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Home My WebLink About20141555.tiff STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk, MD,MSPH ��;°F \o,�� Executive Director and Chief Medical Officer 'Ye 1 S'�) Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr.S. Laboratory Services Division ./876. 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 www.colorado.gov/cdphe and Environment Weld County - Clerk to the Board 1150 O St PO Box 758 RECEIVED Greeley, CO 80632 May MAY 2 t 2014 l s, 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On May 18, 2014, the Air Pollution Control Division will publish a public notice for Bonanza Creek Energy Operating Company LLC— Latham 14-2 Production Facility, in the The (ircelet I rihune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health & Environment APCD-SS-B I 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary' Sources Program Air Pollution Control Division Enclosure • CC PL(MfttYpw £,e, (JM)ntLP&) 2014-1555 �t,bli� r�� 5-- 24- r-i STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH �,OF coz0� Executive Director and Chief Medical Officer '� , 90 Dedicated to protecting and improving the health and environment of the people of Colorado -"' r-L o P 9 P P +i 's& : 4300 Cherry Creek Dr.S. Laboratory Services Division 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 www.colorado.gov/cdphe and Environment Website Title: Bonanza Creek Energy Operating Company LLC—Latham 14-2 Production Facility—Weld County Released To: The Greeley Tribune On: May 15, 2014 Published: May 18, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company LLC Facility: Latham 14-2 Production Facility Oil and gas production facility SWSW Section 2, T4N, R63W Weld County The proposed project or activity is as follows: The applicant proposes to operate a new oil and gas production facility. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application,the Division's analysis, and a draft of Construction Permit 12WE3095.CP3 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission, The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Carissa Money Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-Bl Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us STATE OF COLORADO oy.cow COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT , AIR POLLUTION CONTROL DIVISION �Q i TELEPHONE:(303)692-3150 *1876• CONSTRUCTION AUCTION PERMIT PERMIT NO: 12WE3095 Issuance 3 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company, LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the Latham 14-2 Production Facility, located in the SWSW Section 2, Township 4N, Range 63W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment ID Point Description Six (6) 400 bbl and six (6) 500 bbl above ground atmospheric Tanks 001 condensate storage tanks. One (1)Arrow Engine Company, Model A-62, Serial Number 6B12D008373, natural gas-fired, naturally aspirated, 4SRB El 004 reciprocating internal combustion engine, site rated at 80 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system. This emission unit powers a pump jack. Truck 005 Truck loadout of condensate. Emissions from the loadout are Loadout not controlled. FUG 006 Fugitive VOC equipment leak emissions One (1) pneumatic pump for water transfer, rated at 600 scf/hr P-1, P-2 007 (Sandpiper, Model G1F, Serial # 2004234), and one (1) pneumatic pump for heat trace circulation, rated at 600 scf/hr (Sandpiper, Model G1F, Serial #1991657) P-3 010 One (1) pneumatic pump used for water transfer, rated at 600 scf/hr(Sandpiper, Model G1F, and serial number: 2040601) Low-pressure separator controlled by a VRU and an enclosed SEP-1 014 flare. Flare has a minimum combustion efficiency of 95%. AIRS ID: 123/9A7D Page 1 of 24 I olorl Depa en P li Health and Environment D it Pollution Control Division P-4 015 • - (1 •'"-ii a • sed f ter transfer, rated at 600 scf/hr(Sandpiper, Model G1F, and serial number: 2091564) SEP-3 016 Low-pressure separator controlled by a VRU and an enclosed flare. Flare has a minimum combustion efficiency of 95%. SEP-4 017 Low-pressure separator controlled by a VRU and an enclosed flare. Flare has a minimum combustion efficiency of 95%. Point 004: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow Engine Company A-62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Points 007, 010, and 015: A pump may be replaced with another pump in accordance with the provisions of the Alternate Operating Scenario (AOS) in this permit. 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. Points 014 through 017: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Points 006, 014 through 017: Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, I I I.F.4.) 4. Points 014, 016 and 017: Within ninety (90) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flowrate of natural gas vented from each low pressure separator. The operator shall use the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed ninety(90)days after issuance of this permit. AIRS ID: 123/9A7D Page 2 of 24 olor Depai nen f P li Health and Environment it Pollution Control Division 5. Points 006, 0 g per rash omplet I 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.) 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) Annual Limits: Facility Tons per Year Equipment AIRS Emission ID Point NOx VOC CO Type Tanks 001 --- 8.2 1.6 Point El 004 2.2 --- 3.7 Point Truck Point 005 --- 21.9 --- Loadout FUG 006 --- 14.5 --- Fugitive P-1, P-2 007 --- 3.5 2.5 Point P-3 010 --- 1.8 1.2 Point SEP-1 014 --- 7.0 1.8 Point P-4 015 --- 1.8 1.2 Point SEP-3 016 --- 7.0 1.8 Point SEP-4 017 --- 7.0 1.8 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits 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 twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month 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 permitted emission units, requiring an APEN, at this facility. AIRS ID: 123/9A7D Page 3 of 24 olor Depa en P li Health and Environment it Pollution Control Division 8. The emission .mu th e sh ated aintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit(Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment ID Point Control Device Controlled Tanks 001 Enclosed Flare VOC El 004 Non-Selective Catalytic NOx and CO Reduction P-1, P-2 007 Enclosed Flare VOC P-3 010 Enclosed Flare VOC SEP-1 014 VRU and Enclosed Flare VOC P4 015 Enclosed Flare VOC SEP-3 016 VRU and Enclosed Flare VOC SEP-4 017 VRU and Enclosed Flare VOC 9. Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended 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 10. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment ID Point Process Parameter Annual Limit Tanks 001 Condensate Throughput 214,620 BBL/yr El 004 Consumption of natural gas as a 6.3 MMscf/yr fuel Truck Loadout 005 Condensate Loaded 214,620 BBL/yr P-1, P-2 007 Natural Gas Consumed 10.6 MMSCF/yr P-3 010 Natural Gas Consumed 5.3 MMSCF/yr SEP-1 014 Natural Gas Vented from Low 9.9 MMSCF/yr Pressure Separator AIRS ID: 123/9A7D Page 4 of 24 olor Depa en if P Ii "Health and Environment .....Y •it Pollution Control Division P-4 k. r5 Ga ""dined 5.3MMSCF/yr SEP-3 016 Natural Gas Vented from Low g.g MMSCF/yr Pressure Separator SEP-4 017 Natural Gas Vented from Low 9.9 MMSCF/yr Pressure Separator The owner or operator shall calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 11. Points 014, 016 and 017: Upon installation of the flow meter required under Condition 4, the owner or operator shall continuously monitor and record the volumetric flowrate of natural gas vented from each low pressure separator using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented from each separator. The owner or operator shall use monthly throughput records to demonstrate compliance with the limits specified in Condition 10 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. Points 001, 004, 005, 007, 010, 014, 015, 016 and 017: The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 13. 