HomeMy WebLinkAbout20210476.tiff COLORADO
41 Department of Public
cDPME Health&Environment RECEIVED
FEB 16 2021
WELD COUNTY
COMMISSIONERS
Weld County - Clerk to the Board
1150 0 St
PO Box 758
Greeley, CO 80632
February 8, 2021
Dear Sir or Madam:
On February 9, 2021, the Air Pollution Control Division will begin a 30-day public notice period for
Bison Oil Et Gas II, LLC - Boomslang 14 Tank Battery. A copy of this public notice and the public
comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health &t Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
Jared Polls,Governor I Jill Hunsaker Ryan,MPH, Executive Director ' ,
Pv b I:C Ke v':e W c c:PL(TP)HL(QS/TR) pto(vM/sR/GH/GK), 2021-0476
oGCsM)
02 /24 /2I
MYM: Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
CDPHE
C
Comment
Website Title: Bison Oil Et Gas II, LLC - Boomslang 14 Tank Battery - Weld County
Notice, Period Begins: February 9, 2021
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: Bison Oil Et Gas II, LLC
Facility: Boomslang 14 Tank Battery
Exploration Et Production Well Pad
SESE S14 T8N R60W
Weld County
The proposed project or activity is as follows: This source is requesting individual permit coverage for the
well pad production facility. The APEN's were received in October, 2019 and the source was constructed in
early 2020. The source is requesting individual permit coverage for the crude oil storage tanks and venting
of natural gas from the vapor recovery units during VRU downtime. The source has also requested GP08
coverage for the produced water tanks on-site. This source is located in the ozone nonattainment area and
is synthetic minor for VOC and n-hexane.
The Division has determined that this permitting action is subject to public comment per Colorado
Regulation No. 3, Part B, Section III.0 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 19WE1009 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Lauraleigh Lakocy
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
4 i As Department of Public
1 � Health 8 Environment
r:;;. COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
CONSTRUCTION PERMIT
Permit number: 1 9WE 1 009 Issuance: 1
Date issued:
Issued to: Bison Oil &t Gas II, LLC
Facility Name: Boomslang 14B Tank Battery
Plant AIRS ID: 1 23/A0A1
Physical Location: SESESEC 14 T8N R6OW
County: Weld County
Description: Well Production Facility
Equipment or activity subject to this permit:
Facility AIRS Emissions Control
Equipment ID Point Equipment Description Description
Crude Tanks 001 Five (5) 750 barrel fixed roof storage Enclosed Combustion
vessels used to store crude oil Device
Bulk VRT/Test Enclosed Combustion
VRT 002 Two (2) Vapor Recovery Towers Device
This permit is granted subject to all rules and regulations of the Colorado Air Quality Control
Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to
the specific general terms and conditions included in this document and the following specific terms
and conditions.
REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (Division) no later than fifteen days
after commencement of operation under this permit by submitting a Notice of Startup
(NOS) form to the Division. The Notice of Startup (NOS) form may be downloaded online at
https://www.colorado.gov/pacific/cdphe/air/manage-permit. Failure to notify the Division
of startup of the permitted source is a violation of AQCC Regulation Number 3, Part B, III.G.1
and can result in the revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit must 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
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C ».,,,. COLORADO
Nue Air Pollution Control Division
Department of Public Health a Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
result in revocation of the permit. A self certification form and guidance on how to self-
certify compliance as required by this permit may be obtained online at
www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section
III.G.2.)
3. This permit must 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. (Regulation
Number 3, Part B, Section
4. The operator must complete all initial compliance testing and sampling as required in this
permit and submit the results to the Division as part of the self-certification process.
(Regulation Number 3, Part B, Section III.E.)
5. The operator must 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
6. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
Annual Limits:
Facility AIRS Tons per Year Emission
Equipment ID Point PM2.5 NO,t VOC CO Type
Crude Tanks 001 --- --- 10.2 2.0 Point
Bulk VRT/Test 002 --- - 4.1 --- Point
VRT
Note: See"Notes to Permit Holder"for information on emission factors and methods used to calculate limits.
Facility-wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons
per year.
Facility-wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year.
The facility-wide emissions limitation for hazardous air pollutants must apply to all permitted
emission units at this facility.
Compliance with the annual limits, for both criteria and hazardous air pollutants, must be
determined on a rolling twelve (12) month total. By the end of each month a new twelve
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COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
month total is calculated based on the previous twelve months' data. The permit holder must
calculate actual emissions each month and keep a compliance record on site or at a local
field office with site responsibility for Division review.
7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to
calculate emissions and show compliance with the limits. The owner or operator must submit
an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any
other method of calculating emissions.
8. The emission points in the table below must be operated and maintained with the emissions
control equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit. (Regulation Number 3, Part B, Section III.E.)
Facility AIRS Control Device Pollutants
Equipment ID Point Controlled
Crude Tanks 001 Enclosed Combustion Device VOC and HAP
Emissions from the Bulk VRT/Test VRT are
Bulk 002 routed to an Enclosed Combustion Device VOC and HAP
VRT/Test VRT during Vapor Recovery Unity (VRU)
downtime
PROCESS LIMITATIONS AND RECORDS
9. This source must be limited to the following maximum processing rates as listed below.
Monthly records of the actual processing rates must be maintained by the owner or operator
and made available to the Division for inspection upon request. (Regulation Number 3, Part B,
II.A.4.)
Process Limits
Facility AIRS
Equipment Point Process Process Parameter Annual Limit
ID
Crude Tanks 001 01 Crude Oil throughput 643,632 barrels
02 Combustion of pilot light fuel 0.4 MMSCF
Bulk 01 Crude Oil Throughput During 64,363 barrels
VRT/Test 002 VRU Downtime
VRT 02 Combustion of pilot light fuel 0.4 MMSCF
Note: The crude oil throughput used to determine compliance with these limits will be the
combined crude oil throughput measured at the outlet of the four (4) high pressure
separators.
The owner or operator must monitor monthly process rates based on the calendar month.
Compliance with the annual throughput limits must 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
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r«,» COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
previous twelve months' data. The permit holder must calculate throughput each month and
keep a compliance record on site or at a local field office with site responsibility, for Division
review.
10. Point 002: The owner or operator must continuously monitor and record Vapor Recovery Unit
(VRU) downtime while emissions are routed to the control device.
11. Point 002: The owner or operator must use monthly VRU downtime records, monthly
condensate/crude oil throughput records, calculation methods detailed in the OEtM Plan, and
the emission factors established in the Notes to Permit Holder to demonstrate compliance
with the process and emissions limits specified in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
12. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001)
must be marked on the subject equipment for ease of identification. (Regulation Number 3,
Part B, Section I I I.E.) (State only enforceable)
13. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
14. Point 001, 002: The combustion device covered by this permit is subject to Regulation
Number 7, Part D, Section II.B.2. General Provisions (State only enforceable). If a flare or
other combustion device is used to control emissions of volatile organic compounds to comply
with Section II, it must be enclosed; have no visible emissions during normal operations, as
defined under Regulation Number 7, Part D, Section II.A.23; and be designed so that an
observer can, by means'of visual observation from the outside of the enclosed flare or
combustion device, or by other convenient means approved by the Division, determine
whether it is operating properly. This flare must be equipped with an operational auto-igniter
according to the schedule in Regulation Number 7, Part D, Section II.6.2.d.
15. Point 001: This source is subject to Regulation Number 7, Part D, Section I. The operator
must comply with all applicable requirements of Section I and, specifically, must:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for storage tanks; and
• Ensure that the combustion device controlling emissions from this storage tank be
▪ enclosed, have no visible emissions, and be designed so that an observer can, by
means of visual observation from the outside of the enclosed combustion device, or by
other means approved by the Division, determine whether it is operating properly.
