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Home My WebLink About20121202.tiff STAT LQ NcOLORADO John W. Hickenlooper,Governor C`,VMISSIONERS oF.��< Christopher E. Urbina, MD, MPH �0 'co< Executive Director and Chief Medical Officer tir - 1p o r (� A 1 i�i 50 Dedicated to protecting and improving the health and environment of the pe .�{� � 4300 Cherry Creek Dr.S. Laboratory Services Division RECEIVED t 1876 j Denver, Lowry Phone(303)692 2000 80246-1530 8100 Blvd. 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment May 7, 2012 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 Bear Tracker Energy, LLC. This public notice will be published in the Greeley Tribune on May 12, 2012. 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-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Attention: Ellen Evans Regards, cf- C. E ASAA41.,. Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division \h YN PJ, 5- (c1 -1 5-/C / 2012-1202 NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR HEREFORD RANCH NATURAL GAS PROCESSING FACILITY BY Bear Tracker Energy, LLC CONTENTS 1 . PUBLIC NOTICE 2. PRELIMINARY ANALYSIS 3. AIR POLLUTANT EMISSION NOTICES 4. DRAFT PERMIT PREPARED BY: DENNIS M. MYERS 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 .0V•.cozo Executive Director and Chief Medical Officer ys ' RO Dedicated to protecting and improving the health and environment of the people of Colorado * * 4300 Cherry Creek Dr. S. Laboratory Services Division .Ian * . 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 May 7, 2012, published May 12, 2012 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: Bear Tracker Energy, LLC has submitted an application to the Division for the construction of the Hereford Ranch Processing Plant to be located in Section 26, Township 12 North, Range 63 West in Weld County Colorado. The facility will consist of electric motor driven inlet compression, a 20 MMSCFD capacity molecular sieve gas dehydration system, a condensate stabilizer, a refrigeration assisted cryogenic demethanizer liquid recovery process, electric motor driven propane refrigeration system, a hot oil utility system, a 4MMSCFD TEG dehydration system, a liquid/liquid amine treating system, a natural gas liquids EG drying system, and electric motor driven residue gas compression. An emergency flare will be installed to control plant emergency shutdown events, facility pressure relief valves and inlet and residue compressor blowdowns. The amine unit process vents will be routed to a thermal oxidizer. The site is potentially a major source for the Title V Operating Permit Program if the operator did not install emission controls and accept federally enforceable emission limits in the proposed modified permit. Since the operator will accept these limits and controls, this source will be considered a synthetic minor source for the Title V Operating Permit Program. As such, this proposed draft permit is subject to public comment per Regulation 3, Part B, Section III.C.1.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: Dennis M. Myers Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD,SS-B 1 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 25-7-114.5(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. PRELIMINARY ANALYSIS DATE: May 8, 2012 APPLICANT: Bear Tracker Energy, LLC PERMIT NUMBER: 10WE2188 REVIEW ENGINEER: Dennis M. Myers, P.E. CONTROL ENGINEER: Chris Laplante PROJECT DESCRIPTION Bear Tracker Energy, LLC has submitted an application to the Division for the construction of the Hereford Ranch Processing Plant to be located in Section 26, Township 12 North, Range 63 West in Weld County Colorado. The facility will consist of electric motor driven inlet compression, a 20 MMSCFD capacity molecular sieve gas dehydration system, a condensate stabilizer, a refrigeration assisted cryogenic demethanizer liquid recovery process, electric motor driven propane refrigeration system, a hot oil utility system, a 4MMSCFD TEG dehydration system, a liquid/liquid amine treating system, a natural gas liquids EG drying system, and electric motor driven residue gas compression. An emergency flare will be installed to control plant emergency shutdown events, facility pressure relief valves and inlet and residue compressor blowdowns. The amine unit process vents will be routed to a thermal oxidizer. The site is potentially a major source for the Title V Operating Permit Program if the operator did not install emission controls and accept federally enforceable emission limits in the proposed modified permit. Since the operator will accept these limits and controls, this source will be considered a synthetic minor source for the Title V Operating Permit Program. As such, this proposed