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. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. &4.) 14. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 15. 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. (Reference: Regulation No. 1, Section II.A.5.) 16. Point 001: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. AIRS ID: 123/9A7D Page 5 of 24 Depa en P li Health and Environment it Pollution Control Division 17. Point 001: TDolor u t keepi onitoring, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 18. Point 001: 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. 19. Point 001: 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 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. 20. Point 005: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology (RACT) AIRS ID: 123/9A7D Page 6 of 24 olor Depa en. f P li Health and Environment it Pollution Control Division t # requirements ati u , P 1.,D.2.a tee, densate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 21. Point 005: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 21 (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 22. Point 005: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 23. This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 24. Point 006: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a semi-annual basis. The first AVO inspection must be completed within 180 days of permit issuance. ii. For each leak found in the AVO inspection, a gas detector may be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. Component leaks less than 10,000 ppm shall not require repair. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. AIRS ID: 123/9A7D Page 7 of 24 olor..i Depa en P li Health and Environment it Pollution Control Division r-fl,a4 - using f the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. OPERATING & MAINTENANCE REQUIREMENTS 25. Points 001, 004, 006, 007, 010, 014, 015, 016 and 017: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to 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 26. Point 006: Within one hundred and eighty days (180) after issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 27. Point 004: This engine may be subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 28. Point 006: On an annual basis, the owner or operator 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. AIRS ID: 123/9A7D Page 8 of 24 olor., Depa en P li 'Health and Environment �z it Pollution Control Division a ; • ALTERNATE OPE .,3�.•r� SO NA-1OS. 29. Points 007, 010 and 015: These pumps may be replaced with a like-kind pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like-kind replacement pump shall be the same make, model and capacity as authorized in this permit. 30. Points 007, 010 and 015: The owner or operator shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 31. Points 007, 010 and 015: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 32. All previous versions of this permit are cancelled upon issuance of this permit. 33. This permit replaces the following permits and/or points, which are cancelled upon issuance of this permit. Existing Existing Permit No. Emission Point New Permit No. G P01 123/9A7D/001 12W E3095 34. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. 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 AIRS ID: 123/9A7D Page 9 of 24 olor.�Depa en P li Health and Environment it Pollution Control Division d. When: -rm' .hot.?per,..•, st < : d; 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 owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 35. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) 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 Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 36. MACT Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 37. 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. 38. 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 obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 39. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. AIRS ID: 123/9A7D Page 10 of 24 �a • ,:v • e • olor. Depaen1 U P li Health and Environment ii A it Pollution Control Division rte; 40. Unless specifi•,.% ed • > _, k g .t'er,al • spe '.i it onditions 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. 41. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 42. 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. 43. 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: Carissa Money Permit Engineer Permit History Issuance Date Description Issuance 3 This Issuance Updated condensate tanks (Pt 001) emissions and throughputs, added tanks, and converted from GP01 to this permit. Increased emissions and throughput for condensate loadout (Pt 005). Increased fugitive emission limit (Pt 006). Decreased emission limit for pneumatic pumps P- 1 and P-2 (Pt 007). Increased throughput and emission limit for pneumatic pump P-3 (Pt 010). Added new equipment covered under AIRS Point 014, 015, 016 and 017. Issuance 2 10/9/2013 Addition of pneumatic pump (Pt 010). AIRS ID: 123/9A7D Page 11 of 24 olor Depa en P li ealth and Environment it Pollution Control Division Issuance 1 13/ Iss anz k Energy Operating Company LLC AIRS ID: 123/9A7D Page 12 of 24 1 p S olor De a ', en of P ' li Health and Environment `s 'v it Pollution Control Division k Notes to Permit Holder a ime oft e an -. `" 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions • Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s)operate at the permitted limitations. Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission Rate emissions Emission Point (Ib/yr) reportable? Rate(Ib/yr) Benzene 71432 A 2,052 Yes 103 Toluene 108883 C 1,464 Yes 73 001 Xylenes 1330207 C 314 Yes 16 n-Hexane 110543 C 12,115 Yes 606 2,2,4-trimethyl 540841 C 550 Yes 27 pentane Formaldehyde 5000 A 139 No 139 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 004 Acrolein 107028 A 15 No 15 Benzene 71432 A 9 No 9 1,3-Butadiene 106990 A 4 No 4 Toluene 108883 C 3 No 3 n-Hexane 110543 C 4,085 Yes 4,085 Benzene 71432 A 775 Yes 775 005 Toluene 108883 C 2,184 Yes 2,184 Ethylbenzene 100414 C 383 Yes 383 Xylenes 1330207 C 1,648 Yes 1,648 AIRS ID: 123/9A7D Page 13 of 24 olor Depa en P li it PollutionHealthand Control DivisionEnvironment 2,2,4-trig+s§. -, 41 8 Yes 568 pentane Benzene 71432 A 255 Yes 255 Toluene 108883 C 650 Yes 650 006 Ethylbenzene 100414 C 116 No 116 Xylenes 1330207 C 484 Yes 484 n-Hexane 110543 C 1,324 Yes 1,324 Benzene 71432 A 283 Yes 14 Toluene 108883 C 249 No 12 007 Ethylbenzene 100414 C 31 No 2 Xylenes 1330207 C 105 No 5 n-Hexane 110543 C 1,678 Yes 84 Benzene 71432 A 142 No 7 Toluene 108883 C 124 No 6 010 Ethylbenzene 100414 C 16 No 1 Xylenes 1330207 C 53 No 3 n-Hexane 110543 C 839 Yes 42 Benzene 71432 A 1,581 Yes 40 Toluene 108883 C 1,363 Yes 34 014 Ethylbenzene 100414 C 172 No 4 Xylenes 1330207 C 458 Yes 11 n-Hexane 110543 C 9,430 Yes 236 Benzene 71432 A 142 No 7 Toluene 108883 C 124 No 6 015 Ethylbenzene 100414 C 16 No 1 Xylenes 1330207 C 53 No 3 n-Hexane 110543 C 839 Yes 42 Benzene 71432 A 1,581 Yes 40 Toluene 108883 C 1,363 Yes 34 016 Ethylbenzene 100414 C 172 No 4 Xylenes 1330207 C 