and other hydrocarbons, it shall be enclosed, have no visible emissions during normal operation, 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." 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. 33 of 37 K:\PA\2016\16WE0773.CP1.xlsm Section 07 - Initial and Periodic Sampling and Testing Reouirements Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes 1. The emissions from the condensate storage vessels are primarty captured by a vapor recovery unit and recycled within the facility. However, during VRU downtime, the condensate tankemissions will be routed to the enclosed flare. For this calculation, the operator assumed the entirety of the modeled condensate tank wastegas volumewould be sent to and controlled by the enclosed flare. This is a conservativeestimate of emissions and was therefore determined to be acceptable. - _--- 2. The emissions from the ethylene glycol dehydration unit flash tank are primarily used as fuel gas for the reboiler.However, these emissions may also be routed to the enclosed flare. For this calculation, the operator assumedthe entirety of the flash tank; waste gas volume -would be routed to and controlled by the en closed flare. The operator also assumedithe.reboiler burner would operate. at 8760 hrs/year.This approachis conservative and results in the greatest operational flexibility for the operator. Since the operator is assuming the worst case scenario for each operating scenario, the. operator will not be required to monitorthe the "emission unit operations independently during periods when emissions are ro Media the primary versus the backupemissions control device" (PS Memo 15-02). By permitting the entire flash tank waste gas volume at the enclosed flare, the operator has theability to send: additional volume to the flare in the event the reboiler is not operational for a greater amount of time than is initially anticipated. By also assuming the reboiler operates at 8760 hrs/year, the operator is accounting for the emissions in the event that all flash tank emissions are routed to the reboiler. By doing this, the operator is double counting the NOx and CO emissions resulting from the combustion of the flash tank waste gas However, the NOx and CO emissions resulting from both operating scenarios (entire flash gas volume routed to ECD and reboiler operating at 8760 hrs/yearl are D4 tpy and 0.53 tpµrespectively. Since this is less than 1 tpy and emissions do notexceed modeling or major source threshokls, itwas determined this method was acceptableDar permitting purposes. 3. The requested volumecalculation for the E6 dehydrator still vent a vent and flash tank.-- - is scaledby a. factor oftwo because there aretwo ethylene glycol dehydration units cility. Each unit has a still 4, The operator calculated the heating values for each stream routed to the reboiler by multiplying the mote% values .predicted -in the ProMax;simulaation by standard. net heelingvaluesfor each component in the stream. Typically the heat values used in the calculations are obtained directly from the ProMax simvfation. However, the difference between calculating emissions using the net heating values (lower heating values) used by the operator compared to the gross heating values (higher heating values) reported by, ProMax-is negligible. Byusingthe gross heating values predicted by the pmoldairSimulation (2686 Btu/scf - Condensate Tank Waste Gas; 886 Btufscf - Eli Flash Tank; 70 Btu/scf - Eli Still Vent;1131 Btu/scf- Purge/Pilot}, the NOx and CO emissions were calculated tobe 5.0 tpy and 9:93 tpy respectively. This difference is fess than 1 tpy when compared to using the net heating values calculated by the operator. Additionally, the results using the higher heating values does cause the facility to exceed modeling or major source thresholds or change the regulatory applicability for this source. Due to these reasons, it was determined that using the operator determined heating values for calculations was representative and acceptable for this analysis. - - - --- --- Section 09 - Inventory 5CC Coding and Emissions Factors Uncontrolled Emissions AIRS Point # Process # 5CC Code Pollutant Factor Control % Units 013 01 ,w.pi PM10 9.94 0 lb/MMscf Burned PM2.5 9.94 0 lb/MMscf Burned NOx 184.08 0 lb/MMscf Burned VOC 7.2 0 lb/MMscf Burned CO 367.50 0 lb/MMscf Burned The emission factors provided here for inventory purposes are based on an average heating value of 1,334 Btu/scf. This average heating value accounts for the condensate waste gas stream, ethylene glycol flash tank and still vent waste stream and the purge/pilot light gas stream. 34 of 37 K:\PA\2016\ 16WE0773.CP1.xlsm Section 01- Adminstrative Information Facility AIRs ID: 123 9E99 014 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Actual Throughput = Annual requested Throughput = Section 04 - Emissions Factors & Methodologies Emissions Summary Table (Actual Emissions) Condensate loadout to tank trucks. Emissions from this source are not controlled. Barrels (bbl) per year 41198 Barrels (bbl) per year 1730316 gal/yr Pollutant VOC 4.160E-04 Emission Factor Uncontrolled Emissions Controlled Emissions Source lb/bbl 0.00 tpy 0.00 tpy CDPHE - PS Memo 14-02 Benzene lb/bbl 0.00 lb/yr 0.00 lb/yr CDPHE - PS Memo 14-02 n -Hexane 610E-03; lb/bbl 0.00 lb/yr 0.00 lb/yr CDPHE - PS Memo 14-02 Emissions Summary Table (Requested Emissions) Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC Benzene 0.2360 4.160E-04 lb/bbl lb/bbl 4.86 tpy 17.14 lb/yr 4.86 tpy 17.14 lb/yr CDPHE - PS Memo 14-02 CDPHE - PS Memo 14-02 n -Hexane .610E-03 lb/bbl 148.72 lb/yr 148.72 lb/yr CDPHE - PS Memo 14-02 Regulatory Review Regulation 1- Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1.) Regulation 2- Odor Section I.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 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. Regulation = 3 - APEN and Permitting Requirements Is this site considered an exploration and production location (e.g. well pad)? If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons (238 BBLs) per day of crude oil on an annual average basis? N/A If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section 11.0.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1 N/A 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.a) Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8 -hour ozone nonattainment area, but not the 1 -hour ozone 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 tank battery from which loadout is occurring has not yet been constructed, this source is considered "new or modified." Operator is using submerged fill, therefore, RACT requirements are satisfied. Regulation 6 -=New Source Performance Standards No applicable subpart. This facility is not a bulk gasoline terminal. Regulation 7 - Volatile Organic Compounds No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 76,000 liters of gasoline (20,000 gallons), which is loaded directly into transport vehicles. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. Regulation 8- Hazardous Air Pollutants MACT EEEE: Not subject because the facility is classified as a synthetic minor source of HAPs Additional Notes: 1. According to PS Memo 14-02 Section 5.2 "The state default emission factors noted above may be used at any oil and gas hydrocarbon liquid loading operation that utilizes submerge fill." Since this facility is a natural gas processing facility that uses submerge fill for its loadout operations, the state default loadout emission factors are appropriate for estimating emissions from this source. 2. VOC is the only reportable emission from this source. As such, the permit will only contain an emission factor for VOC. AIRS (County/Plant) 123/9E99 Permit No. 16WE0773 Date 9/9/2016 Point # SCC Pollutant or CAS Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)' Controlled Requested Emissions (tpy)* PTE (tpy)' Ctrl. Eff% NCRP = reportable ? 014 40600132 VOC 5.619 Ib/1000gal CDPHE - PS Memo 14-02 4.86 4.86 0% Yes 014 40600132 Benzene 0.0099 lb/1000gal CDPHE - PS Memo 14-02 17.14 17.14 0% No 014 40600132 n -Hexane 0.08595 lb/1000gal CDPHE - PS Memo 14-02 148.72 148.72 0% No **HAP emissions have units of lbs/year.** Permit number: Date issued: Issued to: DO on F trol Division Department of Public Health & Environment CONSTRUCTION PERMIT 16WE0773 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Discovery DJ Services LLC Discovery Fort Lupton Plant 123/9E99 SEC 11 T1 N R66W Weld County Natural Gas Processing Plant Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description El 001 One (1) Caterpillar Model: G3516B SN: TBD natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 1,380 HP and 1400 RPM. This emission unit is used for natural gas compression. Oxidation Catalyst and Air -Fuel Ratio Controller E2 002 One (1) Caterpillar Model: G3516B SN: TBD natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 1,380 HP and 1400 RPM. This emission unit is used for natural gas compression. Oxidation Catalyst and Air -Fuel Ratio Controller E3 003 One (1) Caterpillar Model: G3516B SN: TBD natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 1,380 HP and 1400 RPM. This emission unit is used for natural gas compression. Oxidation Catalyst and Air -Fuel Ratio Controller E4 004 One (1) Caterpillar Model: G3516B SN: TBD natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 1,380 HP and 1400 RPM. This Oxidation Catalyst and Air -Fuel Ratio Controller COLORADO Air Pollution Control Division Detxsnmert at Pub Health G ErnmorrrremC Page 1 of 28 e ° ssi unit is sed for natural gas cp = 'ion. CB 005 Natural gas venting from compressor blowdowns. Emissions from this source are vented to the atmosphere. None RP 006 Natural gas venting from reciprocating compressor rod packing. Emissions from this source are vented to the atmosphere. None D1 007 One (1) Enerflex Ethylene Glycol (EG) natural gas dehydration unit (Model a Serial Number: TBD) with a design capacity of 20 MMscf per day. This emissions unit is equipped with one (1) gas -glycol pump (Make, Model, SN: TBD) with a design capacity of 7.5 gallons per minute. This unit is equipped with a reboiler, still vent and flash tank. Emissions from the still vent are routed to a condenser and then to an enclosed flare. Emissions from the flash tank are used as fuel gas for the regenerator reboiler or routed to the enclosed flare. D2 008 One (1) Ethylene Glycol (EG) natural gas dehydration unit (Make, Model a Serial Number: TBD) with a design capacity of 20 MMscf per day. This emissions unit is equipped with one (1) gas -glycol pump (Make, Model, SN: TBD) with a design capacity of 7.5 gallons per minute. This unit is equipped with a reboiler, still vent and flash tank. Emissions from the still vent are routed to a condenser and then to an enclosed flare. Emissions from the flash tank are used as fuel gas for the regenerator reboiler or routed to the enclosed flare. FUG 009 Equipment leaks (fugitive VOCs) from a natural gas processing facility. None CT 010 Ten (10) 400 barrel fixed roof storage vessels connected via liquid manifold used to store condensate. Emissions from this source are a function of vapor recovery unit (VRU) downtime. 