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Home My WebLink About20173324.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 11500 St PO Box 758 Greeley, CO 80632 September 19, 2017 Dear Sir or Madam: RECEIVED SEP252017 WELD COUNTY COMMISSIONERS On September 21, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for DCP Operating Company, LP - Milton Compressor Station. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure RV i (J lo/a/17 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor ; Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer CC : PLCcnm/ TP), KLC 3T) pc,nJCER/CH/ a1M/CK) q/85/I7 2017-3324 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: DCP Operating Company, LP - Milton Compressor Station - Weld County Notice Period Begins: September 21, 2017 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: DCP Operating Company, LP Facility: Milton Compressor Station Compressor Station NE SEC 12 T3N R65W Weld County The proposed project or activity is as follows: Applicant proposes a new compressor station in the non - attainment area. Compressor station included two compression turbines, a glycol natural gas dehydrator, and hydrocarbon loadout activity. 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 17WE0642 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us RA DO Colorado Air Permitting Project Project Details Review Engineer: Package #: Received Date: Review Start Date: Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Address/Location: Type of Facility: What industry segment? Christopher Kester 36427& 6/8/2017 7/19/2017 DCP Operating Company, LP 123 9F42 Milton Compressor Station NE quadrant of Section 12, Township 3N, Range 65W, in Weld County, Colorado Natural Gas CompressorStaation Oil & Natural Gas Production & Process Is this facility located in a NAAQS non -attainment area? Yes If yes, for what pollutant? Larbon Monoxide (CO) laarticulate Matter (PM) Weld Quadrant Section Township Range N Section 02 - Emissions Units In Permit Application zone (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 Turbine TURB-1 No 17WE0642 1 Yes Perms Initial Issuance 002 Turbine TURB-2 No 17WE0642 1 Yes Permit Initial Issuance 003 TEG Dehydrator- D-1 Yes 17WE0642 1 Yes Permit initial Issuance 004 Hydrocarbon Liquid Loading L-1 No 17WE0642 1 Yes ' Permit Initial -.''r. Issuance Pressurized Loading 005 Produced. Water Tank PW No 17WE0643.XP 1 No AMEN Required / Permit Exempt <1% Crude by volume exemption Section 03 - Description of Project Applicant proposes a new synthetic minor compressor station in the non -attainment area. Section 04 - Public Comment Requirements Is Public Comment Required? yes If yes, why? Requesting Synthetic Minor Pe Section 05 - Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required? If yes, for what pollutants? Colorado Air Permitting Project If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? If yes, explain what programs and which pollutants here: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) No. SO2 NOx ❑ ❑ ❑ ❑ No SO2 NOx ❑ ❑ ❑ ❑ CO VOC PM2.5 PM10 TSP HAPs ❑ ❑ ❑ ❑ ❑ 0 0 ❑ ❑ 0 0 CO VOC PM2.5 PM10 TSP HAPs ❑ ❑ ❑ ❑ ❑ ❑ 0 ❑ ❑ ❑ 001 - Turb 1 One (1) Solar Taurus 70, Serial Number (TBD), natural gas -fired, natural gas compression turbine, site rated at 8,534 horsepower at 11,575 RPM. Engine Information berating Mfg's Max. Rated Horsepower @ sea level: 8534 Horsepower used for calcuations: 8534 BSCF @ 100% Load (btu/hp-hr): 8461 Site - Rated BSCF @ 100% load (btu/hp-hr): 8461 Max hrs/yr of Operation) 8760 Calculations Fuel Use Rate @ 100% Load 70582.8 scf/hr MAX POTENTIAL Annual Fuel Consumption 618.305 MMscf/yr REQUESTED Annual Fuel Consumption 618.305 MMscf/yr Fuel Heating Value 1023 btu/scf Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions PM 0.00660 Ib/MMBTU 0.007 lb/MMBTU 2.1 tpy 2.1 tpy SOx 0.00340 lb/MMBTU 0.003 lb/MMBTU 1.1 tpy 1.1 tpy NOx 0.21000 g/hp-hr 0.210 g/hp-hr 17.3 tpy 17.3 tpy CO 0.23700 g/hp-hr 0.237 g/hp-hr 19.5 tpy 19.5 tpy VOC 0.00210 lb/MMBTU 0.002 lb/MMBTU 0.7 tpy 0.7 tpy Formaldehyde 0.00071 lb/MMBTU 0.001 Ib/MMBTU 449 lb/yr 449 lb/yr Acetaldehyde 0.00004 lb/MMBTU 0.000 lb/MMBTU 25 lb/yr 25 lb/yr Acrolein 0.00001 lb/MMBTU 0.000 Ib/MMBTU 4 lb/yr 4 lb/yr Benzene 0.00001 Ib/MMBTU 0.000 lb/MMBTU 8 lb/yr 8 lb/yr NOx CO 0.054603475 0.061623922 lb/MMBTU Ib/MMBTU 17WE0642.CP1.xlsm Source AP -42 AP -42 Manufacturer Manufacturer with a safety factor AP -42 AP -42 AP -42 AP -42 AP -42 17WE0642.CP1.xlsm 002 - Turb 2 One (1) Solar Taurus 70, Serial Number (TBD), natural gas -fired, natural gas compression turbine, site rated at 8,534 horsepower at 11,575 RPM. Engine Information berating Mfg's Max. Rated Horsepower @ sea level: 8534 Horsepower used for calcuations: 8534 BSCF @ 100% Load (btu/hp-hr): 8461 Site - Rated BSCF @ 100% load (btu/hp-hr): 8461 Max hrs/yr of Operation) 8760 Calculations Fuel Use Rate @ 100% Load 70582.8 scf/hr MAX POTENTIAL Annual Fuel Consumption 618.305 MMscf/yr REQUESTED Annual Fuel Consumption 618.305 MMscf/yr Fuel Heating Value 1023 btu/scf Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions PM 0.00660 Ib/MMBTU 0.007 lb/MMBTU 2.1 tpy 2.1 tpy SOx 0.00340 lb/MMBTU 0.003 lb/MMBTU 1.1 tpy 1.1 tpy NOx 0.21000 g/hp-hr 0.210 g/hp-hr 17.3 tpy 17.3 tpy CO 0.23700 g/hp-hr 0.237 g/hp-hr 19.5 tpy 19.5 tpy VOC 0.00210 lb/MMBTU 0.002 Ib/MMBTU 0.7 tpy 0.7 tpy Formaldehyde 0.00071 lb/MMBTU 0.001 lb/MMBTU 449 lb/yr 449 lb/yr Acetaldehyde 0.00004 Ib/MMBTU 0.000 Ib/MMBTU 25 lb/yr 25 lb/yr Acrolein 0.00001 Ib/MMBTU 0.000 Ib/MMBTU 4 lb/yr 4 lb/yr Benzene 0.00001 Ib/MMBTU 0.000 lb/MMBTU 8 lb/yr 8 lb/yr 17WE0642.CP1.xlsm Source AP -42 AP -42 Manufacturer Manufacturer with a safety factor AP -42 AP -42 AP -42 AP -42 AP -42 17WE0642.CP1.xism Glycol Dehydrator Emissions Inventory Section 01- Administrative Information 'Facility AIRs ID: 123 County 9F41 Plant 003 Point Section 02 - Equipment Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Recirculation Pump Information Number of Pumps Pump Type Make: Model: Design/Max Recirculation Rate: Dehydrator Equipment Flash Tank Reboiler Burner Stripping Gas Dehydrator Equipment Description Emission Control Device Description: flash tank, and reboiler burner One )1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: T80, Serial Number: TBD) with a design capacity of 130 MMscf per day. This emissions unit is equipped with 2 (Make: T80, Model: TBD) electric driven glycol pump with a design capacity of 40 gallons per minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are routed directly to the closed -loop system. Asa secondary control device, flash tank emissions are muted to the Enclosed Flare . Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Dehydrator Still Vent and Flash Tank (if present) Requested Permit Limit Throughput = 47,45G MMscf per year Potential to Emit (PTE) Throughput = 47,450 MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Still Vent Control Condenser. Condenser emission reduction claimed: Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Still Vent Gas Heating Value: Still Vent Waste Gas Vent Rate: Flash tank Control Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Flash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: 8497.2: hr/yr 262.6 hr/yr :.. 298. Btu/scf 9.32E003. scfh Ii 438:: hr/Yr 1468:-Btu/scf 292E+03 scfh 9%. Control Efficiency % (3% downtime) Control Efficiency % 100%:. Control Efficiency % (5%downtime) 95% Control Efficiency % (5% uptime) Wet Gas Processed: Still Vent Primary Control: 46,026.5 MMscf/yr Still Vent Secondary Control: 1,423.5 MMscf/yr Waste Gas Combusted: Still Vent Primary Control: 79.2 MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Wet Gas Processed: Flash Tank Primary Control: 45,077,5 MMscf/yr Flash Tank Secondary Control: 2,372.5 MMscf/yr Waste Gas Combusted: Flash Tank Primary Control: 0.0 MMscf/yr Flash Tank Secondary Control: 1.3 MMscf/yr Glycol Dehydrator Emissions Inventory Section 04 - Emissions Factors & Methodologies Dehydrator The source used GRI Glycali 4.0 to estima analysis collected on 11/4/2016 Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate STILL VENT Control Scenano Primary Secondary Pollutant Uncontrolled (lb/hi ) Controlled (lb/hr) Controlled (I12/hr) VOC ......120:2186.. 6.01093 120.2186 Benzene 18,0755 0.903775 18.0755 Toluene --...16,759, 0.83795 16.759 Elhylbenzene 0.4728 0.02364 0.4728 Xylenes 4.7044... 0.23522 4.7044 n -Hexane 2:8016 0.14118 2.8316 224-TMP 0.1178 0.00089 0.0178 FLASH TANK Control Scenano Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (Ib/hr) Controlled (Ib/hr) VOC 81,385 0 4.06925 Benzene 0.1779 0 0.008895 Toluene .....0.0981... 0 0.004905 Elhylbenzene 0.0015 0 7.5E-05 Xylenes :0,01 0 0.0005 n -Hexane 0.9265 0 0.046325 224-TMP 0,0004. 