458 Yes 11 n-Hexane 110543 C 9,430 Yes 236 Benzene 71432 A 1,581 Yes 40 • 017 Toluene 108883 C 1,363 Yes 34 Ethylbenzene 100414 C 172 No 4 AIRS ID: 123/9A7D Page 14 of 24 s olor tDepa ment8f P lic`Health and Environment it Pollution Control Division s Xylem 133020 :'-C n 45S Yes 11 n-Hexane 110543 C 9,430 Yes 236 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput NOx 0.068 lb/MMBtu 0.068 Ib/MMBtu AP-42, Table 13.5-1 CO 0.370 lb/MMBtu 0.370 lb/MMBtu AP-42, Table 13.5-1 VOC 1.5224 0.0761 Source 110543 n-Hexane 0.0564 0.0028 Source 71432 Benzene 0.0096 0.0005 Source 108883 Toluene 0.0068 0.0003 Source 1330207 Xylene 0.0015 0.0001 Source 540841 2,2,4 0.0026 0.0001 Source trimethylpentane Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. Point 004: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.9197 14.7000 0.7447 2.793 CO 1.5465 5.8000 1.2799 4.8000 VOC 0.0107 0.0400 0.0107 0.0400 5000 Formaldehyde 0.021 0.0900 0.021 0.0900 67561 Methanol 0.0031 0.0115 0.0031 0.0115 75070 Acetaldehyde 0.0028 0.0105 0.0028 0.0105 107028 Acrolein 0.0026 0.0099 0.0026 0.0099 71432 Benzene 0.0016 0.0059 0.0016 0.0059 106990 1,3-Butadiene 0.0007 0.0025 0.0007 0.0025 108883 Toluene 0.0006 0.0021 0.0006 0.0021 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8268 Btu/hp-hr, a site- rated horsepower value of 80, and a fuel heat value of 918 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Spec Sheet Manufacturer Spec Sheet CO Manufacturer Spec Sheet Manufacturer Spec Sheet VOC Manufacturer Spec Sheet No Control 5000 Formaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control AIRS ID: 123/9A7D Page 15 of 24 olor Depa en f P Ii Health and Environment it Pollution Control Division CAS II e Controlled EF Source Natural Gas 71432 Benzene AP-42;Table 3.2-3 (7/2000); No Control Natural Gas _ 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3(7/2000); No Control Natural Gas Point 005: Emission Factors-Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.205 AP-42 110543 n-Hexane 0.0190 AP-42 71432 Benzene 0.0036 AP-42 108883 Toluene 0.0102 AP-42 100414 Ethylbenzene 0.0018 AP-42 1330207 Xylenes 0.0077 AP-42 540841 2,2,4-trimethylpentane 0.0026 AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95)using the following values: L= 12.46*S*P*M/T S=0.6(Submerged loading: dedicated normal service) P(true vapor pressure)=5.02 psia M (vapor molecular weight) =68 Ib/Ib-mol T(temperature of liquid loaded)=524 R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the liquids by the VOC emission factor. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2067 0 646 505 Flanges 187 0 411 216 Open-ended Lines 105 0 44 15 Pump Seals 0 0 0 0 Valves 349 0 164 92 Other" 74 0 0 8 VOC Content (wt. 0.2307 N/A 0.9962 1.0000 fraction) Benzene Content (wt. 0.0005 N/A 0.0177 0.0012 fraction) Toluene Content (wt. 0.0004 N/A 0.0497 0.0003 fraction) Ethylbenzene (wt. 0.0001 N/A 0.0087 0.0001 fraction) AIRS ID: 123/9A7D Page 16 of 24 •olor.. . Depa -nen cf P •li Health and Environment it Pollution Control Division Xylenes Conten r` •.4 r0 / _, 1.0375 0.0001 fraction) n-hexane Content (wt. 0.0027 N/A 0.0930 0.0001 fraction) "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 N/A , 2.1E-04 1.1E-04 Flanges 3.9E-04 N/A 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 N/A 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 N/A 2.5E-03 9.8E-05 Other 8.8E-03 N/A 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 and liquids analyses. Points 007, 010 and 015: Emission Emission Factors- Factors - AIRS Uncontrolled Controlled Point CAS# Pollutant Ib/MMscf vented Ib/MMscf vented Source VOC 13,480 674 All emission factors NO, 0.068 Ib/MMBTU are based on the stated consumption CO 0.37 lb/MMBTU and the average of sales gas analysis 007, 110543 n-Hexane 159.626 7.9813 from Latham 14- 010 and 71432 Benzene 11-2HZ dated 26.930 1.3465 2/21/2013, Latham 015 14-2 dated 108883 Toluene 23.663 1.1832 2/21/2013 and Latham 44, 41- 100414 Ethylbenzene 2.988 0.1494 2HNB dated 9/5/2013 1330207 Xylenes 9.991 0.4996 The displacement equation can found in "EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10-Displacement Equation (10.4-3)." Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,283 BTU/scf was used for calculations. AIRS ID: 123/9A7D Page 17 of 24 oloR ? FtI 'ohut0n Dep Health and Environment D Control Division Points 014,016 an Weight Emission CAS# Pollutant Fraction of Factors Gas(%) Uncontrolled Source NOx 0.068 AP-42, Table 13.5-1 ___ lb/MMBtu CO -- 0.37 lb/MMBtu AP-42,Table 13.5-1 VOC 60.9% 56,245.9 Engineering lb/mmscf Calculation PM10 --- 40 ug/I AP-42,Table 13.5-1 SOx 0.00036 0.002 gr/scf ___ lb/MMBtu 71432 Benzene 0.17% 159.54 Engineering lb/mmscf Calculation 108883 Toluene 0.15% 137.62 Engineering lb/mmscf Calculation 100414 Ethylbenzene 0.02% 17.368 Engineering lb/mmscf Calculation 1330207 Xylenes 0.05% 46.222 Engineering lb/mmscf Calculation 110543 n-hexane 1.03% 951.85 Engineering lb/mmscf Calculation Note: The uncontrolled VOC and HAP emissions were calculated using a gas sample collected 9/5/2013 of the flash gas from the low pressure separator to estimate the VOC and HAP content of the stream and a Promax model to estimate stream flow. Actual controlled VOC and HAP emissions shall be calculated based on actual VRU operating time, a control efficiency of 100% during VRU uptime, and a flare control efficiency of 95% during VRU downtime. Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HEN of 2,009 BTU/scf was used for calculations 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Point 004:This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting—effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf AIRS ID: 123/9A7D Page 18 of 24 , A olorai,• ;Depar nen Iic2Health and Environment tj. # it Pollution Control Division 8) Point 004: This englq spec 0 rt • ZZZZat: tional Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting - effective October 19, 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/rice/fr20au10.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: NOx, CO, VOC, HAP NANSR Synthetic Minor Source of: NOx and VOC MACT ZZZZ Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: huff, tr.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 777Z—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX 11) 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: www_colorado.qov/cdphe/oilgaspermits AIRS ID: 123/9A7D Page 19 of 24 Di Depa en f P li Health and Environment it Pollution Control Division :rc1, ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9A7D Page 20 of 24 olor DepaI;nen, df P tic Health and Environment ¶air Pollution Control Division 2.1.2 The owner or o 4,14 y a epl tit xisting,.1 t pressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer)as found on the Division's web site at: http://www.colorado.qov/cs/Satellite/CDPHE-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time)emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9A7D Page 21 of 24 olor Depa en P li Health and Environment it Pollution Control Division For comparison with a I' a er ' (Ib/ ), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B§ II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment,except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO:The emission limitations in NSPS JJJJ NOX:The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. • Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9A7D Page 22 of 24 t olor Depa en P li Health and Environment it Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine(RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9A7D