10% VRU downtime is assumed. Vapor Recovery Unit (VRU) and Enclosed Flare during VRU downtime. E5 011 One (1) Caterpillar Model: G3508B SN: TBD natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 690 HP and 1400 RPM. This emission unit is used for natural gas compression. Oxidation Catalyst and Air -Fuel Ratio Controller E6 012 One (1) Caterpillar Model: G3508B SN: TBD natural gas fired, turbocharged, 4SLB reciprocating internal combustion engine, site rated at 690 HP and 1400 RPM. This emission unit is used for natural gas Oxidation Catalyst and Air -Fuel Ratio Controller COLORADO Air Pollution Control Division :#..pan-rniN'p[: L'f Putd%+: Heztlth tl ill airorirre,nC Page 2 of 28 c® pr lion. Plant Flare 013 One (1) enclosed flare (Make, Model, SN: TBD) used to control emissions from the ethylene glycol dehydration unit still vent (point 007 and 008). This enclosed flare also controls emissions from the ethylene glycol dehydration unit flash tank (point 007 and 008) when emissions are not routed to the reboiler and from the condensate storage vessels (point 010) when emissions are not routed to the VRU. None LT 014 Truck loadout of condensate. None Points 001-004: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3516B engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Points 011-012: These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3508B engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1 YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated COLORADO Air Pollution Control Division De a rtrne'tt`vi Ptgtka: HeavHhv ;vireg r. -:eat Page 3 of 28 rant extensions of the deadline. (Regulation Number 3, art :, -ct . .F. 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. Points 001-004 and 011-012: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • Manufacture date • Construction date • Order date • Date of relocation into Colorado • Serial number • Manufacturer • Model Number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 6. Points 007-008: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • The dehydrator manufacturer name, model number and serial number • The glycol circulation pump manufacturer name and model number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 7. Point 013: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 8. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. ,EMISSION LIMITATIONS AND RECORDS 9. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4. ) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type PM2.5 NO, VOC CO El 001 --- 1,138 1,087 1,138 Point E2 002 --- 1,138 1,087 1,138 Point E3 003 --- 1,138 1,087 1,138 Point COLORADO Air Pollution Control Division [hanrtrner t UI Put& hkctth , r_ivirwvnear[ Page 4 of 28 i 1,138 1,087 1,138 Point CB 005 --- --- 832 --- Point RP 006 --- --- 3,618 --- Fugitive D1 007 --- --- 68 --- Point D2 008 --- --- 68 --- Point FUG 009 --- --- 6,081 --- Fugitive CT 010 --- --- 1,308 --- Point E5 011 --- 578 628 578 Point E6 012 --- 578 628 578 Point Plant Flare 013 --- 781 --- 1,545 Point LT 014 --- --- 832 --- Point Note: Monthly limits are based on a 31 -day month. The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds per month. Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per month. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 N0X V0C CO El 001 --- 6.7 6.4 6.7 Point E2 002 --- 6.7 6.4 6.7 Point E3 003 --- 6.7 6.4 6.7 Point E4 004 --- 6.7 6.4 6.7 Point CB 005 --- --- 4.9 --- Point RP 006 --- --- 21.3 --- Fugitive D1 007 --- --- 0.4 --- Point D2 008 --- --- 0.4 --- Point FUG 009 --- --- 35.8 --- Fugitive (COLORADO Air Pollution Control Division fA. anrrremt %hil . Health & L'm:vonrnznt Page 5 of 28 E5 011 7.7 Point 3.4 3.7 3.4 Point E6 012 3.4 3.7 3.4 Point Plant Flare 013 4.6 9.1 Point LT 014 4.9 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 10. Points 007-008: Compliance with the emission limits in this permit shall be demonstrated by running the ProMax version 4.0 or higher on a monthly basis using the most recent extended wet gas analysis and recorded operational values, including: gas throughput, lean glycol recirculation rate, chiller temperature and pressure, condenser temperature, wet gas inlet temperature and pressure, and flash tank temperature and pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request 11. Point 009: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 12. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled El 001 Oxidation Catalyst and Air -Fuel Ratio Controller VOC, CO, and Formaldehyde E2 002 Oxidation Catalyst and Air -Fuel Ratio Controller VOC, CO, and Formaldehyde COLORADO Air Pollution Control Division ULt Heatsh fj Emir TU7trtnt: Page 6 of 28 $ •a ion Catalyst and Air -Fuel Ratio Controller VOC, CO, and Formaldehyde E4 004 Oxidation Catalyst and Air -Fuel Ratio Controller VOC, CO, and Formaldehyde D1 007 Still Vent: Condenser and Enclosed Flare VOC and HAP Flash Tank: Reboiler or Enclosed Flare D2 008 Still Vent: Condenser and Enclosed Flare VOC and HAP Flash Tank: Reboiler or Enclosed Flare CT 010 Vapor Recovery Unit (VRU) VOC and HAP Enclosed Flare during VRU downtime VOC and HAP E5 011 Oxidation Catalyst and Air -Fuel Ratio Controller VOC, CO, and Formaldehyde E6 012 Oxidation Catalyst and Air -Fuel Ratio Controller VOC, CO, and Formaldehyde PROCESS LIMITATIONS AND RECORDS 13. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) El 001 Consumption of natural gas as fuel 80.3 MMscf 6.8 MMscf E2 002 Consumption of natural gas as fuel 80.3 MMscf 6.8 MMscf E3 003 Consumption of natural gas as fuel 80.3 MMscf 6.8 MMscf E4 004 Consumption of natural gas as fuel 80.3 MMscf 6.8 MMscf CB 005 Compressor Blowdown Events 144 events 12 events RP 006 Natural gas vented from compressor rod packing 2.63 MMscf 0.22 MMscf D1 007 Natural Gas Throughput 7,300 MMscf 620 MMscf D2 008 Natural Gas Throughput 7,300 MMscf 620 MMscf CT 010 Total Condensate Throughput 41,198 barrels 3,499 barrels ?COLORADO i Air Pollution Control Division amt-;tPublic !lean b Environment Page 7 of 28 Co sensate hrou ` gut while emissions are routed to the enclosed flare 4 120 barrels ' 350 barrels E5 011 Consumption of natural gas as fuel 39.9 MMscf 3.39 MMscf E6 012 Consumption of natural gas as fuel 39.9 MMscf 3.39 MMscf Plant Flare 013 Combustion of waste gas from the ethylene glycol dehydration unit still vent and flash tank (points 007-008) and the condensate storage vessels (point 010) 49.2 MMscf 4.18 MMscf LT 014 Condensate Loading 41,198 barrels 3,499 barrels The owner or operator shall monitor monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 14. Points 007-008: This unit shall be limited to the maximum lean glycol circulation rate of 7.5 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation Number 3, Part B, II.A.4) 15. Point 010: The owner or operator shall continuously monitor and record Vapor Recovery Unit (VRU) downtime while emissions are routed to the enclosed flare. 16. Point 010: The owner or operator must use monthly VRU downtime records, monthly condensate throughput records, calculation methods detailed in the O&M Plan, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emissions limits specified in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 17. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 18. Points 001-004, 007-008, and 010-014: The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 19. Points 001-006, 009, 011-012 and 014: Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation Number 1, Section II.A.1. a 4.) COLORADO Air Pollution Control Division DtatEtrcme:ttt of Puttdc Heatrtb �,'xnvurury�ait Page 8 of 28 20. • t� is 0 +0� an • 11�� 12: Th equipment is subject to the control requirements for atio a . rt • - •'fines e 8 -hour ozone control area under Regulation No. 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. 21. Point 006 and 009: These sources are subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive V0C emissions from leaking equipment, the teak detection and repair (LDAR) program as provided at 40 C.F.R. Part 60, Subpart KKK (see Regulation Number 6, Part A, Subpart KKK) shall apply, regardless of the date of construction of the affected facility. The operator shall comply with all applicable requirements of Section XII. Compliance with NSPS 0000a, as referenced in the notes to permit holder, shall satisfy the requirements of Regulation Number 7, Section XII.G.1. 22. Point 006 and 009: Minor 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 for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation Number 3, Part B, III.D.2.a). Compliance with NSPS 0000a, as referenced in the notes to permit holder, shall satisfy the requirement to apply Reasonably Available Control Technology (RACT). 23. Points 007-008: This source is subject to the control requirements under Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and specifically uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 24. Points 007-008, 010, and 013: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2 General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 25. Points 007-008: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. 26. Point 009: 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. COLORADO Mr Pollution Control Division eaartr e^itz:i Pubic Health 17 ErNirt FiTrIVIC Page 9 of 28 27. ubject . Regulation Number 7, Section XII. The operator shall quire °'' - ° s of Section XII and, specifically, shall: • Comply with the monitoring 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) 28. Point 010: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 29. Point 010: 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. 30. Point 014: 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 shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 31. Point 014: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a) Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b) All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c) The owner or operator shall inspect onsite loading equipment during loading operations to monitor compliance with above conditions. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 32. Point 014: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable OPERATING Et MAINTENANCE REQUIREMENTS 33. Points 001-004 and 007-012: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the 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.) COMPLIANCE TESTING AND SAMPLING COLORADO Air Pollution Control Division Put,: Elvirernmint Page 10 of 28 34. Points 001-004 and 011-012: A source initial compliance test shall be conducted to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Formaldehyde 35. Points 007-008, 010 and 013: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) 36. Points 005-006 and 007-008: The owner or operator shall complete an initial extended wet gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 37. Points 009: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of NGL (light oil service) that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. These extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. 