0 0.00027 Emission Factors Pollutant VOC Ben Glycol Dehydrator Uncontrolled (Ib/MMscf( (Ib/MMscf) (Wet Gas Throughput) (Wet Gas Throughput) Controlled 40.94 3.706844308 0.288241597 Tolue 3.423288 0.267214048 Ethylbentene 0.096319385 0.0075379 0.957385846 0.07500045 0.763183385 0.045610437 0.004711385 0.00028650 Xylene n -Hexane 224 TMP Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer (%): Still Vent Primary Control Device Uncontrolled Uncontrolled Emission Factor Source Pollutant (Ib/MMBtu( (lb/MMscf( Emission Factor Source (Waste Heat Combusted( PM10 0.00' PM2.5 0.007 NOx ...:::, 0.0680 (Waste Gas Combusted( 2.2204 2.2204 20.2640 92.3800 Still Vent Secondary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu( (Ib/MMscf( Emission Factor Source (Waste Heat Com busted) PM10 ...':';: 0:. PM2.5 :0,9075 NOz 0.0680 Pollutant (Waste Gas Combusted( 2.2204 20.2640 Flash Tank Primary Control Device Uncontrolled Uncontrolled (Ib/MM8tu( (Ib/MMscf( Emission Factor Source (Waste Heat (Waste Gas Combusted( Combusted) 0,0075 0.0075 NOx 0:0680: CO 03300. 10.9380 99.8240 455.0800 Flash Tank Secondary Control Device Uncontrolled Uncontrolled Pollutant (Ib/MMBtu( (Ib/MMscf( Emotion Factor Source (Waste Heat (Waste Gas Combusted( Combusted( PM10 0.0075 10.9380 Not CO 0.0075 10.9380 0.0680. 99.8240 0.3100 455.0800 Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 Nox CO VOC 0.1 0.1 0.1 0.1 0.1 0.1 0.1 , 0.1 0.1 0.1 2.8 2.8 2.8 2.8 2.8 12.7 12.7 12.7 12.7 12.7 971.3 971.3 46.4 971.3 46.4 Hazardous Air Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (lb/yr) (Ib/yr) Glycol Dehydrator Emissions Inventory Benzene 87.94 87.94 6.84 87.94 6.84 175890 13677 Toluene 31.22 81.22 6.34 81.22 6.34 162435 12679 Ethylbenzene 2.29 2.29 0.18 2.29 0.18 4570 358 Xylene 22.71 22.71 1.78 22.71 1.78 45428 3559 n -Hexane 18.11 18.11 1.08 18.11 1.08 36213 2164 224 TMP 0.11 0.11 0.01 0.11 0.01 224 14 Section 06 - Regulatory Summary Analysis _ Regulation 3, Parts A, B Regulation 7, Section XVII.B,D Regulation 7, Section XVII.B.2.e Regulation 7, Section XII.H Regulation 8, Part E, MAR Subpart HH (Area) Regulation 8, Part E, MACE Subpart HH (Major) Regulation 8, Part E, MACT Subpart HHH (See regulatory applicability worksheet for detailed analysis) Source requires a permit Dehydrator is subject to Regulation 7, Section XVII, B, 0.3 The control device for this dehydrator is not subject to Regulation 7, Section X011.8.2 Dehydrator is subject to Regulation 7, Section XII.H Dehy is subject to area source MACT HH, per the requirements in 63.764(O2) You have indicated that this facility is not subject to Major Source requirements of N You have indicated that this facility is not subject to MACT HHH, Section 07 - Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a year of application submittal? If no, the permit will contain an Initial Compliance" testing requirement to demonstrate compliance with emission limits Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Please note that 48840 MMBtu/yrwas added to the combustion emissions from the pilot light. AIRS Point # 003 01 Section 09 - Inventory SCC Coding and Emissions Factors Pollutant PM10 PM2.5 NOx VOC CO Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Uncontrolled Emissions Factor 0010/01 001V/0! 0.117 40.9 0.534 3.707 3.423 0.096 0.957 0.763 0.005 Control % 0.0% 0.0% 0.0% 9521.8% 0.0% 9222.4% 9219.4% 9217.4% 9216.6% 9402.4% 9391.9% Glycol Dehydrator Emissions Inventory Glycol Dehydrator Emissions Inventory Glycol Dehydrator Emissions Inventory Units Ib/MMscf Ib/MMscf Ib/MMscf Ib/MMscf Ib/MMscf Ib/MMscf Ib/MMscf Ib/MMscf ib/MMscf Ib/MMscf Ib/MMscf Dehydrator Colorado Regul ATTAINMENT 1. Are uncont 2. Are total fa NON -ATTAIN M 1. Are uncont 2. Are total fa Colorado Regul 1. Is this glycc 2. Is this glycc 3. Is the sum 4. Are actual t Section XII. MACT AnaN 1. Is the dehyl a. b. 2. Is the dehyl 40 CFR, Part 63 Area Soura 1. Is the dehyl Exemption: 2a. 2b. 3. Is the unit I Major Sour 1. Does the fa Small or La 2a. 2b. Small Dehv 3. 4. 40 CFR, Part 63 1 Is the facilit Small or La 2a. 2b. Small Dehv 3. 4. Colorado Regul 1. Is the dehyt 2. Is this dehy 3. Is this deh 4. Was this gl' 4a. 5. If construct Section XVI Section XVI Alternative 6. Yes No Regulatory Analysis Worksheet ation 3 Parts A and B - APEN and Permit Requirements You have indicated that source is in the Non -Attainment Area rolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Pa cility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TI You have indicated that source is in the Non -Attainment Area ENT rolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, 5 cility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater th, Source requires a permit ation 7, Section XII.H )I natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/r )I natural gas dehydrator located at an oil and gas exploration and production operation', natural gas compressor of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Re IDehydrator is subject to Regulation 7, Section XII.H H — Emission Reductions from glycol natural gas dehydrators rsis drator located at an oil and natural gas production facility that meets either of the following criteria: A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user' (63.760(a)(3))? drator located at a facility that is a major source for HAPs? Go to MACT HH Area Source Requirement section to determine MACT HH applicability Subpart MACT HH, Oil and Gas Production Facilities e Requirements drator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))? S Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per c Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere ocated inside of a UA plus offset and UC boundary area? Dehy is subject to area source MACT HH, per the requirements in 63.764(d)(2) Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards Do Not Apply §63.773 - Monitoring Standards Do Not Apply §63.774 - Recordkeeping §63.775 - Reporting •ce Requirements Icility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility- rge Dehy Determination Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per d Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere Requirements Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B) For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation You have indicated that this facility is not subject to Major Source requirements of MACT HH. Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting , Subpart MACT HHH, Natural Gas Transmission and Storage Facilities :y wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the rge Dehy Determination Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per c Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere Requirements Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(2) and For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicabl You have indicated that this facility is not subject to MACT HHH. Subpart A, General provisions per §63.1274 (a) Table 2 §63.1275 - Emissions Control Standards §63.1281 -Control Equipment Standards §63.1283 - Inspection and Monitoring §63.1284 - Recordkeeping §63.1285 - Reporting ation 7, Section XVII.D drator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)? drator located at a transmission/storage facility? ydrator located at an oil and gas exploration and production operation , natural gas compressor station c /col natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)? equal to or greater than 6 tons per year VOC or 2 tpy VOC if the dehydrator is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)? ed on or after May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to Dehydrator is subject to Regulation 7, Section XVII, B, D.3 II.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions II.D.3 - Emissions Reduction Provisions Emissions Control (Optional Section) Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e Section XVII.B.2.e — Alternative emissions control equipment Disclaimer Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can, " is intended to describe APCD interpretations and recommendations. Mandatory terminology Yes Yes Source Requires an APEN. Go to the next question Source Requires a permit Continue - You have indicated the attainment status on the Project Summary Sheet. Continue - You have indicated the facility type on the Project Summary Sheet. Go to the next question Dehydrator is subject to Regulation 7, Section XII.H Continue - Source is subject to MACT HH requirements. You have indicated the source category on t Go to MACT HH Area source applicability section Continue - You have indicated the dehydrator type on the dehydrator inventory sheet. go to the next question go to the next question The dehy is subject to the Lopt requirements in 63.764(d)(2) Continue - You have previously indicated this in the MACT section Continue - You have previously indicated this in the beginning of the MACT section Continue - You have previously indicated this in the Reg 7, Section XII determination Go to question 5 Source is subject he Project Summary Sheet. 004 Pressurized Condensate Tank Truck Loadout Liquid Hose Diameter 0.16667 feet Vapor Hose Diameter 0.16667 feet Liquid Hose Length* 1 feet Vapor Hose Length* 1 feet Liquid Hose Volume 0.0218 cubic feet Vapor Hose Volume 0.0218 cubic feet Truck and Tank Pressure 97 psig 109.2 psia Loadout Capacity 7000 gallons/load Condensate Production 2500000 gallons/month 357.14286 loadouts/month 4286 loadouts/year *Length ac( pressurized 714285.71 bbl/yr All liquid lines contain liquid products at individual specific gravity. 