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Home My WebLink About20112359.tiff STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina,MD, MPH �oF•coto� Executive Director and Chief Medical Officer r6 Dedicated to protecting and improving the health and environment of the people of Colorado .(\ ;t, 4300 Cherry Creek Dr. S. Laboratory Services Division t Y/any+t* Denver,Colorado 80246-1530 8100 Lowry Blvd. tags Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.stale.co.us and Environment August 29, 2011 Mr. Steve Moreno Weld County Clerk 1402 N. 17th Ave. Greeley, , CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for the DCP Midstream, LP. This public notice will be published in Greeley Tribune on September 1, 2011. Thank you for assisting the Division by making the enclosed package (includes public notice, preliminary analysis, Air Pollutant Emission Notice(s) and draft permit(s)) available for public review and comment. It must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please forward any comment regarding this public notice to the address below. Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Attention: Ellen Evans Regards, Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division R—bk1c. 1`QA) lecc. c' „ . h-aL , Pt. 2011-2359 ci --7 - II 9- lil NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR NATURAL GAS PROCESSING PLANT BY DCP Midstream, LP CONTENTS 1 . PUBLIC NOTICE 2. PRELIMINARY ANALYSIS 3. AIR POLLUTANT EMISSION NOTICES 4. DRAFT PERMIT PREPARED BY: STEPHANIE CHAOUSY COLORADO DEPARTMENT OF PUBLIC HEALTH & ENVIRONMENT 4300 CHERRY CREEK DRIVE SOUTH, APCD-SS-B1 DENVER, CO 80246-1530 STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina, MD, MPH Si � Executive Director and Chief Medical Officer c h O Dedicated to protecting and improving the health and environment of the people of Colorado , �"% „ 4300 Cherry Creek Dr.S. Laboratory Services Division " " Denver,Colorado 80246-1530 8100 Lowry Blvd. _ / Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment Released to: The Greeley Tribune on August 29, 2011, published September 1, 2011 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT The Colorado Air Pollution Control Division declares the following proposed construction activity warrants public comment. Therefore, the Air Pollution Control Division of the Colorado Department of Public Health and Environment hereby gives NOTICE, pursuant to Section 25-7-114.5(5), C.R.S. of the Colorado Air Quality Control Act that the Division received an application for an air pollution emission permit on the following proposed project and activity: DCP Midstream, LP proposes to construct and operate an oil and natural gas processing facility known as the LaSalle Natural Gas Processing Plant. This facility will include one (1) 110 MMSCF/day amine sweetening unit, one (1) hot oil heater at 47 MMBtu/hr, one (1) regenerative heater at 8.8 MMBtu/hr, a condensate loadout, four (4) 400-bbl condensate storage tanks and associated fugitive emissions. It will be located in Section 31 of Township 5 North, Range 64 West in Weld County. The source is not subject to Non-Attainment New Source Review(NANSR) because the controlled criteria pollutant emissions are less than the threshold of 100 TPY. The source would be considered a major source of air pollutants subject to Non-Attainment New Source Review (NANSR) requirements if the operator did not install emissions controls and accept Federally enforceable emissions limits in the proposed permit. Since the operator will accept emissions limits less than IOU tons per year for each criteria pollutant and less than 10 tons per year any single hazardous air pollutant(HAP) and 25 tons per year total combined HAP, this source will be considered a synthetic minor source not subject to NANSR or MACT review. As such, this permit is subject to public comment per Regulation 3, Part B, Section III.C.I.c.(iii) and III.C.I.d. Copies of the draft permit and preliminary analysis are available for review in the public comment package. The Division has determined that the proposed source will comply with all applicable regulations and standards of the Colorado Air Quality Control Commission and has made a preliminary determination of approval of the application. The Division hereby solicits and requests submission of public comment from any interested person concerning the aforesaid proposed project and activities to comply with the applicable standards and regulations of the Commission for a period of thirty (30) days from the date of this publication. Any such comment must be submitted in writing to the following addressee: Stephanie Chaousy, PE Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 Within thirty(30) days following the said thirty (30)-day period for public comment,the Division shall consider comments and, pursuant to Section 25-7-1 14.5(7)(a), either grant, deny, or grant with conditions, the emission permits. Said public comment is solicited to enable consideration of approval of and objections to the proposed construction of the subject project and activity by affected persons. A copy of the applications for the emission permits, the preliminary analysis of said applications, and accompanying data concerning the proposed project and activity are available for inspection at the office of the Clerk and Recorder of Weld County during regular business hours and at the office of the Air Pollution Control Division, Colorado Department of Public Health and Environment, 4300 Cherry Creek Drive South, Denver, Colorado. Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: DCP Midstream, LP Permit Number: 11WE1481 Source Location: Section 31, T5N, R64W,Weld County (non-attainment) Point 001: Amine Sweetening Unit Point 002: Hot oil heater Point 003: Regeneration heater Equipment Description: Point 004: Condensate loadout. Point 005: 4-400bb1 condensate storage tanks Point 006: Fugitive emissions AIRS ID: 123-9012 Date: June 30, 2011 Review Engineer: Stephanie Chaousy, PE Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 (Facility- Transfer of Ownership APEN Exempt/Permit Exempt wide) Section 3 —Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? Yes X No Did the applicant provide ample information to determine emission rates? X Yes No Page 1 If you answered "no" to any of I emailed Wes Hill on 6/30/11: the above, when did you mail an • Point 006: It seems that the wt% information on the gas analysis is Information Request letter to the not matching what is on the APEN. I requested of him to review the source? submittal and to make sure the correct gas analysis was included in the package. Wes wrote back on 7/5/11: The analysis that was included with the application was an extended liquid condensate analysis which was not used for calculating the fugitive emissions. Since this facility has not been built, we do not have an actual inlet gas analysis. The fugitive emissions were based on the "treated stream"from the amine unit PROMAX run. We chose the treated stream to be a little more conservative. The inlet stream was determined from engineering based on several different streams that could possibly be routed to the plant. Our engineers made their best guess at a composite concentration and used that in the PROMAX run. An actual gas analysis will likely be required by the permit for self-certification and that will be fine. • I cannot find the "insignificant inventory" sheet (that is referenced on APCD Form 102). He sent it to me via email on 7/5/11, but it was in Attachment C, not Attachment F where I thought it would be. On what date was this application complete? March 23, 2011 Section 4—Source Description AIRS Point Equipment Description Natural gas sweetening system using a solution of Methyldiethanolamine (MDEA), process feed gas design rated at 110 MMSCF per day, and an amine recirculation rate of 520 gallons per minute. This system consists of: natural gas amine contactor, amine flash 001 tank, and amine regenerator(heating unit under AIRS PT ID: 123/9012/002). Emissions from the acid gas stream are routed to a regenerative thermal oxidizer with a destruction efficiency of 99%. Emissions from the flash tank stream are controlled with a vapor recovery unit (VRU) with a control efficiency of 100%. 