draft permit is subject to public comment per Regulation 3, Part B, Section 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. Air pollutant emissions from the proposed modification are as follows: SUMMARY OF EMISSIONS (tons/year) AIR POLLUTANT CONTROLLED POTENTIAL TO EMISSIONS EMIT Nitrogen Oxides 15.9 15.9 Carbon Monoxide 40.3 40.3 Volatile Organic 64.7 239.4 Compounds Total Hazardous Air 1.2 2.5 Pollutants Any Individual 0.2 1.2 Hazardous Air Pollutant (benzene) SOURCE IMPACT ANALYSIS The Division believes this source will not cause or contribute to a violation of national ambient air quality standards. SOURCE CLASSIFICATION This facility has been determined to be a synthetic minor source for Title V Operating Permit Program. 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O E — c o a — E tz. —m ' v w 5 U > W a e , O' d a I w I v u w v I o c P4 I w N O 0. 0 VZ T R y 1 E. m G, Q� CC O o ° o o c , o >� H c o . E m p, o '" x 0 U o 0 C v A Z co .O• ' C m . 0 s W v, O O p 0 C o O.y 0 _I " O o o' 0 C o ro o F a a. N Z > U F tic 0 LL 4 s E W Z L 0.. C v 0 W to U co Q ® v •°. o .o C O M H N •Ey' w A 2 U � N ¢ iZ i O ccu W 00o c o R.CI la CO in ra. oa) x W ,_., Q ` � R Q 1:1 Cd y � � . co a a ; "vE Mg a) = o o a, W m. d 8 v _ U3 N ce 0 - O LU cu - i 3 O or) O N o CJ 0Q• y F- _ N co Z m O 1 G+.. u cciIt OS CO .r. N c I5 OS IC V. Z V v to c, m m d Z CU O 'O eh ..7 w U z c w C.) ... E c s •+ +r I_ 0. • H d �' CD W C4 U � 'c > > 113 i GC " = d c 0) c c0 0 _ u at — Z H m E 'c CO N N T:, Q W`� r r v I ' ar .a F2 r 0 J" `� R O 6 U O� G U Ce n o E al o 0 Q U .c 0 E W O J N c '. C Ca V O a Q U ' O a.+ CJ CD< J M 0 aai E Y >� r6. U O n/ Gf G, °c° ^0 C N ` 0 a. L. 'L Q O Li.! d ,a c Cr U N o �` a) c o c a c a © z c X t,:, '' L Q ~ Tti vN a1 a) cd ce C d ` Q O1 I o a) U-1 m fn m . U m c III ° .0 o. Q V 4-. 73 E O O U ce y ,i-+ a) a., a) o O 0 ti Z .�al U b ; - o LT' O �O Q U � O a) p O '� u cn 0. U a. a W ti cd -0 co n• o. w I- 0 Z c m E co in CO _ i_ __ FT STATE OF COLORADO e COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION *1876*, TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 10WE2188 Issuance 1 DATE ISSUED: ISSUED TO: Bear Tracker Energy, LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas processing facility, known as the Hereford Ranch Processing Plant, located in the Section 26, Township 12N, Range 63W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Emergency open flame flare.(make, model, and s/n to FL 011 be provided with a normal operating rate of 12.6 MMBtu per hour, for control of emissions from plant emergency shutdowns, pressure relief valves, and compressor blowdowns. FUG 012 Equipment leaks (fugitive VOCs) from equipment/components in natural gas, natural gas liquid, and heavy oil streams. Equipment leaks (fugitive VOCs) from equipment/components FUG 013 in gaseous and liquid propane service. Propane One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: to be provided) with a design capacity of 4.0 MMscf.per day. This emissions unit is equipped TEG 016 with one (1) gas-glycol pump (make, model: to be provided) with a design capacity of 4.0 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Flash tank vapors are vented to the atmosphere. Emissions from this unit are not controlled. One (1) natural gas fired hot oil heater (Make, Model, and s/n HT5802 017 to be provided) for process heating; maximum design rated at 25 MMBtu/hour. ` AIRS ID: 123/8761 Page 1 of 20 NGEngine Version 2009-1 B> ck rgy, C olorado Department of Public Health and Environment P= , 218 Air Pollution Control Division Is- - , 1 F De Lion Equipment ID Point One (1) Diethanolamine (DEA) natural gas liquids only (liquid to liquid) sweetening system for acid gas removal with a design capacity of 142.5 gallons per minute (make, model, serial number. T¢D). This emissions unit is equipped with one (1) AMInc 018 , model,(TBD), electric amine recirculation pump with a total design'capacity of 100 gallons per minute. This system includes a natural gas liquids/amine contactor, a flash tank, and an amine regeneration reboiler heated by hot oil. All emissions from the'flash tank and amine regenerator are routed to the thermal oxidizer. IN 1 SV 019 Inlet compressor seal vent emissions IN 2 SV 020 Inlet compressor seal vent emissions IN 3 SV 021 Inlet compressor seal vent emissions INC 1 BD 022 Compressor blow down emissions routed to facility emergency flare (AIRS Point 011) INC 2 BD 023 Compressor blow down emissions routed to facility emergency flare (AIRS Point 011) INC 3 BD 024 Compressor blow down emissions routed to facility emergency flare (AIRS.Point 011) THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO 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, II.