'All vapor return lines contain products that behave as Ideal Gases at 60 deg F and stor P*V=n*R*T Where: P = pressure in hose at time of disconnect = storage tank pressure (psia) V = Volume of hoses (cubic feet) n = number of Ibmoles of product in hoses R = Universal Gas Constant = 10.73 ftA3 * psi / Ibmole / deg R T = avg loadout temp = 60 deg F = 519.67 deg R Vapor Density n 0.00042725 Ibmol n/V 0.01958372 Ibmol/ft^3 MW 32.4 Ib/Ibmol Vapor Density 0.63451264 lb/ft^3 Vapor VOC Emissions 59.3267936411b/yr 0.029663397 tpy Total VOC Emissions 1.92 tpy Emission Factor 0.897 lb/loadout n -hexane mass fraction 0.07521 D Liq Total n -hexane Emissions 289.2 lb/yr Emission Factor 0.0675 Ib/loadout :ounts for length of isolation valve on I hose age tank pressure Liquid Density SG 0.65 ensity of Water 8.33 lb/gal Liquid Density 5.4145 lb/gal 40.50 lb/ft^3 luid VOC Emissions 3786.784167 lb/yr 1.89 tpy Produced Water Storage Tank(s) Emissions Inventory Section 01- Administrative Information 'Facility AIRS ID: 123 9F41 'r 005 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit TWO (2) 210641= produced Water storagetanks Description: Emission Control Device N o None Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Produced Water Throughput = 21,900'. Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = 21,900: Barrels (bbl) per year 1, 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 = 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? Produced Water Tank Emission Factor Source Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Produced Water Throughput) (Produced Water Throughput) IfJCSMIECEEMMIIMEEMPCasFpeiesfW�Etet`, IMMICEMININ INIMISMINNII , :: ,dj,,} 0.007 0.007 s,. x s. 0.022 t_ Pollutant Control Device Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Produced Water Throughput) Section 05 - Emissions Inventory Criteria Pollutants Hazardous Air Pollutants n -Hexane 0.2409 Potential to Emit Uncontrolled (tons/year) Potential to Emit Uncontrolled (tons/year) Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B, C.1, C.3 Regulation 7, Section XVII.C.2 Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) 0.0767 0.2409 0.0767 0.2409 Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Source requires APEN, is permit exempt Storage Tank is not subject to Regulation 7, Section XVII Storage Tank is not subject to Regulation 7, Section XVILC.2 0.2409 0.0767 0.2409 Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) 153.3000 481.8000 153.3000 481.8000 29 of 33 K:\PA\2017\17W E0642.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory Regulation 6, Part A, NSPS Subpart 0000 'Storage Tank is not subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis). 30 of 33 K:\PA\2017\17WE0642.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Samoling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. �„+,�ilseiv✓, If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section OS - Technical Analysis Notes Source is claiming the <1% crude oil by volume'. AIRS Point # 005 Section 09 - Inventory 5CC Coding and Emissions Factors otter will be written for this point. Process # 5CC Code 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+Flashing losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons liquid throughput PM2.5 0.00 0 lb/1,000 gallons liquid throughput NOx 0.00 0 lb/1,000 gallons liquid throughput VOC 6.2 0 lb/1,000 gallons liquid throughput CO 0.00 0 lb/1,000 gallons liquid throughput Benzene 0.17 0 lb/1,000 gallons liquid throughput Toluene 0.00 0 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 0 lb/1,000 gallons liquid throughput Xylene 0.00 0 lb/1,000 gallons liquid throughput n -Hexane 0.52 0 lb/1,000 gallons liquid throughput 224 TMP 0.00 0 lb/1,000 gallons liquid throughput 31 of 33 K:\PA\2017\ 17WE0642.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet 00 Y H O. 2 3 d C1 v m w a d 41 GI -c O c C O W CO C 01 ._ N a -o C d c c m GCI E m m E `0 3 m C C .O a a a O0 E a L 2 Y H a 2 CO N 0 C N a 3 v s a 0 C z a, m 0 Y 0 0 ATTAINMENT O 3ro 06 [O = co a '« ri y o m a- 6 o O o � _ 0 0 0 0 a a a c v m m '5 '5 '5 o 00 0 • vi NON -ATTAINMENT a N22 c o V U l7 0: c 0 Colorado Re v 0 a m O l0 O mO O 0 E 0 m c 0 0 3 0 c u O 0 a 0 m 0 a 0 a 0 0 a O 3 0 c 00 c a m V u x Y'* C ted with Air Pollution Control Equipment F- C O 0 a 0 0 ▪ O. 3 3 C w K O W V 0. v ; m u u O 3 u c Y c c « 0 a° v N N N O N N M C 10 Transmission and Distribution art 0000. Standards of Performance for Crude Oil and Natural Gas Production 40 CFR. Part N m v NSPS 0000 O tm cO N I0 b O tp a O 0 O a z 0 9 O Q O •A E b i m C 0 E O O O O a z v c 2 v E P 0 `m m m a « a- au M x a c d c v v 0 O o 2 0£ C0 a ° g -%d N = n K T o°ma m— m c c 0 j 0 v « v a N V a y o 6 O o ° o o 2 M G _N > V 0 £ n 0 a o . V m« m O; O .3 m a° m p C .3 t;Iii A A 0 w : U d u A M v M a v a .0 0 IA N N Y) tD0 C N .v . v . �0. W ° d Z d E N O k} );/\ (\\\\ \ r. r.8/ \/\\\ E8 SAVA 2-7,02°a■!k\ {]2: 3±§!i\ k(]\$) ▪ @2|/§ / kf2.e! \\-282\ {)\)\.e >2)] \s§®(0 \ ((\§ J\§/ff \\\\\� ■ rwl4 1O) L(00- 2 t/@! 2##R2/ }/i/ -V2 W, \ \\\\\ )&7#t{ 2g2,10 Q11,0.2% a• `.2% S _k§]f\ {/®){) )]E ° &2.'s DO ontrol Division Department cf Public Health Et Environment Permit number: Date issued: Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: STRUCTION PERMIT Issuance: I DCP Operating Company, LP Milton Compressor Station 123/9F42 NE SEC 12 T3N R65W Weld County Natural Gas Compressor Station Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TURB-1 001 One (1) Solar Taurus 70, Serial Number (TBD), natural gas -fired, natural gas compression turbine rated at 72.2 MMBtu/hr, and site rated at 8,534 horsepower at 11,575 RPM. None TURB-2 002 One (1) Solar Taurus 70, Serial Number (TBD), natural gas -fired, natural gas compression turbine rated at 72.2 MMBtu/hr, and site rated at 8,534 horsepower at 11,575 RPM. None D-1 003 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 130 MMscf per day. This emissions unit is equipped with 2 (Make: TBD, Model: TBD) electric driven glycol pump with a design capacity of 40 gallons per minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Combustor. Emissions from the flash tank are routed back to the inlet via the vapor recovery unit (VRU). As a secondary control device and during VRU downtime, flash tank emissions are routed to the Enclosed Combustor. L-1 004 Pressurized condensate tank truck loadout None COLORADO Air Pollution Control Division Page 1 of 21 y be replaced with another Solar Taurus 70 turbine in pore to me replacement provision or with another Solar Taurus 70 in accordance wi t e permanen rep* acement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 003: The glycol pump may be replaced with another pump of the same design capacity in accordance with the provisions of the Alternate Operating Scenario (AOS) included in this permit as Attachment This permit is granted su.-ct to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Poll on Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions in a E and 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. The Notice of Startup form may be downloaded online at https://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 No. 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. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shalt be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • Points 001 Et 002: Serial number • Point 003: The dehydrator manufacturer name, model number and serial number • Point 003: 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 No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. COLORADO Mr Pollution Control Division Page 2 of 21 7.onexceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Faci lit Equipme I TURB-2 AIRS Point Pounds per Month PM2.5 NO, V0C CO Emission Type 001 357 2,940 3,318 Point 002 357 2,940 3,318 D-1 003 476 7,890 2,158 L-1 004 374 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 NO X V0C CO TURB-1 001 2.1 17.3 --- 19.5 Point TURB-2 002 2.1 17.3 --- 19.5 Point D-1 003 --- 2.8 46.4 12.7 Point L-1 004 --- --- 2.2 --- Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. COLORADO Air Pollution Control Division Page 3 of 21 8. �'oint I3 •liana the i Sion limits in this permit shall be demonstrated by running or higher on a monthly basis using the most recent extended wet gas ana ysis an recor.e: operational values, including: gas throughput, lean glycol recirculation rate, enclosed combustion device (ECD) downtime, vapor recovery unit (VRU) downtime, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basi ^ ;g; into the model and be provided to the Division upon request. 9. The owner or op ator shall operate and maintain the emission points in the table below as a closed loop syst and shall recycle 100% of emissions as described in the table below. (Regulation Num. r 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Emissions Recycling Description Pollutants Recovered D-1 003 Flash Tank: Recycled to Plant Inlet with a VRU (except during VRU downtime - up to 5% downtime annually) VOC and HAP 10. 