Page 23 of 24 olor Depa en P li Health and Environment it Pollution Control Division requirements for the e incl in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review.The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. • AIRS ID: 123/9A7D Page 24 of 24 Division Information Engineer: Carissa Money Control Engineer: Chris Laplante Review Date: 02/20/2014 Application Date: 10/18/2013 Facility Identifiers Permit No. 12W E3095 AIRS County& 123 Weld Facility it 9A75 Facility Type: exploration and production facility ❑� Located in the 8-hour non-attainment area? Q True Minor @ Synthetic Minor for: r' VOC F N0x 7 CO Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC • Source Name: Latham 14-2 Production Facility Source Location: SWSW Section 2, Township 4N, Range 63W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company, LLC Mailing Address 2: 410 17th Street, Suite 1500 Address r State Zip: Denver, CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pyoung@bonanzacrk.com 'Section 02: Requested Action Self Certification Required? Yes for new points Issuance Number: 3 Source Description: Natural exploration and production facility known as the Latham 14-2 Production Facility, located in the SWSW Section 2 Township 4N. Range 63W, Weld County. Colorado. Point Name Type Control Permit Action Increase number of tanks,throughput and 001 Tanks Condensate Tanks Flare emissions.Convert from GP01 to facility wide permit 005 Truck Loadout None Loadout Increase throughput and emissions 006 FUG Fugitives None Increase emission limit and comp counts 007 P-1, P-2 Pump Flare Decrease emissions based on gas sample 010 P-3 Pump Flare Increase throughput and emissions 014 SEP-1 Separator Flare Flare New Point.Control includes VRU and flare 015 P-4 Pump Flare New point 016 SEP-3 Separator Flare Flare New Point.Control includes VRU and flare 017 SEP-4 Separator Flare Flare New Point.Control includes VRU and flare 001 Six (6)400 bbl and six (6) 500 bbl above ground atmospheric condensate storage tank Emissions Calculations Pollutant E.F. Source Controlled EFI VOC 1.5224 lb/bbl E&P TANK 0.0761 Benzene 0.0096 lb/bbl E&P TANK 0.0005 n-Hexane 0.0564 lb/bbl E&P TANK 0.0028 Toluene 0.0068 lb/bbl E&P TANK 0.0003 Xylenes 0.0015 lb/bbl E&P TANK 0.0001 224-TMP 0.0026 lb/bbl E&P TANK 0.0001 Requsted Throughput 214620 bbl Control O No Control ®Flare Pollutant Uncontrolled Emissions Controlled Emissions VOC 163.369 tpy 8.2 tpy Benzene 2052 lb/yr 103 lb/yr n-Hexane 12115 lb/yr 606 lb/yr Toluene 1464 lb/yr 73 lb/yr Xylenes 314 lb/yr 16 lb/yr 224-TMP 550 lb/yr 27 lb/yr Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II.A and B of this regulation. Section iliA.5 S r ,.,,es:, I *ur k of r,., c L. i .,hen r .U., G3 s,.. No nr ()poi a.7 of ee srn ike .. s hoICC „ ,,. ne f N tll1 C0111:)1(`*()") Of l i,G `Sf . IOA .ISI] BI o_ 1,;), 't the n; a..r III.,ii. , . 6,.050. Or I. fora ,,., ,,.r�r', n:7 y;�ti �a more loan SIX T' 0Ut00 In 3 / xly(rn n Regulation 2—Odor Section I.A-No person,wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7)or more volumes of odor free air. Regulation 6-New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. Is this source greater than 19,800 gallons(471 bbl)?Six of the tanks are greater than 471 bbl, six are not Is this source subject to NSPS Kb? N.e 12 W E3095.CP3 123/9A7D The 400 bbl tanks are not subject because the capacity is less than the minimum threshold. The 500 bbl tanks are not subject since they are located at the wellhead site. store condensate.and are prior to custody transfer (60.110b(d)(4)). Regulation 7—Volatile Organic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is subject to the emission control requirements for condensate tanks since it is located in an attainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS .. Applicant is subject since actual uncontrolled emissions are greater than 20 tpy of VOC. 12WE3095.CP3 123/9A7D 005 Truck Condensate Loadout Cell References Pollutant Uncontrolh AP-42:Chapter 5,2 VOC D28 Equation 1 Nox L=12.46*S"P"M/T CO L=loading losses in lb per 1000 gallons loaded Benzene D38 S=Saturation Factor n-Hexane D39 P=true vapor pressure of liquid loaded[psia] Throughpu D25 Calculations M=molecular weight of vapors[lb/lb-mole] T=temperature of bulk liquid loaded[deg.R] 1 degree Fahrenheit=460.67 degree Rankine 0.6 Submerged loading:dedicated normal service P 5.02 psia based on average RVP of 7.2 from 3 stable oil samples,and AP42 Figure 7.1-13a for crude oil M 68 lb/lb-mole based on AP42 Table 7.1-2 for gasoline RVP 7 T 524 deg.R L 4.87 lb/10^3 gal 2.05E-01 lb/bbl Annual requested Throughput 214620 BBL/yr 9014040 gal/yr Annual requested VOC emissions 43901 lb/yr 21.95 tpy Regulatory Considerations This facility is not concisdered a terminal(in Reg.7)because it does not distribute gasoline This facility is not considered a bulk plant(in Peg.7)because it does not distribute gasoline. NCRPs Emissions Emission Factors Component Mass Frac. lb/yr tpy Notes lb/bbl lb/1000gal Benzene 0.017659 775 0.39 �, 0.0036 0.0860 n-hexane 0.093055 4085 2.04 r „�,I, .. 0.0190 0.4532 Toluene 0.049757 2184 1 09 , n ,, 1� r, ys: ii t. 0.0102 0.2423 Ethylbenzene 0.008717 383 019 I 0.0018 0.0425 Xylene 0.037536 1648 0 82 ,-1 r r 0.0077 0.1828 224-TMP 0.012932 568 028 - i. . .il 0.0026 0.0630 12WE3095.CP3 E3095.CP3 123/9A7D 0 Q eraOa ,0a " OOm ^ "e. = 000000000gi 8a FA- m n n n .. ... 3 g00200 : 00 - :g0 OOOOOOo . OO “4 s24" sc.m m „ n n . OOOOOOOO 5 E5 r m fr 3 o o *, 4 o o O O o e o o e i a * E U X i N ":$ u on .+ o n g o 000a oo di e3 0 f 15 • ja0ocnoo ' m0 0} OSn CI: V_m a n 0 0 0 0 0 0 0 ' E $ _ 5. wA O 0a .. O O 0 0 0 0 0 0 0 0 4a m d - O a ° omo m OOOOOO e E s- 0z 3 F 2t„ fr-., O O m 0000000000 ,4 0 $ F Ov. mS -� 0 .. .. n e OOOOn .. O m c A $ li o' 00evo e ;, ,-4. 000000n .. 0 Dpi m3 00000 _ 3 0 3 XOOOO .. 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O .9 a E 3 E f i E 9 2 m z Z, A s� E 9'4 EP — — c ? $— t — c :aa Y _ _ u 0 W o a ..0 `o 'n ?, --.7 %. 6 § 5 z O. y u 0 p is > .tsy H H g 3 K ,I _ N m 6 o 1 c_ _ c " z 3 ¢ .. a CC_ _ = wC3 _ _ m0f 9 2 & rc 2 z` One (1) pneumatic pump for water transfer. rated at 600 scf/hr (Sandpiper. Model G1 F. Serial # 2004234). and one (1) pneumatic pump for heat trace 007 circulation, rated at 600 scf/hr (Sandpiper, Model G1F, Serial #1991657) Section 04: Pump Information Manufactur Sandpiper Model Number: G1F Serial Pump Number: 2004234 and 1991657 Information Pump capacity 9.1 gallons per minute pumped natural gas 1200 scf/hour used consumptio Control O Uncontrolled ®Flare Section 05: Emission Calculations Emission Calculation Method • EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4- 3) Ex=Q* MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas* MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Q 1200 scf/hr MW 22.1 Ib/Ib-mol Hours of Op. 8760 hours/yr Requested Throughput 10.512 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy nitrogen 0.573333333 28 0.0073 nitrogen 0.508 4452.576 2.226 CO2 2.12 44 0.0422 nitrogen 2.953 25872.279 12.936 methane 75.0425 16.04 0.5447 methane 38.111 333854.935 166.927 ethane 12.8389 30.07 0.1747 ethane 12.224 107079.759 53.540 propane 6.289333333 44.09 0.1255 propane 8.780 76911.424 38.456 isobutane 0.591033333 58.12 0.0155 isobutane 1.088 9527.605 4.764 n-butane 1.5805 58.12 0.0416 n-butane 2.908 25478.054 12.739 isopentane 0.256566667 72.15 0.0084 isopentane 0.586 5134.317 2.567 n-pentane 0.316633333 72.15 0.0103 n-pentane 0.723 6336.349 3.168 cyclopentane 0.022966667 72.15 0.0007 n-pentane 0.052 459.600 0.230 n-hexane 