38. Point 009: 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", "condensate light liquid service", "NGL 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. 39. Point 010: The owner or operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site - specific emissions factor using Division approved methods. Results of site -specific sampling and analysis shalt be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. Periodic Testing Requirements COLORADO Air Pollution Control Division A:aar�rrwra' f : u61w Htnt v Etwirorune:• Page 11 of 28 40. its 1 e04 . nd + 1 2: The engines are subject to the periodic testing requirements s sp- eg a • aintenance (O&M) plan as approved by the Division. Revisions to your OEtM plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 41. Points 007-008: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the ethylene glycol dehydration unit on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. 42. Point 009: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of NGL (light oil service) that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. These extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ADDITIONAL REQUIREMENTS 43. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO), per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. • Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. COLORADO Air Pollution Control Division TilC::i JI P,,b{ c Mtaimb 17vUUFRT ,L Page 12 of 28 44. do Relation No. 3, Part D shall apply at such time that any atio oration omes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.B). 45. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) 46. MACT Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 47. 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. 48. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 49. 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. 50. 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. 51. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 52. 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 COLORADO Air Pollution Control Division UewIrne't`�:t : '4, z 1 leakth b _T.'vunrnent Page 13 of 28 n wn terminate. activi is to be discontinued, the owner must notify the Division llati ." the permit. Upon notification, annual fee billing will 53. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Harrison Slaughter Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Discovery DJ Services LLC Permit for a new natural gas processing facility located in the ozone non -attainment area. COLORADO Air Pollution Control Division Page 14 of 28 No this ,F" it issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Formaldehyde 50000 4,664 3,023 Acetaldehyde 75070 739 739 Acrolein 107028 454 454 Methanol 67561 221 221 Benzene 71432 39 39 Toluene 108883 36 36 Ethylbenzene 100414 4 4 Xytenes 1330207 17 17 n -Hexane 110543 98 98 2,2,4- Trimethylpentane 540841 22 22 002 Formaldehyde 50000 4,664 3,023 Acetaldehyde 75070 739 739 Acrolein 107028 454 454 Methanol 67561 221 221 Benzene 71432 39 39 Toluene 108883 36 36 Ethylbenzene 100414 4 4 COLORADO Air Pollution Control Division UE:,x�rrrtir t'%t .,Lay € {eaEtt. Fs.,Znvirurv.^.am Page 15 of 28 n -Hexane 110543 es 17 17 98 98 2,2,4- Trimethylpentane 540841 22 22 003 Formaldehyde 50000 4,664 3,023 Acetaldehyde 75070 739 739 Acrolein 107028 454 454 Methanol 67561 221 221 Benzene 71432 39 39 Toluene 108883 36 36 Ethylbenzene 100414 4 4 Xylenes 1330207 17 17 n -Hexane 110543 98 98 2,2,4- Trimethylpentane 540841 22 22 004 Formaldehyde 50000 4,664 3,023 Acetaldehyde 75070 739 739 Acrolein 107028 454 454 Methanol 67561 221 221 Benzene 71432 39 39 Toluene 108883 36 36 Ethylbenzene 100414 4 4 Xylenes 1330207 17 17 n -Hexane 110543 98 98 2,2,4- Trimethylpentane 540841 22 22 005 Benzene 71432 38 38 Toluene 108883 26 26 Ethylbenzene 100414 7 7 Xylenes 1330207 18 18 n -Hexane 110543 103 103 2,2,4- Trimethylpentane 540841 37 37 006 Benzene 71432 163 163 Toluene 108883 112 112 Ethylbenzene 100414 29 29 COLORADO Air Pollution Control Division Page 16 of 28 es 0207 75 75 n -Hexane 110543 444 444 2,2,4- Trimethylpentane 540841 159 159 007 Benzene 71432 8,153 408 Toluene 108883 2,784 140 Ethylbenzene 100414 328 17 Xylenes 1330207 1,448 73 n -Hexane 110543 5 1 2,2,4- Trimethylpentane 540841 2 1 008 Benzene 71432 8,153 408 Toluene 108883 2,784 140 Ethylbenzene 100414 328 17 Xylenes 1330207 1,448 73 n -Hexane 110543 5 1 2,2,4- Trimethylpentane 540841 2 1 009 Benzene 71432 1,009 428 Toluene 108883 1,014 419 Ethylbenzene 100414 338 138 Xylenes 1330207 912 371 n -Hexane 110543 2,758 1,170 2,2,4- Trimethylpentane 540841 1,386 574 010 Benzene 71432 25,975 130 Toluene 108883 11,690 59 Ethylbenzene 100414 1,440 8 Xylenes 1330207 3,152 16 n -Hexane 110543 74,445 373 2,2,4- Trimethylpentane 540841 18,159 91 011 Formaldehyde 50000 2,318 1,502 Acetaldehyde 75070 367 367 Acrolein 107028 226 226 Methanol 67561 110 110 Benzene 71432 20 20 COLORADO Mr Pollution Control Division Mean b. ElvIre rune,m Page 17 of 28 Ethylbenzene ne 883 18 18 100414 2 2 Xylenes 1330207 8 8 n -Hexane 110543 49 49 2,2,4- Trimethylpentane 540841 11 11 012 Formaldehyde 50000 2,318 1,502 Acetaldehyde 75070 367 367 Acrolein 107028 226 226 Methanol 67561 110 110 Benzene 71432 20 20 Toluene 108883 18 18 Ethylbenzene 100414 2 2 Xylenes 1330207 8 8 n -Hexane 110543 49 49 2,2,4- Trimethylpentane 540841 11 11 014 Benzene 71432 18 18 n -Hexane 110543 149 149 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: Points 001-004: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx 1.51x10"'" 5.0x10-' 1.51x10-' 5.0x10-' CO 7.34x10-' 2.43 1.51x10"' 5.0x10"' VOC 1.45x10"' 4.8x10"' 1.45x10"' 4.8x10"' 50000 Formaldehyde 5.28x10"` 1.75x10-' 3.42x10' 1.13x10"' 75070 Acetaldehyde 8.36x10-3 2.77x10-' 8.36x10"3 2.77x10' 107028 Acrolein 5.14x10"3 1.7x10' 5.14x10-3 1.7x10"` 67561 Methanol 2.5x10-3 8.28x10"3 2.5x10"3 8.28x10"3 Note: Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7,301 Btu/hp-hr, a site - rated horsepower value of 1,380, and a fuel heat value of 1,100 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 ICOLORADO Air Pollution Control Division Page 18 of 28 C Poi eta ! ncontrolled EFSource Controlled EF Source 7 I I � ceta . e y. e �- Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 107028 Acrolein AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 67561 Methanol AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 Point 005: CAS # Weight Fraction of Gas (%) Pollutant Uncontrolled Emission Factors (lb/event) Source 26.73 VOC 67.84 Gas Analysis Note: The VOC content of the gas used in the application is based on a representative gas sample from the Ward Petroleum Sharp 24-3-11HC site. Point 006: CAS # Weight Fraction of Gas (%) Pollutant Uncontrolled Emission Factors (lb/MMscf) Source 26.73 VOC 16,151.56 Gas Analysis 110543 0.28 n -Hexane 168.94 Mass Balance Note: The VOC content of the gas used in the application is based on a representative gas sample from the Ward Petroleum Sharp 24-3-11HC site. Point 007-008: The emission levels contained in this permit are based on the information provided in the application and the ProMax 4.0 model. Point 009: Component Gas Service Heavy Oil Condensate (Light Oil) NGL (Light Oil) Water/Oil Service Connectors 7,500 2,658 404 9,465 11 Flanges 959 325 230 1,437 68 Open-ended Lines 1 0 0 318 0 Pump Seals 0 32 9 4 0 Valves 1,244 382 235 2,886 24 Other* 36 14 6 69 0 VOC Content (wt. fraction) 0.2662 1 0.9982 0.5304 1 Benzene Content (wt. fraction) 1.022E-03 --- 2.212E-2 2.435E-3 --- Toluene Content (wt. fraction) 6.969E-4 --- 3.434E-2 1.688E-3 --- Ethylbenzene (wt. fraction) 1.80E-4 --- 1.34E-2 4.39E-4 --- Xylenes Content (wt. fraction) 4.707E-4 --- 3.681E-2 1.147E-3 --- n -Hexane Content (wt. fraction) 2,783E-3 --- 5.978E-2 6.72E-3 --- 2,2,4- Trimethylpentane Content (wt. 9.931E-4 --- 4.529E-2 2.415E-3 --- COLORADO Air Pollution Control Division Jepurrne^R.-3t Puaz HusEin 6 El-riunnmenc Page 19 of 28 *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 SWater/Oil ervi Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Table 2-4 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 and liquids analyses. Point 010: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 74.28 3.71 ProMax 71432 Benzene 6.30x10-' 3.15x10-2 ProMax 108883 Toluene 2.83x1O' 1.42x10"` ProMax 100414 Ethylbenzene 3.49x10-` 1.75x10-3 ProMax 1330207 Xylene 7.65x10-` 3.82x10-3 ProMax 110543 n -Hexane 1.80 9.03x10"` ProMax 540841 2,2,4- Trimethylpentane 4.40x10' 2.20x10-2 ProMax Note: a) During operations when emissions are routed to the enclosed flare, the controlled emission factors in the table above shall be used to calculate actual emissions. These emission factors are based on the enclosed flare control efficiency of 95%. b) During operations when emissions are routed to the vapor recovery unit (VRU), a control efficiency of 100% may be used to calculate actual controlled emissions. Points 011-012: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx 1.51 x1O' 5.0x10-' 1.51x10-1 5.0x10"' 5.0x10-' CO 7.84x10-' 2.58 1.51x10"' VOC 1.67x1O' 5.5x10-' 1.67x10-' 5.5x10-' 50000 Formaldehyde 5.28x10-` 1.74x10-' 3.42x10-` 1.12x10-' !COLORADO Air Pollution Control Division He ltd b to vunrnenc Page 20 of 28 CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr 75070 Acetaldehyde 8.36x10-3 2.75x10 ` 8.36x10"3 2.75x10"1 107028 Acrolein 5.14x10-3 1.69x10-` 5.14x10-3 1.69x10-` 67561 Methanol 2.5x10-3 8.23x10-3 2.5x1O3 8.23x10-3 Note: Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7,254 Btu/hp-hr, a site - rated horsepower value of 690, and a fuel heat value of 1,100 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 75070 Acetaldehyde AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 107028 Acrolein AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 67561 Methanol AP -42 Chapter 3 Table 3.2-2 AP -42 Chapter 3 Table 3.2-2 Point 013: CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Source NOx 0.138 TNRCC Flare Emissions Guidance CO 0.2755 TNRCC Flare Emissions Guidance Note: a) The emission levels in this permit for this point are based on the heat content and gas volume from the following process streams: Process Stream Heat Content (Btu/scf) Gas Volume (MMscf/year) Condensate Storage Vessel Waste Gas 2,474 25.67 Ethylene Glycol Dehydration Unit Still Vent Waste Gas 29 21.69 Ethylene Glycol Dehydration Unit Flash Tank Waste Gas 801 1.76 Purge/Pilot Gas 1,023 0.04 Average Heat Content 1,334 a.��NI Total Gas Volume \�� 49.2 COLORADO Air Pollution Control Division fhrzusrner;t a'?