'The owner or operator shall operate and maintain the emission points in the table below with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. The owner or operator shall operate this dehydration unit so as to prevent any emissions directly to the atmosphere except as authorized below. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled D-1 003 Still Vent: Enclosed Combustor (except during enclosed combustor downtime - up to 3% downtime annually) VOC and HAP Flash Tank: Enclosed Combustor (during VRU downtime - up to 5% downtime annually) VOC and HAP COLORADO Air Pollution Control Division Page 4 of 21 our : alit llowing maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment IRS Process Parameter Annual Limit Monthly Limit TURB-1 001 Consumption of natural gas as a fuel 619 MMscf 53 MMscf TURB-2 002 Consumption of natural gas as a fuel 619 MMscf 53 MMscf D-1 003 Natural Gas Processed 47,450 MMscf 4,030 MMscf Natural gas processed while still vent emissions routed to atmosphere 1,424 MMscf --- Natural gas processed while flash tank emissions routed to enclosed combustor 2,373 MMscf --- L-1 004 Pressurized loadout events 4,286 loadouts 365 loadouts The owner or operator shall calculate 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. 12. Point 003: This unit shall be limited to the maximum lean glycol circulation rate of 40 gallons per minute. The lean glycol recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (Loft) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4) 13. Point 003: On a monthly basis, the owner or operator shall monitor and record operational values including: ECD downtime, VRU downtime, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. STATE AND FEDERAL REGULATORY REQUIREMENTS 14. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 15. 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 COLORADO ', Air .Pollution Control Division Page 5 of 21 ject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall e: Regulation No. 1, Section II.A.1. a 4.) 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Points 001 £t 002: This source is subject to the Particulate Matter and Sulfur Dioxide Emission Regulations of Regulation 1 including, but not limited to, the following(Regulation 1, Section III.A.1):: a. No owne air operator shall cause or permit to be emitted into the atmosphere from any fuel -burn < g equipment, particulate matter in the flue gases which exceeds the following (Regulate 1, Section III.A.1):: (i) For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less than or equal to 500x106 BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0.5(FI)-0.26 Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. (ii) If two (2) or more fuel burning units connect to any opening, the maximum allowable emission rate shall be calculated on a lb/ hour basis as calculated from a weighted average of the individual allowable limits for each unit ducting to the common stack. b. Emissions of sulfur dioxide shall not emit sulfur dioxide in excess of the following combustion turbine limitations. (Heat input rates shall be the manufacturer's guaranteed maximum heat input rates). New sources (Regulation 1, Section VI.B.4.c): Combustion Turbines with a heat input of less than 250 Million BTU per hour: 0.8 pounds of sulfur dioxide per million BTU of heat input. 18. Points 001 £t 002: This source is subject to the New Source Performance Standards requirements of Regulation 6, Part B including, but not limited to, the following (Regulation 6, Part B, Section II): a. Standard for Particulate Matter - On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: (i) (i) For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=0.5(FI )-0.26 Where: PE is the allowable particulate emission in pounds per million Btu heat input. Fl is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. (ii) Greater than 20 percent opacity. b. Standard for Sulfur Dioxide - On and after the date on which the required performance test is competed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere sulfur dioxide in excess of: (i) Sources with a heat input of less than 250 million Btu per hour: 0.8 lbs. S02/million Btu. COLORADO Air Pollution Control Division Page 6 of 21 19. •oint+0° +02: m .mb i• turbines are subject to the New Source Performance s of $x •ul 'on No. 6, Part A, Subpart KKKK, Standards of Performance for ationary ombus ion Tursinesinc uding, but not limited to, the following: • 40 CFR, Part 60, Subpart A - General Provisions • §60.4320 - Nitrogen Oxide Emissions Limits o S a) - NOx emissions shall not exceed 25 ppm at 15% 02 or 1.2 lb/MW-hr; • §60.4330 - S fur Dioxide Emissions Limits o §60. 30 (a)(1) - 5O2 emissions shall not exceed 0.9 lb/MW-hr gross output; or o §6+. a .+ (a)(2) - Operator shall not burn any fuel that contains total potential sulfur emissions in excess of 0.060 lb SO2/MMBtu heat input. • §60.4333 - General Requirements o §60.4333 (a) - Operator must operate and maintain your stationary combustion turbine, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup, shutdown and malfunction. • §60.4340 - NOX Monitoring o §60.4340 (a) - Operator shall perform annual performance tests in accordance with §60.4400 to demonstrate continuous compliance with NOX emissions limits. If the NOX emission result from the performance test is less than or equal to 75 percent of the NOX emission limit for the turbine, you may reduce the frequency of subsequent performance tests to once every 2 years (no more than 26 calendar months following the previous performance test). If the results of any subsequent performance test exceed 75 percent of the NOX emission limit for the turbine, you must resume annual performance tests. • §60.4365 (or §§60.4360 and 60.4370) - 5O2 Monitoring o The operator shall comply with §60.4365 or with both §560.4360 and 60.4370 to demonstrate compliance with SO2 emissions limits. • §60.4375 - Reporting o §60.4375 (b) - For each affected unit that performs annual performance tests in accordance with §60.4340(a), you must submit a written report of the results of each performance test before the close of business on the 60th day following the completion of the performance test. • §S60.4400 and 60.4415 - Performance Tests o Annual tests must be conducted in accordance with §60.4400(a) and (b). o Unless operator chooses to comply with §60.4365 for exemption of monitoring the total sulfur content of the fuel, then initial and subsequent performance tests for sulfur shall be conducted according to §60.4415. 20. Point 003: During VRU downtime, operator shall reduce uncontrolled VOC emissions from the flash tank by at least 95 percent through the use of an enclosed combustor. 21. Point 003: This source is subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators; and COLORADO Air Pollution Control Division Page 7 of 21 l missions of volatile organic compounds from the still vent densate-glycol (GCG) separator (flash separator or flash tank), i presen s all :e re•uced 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.) 22. Point 003: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII .l Provisions (State only enforceable). If a flare or other combustion device is used to contro -missions of volatile organic compounds to comply with Section XVII, it shall be enclosed; ha ; no visible emissions during normal operations, as defined under Regulation Number 7, XVII. 6; and be designed so that an observer can, by means of visual observation from the outsi•s 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. 23. Point 003: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. 24. Point 003: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) COLORADO Air Pollution Control Division Page 8 of 21 T HH pli•a•le m •' �f 1' Area Source rt ' Outside UA/UC boundary §63.760 - Applicability and designation of affected source §63.760 (f) - The owner or operator of an affected major source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(1) and (f)(2) of this section. The owner or operator of an affected area source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(3) through (f)(6) his section. §63.764 - General Standards 561764 (d)(2) -Each owner or operator of an and UC boundary (as defined in §63.761) shall paragraphs (d)(2(i) through (iii) of this section. 