0.0702 86.18 0.0027 n-hexane 0.192 1677.991 0.839 12WE3095.CP3 123/9A7D cyclohexane 0.019533333 84.18 0.0007 cyclohexane 0.052 456.070 0.228 Other hexanes 0.1164 86.18 0.0045 Other hexanes 0.318 2782.311 1,391 heptanes 0.0587 100.21 0.0027 heptanes 0.186 1631.531 0.816 methylcyclohexa 0.017166667 98.19 0.0008 methylcyclohe 0.053 467.519 0.234 224-TMP 6.66667E-05 114.22 0.0000 224-TMP 0.000 2.112 0.001 Benzene 0.013066667 78.11 0.0005 Benzene 0.032 283.085 0.142 Toluene 0.009733333 92.14 0.0004 Toluene 0.028 248.746 0.124 Ethylbenzene 0.001066667 106.17 0.0001 Ethylbenzene 0.004 31.411 0.016 Xylenes 0.003566667 106.17 0.0002 Xylenes 0.012 105.029 0.053 C8+Heavies 00417 879.83612 0.0166 C8+Heavies 1.162 10176.161 5,088 Mass Fraction VOC: 0.2312 Total 70.855 Heating Value I 1263 BTU/scf Combustion emission factor source: AP-42:Chapter 13.5 • 0.07 I lb NOX/MMBtu 0.37 I lb CO/MMBtu • Notes Mole%,MW.and mass fractions based on average of three extended sales gas analysis for Latham 14-11-2HZ(collected 2/21/2013).Latham Emissions Summary U 0.5 tpy NOX ncontrolle d/PTE 2.5 tpy CO 70.9 tpy VOC Controlled 3.5 tpy VOC Scenario A Controlled CAS# Total(lb/yr) Bin Reportable Total n-hexane 110543 1678.0 C Yes 84 224-TMP 540841 2.1 C No 0 Benzene 71432 283.1 A Yes 14 Toluene 108883 248.7 C No 12 E-Benzene 100414 31.4 C No 2 Xylenes 1330207 105.0 C No 5 Resultant Emission Factors Controlled VOC 13480.719 lb/MMscf natural gas used 674.04 lb/MMscf Benzene 26.930 lb/MMscf natural gas used 1.3465 n-hexane 159.626 lb/MMscf natural gas used 7.9813 Toluene 23.663 lb/MMscf natural gas used 1.1832 E-Benzene 2.988 lb/MMscf natural gas used 0.1494 Xylenes 9.991 lb/MMscf natural gas used 0.4996 224-TMP 0.201 lb/MMscf natural gas used 0.0100 12WE3095.CP3 123/9A7D One (1) pneumatic pump used for water transfer, rated at 600 scrihr 010 (Sandpiper, Model G1F, and serial number: 2040601) Section 04: Pump Information Manufactur Sandpiper Model Number: G1F Serial Pump Number: 2040601 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control O Uncontrolled ®Flare Section 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4- 3) Ex=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas* MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Q 600 scf/hr MW 22.1 I b/Ib-mol Hours of Op. 8760 hours/yr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy nitrogen 0.573333333 28 0.0073 nitrogen 0.254 2226.288 1.113 CO2 2.12 44 0.0422 nitrogen 1.477 12936.139 6.468 methane 75.0425 16.04 0.5447 methane 19.056 166927.467 83.464 ethane 12.8389 30.07 0.1747 ethane 6.112 53539.880 26.770 propane 6.289333333 44.09 0.1255 propane 4.390 38455.712 19.228 isobutane 0.591033333 58.12 0.0155 isobutane 0.544 4763.802 2.382 n-butane 1.5805 58.12 0.0416 n-butane 1.454 12739,027 6.370 isopentane 0.256566667 72.15 0.0084 isopentane 0.293 2567.159 1.284 n-pentane 0.316633333 72.15 0,0103 n-pentane 0.362 3168.175 1.584 cyclopentane 0.022966667 72.15 0.0007 n-pentane 0,026 229.800 0.115 n-hexane 0.0702 86.18 0.0027 n-hexane 0.096 838.996 0.419 12WE3095.CP3 123/9A7D cyclohexane 0.019533333 84.18 0.0007 cyclohexane 0.026 228.035 0.114 Other hexanes 0.1164 86.18 0.0045 Other hexanes 0.159 1391.155 0.696 heptanes 0.0587 100.21 0.0027 heptanes 0.093 815.765 0.408 methylcyclohexa 0.017166667 98.19 0.0008 methylcyclohe 0.027 233.760 0.117 224-TMP 6.66667E-05 114.22 0.0000 224-TMP 0.000 1.056 0.001 Benzene 0.013066667 78.11 0.0005 Benzene 0.016 141.543 0.071 Toluene 0.009733333 92.14 0.0004 Toluene 0.014 124.373 0.062 Ethylbenzene 0.001066667 106.17 0.0001 Ethylbenzene 0.002 15.705 0.008 Xylenes 0.003566667 106.17 0.0002 Xylenes 0.006 52.515 0.026 C8+Heavies 0.0417 879.83612 0.0166 C8+ Heavies 0.581 5088.081 2.544 Mass Fraction VOC: 0.2312 Total 35.427 Heating Value I 1283 BTU/scf Combustion emission factor source: AP-42:Chapter 13.5 0.07 I lb NOX/MMBtu 0.37 I lb CO/MMBtu Notes Mole 1O,MW,and mass fractions based on average of three extended sales gas analysis for Latham 14-11-2HZ(collected 2/21/2013).Latham Emissions Summary Uncontrolle tpy NOX ncontrolle d/PTE 1.25 tpy CO 35.4 tpy VOC Controlled 1.8 tpy VOC Scenario A Controlled CAB# Total (lb/yr) Bin Reportable Total n-hexane 110543 839.0 C No 42 224-TMP 540841 1.1 C No 0 Benzene 71432 141.5 A Yes 7 Toluene 108883 124.4 C No 6 E-Benzene 100414 15.7 C No 1 Xylenes 1330207 52.5 C No 3 Resultant Emission Factors Controlled VOC 13480.719 lb/MMscf natural gas used 674.04 lb/mmscf Benzene 26.930 lb/MMscf natural gas used 1.3465 n-hexane 159.626 lb/MMscf natural gas used 7.9813 Toluene 23.663 lb/MMscf natural gas used 1.1832 E-Benzene 2.988 lb/MMscf natural gas used 0.1494 Xylenes 9.991 lb/MMscf natural gas used 0.4996 224-TMP 0.201 lb/MMscf natural gas used 0.0100 12WE3095.CP3 123/9A7D Low-pressure sc parole r con troll ed by a VUU aro an nun need f rue dunop VI U rnwntime,VRU'as a mo niuni nneiiiiiunal 014 time of 5(1/r,and flare has a minimum somb,s,,on e`rcciency o1 9u%. Equipment Description This source vents natural gas from: a low pressure separator located at the well head Emissions from this source are: routed to a flare 'during VRU downtime Natural gas venting from a low pressure separator located at the well head.Emissions from this source are routed to a flare. emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=O'MW*Xx/C Ex=emissions of pollutant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(0) 9.91 MMscf/yr 1131.0 scf/hr 0.84 MMscf/mo MW 35.000 Ib/b-mol 0.027 MMscf/d mole% MW Ibx/Ibmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 2.17 44.01 0.955 0.027 CO2 2.8 24965 12.48 N2 0.07 28.013 0.020 0.001 N2 0.1 513 0.26 methane 31.793 16.041 5.100 0.146 methane 15.2 133319 66.66 ethane 25.4362 30.063 7.647 0.218 ethane 22.8 199900 99.95 propane 24.4402 44.092 10.7762 0.308 propane 32.2 281703 140.85 isobutane 2.7114 58.118 1.5758 0.045 isobutane 4.7 41194 20.60 n-butane 7.8882 58.118 4.5845 0.131 n-butane 13.7 119844 59.92 isopentane 1.4442 72.114 1.0415 0.030 isopentane 3.1 27225 13.61 n-pentane 1.8301 72.114 1.3198 0.038 n-pentane 3.9 34500 17.25 cyclopentane 0.1326 70.13 0.0930 0.003 cycbpentane 0.3 2431 1.22 n-Hexane 0.4186 86.18 0.3607 0.0103 n-Hexane 1.1 9430 4.72 cyclohexane 0.1165 84.16 0.0980 0.003 ,cyclohexane 0.3 2563 1.28 Other hexanes 0.6804 86.18 0.5864 0.017 Other hexanes 1.7 15328 7.66 heptanes 0.3533 100.21 0.3540 0.010 heptanes 1.1 9255 4.63 methylcyclohexane 00979 98.19 0.0961 0.003 methylcyclohexane 0.3 2513 1.26 224-IMP 0 0003 114.23 0.0003 0.000 224-TMP 0.0 9 0.00 Benzene 00774 78.12 0.0605 0.0017 Benzene 0.2 1581 0.79 Toluene 0.0566 92.15 0.0522 0.0015 Toluene 0.2 1363 0.68 Ethylbenzene 0.0062 106.17 0.0066 0.0002 Ethylbenzene 0.0 172 0.09 Xylenes 0.0165 106.17 0.0175 0.0005 Xylenes 0.1 458 0.23 08+Heavies 0.258 114000 0.2941 0.0084 C8+Heavies 0.9 7689 3.84 VOC mass fraction: 0.6091 Total VOC Emissions(Uncontrolled) 278.63 35.039 Total VOC Emissions(Controlled) 7.0 Notes monthly limit assuming 95%control(lb/mo.) 1183.2 Mole%and MW are based on sample results of flash gas to VRU collected 9/5/2013 from Latharn 44 Flowrate is based on Promax run.Emissions are based on 8760 hours of operation per year. I calculated the average MW of CB+based on the average MW on the analysis for the gas to be 99 Source used 114 which slightly increased emissions by 0.51pc Flaring Information Equipment Description The low pressure separator is controlled by a VRU with 50%optima.When the VRU is down,the low pressure separator gas is routed to a flare. Manufacturer Leed Model L30-0010 48" Serial Number 21236,21237,20950,21235,21244,20927,HOC-48 SN 17987&17986 Gas