�vL�-.tie tchb_mvurvne+i[ Page 21 of 28 b) Total actual emissions for this point are based on the average heat content and total gas volume of the process streams routed to and controlled by the enclosed combustor. The following equation demonstrates this calculation: EF,16 ll (Average Heat Content, MMBLu) (Cos Volme Routed to Flare, MMscf l ( 1 ton l Combustion Emissions py — (MMBtu)s 1 MMscf / \ year ) \2000 1b) Point 014: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Source VOC 2.36x101 CDPHE PS Memo 14-02 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) Points 001-004 and 011-012: These engines are subject to 40 CFR, Part 60, Subpart JJJJ— Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.govittn/atw/area/fr18ja08.pdf 9) Points 001-004 and 011-012: These engines are subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr181a08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 10) Points 006 and 009: These sources are subject to 40 CFR, Part 60, Subpart 0000a —Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting - effective August 02, 2016). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: https://www.gpo.gov/fdsys/pkg/FR-2016-06-03/pdf/2016-11971.pdf 11) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, CO, Formaldehyde, Benzene, n - Hexane and Total HAPs COLORADO Air Pollution Control Division Page 22 of 28 tic ' Source of: V0C MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable Major Source Requirements: Not Applicable Area Source Requirements: Applicable MACT ZZZZ NSPS KKK Not Applicable NSPS 0000 Not Applicable NSPS OOOOa Applicable 12) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Mr Pollutiea Control Division beeentre•re i Ruble; He th , rmevur rr;m Page 23 of 28 CHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. COLORADO Air Pollution Control Division smer:t of Public He thEnvironment Page 24 of 28 2.1. n o` .pato+ a•ermantly replace the existing compressor engine with another ength t , mod , .nd horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: https://www.colorado.gov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring-Protocol.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. -COLORADO Air Pollution Control Division xneret ear vurr ni Page 25 of 28 For .. o 1 a ort rm ° mit tha is either input based (lb/mmBtu), output based (g/hp-hr) or ntra = g ' 15% °� that the existing unit is currently subject to or the • • b."'•'" pp�• replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B S II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or S02 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. COLORADO Air Pollution Control Division ih.arr,rn,,' c 3t Nubtc I -1 alt%i ti = rmunmrnc Page 26 of 28 Theme:.: e em "n t sha "` appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500≤Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.6 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, COLORADO Air Pollution Control Division a •rT nc.•ur.:jac Heethfr. Envirorv.^eac Page 27 of 28 and -.. ge. 're went for he pe anent engine replacement shall be included in the ..l rt ..rt -.lire ondi : 2.1.2. Any testing required by the MACT is in addition to APP Y `" q that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. COLORADO Air Pollution Control Division Huilaa (Par Rent: Page 28 of 28 • Internal Combustion En Emission Source AIRS ID: CY' .10 E a.o your organization.] [Provide Facility Equipment ID to identify how this equipment is referenced w w Facility Equipment ID: nested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information for NEW permit or newly reported emission source for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) Change company name O It Transfer of ownership ❑ ❑ Blank APENs will not be accepted. y P y a OV ? o o a • C W R c p a et r -D t0 o0 z 2. Qy .V ❑■❑❑ ED N N a Source Location: Section 11, T1N, R66W Elevation: 5,135 co C a) y U ti • U) o C/) M U) o 5 _os ZIP Code: 75230 Mailing Address: 7859 Walnut Hill Lane, Suite 335 (214) 414-1980 Phone Number: Cory G. Jordan 4.C Section 03 — General Information C O CO R b U U U) U) L U) O cn '.) U) 2 C U. C N 0 C co OO y 0 m 0. O v O On cn C X U) ti 3 N U, x U U CO r CO cn O L N Normal hours of source operation: Gas Compression O U) 'C L c7 = R O C 8 z O 00 V 0... W C Z 0.)-1 N U P. M M 0. a) Q N N r!,4 -,; R L. C O C U U U) • y ,..0,D ,.D g 0 a) SOT. C E M M M= .• ^ O C O O O z cu • U• L. R''r. C _ '. C p :6 pp '� `A C W .. j C it L O `mil z — —_ U) ▪ C A w •R Z Pw-, p v ^ y v ▪ a co • i N • V a.D ti ^ ° a. co .+-. = o c- v On . c s E o o a c°, o. U d ^ 6 > °: • S a o ≥ o o0 > to L • • U O C C O A g > - O R O O 6r N • C >" c UoO0 o u y ' N o0 O w aR) a, A ?' • g" L A , U C.^ o o a x w C ^ U c 'y U) •° m y yo7c.AV u 5 op 'a.^ e� oao v .° a -a.-- .- H �„ 27UdYC w° Qcn APEN fornts: htl n://vk w\v v/cclt,he/permitstatus U,; C U) U 0. Q ❑ M Date engine construction commenced: O N Date the engine was ordered: c0 C Date of any reconstruction/modification: co C Date the engine was relocated into Colorado: O z cn O C. CU CO F") U) O 7 U) R _J a)) 2 0. ° =u a� IV • O U) _ -_ • c 3c C) CD cu z O CO U •^ • o U). 'd 0.0 U) Engine date of manufacture: 2015/2016 C a) O Manufacturer: ❑ ❑ DE 7.1 On CG O L) O M NZ Manufacturer's maximum site ratine: a) On F � C L U .0 a❑ Combustion: .VU co C What is the maximum number of hours this engine is used for emergency back—up power? Form APCD-201-RICEAPEN-Ver.02.10.2014.docx co CD M FORM APCD-201 Internal Combustion Ermine' Digitize Plot Plan (Preliminary) C) v co co N u-) CO CO O z 0 o 0 > V N N t) U v O) co Cl 2 C op C C > r U N Q72C) Y .W G v 0 C V C) Cr) w Q C O Other: Length (inches) = o ❑ �■ Ve ): ❑' Direction of stack outlet (check one): Section 06 — Fuel Consumption Information C. C) O Seasonal Fuel Use (% of Annual Use) O C e) tO N ti N C N C) w C) O N CO 0 c. vp b0 c. Requested Permit Limit Y0 O d U C G a) U) 0 N- 0 0 Natural Gas O z C ❑ ) CCS L C N N L. >- C 0 = �i. ` J �y C r o c) c) e ra C) - LL > O Q C C) a • C 3 U) b = • O C. h caj hA N n O C) cr A D > Estimation Method or Emission Factor Source AP -42 R N a N Q AP -42 Manufacturer Manufacturer Manufacturer 7 N a N a N O. Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 11 Requested Permitted Emissions Controlled (Tons/Year) 7T O O 0 O C 0 O = G M 0 O co 0 O 6.7 6.4 N- 0 7) 0.37 0.23 0.02 Uncontrolled (Tons/Year) ., O G it O O C. 0 Q 0 d N- c0 V c0 N co 0 N N- O N O 0 O lJ Emission Factor Documentation attached Data year for actual calendar yr. emissions below & fuel use above (e.g. 2007): II nia Actual Calendar Year Emissions2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu g/hp-hr g/hp-hr g/hp-hr J .-• C co 2 C m 2 C m 2 Uncontrolled Basis ,', v J ,- I." , or ,- L O O O 0.5 V O Y J Q ''\1 c O V O O O O V O O Control Elfciency (% Reduction) o O O O. O O C) N. O CC) O O O Control Device Description L C C 0 V] Primary C ...F..1 CO C C C C C a) C Oxid. Cat Oxid. Cat Oxid. Cat fC C N C C C Pollutant II TSP o r. X C X C C 1 C CO Formaldehyde Acetaldehyde O N p Q = f 0 c (0 O C� O U C C. C) CU C) a C 0 N 0. C) N N O t C >, CC CO N w 0 CU o z N N CC Q N at Form APCD-201-RICEAPEN-Ver.02.10.2014.docx Internal Combustion En J-.r(7*-)Vr 1Y Emission Source A cr N E LL. [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] w Facility Equipment ID: nested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information for NEW permit or newly reported emission source for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) N C', N c u c Cu ee O .' o ❑li .) 0) a -o 0. C O V > R _ C U CO CO Lt z I c 0 U a) in Source Location: U7 O1 U) 1-1 R W CO C . V 00044 N o Q: -a U 5 Q :73 o on �z = ZIP Code: 75230 7859 Walnut Hill Lane, Suite 335 (214) 414-1980 Phone Number: Cory G. Jordan cto O 0 OU Section 03 — General Information For new or reconstructed sources, the projected startup date is: n/a T O O N C p_ o E 0 a) CO N C.D at X N - 0 Z Cu General description of equipment purpose: o •a o 5 0. on zi7 U • 0.. C N Q O L c N a, b P a E - r co C > o U Co. L U U K, 7 0 '.r y 7 .7 b)•6) big c W • C OD L O 9y 7 CO 0 •-• 06° O1 0 U Y y Cu i 7.C .� y •� V CC N Z P O u T C C O •.: C' C t E Cu c w i^ cd � C L 0 4% U O CO d •c LO Cu 5 E cc3> "> U E V c > o 0 oL u° aCi A 7,0 o C tw•fl� 0 y o — o 0 0 _ E•= Le _oo U E. 0 C� 4 aX)U zvjc < p CC O V L � N U o 00 LO 4))U U 40 o o c en u O CC 00 n en 1" -- en rn M Co CND Co E M M en c o o Z ,o z 0. • '0 C N i 0 N P. CU > U o p O N .0 Q C o U O C '"E - c. 0o ro • _ ° Q� guv/cdphe/A P APEN forms: h ado.gov/cdphe/permitstatus Application status: Date engine construction commenced: m NN Date the engine was ordered: Cu C Date of any reconstntction/modification m C Date the engine was relocated into Colorado: o O C z CC cle act N Cu 0 zo >0 C U 0 N =1 N U C. r2 C) co a) z U Cu C .L U A. CD C W 2015/2016 Model: G3516B ❑ ❑ 0 0 0. Cu C) 0 0 a CO W U C. C' i • C. F 0 C..: O O Manufacturer's maximum rated horsepower @ sea level: Manufacturer's maximum site rating: U ai o U C Cu Cu ' 7a 0. 0 0 o LC R. R. c. 'C O O O O U U C C O O X X 0 0 a a U U U U ❑ ❑� Ca C What is the maximum number of hours this engine is used for emergency back—up power? Form APCD-201-RICEAPEN-Ver.02.10.2014.docx N 0 CSD Lt's 0O\ �/ Cr) FORM APCD-201 1311 • VI ---p,..°',M11 9 ,,„ ,, .. , „„,,,, Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) IDigitize Plot Plan (Preliminary) Seasonal Fuel Use (% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov u' csi O V/ I Estimation Method or Emission Factor Source AP -42 AP -42 . AP -42 Manufacturer IManufacturer IManufacturer H AP -42 AP -42 I AP -42 n is complete, true and correct. If this is a mdition of general permit GP02. l"V l' (2� r/ orq,� print) Title rm APCD-201-RICEAPEN-Ver.02.10.2014.docx _TE Co ..1. O N .7 1 N Requested Permitted Emissions Uncontrolled Controlled (Tons/Year) (Tons/Year) 0.03 6.7 6.4 6.7 1.51 0.02 f r, JTM) y v ♦. Ot O .,. CO J 0 UTM Northing or Latitude (meters or degrees) 4434719 u7 N %.: O Q O Q O O M O 01 N O u7 O O V O CO I _L9I 6.4 Cr N 0.37 0.23 N OI cp '",4O - J O O Q O 9 O Oy. N M co (V O O .d. UTM Easting or Longitude (meters or degrees) c4 c...., o 0 O v Actual Calendar Year Emissions' Uncontrolled Controlled (Tons/Year) (Tons/Year) Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not lis y or missing information and requires re -submittal. Mc, annual emission fees will be based on requested emissions. formation contained herein and information submitted with this applicatioi that this source is and will be operated in full compliance with each c C- Cory G. Jordan Date Name of Legally Authorized Person (Please Page 2 of 2 Fo v v co N Co Fuel Heating Value (Btu/lb, Btu/gal, Btu/SCF) 1,100 Btu/scf M y 0 O = N N M Horizontal Datum (NAD27, NAD83, WGS84) NAD83 CE (APEN) & Application for Cons Emission Factor Uncontrolled Basis Units 7 co lb/MMBtu Ib/MMBtu Ib/MMBtu g/hp-hr g/hp-hr g/hp-hr 1) v lb/MMBtu y in lb/MMBtu Moisture (%) a 9 a Actual Reported for Calendar Year Requi Is this engine equipped with an Air/Fuel ratio controller? El Yes ❑ Section 07 — Emissions Inventory Information & Emission Control Information E Emission Factor Documentation attached Data year for actual calendar yr. emi.! 0.48 Cli �U 129.2 heal ❑ Vertical with obstru Circular: Inner Diameter (inches) f vl r,'-ca;�i` el tr H sa L '� u, '_I ,y - c- co o o Co T • �J ClU • 0 fi v o 8 0 0 v 0 0 Flow Rate (ACFM) 6089.4 - cr C- O O ® 9 0 0 0 Control Efficiency (% Reduction) "" CC. O O O O O o T of r e1 Ci co O O O E. H 0 Control Device Description Primary Secondary Operator Stack Base Stack Discharge Stack Elevation Height Above 1D No. (feet) Ground Level (feet) Co co Oxid. Cat Oxid. Cat Oxid. Cat Co cn ,-- m C m C m C m C m C co C co C CO C Pollutant TSP xON VOC CO Formaldehyde Acetaldehyde Acrolein N W 2. 