63.764 (d)(2)(i) - Determine the optimum glycol equation: gal TEG *(F*(I-0)v Lo„ =1.15*3.O area source not located in a UA plus offset comply with the provisions specified in circulation rate using the following a TEG-to water ratio (gal TEG/lbH2O) of safety. unit such that the actual glycol glycol circulation rate determined in If the TEG dehydration unit is unable content using the glycol circulation rate the owner or operator must calculate Version 3.0 or higher. The owner or unit must be operated using the with the initial notification in determination specified in paragraph in §63.774(f) and submit the Initial in §63.775(c)(7). If operating conditions circulation rate is required, the owner or accordance with paragraph (d)(2)(i) or (ii) under §63.775(c)(7)(ii) through (v). lb H2O 24hr/day , Where: LOPT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) 0 = Outlet water content (lb/MMSCF) 3.0 = The industry accepted rule of thumb for 1.15 = Adjustment factor included for a margin §63.764 (d)(2)(ii) - Operate the TEG dehydration circulation rate does not exceed the optimum accordance with paragraph (d)(2)(i) of this section. to meet the sales gas specification for moisture determined in accordance with paragraph (d)(2)(i), an alternate circulation rate using GRI-GLYCalcTM, operator must document why the TEG dehydration alternate circulation rate and submit this documentation accordance with §63.775(c)(7). §63.764 (d)(2)(iii) - Maintain a record of the (d)(2)(ii) in accordance with the requirements Notification in accordance with the requirements change and a modification to the optimum glycol operator shalt prepare a new determination in of this section and submit the information specified §63.774 - Recordkeeping Requirements §63.774 (b) - Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section §63.774 (b)(1) §63.774 (b)(1) - The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. §63.774 (b)(1)(i) - All applicable records shall be maintained in such a manner that they can be readily accessed. §63.774 (b)(1)(ii) - The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request. §63.774 (b)(1)(iii) - The remaining 4 years of records may be retained offsite. §63.774 (b)(1)(iv) - Records may be maintained in hard copy or computer -readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche. §63.774 (f) - The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. COLORADO Air Pollution Control Division Page 9 of 21 r " T HH £ pli le m �.,, •- Area Source � Outside UA/UC boundary §63.775 (c) - Except as provided in paragraph (c)(8), each owner or operator of an area source subject to this subpart shall submit the information listed in paragraph (c)(1) of this section. If the source is located within a UA plus offset and UC boundary, the owner or operator shall also submit the information listed in paragraphs (c)(2) through (6) of this - tion. If the source is not located within any UA plus offset and UC boundaries, the . o �:ner or operator shall also submit the information listed within paragraph (c)(7). §63.775 (c)(1) - The initial notifications required under §63.9(b)(2) not later than January 3, 2008. In addition to submitting your initial notification to the addressees specified under §63.9(a), you must also submit a copy of the initial notification to EPA's Office of Air uality Planning and Standards. Send your notification via e-mail to CCG-ONG®EPA.GOV or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Coatings and Chemicals Group (E143-01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711. §63.775 (c)(7) - The information listed in paragraphs (c)(1)(i) through (v) of this section. This information shall be submitted with the initial notification. §63.775 (c)(7)(i) - Documentation of the source's location relative to the nearest UA plus offset and UC boundaries. This information shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the names of the nearest urban cluster with 10,000 people or more and nearest urbanized area. §63.775 (c)(7)(ii) - Calculation of the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i). §63.775 Reporting §63.775 (c)(7)(iii) - If applicable, documentation of the alternate glycol circulation rate Requirements calculated using GRI-GLYCalcTM, Version 3.0 or higher and documentation stating why the TEG dehydration unit must operate using the alternate glycol circulation rate. §63.775 (c)(7)(iv) - The name of the manufacturer and the model number of the glycol circulation pump(s) in operation. §63.775 (c)(7)(v) - Statement by a responsible official, with that official's name, title, and signature, certifying that the facility will always operate the glycol dehydration unit using the optimum circulation rate determined in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. §63.775 (f) - Notification of process change. Whenever a process change is made, or a change in any of the information submitted in the Notification of Compliance Status Report, the owner or operator shall submit a report within 180 days after the process change is made or as a part of the next Periodic Report as required under paragraph (e) of this section, whichever is sooner. The report shall include: §63.775 (f)(1) - A brief description of the process change; §63.775 (0(2) - A description of any modification to standard procedures or quality assurance procedures §63.775 (0(3) - Revisions to any of the information reported in the original Notification of Compliance Status Report under paragraph (d) of this section; and §63.775 (0(4) - Information required by the Notification of Compliance Status Report under paragraph (d) of this section for changes involving the addition of processes or equipment. 25. Point 004: 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 loading from a pressurized tank to a pressurized tank truck. (Reference: Regulation 3, Part B, III.E) COLORADO Air Pollution Control Division Page 10 of 21 26. ading operations, regardless of size, shall be designed, ned minimize leakage of volatile organic compounds to the ,.ate a mosphere o t eYmaximum ex en practicable. OPERATING Et MAINTENANCE REQUIREMENTS 27. Point 003: U on startup of this point, the owner or operator shall follow the most recent operating an ance (OEM) plan and record keeping format approved by the Division, in order to demons ate compliance on an ongoing basis with the requirements of this permit. Revisions to your M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, art B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. Points 001 Et 002: These turbines are subject to the initial testing requirements of 40 C.F.R. Part 60, Subpart KKKK as referenced in this permit. 29. Point 003: The owner or operator shall complete the initial extended wet gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.) Periodic Testing Requirements 30. Points 001 Et 002: This turbine is subject to the periodic testing requirements of 40 C.F.R. Part 60, Subpart KKKK as referenced in this permit. 31. Points 001 Et 002: The operator shall conduct, at a minimum, annual portable analyzer monitoring of the turbine exhaust outlet emissions of nitrogen oxides (NOr) and carbon monoxide (CO) to monitor compliance with the emissions limits. Results of all tests conducted shall be kept on site and made available to the Division upon request. 32. Point 003: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. ADDITIONAL REQUIREMENTS 33. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NOx per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or COLORADO Air Pollution Control. Division Page 11 of 21 tons las E" su mitte.; or o s per year or more, a change in actual emissions of five r or more, whichever is less, above the level reported on the For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level on the last APEN submitted to the Division. • Wheneve here is a change in the owner or operator of any facility, process, or activity; or • Whene a -w control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 34. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 35. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 36. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 37. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 38. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied 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. 39. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. COLORADO Air Pollution Control Division Page 12 of 21 40. iolat •tterm•er o of the provisions of the Colorado Air Pollution Prevention e re ati• _ of the AQCC may result in administrative, civil or criminal en orcemen ac ions under wmec ions 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Christop r Kester Permit E sineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to DCP Operating Company, LP COLORADO Air Pollution Control Division Page 13 of 21 Notes mit issuance: 1) T t h for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production based on the con upon request of the control regulation or and complete appli terial processing limits and emission limits contained in this permit are io rates requested in the permit application. These limits may be revised ner or operator providing there is no exceedance of any specific emission y ambient air quality standard. A revised air pollution emission notice (APEN) n 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-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (Ib/yr) TURB-1 001 Formaldehyde 50000 449 449 TURB-2 002 Formaldehyde 50000 449 449 D-1 003 Benzene 71432 175,890 13,677 Toluene 108883 162,435 12,679 Ethylbenzene 100414 4,570 358 Xylenes 1330207 45,428 3,559 n -Hexane 110543 36,213 2,164 2,2,4- Trimethylpentane 540841 224 14 L-1 004 n -Hexane 110543 289 289 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons per year (tpy) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 'COLORADO Air Pollution Control Division Page 14 of 21 mit are based on the following emission factors: CAS Pollutant Emission Factors (lb/MMBtu) - Uncontrolled Source PM2.5 0.0066 AP -42 0.055 Manufacturer 0.062 Manufacturer plus safety factor V 0.002 AP -42 50000 Formaehyde 0.00071 AP -42 Emission factors are based on a Brake -Specific Fuel Consumption Factor (Higher Heating Value) of 8461 Btu/hp-hr, a site -rated horsepower value of 8534 HP and a fuel heat value of 1023 Btu/scf. Point 003: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Controlled emissions are based on a combustor control efficiency of 95%. Total actual flash tank and still vent combustion emissions are based on the sum of the emissions for the still vent primary control, flash tank secondary control, pilot gas combustion, and assist gas combustion. Total combustion emissions are based on the following emission factors: Still Vent Primary Control: CAS # Pollutant Uncontrolled Emission Factors lb/MMBtu Waste Gas Combusted Source N0x 0.068 AP -42 Chapter 13.5 Industrial Flares CO 0.31 Note: The combustion emission factors are based on a heating value of 300 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the waste gas flow from the regenerator overheads stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this control device. Flash Tank Secondary Control: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Waste Gas Combusted Source N0x 0.068 AP -42 Chapter 13.5 Industrial Flares CO 0.31 Note: The combustion emission factors are based on a heating value of 1468 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the waste gas flow from the flash tank off -gas stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this control device. COLORADO Air Pollution Control Division Page 15 of 21 The emission levels contained in this permit are based on the following emission factors: CAS Pollutant Emission Factors (Ib/loadout) - Uncontrolled Source 1.0242 Engineering Calculation 110543 n -H4 ane 0.0675 Emission factors re based on liquid and vapor line volumes of 0.0218 ft^3/loadout venting directly to the phere. 6) At the time of permit issuance, DCP has indicated that there is the following equipment and activities located at the facility that is exempt from APEN reporting: Equipment / Activity Description 1,000 gal Methanol Tank 200 gal Lube Oil Tank 1,000 gal Glycol Tank 80 bbl drain tank 2 - 60,000 gal pressurized condensate storage tanks Turbine la Blowdown Turbine 1 b Blowdown Turbine 2a Blowdown Turbine 2b Blowdown Turb-1 and Turb-2 Purges Dehydrator Reboiler (H-1) Pigging Fugitive Component Leak Emissions 7) 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. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC and HAP NANSR Synthetic Minor Source of: VOC 9) 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/ COLORADO Air Pollution Control Division Page 16 of 21 NSPS NSPS Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories 60.1 -End for New Stationary Sources Subpart A - Subpart KKKK Part 60, Appendixes Appendix A - Appendix I MACT 63. MACT Subpart A - Subpart Z 63.600 z .1199 Subpart AA - Subpart DDD MACT 63.12 .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 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS TURBINES WITHOUT CONTINUOUS EMISSIONS MONITORING August 16, 2011 1. Routine Turbine Component Replacements The following physical or operational changes to the turbines in this permit are not considered a modification for purposes of NSPS GG, major stationary source NSR/PSD, or Regulation No. 3, Part B. Note that the component replacement provisions apply ONLY to those turbines subject to NSPS GG. Neither pre-GG turbines nor post GG turbines (i.e. KKKK turbines) can use those provisions. 1) Replacement of stator blades, turbine nozzles, turbine buckets, fuel nozzles, combustion chambers, seals, and shaft packings, provided that they are of the same design as the original. 2) Changes in the type or grade of fuel used, if the original gas turbine installation, fuel nozzles, etc. were designed for its use. 3) An increase in the hours of operation (unless limited by a permit condition) 4) Variations in operating loads within the engine design specification. 5) Any physical change constituting routine maintenance, repair, or replacement. Turbines undergoing any of the above changes are subject to all federally applicable and state only requirements set forth in this permit (including monitoring and record keeping). If replacement of any of the components listed in (1) or (5) above results in a change in serial number for the turbine, a letter explaining the action as well as a revised APEN and appropriate filing fee shall be submitted to the Division within 30 days of the replacement. Note that the repair or replacement of components must be of genuinely the same design. Except in accordance with the Alternate Operating Scenario set forth below, the Division does not consider that this allows for the entire replacement (or reconstruction) of an existing turbine with an identical new one or one similar in design or function. Rather, the Division considers the repair or replacements to encompass the repair or replacement of components at a turbine with the same (or functionally similar) components. 2. Alternative Operating Scenarios COLORADO Aix Pollution Control Division Page 17 of 21 Th , folio g .five ng S n io (AOS) for the temporary and permanent replacement of coents has been reviewed in accordance with the requirements of n No. .,"'ar io . `, - ational 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 turbine or turbine component replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such turbine component replacement without applying for a revision to this permit or obtaining a new Co'`str io Permit. 2.1 Turbine Replaceme The following As corporated into this permit in order to deal with a turbine breakdown or periodic routine maintenance and repair of an existing onsite turbine that requires the use of a temporary replacement turbine. "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 turbine is in operation. If the turbine 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. Any permanent turbine replacement under this AOS shall result in the replacement turbine being considered a new affected facility for purposes of NSPS and shall be subject to all applicable requirements of that Subpart including, but not limited to, any required Performance Testing. All replacement turbines 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 the NSPS 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 turbine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the turbine (s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement turbine. 2.1.1 The owner or operator may temporarily replace an existing turbine that is covered by this permit with a turbine that is the exact same make and model as the existing turbine without modifying this permit, so long as the temporary replacement turbine complies with the emission limitations for the existing permitted turbine and other requirements applicable to the original turbine. Measurement of emissions from the temporary replacement turbine shall be made as set forth in section 2.2. 2.1.2 The owner or operator may permanently replace the existing turbine that is covered by this permit with a turbine that is the exact same make and model as the existing turbine without modifying this permit so long as the permanent replacement turbine complies with the emission limitations and other requirements applicable to the original turbine as well as any new applicable requirements for the replacement turbine. Measurement of emissions from the temporary replacement turbine shall be made as set forth in section 2.2. 2.1.3 An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement turbine shall be filed with the Division for the permanent replacement turbine within 14 calendar days of commencing operation of the replacement turbine. 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 turbine. This AOS cannot be used for permanent turbine replacement of a grandfathered or permit exempt turbine or a turbine 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 turbine replacement. COLORADO Air Pollution Control Division Page 18 of 21 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 tes specified by the p testing, this test condu test is not required for d by this Condition may be used to satisfy the periodic testing requirements e relevant time period (i.e. if the permit requires quarterly portable analyzer ed under the AOS will serve as the quarterly test and an additional portable analyzer other three months). The owner or operatol l 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 turbine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement turbine. All portable analyzer testing required by this permit shall be conducted using the most current version of the Division's Portable Analyzer Monitoring Protocol as found on the Division's website. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the replacement turbine 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 turbine 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 turbine 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 turbine is taken offline. 2.3 Applicable Regulations for Permanent Turbine Replacements 2.3.1 NSPS for Stationary Gas Turbines: 40 CFR 60, Subpart GG §60.330 Applicability and designation of affected facility. (a) The provisions of this subpart are applicable to the following affected facilities: All stationary gas turbines with a heat input at peak load equal to or greater than 10.7 gigajoules (10 million Btu) per hour, based on the lower heating value of the fuel fired. (b) Any facility under paragraph (a) of this section which commences construction, modification, or reconstruction after October 3, 1977, is subject to the requirements of this part except as provided in paragraphs (e) and (j) of §60.332. A Subpart GG applicability determination as well as an analysis of applicable Subpart GG monitoring, recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in any request for a permanent turbine replacement COLORADO Air Pollution Control Division Page 19 of 21 g ration No. 6. Part B, Section I.B. that Relocation of a source from the State of Colorado is considered to be a new source, subject to req i.e., the date that the source is first relocated to Colorado becomes equivalent to the commence construction date for purposes of determining the applicability of NSPS GG requirements). 2.3.2 NSPS for Stationary Combustion Turbines: 40 CFR 60, Subpart KKKK §60.4305 Do t su' .art apply to my stationary combustion turbine? (a) If you are th E'.wner or operator of a stationary combustion turbine with a heat input at peak load equal to or grea than 10.7 gigajoules (10 MMBtu) per hour, based on the higher heating value of the fuel, which co `" =r ced construction, modification, or reconstruction after February 18, 2005, your turbine is subject to this subpart. Only heat input to the combustion turbine should be included when determining whether or not this subpart is applicable to your turbine. Any additional heat input to associated heat recovery steam generators (HRSG) or duct burners should not be included when determining your peak heat input. However, this subpart does apply to emissions from any associated HRSG and duct burners. (b) Stationary combustion turbines regulated under this subpart are exempt from the requirements of subpart GG of this part. Heat recovery steam generators and duct burners regulated under this subpart are exempted from the requirements of subparts Da, Db, and Dc of this part. A Subpart KKKK applicability determination as well as an analysis of applicable Subpart KKKK monitoring, recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in any request for a permanent turbine replacement 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 commence construction date for purposes of determining the applicability of NSPS KKKK requirements). 2.4 Additional Sources The replacement of an existing turbine with a new turbine 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; a turbine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite turbine has to go through the appropriate Construction/Operating permitting process prior to installation ATTACHMENT B: ALTERNATIVE OPERATING SCENARIO GLYCOL PUMP 1. The dehydrator's gas -driven glycol pump may be replaced with another gas -driven glycol pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A replacement pump shall be the same capacity as authorized in this permit. COLORADO Air Pollution Control Division Page 20 of 21 2. The owner or operator shall maintain a log on -site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 3. Allpump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. COLORADO Aix Pollution Control Division Page 21 of 21 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 7IvLQ `TZ- AIRS ID Number: 123 /0F4v/ 0 a [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Namet: Site Name: DCP Operating Company, LP Milton Compressor Station Site Location: NE 1/4, S12, T3N, R65W Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@DCPMidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-2OO - General APEN - Revision 1/2017 364281 �j COLORADO 1 I �� nip n nv a wnu HNa1N b Fsr�mnmen+ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit h and AIRS ID] Section 2- Requested Action (] NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Natural Gas Compression Turbine Manufacturer: Solar Model No.: T70 Serial No.: TBD Company equipment Identification No. (optional): TURB-1 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 COLORADO 2 I _ Health 6 nsILVt v„honm.n+ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (Specify Units) Material Consumption: Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.245345°, -104.609882° ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator StackIDNo.- Discharge Height Above Ground LevelACFM) (Feet), Temp. ('F) Flow Rate (ACFM) Velocity (fr/sec TURB-1 45 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Upward with obstructing raincap 0 Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): COLORADO Form APCD-200 - General APEN - Revision 1/2017 3 1 AV °`° 77„°�"'°H` HuIU� b Fr�iro�m.m Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) • Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit. Limit4 (Specify Units) 72.2 618.3 MMscf/yr - From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Pipeline natural gas Heating value (give units): 1023 Btu/scf a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOx NO), CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 4 I AV H�nm�mdAbuc h b Fsimonm.m COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP-42,etc) f9 Actual Annual Emissions Requested Annual Permit 4 Emission Limit(s) u(Tons/year)d O(Tons/yearncontrolleontrolled)6 Uncontrolled Controle (Tons/yel ord) TSP (PM) 0.0066 Ib/MMBtu / AP -42 2.1 2.1 PM10 0.0066 Ib/MMBtu '' AP -42 2.1 ' 2.1 PM2.5 0.0066Ib/MMBtu' AP -42 2.1 - 2.1 SOx 0.0034 Ib/MMBtu/ AP -42 1.1 ' 1.1 NO, 0.055 Ib/MMBtu' Mfg. 17.3 -' 17.3 CO 0.062Ib/MMBtu/ Mfg. 19.5 - 19.5 VOC 0.0021 Ib/MMBtu ' AP -42 0.7 - 0.7 Other: a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? ❑✓ Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Numbers Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions6 (Ms/year) 50-00-0 Formaldehyde N/A 7.1E-041b/MMBtu - AP -42 449.1 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 COLORADO 5 I Htiw„b'ab 4, Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: 5 Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - General APEN - Revision 1/2017 COLORADO 6I Lt., -0«..c F �ironm�n, 1 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 123 /RP4-21 001.- [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: DCP Operating Company, LP Milton Compressor Station Site Location: NE 1/4, S12, T3N, R65W Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@DCPMidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 364280 COLORADO Form APCD-200 - General APEN - Revision 1/2017 1 I &V L'===.1, Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑r NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR - ▪ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Natural Gas Compression Turbine Manufacturer: Solar Model No.: T70 Company equipment Identification No. (optional): TU RB-2 For existing sources, operation began on: Serial No.: TBD For new or reconstructed sources, the projected start-up date is: TBD ❑� Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year Jun -Aug: Sep -Nov: Form APCD-200 - General APEN - Revision 1/2017 COLORADO 2 I _ ne��,mrmun, Hwlth b F Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use O Check box if this information is not applicable to source or process From what year is the actual annual amount? Description Design Process Rate (Specify Units) Actual Annual Amount (Specify Units) Requested Annual Permit Limit4 (Specify Units) Material Consumption: Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.245345°, -104.609882° ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. " Operatorz Stack ID No. Discharge Height " Above Ground Level (Feet) Temp. " ('F) Flow Rate (ACFM) Velocity (ft/sec) TURB-2 45 Indicate the direction of the stack outlet: (check one) ❑✓ Upward O Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Upward with obstructing raincap QQ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): ll Form APCD-200 - General APEN - Revision 1/2017 COLORADO 3 I N�e�; Public Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit #, and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units) Requested Annual Permit Limit4 (Specify Units) 72.2 618.3 MMscf/yr From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (Asumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: El Other (describe): Pipeline natural gas Heating value (give units): 1023 Btu/scf a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Collection Efficiency Overall Control Efficiency (% reduction in emissions) TSP (PM) NAB) PM2.s SOx NOx CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 4 I ANag COLORADO irr Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Use the data reported in Sections 4 and 6 to calculate these emissions. PollutantFactor Uncontrolled Emission (Specify Units) Emission Factor Source (AP Mfg. etc) Actual Annual Emissions Requested Annual Permit a Emission Limit(s) Uncontrolled ( Controlled6 (Tons/year) 6 Uncontrolled (Tons/year) (Tons/year) ons/year)) TSP (PM) 0.0066 lb/MMBtu--- AP -42 2.1 2.1 PM10 0.0066Ib/MMBtu'-- AP -42 2.1 — 2.1 PM2 5 0.0066 Ib/MMBtu AP -42 2.1 ' 2.1 SOx 0.0034 Ib/MMBtu - AP -42 1.1 ' 1.1 NOx 0.055 Ib/MMBtu-' Mfg. 17.3 - 17.3 CO 0.062 1b/MMBtu' Mfg. 19.5 - 19.5 VOC 0.0021 Ib/MMBtu ' AP -42 0.7 — 0.7 Other: 4 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? O Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS Number8 Chemical Name Overall Control Efficiency ` Uncontrolled Emission Factor (specify units) Emission Factor Source (AP 42, Mfg. etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions6 (lbs/year) 50-00-0 Formaldehyde N/A 7.1E-04Ib/MMBtu — AP -42 449.1 i 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2OO - General APEN - Revision 1/2017 5 I �¢ COLORADO Depvmen[ d wain Htaha b EmironTaN Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 6ii/ZoI Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: (IJ Draft permit prior to issuance gi Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-2OO - General APEN - Revision 1/2017 6 I AV Hxath b Grsronmem COLORADO Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-2OO) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 11 AIRS ID Number: 12 3 /61F+2.1 00 3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: D-1 - TEG Dehydration Unit [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Milton Compressor Station Site Location: NE 1/4, S12, T3N, R65W Mailing Address: (Include Zip code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 364282 COLORADO 1 I .® Dcpamncn[dPuEuc Haalih 6 Env4nnmenl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 2- Requested Action ✓❑ NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: TEG dehydration unit for water removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: D-1 - TEG Dehydration Unit / / ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions ❑✓ days/week Yes Yes 52 ❑✓ weeks/year No No Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 2 AV "`I ,ms Hwahh b Fs�Yrnnman, COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: TBD TBD CI Ethylene Glycol (EG) Model Number: TBD Reboiler Rating: 3.0 ❑ (DEG) DiEthylene Glycol Glycol Pump Drive: ✓❑ Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: TBD ▪ (TEG ) # of pumps: Glycol Recirculation rate (gal/min): Lean Glycol Water Content: 1 Max: 40 Wt.% Requested: 40 MMBTU/hr hr TriEthylene Glycol Acfm/gpm Dehydrator Gas Throughput: Design Capacity: 130 MMSCF/day Requested: 47,450 MMSCF/year Actual: MMSCF/year Inlet Gas: Water Content: Wet Gas: Flash Tank: Cold Separator: Pressure: Pressure: 1056 Pressure: 60 psig lb/MMSCF psig psig Stripping Gas: (check one) ❑✓ None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm Temperature: ❑✓ Saturated Temperature: Temperature: 110 °F 6.7 Dry gas: 100 °F °F lb /MMSCF ❑ NA ❑ NA Additional Required Information: ❑✓ Attach a Process Flow Diagram 0 Attach GRI-GLYCaIc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) ❑� Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 3 Ho°t falQ, b isvbonmenl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.245345°, -104.609882° Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('F) Flow Rate (ACFM) Velocity (ft/sec) D-1 Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-2O2 -Glycol Dehydration Unit APEN - Revision 02/2017 4 !Li COLORADO Dent A Public 1. *al fl 0 ft EIMMO VIT.n1 Permit Number: AIRS ID Number: i [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information Used for control of: ❑ Condenser: Type: Make/Model: Maximum Temp Average Temp Requested Control Efficiency % ❑✓ VRU: Used for control of: Flash Tank Vapors Size: Make/Model: Requested Control Efficiency 95 % VRU Downtime or Bypassed 5 ❑ Combustion Device: Used for control of: Still Vent Stream Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: TBD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95 98 % Waste Gas Heat Content Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.O5 MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime 0 ✓❑ Other: Used for control of: Description: Control Efficiency Requested Flash Tank Vapors during VRU downtime Enclosed Combustion Device 95.0 % During periods of ECD downtime, estimated at 3% annually, still vent emissions will be vented to the atmosphere Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 5 I h® °`P°" ""`�', x.aim s �.w.a,m.n, COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction)• Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO NO,, CO VOC Vapor Recovery Unit / Enclosed Combustor 95.0 HAPs Vapor Recovery Unit / Enclosed Combustor 95.0 Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions. Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual. Permit gEmission Limit(s)4 Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SO, NO,, 0.068 Ib/MMBtu AP -42 CO _11.370.31 Ib/MMBtu AP -42 R,.?) -3-7— ii,71.2r.r VOC 40.9 Ib/MMscf GLYCaIc 971.3 - 46.4 - Benzene 3.7 Ib/MMscf GLYCaIc 87.9 6.8 — Toluene 3.4 Ib/MMscf GLYCaIc 81.2 - 6.3 Ethylbenzene 0.1 lb/MMscf GLYCaIc 2.3 -- 0.2. Xylenes 1.0 Ib/MMscf GLYCaIc 22.7 - 1.8 - n -Hexane 0.8 Ib/MMscf GLYCaIc 18.1 1.1 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-2O2 -Glycol Dehydration Unit APEN - Revision 02/2017 6 l •® Hulb F rleonmont Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ✓� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: / /www.colorado.gov/cdphe/apcd • COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7 I °"""°`n`"" ` xaann a �.�nonm.m (7 --ri.crrY Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-2OO) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: NNE E Q(Q 4- Z AIRS ID Number: 12 3 /q F-4-2" Q64 Y [Leave blank unless APCD has already assigned a permit # and AIRS ID] T Company equipment Identification: L-1 - Pressurized Hydrocarbon Liquid Loading [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: DCP Operating Company, LP Milton Compressor Station Site Location: NE 1/4, S12, T3N, R65W Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address' RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 IUse the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes wilt require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 364283 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 1Ief.1 COLORADO xaaun u, roman Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) OR ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Pressurized truck loadout of condensate For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / TBD/ Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? ❑ Yes ❑ No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes El No ❑ Yes El No ❑ Yes El No ❑ Yes ❑ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 2 I flepiTiT rcdPuhUc Hxal�n b Envvtenmant Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr Actual Volume Loaded: Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature bulk liquid loading: °F True Vapor Pressure Psia 60 °F Molecular weight of displaced vapors Lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: yZSib 1.o.31 .fir 714,286 Bbl/yr Actual Volume Loaded: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr Product Density: 40.5 Lb/ft3 Load Line Volume: 0.0218 ft3/truckload Vapor Recovery Line Volume 0.0218 ft3/truckload 3 I AV tettEt ntd � H:�un n ��uonm.m COLORADO Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit #, and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.245345°, -104.609882° Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('F) Flow Rate (ACFM) Velocity (ft/sec) L-1 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑✓ Loading occurs using a vapor balance system: Requested Control Efficiency 100 % ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency % Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 4I A¢ COLORADO d rush. Hu1N b...annum, Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] 5 Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO, NO„ CO VOC HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC ❑ Condensate ❑ Crude 0.236 Lbs/BBL 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Controlleds (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SO, NO, 'n11a►n4„tf VOC '"`' Jrnuui Eng. Estimate 1.9 • 1.9 CO Benzene Toluene Ethylbenzene Xylenes n -Hexane Q. cx0-7c \b,I.ado.i- 0.13 Q, 1 S 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 5 I AV zm-,1 7:-. N He HwiUl b F v�ronmam Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. • Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ✓❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-2O8 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 6 I }1*ann bEntonoul Hello