Heating Value 2009 Btu/scf Throughput 9952.14402 MMBtu/yr Throughput is based on 50%of total low pressure separator gas volume when VRU is d. Combustion emission factor source: AP-42:Chapter 13.5 I 0.07 I lb NOX/MMBtu I 0.37 I lb CO/MMBtu 12WE309S.CP3 123/9A70 0 34 ( tpy NOX 1.84 1 tpy CO Emissions Summary 0.3 tpy NOX Uncontrolled/PTE 1.8 tpy CO 278.6 tpy VOC Controlled 7.0 tpy VOC Controlled incluCes VRU and fare Uncontrolled Scenario A Controlled Total Total(Ib/yr) Bin Reportable? (lb/yr) Benzene 1551 A Yes 40 Toluene 1363 C Yes 34 hthybenzene 172 C No 4 Xy:enes 458 C Yes 11 n-hexane 9430 C Yes 236 224-TMP 9 C No 0.2 Regulatory Applicability A CC Re ulation 1 This source is sobjoct to the opacity requirements for flares in Section Il.A.5:'No owner or operator of a 429C Regulation Z Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the _44CC Regulation 33 Is public comment Public Comment Required required? Emission Factors for Permit Uncontrolled NOX 68.306 lb/MMscf natural gas vented CO 371.665 lb/MMscf natural gas vented VOC 56245.9 lb/MMscf natural gas vented Benzene 159.5379 lb/MMscf natural gas vented Toluene 137.6172 lb/MMscf natural gas vented Ethylbenzene 17.3682 lb/MMscf natural gas vented Xylenes 46.2218 lb/MMscf natural gas vented n-Hexane 951.8456 lb/MMscf natural gas vented 224-IMP 0.9042 lb/MMscf natural gas vented Controlled-based on 50%downtime fQEVBsJ and 95%control of flare during VRU downtime NOX 68.306 lb/MMscf natural gas vented CO 371.665 lb/MMscf natural gas vented VOC 1406.1470 lb/MMscf natural gas vented Benzene 3.988 lb/MMscf natural gas vented Toluene 3.440 lb/MMscf natural gas vented Ethylbenzene 0.434 lb/MMscf natural gas vented Xylenes 1.156 Ib/MMscf natural gas vented n-Hexane 23.796 lb/MMscf natural gas vented 224-TMP 0.023 lb/MMscf natural gas vented 12WE3095 C''3 123/9A7D One (1) pneumatic pump used for water transfer, rated at 600 scFhr 015 (Sandpiper, Model C1F, and serial number: 2091564) Section 04: Pump Information Manufactur Sandpiper Model Number: G1F Serial Pump Number: 2091564 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control O Uncontrolled ®Flare Section 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4- 3) Ex=Q* MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=5G of gas* MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Q 600 scf/hr MW 22.1 Ib/Ib-mol Hours of Op. 8760 hours/yr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy nitrogen 0.573333333 28 0.0073 nitrogen 0.254 2226.288 1.113 CO2 2.12 44 0.0422 nitrogen 1.477 12936.139 6.468 methane 75.0425 16.04 0.5447 methane 19.056 166927.467 83.464 • ethane 12.8389 30.07 0.1747 ethane 6.112 53539.880 26.770 propane 6.289333333 44.09 0.1255 propane 4.390 38455.712 19.228 isobutane 0.591033333 58.12 0.0155 isobutane 0.544 4763.802 2.382 n-butane 1.5805 58.12 0.0416 n-butane 1.454 12739.027 6.370 isopentane 0.256566667 72.15 0.0084 isopentane 0.293 2567.159 1.284 n-pentane 0.316633333 72.15 0.0103 n-pentane 0.362 3168.175 1.584 cyclopentane 0.022966667 72.15 0.0007 n-pentane 0.026 229.800 0.115 n-hexane 0.0702 86.18 0.0027 n-hexane 0.096 838.996 0.419 12WE3095.CP3 123/9A7D cyclohexane 0019533333 84.18 0.0007 cyclohexane 0.026 228.035 0.114 Other hexanes O1164 86.18 0.0045 Other hexane=- 0.159 1391.155 0.696 heptanes 0.0587 100.21 0.0027 heptanes 0.093 815.765 0.408 methylcyclohexa 0017166667 98.19 0.0008 methylcyclohe 0.027 233.760 0.117 224-TMP 6.66667E-05 114.22 0.0000 224-TMP 0.000 1.056 0.001 Benzene 0.013066667 78.11 0.0005 Benzene 0.016 141.543 0.071 Toluene 0.009733333 92.14 0.0004 Toluene 0.014 124.373 0.062 Ethylbenzene 0.001066667 106.17 0.0001 Ethylbenzene 0.002 15.705 0.008 Xylenes 0.003566667 106.17 0.0002 Xylenes 0.006 52.515 0.026 C8+ Heavies 0.0417 879.83612 0.0166 C8+ Heavies 0.581 5088.081 2.544 Mass Fraction VOC: 0.2312 Total 35.427 Heating Value I 1283 BTU/scf Combustion emission factor source: AP-42.Chapter 13.5 0.07 I lb NOX/MMBtu 0.37 I lb CO/MMBtu Notes Mole . '.16V.and 1,1aS7;'racoons based or average of Inree extended sales gds +'vsis for Latham 14-1'-'_HZ(collected 221:20131. Latham Emissions Summary Uncontrolle tpy NOX ncontrolle d/PTE 1.2 tpy CO 35.4 tpy VOC Controlled 1.8 tpy VOC Scenario A Controlled CAS# Total (Ib/yr) Bin Reportable Total n-hexane 110543 839.0 C No 42 224-TMP 540841 1.1 C No 0 Benzene 71432 141.5 A Yes 7 Toluene 108883 124.4 C No 6 E-Benzene 100414 15.7 C No 1 Xylenes 1330207 52.5 C No 3 Resultant Emission Factors Controlled VOC 13480.719 lb/MMscf natural gas used 674.04 lb/MMscf Benzene 26.930 lb/MMscf natural gas used 1.3465 n-hexane 159.626 lb/MMscf natural gas used 7.9813 Toluene 23.663 lb/MMscf natural gas used 1.1832 E-Benzene 2.988 lb/MMscf natural gas used 0.1494 Xylenes 9.991 Ib/MMscf natural gas used 0.4996 224-TMP 0.201 Ib/MMscf natural gas used 0.0100 12WE3095.CP3 E3095.C P3 123/9A7D I ow-pressure separator c LiCio.sid by a VFl1 arici an chi used l' ..I mmg Vlltl n tvsnnnii• A Ltl hoc a n in loin,ciiiii.sioniii 016 cosi oi ii(13). ,a 11 flue hnn n ihrointi in'.rvrnbt vat'of->-:... Equipment Description This source vents natural gas from: a low pressure separator located at the well head Emissions from this source are: routed to a flare (during VRU downtime Natural gas venting from a low pressure separator located at the well head.Emissions from this source are routed to a flare. Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=G'MW*XxIC Ex=emissions of pollutant x • O=Volumetric flow rateNolume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(0) 9.91 MMscf/yr 1131.0 scfrhr 0.84 MMscf/mo MW 35.000 lb/b-not 0.027 MMscf/d mole% MW Ibx/Ibmol mass fraction E lb/hr Ib/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 2.17 44.01 0.955 0.027 CO2 2.8 24965 12.48 N2 0.07 28.013 0.020 0.001 N2 0.1 513 0.26 methane 31.793 16.041 5.100 0.146 methane 15.2 133319 66.66 ethane 25.4362 30.063 7.647 0.218 ethane 22.8 199900 99.95 propane 244402 44.092 10.7762 0.308 propane 32.2 281703 140.85 isobutane 27114 58.118 1.5758 0.045 isobutane 4.7 41194 20.60 n-butane 7.8882 58.118 4.5845 0.131 n-butane 13.7 119844 59.92 isopentane 14442 72.114 1.0415 0.030 isopentane 3.1 27225 13.61 n-pentane 18301 72.114 1.3198 0.038 n-pentane 3.9 34500 17.25 cyctopentane 0.1326 70.13 0.0930 0.003 cyclopentane 0.3 2431 1.22 n-Hexane 04186 86.18 0.3607 0.010 n-Hexane 1.1 9430 /]2 cyctohexane 0.1165 84.16 0.0980 0.003 cyclohexane 0.3 2563 1.28 Other hexanes 0.6804 86.18 0.5864 0.017 Other hexanes 1.7 15328 7.66 heptanes 0.3533 100.21 0.3540 0.010 heptanes 1.1 9255 4.63 nethylcyctohexane 0.0979 98.19 0.0961 0.003 methylcyclohexane 0.3 2513 1.26 224-TMP 0.0003 114.23 0.0003 0.000 224-TMP 0.0 9 0.00 Benzene 0.0774 78.12 0.0605 0.002 Benzene 0.2 1581 0.79 Toluene 0.0566 92.15 0.0522 0.001 Toluene 0.2 1363 0.68 Etl'tenzene 00062 106.17 0.0066 0.000 ENytbenzene 0.0 172 0.09 Xylenes 0.0165 106.17 0.0175 0.001 Xylenes 0.1 458 0.23 C8-)Heavies 0.258 114 CC0 0.2941 0.008 C13).Heavies 0.9 7689 3.84 VOC mass fraction: 0.6091 Total VOC Emissions(Uncontrolled) 278.63 35.039 Total VOC Emissions(Controlled) 7.0 No s monthly limit assuming 95%control(lb/ma.) 1183.2 Mole%and MW are based on sample results of flash gas to VRU collected 9/5/2013 from Latham 44 Fluwrate is based on Promos run.Emissions are based on 8760 hours of operation per year I calculated the average MW of 08+based on the average MW on the analysis for the gas to be 99.Source used 114 which slightly increased emissions by 0.5 tpl Flaring Information Equipment Description The low pressure se arator is controlled by a VRU with 50%uptime.When the VRU is down,the low pressure