(Regulation Number 7, Part D, Section I.C.) (State only enforceable)
16. Point 001: The storage tank covered by this permit is subject to the emission control
requirements in Regulation Number 7, Part D, Section II.C.1. The owner or operator must
install and operate air pollution control equipment that achieves an average hydrocarbon
control efficiency of 95%. If a combustion device is used, it must have a design destruction
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;'' COLORADO
/ Air Pollution Control Division
4� Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
efficiency of at least 98% for hydrocarbons except where the combustion device has been
authorized by permit prior to March 1, 2020. The source must follow the inspection
requirements of Regulation Number 7, Part D, Section II.C.1.d. and maintain records of the
inspections for a period of two years, made available to the Division upon request. This
control requirement must be met within 90 days of the date that the storage tank commences
operation.
17. Point 001: The storage tanks covered by this permit are subject to the venting and Storage
Tank Emission Management System ("STEM") requirements of Regulation Number 7, Part D,
Section II.C.2.
18. Point 002: The separator covered by this permit is subject to Regulation 7, Part D, Section
II.F. On or after August 1, 2014, gas coming off a separator, produced during normal
operation from any newly constructed, hydraulically fractured, or recompleted oil and gas
well, must either be routed to a gas gathering line or controlled from the commencement of
operation by air pollution control equipment that achieves an average hydrocarbon control
efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency
of at least 98% for hydrocarbons.
19. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator
of oil and natural gas operations and equipment at or upstream of a natural gas processing
plant in Colorado must submit a single annual report that includes actual emissions and
specified information in the Division-approved report format. The information included in the
annual report must be in accordance with the general reporting requirements of Regulation
Number 7, Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter,
owners or operators must maintain the information according to Regulation Number 7, Part D,
Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V)
OPERATING Et MAINTENANCE REQUIREMENTS
20. Upon startup of these points, the owner or operator must follow the most recent operating
and maintenance (OEM) plan and record keeping format approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions
to the OEM plan are subject to Division approval prior to implementation. (Regulation
Number 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
21. Point 001, 002: The owner or operator must demonstrate compliance with opacity standards,
using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or
absence of visible emissions. "Visible Emissions" means observations of smoke for any period
or periods of duration greater than or equal to one minute in any fifteen-minute period during
normal operation. (Regulation Number 7, Part D, Sections I.C, II.B.2. and II.A.23)
22. Point 001: The owner or operator must complete site specific sampling including a
compositional analysis of the pre-flash pressurized crude oil routed to these storage tanks
Page 5 of 12
y COLORADO
Air Pollution Control Division
Department of Public Health h Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
and, if necessary for emission factor development, a sales oil analysis to determine RVP and
API gravity. Testing must be in accordance with the guidance contained in PS Memo 14-03.
Results of testing must be used to determine site-specific emissions factors for VOC and
Hazardous Air Pollutants using Division approved methods. Results of site-specific sampling
and analysis must be submitted to the Division as part of the self-certification and used to
demonstrate compliance with the emissions factors chosen for this emissions point.
23. Point 002: The owner/operator must complete an initial site specific extended gas analysis
("Analysis") within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the natural gas vented from this emissions
unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and
2,2,4-trimethylpentane content (weight fraction) of this emission stream. Results of the
Analysis must be compared to the content (weight fraction) for the pollutants referenced in
the "Notes to Permit Holder". Results of the Analysis must be submitted to the Division as
part of the self-certification and must demonstrate the content (weight fraction) established
through the Analysis are`less than or equal to, the content (weight fraction) submitted with
the permit application and established herein in the "Notes to Permit Holder" for this
emissions point. If any site-specific pollutant content (weight fraction) developed through this
Analysis is greater than the pollutant content (weight fraction) submitted with the permit
application and established in the "Notes to Permit Holder" the operator must submit to the
Division within 60 days, or in a timeframe as agreed,to by the Division, a request for permit
modification to address these inaccuracies.
Periodic Testing Requirements
24. This source is not required to conduct periodic testing, unless otherwise directed by the
Division or other state or federal requirement.
ADDITIONAL REQUIREMENTS
25. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A,
II.C.)
• Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five
(5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone
nonattainment areas emitting less than 100 tons of VOC or NOX per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
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11
Ito Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on
the last APEN submitted; or
For any non-criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or
activity; or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
26. Federal regulatory program requirements (i.e. PSD, NANSR) must 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 must not exceed the Federal program threshold until
a permit is granted. (Regulation Number 3, Parts C and D).
GENERAL TERMS AND CONDITIONS
27. This permit and any attachments must be retained and made available for inspection upon
request. The permit may be reissued to a new owner by the APCD as provided in AQCC
Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the
submittal of a revised APEN and the required fee.
28. If this permit specifically states that final authorization has been granted, then the remainder
of this condition is not applicable. Otherwise, the issuance of this construction permit does
not provide "final" authority for this activity or operation of this source. Final authorization
of the permit must be secured from the APCD in writing in accordance with the provisions of
25-7-114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final
authorization cannot be granted until the operation or activity commences and has been
verified by the APCD as conforming in all respects with the conditions of the permit. Once
self-certification of all points has been reviewed and approved by the Division, it will provide
written documentation of such final authorization. Details for obtaining final authorization
to operate are located in the Requirements to Self-Certify for Final Authorization section
of this permit.
29. 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,
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�� COLORADO
> Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
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.
30. Unless specifically stated otherwise, the general and specific conditions contained in this
permit have been determined by the APCD to be necessary to assure compliance with the
provisions of Section 25-7-114.5(7)(a), C.R.S.
31. 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 must constitute a rejection of the entire permit
and upon such occurrence, this permit must 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.
32. 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.
33. 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:
Lauraleigh Lakocy
Permit Engineer
Permit History
Issuance Date Description
Issuance 1 This Issuance Issued to Bison Oil &t Gas II, LLC
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r� COLORADO
Air Pollution Control Division
Department of Fublie Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder must pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this
permit. (Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative
Defense Provision for Excess Emissions During Malfunctions. The owner or operator must 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 ILEA of the
Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non-criteria reportable air pollutants are estimated based upon the
process limits as indicated in this permit. This information is listed to inform the operator of the
Division's analysis of the specific compounds emitted if the source(s) operate at the permitted
limitations.
AIRS Uncontrolled Controlled
Point Pollutant CAS # Emissions ` Emissions
(lb/yr) (lb/yr)
Benzene 71432 2578 129
Toluene 108883 2,616 131
Ethylbenzene 100414 2,074 104
001 Xylenes 1330207 1,335 67
n-Hexane 110543 13,177 659
2,2,4 540841 2,078 104
Trimethylpentane
Benzene 71432 987 49
Toluene 108883 1,002 50
Ethylbenzene 100414 796 40
002 Xylenes 1330207 512 26
n-Hexane 110543 5,054 253
2,2,4 540841 797 40
Trimethylpentane
Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year
(lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice.
Page 9 of 12
COLORADO
C .4141/4-Aso
Ito Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
5) The emission levels contained in this permit are based on the following emission factors:
Point 001: Total actual emissions are obtained from the sum of emissions resulting from the
storage vessels and combustion of waste gas from the storage vessels (process 01) and the
combustion of pilot light fuel (process 02).
Process 01: Crude Oil Throughput
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
CO 5.9E-03 5.9E-03 AP-42,
Chapter 13.5
VOC 0.636 3.18E-02
71432 Benzene 4.00E-03 2.00E-04 Representative
108883 Toluene 4.06E-03 2.03E-04 Sample Taken
4/16/2018,
100414 Ethylbenzene 3.22E-03 1.61E-04 Modeled from HP
1330207 Xylene 2.07E-03 1.04E-04 Separator Outlet
110543 n-Hexane 2.05E-02 1.03E-03 Using WINSIM
2,2,4-
540841 3.23E-03 1.62E-04 Design 11
Trimethylpentane
Note: The controlled emissions factors for this point are based on a control efficiency of 95%.
Process 02: Combustion of Pilot Light Fuel
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/MMSCF lb/MMSCF
CO 316.2 316.2 AP-42,
Chapter 13.5
Note:The CO emission factor listed in the table above were obtained by multiplying the AP-42 Chapter 13.5 CO
emission factors (0.31 lb/MMBtu) by a heat value of 1,020 Btu/scf. Actual emissions are calculated by
multiplying the emission factors in the table above by the total fuel flow of the pilot gas. Pilot light fuel
flow is based on a constant rate of 20.5 scf/hr. There are two (2)enclosed combustion device used to
control emissions from the crude oil storage vessels. As a result, the total pilot gas fuel flow is 41 scf/hr.