0 0.1 O 7) d ee(VCr.I Internal Combustion En [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] w Facility Equipment ID: nested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information for NEW permit or newly reported emission source for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) Change company name C Transfer of ownership ❑ ❑ ange fuel or equipment ange permit limit 0 d d 7 ( 4.4 d L" r C) N O 6 U_ u z&) U Source Location: Section 11, TIN, R66W C.) ❑ ❑ LU CO L6 O 0 0 433, O L.14 Q LI p d C El Z o d (U (U 7 V 0 x ZIP Code: 75230 (214) 414-1980 Phone Number: Cory G. Jordan O- .. va U Section 03 — General Information m C For new or reconstructed sources, the projected startup date is For existinc sources, operation began on: Normal hours of source operation: Gas Compression General description of equipment purpose: o ,) o L of - z C. w E Z „ . a 0 G ^� N Q r Q R .07 U) 0 v cL. G U) C. C. E r W U © c C Q P U Z N L ._ c .'m on c. o d > o a co E i v] V Q N U a y CE ,p ti = u Mr 0. C ca T L R.,, V V C s E o c V i= a E) •C a; U) C o E _ c,- C u Y L O . y r o V C d a I. - m o M= E oCIII Q > c: , E Z e7 c.. O U C' m O c))C o o s w o p L o _ U Go (,',^ oo. F v ZusUQ For guidance on how to complete this APEN form: O 0 00 WI C- APEN forms: litio;//www.c( colnrado.v/cdphc/nen Application status: htlp://\ Date engine construction commenced: N Date the engine was ordered: co C Date of any reconstruction/modification: co C Date the engine was relocated into Colorado: 00 O z a C) Engine displacement: co 0 LO N Engine date of manufacture: z .D 0 2 C Manufacturer: ❑ ❑ U co 3 .0 ea 72 CL n_ 0 >' U) R Q. E C G (J ❑ 0 O O O CO co Manufacturer's maximum rated horsepower @ sea level: Manufacturer's maximum site rati CO C- Engine Brake Specific Fuel Consumption @ 100% Load: cr:C V 0 U C) ai o C C U c0 • C y O a O O 0 0 .r:, .� E N CL CL ca w a O O al al U Q) U) O O 0 0 U U U U co C co C What is the maximum number of hours this engine is used for emergency back—up power? Form APCD-201-RICEAPEN-Ver.02.10.2014.docx N O U) too FORM APCD-201 Cid • Internal Combustion En • Emission -Sou rce AIRS ID: ± Permit Number: O O O a) L C C CC "O a) O a. CC a) C. C C (a—( O C a) a) C C O Ca N a) a) a) C C. a) O CC C E C C CC Vi 0 a) cr o Digitize Plot Plan (Preli v OD V to Z E v N N V k^ O O N z z O v C) N a; O w" C) CO C. E CO CO C) w C G TICS C .i. ❑ co U CC Ca C C a) Direction of stack outlet (check one): Other: Length (inches) = N Inner Diameter (inches) = L U Section 06 — Fuel Consumntion Information a) C. T Seasonal Fuel Use (')/0 of Annual Use) 0 z 6. rip C) N CA N N N 1,100 Btu/scf Requested Permit Limit C CD O 0 O Natural Gas C z AP -42 1 AP -42 N a Q AP -42 Manufacturer Manufacturer IManufacturer = 1- J N 1- a_ \ / AP -42 II N a a Q Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Uncontrolled Controlled (Tons/Year) (Tons/Year) O O O O O O O O 6.7 7 cO N (C C) c' 1 0.37 N O O p C ch O 0000 O .. Ca O O O C) O O CO O L'9 V'' cO rcl.N an N CO N 0.37 0.23 N O O actual calendar yr. emissions below & fuel use above (e.g. 2UU7): ( Na Emission Factor Actual Calendar Year Emissions2 Uncontrolled Controlled Uncontrolled Basis Units (Tons/Year) (Tons/Year) lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu g/hp-hr g/hp-hr g/hp-hr lb/MMBtu lb/MMBtu lb/MMBtu . r y _ ,n 1 r � J O O O Lc) O O T C4.O L) ® Ca O cA T C? CC) o O cn 0 O 0.0004 O O O O O O S C) a— Li) CO O O O co C ca C m C m C m c0 m U -o x Oxid. Cat Oxid. Cat co c m C co C TSP aV a 0 0 Z> p o U II Formaldehyde v N a m 8 Q o c.7 Q Benzene 1 • CC U, ^ N U C.. U L O C ca -o O 0 U O C aj I o Q „C a) —C7( a) a C\� C �\ Ur - O • 1� 0 O C ' '- .CO C C) C a) C, C O a.) 'p a) N O C T CC Co a) O O a) CC z a) CC C CC Ca T 0. O. CA a) 0' a) a w Form APCD-201 RICEAPEN-Ver.02.10.2014.docx N w O N a) CC • Internal Combustion En CG •U V E V Co) L w 0 C.) W 0.4 U E4 O z O r O [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Facility Equipment ID: nested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information Request for NEW permit or newly reported emission source Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) Request MODIFICATION to existing permit (check each box below that applies) Change company name C Transfer of ownership ❑ ❑ Change fuel or equipment Change permit limit ❑ ❑ ❑■ ❑ ❑ ❑ ❑ N M N O vU UU d z� Source Name: Discovery Fort Lupton Plant County: Weld C) w Elevation: 5,135 Request PORTABLE source permit Request APEN Update ZIP Code: 75230 Emissions data must be completed. Blank APENs will not be accepted. F Co ui (214) 414-1980 Phone Number: Cory G. Jordan C E V u Ca 0 C Co E V C 0 _ O Co Z w° z o d ❑ Cory@discoverymidstream.com Section 03 — General Information For new or reconstructed sources, the projected startup date is: n/a For existing sources, operation began on: weeks/year Normal hours of source operation: Gas Compression General description of equipment purpose: o C- CO O E 2 E V O O. CO L v r = j dt o 0.3 O O CO Cr) WI C. M r M N NCN N r M M in ooZ APEN forms: lilt c -77 C) CO C 0 V Q Date the engine was ordered: Date of any reconstruction/modification: Co CO Date the engine was relocated into Colorado: O z Co Co C) CO CO 0 a CO � J O -o n. C) C c O Co E L r V C 1• C C w V CO 1.O N 0 N Engine date of manufacture: CO CD CD a) O Co a) U Manufacturer: ❑ ❑ C) O C) v c C O ❑ E 00 W O O p CO C) a) aC) CO a o 0 v U CO V) C V x co co C _ ti ti y 9) CO o c 6 O N- Engine Brake Specific Fuel Consumption @ 100% Load: F CO U 1O C) Ln co 0 .D ❑E E r CO w CO z ED 0 O- 5, U E ❑ -E 0 CO U • O C CO ' ti COo O O L. 0 .CO .: s c. at' -C O O O O CO. CO. U C.) C) ti a) CS" O O x x O O N N U U ❑o C CO co C What is the maximum number of hours this engine is used for emergency back—up power? Form APCD-201-RICEAPEN-Ver.02.10.2014.docx LCD V J Cr) FORM APCD-201 eira 110.4 rl 71) Internal Combustion En Emission Source AIRS ID: 2 F O an O J CO -J aa) L .re C CO 'O a) O C. U U a) C. C E 4-. O C a) a) C C O CO C C C CO N a) a) a) CO I.. CO a) CO 0) C E` o c N C O CO C u � E i, L O,1 -T; U o O C C) 2 Digitize Plot Plan (Preliminary) C Q on 2 C) b0 .2. N z C) E 0000 N CC) co 0 z z o J N cri N C) cc O Q C)) CO O CO C Cn w ❑ Other (Describe): CO C) C) Direction of stack outlet (check one): Width (inches) = Circular: Inner Diameter (inches) = ing Shape & Size (check one): O s CU C C ) � L O CO a, C O O. a) a) � r, CA a, 0 N CO V CO te. 0 V C O E L R CO V R R L G CO C. C CO C 0 R C O Estimation ethod or Emission Factor Source AP -42 AP -42 AP -42 AP -42 Manufacturer Manufacturer Manufacturer C N Q AP -42 - II N < Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) 0000 O O a a I. 6.7 6.4 N- a Lf) 0.37 N a O O Uncontrolled (Tons/Year) co O O O C O O O 0,003 b -till (•) O d 6.7 7 a 32.4 N C-) N 10.37 10.23 N a O Actual Calendar Year Emissions' Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu g/hp-hr g/hp-hr g/hp-hr fi Ib/MMBtu lb/MMBtu Ilb/MMBtu Uncontrolled Basis v, L ('L 3. f ._ ,- O9 O OO o 0.5 V a T vi g PC T o v co O a _ C) O a v O O o Control Efficiency (% Reduction) O O O O O O C N- U) M O O O Control Device Description Secondary CO C. CO ,..c2 CO C CO C CO C (O C Oxid. Cat Oxid. Cat I Oxid. Cat CC C CO C CO C Pollutant 'II TSP G�.. o.. C C./.1 xON II O > C U Formaldehyde II Acetaldehyde I C o 0 Q I) a CL) CO 0, En U a) O U 'O C CO a) C a) a) bA a0 E O O .tn. O OO u O C .0 a) + U L 3 .Ta, E a) O N t17 _O -O •N .— E CO CO t 9. E at C) o L C U v C c7 • ^O an U C = ai ca r, a) a) L E O an y O an .Y N � n N .O ca Ti o Q O a) N C) o v a >, C. O. z s� E- C. m 6 Z C 0 a V �+ O V., C "`"t 1 47) U C ��, C R o \r- o NL sue. bD N QO v N C X11 OO E O C i a • cog 9 bA c c6 D O O 0 C • 1 a) CO a) C. C O a) • N 0 t o CC a a) O O CO z Y CO Ca Form APCD-201-RICEAPEN-Ver.02.10.2014.docx N O O N an CO C. 7,4 2 Cr"' Cr" Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit tt & AIRS ID] lur i- Permit Number: is referenced within your organization.] [Provide Facility Equipment ID to identity how this equipm m U Facility Equipment ID: uested Action (check applicable request boxes) Section 02 — Re Section 01— Administrative Information Request for NEW permit or newly reported emission source Request PORTABLE source permit Change company name Change fuel or equipment a O El Transfer of ownership Change permit limit Request APEN Update D❑0 0 Discovery DJ Services LLC Discovery Fort Lupton Plant 8 E z z 0 U w Elevation: 5,135 c ZIP Code: 75230 Mailing Address: 7859 Walnut Hil Lane, Suite 335 Emissions data must be completed. Blank APENs will not be accepted. X E— f9 m O Section 03 — General Information For new or reconstructed sources, the projected startup date 0 ro 0�0 .O 0 C) 0 U) • O C y N C) 3 Normal Hours of Source Operation: General description of equipment and purpose o . E O CA vi ° ! • , 'Cr t2- ,_... y C) M rn a °' rn a c ti y D ,O VD C. b U + e t+1 O ` ,..,),=,,, O o z 44 a a q C • C. w E -, p ^ c4 W p ai ti 69 ,q Py = _ y w d ti = c • 5 � 3 dx • C © > > © U , c.) 30 C .3 p T O q C }- A A q A 17-0 w T C C m, O• 3 � 'ti ^O y O O o N .' W ~ R R V C a CO d E a o U N W L a> ti > a> OO O �, 4:= , L O U O= O .d " 5 R p 0. M N p a. E-• U) C, C d c/a APEN forms: Iii Application stat z N O uinment Information & Material Use Manufacturer: 4.2 Mscf/event/unit w C w 0 co 0 3 Check box to request copy of draft permit prior to issuance. Check box to request copy of draft permit prior to public notice. ❑ 0 O 4.4 A Natural Gas .474 Nti -o 0b p o 4. 