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 AIRS ID: 123/8761 Page 2 of 20 B� ck rgy, C olorado Department of Public Health and Environment P_ 218 Air Pollution Control Division Is- - : 1 :e • Re No Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III. . . 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 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) 6. The manufacturer, model number, and serial number of Points 011, 016, 017, 018, 019, 020, 021, 022, 023, and 024 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.) 7. The operator shall retain the permit final authorization letter issued by the Division after completion of self-certification, with the most current ',construction permit. This construction permit alone does not provide final;authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS ' 8. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Sect Point ion II.A.4) Monthly Limits: Pounds per Month Emission Facility AIRS Type Equipment ID Point NOx VOC CO SO2 FL 011 646 3483 Point FUG 012 4536 Point FUG 013 561 Point Propane TEG 016 373 Point ' HT5802 017 1848 107, ' , 1550 Point AMInc 018 221 1088, 1835 272 Point IN 1 SV 019 1325 Point IN 2 SV 020 1325 Point IN 3 SV 021 1325 Point INC 1 BD 022 136 Point INC 2 BD 023 136 Point INC 3 BD 024 136 Point AIRS ID: 123/8761 Page 3 of 20 B= ck: -rgy, C olorado Department of Public Health and Environment P: I ,. I 218 Air Pollution Control Division Is- 1 or u y rig' ar_ . on 1-day month. Annual Limits: Tonsper Year Emission Facility AIRS Type Equipment ID Point NO, VOC CO SO2 FL 011 3.8 20.5 Point FUG 012 26.7 Fugitive FUG Propane 013 3.3 Fugitive TEG 016 2.2 Point HT5802 017 10.8 0.6 9.1 Point AMInc 018 1.3 6.4 10.8 1.6 Point IN 1 SV 019 7.8 Fugitive IN 2 SV 020 7.8 Fugitive IN 3 SV 021 7.8 Fugitive INC 1 BD 022 0.8 Point INC 2 BD 023 0.8 Point INC 3 BD 024 0.8 Point See "Notes to Permit Holder #4 for information on emission factors and methods used to calculate limits. 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, 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 review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. Point 018: Liquid to liquid amine unit(AMInc) 9. This unit shall be equipped with a thermal oxidizer. The thermal oxidizer shall reduce uncontrolled emissions of VOC from the unit 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.) AIRS ID: 123/8761 Page 4 of 20 B r ck: -rgy, C olorado Department of Public Health and Environment P it • 218. Air Pollution Control Division Is- anc: 1 t i e r : •r 10. Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, and other operational values specified in the O&M Plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc Points 012 and 013: Equipment Leaks " ° 11. The operator shall calculate actual emissions from these emissions points based on representative actual component counts for the facility along with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. Points 022, 023, and 024: Compressor blowdown emissions 12. Compressor blowdown emissions shall be routed to the facility emergency flare (AIRS ID 011). The flare shall reduce compressor blowdown VOC emissions 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.) PROCESS LIMITATIONS AND RECORDS 13. This source shall be limited to the following maximum consumption, processing and/or operational rates as listed below. Monthly records of the actual consumption 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 109.5 9.3 FL 011 Consumption of natural gas as a fuel MMSCF MMSCF 1,460 TEG 016 Processing of natural gas MMSCF 124.0 MMSCF HT5802 017 Consumption of natural gas as a fuel 216.5 18.4 MMSCF MMSCF 74,898,000 6,361,200 AMInc 018 Processing of natural gas liquids Gallons Gallons IN 1 SV 019 0.438 0.04 Seal Vent Natural gas leakage MMSCF MMSCF IN 2 SV 020 0.438 0.04 Seal Vent Natural gas leakage MMSCF MMSCF IN 3 SV 021 0.438 0.04 Seal Vent Natural gas leakage MMSCF MMSCF INC 1 BD 022 0.831 0.07 Natural gas vented from blowdown MMSCF MMSCF INC 2 BD 023 Natural gas vented from blowdown 0.831 0.07 AIRS ID: 123/8761 Page 5 of 20 B- ck rgy, C olorado Department of Public Health and Environment P. ,. 218 Air Pollution Control Division Is- 1 • MMSCF MMSCF I 3 0.831 0.07 Natural gas vented from blowdown MMSCF MMSCF During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly limitation shall be required. 