002 Hot oil heater(manufacturer, model, SN: TBD) that heats oil for several processes within the gas plant. 003 Regenerative heater(manufacturer, model, SN: TBD) used for molecular sieve regeneration. 004 Condensate loadout. Emissions controlled by a combustor with a minimum destruction rate of 95%. 005 Four(4) tanks, 400 bbl each, for storage of stabilized natural gas condensate. Emissions controlled by a combustor with a minimum destruction rate of 95%. 006 Equipment leaks (fugitive VOCs) from a natural gas processing facility. Emissions are controlled with a LDAR program. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes" the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Section 5— Emission Estimate Information _ AIRS Point Emission Factor Source Page 2 001 Site-specific using ProMax (Refer to Section 14 for calculations) 002 AP-42, Section 1.4, Tables 1.4-1, 1.4-2, and 1.4-3 003 AP-42, Section 1.4, Tables 1.4-1, 1.4-2, and 1.4-3 AP-42: Chapter 5.2, Equation 1 L = 12.46"S*P"M/T where: L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] 004 M = molecular weight of vapors [lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] For NOx and CO emissions, emission factors came from TNRCC (Texas Commission on Environmental Quality) NOx = 0.138 lb/mmbtu; CO = 0.5496 lb/mmbtu 005 Site-specific emission factors using TANKS 4.0.9d and extended liquids analysis (Refer to Section 14 for calculations) 006 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 40,150 MMSCF/yr 002 448.99 MMSCF/yr 003 42.03 MMSCF/yr 004 456,250 bbl per year condensate loaded 005 456,250 bbl per year condensate Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2297 --- 7279 --- 006 Flanges 2062 --- 1375• --- Open-Ended Lines 0 --- 0 --- _Pump Seals 0 --- 46 --- Valves 3026 --- 2378 --- Other 178 --- 43 _ --- Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 40,150 MMSCF/yr 002 448.99 MMSCF/yr 003 42.03 MMSCF/yr 004 456,250 bbl per year condensate loaded 005 456,250 bbl per year condensate Page 3 Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 2297 --- 7279 --- 006 _Flanges 2062 --- 1375 --- Open-Ended 0 --- 0 --- Lines Pump Seals 0 --- 46 --- Valves 3026 --- 2378 --- Other 178 --- 43 --- Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 40,150 MMSCF/yr 002 448.99 MMSCF/yr 003 42.03 MMSCF/yr 004 456,250 bbl per year condensate loaded 005 456,250 bbl per year condensate Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) _ Connectors 2297 --- 7279 --- 006 Flanges 2062 --- 1375 --- Open-Ended Lines 0 --- 0 --- Pump Seals 0 --- 46 --- Valves 3026 --- 2378 --- Other 178 --- 43 --- Does this facility use control devices? X Yes No % Reduction AIRS Point Process Control Device Description Granted 01 Flash Tank Stream: VRU 100 001 01 Acid Gas Stream: RTO 99 002 01 NA 0 ` 003 01 NA 0 004 01 Combustor 95 005 01 Combustor 95 75% except for 006 01 LDAR control program flanges & connectors: 30% Page 4 [ Section 6- Emission Summary (tons per year) Point H2S SOx NO, VOC CO Single HAP Total HAP 001 13.1 24.5 0.4 448.5 1.9 50.6 (benzene) 98.0 002 --- --- 11.2 1.2 18.9 0.4 (n-hexane) 0.4 003 --- --- 1.1 0.1 1.8 0.03 (n-hexane) 0.03 PTE: 004 --- --- 0.1 46.2 0.5 3.3 (n-hexane) 7.0 I 005 --- --- 0.1 25.2 0.3 1.8 (n-hexane) 3.8 006 --- --- --- 120.6 --- 2.1 (n-hexane) 2.3 001 13.1 24.5 0.4 448.5 1.9 50.6 (benzene) 98.0 002 --- --- 11.2 1.2 18.9 0.4 (n-hexane) 0.4 Uncontrolled point 003 --- --- 1.1 0.1 1.8 0.03 (n-hexane) 0.03 source emission rate: 004 --- --- 0.1 46.2 0.5 3.3 (n-hexane) 7.0 005 --- --- 0.1 25.2 0.3 1.8 (n-hexane) 3.8 006 --- --- --- 120.6 --- 2.1 (n-hexane) 2.3 001 0.13 24.5 (0.4) 1.3 1.9 0.5(benzene) 0.9 002 --- --- 11.2 1.2 18.9 0.4 (n-hexane) 0.4 Controlled point 003 --- --- 1.1 0.1 1.8 0.03 (n-hexane) 0.03 source emission rate: 004 --- --- (0.1) 2.3 (0.5) 0.2 (benzene) 0.4 005 --- --- (0.1) 1.3 (0.3) 0.1 (n-hexane) 0.2 006 --- --- --- 38.8 --- 0.8 (n-hexane) 0.9 Total permitted 0.13 24.5 12.3 45.0 22.6 1.3 (n-hexane) 2.8 emissions (TPY) Section 7— Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable? Rate(Ib/yr) Point 109 Benzene 71432 A 101157 Yes 943 Toulene 108883 C 68534 Yes 646 Ethylbenzene 100414 C 1167 Yes 11 Xylenes 1330207 C 13175 Yes 125 n-Hexane 110543 C 11863 Yes 12 Point 002 Formaldehyde 50000 A 34 No 34 n-Hexane 110543 C 808 No 808 Point 003 Formaldehyde 50000 A 3 No 3 n-Hexane 110543 C 76 No 76 Point 004 Page 5 Benzene 71432 A 1228 Yes 61 Toulene 108883 C 3402 Yes 170 Ethylbenzene 100414 C 253 No 13 Xylenes 1330207 C 2571 Yes 129 n-Hexane 110543 C 6605 Yes 330 Point 005 Benzene 71432 A 670 Yes 34 Toulene 108883 C 1858 Yes 93 Ethylbenzene 100414 C 138 No 7 Xylenes 1330207 C 1404 Yes 70 n-Hexane 110543 C 3607 Yes 180 Point 006 Benzene 71432 A 210 Yes 64 Toulene 108883 C 147 No 44 Xylenes 1330207 C 28 No 9 n-Hexane 110543 C 4128 Yes 1260 Note: Regulation 3, Part A, Section I1.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 01 VOC, Regulation No. 3, Part B., Section Stack Test HAPS III.G.3 VOC, Extended sour gas 001 01 HAPS State-only requirement analysis VOC, Initial sample of the 01 HAPS State-only requirement inlet gas to the plant 01 VOC, State-only requirement Extended gas analysis 006 HAPS 01 VOC, State-only requirement Component hard count HAPS Section 9— Source Classification Are these new previously un-permitted sources? Yes No Point 001: Amine Sweetening Unit X Point 002: Hot oil heater X Point 003: Regeneration heater X Point 004: Condensate loadout. X Point 005: 4-400bb1 condensate storage tanks X Point 006: Fugitive emissions X Page 6 What is this point classification? True Minor Synthetic Minor Major Point 001: Amine Sweetening Unit X Point 002: Hot oil heater X Point 003: Regeneration heater X Point 004: Condensate loadout. X Point 005: 4-400bbl condensate storage tanks X Point 006: Fugitive emissions X What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? Yes X No If"yes" what kind of modification? Minor Synthetic Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? Yes X No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? X Yes' No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Regulation 1 Particulate;Smoke;Carbon'Monozide'aiid Sulftar Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 001-006 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Requlation`2-Odor Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-006 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Page 7 Regulation 3-APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements 001-006 Applicant is required to file an APEN since emissions exceed.] ton per year VOC in a nonattainment area for ozone. Part B —Construction Permit Exemptions 001-006 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.3.a) Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. The date of interest for determining 004 whether the source is new or modified is therefore November 20, 2007 (the date of the 8- hour ozone NA area designation). Since the tank battery from which loadout is occurring will be in service after the date above, this source is considered "new or modified." DCP Midstream used 0.6 (submerged-normal service) for their saturation factor. This satisfies RACT requirements. Requlatitn 6=New Source Performance Standards ,:i ,,,r NSPS LLL: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after January 24, 1984. 