separator gas is routed to a flare. Manufacturer Leed Model L30-0010 48" Serial Number 21236,21237,20950,21235,21244,20927,HOC-48 SN 17987&17986 Gas Heating Value 2009 Btu/scf Throughput 9952.14402 MMBtu/yr Throughput is based on 50%of total low pressure separator gas volume when VRU is d Combustion emission factor source: AP-42:Chapter 13.5 L 0.07 I lb NOX/MMBtu I 0.37 I lb CO/MMBtuI 12WE3095.CP3 123/9A7D 0.34 tpy NOX 1.84 tpy CO Emissions Summary 0.3 tpy NOX Uncontrolled/PTE 1.8 tpy CO 278.6 tpy VOC Controlled 7.0 tpy VOC Controlled includes VRU and flare Uncontrolled Scenario A Controlled Total Total(Ib/yr) Bin Reportable? (Ib/yr) Benzene 1581 A Yes 40 Toluene 1363 C Yes 34 Ethylbenzene 172 C No 4 Xylenes 458 C Yes 11 n-hexane 9430 C Yes 236 224-TMP 9 C No 0 Regulatory Applicability AQCC Regulation i [This source is subject to the opacity requirements for flares in Section II.A.5.'No owner or operator of a AQCC Regulation 2 [Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the AQCC Regulation 3 Is public comment Public Comment Required required? Emission Factors for Permit Uncontrolled NOX 68.306 b/MMscf natural gas vented CO 371.665 b/MMscf natural gas vented VOC 56245.8818 b/MMscf natural gas vented Benzene 159.5379 b/MMscf natural gas vented Toluene 137.6172 b/MMscf natural gas vented Ethylbenzene 17.3682 b/MMscf natural gas vented Xylenes 46.2218 b/MMscf natural gas vented n-Hexane 951.8456 b/MMscf natural gas vented 224-TMP 0.9042 b/MMscf natural gas vented Controlled-based on 50%downtime for VRU and 95%control of flare during VRU downtime NOX 68.306 b/MMscf natural gas vented CO 371.665 b/MMscf natural gas vented VOC 1406.1470 b/MMscf natural gas vented Benzene 3.9884 b/MMscf natural gas vented Toluene 3.4404 b/MMscf natural gas vented Ethylbenzene 0.4342 b/MMscf natural gas vented Xylenes 1.1555 b/MMscf natural gas vented n-Hexane 23.7961 b/MMscf natural gas vented 224-IMP 0.0226 b/MMscf natural gas vented 12 W E3095.CP3 123/9A70 Low-pressure separator controlled by a VRII ana an enclosed flare during VRU downtime.VRU has a min m m >erational 017 time of 50'E.and flare has a minimum cornbr s cr efficiency of 95".=:,. Equipment Description This source vents natural gas from: a low pressure separator located at the well head Emissions from this source are: routed to a flare 'during VRU downtime Natural gas venting from a low pressure separator located at the well head.Emissions from this source are routed to a flare. Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II.Chapter 10-Displacement Equation(10.4-3) Ex=O'MW'Xx IC Ex=emissions of pollutant x O=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mot)at 60F and 1 atm Throughput(0) 9.91 MMscf/yr 1131.0 scf/hr 0.84 MMscf/mc ' MW 35.000 lb/lb-mol 0.027 MMscf/d mole% MW lbx/Ibmol mass fraction E lb/hr lb/yr spy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 2.17 44.01 0.955 0.027 CO2 2.8 24965 12.48 N2 0.07 28.013 0.020 0.001 N2 0.1 513 0.26 methane 31.793 16.041 5.100 0.146 methane 15.2 133319 66.66 ethane 254362 30.063 7.647 0.218 ethane 22.8 199900 99.95 propane 244402 44.092 10.7762 0.308 propane 32.2 281703 140.85 isobutane 2.7114 58.118 1.5758 0.045 Isobutane 4.7 41194 20.60 n-butane 78882 58.118 4.5845 0.131 n-butane 13.7 119844 _ 59.92 isopentane 1.4442 72.114 1.0415 0.030 isopentane 3.1 27225 13.61 n-pentane 18301 72.114 1.3198 0.038 n-pentane 3.9 34500 17.25 cyclopentane 0.1326 70.13 0.0930 0.003 cyclopentane 0.3 2431 1.22 n-Hexane 04186 86.18 0.3607 0.010 n-Hexane 1.1 9430 4.72 • cyclohexane 0.1165 84.16 0.0980 0.003 cyclohexane 0.3 2563 1.28 Other hexanes 0.6804 86.18 0.5864 0.017 Other hexanes 1.7 15328 7.66 heptanes 0.3533 100.21 0.3540 0.010 heptanes 1.1 9255 4.63 methylcyclohexane 0.0979 98.19, 0.0961 0.003 methylcyclohexane 0.3 2513 1.26 224-IMP 0.0003 114.23 0.0003 0.000 224-TMP 0.0 9 0.00 Benzene 0.0774 78.12 0.0605 0.002 Benzene 02 1581 0.79 Toluene 0.0566 92.15 0.0522 0.001 Toluene 02 1363 0.68 Ethylbenzene 0.0062 106.17 0.0066 0.000 Ethylbenzene 0.0 172 0.09 Xylenes 0.0165 106.17 0.0175 0.001 Xylenes 0.1 458 0.23 C8*Heavies 0.258 t 14.000 0.2941 0.008 08.Heavies 0.9 7689 3.84 VOC mass fraction: 0.6091 Total VOC Emissions(Uncontrolled) 278.63 35.039 Total VOC Emissions(Controlled) 7.0 Notes monthly limit assuming 95%control(lb/mo.) 1183.2 Mole%and MW are based on sample results of flash gas to VRU collected 9/5/2013 from Latham 44 Flowrate is based on Promax run.Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8w based on the average MW on the analysis for the gas to be 99 Source used 114 which slightly increased emissions by 0.5 tpy Flaring Information Equipment Description The low pressure separator is controlled by a VRU with 50%uptime.When the VRU is down,the low pressure separator gas is routed to a flare. Manufacturer Leed Model L30-001048" Serial Number 21236,21237,20950,21235,21244,20927,HOC-48 SN 17987 8 17986 Gas Heating Value 2009 Btu/scf Throughput 9952.14402 MMBtu/yr Throughput is based on 50%of total low pressure separator gas volume when VRU is d. Combustion emission factor source: AP-42:Chapter 13.5 I 0.07 I lb NOX/MMBtu I 0.37 I lb CO/MMBtu I 12WE3095.Cp3 123/987D 0.34 tpy NOX 1.84 tpy CO Emissions Summary 0.3 tpy NOX Uncontrolled/PTE 1.8 tpy CO 278.6 tpy VOC Controlled 7.0 tpy VOC Controlled includes VRU and flare Uncontrolled Scenario A Controlled Total Total(lb/yr) Bin Reportable? (lb/yr) Benzene 1581 A Yes 40 Toluene 1363 C Yes 34 Ethylbenzene 172 C No 4 Xylenes 458 C Yes 11 n-hexane 9430 C Yes 236 224-TMP 9 C No 0 Regulatory Applicability A CC R ulation 1 This source is subject to the opacity requirements for Pares in Section II A.5.'No owner or operator of a At3CC Regy l lion 2 (Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the AQCC Regulation 3 Is public comment Public Comment Required required? Emission Factors for Permit Uncontrolled NOX 68.306 lb/MMscf natural gas vented CO 371.665 lb/MMscf natural gas vented VOC 56245.8818 lb/MMscf natural gas vented Benzene 159.5379 lb/MMscf natural gas vented Toluene 137.6172 lb/MMscf natural gas vented Ethylbenzene 17.3682 lb/MMscf natural gas vented Xylenes 46.2218 lb/MMscf natural gas vented n-Hexane 951.8456 lb/MMscf natural gas vented 224-TMP 0.9042 lb/MMscf natural gas vented Controlled-based on 50%downtime for VRU and 95%control of flare during VRU downtime NOX 68.306 lb/MMscf natural gas vented CO 371.665 lb/MMscf natural gas vented VOC 1406.1470 lb/MMscf natural gas vented Benzene 3.9884 lb/MMscf natural gas vented Toluene 3.4404 lb/MMscf natural gas vented Ethylbenzene 0.4342 lb/MMscf natural gas vented Xylenes 1.1555 lb/MMscf natural gas vented n-Hexane 23.7961 lb/MMscf natural gas vented 224-TMP 0.0226 lb/MMscf natural gas vented 12WE3095.CP3 123/9470 0 II N a K 0 N N N N N N 00000 0 0 0 0 N N 0' 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0000 Z : o• >r,> r> ,> » >r> r »> ,> zzz > zzzz 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .9.,.. .,...-4....."