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. Point 011: Flare 14. The operator shall continuously monitor total gas volume routed to the flare on a monthly basis using a flow meter. By the end of each month, the total flow for the previous months' data shall be calculated, and a new twelve-month total shall be calculated and recorded based on the previous twelve months' data. Point 016: TEG Dehydrator. ( , °;r r 15. This unit shall be limited to the maximum lean glycol circulation rate of 4.0 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) Point 018: Liquid to liquid amine unit(AMInc1 16. This unit shall be limited to the maximum lean amine recirculation rate of 100 gallons per minute. The amine recirculation rate shall be recorded daily 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 17. 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). 18. 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.) 19. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/8761 Page 6 of 20 B> ck rgy, C olorado Department of Public Health and Environment 218 Air Pollution Control Division Is- 1 • • ., -ts 13 ive E 'ssion Leaks (FUG and FUG Propanel 20. 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(f) 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 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 AIRS ID: 123/8761 Page 7 of 20 B- ck rgy, C olorado Department of Public Health and Environment P. ' 218 Air Pollution Control Division Is- 1 men he identification on the pressure relief device may be removed a er 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 §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): • AIRS ID: 123/8761 Page 8 of 20 B- ck rgy, C olorado Department of Public Health and Environment P= 218 Air Pollution Control Division Is- - . 1 • 1 umb f pressure relief devices for which leaks were detected as require 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) Point 016: TEG Dehydrator 21. This source is subject to the TEG dehydrator area source requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: • §63.764 - General Standards o §63.764 (e)(1) -The owner or operator is exempt from the requirements of paragraph (c)(1) and (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). • §63.764 (e)(1)(i) — The actual annual average flowrate of natural gas to the glycol dehydration unit is less than 85 thousand standard cubic meters per day (3.0 MMSCF/day), as determined by the procedures specified in §63.772(b)(1) of this subpart; or • §63.764 (e)(1)(ii) — The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. • §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration o §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under§63.764(e)(1). • §63.772(b)(1) - The determination of actual flowrate of natural gas to a glycol dehydration unit shall be made using the procedures of either paragraph (b)(1)(i) or (b)(1)(ii) of this section. • §63.772(b)(1)(i) — The owner or operator shall install and operate a monitoring instrument that directly measures natural gas flowrate to the glycol dehydration unit with an accuracy of plus or minus 2 percent or better. The owner or operator shall convert annual natural gas flowrate to a daily average by dividing the annual flowrate by the number of days per year the glycol dehydration unit processed natural gas. • §63.772(b)(1)(ii) - The owner or operator shall document, to the Administrator's satisfaction, that the actual annual average AIRS ID: 123/8761 Page 9 of 20 • ck rgy, C olorado Department of Public Health and Environment P 218 Air Pollution Control Division Is- - 1 na ri -I gas flowrate to the glycol dehydration unit is less than 85 ousand standard cubic meters per day. • §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. • §63.772(b)(2)(i) — The owner or operator shall determine actual average benzene emissions using the model GRI- GLYCaIc TM , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc TM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit • and may be determined using the procedures documented in the Gas .Research Institute (GRI) report entitled "Atmospheric • Rich/Lean, Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or • §63.772(b)(2)(ii) - The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (H), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. • §63.774 - Recordkeeping Requirements o §63.774 (d)(1) - An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. • §63.774 (d)(1)(i) - The actual annual average natural gas throughput (in terms of natural gas flowrate to the glycol dehydration unit per day) as determined in accordance with §63.772(b)(1), or • §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). Point 017: Hot Oil Heater (H158021 22. 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)). AIRS ID: 123/8761 Page 10 of 20 B= ck rgy, C olorado Department of Public Health and Environment P- 218 Air Pollution Control Division Is- - 1 ly r of fu ombusted required under the.previous condition shall be main aine y he owner or operator bf 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 23. Particulate emissions shall be limited as per: Regulation 6, Part B, II.C.2. Point 018: Liquid to liquid amine unit(AMInc) 24. 