001 This source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.647(c) to keep for the life of the equipment an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. NSPS Dc: applies to each "stream generating unit" for which c/m/r commenced after June 9,1989 and that has a maximum design heat input capacity of 100 MMBtu/hr or 002 less, but greater than 10 MMbtulhr. This source is greater than 10 MMBtu/hr (47 MMBtu/hr) and will be commencement after June 9, 1989. Therefore, this source is subject to NSPS Dc. NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 005 Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No WHY? Because these tanks each have capacity less than 471 bbl. NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities (any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids (NGLs) or both). 006 Is this source at a "natural gas processing plant?" Yes Is this source subject to NSPS KKK? Yes WHY? Because this source is defined as a "natural gas processing plant" per the definition of NSPS KKK. This facility has implemented an LDAR control program. Regulation 7.=Volatile Organic Compounds ,,-„ XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Not subject because tanks store stabilized condensate). 005 XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC.) Regulation 8 Hazardous Air Pollutants 004 and MACT EEEE: Organic Liquids Distribution 005 This source is not subject to MACT EEEE because it is not located at a major source of HAP. MACT HH 005, 006 This source is not subject to MACT HH because it is not located at a major source of HAP. Source not subject to area source because no TEG dehydrator. Section 13— Aerometric Information Retrieval System Coding Information Process Pollutant/ Fugitive Emission Control Point Process Description Emission Factor CAS# (Y/N) Factor Source (%) Page 8 22.34 lbs/mmscf VOC No ProMax 99 Simulation 2.52 lbs/mmscf Benzene 171432 No ProMax 99 Simulation 1.71 lbs/mmscf Toluene/108883 No ProMax 99 01 001 Sweetening unit 0.03 lbs/mmscf Ethylbenzene/ No ProMax 99 100414 Simulation 0.33 lbs/mmscf Xylenes/1330207 No ProMax 99 Simulation 0.30 lbs/mmscf n-Hexane/ No ProMax 99 110543 Simulation SCC 31000305—Gas Sweetening; Amine process 50 lbs/mmscf NOx No AP-42; Table NA 1.4-1 - 01 47 MMBtu/hr Hot 84 lbs/mmscf CO No AP-42;Table NA 002 Oil Heater 1.4-1 5.5 Ib/mmscf VOC No AP 42;Table NA 1.4-2 SCC 10200602: 10-100 Million btu/Fir 50 Ibs/mmscf NOx No AP-42;Table NA 1.4-1 01 8.8 MMBtu/hr 84 lbs/mmscf CO No AP-42;Table NA • 003 Regen Heater 1.4-1 AP-42;Table 5.5 Ib/mmscf VOC No 1.4-2 NA SCC 10200603: < 10 Million btu/hr 004 01 Truck Condensate 4.82 lb/1000 gal VOC No AP-42 95 Loadout throughput SCC 4060132: Crude Oil: Submerged Loading(Normal Service) 2.6322 lb/1000 VOC No Tanks 4.0.9d 95 gal throughput 0.138 NOx No TNRC NA lbs/mmbtu 0.5496 CO No TNRC NA Ibs/mmbtu 0.0035 lb/1000 Extended gal throughput Benzene/71432 No liquids 95 analysis Stabilized 0.00971b11000 Extended 01 Condensate Toluene/108883 No liquids 95 005 Storage Tanks gal throughput analysis 0.0073 lb/1000 Ethylbenzene/ Extended gal throughput 100414 No liquids 95 analysis 0.0731 lb/1000 Extended gal throughput Xylenes/1330207 No liquids 95 analysis 0.1879 lb/1000 n-Hexane/ Extended gal throughput 110543 No liquids 95 analysis sCC 40400311 —Fixed Roof.Tank, Condensate, working+breathing+flashing losses All 75%,except 006 01 Fugitive VOC VOC Yes EPA-453/R-95- for flanges& Leak Emissions 017,Table 2-4 connectors: 30% SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections,seals, drains) Page 9 Section 14— Miscellaneous Application Notes AIRS Point 001 Amine sweetening unit The reboiler is rated at 47 MMBtu/hr and is covered under AIRS PT 002 since it is not eligible for Regulation 3, Part A, II.D.1.k exemptions. Site-specific using ProMax VOC = (448.44*2000)/40150= 22.34 lb/mmscf Benzene = (50.58*2000)/40150=2.52 lb/mmscf Toluene= (34.27*2000)/40150 = 1.71 lb/mmscf Ethylbenzene = (0.58*2000)/40150= 0.03 lb/mmscf Xylenes= (6.59*2000)/40150=0.33 lb/mmscf n-hexane = (5.93*2000) /40150 = 0.30 lb/mmscf Controlled emission factors are calculated with 99% control. The table below summarizes the inputs to the process simulation used to calculate the PTE for this equipment. TABLE 1 Parameter Inlet Gas Rich Amine Lean Amine Sour Gas input Flash Tank Feed Stream Temperature 112 °F 199.3°F 122 °F 112 °F 155.7 °F Pressure 900 psig 21.7 psia 925 psia 900 psia 72.3 psia Flowrate NA 555.7 gal/min 520 gal/min 110 mmscf/day NA For lean amine stream: Amine wt%45-60, Piperazine wt% 3-7%,Water Wt%40-55 Carissa Money provided comments during manager review. I emailed Wes Hill with DCP on 8/4/11 the following questions based on her review: 1. It looks like Promax was run based on 44% MDEA and 6% piperazine. The APEN says that amine wt is 45- 60% MDEA. The model needs to be run with the highest allowable MDEA concentration to ensure the maximum emissions are modeled. If 44% is the maximum allowable concentration, I will just redline the APEN. Wes responded on 8/16/11: You can just list 50%on the APEN. The amine is an MDEA/Piperazine mix. Piperazine is an additive to the blend that acts like a "promoter"for the MDEA. This essentially makes the MDEA more efficient at removing CO2. The vendor will not provide the mix because it is proprietary but after speaking with them, we felt that our 44%MDEA/6%piperazine (50%total)Is a good approximation for emissions purposes. The bottom line is that it will be about a 50/50 mix amine and water. The range was a first guestimate but we believe that our PROMAX run is accurate. Since we don't know the exact mix, please leave %MDEA out of the description. 