Page 10 of 12
;;F , COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Point 002:
Uncontrolled Controlled
CAS # Pollutant Emission Emission Weight% Source
Factors Factors 1
(lb/bbl) (lb/bbl) _
VOC 2.56 1.28E-01 78.02 1
71432 Benzene 1.53E-02 7.65E-04 0.467 Representative
108883 Toluene 1.56E-02 7.80E-04 0.474 Sample Taken
4/16/2018,
100414 Ethylbenzene 1.24E-02 6.20E-04 0.37 Modeled from
1330207 Xylene 7.96E-03 3.98E-04 0.242 HP Separator
110543 n-Hexane 7.85E-02 3.93E-03 2.39 Outlet Using
WINSIM Design II
540841 2,2,4 1.24E-02 6.20E-04 0.377
Trimethylpentane
Note: The controlled emissions factors for this point are based on a control efficiency of 95%.
The emission factors listed above are based on modeled separator temperature of 139°F and
separator pressure of 5 psig.
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 must be submitted no later than 30 days before the five-year term expires. Please
refer to the most recent annual fee invoice to determine the APEN expiration date for each
emissions point associated with this permit. For any questions regarding a specific expiration date
call the Division at (303)-692-3150.
7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and
associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A)
when applicable.
8) This facility is classified as follows:
Applicable Status
Requirement
Operating Permit Synthetic Minor Source of: VOC, n-hexane
PSD True Minor Source
NANSR Synthetic Minor Source of: VOC
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://www.ecfr.gov/
Page 11 of 12
Cr =: COLORADO
_ __ Air Pollution Control Division
�� Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Part 60: Standards of Performance for New Stationary Sources
NSPS 60.1-End Subpart A - Subpart UUUU
NSPS Part 60, Appendixes Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
MACT 63.1-63.599 Subpart A - Subpart Z
MACT 63.600-63.1199 Subpart AA - Subpart DDD
MACT 63.1200-63.1439 Subpart EEE - Subpart PPP
MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY
MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM
MACT 63.8980-End Subpart NNNNN - Subpart)0000(X
Page 12 of 12
Colorado Air Permitting Project
PRELIMINARY ANALYSIS-PROJECT SUMMARY
Project Details For Division Use Only
Review Engineer: _a.�.•;•
Package#:
Received Date: ,2
Review Start Date:
Section 01-Facility Information
Company Name: lion OA Go OLC Quadrant Section Township Range
County AIRS ID: - -' 0 „tt cattntjtAttfttittt
Plant AIRS ID: i3. - Source provided quadrant information via email 1/5/21
Facility Name: t-
Physical
Address/Location: srSF luff-3::It of Sections 14,Township Sit Range 60W
, County: Weld County
Type of Facility: S. a:; Rt� `r`
What industry segment?u w ) �
Is this facility located in a NAAQS non-attainment areal °1
If yes,for what pollutant? 41.4Prat ` m
Section 02-Emissions Units In Permit Application
Leave Blank-For Division Use Only
Permit If
AIRS Point It Emissions _ (Leave blank unless Issuance Self Cert Engineering
(Leave blank unless APCD Emissions Source Type Equipment Name Action
Control? APCD has already ISRequired? Remarks
has already assigned)
assigned)
s# l
Section 03-Description of Project
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Sections 04,05&06-For Division Use Only
Section 04-Public Comment Requirements
s"
Is Public Comment Required?
If yes,why?
Section 05-Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? hi
If yes,for what pollutants? a
yes,attach a copy of Technical Services Unit modeling results summary.
Section 06-Facility-Wide Stationary Source Classification
Is this stationary sourcea true minor?
Is this stationary sources synthetic minor?
If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(PSD) ❑ ❑ ❑ ❑ ❑ El
Title V Operating Permits(OP) ❑ 0 ❑ ❑ 0 0 0 ❑
Non-Attainment New Source Review(NANSR) El ❑�
Is this stationary sources major source? ittplititkiagirrittitt
If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(PSD) ❑ 0 El ❑ ❑ ❑
Title V Operating Permts(OP) ❑ ❑ ❑ ❑ 0 El ❑ ❑
Non-Attainment New Source Review(NANSR) ❑ ❑
Storage Tank(s)Emissions Inventor}
Section 01-Administrative Information
Facility AIRS ID: RIA i✓` ROMPSVWS r Q&'7'^9 Uw
County Plant Point
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Section 02-Equipment Description Details
Storage Tank Liquid
Detailed Emissions Unit a � �� a` ' - �, f� 2
Description: ns�9y rf ..�°,"�,,� .. .,,.»,11-7�.r .< ",5s #`s k
Emission Control Device t"gai6`siikei Sfitt'sLk+oa.73'e'4tcnt � e
Description ,', wi r 0 m -F
Requested Overall VOC&HAP Control Efficiency A.
Limited Process Parameter 'x.
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Storage Tank(s)
Actual Throughput=. 9; yr '0`i'.Barrels(bbl)per year
(Requested Permit Limit Throughput= KQ c 0^Barrels(bbl)per year Requested Monthly Throughput= 546664,6 Barrels(bbl)per month
Potential to Emit(PTE)Condensate Throughput f%4�y �="„"t Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)
Heat content of waste as= py s z9
g " i7 '^'Btu/scF
Volumef waste gas emitted per BBLpf liquids /i4;
produced= „i�i�/��
,y" �a,NySsff/bbl See technical analysis notes below
q
Actual heat content of waste gas routed to combustion device= 0.0 MMBTU per year
Requested heat content of waste gas routed to combustion device= 12,246.2 MMBTU per year
Potential to Emit(PTE)heat content of waste gas routed to combustion device= 12,245.2 MMBTU per year
Control Device •
ovorm
Pilot Fuel Use Rate: 1,,. scfh 5.e MMscf/yr
Pilot Fuel Gas Heating Value: 00 „,ze? Btu/scf 365.3 MMBTU/yr
Section 04-Emissions Factors&Methodologies
Will this storage tank emit flash emissions?
Uncontrolled Controlled
Pollutant (Ib/hbl) (lb/bbl) Emission Factor Source
(Crude Oil (Crude Oil
Throughput) Throughput)
1.111:12.11111M1s5ti a
0d'J
0170<
O.082
O 6:G:
Control Device _
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source
(waste heat (Crude Oil
combusted) Throughput)
0,0 07,
.0.00?. _
00G
0.G530 e a-
0;31G0
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant MEOSTERIMEM Emission Factor Source
(Pilot Gas Heat (Pilot Gas
Comhusted) Throughput)
,,.6sx F
Zr.t 0.0-moo-woo zizszrktitliii*ovitiNt,,kozoitats1
a 6,,.c a Fn;ys WOMEN k'!:'V°NtEgAiAiii•ViaiA:Ar-Wr,:t:'
Section 05-Emissions Inventory
Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits
Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled
(tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month)
PM10 O.0 0.0 0.G 0,0 0.0 8.0
PM2.5 0.0 0.3 0.0 v.G 0:0 8.0
5Ox 9.0 0.0 G.0 0.0 0.0 0.6
NOx 0.4 0.0 0.G 0.8 0.4 72,6
VOC 204.7 0.0 U.S 204.7 10.2 1738.5
CO 2.0 0,1 0,1 20 2.0 332.2
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
Ohs/year) (lbs/year) (Ibs/year) Ohs/year) (Ibs/year)
Benzene 2574.6 50 0.3 2574,5 126.7
Toluene 2613.. 3.0 C 0 2613.1 130-7
Ethylbenzene 2072.E 0.0 0.0 2372.5 103,€
2 of 14 C:\Users\Ilakocy\Desktop\Remote Working Docs\Package 421273\19WE1009.CP1
Storage Tank(s)Emissions inventory
Xylene 332.3 0.0 0,0 1332.3 65.6
n-Hexane 13'� 4.5 4.s': 0.0 130945 659.7
224 TMP 2070.9 0,0 0.0 2078.9 103.9
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3 of 14 C:\Users\Ilakocy\Desktop\Remote Working Docs\Package 421273\19W E1009:CP1
Storage Tank(s)Emissions inventory
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Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B Source reunites a permit
Regulation 7,Part D,Section I.C,D,E,F Storage tank is subject to Regrua.fon 7,:Bari O,SneUon l.C-F
Regulation 7,Part 0,Section.I.G,C 590 age Tank is not su':;jec_to Regulation 7,Section I.G
Regulation 7,Part D,Section II.B,Cl,, C.3 Storose tona is sutgect to qe.g:_:Z1,1011 7,Part O,Section II,B,C
Regulation 7,Part O,Section II.C.2 Sbotrega tank is sciaritost to Rept...ion ,Par'_n,Seaton II.C.2
Regulation 7,Part D,Section 11.C.4.a.(i) to Regulation 7,Part D.Section il.0-.ail
Regulation 7,Part D,Section ll.C.4.a.(ii) Storage Tank is eo s,.v,-c.to RPSU_tron 7,Paat't D ec:or l'- 4 f.0,;.Regulation 6,Part A,NSPS Subpart Kb Storage Tani,is of su ject to POPS Kb
•
Regulation 6,Part A,NSPS Subpart 0000 Storage tank is not subject o 105 05 0000.