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 §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 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 AIRS ID: 123/8761 Page 11 of 20 B� ck rgy, C olorado Department of Public Health and Environment P= '. 218 Air Pollution Control Division Is- - 1 I & T E R IREMENTS 25. Upon startup, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by;the pivision, in order to demonstrate compliance on an ongoing basis with the:requiremLrits jof 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.) Point 018: Liquid to liquid amine unit(AMInc) 26. The inlet liquid temperature and inlet liquid pressure shall be measured and recorded monthly. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements for Points 011: Emergency Flare 27. The owner or operator shall demonstrate compliance with Condition 18, using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section I I.A.1&4). Initial Testing Requirements for Point 012 and 013: Equipment Leaks 28. 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) that may be released as fugitive emissions. This extended gas, analysis shall be used in the compliance demonstration as required in the Emisaion 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. 29. 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. Initial Testing Requirements for Point016: TEG Dehydrator 30. The owner or operator shall complete the initial annual extended wet gas analysis testing required by this permit and submit the results to the Division as part of the self- certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) Initial Testing Requirements for Point 018: Liquid to liquid amine unit(AMInc) 31. The operator shall sample the inlet.liquid to the plant on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the liquid 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 38 may be used for this demonstration AIRS ID: 123/8761 Page 12 of 20 B= ck rgy, C olorado Department of Public Health and Environment P= +. 218 Air Pollution Control Division Is- - 1 3 h op hall plete an extended sour liquid analysis prior to the inlet oft e amine uni on a semi annual basis. Results of the sour liquids analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per Condition 8. 33. This owner or operator shall complete the initial annual sour liquid analysis testing required by this permit and submit the results to the Division as part of the self- certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) 34. A source initial compliance test shall be conducted on this emissions point 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) Sulfur Dioxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Benzene, Toluene, Ethylbenzene, Xylenes and n-Hexane using EPA approved methods. Periodic Testing Requirements for Point 016: TEG Dehydrator 35. The owner or operator shall complete an extended wet gas analysis of the plant inlet 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. Periodic Testing Requirements for Point 012 and 013: Equipment Leaks 36. 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. 37. This facility is subject to the leak detection and repair (LDAR) requirements of 40 C.F.R Part 60, Subpart KKK. Periodic Testing Requirements for Point 018: Liquid to liquid amine unit(AMInc) 38. The operator shall sample the inlet liquid to the plant on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the liquid 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 39 may be used for this demonstration AIRS ID: 123/8761 Page 13 of 20 Bz. ck rgy, C olorado Department of Public Health and Environment P= '. 218 Air Pollution Control Division Is- - :, 1 3• h o shall r;i plete an extended sour liquid analysis prior to the inlet of e amine uni on an semi annual basis. Results of the sour liquid analysis shall be used to calculate emissions of criteria pollutants per Condition 8. ADDITIONAL REQUIREMENTS 40. 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: 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 mere, 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. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 41. 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. 42. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this 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 HH. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 43. 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. AIRS ID: 123/8761 Page 14 of 20 B ck rgy, C olorado Department of Public Health and Environment Ps '. 