4." Other Process M FORM APCD-200 4) a • U' C C RS Ca. Oa z WI C s�r^ V1 ICI a• Emission Source AIRS ID: 11 Section 05 — Emission Release Information (Attach a separate sheet with relevant information in the event of multiple releases; provide datum & either Lat/Long or UTM) C O c N 4 Digitize Plot Plan (Preliminary) c 0 CO Csl P E QzCID ° C Z 0 z v > 4,14 Z 0 < 0w Hv z Z 441, CO CO 5 41 -z m U Width (inches) = 0 II 0 G1 .0 0 D -i0 G a M 0) o �^ 0 x ▪ ❑ 4- .5 U 0 C 0O m 0 Direction of outlet (check one): went & Fuel Consumption Information 4) Section 06 — Combustion E ^0 0 0) 0 z z 0 U to 4) ''0 .41 0)) O' R 0 O 0 0, G) PTV ^/U 3 4) 0 a Section 07 — Emissions Inventory Information & Emission Control Information Estimation Method or Emission Factor Source Mass Balance I pollutants not listed above. Requested Permitted Emissions Controlled I (Tons/Year) 7 Uncontrolled (Tons/Year) T hr Actual Calendar Year Emissions' Controlled (Tons/Year) Uncontrolled (Tons/Year) IPlease use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report Emission Factor Units 4) > Uncontrolled Basis 04.1 rr chi Control Efficiency (% Reduction) Overall Collection Efficiency Control Device Description Secondary g 0. Pollutant I TSP a I PM2,5 O `ON I C Ov 1; g L L O 121 CQ 44 n r1 0, N cn N a 0 a, 0 0.0 N N N 0 z c0 A Form APCD-200 — GeneralAPEN — Ver.02.10.2014.docx w O bA N CO Cst E r�r v i�. O CZI a Co Co F�1 0 O d a Emission Source AIRS ID: 17 ?a [Leave blank unless APCD has already assigned a permit # & AIRS ID] 0 Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Facility Equipment ID: nested Action (check applicable request boxes) Section 02 — Re Section 01— Administrative Information Request for NEW permit or newly reported emission source Request PORTABLE source permit Change company name 0 Transfer of ownership ❑ ❑ Change fuel or equipment Change permit limit s with a Federally enforceable limit on PTE : 0) a) 01' ❑ ❑ 4 Request APEN Update o❑❑ 0 00) Elevation: 5,135 ZIP Code: 75230 Mailing Address: 7859 Walnut Hill Lane, Suite 335 Emissions data must be completed. Blank APENs will not be accepted. co co To 0 Section 03 — General Information For new or reconstructed sources, the projected startup date i For existing sources, operation began on: 0) 3 173- C:7) N L() ci) 0. oo o 3 0 0 H 0 U lD ,g 0 Q O to N N O. E O tv U Normal Hours of Source Operation: General description of equipment and purpose: ob y tO 0. y z 0) 'C U 0 a>i U�jy r C O'C . v° q o �C� Do 0 0 0 a) 9. >` O 0. E 0 > 3 W y o C .O O w0) 0 o o •0 0 0 o• cJ U LL N G 0) 8 .0. L 0 00 )0 M N01 01 01 en en O O O cia 0 0 o ;-; a) V V o q ti _ N a C o o U 0) 0 C .O .0 00 a. <4. APEN forms: http:,;' Application status: 0 0 0 z ❑ uinment Information & Material Use W anufacturin z CO Co 0 z 4) 'b O .JO CU .2" N O C L a 0 d 0 0 soi ,A. O j a c a) A C4 Manufacturer 7) ^y It 50 scf per compressor 2.6 MMscfy Total for 6 Compressors Natural Gas Other Process Check box to request copy of draft permit prior to issuance. Check box to request copy of draft permit prior to public notice. ❑a 0.2014.docx N w 0 C a FORUM APCD-200 / 'E`l`l / LL liJ Permit Number: 0 bL 0 CO d s d o b b 0 4. Cl, a) CO a) C) a) C, 0 O CL) N a) C O C C O C) H a) a) CO Y C CO a) 7.3 a) el gg W 0 0 O O 8 La 0 v w 0„ o CO Digitize Plot Plan (Preliminary) a v o N m O z Z O w z Z x2 o d " '6./1 F z Z • ,z m a O Other (Describe): z0 Vertical with obstructing raincap 0 Direction of outlet (check one): Width (inches) _ ❑ Other: Length (inches) = Circular: Inner Diameter (inches) _ Lion Information went & Fuel Consum CC Section 06 — Combustion E z CU 4-7 .mod.) Manufacturer: O z O CC CC b CC E o, cr a cs 0) 3 a C) V a C R N en 0 m C C C 0 O E g CC R O O V. T. 61 ❑ a COm a U A b O w O •p 0 CO � Q ❑ CC F C m o E V C O h' A U 0 ♦+ u w 9 ❑ S7 w U C Estimation Method or Emission Factor Source Eng. Estimate II pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) 20.56 Uncontrolled (Tons/Year) cw Actual Calendar Year Emissions4 Controlled (Tons/Year) Uncontrolled (Tons/Year) C. — Non -Criteria Reportable Air Pollutant Addendum form to report Emission Factor Units .`A 5 a Uncontrolled Basis G C) F Control Efficiency (% Reduction) Overall Collection Efficiency IPlease use the APCD Control Device Description Secondary C 0. Pollutant TSP o a '; a r, O c "ON C.) O O U 5 o v 'C v y m2 i C, .N CC v Z� w n' a ao RCC ▪ a '❑ P cai CD CL rc u d A P a C2 Cr et 00 C 0 cis C) H Authorized to Supply Data 0 CO a Form APCD-200 — GeneralAPEN — Ver.02.10.2014.docx CC 0 0 CC br) CO C, z LLB LLI U O z z O co 2 LLJ z O a. LU Mj c"" CC 0 LU 9 O z E `o t) c a, a E 0 U C O a) U C fa C C) a, m a) CO m J a) a) a) co AIRS ID Number: Permit Number: U J J a) O a) co 0 a) O U Cn 0 Company Name: a) O U a N Plant Location: (214) 414-1980 Cory G. Jordan Person to Contact: Cory@discoverymidstream.com E-mail Address: Controlled Actu I Emissions Ibs/ ear 11) n1 J Uncontrolled wr'd_f,a Emissions Ibs/ ear 443.95 lb/yr Emission Factor Source Engineering Estimate Emission Factor (Include Units) Lc Control Equipment / Reduction (%) Chemical Name n -Hexane Chemical Abstract Service (CAS) Number 110543 c`) + o Cci 0 C6 ca a a a 0 O) O a) N •L c 0 a, ca a) -J C O L ) a) a_ O N i_ L a a) Cc a) 76 0 a O a O O U) O r CO C) O a`) C 0 a) E ca Z Form_Revision_Date;_.Agri l 14,-201 Ke_ce_I V e -j rot 6J A O rP V E QI 0 U 0 ° % O .V. z z \ CC Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Permit Number: Facility Equipment ID: Section 02 — Requested Action (Check applicable request boxes) Section 01 — Administrative Information Request for NEW permit or newly reported emission source C d C O C) u a C) s v ann Di .40 a, z O U W O a ❑ ❑ O a) U U v) Change company name Change process or equipment 3 a a O C-) Transfer of ownership Change permit limit anai C) w krr. Request to limit HAPs with a Federally enforceable limit on PTE N N O 'C O R U o a P-) N O 7/,O a ° o ....' O > >, U V O CL L. L 0 O u > 4 h .- - a, a) C O O C a C c R C O w a L 4o, .O R G m on a) oC d O • _ co cn n .0 O Y!. U d 0 44 .sr w > 3 GO a, t X O c w W H a o w ° co C O a O ' E O C h z O y d H W ro o o. dP.C.C. z A O To Section 03 — General Information CC n cn do CIS 3 L C) R N � O 4.4 0 > •n O R 0 'o R C o >' N W O C CO CD g CU C m O a). a0 O i O ) CD a O O C) bL a 173 k R L O w° units at this Don't know C C A Ca ❑ ❑ ❑ O O O z z En rn a) C) U ® El o a) Lo_ m C. C, W C bD y -o U i 2 r c c 000 N en en rn A 4U � 2 .C 0 .� .= W W a ro g' O 0. Q a 0 up Yx U L E a) .0 'C U co r. O a. Ob V O O y o o O .tr.,.. G, o' co C/) . C r... P.> C73 a) © t"' o) o a) w 0 •3 O .i M UO ≥ cc a e A Ca R '..,o 1 .=. o >' o o . d o ° '� y To W U C7 W L O �, 0 Q yW ^o L' „w V O O U vNi • O 9 `o ACC 1.iO cu o °' 0.ci) .C) h ° U °: `° a s � V RAU d CO .� V �C o c.) o o R H a.):::.:,/L O w Qcn 0 0 00 .r -- N C. M M M 1. N ,..4 N z APEN forms: http:// v11,11 ado.gov /cdphc/pei Application status: hp://vv . o FA •5 w hx Q 0 v a .5 O Q o 2 x O L a CO i I. Cil O g ,C CO o CD E 8 A 'O L X ?O O 0 G•14 ou 0 w Cn a.-- C. <..... i z aC ) O O Q C L 0 O. Ca q C O m O R .o ti C A L o C 'fl S yU ° O A co. 70 a 7 F. to to 3 C 0w u C7 ♦ AAC A A H z CC A Qa H N C O C) G 0 Manufacturer: Reboiler Rating: Cl. 0O Ethylene Glycol (EG) H C7 V 0 U H ❑ In ❑ Ca CL C 5 o. 0 C7 C7 A Qa H Pump Make & Model: Lean glycol water content: .0 a) a O z Cfi N T � U U 00 C N C V') C C C C Z z C) 7O a; i a a a U co C T CO a a)L aoi G Q C. II cC. a)0. T H H H ca O Design Capacity: a a. CD a O CO Ca O W U 0p CO 0 N CL CL O O .1 VJ C7 C) 3 a. Water Content: ad CC w CD CL C C) C) Cold Separator: CO C) C7 hD C C. C. 00 L • Et 112, n. C .8 N O CC C.5 C C) C) — O L N X o 0 aO°n W H CO 0.l on t O U C. .a Rai a C) o > A A O R CD rn � "' U C7 x LO a) CL U C C7 C.) U C.) CO EEZ FORM APCD-202 APCD-202_Dehy-APEN-1 Lr �JJ ti N cri —77 CU Cd CL. W CO Cr) Cr) M Emission Source AIRS ID: Permit Number: Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) ust be listed here) Section 05 — Stack Information (Combustion sta 0) 0 o Digitized Plot Plan H o N 00 z U ▪ N O 00 M .U+ o< w " Obi N F- M era Other (Describe): Width (inches) = ❑ Horizontal ❑ Down O Other: Length (inches) = Vertical with obstructing raincap Direction of stack outlet (check one): Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) Section 08 — Emissions Inventory Information & Emission Control Information N 0 00 0 0 0 L 00 O .0 O .y E 00 •0 00 0 V 00 F d 00 v .0 u 00 00 0 0 0 Estimation Method or Emission Factor Source AP -42 ProMax AP -42 ProMax ProMax ProMax ProMax ProMax Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) N o? 6, s'.:1, O o T W' O 0 O 0 O 0 O 0 Uncontrolled Tons/Year) M ..w II."' O N • P 4.08 • O 0.72 0.00 Actual Calendar Year Emissions3 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units lb/MMscf Fuel lb/MMscf Gas 44 O co lb/MMscf Gas lb/MMscf Gas lb/MMscf Gas lb/MMscf Gas lb/MMscf Gas Uncontrolled Basis o • C..1'N b A. . -,O 00 M 1fJ O O O N o O O 0 Control Efficiency (% Reduction) Identify in Section 07 Control Device Description Secondary Primary Pollutant xON VOC II CO Benzene II Toluene a) 0) .N - a) .0 W Xylene n -Hexane y o = 0 Q ea .O co s_ 'O O C 00 0 L 0 APCD-202 Dehy-APEN-1 a) 0 •- O a) a) a) co O a`) CL • O N 0 .y OD a� w O a) N O Z N a) CO a a) id ca Legally Authorized to Supply AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unit' [Leave blank unless APCD has already assigned a permit # & AIRS ID] N N .!f Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Facility Equipment ID: Section 02 — Requested Action (Check applicable request boxes) Section 01 — Administrative Information Request for NEW permit or newly reported emission source Change company name Change process or equipment C) w 17 3 Transfer of ownership Change permit limit Request to limit HAPs with a Federally enforceable limit on PTE Request APEN update only (check the box below that applies) l^ ea a Cory@discoverymidstream.com E-mail Addre Request combined BTEX unit/enclosed flare control efficiency of 98% � d .7;z a.3 Section 03 — General Information 3 'O N A b O ai C) 0 2" .. 7 O O, C 'O O •• bp 7 r. a C)) o C) 0 o � Sc. O O "6 L L 7o 0 C s00. 4.. O G 7 O . O u, .L U a O y . Z -O z C7• Don't know 0 0 7 7 C o a ❑ ❑ ❑ z z z ® ❑ El >U >U ❑ ® ❑ D. Will this equipment be operated in any NAAQS nonattainment area? (htto://www.colorado.gov/cdphciattaininciit) o C) .. C E `o 000v, a z y U M M M g. W N N N N Q 7 Q C0 ,.O V' .0 ° U y E M M M U CEn O O coZ'" 7 C '> EC O O �.M.. �=_. u a) c) a0+ _ co E . _C• 001 C '+o - I) W J E oD m W a ^ aP� r= Q. d U cR Q 0 cn U d t '_ .7x O 7 i ct 3 E a) ,u s 0 at i ^ 0 C. u I O O oD a Q, ° cfp ° 0. p 0.L. - to 7LL1 tai.e =I: R., Q -o J-. O o E .0 O OL `" — .� > •U W R L N C O d _— 0 0 ° A A t'O v 07 ! o U0 °. oz aa)iU ro �' o c y J L ... 'O 7 c� is c.= c° s F. 'v 5 0_ .�•L1 U ca — U O C �D 0.i ro W d F-, cu '� U d My AA w° . Cn a Q ° z C)cip Manufacturer: ca Reboiler Rating: DiEthylene Glycol (DEG) aD U O aC a E 7 0. O A E- 5 1f) C C) 0 U 3 O cD C .-I Ord L L U U 0 N O N Design Capacity: Dehy. Gas Throughput: C) C C) C) a) 2 CID Water Content: L CD O O z Cold Separator: z O bD OD a• U U Cr ate) U 0 0', 0 0I! .O U U U U CI El F_ C) C) a) .32 C C w CC p U C) U 0 .1,‘) -15 W d O w 1-2 z W - d F `^ a O a) .. F 'n ate) 3 O O > D 3 a) r 7 C) 0 0 C L C. 7 O C E °t3 L C 7 O 0 A a) 0. C L bC .C O Ld cD0.1 bD -0 7 O u • C CO O =o 3 " o ro � U U 0 co 0 o� U U co co Q Q EEO FORM APCD-202 APCD-202_Dehy-APEN-2 1�1 O • .�i E O r-+ z O ..Vi z W C yzy C Fti C Emission Source AIRS ID: 113 N 3 ' Permit Number: ion) Location (Datum & either Lat/Long or UTM Section 06 —Stack (Source, if no c be listed here) U Section 05 — Stack Information (Combus 00 0 •1 VO VO ,n 2 0 o o N ry z •U 0 O g O Q 1.01 N 0. r (✓ v 0 O CC 0 0 Other: Length (inches) = x ❑ 0 Vertical with obstructing raincap C) Direction of stack outlet (check one): Circular: Inner Diameter (inches) = Exhaust Opening Shape & Size (check one): Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) 0 • r } V 3 4.4 Section 08 — Emissions Inventory Information & Emission Control Information O N .0 0 01 0 .0 .23 U D O .y L O U U 0 CC U W 9 U s CC .R. 0 C 0 C E 0 A I- U Gr. , E w Estimation Method or Emission Factor Source 7 OIL Q ProMax AP -42 ProMax ProMax ProMax ProMax ProMax Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted . Emissions Controlled (Tons/Year) N O N O O O CO O O O O 0 o Uncontrolled (Tons/Year) ,- rr {* d0 . oo O O, M \D .. 