NS PS Subpart 0000a 5tu333e Tanjt is not subectnc N5 53000a
Regulation 8,Part E,MACC Subpart FIR Storage Tatitkic no,sublet's to MACS NH
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial and Periodic Sampling and Testing Requirements
For condensate or crude oil tanks,does the company use the state default emissions factors to
estimate emissions? - •
If yes,are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the
99316193
uncontrolled actual or requested emissions for a condensate storage tank estimated to he greater than or equal to 80 tpy? f• ,
If yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company use a site specific emissions factor to estimate emissions?
Astfataragagsgs
If yes and if there are flash emissions,are the emissions factors based on a pressurized liquid sample drawn at the facility being
permitted(for produced water tanks,a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample
should he considered representative which generally means site-specific and collected within one year of the application received
date.However,if the facility has not been modified(e.g.,no new wells brought on-line),then it may be appropriate to use en
alder site-specific sample.
If no,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company request a control device efficiency greater than 95%for a flare or combustion device? 733k9t93133939.4.99334193
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Setion 08-Technical Analvsi Notes •
The vowme or waste gas per bbl crude oil throughput was calculated based on the W inSim outputs;=(387.912)/718345+(943124/(128726)/69)'379 6 5 83 ct/bbl The source calculated a more tonservativegas to oil
ratio(clash emissions GOR.6.335500534)and requested that the permitted limits reflect this more conservative value.The va Otte adore reflects the total contributions from t asit and working/breathing emissions
The ang/b athingcontrbtwbons,o the(005 were calculated using the following vanes:l/(0.0366 lb/scf).5 tanks`9,431i b/yeardvided by 8760 hours.According to my calculation,the yii.is an scr/hrvalue of
147 sof/hr.The source appears to have a slrgh.,y lower calculation,but ail-in-all(considering the more conservative.lash),the GOR Brood above s considered d acceptable as is ft within 00'of what n y calculations
yi=Id.
The course is tra_xrng throughput for the stm agetanks based on,he total o I throughput from ail the lipeporators at tr e s ite The meter locations tracking this throughput is located in the original pet ran .
application.The source used a sample taken at the outlet of the HP separator as the site to model the emissions from the tan it.Per the init.{issuance of this perm t,the source will be required to demonstrate
pit
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
• Uncontrolled
Emissions
AIRS Point If Process if SCC Code Pollutant Factor Control% Units
Os:1 01 PMIO 0-00 0 lb/1,000 gallons Crude Oil throughput
PM2.5 0.30 0 lb/1,000 gallons Crude Oil throughput
SOx 'REF 7 I6/1,000 gallons Crude Oil throughput
NOx C.0. 9 lb/1,000 gallons Crude Oil throughput
VOC 13,14 95 lb/1,000 gallons Crude Oil throughput
CO 0.14 _ lb/1,000 gallons Crude Oil throughput
Benzene 0.13 95 lb/1,000 gallons Crude Oil throughput
Toluene 0.10 -95 lb/1,000 gallons Crude Oil throughput
Ethylbenzene 0.08 95 16/1,000 gallons Crude Oil throughput
Xylene 0.05 RS Ib/1,000 gallons Crude Oil throughput
n-Hexane 0,49, 95 lb/1,000 gallons Crude Oil throughput
224 TMP _O,OB OS lb/1,000 gallons Crude Oil throughput
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Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Re
rt mPm Re u
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2TPY(Regulation 3,Part A,Sedlon 11.0.14? Source Requires an APES.Gota
2. Is the construction date prior to 4/14/2014 and not modified after4/14/14 with a storage tank throughput less than 90,000 gallons per year(See PS Memo 1403 for additional guidance on grandfather applicability)? Go to next question
3. Are total facility uncontrolled VOC emissions ereaterthan SIPS,NOx greater than 10TPY or CO emissions greater than nu TPY(Regulation 3,Part B,Section 11.0.3)? Source Requires a permit
1Vga have 1nd:caid that yaw,sin the Nort.fittatnnwrg Area
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than LTPY(Regulation 3,PartA,Section 11.0.1.a)? +Source Requires an APEN.Go to
2. Is the construction date prior to 4/14/2014and not modified raker 4/14/14wi[h astaraeetankihroughput lessthan ae,ow gallons per year(See PS Memo 1403for additional guidance on grandfather applicability)? . Go to next question
3. Are total fedlny uncontrolled VOC emissions greater than 2TPY,NOe greater than STPY or CO emissions greater than so TPY(Regulation 3,Part B,Section 11.0.2)7 Source Requires aperme
Colorado Regulation].Part 0,Section I.C-F&G
1. Is this storage tank located in the 8-hr ozone control area or any ozone non-attainment area orattainment/maintenance area(Regulation 7,Part D,Section l.A.11? scs Continue-You have indicatedth
2. Is this storage tank located at oil and gas operations that coiled,store,or handle hydrocarbon liquids or produced water ANDthat are located at or upstream of a natural gas processing plant(Regulation 7,Part D,Section lull? Yes Continue-You have indicated th
3. Isthis storage tank located at a natural gas processing plant(Regulation 7,Part 0,Section 1.6)7 n.. Storage Tank is not subject to Re
4. Does this storage tank contain Condensate? +Nc
5. Does this storage tank exhibit"Flash"(e.g.storing non-stabiibed Ilquids)emissions(Regulation 7,part D,Section 1.6.2)7 Yes
6. Are uncontrolled actual emissions of this storage tank equalto or greater than 2tons per year VOC(Regulation 7,Part O,Section l.0.3.a(ii))?
Sroraw
..nit is svb;ecito Wriula cn:,Tar.:,Session '-
Part 0,SectionI.C.1-General Requirements for Air Pollution Control Equipment-Prevention of Leakage
Part 0,Section I.C.2-Emission Estimation Procedures •
Part 0,Section 1.0-Emissions Control Requirements
Part D,Section LE-Monitoring
Part e,Section I.F-Recordkeeping and Reporting
In500a eeihiew So-ragrSa
Part D,section I.G.2-Emissions Control Requirements
Parte,Section I.C.1.a and b-General Requirements for Air Pollution Control Equipment-Prevention of Leakage o
Colorado Regulation],Part Cr.Section 11
1. Is this storagetank located at atransmission/storagefaciltty7 No Continue-You have indicatedth
2. Is this storage tank'located at an oil and gas exploration and production operation,well production facilvy',natural gas compressor station'or natural gas processing plant°(Regulation 7,Part D,Section ll.Cl? Vgs Go to the next question-You ha
3. Does tho storage tank have a fixed roof(Regulation 7,Part e,Section ll.0.20)? WAWA.Go to the next question
4. Are uncontrolled actual emissions of this.storagetankequalto or greater than 2tons per year VOC(Regulation 7,Part D,Section ll.C.1.c)? dt.166lirkwl Source Is subject to parts of Regi
I,a'- =,,ki_verrruncguia'.'Ean 7.Part C-.Section'.=.B.CO&C.3
Part D,SectionIO.B-General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part 0,Section III.C.1-Emissions Control and Monitoring Provisions
Part 1,Section W-C.3-Recordkeeping Requirements
5. Does the storage tank contain only"stabilized"liquids(Regulation 7,Parts Section ll.0 2.b)? nlri/ts, Source Is subject to all provsion
gtrabaet k Essataaw ttt gay,lation2.2att -_
Part D,Section II.C.2-Capture and Monitoring for Storage Tanta fitted with Air Pollution Control Equipment
Is the contralledstoragetank located at a well production facility,natural gas compressor station,or natural gas processing plant constructed an or after May 1,2020 or located at a facility that was modified on or after May 1,2020,such }}}"'.