2. The amine unit H2S emissions are incorrect. It was assumed 100%conversion of H2S to SO2 but it should only be assumed 99%. SO2 and H2S emission limits will need to be revised on the APEN addendum form. Wes responded 8/16/11: Yes, we had done 100%conversion to be conservative on the SO2. I think that is fine. Attached is a signed APEN addendum that includes the H2S concentration AIRS Point 002 I Hot Oil Heater This source requires a permit because: • CO emissions are greater than 1 TPY, and since the facility is permitted, this source is permit-required (since total facility is greater than 5 TPY CO). • The rating of the heater is 47.0 MMBtu/hr,which is greater than the APEN-exemption threshold of 5 MMBtu/hr. Emission factors are based from AP-42, Section 1.4. August 25, 2011: During Operator DRAFT review, DCP noticed an error in their emission calculations. The heat value and fuel use numbers were incorrect. I revised the PA and permit accordingly. AIRS Point I 003 Regen Heater This source requires a permit because: • CO emissions are greater than 1 TPY, and since the facility is permitted, this source is permit-required (since total facility is greater than 5 TPY CO). • The rating of the heater is 8.8 MMBtu/hr, which is greater than the APEN-exemption threshold of 5 MMBtu/hr. Emission factors are based from AP-42, Section 1.4. August 25, 2011: During Operator DRAFT review, DCP noticed an error in their emission calculations. The heat value and fuel use numbers were incorrect. I revised the PA and permit accordingly. Page 10 AIRS Point 004 I Condensate truck loadout AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T S 0.6 Submerged loading: dedicated normal service P 5.0032 psia M 66 lb/lb-mole for gasoline with RVP = 11.5 T 512.45 deg. R L 4.821b/10^3 gal 2.02E-01 lb/bbl Annual requested Throughput 19162500ga1/yr Annual requested VOC emissions 923131b/yr 46.2tpy Where: S 0.6 Submerged loading: dedicated normal service P 5.0032 Psia Based on EPA TANKs run M 66 Lb/lb-mole Based on EPA TANKs run T 512.45 Deg R Based on EPA TANKs run L 4.82 Lb/10^gal This value is used to calculate annual emissions Emission factors for NOx and CO came from the TNRCC (Texas Commission on Environmental Quality) NOx=0.138 lb/mmbtu; CO =0.5496 lb/mmbtu Carissa Money provided comments during manager review. I emailed Wes Hill with DCP on 8/4/11 the following questions based on her review: 1. Even though there is not an O&M template online for condensate loadouts, I would like to request an O&M plan for the condensate loadout since it is a controlled point source at a synthetic minor facility. I would suggest using the O&M template for the condensate tank, and write-up something that will accommodate the loadout. Wes responded on 8/16/11: See attached O&M Plan for the loadout. AIRS Point I 005 I Condensate Storage Tanks Site-specific emission factors using TANKS 4.0.9d and extended liquids analysis Conversion from lb/bbl to lb/1000 gal 4 ((lb/bbl e.f.)* 1000)/42 VOC = (25.22*2000)/(456250) =0.111 lb/bbl (2.6322 lb/1000 gal) Benzene= (0.34'2000)/(456250) =0.002 lb/bbl (0.0035lb/1000 gal) Toluene = (0.93'2000)/(456250) =0.0041 lb/bbl (0.0097 lb/1000 gal) Ethylbenzene= (0.07'2000) /(456250) =0.0003 lb/bbl (0.0073 lb/1000 gal) Xylenes=(0.70"2000)/(456250) = 0.0031 lb/bbl (0.0731 lb/1000 gal) n-hexane = (1.80'2000)/(456250) = 0.0079 lb/bbl (0.1879 lb/1000 gal) For NOx and CO emissions, emission factors came from TNRCC (Texas Commission on Environmental Quality) NOx =0.138 lb/mmbtu; CO = 0.5496 lb/mmbtu AIRS Point I 006 I Fugitive emissions This source requires a permit because uncontrolled VOC emissions are greater than 2 TPY. Source is controlling VOC emissions since emissions are greater than 100 TPY using a LDAR program per NSPS KKK requirements. Carissa Money provided comments during manager review. I emailed Wes Hill with DCP on 8/4/11 the following questions based on her review: 1. Something is incorrect with the fugitive emission limits. The calculation sheets say that DCP is claiming 75% on gas components and 30% control on liquid components for LDAR program. The emissions on the APEN are showing 92%. Please see attached. I think only the gas components were counted up, and not both gas and liquid. This increase still makes the facility less than 100 TPY controlled VOC (syn minor). Wes responded on 8/16/11: You are correct. There was an error in the summary table that did not pull in the liquids. Please redline the fugitives APEN using the numbers provided in the attached revised calculation sheet. August 25, 2011: During Operator DRAFT review, DCP noticed an error in their emission calculations. The control factors should have been 75%for all components except for flanges and connectors, which would be 30%control. The original application showed 75% control for gas services and 30% control for liquid services. I revised the PA and permit and added a note in the "Notes to Permit Holder"explaining the control efficiencies. Page 11 Insignificant Activities The source provided emission estimates for several insignificant activities at the facility. Since APENs were not submitted for these insignificant activities, emissions and regulatory applicability were not evaluated for these activities/points. Emissions listed in the application were included in the history file to understand total facility emissions but otherwise not reviewed as part of this permit action. Facility Wide Comments DCP is proposing to construct and operate a natural gas processing facility with a capacity of 110 MMscfd. This stationary source will be located in Weld County which is currently considered a non-attainment area for ozone. The facility will install emissions controls in order to be considered a synthetic minor source for Non-attainment New Source Review(NANSR) requirements that would have otherwise been triggered due to emissions of volatile organic compounds (VOC) in excess of 100 tons per year. The source will be a synthetic minor source of criteria pollutants and HAP emissions for Title V Operating Permit program. DCP supplied a greenhouse gas inventory with the application and stated that the CO2e potential to emit from the LaSalle Compressor Station will be less than 100,000 tpy. Carissa Money provided comments during manager review. I emailed Wes Hill with DCP on 8/4/11 the following questions based on her review: 1. We will need confirmation that the plant is not located in an existing area of poor air quality per the modeling guidelines. Wes responded on 8/16/11: The term "existing area of poor air quality"is not defined in the State statute or in Regulation No. 3. To the extent the term is referenced in guidance issued by the Division (i.e., the May 20, 2011 Colorado Modeling Guideline), we are concerned that recent iterations of that guidance have not been properly subject to public notice and comment. Given these facts, DCP is uncertain as to how to respond to the Division's inquiry other than to reiterate that the La Salle plant was carefully engineered to ensure that the facility-wide emissions of NOx will be less than 40 tpy(i.e., 20.8 tpy in this case). Therefore,per PS Memo 10-01, the project is not subject to ambient air modeling requirements because it does not trigger the 40 tpy SER referenced in the PS Memo. While the facility-wide emissions are therefore determinative in this case for modeling purposes, it may also be useful to note the following as it relates to various notes in "Table 1"to Modeling Guideline. The first note states: "(1) Modeling is usually warranted, even though the source or modification does not exceed the modeling thresholds in Table 1, if it is reasonable to believe the source will cause or contribute to a violation of applicable ambient air quality standards in circumstances such as: (a) Sources of SO2, PM-10, CO, or Pb where a substantial portion of the new or modified emissions have poor dispersion characteristics(e.g., rain caps, horizontal stacks, fugitive releases, 3 or building downwash4)in close proximity to ambient air at the site boundary. . . ." The LaSalle Gas Plant will not have any horizontal stacks or rain caps causing poor dispersion from any of the NOx sources. The main sources of NO,are the 2 heaters which will both have stacks that are 40 feet tall. DCP has also purchased approximately