-e. 0 0 0 0 0 W N m N N m N 0 0 0 0 0 0 0 0 0 0 0 0 10 N m m N N N N m m 1n -C•m m m m m m m m m m m m m m m m m 03 OM N- rm., L•a my m(O •la CO N N La Nt mm conic!m 0 06- 06' tit V^49 C'I W m ry H t710 N 1-- N C9 f0 a N .4 N f0 V 4 o N N N i r M m F r 0- O N {{ N 0' OOh en WN mn wm(OOm en ea la oa m N N9M O N�V NN m< O ^ n Nor t7 O 2 am r N1-- NMr 10 4No Or Nr r OJ r 6 W al H H H H H o 0 0 0 o o O O o 0 0 r I, N N N r d d d 0 d d 030303003 C N I J J J J J J LO N D J J J J o OOoo (ojn D'0 O'O'0 0 n nj O'S O'V Q O W m m N N N 0 d d 0 0 d d 0 d 0 d O magma d 0 C C C C C 0 0 0 C C C C C 1i 0 �,d0 0_!c tK K �[ K K a a p CO ry 0 y 0 y 0 y 0 d Z Z 0 0 0 00 p 0o00000 mu (00000 Nmoor)ro LO N 1010 ~ ~ U U U U 0 0 ~ ~ 0 0 0 0 0 'Fwd a a n n a a 0 0 01 0 0 a 0 N 0 0 0 0 0 0 V ar V v g N N 0 0 0 0 0 N N N N 0 co N 0 J y 000) 00 0) m0)m m m Q CCCC naaaaagyannnn E di'� « accccccaaaa a aaH0 ? ?H a aa !?!?yyy W VJ fnN41 fA NN Q W W W W W W W W W W W Q 0000000 Q Q ❑c o oo 0 (000 (0 (000 (000coco m en to m 0)m 0)0)0)0)0) 0)m 01) 000000 O 0 O Ott t c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0000000000000 2MMM2MMM MMMMMMM .N 000000 8000000 i.i.i., i.Z 2222222 22 M MMMM .E .o.O as as .o Jo a sa as .0 JO SD a, as an 1] .O.nn n n n nag n W a d V ° nn000 oon�o coN oor, ro E. moam0 o (nln PNo �m m l+1 aft: m (nrar yr mro ry U ON N01N0 nto hm0 RNm1NO(NG p .;<,6ON NOOONi (mo mm6 NN y ym rnmm Of C 01)0 ,-7 O O 9.0 0 0 7 04.0 m m yy m^ 0 fl 'co mmN coC'I m thm W -i LL m0 r 000 ROo 0000 CNN(O V and NN N 0)1- m V r NNN m N J O 0) LL C C C C C C C C C C C C C C C C C C C C C C C C C C C C C C C C C M 0 0 0 C N N C 0 0 0 C U d C d Cp C 0 m o N X d C H N d a C %1� N 0 C % N d d C 02° §124) N Do d= O T N O d O S T C N 0 d O T t O00213= -5.= 0 0 0 o3€JT N U m > m CHXN > OH W X CN >OHX & Z0> OHLuX C Z0> 01-W X 0 m Ln p O CN9 M M 0 r N)M< Q M 1+] p 9. 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O 222229 222222 222222 222222 '� 777777 N N N N N_ N_ J U) U) 0 0 0 0 0 0 U) J 0 J 0 0 J UJ (N J J J J 0 0 (A m _ J _ J 0 0 M 0 0 0 0 OM M O"o'Q QV O'(rj M O' O'O' 00 O OrrOM000WWWWWWWWWWWWW000000 N C 0 N c C C C C N N C C C C C C N N C C C C C C N N C C C C C C 0 a a m m N 0) O m a a O O 0) O m O a a 0) O N o m m a a 0 N o o O m L_ C N H H N N N N o N !- H o N N a o N H I- N o a N N N H H N o d a N N O U U U U U U U U U U U U U U U U U U U 0 0 0 0 0 0 p m N N (0 N N N N N N N N N N N N N N N N N N N N N N N m N (0 (0 (0 (0 E ° mm a s a s a at a a a a a a 1 Y a a a a a ay9 a a a a as E O m a a N N N N N N a a N N N N N N a a N N N N N N a a N N N N N N w U1 0 0 0 0 0 0 0 < < OOOOOO < < OOOOOO 0 0 O O O 0 O 0 tt `Utttutu `ptu `Utu `U`p u `U`p <`)uuut tUfu `o `pu`p ✓ 000000000000000000000000000000000 O 22222222222M2222222222 BBBIIBBBB w y m m m M O m N m o N C') OMN m COON (0 m O (O m h f- N m(() O O N- O m O m h n m V) O(O m n N- N m N C N (O 0 4 M m V Q m 0 N (O 0 Oj m m Q (O (O N M m V p o m O(p Q N m m N 0 N N- m N m W (O O (O Q N(O m N m O m Q N m m N(O C (0 m r N m O M N N y Q m m m m m M N m M r (h r N m m M N N r m m m m M n m 0 0 r ^ N N m m(O (0 m m^' r m m m m m N r r m 0 � LL r m M (n r r Q m m V N N N m r m M m V m m M N r aT m N 0 0 m 0 LL C C C C C C C C C C C C C C C C C C C C C C C C C C C C C C C G C M 0) 0 N N N N C (0 C 2 N N . C 2 0) m d C 2 N N y c >0 N 0 N L O o O N O t T L 8 c o 2 3 T t O O O N t J.t O O O W p t .. N U c Z o > m w X c Z o> c0 w X c Z o > 6] w X c Z o > m w X c Lo M 0 000 MW M M M M V O M M V 0 ZZ n c e v o a r CO y N r w K N $ -t o a N m o N- m O o 0 N- 00 0 0 n 0 o ° 0 n moo 0 7 0 0 0 0 00 M 00m M NN O O a ^o d (n • 0 • m m m m m ? w o N o o o N E9 0 0 0 0 E o 0 0 0 0 • m m o U °) (y M m • II 0• m m m u 0 Q m m n a 3 3 3 3 v 2 K o o- Z d LU W L U T W F a a '2 a ° S o 'E o. Qwv 0 • v co LL C N d N E oo Wm C .F1 y W 0, m O c 0 c o D LL 0 N J m LL (4) C U � CD s N 10 U m 1n• 2 0 IS ❑ m o n W N c 0. m ^ m N N ti LL U N ▪ ° • o c N v U 0. 3 v a 0 U 5 N c a a d Y a a o E • Wd 0 U • z? 14-11-2Hz 14-2 44, 41-2HNAverage mol% helium 0.01 0.01 0.01 0.01 nitrogen 0.53 0.63 0.56 0.573333 C02 2.21 2.04 2.11 2.12 methane 74.145 77.5751 73.4074 75.0425 ethane 13.5375 11.5722 13.407 12.8389 propane 6.728 5.3258 6.8142 6.289333 isobutane 0.609 0.5011 0.663 0.591033 n-butane 1.5414 1.3419 1.8582 1.5805 isopentane 0.2035 0.2525 0.3137 0.256567 n-pentane 0.2508 0.3128 0.3863 0.316633 cyclopenta 0.0182 0.0236 0.0271 0.022967 n-hexane 0.0449 0.0803 0.0854 0.0702 cyclohexan 0.0118 0.0231 0.0237 0.019533 Other hexa 0.0802 0.1299 0.1391 0.1164 heptanes 0.0299 0.0729 0.0733 0.0587 methylcycl 0.0088 0.0219 0.0208 0.017167 224-TMP 0 0.0001 0.0001 6.67E-05 Benzene 0.0089 0.0147 0.0156 0.013067 Toluene 0.0055 0,0115 0.0122 0.009733 Ethylbenze 0.0006 0.0011 0.0015 0.001067 Xylenes 0.0024 0.0043 0.004 0.003567 C8+ Heavie 0.0233 0.045 0.0568 0.0417 avg VOC mol% 9.408233 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY /1'^ . Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) AIRS ID#': 123/9A7D/001 ❑ APEN update only4 ® New or previously unreported battery ® Modification to existing sources ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GP0I ❑ Synthetic minor facility I L's/✓r.C-SClq &cancellation request for individual permit6: ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ® Registered under general permit no.GP01 ❑ Administrative permit amendment' I ❑ Permitted under individual permit: ❑ Other: F For individual permit applications,check if you wants: ®A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Name9: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 Mailing Address10: 410 17°i Street,Suite 1500 pyoung@BonanzaCrk.co City: Denver State: CO Zip: 80202 E-mail: m Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 6-400 bbl, Tank Battery Name'1: Latham 14-2 Production Facility(COGCC#429121) Number of tanks: 6-500 bbl Location"(QQ Sec.Twp.Range.): SW/SW,Sec 2,T4N,R63W County: Weld Total tank capacity[bbl]: 5,400 Calendar year for which"Actual"data applies'3: 2013 Year(s)tank(s)were placed in service14: 6-2012,6-2013 Six(6)Leed L30-0010 48" SN:21236,21237,20950,21235, Control Description's: 21244,20927,and two(2)HOC-48 SN: 17987& 17986 Control Efficiency's: 95% Condensate Throughput''[bbl'year] Requested's: N/A Maximum for PTE calculation19: 214,620 Actual20: 178,850 While Controls Operational' 178,850 Other equipment at facility: Heater treaters,produced water tanks,natural gas-fired engines,pneumatic pumps ADEN update due to addition of 2 new wells and new equipment onsite.Previously permitted tank batteries 1 and 2 under AIRS IDs 123/9A7D/001 and 123/9A7D/002 are now combined into 1 single battery under 123/9A7D/001.Request to convert from Comments: general permit to site specific permit. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ® Check if site-specific emission factors provided to calculate emissionsJ3. Emission Factor Battery Requested Emission's Actual Emissions'° Pollutant'° [lbTbl] PTE25 Uncontrolled'6 Controlled27 Uncontrolled26 Controlled. VOC[tons/year] 1.52 163.37 163.37 8.17 136.14 6.81 NOx [tons/year] 0.3 0.3 0.25 0.25 CO[tons/year] 1.62 1.62 1.36 1.36 Benzene[lbs/year] 0.010 2,052.0 2,025.2 102.60 1,710.0 85.5 o-Hexane[lbs/year] 0.056 12,115.2 12,115.2 605.76 10,096.0 504.8 Wells serviced by this tank or tank battery's ApI#: 05-123-35698 Name: Latham 14-2 ❑Newly Reported Well Ap)#: 05-123-35697 Name: Latham 14-11-2HZ ❑Newly Reported Well • API#: 05-123-37290 Name: Latham 44-11-2HNB ®Newly Reported Well API#: 05-]23-37287 Name: Latham O-K-2HNB ®Newly Reported Well API#: Name ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: • ❑Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief If this is a registration for coverage under general permit GP0I,I further certify that this source is and will be operated in full compliance with path condition ofIkeneral permit GPO]. 4 Signature of Legally Authto,razed Person(not a vendor or consultant) Date. David J.Lillo Vice President,Rocky Mt.Asset Management Type or Print Name of Person Signing Above Official Title Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 FormAPCD-205-E&PCondensateTankAPEN.docx 301518 ,° o _ o ' o C .. `o E `c - z u Y11 1 Y n vi �] O c. .". 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