6. that an additional t ll d storage vessel is construrtedtoan anticipatedincreasein throughput of hydrocarbon liquids or produced water(Regulation 7,Part 0,Section llC.9.a(l7 rd`is^.F', Storage Tank is not subject to Re
IStatage Yank oot subts,-, itgattatian PartIt_S ILCAstti
Isthe contralledstorage tanklocated at a wellproduction facility, t l gas compressorstaton,or natural gas processing plant constructed on or afterlanuary 1,2021 or located at afaclty that was modified on or after January 1,
7. 2021,such that an additional controlled storage vessel is constructedt receiVe an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7,Part D,Sectoo Il.C4a.l)?
'Storage ,.D,Secttort v GA
40 CFR,Part 60.Subpart Kb,Standards of Performance for Volatile Oneanic liquid Storage Vessels
1. Is the individual storage vessel capacity greater than or equal to 75 cublcmeters(m'1[6472 BBLs](40 CFR 60.110h(a))? 70Go to the next question
2. Does the storage vessel meet the following exemption in 60.111h(d)(4)? WAS*Storage Tank is not subject WE
a.Does the vessel has a design capacity less than or equal to 1,589.874ms("10,OOO BBL]used for petroleum'or condensate stored,processed,or treated prior to custody transfer'as defined In 60.111b7
3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after July23,1984(40 CFR 60.110b(a))7 .. .
4. Does the tank meet the definition of"storage vessel'in 60.11167
5. Does the storage vessel store a"volatile organic liquid(VOLT"'as defined In 50.111b?
6. Doesthoesorage vessel meet any one of the following additional exemptions: 4`
a.la the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa(-29.7 psi]and without emissions to the atmosphere(60.110b(d)(2)17;or farWl egOrl
b.The design capacity a greater than or equal to 151 m'['950 BBL]and stores a liquid with a maximum true vapor pressure`less than 3.5 kPa(60.110h(b)l?;or
c.The design capacity is greater than or equalto 75 M'[-472 BBL]but less than 151 m'["950 BBL]and stores a liquid with a maximum true vapor pressures less than 15.0 kta(60.110blbll?
7. Does the storage tank meet either one ofthefollowing exemptions from control requirements:
a.The design capacity is greater than or equal to 151m[-BSO BBL)and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa but less than 5.2kPa7;or
b.The design capacity Is greater than or equal to 75 Mc[-472 BBL]but less than 151 m'I9513 BBL]and stores a liquid with a maximum true vapor pressure greaterthan orequal to 15.0 kPa but lessthan 27.6 kPa7
liar, unk..is!fin subieet Psi._
90 CFR.Part 60.Subpart 0000/0000a,Standards of Performance for Crude 011 and Natural Gas Production.Transmission and Distribution
1. Is this storage vessel located at a facility in the onshore oil and natural gas production segment,natural gas processing segment or natural gas transmission and storage segment of the industry? Continue-You have indicatedth
2. Was this storage vessel constructed,reconstructed,or modified(see defnhions 90 CFR,6u.2)between August 23,2011 and September 18,2013? gregny Storage-rank's not subject NSPS
3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after September 18,2015? 1''E5..,.,.`n`Goto the next question
4. Are potential Von emissions'from the individual storage vessel greater than or equal to 6 tons per year? l6iC7,tt.4i Storage Tank is not subject NSPS
5. Does this storage vessel meet the definition of"storage vessel"'per 60.5430/60.5430a? W.n
6 Is the storage vessel subject to and controlled In accordance with requrements for storage vessels In 40 CFR Part 60 Subpart Kb or aft CFR Part 63 Subpart HH? tddy ,.a
Itrvroge rank,rs.su,,r is iitPS O00Crs
[Note:If a storage vessel is previously determined to be subjectto NSPS 0000/0000a due to emissions above 6 tons per year VOC on the applicability determination date,It should remain subjectto NSPS 0000/0000a per
60.5365(e)(1)/60.5365a(e)(2)even if potential VOC emissions drop below 6 tons per year]
40 CFR,Part 63,Subpart MALT HH,Oil and Gas Production Facilities
1. Is the storage tank located at an oil and natural gas production faollitythat meets either of thefollowing criteria: Ives 'Continue-You have indicated th
a.Afacility that processes,upgrades or stores hydrocarbon liquids'(63.760(a)(2));0R
b.Afaoilitythat processes,upgrades or stores natural gas prior to the paint at which natural gas enters the natural gastransmission and storage source category or is delivered to afinal end user'(53.760(a)(3)1?
2. Is the tank located at a facility that is major'for HAPs? NMI Storage Tank Is not subject MAC
3. Does the tank meet the definition of"storage vessel"'in 63.761?
4. Does the tank meet the definition of"storage vessel with the pvtentialfar flash emissions"'per 63.7617 D ..
5. Is the tank subject to control requirements under 40 CFR Part 60,Subpart Kb or Subpart 00007 ,5151
ISlu g
SubpartA,General provisions per 463.764(a)Table 2
§63366-Emissions Control Standards
§63.773-Monitoring
§63.879-Recordkeeping
§63.f]5-Reporting
RACT Review
RACT review is required if Regulation]does not apply AND if the tank is inthe norr'attainment area.If the tank meets both criteria,then review RAC"requirements.
Disclaimer
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•
This.document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This document is not •
a rule or regulation,and the analysis it contains may not apply to a particular situation based upon the individual facts end circumstances.This document does not change or substitute for any law,regulation,
or any other legally binding requirement and is not legally enforceable.In the event of any conflict between the language of this document and the language of the Clean Air Act„its implementing regulations,
and Air Quality Control Commission regulations,the language of the statute or regulation will control.The use of non-mandatory language such as"recommend,""may,""should;"and"can,"is intended to •
describe APCO interpretations end recommendations.Mandatory terminology such as"must"and"required"are intended to describe controlling requirements underthe terms of the Clean Air Act and Air
Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself
Tank Calculation Verifications
Mass flow from HYSYS Model,working/breathing emissions from Tanks 4.0.9d model
Compound Mass Flow(lb/Hr) Emission Factor(lb%of VOC Total (W/B/Flash)
H2S 0.000000
Nitrogen 0 0.000000
CO2 0.551516000 0.007506
CH4 1.66273 0.022630
Ethane 5.4444 0.074100
Propane 14.4835 0.197124
Isobutane 2.5013 0.034043 5.938
Butane 10.1618 0.138305 24.122
Isopentane 2.67413 0.036396 6.348
Pentane 4.0500 0.055122 9.614
Methylpentane 1.196825 0.016289 2.841
n-Hexane 1.35597 0.018455 3.219 0.020451
Cyclohexane 0.30746 0.004185 0.730
Methylcyclohexane 0.00000 0.000000
Heptane 3.06298 0.041688 7.271
2,2,4-Trimethylpentane 0.2138870 0.002911 0.508 0.003226
Benzene 0.265261 0.003610 0.630 ° 0.004001
Toluene 0.269234 0.003664 0.639 0.004061
Ethylbenzene 0.2134150 0.002905 0.507 0.003219
xylene 0.137417 0.001870 0.326 0.002073
Octane 0.83716 0.011394 1.987
Nonane 0.172186 0.002343 0.409
Decanes+ 0.223620 0.003044 0.531
VOC's 42.126108 0.573 0.635
Total 49.784774
%VOC 84.6164492
Hours/Year 8760
Throughput(bbl/yr) 643632
VOC w/b (Ib/bbl)* 0.061995093
*Considers VOC%
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Separator Venting Emissions inventory
Section 01-Administrative Information
" s
Facility AIRs ID:
County Plant Point
Section 02-Equipment Description Details
Detailed Emissions Unit Description: Mitarif.fietAiiire .:::: 7.:4%•''. •
Emission Control Device Description: '
Requested Overall VOC&HAP Control Efficiency%:
Limited Process Parameter ,-
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Separator
Actual Throughput=0X,VitAlCiff•A Barrels(hbl)per year
Requested Permit Limit Throughput.)4tegoogpx.Barrels(bbl)per year Requested Monthly Throughput= 5466.4 Barrels(bid)per month
Potential to Emit(PIE)Throughput= 64363.0 Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)for Air Pollution Control
Separator Gas Heating Value:
Volume of waste gas emitted per BBL of ne1i.,
liquids throughput: scf/bbl
Control Device
Pilot Fuel Use Rate: 4 scfh 0 4 MMscf/yr
Pilot Fuel Gas Heating Value: iUs Btu/scf
Section 04-Emissions Factors&Methodologies
Descrip!io!!