a quarter section of land to build the facility on, so the ambient air boundary is distant from release points. The Note 1(b) states: "(b) Sources of SO2, PM-10, CO, or Pb located in complex terrain (e.g., terrain above stack height in close proximity to the source) . . . ." This facility will be located near La Salle, Colorado on mostly flat terrain. This is not a mountainous area; therefore, complex terrain should not be an issue. The Note 1(c)states: "(c) Sources located in areas with poor existing air quality. . . ." Since the term "area with poor existing air quality"is not defined, DCP can only confirm that the La Salle Plant will be located in the ozone non-attainment area. The largest source of NO,within a 5 km of the plant is AKA Energy's Kersey Gas Plant at 10.4 tpy. The other nearby sources(i.e. within 5km) are small tank combustors from local E&P companies. DCP does not believe that the La Salle plant location, or its proximity to other small sources constitutes an "area with poor existing air quality". The note 1(d)states: "(d)Modifications at existing major stationary sources, including grandfathered sources that have never been modeled before." After further discussion and review, this project will not require modeling since NOx is less than 40 TPY. Page 12 CL N 0 CO 3 3 A o c 'c E a � Jest E v ° ti 74 o o E Z , o `/ l (4, .n .n F o c Cr �' P. c U c cn a, rn a .o o c a m K c N o ❑ ❑ 5 F u n a c — a e F C'- i eH ' E. 0 od :e c c oro .- c-0v i t o a y 3 Z Z c .E ? G:7 - a s .. .. ,ti aoS: y u E m .Lu. N ❑ ❑ i H c .�. ,;� _� cc�. = o '� '� P' e o E w E u a -- :‘," A tc° ss z o. 6 a n. -- 1 a 9 cui u w u r u C ro Y ❑ Ei ,o i E oN �=. WM m .C Lw 'O oL v ,dW d. 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STATE OF COLORADO pF COzo COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT New`_ AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 ` ,s,6% CONSTRUCTION PERMIT PERMIT NO: 11WE1481 WE1481 Issuance 1 DATE ISSUED: ISSUED TO: DCP Midstream, LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas processing facility, known as the LaSalle Natural Gas Processing Plant, located in Section 31, Township 5 North, Range 64 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point Natural gas sweetening system using a solution of Methyldiethanolamine (MDEA), process feed gas design rated at 110 MMSCF per day, and an amine recirculation rate of 520 gallons per minute. This system consists of: natural gas AM001 001 amine contactor, amine flash tank, and amine regenerator (heating unit under AIRS PT ID: 123/9012/003). Emissions from the acid gas stream are routed to a regenerative thermal oxidizer with a destruction efficiency of 99%. Emissions from the flash tank stream are controlled with a vapor recovery unit (VRU) with a control efficiency of 100%. H-6001 002 Hot oil heater (manufacturer, model, SN: TBD) that heats oil for several processes within the gas plant. H-3001 003 Regenerative heater (manufacturer, model, SN: TBD) used for molecular sieve regeneration. LO 004 Condensate loadout. Emissions controlled by a combustor with a minimum destruction rate of 95%, Four (4) tanks, 400 bbl each, for storage of stabilized natural Tanks 005 gas condensate. Emissions controlled by a combustor with a minimum destruction rate of 95%. Equipment leaks (fugitive VOCs) from a natural gas FUG 006 processing facility. Emissions are controlled with a LDAR program. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND AIRS ID: 123/9012/999 Page 1 of 17 NGEngine Version 2009-1 DCP Midstream, LP .' . Col r'• do Dpi ' !rtt e !Public Health and Environment Permit No. 11WE1481 • Air Pollution Control Division Issuance 1 CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the APCD no later than fifteen days after commencement of the permitted operation or activity by submitting a Notice of Startup (NOS) form to the APCD. The Notice of Startup (NOS) form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the permitted source is a violation of 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) after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee'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; (Hi) 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. Points 002 and 003: The manufacturer, model number and serial number of the subject equipment shall be provided to the Division within fifteen days (15) after commencement of operation. This information shall be included on the Notice of Startup (NOS) 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. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility AIRS Pounds per Month Emission Equipment Point H2S SO, NO, VOC CO Type ID AM001 001 34 4,179 ---- 225 327 Point AIRS ID: 123/9012/999 Page 2 of 17 'Nyti a `n en . ,6 A w-1 t t'� 1, DCP Midstream, LP 'gj y,9' Col �i ,do D p rtmeiit of Public Health and Environment Permit No. 11WE1481 t ,, ^� r Air Pollution Control Division Issuance 1 ,` .„v. �4_ c L t:L, H-6001 002 --- --- 1,920 221 3,211 Point H-3001 003 --- --- 187 --- 306 Point LO 004 --- --- --- 393 --- Point Tanks 005 --- --- --- 221 --- Point FUG 006 --- --- --- 6,591 --- Point Monthly limits are based on a 31-day month. Facility-wide emissions of each individual hazardous air pollutant shall be less than 1,358.9 lb/month. Facility-wide emissions of total hazardous air pollutants shall be less than 3,397.3 lb/month. Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point HZS SO. NO,� VOC CO Type AM001 001 0.2 24.6 ---- 1.3 1.9 Point H-6001 002 --- --- 11.3 1.3 18.9 Point H-3001 003 --- --- 1.1 --- 1.8 Point LO 004 --- --- 2.3 --- Point Tanks 005 --- --- --- 1.3 --- Point FUG 006 --- --- --- 38.8 --- Point See "Notes to Permit Holder #4 for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly limitation shall be required. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (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 monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division AIRS ID: 123/9012/999 Page 3 of 17 i ]V 'G a1y�y 'P :LFs DCP Midstream, LP , ! Color do D park eb, ott Public Health and Environment Permit No. 11WE1481 F� ,05 Air Pollution Control Division Issuance 1 MEk, d,, ', A.t ,, . ;�., r,. ,-, review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 8. Point 001: Compliance with the emission limits in this permit shall be demonstrated by running the Promax simulation model or Division-approved software on a monthly basis using the most recent amine unit inlet extended sour gas analysis and recorded operational values (including gas throughput, lean amine recirculation rate, VRU downtime, and other operational values as specified in the O&M plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into Promax simulation model. 9. Point 001: 100% of emissions that result from the flash tank shall be routed to the VRU to be recycled and recompressed. Emissions from the regenerator still vent shall be collected and controlled by a regenerative thermal oxidizer in order to reduce the emissions of volatile organic compounds to the level listed in this section, above. Operating parameters of the VRU and thermal oxidizer are identified in the operation and maintenance plan for this unit. (Reference: Regulation No.3, Part B, Section III.E.) 10. Point 004: This unit shall be configured such that the vapors are routed to a facility combustor. The combustor shall reduce uncontrolled emissions of VOC to the emission levels listed in this section, above. (Reference: Regulation No.3, Part B, Section III.E.) 11. Point 005: This emissions point shall be configured such that the vapors are routed to a facility combustor. The combustor shall reduce uncontrolled emissions of VOC to the emission levels listed in this section, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 12. Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 13. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Annual Monthly Limit Equipment Point Process Parameter Limit (31 days) ID AM001 001 Natural gas throughput 40,150 3,410 MMscf/yr MMscf/month H-6001 002 Consumption of natural gas as a fuel 449.0 38.1 MMscf/yr MMscf/month AIRS ID: 123/9012/999 Page 4 of 17 • � Haft fr DCP Midstream, LP Coln I do p itie o Public Health and Environment Permit No. 11 WE1481 Air Pollution Control Division Issuance 1 TM re,V, the life of the facility, an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. Heaters 19. Point 002: This source is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A Subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units including, but not limited to, the following: a. The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month (40 CFR Part 60.48c(g)). b. Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record (40 CFR Part 60.48c(i)). In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply. c. At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 d. No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (§ 60.12) e. Written notification of construction and initial startup dates shall be submitted to the Division as required under § 60.7. f. Records of startups, shutdowns, and malfunctions shall be maintained, as required under § 60.7. g. Excess Emission and Monitoring System Performance Reports shall be submitted as required under § 60.7. h. Performance tests shall be conducted as required under § 60.8. General notification and reporting requirements under § 60.19. 20. Points 002 and 003: Particulate emissions shall be limited as per: Regulation 6, Part B, II.C.2. Condensate Truck Loadout AIRS ID: 123/9012/999 Page 6 of 17 DCP Midstream, LP s Coii do D. late- or Public Health and Environment Permit No. 11WE1481 # Air Pollution Control Division Issuance 1 H-3001 003 Consumption of natural gas as a fuel 42.03 3.6 MMscf/yr MMscf/month 456,250 38,750 LO 004 Condensate Loading BBL/yr BBL/month 456,250 38,750 Tanks 005 Condensate throughput BBL/yr BBL/month Compliance with the yearly consumption 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 monthly consumption of natural gas and keep a compliance record on site or at a local field office with site responsibility, for Division review. 14. Point 001: This unit shall be limited to the maximum lean amine recirculation pump rate of 520 gallons per minute. The lean amine recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 15. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable). 16. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. & 4.) 17. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) Amine Sweetening Unit 18. Point 001: This amine unit is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart LLL, Standards of Performance for Onshore Natural Gas Processing: SO2 Emissions, including, but not limited to, the following: • 40 CFR, Part 60, Subpart A— General Provisions • §60.640 —Applicability and Designation of Affected Facilities o §60.640(b) - Facilities that have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are required to comply with §60.647(c) but are not required to comply with §§60.642 through 60.646. • §60.647 — Record keeping and reporting Requirements o §60.647(c) - To certify that a facility is exempt from the control requirements of these standards, each owner or operator of a facility with a design capacity less that 2 LT/D of H2S in the acid gas (expressed as sulfur) shall keep, for AIRS ID: 123/9012/999 Page 5 of 17 • w;w wa 134 sxx g .vv.,xs.,; DCP Midstream, LP Col i do pamelt or Public Health and Environment Permit No. 11WE1481 Air Pollution Control Division Issuance 1 7,, •k .A. i 21. Point 004: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) Condensate Storage Tanks 22. Point 005: The condensate storage tanks covered by this permit are subject to Regulation 7, Section XVII emission control requirements. These requirements include, but are not limited to: Section XVII.C. - Emission reduction from condensate storage tanks at oil and gas exploration and production operations, natural gas compressor stations, natural gas drip stations and natural gas processing plants. XVII.C.1. Beginning May 1, 2008, owners or operators of all atmospheric condensate storage tanks with uncontrolled actual emissions of volatile organic compounds equal to or greater than 20 tons per year based on a rolling twelve-month total shall operate air pollution control equipment that has an average control efficiency of at least 95% for VOCs on such tanks. XVII.C.3. Monitoring: The owner or operator of any condensate storage tank that is required to control volatile organic compound emissions pursuant to this section XVII.C. shall visually inspect or monitor the Air Pollution Control Equipment to ensure that it is operating at least as often as condensate is loaded out from the tank, unless a more frequent inspection or monitoring schedule is followed. In addition, if a flare or other combustion device is used, the owner or operator shall visually inspect the device for visible emissions at least as often as condensate is loaded out from the tank. XVII.C..4. Recordkeeping: The owner or operator of each condensate storage tank shall maintain the following records for a period of five years: XVII.C.4.a. Monthly condensate production from the tank. XVII.C.4.b For any condensate storage tank required to be controlled pursuant to this section XVII.C., the date, time and duration of any 41 period where the air pollution control equipment is not operating. The duration of a period of non-operation shall be from the time that the air pollution control equipment was last observed to be operating until the time the equipment recommences operation. XVII.C.4.c. For tanks where a flare or other combustion device is being used, the date and time of any instances where visible emissions are observed from the device. 