0.72 O O Actual Calendar Year Emissions3 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units lb/MMscf Fuel 1 co, C., W cd .0 0 lb/MMscf Fuel lb/MMscf Gas lb/MMscf Gas lb/MMscf Gas lb/MMscf Gas Ib/MMscf Gas Uncontrolled Basis eCO O ^� rf ti i, 7 ,N., .-+ O 0.05 N O CO O Control Efficiency (% Reduction) Identify in Section 07 Control Device Description Secondary Primary Pollutant xOINI O O c....) 0 N 0a) coy-= a) O O o 0 0 u N a) al v a) >C IIn -Hexane C O CC u eM a, E 0 • a7 Z71' a+ R cli E O L c-. d 0 iO F c C O CO Fs 'o 0 2 2 .C) L C) _ ▪ D .0 —_ ,fl C) • 3 C O 0 ,a ,.,2.20 o _ 0 0 ▪ �� V \. 0.F C ,,20 m es mE E E C a .D TW es U *, a" --=. CC Ct O ♦+ U ` a ., L L o'Q • T).3 V .N I7, eu lZ • O a I..I w• LI 0 w w ,- u aD -,.., F4 L �_ 0 U 0 D a) 'E' -o s C o = 1J:C Q n ° I L) U vi .o F O • N O 0 Q C CC 0 0 ti U O V C) C 0. a) CC a) CL CC 0 LO a) a) N O OD cC a) u O 0) CC z a) C rized to Supply Da c I i C) C CU Cd 04 APCD-202_Dehy-APEN-2 W O N a) CC a [Leave blank unless APCD has already assigned a permit # & AIRS ID] 1t u)ITrf77J, Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] LL Facility Equipment ID: nested Action (Check applicable request boxes) Section 02 — Re Section 01 — Administrative Information Request for NEW permit or newly reported emission source APEN Submittal for update only (Please note blank APENs will not be accepted) D ❑ ❑ ❑ N M N o C Uj O U U � Z C 0 U M LO 0 ▪ U N Mailing Address: 7859 Walnut Hill Lane, Suite 335 Phone Number: (214) 414-1980 Fax Number: (214) 414-1980 o •o o 4z Section 03 — General Information For new or reconstructed sources, the projected startup date is: For existing sources, operation begai 0) 3 N U 3 >, -C N - L O N Normal Hours of Source Operation: a •r U Q a� C ❑ Well Production O 'O C, O 5 C Z.1 U U N Q A 0^ U U ▪ dII • 70' ao Ct C,2 LID CU i C O U N r >, o U L N > > to.� o • 4!) .2 En >C C o O O U O 2-.,) C • A " p 4. 'a ) a) w z 0) a 0 O O C U cts 00 C M M rn O 0 M rn • APEN forms: hbp: '\v\c Application status C 0 ❑ Information 0 C Section 04 — Re Don't know C C Q Q Don't know ❑ ❑ ❑ ❑ O O O O z z z Z 0000 CD Ct CU It r D ❑ D ❑ Is this equipment subject to Regulation 7, Section XVII.F? Is this equipment subject to NSPS 40 CFR Part 60, subpart KKK? Is this equipment subject to NSPS 40 CFR Part 60, subpart OO0O? Is this equipment subject to NEST IAP 40 CFR Part 63, Subpart RH? Section 05 — Stream Constituents n -Hexane (wt. %) rtO -3 ti G J illv': © La. O O O co O Xylene (wt. "A)) O 0 ri-: F o w o 0 O d C Ethylbenzene (wt. %) C N O ` O O c•') O y o '- v Toluene (wt. °/u) _ :6 M o in 4- O O O cC) d ae fh ^tea p CO C O 0 O tV O VOC wt. ti Id) O O C MN— ‘—• a— Stream I_ Gas Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) _ u C C U C U C C: 0 0 C. C) CL Cr C C�. O C C X 0 N U a a) 0 C C 'D CL 2 O as 00 C U It 'O b C) C) 'J C b co OOn G) 5 y C ❑l CJ co mto M FormAPCD-203-FugitiveComponentLeaksAPEN-V N CO O 00 a0 0.. FORM APCD-203 onent Leak Emissions' AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Fu CS — N Emission Source AIRS ID: Permit Number: & Control Information CO Section 07 —Leak Detection & Re Long or UTM) Section 06 — Location Information (Provide Datum and H G G N N CO ^O U 0 O On a 1= a .- 0 C) O .0 C) CO 0 0 0. R U U J 0 .5 cdo r• C) G 0 a O O 00 O 0. Ca O O z Digitized Plot Plan N- M 0 LCD M co 0 z d 0 W LIT CJ CCi O a co C C CO C CO O N Z3 0 a E CO O bb o o E F N 'O ,72 0 y O 00 rn C. 0 O 5 O O O v 00 � N 0 0 0 a CO i O g, V CO U `G o R O N y d � d CID v c 0 a) Q U a) -o co a) J N a) a) 0_ O U m O E _ o Co U co _ U O .C C/) W C O n Co H _ a) a) c 0 0 0 Actual Count conducted on the following d Estimated Count El rst O U Equipment Type 00 CO Open -Ended Lines Pump Seals CD N 0. C) O N ap 0 L 0 L CO '9 V CO CO L CO CO CC C s CO .R. CO C O C CO V o C O CO G LL Estimation Method or Emission Factor Source 1 � , co CCI a) .n CD H ., m M a) .a CD H Table 2-8 1-'f II ,.- CO N m .Q CO H ro CCJ a) 1 ca H Table 2-8 7 ' ( II Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions5 Controlled (Tons/Year) co c;) CO O O © 0.03 o.r} O O r, O O Uncontrolled (Tons/Year) en O m p a o o 0 a O 7 c'i O m o o 6 Actual Calendar Year Emissions4 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor C Identify in Section 08 Uncontrolled Basis Control Efficiency (% Reduction) Identify in Section 07 Control Device Description Secondary CO C Pollutant V0C a V G 0 O N O w Y v = _• J u - CO C d N 0 U G CO 00 O T m O = o •' 0 - to 0 y i O Sr P U) O C C) - .`r - 0 r E E , Cu m C) CO a X O N UmE CI I= g y u C. "J O r Q O To V O U `\��' bA .. R = 3 . O U O N 1 o. �1 V ." 6 O F C) T U A C Y O E O E C o E o u N, H' N C C� d to Supply Da FonnAPCD-203-FugitiveComponentLeaksAPEN-Ver.1 1-13-2014 FORM APCD-203 I! li z LU Lu U O z z CO w.F) z E Qo v O J J O m O' O II J AIRS ID Number: r+ 2 3- ra m Permit Number: 0 J J a) a) C!) 0 a) J O U W 0 Company Name: N O O n N O a) C O 0 Section 11, T1 N, R66W Plant Location: Cory@discoverymidstream.com E-mail Address: Controlled Emissions (Ibs/year) N M ti Lo Uncontrolled lot WdiEmissions (lbs/year) N 6 co C'7 r ------Emission Factor Source EPA I Table 2-4 Emission Factor (Include Units) Various I Table 2-4 Control Equipment / Reduction (%) LDAR Chemical Name V c a) a >, L a) E 4 N N Chemical Abstract Service (CAS) Number I 540841 o Supply Data C 7 0 Ct io 0 >' 0. CO 0 0 a) _N 0 ft1 a) J 4C O rn cu O a) Name of Person Legally Authorized to Supply Data (Please print) Q co O d O E fl Emission Calculationsr VOC ( Benzene I Toluene I EII ylbenane Xylene I n lloxaue I 2 2 3-Trime11 ylpcntnne - � m _ _g., _ c0 - ooz-=O==�z. gar _ _�¢. 0o0000z _ _ __ 585.07 I 249.23 I I 825.86 I 34113 I I 26111.78 I 1121.87 I 1277.93 I 538,66 0000==z - __ - _ _ 0=oo0Zz oa - oo_ooZz. �a-. - - -R, c o 6 0 0 0 66666 Z . . . 66 Z _ m' . _ „ c,, 66 o o _o 'z- o 0 0 0 _,c9 n crv__ 00000 - m 0 6720 f _ ^\ a� 66666Z 66666Z __=o oz - -m00 on ng-6 0 0O=z 00so0z _ _ v = OoOOOz; _ U W s 4.42 .,._0.53 5;-0 _,,o E s!ccocZ ! ! ! ! ! E E_o_oz 0 0 0z o_ oo_z o o 0 0 o.=_0 5 0 O 0-0 / ,__4�0 f i _\ V r T = - m - 0000 -z C oo_ooz,_-,O,_o ac soOo 00 t =oo m g Um=Z�_o 'g 3O 000z2; _o=o==z o===ss_ 7,-, ,,_� _= 0oz -m= 20i ��_- z c _==000z o== ,go o=oo=z m.., _ _� o = o ,_, o 0 0 a- 0 z - c 0 000z o =- o 0 oocz ¢ c= 000 - - ,., c �, E _ oo0z 000ccz o00o z' 0000= o_- 0. 26.623 2 r W Valves I `..235 D.005500.I Valves ".. I 24 /I PRVs (to Flare) Others' Conueclors Flanges d SE >a > u94 OU¢. Open-ended lines Pump Seals • >a >-V OU W Open-ended lines Pump Seals v -> utRY_=u c O U mo a' OUa =1 Open-ended lines Pump Seals E. U s ezt T yr c.:" o Q g ca- .13 d ;)) j 4 0l O J 41 i _ ,, it Emission Source AIRS ID: signed a permit # & AIRS ID] [Leave blank unless APCD has already Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] I - U Facility Equipment ID: nested Action (Check applicable request boxes) Section 02 — Re Section 01 — Administrative Information E z l_ C F4 N 0❑ N M_ N o jig up -o U U 4 u Discovery DJ Services LLC Company Name: C U) V ool C C E L, cs CL C C Cr NCT C 0 O U Change company name ❑ Transfer of ownership ❑ ❑ Change process or equipment Change permit limit ❑ ❑ w tf) co Co O M N lC) C- APEN Submittal for Permit Exempt/Grandfathered source APEN Submittal for update only (Please note blank APEN's will not be accepted) D❑ I- to C6 CO 0 Tank vapors sent to VRU, emissions are due to VRU downtime (10%) Fax Number: (214) 414-1980 discoverymidstream.com 0 C-) O era 64 Ca ee d Ca ro o U z L zz \ I❑'y 00 CC) En In >, y � 3 For new or reconstructed sources, the projected startup date is: C O C C) O Ca 2 O Sri 4) L O O CC N C N 2, L E- J Normal Hours of Source Operation: L I❑ ❑❑ C O T.< d C C- I- O 0 m m C) C m C a) E O U) 'C 0- U -OO 0. a) O a ,0 i a.+ o @ u U L Cr >. O 4 C CS > U Z O 'c. t. cw., o G aCi Or O .`i CD E d N _ C O h re b C G69 e' A L © . Y, •. N N L'i kn— ow a4 N L ,7 C 619 ca •9 - 0 y' u . E 0 U z CD N Y P cc V V d a m e o C u. b _ N Cr d w v•=,0. O ._o U ca '�'� R L E y co \j =•‘.7, ed E 4° • °' N :11t'cie E `0 CZ E W z 0 ,� V OF: cia _^o Q.3 O a'U i • ca o •• E= L A U ai J. a= 0. = O U O> C R d'j i .- O Or O d "a? u W C.: =UdeA For guidance on how to complete this APEN form: M M M N N N T C LCC CC CC _ M M M .M.. fcni :l Co - Information Actual While Controls Operational: Ca" a) N N >l >1 ao a 0. cn-O CC C clo u eC L O Ca E, d RVP of Sales Oil c 0) ❑ External Floating Roof: Internal Floating Roof: Z C Y R Cr h CD C C E o R 0 e- a) CC 7, N o u o . 'Cr C bD _C h O = _4 v 0 F U Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) 1 Newly Reported Well ■ ■ ■ ■ ■ Name of Well C C C Form APCD-205-Condensate Dank APEN-Ver.12-22-2014.doc N Ca CD 00 a) . 4 M FORM APCD-205 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Stora r N Emission Source AIRS ID: Permit Number: Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) O Z 0�Q o z, d O � O Lt - c (~ O z I — U O Vertical with obstructing raincap O Exhaust Opening Shape & Size (check one): Section 07 — Control Device Information E&P Sites Onl Information aration Technolo a) C) Section 08 — Gas/Li C) CO cy O C) O b0 U O O CL C) v O C cCC a C) Ca C) 0 L C) C) C) f,. O .: y 5 C C O r C r.l O �.a O co) L' E C) C) C O CSC E O _ O C C) a O C) C O C) C) N bL C 7 c C .23 i 0 0 F V L O N T.1 CC R C Emission Factor IData Source ProMax ProMax CO ProMax Benzene 2.4E-2- ,. , o , lb/bbl -0:58- 11 ` f 1 0.01 i , ,r x ,.`' , ProMax Toluene 1.0E=2 J u, 1 lb/bbl 0:24 `_'. `; -0:0Q t ' , . ] '\ ProMax Ethylhenzene -1.2E-03 ', ' 1 r 1,, ' lb/bbl 0:03 c) AL. 0:0o- u ✓x 1, ProMax Xylenes 2:5E -0a ( ,' ,�t,i' lb/bbl -0:06 \.'>>71, 0:00 D,r..1'1 ProMax n -Hexane 8.7E=02 I .�,'.' lb/bbl -2:06 a -1.1-1 0.04 U. ‘..1 ProMax 2,2,4-Trimethylpentane 2,0E-02 'II y. ‘ • ' , " lb/bbl 0.47- ' I .i ?, ',, ^' 0.01 i - ,, ProMax Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) N. n Uncontrolled (Tons/Year) _ cN N- [6 cc) Actual Calendar Year Emission2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units Uncontrolled Basis 17 N LP CJ ' O Cr x ON VOC Section 10 —A II 12-22-2014 doe Form APCD-205-CondensateTank APEN-V 0 N O a FORM APCD-205 .S Internal Combustion En Emission Source AIRS ID: W Facility Equipment ID: Section 02 — Requested Action (check applicable request boxes) Section 01— Administrative Information Request for NEW permit or newly reported emission source T number GP02 (Natural Gas Only) Request for coverage under GENERAL PE Cl ❑ ❑ County: Weld Change company name Change fuel or equipment C) w Elevation: 5,135 Transfer of ownership Change permit limit Request APEN Update ZIP Code: 75230 Emissions data must be completed. Blank APENs will not be accepted. F CU (214) 414-1980 Phone Number: Cory G. Jordan Fax Number: (214) 414-1980 O z Section 03 — General Information co C For new or reconstructed sources, the projected startup date For existing sources, operation began on: Gas Compression 0 • ..