ItriS , 470"7. 1#0"ttf:/:*, ,10004::.W#0,0.,1,00.0370A-VOSAtf,hith,P*!crC j41, . „ ,..-
01149Arisit et* -oogAgrdv4v:,ivg,?-;.. „mordvatitewooim*ski ad, givp,1310. 041*
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8 of 14 CALlserAllakocy\Desktop\Remote Working Does\Package 421273\19WE1009.CP1
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Separator Vert:rg Ernrss ors ErventJry
Uncontrolled Controlled
Pollutant (Ib/bbl) (Ib/bbl) Emission Factor Source
(Liquid Throughput) (Liquid Throughput)
Primary Control Device
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) Ih/bbl Emission Factor Source
(Waste Heat
Combusted) (Gas Throughput)
ris
INEEIZI v'..3G tPIr
;r:re
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant M113Emission Factor Source
(Waste Heat
Comhusted) (Pilot Gas Throughput)
,4 i, ?6 ,„
14#,i,2'*a,z�r
4 _
1
7'0'44-"ft-ci',:old 4
Section OS-Emissions Inventory
Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits
Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled
(tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month)
PM10 0,6 6,0 0.0 0.6 _,_ 3
PM2.5 0.0 0.0 9 3 9.0 c.; 3
SOx -... ,_ n0 0,0 0
NOx _._ 0.0 _.r 0.2 0.2 29
VOC 37.4 c,a 82.4 4.1 Cl,,
CO _.3 0.1 0.3 0,5 152
Potential to Emit Actual Emissions Requested Permit Limits ,
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(lbs/year) (lbs/year) (lbs/year) llbs/yearl (lbs/year)
Benzene 995 O 0 985 49
Toluene 3904 0 0 1000 50
Ethylbenzene 790 0 0 799 SO
Xylene 512 0 0 5O2, 26
n-Hexane t,,.; 0 0 6452 253
224 TM 0 0 75 u_
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B onurne requires 0 permit
Regulation 7,Part D,Section 11.B,F Source is subject to yegaiatirra 7,Part D,Sect:00 1€.0-2,F
Regulation 7,Part D,Section II.B.2.e "he cantral device foe this seuaratar;s not stiL ect to Regniation 7,Part 11,Section 0.5'2,
(See regulatory applicability worksheet for detailed analysis)
9 of 14 C:\Users\Ilakocy\Desktop\Remote Working Docs\Package 421273\19W E1009.CP1
Separator Venting Efm=ss.,,'t>
Section 07-Initial and Periodic Sampling and Testing Requirements
Section
Initial
a� ri;a'tifHj;";%"tealing �'. ( {w'/v' 'r r-
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VNAMONINSWr Yr,".A .F: , %r :. .::, „v, .:;,a- :Ay:.,H _f r;y£vvrf"", 3.5> _•'�i6'1'f �.
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.9 x, n,4�,. / li
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a^.,.a
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' is..4'✓G,"r;'o:,;J,'�,,,.2' it ..,,, ..�•1,+r� ,. ., .gi$'„✓idf,�1,33^
Using Liquid Throughput to Monitor Compliance
Does the company use site specific emission factors based on a pressurized liquid sample(Sampled upstream of the
equipment covered under this AIRS ID)and process simulation to estimate emissions?
This sample should have been collected within one year of the application received date.However,if the facility has not been modified(e.g.,
no new wells brought on-line),then it maybe appropriate to use an older site-specific sample
If no,the permit will contain an"Initial Compliance"testing requirement to collect a site-specific liquid sample and conduct an emission
factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application.
Does the company request a control device efficiency greater than 95%for a flare or combustion device?
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08-Technical Analysis Notes
Because this source used a renresentatrve sample from a dri'erent site,this facility is going to have an initial testing requirement The source has statea that a gas sample of the commragieI halt/test VRT gas stream can be sample d and
compared against the weight fract.ons thus resulted from the HVSYS modeling If the source samples the gas and it is greaterthan the weight compositions oPt is modeled gas then the source will be iequ:red?o subimta new A'Ctd to update
the emissions,either based on that sample and/or updated modeling from a pressor<ed liquid sample taken from outlet of the LP separator onste 1 he source may need to take trustipiepressurrzed liquid samples or order apnrop Hate ly
detereune the emissions from both the bulk and test Vials
This source was constructed prior to the issuance ofth s permit and as such,was unable to install a gas flow meter to monitor the volume of gas vetted trom these points Because ofthis,the source will use liquid throughput to demonstrate
cornphar ce with the requested perrmt'rove Also,berarise the source's controlled emissions are not near major source flirt sholds,there is note significant advantage seen five requiring the source to pursue a facility retrofit to install a gas
flow meter,which may be costly and may have some technical hmfta uons.
This source;s controlled by 2 enclosed combustion eevices,with an alternative option to have the gas routed to the ELD's with control Ere stoi age tanks Those 2 ECDc are accounted for under the storage cares The combustion of pilot fuel for
the control devices used to control Lne VREs does not change the permitted emissions limits-in fact,the NOx and CO emissions are below reporting threshold I lea'ever,this permit'cdl till contain a permitted lie.tforthe plot fuel:.sage,it
will rot contain separate calculation r-ethods orrtlmed fo:the,srr,rhustion of plot fuel as that is considered insignificant in this instance
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
AIRS Point# Process# SCC Code Pollutant Uncontrolled Emissions Factor Control% Units
002 01 3-10-001-25 Oil&Gas Pradoctscrr.Cias;3=quid sepzrafeon PM1O C.a 0 __,_.,,_ sat
PM2.5 O.h 0
SOX 0.0
NOx 5.3 0 5 -_ ..es
VOC 2560.0
CO 24,1 0 _ _`?c,aort's
Benzene 15.3 95 132'aarrsls
Toluene 15 6 95 1040 hot'`C.s
Ethylbenzene 12.4 95 Ib/1000 barrels
Xylene 8 0 93 lb/1000 aarrels
n-Hexane 78.5 95 ib/l000 burials
224 TMP 12.a 95 .b/'300 barrels
10 of 14 C:\Users\Ilakocy\Desktop\Remote Working Docs\Package 421273\19WE1009.CP1
`
Separator Calculation Verification
Mass Flow from HYSYS model submitted with application
Compound Mass Flow(lb/Hr) Emission Factor(lb/bb|)
M2S 0.000
Nitrogen 0.000
[02 3.35108 0.046
CH4 18.1061 0.246
Ethane 313485 0.427
Propane 68,657 0.933 �
�
|sobutane 11.1244 0.151
Butane 44,62 0.607
|sopentane 1I.4858 0.156
Pentane 173507 0236 �
xN ethyl cydopontane 5.09511 0.069
n'Heoane 5.76767 7.850E'02
Cydohemane 130588 0.018
K8eChylcyc|ohexane O 0.000
Heptane 13D269 0.177
2,2,4'Trinnethy|pentane 0.939293 0.012
Benzene 1.13E+00 1.534E'02
Toluene 1.14336 1.556E'02
E1hy|benoene 9.08E'01 1.236E'0I
xylene 5.85E-01 7.960['03
Octane 3.57E+00 0.049
Nonone 7.36E'01 0.010
Qecanes+ 9.63E-01 0.013
V0C'u 188271711 2.562
Total 241.069391
Hours/Year 8760
Throughput(6bl/yr) 643632
•
Separator Venting Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts A and B-APEN and Pemrit Requirements
ISsorse t se';. an.Lima
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section ll.D.1.a)?
2. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOR greater than lO TPY or CO emissions greater thee 10 TPY(Regulation 3,Part B,Section ll.0.3)?
Ivou_,e wind'atei source isin Sim No,-cAtHirment Ares'.
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY(Regulation 3,Part A,Section llDla)? kyl, '5u R
2. Are total facility uncontrolled VOCemissions from the greater than 2 TRY,NOR greater than 5 TPY or CO emissions greater than lO TPY(Regulation 3,Part B,Section ll.D.2)? ;r`'cy riv.Source Re
!Saurc >s permit
Colorado Regulation 7,Part D,Section II
1. Was the well newly constructed,hydraulically fractured,or recompleted on or after Augustl,2014? '¢s°'-";} J5 pce
iSoutot tabiiect_...a€isle=an 7,Part D,Sactlan11,11,2,F
Section Il.B.2—General Provisions for Air Pollution Control Equipment Used to Comply with Section II
Section lI.F-Control of emissions from well production facilities
Alternative Emissions Control(Optional Section)
a. Is this separator controlled by a back-up or alternate combustion device(i.e.,not the primary control device)that is not enclosed? - iyJThe contr,
devise his sePor Via_- fr geta€Ias G.Sacticn i1.3.2.e
Section II.B.2.e—Alternative emissions control equipment
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This document is
not a rule or regulation,and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances.This document does not change or substitute for any law,
regulation,or any other legally binding requirement and is not legally enforceable.In the event of any conflict between the language of this document and the language of the Clean Air Act„its implementing
regulations,and Air Quality Control Commission regulations,the language of the statute or regulation will control The use of non-mandatory language such as"recommend,""may,"should,"and"can,"is
intended to describe APCD interpretations and recommendation.Mandatory terminology such as must"and"required"are intended to describe controlling requirements under the terms of the Clean Air
Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself.
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
FACILITY EMISSION SUMMARY
Company Name Bison Oil 1S Gas II,LLC
County AIRS ID 123 History File Edit Date 611112020
Plant AIRS ID A0A1 Ozone Status Non-Attainment
Facility Name Boomslanq 14B Tank Battery Last Modified By: Lauraleigh Lakocy
EMISSIONS-Uncontrolled(tons per year) EMISSIONS With Controls(tons per year)
POINT PERMIT Description PM10 PM2.5 H2S SO2 NOx VOC Fug CO Total PM10 PM2.5 H2S SO2 NOx VOC Fug CO Total REMARKS
AIRS ID. VOC HAPs VOC HAPs
Previous FACILITY TOTAL 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 0.0 0.0 0.0 0.0 New Facility-No Previous"Fetal
Previous Permitted Facility total 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 0.0 0.0 0.0 0.0
001 19WE1009 Crude Oil Tanks{5-750 bhl) - _ 0.4 205.0 2.0 11.9 0.4 10.2 2.0 0.6_Newly requested point
002 '19WE1009 VRT Separator Venting?during VFdl1 0.2 82.5 0.7 4.6 0.2 4.1 0.7 0.2 Newly requested point
003 GPO Produced Water'Tanks(3--750 bbl) 0.9 64.0 4.1 7.1 0.9 5.9 4.1 0.4 Newly requested peed,State Efs
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
0.0 0.0
-
0.0 0.0
•
•
FACILITY TOTAL 0.0 0.0 0.0 0.0 1.5 351.5 0.0 6.8 23.6 0.0 0.0 0.0 0.0 1.5 20.2 0.0 6.8 1.2 VOC: Syn Minor(NANSR and OP)
NOx:True Minor(NANSR and OP)
CO: True Minor(PSD and OP)
HAPS: Syn Minor n-hexane
•
Permitted Facility Total 0.0 0.0 0.0 0.0 1.5 351.5 0.0 6.8 23.6 0.0 0.0 0.0 0.0 1.5 20.2 0.0 6.81 1.2 I Excludes units exempt from permits/APENs
(A)Change in Permitted Emissions 0.0 0.0 0.0 0.0 1.5 20.2 0.0 6.8 Pubcom required because new syn minor permit
limits.Modeling not required based on division
'guidelines.
Total VOC Facility Emissions(point and fugitive) 20.2 Facility is eligible for GP02 because<45 tpy
•
(A)Change in Total Permitted VOC emissions(point and fugitive) 20.2 Project emissions less than 25/50 tpy
•
Note 1
Note 2
•
•
Page 13 of 14 Printed 2/6/2021
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY-HAPs
Company Name Bison Oil&Gas II,LLC
County AIRS ID 123
Plant AIRS ID A0A1
Facility Name Boomslang 14B Tank Battery
Emissions -uncontrolled(lbs per year)
POINT'PERMIT 'Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP H2S TOTAL(tpy)
Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0
001 19WE1009 Crude Oil Tanks(5-750 bbl) 2578 2616 2074 1335 13177 2078 11.9
002 19WE1009 VRT Separator Venting during VRU downtime 987 1002 796 512 5054 797 4.6
003 GP08 Produced Water Tanks(3-750 bbl) 3418 10743 7.1
0.0
_ 0.0
0.0
_ 0.0
0.0
0.0
0.0
0.0
0.0
TOTAL(tpy) 0.0 0.0 0.0 3.5 1.8 1.4 0.9 14.5 0.0 1.4 0.0 0.0 23.6
I
*Total Reportable=all HAPs where uncontrolled emissions>de minimus values
Red Text: uncontrolled emissions<de minimus
Emissions with controls(lbs per year)
POINT'PERMIT (Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224TMP H2S TOTAL(tpy)
Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0
001 19WE1009 Crude Oil Tanks(5-750 bbl) 129 131 104 67 659 104 0.6
002 19WE1009 VRT Separator Venting during VRU downtime 49 50 40 26 253 40 0.2
003 GP08 Produced Water Tanks(3-750 bbl) 171 537 0.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
TOTAL(tpy) 0.0 0.0 0.0 0.2 0.1 0.1 0.0 0.7 0.0 0.1 0.0 0.0 1.2
14 19WE1009.CP1 .2/6/2021
QUANDARY 55 East 4t^Avenue
Denver,CO 80203
0;J TA T www.quandaryconsultants.com
October 14,2019
Colorado Department of Public Health&Environment
APCD-SS-B1
t;"
4300 Cherry Creek Drive South Iy1 G a
Denver,CO 80246-1530
Subject: APENs and Permit Application
Boomslang 14B Tank Battery
To Whom It May Concern:
Quandary Consultants is submitting the enclosed air permit application for the new source"Boomslang 14B Tank
Battery"well production facility in Weld County,CO on behalf of Bison Oil&Gas II,LLC(Bison).Bison requests that
all points in this permit application not requested under a General Permit be permitted with a single facility-wide
air permit.
This permit application is being submitted before startup of the facility so site-specific emission factors have been
developed based on samples taken from the Castor 8-59 19 well production facility nearby(2.2 miles southwest of
Boomslang 14B Tank Battery)also owned and operated by Bison.Site-specific samples for this Boomslang 14B
Tank Battery will be taken and used to develop site-specific emission factors once production stabilizes at the site,
as a part of the self-certification process for the points at this site.