23. Points 005: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. AIRS ID: 123/9012/999 Page 7 of 17 DCP Midstream, LP Pr, , Cola do • p AC,' o Public Health and Environment Permit No. 11WE1481 /c Air Pollution Control Division Issuance 1 Fugitive Emissions 24. Point 006: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive VOC emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 C.F.R. Part 60, Subpart KKK (see Regulation Number 6, Part A, Subpart KKK) shall apply, regardless of the date of construction of the affected facility. The operator shall comply with all applicable requirements of Section XII. 25. Point 006: This facility is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A, Subpart KKK, Standards of Performance for Onshore Natural Gas Processing Plants including, but not limited to, the following: • 40 CFR, Part 60, Subpart A— General Provisions • §60.632 Standards o (a) - Each owner or operator subject to the provisions of this subpart shall comply with the requirements of § 60.482-1 (a), (b), and (d) and 60.482-2 through 60.482-10, except as provided in § 60.633, as soon as practicable, but no later than 180 days after initial startup. o (b) - An owner or operator may elect to comply with the requirements of §60.483-1 and §60.483-2. o (d) Each owner or operator subject to the provisions of this subpart shall comply with the provisions of §60.485 except as provided in §60.633(1) of this subpart. o (e) Each owner or operator subject to the provisions of this subpart shall comply with the provisions of §§60.486 and 60.487 except as provided in §§60.633, 60.635, and 60.636 of this subpart. • §60.633 Exceptions o (a) Each owner or operator subject to the provisions of this subpart may comply with the following exceptions to the provisions of subpart VV. • o (b)(1) Each pressure relief device in gas/vapor service may be monitored quarterly and within 5 days after each pressure release to detect leaks by the methods specified in §60.485(b) except as provided in §60.632(c), paragraph (b)(4) of this section, and §60.482-4 (a) through (c) of subpart VV. • (2) If an instrument reading of 10,000 ppm or greater is measured, a leak is detected. • (3)(i) When a leak is detected, it shall be repaired as soon as practicable, but no later than 15 calendar days after it is detected, except as provided in §60.482-9. • (ii) A first attempt at repair shall be made no later than 5 calendar days after each leak is detected. o (c) Sampling connection systems are exempt from the requirements of §60.482-5. • §60.635 Recordkeeping AIRS ID: 123/9012/999 Page 8 of 17 ^`"'ti 's�, £A �.� ��,�� DCP Midstream, LP . Col %do D� partmet of Public Health and Environment Permit No. 11WE1481 ," � �. Air Pollution Control Division p Issuance 1 o (a) Each owner or operator subject to the provisions of this subpart shall comply with the requirements of paragraphs (b) and (c) of this section in addition to the requirements of§60.486. o (b) The following recordkeeping requirements shall apply to pressure relief devices subject to the requirements of§60.633(b)(1) of this subpart. • (1) When each leak is detected as specified in §60.633(b)(2), a weatherproof and readily visible identification, marked with the equipment identification number, shall be attached to the leaking equipment. The identification on the pressure relief device may be removed after it has been repaired. • (2) When each leak is detected as specified in §60.633(b)(2), the following information shall be recorded in a log and shall be kept for 2 years in a readily accessible location: • (i) The instrument and operator identification numbers and the equipment identification number. • (ii) The date the leak was detected and the dates of each attempt to repair the leak. • (iii) Repair methods applied in each attempt to repair the leak. • (iv) "Above 10,000 ppm" if the maximum instrument reading measured by the methods specified in paragraph (a) of this section after each repair attempt is 10,000 ppm or greater. • (v) "Repair delayed" and the reason for the delay if a leak is not repaired within 15 calendar days after discovery of the leak. • (vi) The signature of the owner or operator (or designate) whose decision it was that repair could not be effected without a process shutdown. • (vii) The expected date of successful repair of the leak if a leak is not repaired within 15 days. • (viii) Dates of process unit shutdowns that occur while the equipment is unrepaired. • (ix) The date of successful repair of the leak. • (x) A list of identification numbers for equipment that are designated for no detectable emissions under the provisions of §60.482-4(a). The designation of equipment subject to the provisions of §60.482-4(a) shall be signed by the owner or operator. • §60.636 Reporting Requirements o (a) Each owner or operator subject to the provisions of this subpart shall comply with the requirements of paragraphs (b) and (c) of this section in addition to the requirements of §60.487. o (b) An owner or operator shall include the following information in the initial semiannual report in addition to the information required in §60.487(b) (1)— (4): Number of pressure relief devices subject to the requirements of AIRS ID: 123/9012/999 Page 9 of 17 • DCP Midstream, LP �' ea ' Col a do p ,_.e . o Public Health and Environment Permit No. 11WE1481 Air Pollution Control Division Issuance 1 §60.633(b) except for those pressure relief devices designated for no detectable emissions under the provisions of §60.482-4(a) and those pressure relief devices complying with §60.482-4(c). o (c) An owner or operator shall include the following information in all semiannual reports in addition to the information required in §60.487(c)(2) (i) through (vi): • (1) Number of pressure relief devices for which leaks were detected as required in §60.633(b)(2) and • (2) Number of pressure relief devices for which leaks were not repaired as required in §60.633(b)(3). OPERATING & MAINTENANCE REQUIREMENTS 26. Points 001 and 005: Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 27. Point 001: A source initial compliance test shall be conducted on emissions point 001 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Volatile Organic Compounds using EPA approved methods. Benzene, Toluene, Ethylbenzene, Xylenes and n-Hexane using EPA approved methods. Hydrogen Sulfide using EPA approved methods Sulfur Oxides using EPA approved methods 28. Point 001: The owner or operator shall complete the initial annual extended sour gas analysis testing required by this permit and submit the results to the Division as part of the self-certification process. Results of the sour gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per Condition no. 8. 29. Point 001: The operator shall complete an initial sample of the inlet gas to the plant to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be submitted to the Division as part of the self-certification process and used to demonstrate compliance with condition 18. The testing required by Condition 28 may be used for this demonstration. AIRS ID: 123/9012/999 Page 10 of 17 r DCP Midstream, LP I Col �, do D p me of Public Health and Environment Permit No. 11 WE1481 Air Pollution Control Division Issuance 1 30. Point 006: Within one hundred and eighty days (180) after commencement of operation, the permittee shall complete the initial extended gas analysis of gas samples that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas analysis and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 31. Point 006: Within one hundred and eighty days (180) after commencement of operation, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 32. Point 001: The operator shall sample the inlet gas to the plant on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Onshore Natural Gas Processing: SO2 Emissions (§60.640(b)). The testing required by Condition 33 may be used for this demonstration 33. Point 001: The owner or operator shall complete an extended sour gas analysis prior to the inlet of the amine unit on an annual basis. Results of the sour gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per Condition 8. 