• 9.' O ▪ C' Ua) w0 • C CO LL y 7a • IS zc� C R CU u a .., U 0CO 4; a) A p ••• O o o v a) U "o cU.0 m m - ▪ _ U c C 0 000 en M an N N N a Cr, ' • anrn O O O —en _ .... e� L ., CC C O 9 8 .` O ti U m O .C ' ❑ ❑ go ° �cn APEN forms: O N Date the engine was ordered: C Date the engine was relocated into Colorado: z U Engine displacement: z CC Model: G3508B CU B. C U ❑❑ ❑ I Engine function: gU a O. as Manufacturer's maximum rated horsepower @ sea level: Manufacturer's maximum site rating: Engine Brake Specific Fuel Consumption @ 100% Load: 0 ❑ c- C y � O 0 L L L C- 0 Y a) a) Ca C. C. Cal A O O C C o O a• C ge, Cu C What is the maximum number of hours this engine is used for emergency back—up power? Form APCD-201-RICEAPEN-Ver.02.10.2014.docx N O a) aD CU P. M M FORM APCD-201 Internal Combustion En Tv1 ti Emission Source AIRS ID: Permit Number: 0 b) a) Cv f..a a) a F N b a) 0 a Cn U 0 cu .o J a) a) cO E cip E �z G O m J G C N a -a Digitize Plot Plan (Preliminary) CO M co z z 4 �c a 2 w O Vd w " LU N M w 0. 5 0 N C`7 LC) uS W Direction of stack outlet (check one): Circular: Inner Diameter (inches) = tion Information Section 06 — Fuel Consum Seasonal Fuel Use (% of Annual Use) 0 LU c b ti N N a) w CV N V 1'I U m co O Requested Permit Limit z c C Natural Gas 0 z Estimation Method or Emission Factor Source AP -42 AP -42 AP -42 AP -42 Manufacturer Manufacturer Manufacturer N - Q I AP -42 II N - Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) N O O N O m ti 04 O O O O'.-, - ti ch - 0.75 ,- O .- O O O Uncontrolled (Tons/Year) 1: CV O O O N. N O O O ti CU O O Q O O n -' r` M N CO a- CO O r p O O Actual Calendar Year Emissions2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor .a Ib/MMBtu 2 m 2 Ib/MMBtu lb/MMBtu a r g/hp-hr n t -; �i r m 2 m 2 Ib/MMBtu Uncontrolled Basis] -... ^ '-' 0 O 0.5 LO O O CO O N 0.0084 LO 0 Co 0 0 Control Efficiency (% Reduction) O o co O O O 4 C co ti Lri M coo Control Device Description Secondary a c0 C C6 C O C 4...'" N C 78 0 a X O U a O lea 'WO t0 C c0 C B/U Pollutant TSP o a. cZNid I 0 C L_ xoN I 0 9 O U IFormaldehyde Acetaldehyde a o d Benzene _ Cs an N a) U a c0 a) C) � w a C 0 a) O a) rn Form APCD-201-RICEAPEN-V er.02.10.2014. docx 0 b 0 O C, w C N O C7 0 U • a) at 0 Internal Combustion Engine' Emission Source AIRS ID: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] w Facility Equipment ID: Section 02 — Requested Action (check applicable request boxes) Section 01— Administrative Information Request for NEW permit or newly reported emission source T number GP02 (Natural Gas Only) Request for coverage under GENERAL PE a❑ O 'b U U Z heck each box below that applies) County: Weld Change company name N C O Transfer of ownership ❑ ❑ Change fuel or equipment Change permit limit O Elevation: 5,135 Request APEN Update 0 ZIP Code: 75230 Emissions data must be completed. Blank APENs will not be accepted. F- 0 (6 O Cory G. Jordan E U O aa> C C R E Y o. v) O O O C O R w z O ❑.E14z Section 03 — General Information For new or reconstructed sources, the projected startup date is: nla 0 O 0 bCD 0 N O O C) a) 0 tat N CO N O I b b 0 a N Normal hours of source operation: Gas Compression 9. O O. a) a a) O O 0 0. U .d CC C7 0 0 ^O C O 0. d a a 0 CO CO v) rim m O O rr CO O CO 9 w � _ 6 -o OU > V O J' p O 0 U 4 O V 0 .5 •0 p. o C F w d rP) APEN forms: h O O O. Date engine construction commenced: co 0 N CC ❑ Date of any reconstruction/modification: co C Date the engine was relocated into Colon O z a M ❑ Ez o 6 H b ❑ 50 CD N CO O N Engine date of manufacture: m co O co co CD a) O Manufacturer: ❑ ❑ N O U ❑ E 0 C) 5 O W as x � O CCU o. CO Cr �apF Ll 0 O C o .5 'd Y 1 0 5 9 0 .CC 0 0 2 2 wF • O as • al LEA a v N Engine Brake Specific Fuel Consumption w 100% Load: ❑ 00 C) N i!) aJ U N ❑ m'U 0 O 64 O 0 r 0. 0, w w O O 0 0 N a) 0 C O .O O ,0• O o .O .O U U ❑M ti C 0 C um number of hours this engine is used for emergency back—up power? What is the ma Form APCD-201-RICEAPEN-Ver.02.10.2014.docx FORM APCD-201 Internal Combustion En AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reci N. N Emission Source AIRS ID: Permit Number: O 0 0 c3 V cc b V b 0 a N V a) w R O O J CCI 8 V -4c71) 0 u Digitize Plot Plan (Preliminary) co co 0 Z o t .°3 wQ N rO) 0 O co M a z y 0�Q m w c U Q C.)) A 0 O Width (inches) _ ❑ Horizontal ❑ Down ❑ Other: Length (inches) = Direction of stack outlet (check one): Section 06 — Fuel Consumption Information Seasonal Fuel Use (% of Am 0 aa 0 N aD 0 N m N 0 U Q N O Requested Permit Limit o U F C, Natural Gas O z c cat E H O C O L) E C O y C, W oEl 4 Ow o = It: •3 o CO C) 0 1 pN o 8u co CIO C v Estimation Method or Emission Factor Source AP -42 I AP -42 AP -42 I AP -42 IManufacturer IManufacturer Manufacturer - N 1 a I AP -42 I AP -42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) N c''''' N 0 mono n ` N 0 ti `. N 0 0 N an _ -.CCC N o Uncontrolled (Tons/Year) N O O d !`Y O O d or. O O 0 O o f� ri N CD 00 o r e- 0 O 0 Actual Calendar Year Emissions2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor lb/MMBtu lb/MMBtu i 00 2 3 2 1- g/hp-hr J g/hp-hr t a) rn 5 y .o lb/MMBtu lb/MMBtu Uncontrolled Basis L L O 0 o 0.5 0.55 L2:58 ; O 0 O d O 0 Control Efficiency (% Reduction) 0,0 co co O C. ou'i CO CO O co Control Device Description Secondary co .Y a c...11 t6 C l0 C l.0 0 N .5...u U X O Oxid. Cat le0 •plxO ld C l0 o c6 C Pollutant I TSP a nx s O c/' x O z> U O O U T '° O G w j, 'C A V d ❑ v o o Q 6) a o CQ true and correct. If this is a U C •:t N o to U R. O O 0 J OC G o U N K O .J•.C, U a C •• a. .174 °_ V U Q. .❑ • 01 0 3 •o' N 0 O +U• -= g . ' ' . C to To s 5.O • "O 'a Oll '0 v• y O F-) v C o O 1" O O Y O .O Q co v c ^ CJ z u A C° 3 ❑ L. N O N C.= N cC e.3-0 O C) U V 4 ' O CO . O ,c it Y v A .O ' Sa Ti'� ��. > d . 0 - 0 C v '-c-' gti O :2,.., , No Q o°J'a ≥ d ^ ,, d N L, ) 6. e, —; ;EJ CD O ntr..0',,,•,,, \v CD as _� C c� 0 '3 ea u a, 0 c..) to w A C m i a) a) Q Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE Emission Source AIRS ID: [Leave blank unless APCD has already assigned a pemsit # & AIRS ID] Permit Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] a) T. a C aJ w nested Action (check applicable request boxes) Section 02 — Re Section 01— Administrative Information Request for NEW permit or newly reported emission a Request PORTABLE source permit Change company name Change fuel or equipment 0 Change permit limit Request to limit HAPs with a Federally enforceable limit on PTE Request APEN Update 0 ❑ 0 ❑ ❑ Discovery DJ Services LLC ZIP Code: 75230 Emissions data must be completed. Blank .WENS ,vrll not be accepted. x H N CC CC a Section 03 — General Information For existing sources, operation began o N C) V n a; O U y ��r---')� o 7-4' U O G m rim _ o O a- U O 1 7 '� •C y '� C I" , c'1 M �' G O L:a U - o C O O O ,.. ro > ti O O L _ �- L I_ O 0 C-< o o G G o R ,o ra C OC ril -. o. o FL cn ,- o 3...= d p -u n' U A _ R G� _.j — to E .% d _ tC cc q v y c+ — °� ti W{ '5 ... >' o a, - _ oD o c _ G '. C a) - LceP -' •v F 0 O a o o ? o a s. v . - a •.y 5> y R L N O �' 7 O O o >`^ o e a U;aa� o U �i x x a . N o? C t L: 0 u N -y^ ? .0 a o o .' - Y c u o °^'' 4 V- 7_ o a) o O C •r m = R a U d = O CO v � 2 C y. = oUc [ 50 1 tZ-� '2 U C....) F- ai '=" U d Q A Q n < Q O 0 Qs z ❑ v r 0 tea rte. CC Ca G 0 CC I�1 a z Manufacturer: n/a s{ p °S v a O Q Waste Gas APEN — Ver.02.I0.2014.do F c.5 Po z z w V z c AIR POLLUT Permit Number: lu>l. iple releases; provide datum & either Lat/Loi e) Section 05 — Emission Release Information (Attach a separate sheet with releva O N- E 5 - F C o ANN -3 r o 0 Z p Q z Ni w O z 0 m M !f) a c F m o r a) Direction of outlet (check one): Width (inches) _ ❑ Other: Length (inches) _ Inner Diameter (inches) Exhaust Opening Shape & Size (check one): Section 06 — Combustion Equipment & Fuel Consumption Information z 0' C a) O z Company equipment Identification No IC C) a) w ct Cr) w A d L ✓ Or N E G I should consider process growth o C) 4 O 0 Section 07 — Emissions Inventory Information & Emission Control Information Estimation Method or Emission Factor Source TCEO Flare radon AP42 O 0 r Please use the APCD Nun -Criteria Reeortable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tous/Year a <r r o m m Uncontrolled (Tons/Year _ r. O Actual Calendar Year Emissions4 Controlled Tons/Year) Uncontrolled Tons/Year Emission Factor Units D In Uncontrolled Basis ap co O � i.r) Lc: N- O Control Efficiency (% Reduction) C L' C v L O U Q O w U Control Device Description 4 O V C C) 4 r o a C1 0 F A. . A., Y. cn NOx VOC IN I O IN N CC) r IC. V O u c V a) 0 0' Ca y i 5 s E 0' • d CC O v CC LC I hereby certify 1:1 a) CO Q olized to Supply Data O ti rr- a" Section 02 — Requested Action (Check applicable request boxes) Section 01— Administrative Information General Permit GP07 Individual Permit F C 0 ❑ (-) (0 —1 a y E a) O U o 0 CD LL U U 0 0 z A i a C O U 715 Mailing Address: 7859 Walnut Hill Lane, Suite 335 V w In X F Ca W 0 0 N Cory@discoverymidstream,corn E-mail Addr Phone Number: (214) 414-1980 N O F 0 C0 E Ca a, 0 a m w S d 0 U O) 0) C 0 O 2 Y m CO m a) 8' c 0 U 0 co 0 E W Addl. Info. & No Section 03 — General Information days/week 52 S O N C O O a) 0 U1 0 w rn S C 0 2 Y S CV a !n a) C O E O O N S W 5 a O Don't know 0 D O C 0 0 0 z z z o a DO ❑. G CJ C c O 0 v q c y_, O a x N U' ..J r tV O r = S c ,°y. .a -2 a < C =i O CV -0 U. aa " o m s y O• ) '' S C O• U o CC C) o C Q O O CJ 6 n b0 G -0' ° •� C 8 En iC O G .b 8 S S 0 L G 0 P7 s y v i a - " � y oc c, 0 .. DC) O O )) 5 c_ < — N 75 ar vS) a Cs 0' E C� U a, a CO L a 0 C! a H C CC C) 0 Product Loaded: (e.g, "rail tank cars," or "tank trucks") U 2 Y !z,'" C 0 w a d t C p ., t.,) a Er' U � W a C 'a a y z E.a2 7 Ito C U T CC a to U- OLIJ U UL 4 a U a it; T d •v 'iC CS .Do 0 s 0 r O p FORM APCD-208 -r- a> a, C) E G R 0 0 U C) a F1 Cil u CC c w Ct 0 C co M O CO Ct M N M co O — 'a F. — o, 6 V D tiz orb z C .56 o Width (inches) e C) C c G L D O. a G DA C .C) i C) u CJ 0 OO A '7 Describe Any Other (Including VRU) VOC & HAP Control Efficiency: 7 CC o Combustion Device used for control of the loadout emissions. CC a C C) C j C c a C u fn Ca a C) DC Q C) CG O O G C) C) a-1 ^U V CC 'b C. U 0 -oo a O O C) G OO O G 0 C) C Y N) C) C) O = O — C U N DC Cet O Dn O m C R m T G .C C. d u C) C) U G L N C- a O Estilnation Method or Emission Factor Source CDPHE PD Memo 11-02 CDPHE PD Memo 140208 CDPHE PD Memo 14-02 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Uncontrolled Controlled. (Tons/Year) (Tons/Year) GO a O) O O 0.074 O Actual Calendar Year Emissions` Uncontrolled Controlled (Tons/Year) (Tons/Year) Emission Factor Uncontrolled Basis Units - .O -O CO r N 0 M O O O O Control Efficiency (% Reduction) Identify in Section 07 0 V C) C) u 0 Secondary 0 U 0: m o O Z U O , O U o t J 0 o o., mo x 0 Q CL u 7 G p V Cl Cory G. Jordan • t H Name of Legally Authorized Person (Please print) N O N O1) Hello