218 Air Pollution Control Division Is- - 1 4 t s i Hy s -c,-s that final authorization has been granted, then the remainder o his con i ion 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,n 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 obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 45. 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. 46. 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. 47. 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 grouhds'set forth; ih•the Colorado Air Quality Control Act and regulations of the Air Quality'Qontrol 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. 48. 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. 49. 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: Dennis M. Myers, PE Permit Engineer AIRS ID: 123/8761 Page 15 of 20 B- ck rgy, - C olorado Department of Public Health and Environment P- +. ryI 218 Air Pollution Control Division , : Is- - , 1 err 't 3 ,4 Issuance Date ' Description Issuance 1 This Issuance 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 for a 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/regulations/airreos/100102agcccommonprovisionsreq.pdf. 3) The following emissions of reportable 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 232 Yes 171 Toluene 012 108883 C 172 No 127 Ethybenzene 100414 C 23 No 17 Xylene 1330207 C 51 No 38 n-Hexane 110543 C 1506 Yes 1109 Benzene 71432 A 1824 Yes 91 Toluene 108883 C 488 No 24 018 Ethybenzene 100414 C 21 No 1 Xylene 1330207 C 59 No 3 019, 020, Benzene 71432'' 1 A 51 Yes 51 021 each AIRS ID: 123/8761 Page 16 of 20 Bz- ck rgy, C olorado Department of Public Health and Environment P: 218 Air Pollution Control Division Is- - 1 024 Benzene 71432 A 96 Yes 5 each 011, 013, None Reportable 016, 017 4) The emission levels contained in this permit are based on the following emission factors: Point 011 Pollutant Ib/MMBtu Source/Comments Control (%) NOx 0.068 AP-42,Table 13.5-1 0.0% VOC 0.370 AP-42,Table 13.5-1 0.0% Point 012: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 733 702 249 0 Flanges 721 200 288 0 Open-ended Lines 2 0. 7 0 Pump Seals 79 0 7 0 Valves 464 334 198 0 Other* 336 274 73 0 VOC Content(wt%) 47.88% 100% 82.67% N/A *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 AIRS ID: 123/8761 Page 17 of 20 Bz,` ck rgy, C olorado Department of Public Health and Environment Pt= I. 218 Air Pollution Control Division Is- 1 •?a�r -03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 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. Control for quarterly monitoring is: 70% gas valve, 61% light liquids valve, and 45% light liquids pump. Point 013: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 19 0 6 0 Flanges 97 0 23 0 Open-ended Lines 0 0 9 0 Pump Seals 13 0 0 0 Valves 43 0 11 0 Other* 14 0 8 0 VOC Content(wt%) 100% N/A 100% N/A *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 i 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 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. Control for quarterly monitoring is: 70% gas valve, 61% light liquids valve, and 45% light liquids pump. Point 016: The emission levels for this point are based on information provided in the application and the GRI GlyCalc 4.0 model. Point 017: Pollutant lb/MMSCF Source/Comments Control (%) NOx 100 AP-42 0.0% VOC 5.5 AP-42 0.0% AIRS ID: 123/8761 Page 18 of 20 1 • B ck rgy, C olorado Department of Public Health and Environment 218 Air Pollution Control Division Is- - , 1 84 AP-42 0.0% Point 018: The emission levels for this point are based on the ProMax 3.2 model using extended sour gas analysis representative of the natural gas processed by this unit submitted with the permit application. Points 019, 020, 021: The VOC emission levels contained in this permit are based on a gas volume of 438,0000 scf/yr per point, and a VOC content of 25.22%. VOC emissions = 35,525 lb/MMSCF natural gas vented. Points 022, 023, 024: The VOC emission levels contained in this permit are based on a gas volume of 830,773 scf/yr per point, and a VOC content of 25.22%. VOC emissions = 35,533.2 lb/MMSCF natural gas vented. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notices (APEN) associated with this permit are valid for a term of five years. The five-year term for this APEN expires on October 18, 2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. • 6) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source: VOC PSD Minor Source MACT HH Area Source Requirements: Applicable MACT ZZZZ Area Source Requirements: Not Applicable 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 AIRS ID: 123/8761 Page 19 of 20 B ck rgy, C olorado Department of Public Health and Environment Pc. ,. 218 Air Pollution Control Division Is- - : ' 1 k r C 0- bpart 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/oilgaspermitfing.html AIRS ID: 123/8761 Page 20 of 20 Hello