34. Point 006: On an annual basis, the permittee shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ADDITIONAL REQUIREMENTS 35. This facility is located in an ozone non-attainment or attainment-maintenance area and subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.b., for minimization and / or control of emissions of Volatile Organic Compounds and Nitrogen Oxides. For the requested emissions, compliance with the requirements to minimize and / or control the emissions specified in this permit are determined to be RACT for this facility. Any request/s for modification of this permit for increased allowable emissions shall be accompanied by RACT analyses. 36. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: AIRS ID: 123/9012/999 Page 11 of 17 DCP Midstream, LP k' > r Coll:IC,: D p rne' of Public Health and Environment Permit No. 11WE1481 , ; • Air Pollution Control Division 4 er Issuance 1 � . � a��.� 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 any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 37. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equals or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 38. Non-attainment New Source Review requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable NSR threshold will require a full NSR review of the source as though construction had not yet commenced on the source. The source shall not exceed the NSR threshold until a NSR permit is granted. (Regulation No. 3 Part D, V.A.7) 39. MACT Subpart EEEE - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart EEEE. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 40. 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 No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 41. 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 No. 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 AIRS ID: 123/9012/999 Page 12 of 17 • DCP Midstream, LP . Col Mtl do p2rtme of Public Health and Environment Permit No. 11WE1481 eu, Air Pollution Control Division Issuance 1 To, -AL obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 42. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant 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 applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 43. 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. 44. 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 applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 45. 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. 46. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This New facility-wide permit including: One (1) amine unit, Issuance one (1) hot oil heater, one (1) regenerative heater, one (1) condensate loadout, four (4) 400-bbl condensate storage tanks, and associated fugitive emissions. AIRS ID: 123/9012/999 Page 13 of 17 DCP Midstream, LP ` j z Col m do Pp. ' e o' Public Health and Environment Permit No. 11WE1481 ' �, Air Pollution Control Division Issuance 1 /` °� ,_ Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request fora permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee 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: http://www.cdphe.state.co.us/requlations/airreqs/100102agcccommonprovisionsreq.pdf. 3) 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. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (Ib/yr) reportable? Rate (Ib/yr) Benzene 71432 A 101157 Yes 943 Toulene 108883 C 68534 Yes 646 001 Ethylbenzene 100414 C 1167 Yes 11 Xylenes 1330207 C 13175 Yes 125 n-Hexane 110543 C 11863 Yes 12 Formaldehyde 50000 A 34 No 34 002 n-Hexane 110543 C 808 No 808 Formaldehyde 50000 A 3 No 3 003 n-Hexane 110543 C 76 No 76 Benzene 71432 A 1228 Yes 61 Toulene 108883 C 3402 Yes 170 004 Ethylbenzene 100414 C 253 No 13 Xylenes 1330207 C 2571 Yes 129 n-Hexane 110543 C 6605 Yes 330 Benzene 71432 A 670 Yes 34 Toulene 108883 C 1858 Yes 93 005 Ethylbenzene 100414 C 138 No 7 Xylenes 1330207 C 1404 Yes 70 n-Hexane 110543 C 3607 Yes 180 AIRS ID: 123/9012/999 Page 14 of 17 DCP Midstream, LP Col r do D pIrtme.' of Public Health and Environment Permit No. 11WE1481 vi Air Pollution Control Division Issuance 1 ,.~ .:. .. Benzene 71432 A 210 - Yes 64 Toulene 108883 C 147 No 44 006 Xylenes 1330207 C 28 No 9 n-Hexane 110543 C 4128 Yes 1260 4) The emission levels contained in this permit are based on the following emission factors: Point 001: The emission levels contained in this permit are based on the Promax simulation model using the extended sour gas analysis representative of the natural gas processed by this unit submitted with the permit application. Emission factors are based on flash tank controlled at 100% and still vent controlled at 99%. • Points 002 and 003: CAS Pollutant Emission Factors— Uncontrolled EF Source U nco ntro Iled-Ib/mms cf NOx 50 AP-42, Section 1.4, Tables 1.4-1 CO 84 AP-42, Section 1.4, Tables 1.4-1 VOC 5.5 AP-42, Section 1.4, Tables 1.4-2 Point 004: Emission Factors - Emission Factors—Controlled Uncontrolled CAS Pollutant Source Source VOC 4.82 lb/1000 gal AP-42 0.241 lb/1000 gal AP-42 NOx 0.138 lb/mmbtu AP-42 0.138 lb/mmbtu AP-42 CO 0.5496 lb/mmbtu AP-42 0.5496 lb/mmbtu AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.0 psia M (vapor molecular weight) = 66 Ib/Ib-mol T (temperature of liquid loaded) = 512.45 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on a flare efficiency of 95%. Point 005: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source VOC 2.6322 lb/1000 gal 0.1316 lb/1000 gal Tanks 4.0.9d throughput throughput — NOx 0.138lbs/mmbtu 0.138Ib/mmbtu TNRC CO 0.5496 lbs/mmbtu 0.5496 lb/mmbtu TNRC • 71432 Benzene 0.0035 lb/1000 gal 0.0002 lb/1000 gal Extended liquids throughput throughput analysis AIRS ID: 123/9012/999 Page 15 of 17 • P.DCP Midstream, LP Col, ado D p me or Public Health and Environment Permit No. 11WE1481 Air Pollution Control Division Issuance 1 ., „,F ,, Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source 108883 0.0097 lb/1000 gal 0.0005 lb/1000 gal Extended liquids Toluene throughput throughput analysis 100414 Ethylbenzene 0.0073 lb/1000 gal 0.0004 lb/1000 gal Extended liquids throughput throughput analysis 1330207 Xylenes 0.0731 lb/1000 gal 0.0037 lb/1000 gal Extended liquids throug_hput throughput analysis 110543 n Hexane 0.1879 lb/1000 gal 0.0094 lb/1000 gal Extended liquids throughput throughput analysis Note: The controlled emissions factors for point 005 are based on the combustor control efficiency of 95%. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2297 --- 7279 --- Flanges 2062 --- 1375 --- Open-Ended Lines 0 --- 0 --- Pump Seals 0 --- 46 --- Valves 3026 --- 2378 --- Other 178 --- 43 --- VOC Content(wt%) 24.16% 100% 100% 100% *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2,4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Note: The controlled emissions factors for point 006 are based on 75% control efficiency, except for flanges and connectors which are based on 30% control efficiency. Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on 03/22/2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. AIRS ID: 123/9012/999 Page 16 of 17 DCP Midstream, LP 'h a vi Col,'�"r do D..partmet:.t of Public Health and Environment Permit No. 11WE1481 _ « V. ti �� Air Pollution Control Division Issuance 1 • ,A„.. '3 x. 6) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic minor source: VOC, HAPS NANSR Synthetic Minor Source: VOC PSD True Minor Source: CO 7) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA— Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ— Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 8) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilgaspermitting.html AIRS ID: 123/9012/999 Page 17 of 17 Hello