Emission calculations,emission factor development documentation,Facility Wide Emission Inventory form,APEN
forms,and other required application paperwork has been included in this package.Payment for APEN and Permit
application fees totaling$885.89 have also been included.Bison requests that the following emissions points are
permitted as listed:
Emissions Points Summary—Boomslang 14B Tank Battery
Emissions Point Description Permit Requested
Crude Oil Tanks Four(4)750-bbl atmospheric bulk crude oil storage tanks,and
one(1)750-bbl atmospheric test crude oil storage tank Individual
VRT Venting Bulk VRT and Test VRT during period of VRU downtime Construction Permit
Produced Water Tanks Three(3),750 bbl atmospheric produced water storage tanks GP08
Please contact Shannon McKibben(Quandary Consultants)at 720.937.5429 or
smckibben@quandaryconsultants.com with any questions or comments about this permit,or to request additional
information.
Sincerely,
Shannon McKibben
Environmental Engineer,Quandary Consultants
720.937.5429 I smckibben@quandaryconsultants.com
CDPHE COLORADO
Form APCD-10000 Department of Public
L Health & Environment
Oil & Gas Industry
Construction Permit Application Completeness Checklist
Ver.November 29,2012
Company Name: Bison Oil & Gas II LLC
Source Name: Boomslang 14B Tank Battery
Date: 10/14/2019
Yes No
Are you requesting a facility wide permit for multiple emissions points?
In order to have a complete application,the following attachments must be provided,unless stated
otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded.
Attachment Application Element Applicant APCD
A APEN Filing Fees 0
B Air Pollutant Emission Notice(s) (APENs) & ❑ n
Application(s) for Construction Permit(s)—APCD Form Series 200
C Emissions Calculations and Supporting Documentation ❑ n
D Company Contact Information-Form APCD-101 Q
E Ambient Air Impact Analysis En C
❑ Check here if source emits only VOC(Attachment E not required)
F Facility Emissions Inventory—Form APCD-102 El
nCheck here if single emissions point source(Attachment F not required)
G Process description, flow diagram and plot plan of emissions unit and/or ® n
facility
❑ Check here if single emissions point source(Attachment G not required)
H Operating&Maintenance(O&M) Plan—APCD Form Series 300 En
® Check here if true minor emissions source or application is for a general
permit(Attachment H not required)
I Regulatory Analysis E ❑
❑ Check here to request APCD to complete regulatory analysis
(Attachment I not required)
Colorado Oil and Gas Conservation Commission(COGCC) 805 Series Rule ❑
Requirements—Form APCD-105
❑ Check here if source is not subject to COGCC 805 Series requirements
(Attachment J not required)
Send Complete Application to: Colorado Department of Public Health&Environment
APCD-SS-B I
4300 Cherry Creek Drive South
Denver,Colorado 80246-1530
Check box if facility is an existing Title V source: ❑ Send an additional application copy
Check box if refined modeling analysis included: ❑ Send an additional application copy
Check box if application is for major NA NSR or PSD permit: ❑ Send eight(8)total application copies
Page I of 1 FonnAPCD-100-AppCompleteChecklist-Ver.11-29-2012.docx
TANKS 4.0.9d
Emissions Report- Detail Format
Tank Indentification and Physical Characteristics
Identification
User Identification: Boomslang 14B
City: Denver
State: Colorado
Company: Bison Oil&Gas II,LLC
Type of Tank: Vertical Fixed Roof Tank
Description: Boomslang 14B Single Tank(750 bbl)
Tank Dimensions
Shell Height(ft): 24.00
Diameter(ft): 15.50
Liquid Height(ft): 13.00
Avg.Liquid Height(ft): 8.00
Volume(gallons): 18,349.74
Turnovers: 294.64
Net Throughput(gal/yr): 5,406,509.00
Is Tank Heated(y/n): N
Paint Characteristics
Shell Color/Shade: Gray/Medium
Shell Condition Good
Roof Color/Shade: Gray/Medium
Roof Condition: Good
Roof Characteristics
Type: Cone
Height(ft) 0.00
Slope(ft/ft)(Cone Roof) 0.06
Breather Vent Settings
Vacuum Settings(psig): -0.03
Pressure Settings(psig) 0.50
Meterological Data used in Emissions Calculations:Denver,Colorado(Avg Atmospheric Pressure=12.12 psia)
TANKS 4.0.9d
Emissions Report- Detail Format
Liquid Contents of Storage Tank
Boomslang 14B-Vertical Fixed Roof Tank
Denver, Colorado
Liquid
Daily Liquid Surf. Bulk Vapor Liquid Vapor
Temperature(deg F) Temp Vapor Pressure(psia) Mol. Mass Mass Mol. Basis for Vapor Pressure
Mixture/Component - Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract. FracL Weight Calculations
Gasoline(RVP 6) All 60.36 47.87 72.86 53.29 2.9568 2.2667 3.8093 69.0000 92.00 Option 4:RVP=6,ASTM Slope=3
TANKS 4.0.9d
Emissions Report - Detail Format
Detail Calculations (AP-42)
Boomsiang 14B-Vertical Fixed Roof Tank
Denver,Colorado
Annual Emission Calcaulations .
Standing Losses(lb): 2,379.9753
Vapor Space Volume(cu ft): 3,049.5364
Vapor Density(lb/cu ft): 0.0366 -Vapor Space Expansion Factor: 0.2066
Vented Vapor Saturation Factor: 0.2831
Tank Vapor Space Volume:
Vapor Space Volume(cu ft): 3,049.5364
Tank Diameter(ft): 15.5000
Vapor Space Outage(ft): 16.1615
Tank Shell Height(ft): 24.0000
Average Liquid Height(ft): 8.0000
Roof Outage(ft): 0.1615
Roof Outage(Cone Roof)
Roof Outage(ft): 0.1615
Roof Height(ft): 0.0000
Roof Slope(ft/ft): 0.0625
Shell Radius(ft): 7.7500
Vapor Density
Vapor Density(lb/cu ft): 0.0366
Vapor Molecular Weight(lb/lb-mole): 69.0000
Vapor Pressure at Daily Average Liquid
Surface Temperature(psia): 2.9568
Daily Avg.Liquid Surface Temp.(deg.R): 520.0337
Daily Average Ambient Temp.(deg.F): 50.2125
Ideal Gas Constant R •
(psia cuft/(Ib-mol-deg R)): 10.731
Liquid Bulk Temperature(deg.R); 512.9625
Tank Paint Solar Absorptance(Shell): 0.6800
Tank Paint Solar Absorptance(Roof): 0.6800
Daily Total Solar Insulation
Factor(Btu/sgft day): 1,568.5833
Vapor Space Expansion Factor
Vapor Space Expansion Factor: 0.2066
Daily Vapor Temperature Range(deg.R): 49.9838
Daily Vapor Pressure Range(psia): 1.5427
Breather Vent Press.Setting Range(psia): 0.5300
Vapor Pressure at Daily Average Liquid
Surface Temperature(psia): 2.9568
Vapor Pressure at Daily Minimum Liquid
Surface Temperature(psia): 2.2667
Vapor Pressure at Daily Maximum Liquid
Surface Temperature(psia): 3.8093
Daily Avg.Liquid Surface Temp.(deg R): 520.0337
Daily Min.Liquid Surface.TOMO.(deg R): 507.6378
Daily Max,Liquid Surface Temp.(deg R): 532.5297
Daily Ambient Temp.Range(deg.R). 27.9417
Vented Vapor Saturation Factor
Vented Vapor Saturation Factor; 0.2831
Vapor Pressure at Daily Average Liquid:
Surface Temperature(psis): 2.9568
Vapor Space Outage(ft): 16.1615
Working Losses(lb): 7,051.2597
Vapor Molecular Weight(lb/lb-mole): 69.0000
Vapor Pressure at Daily Average Liquid
Surface Temperature(psia): 2.9568
Annual Net Throughput(gal/yr-): 5,406,509.0000
Annual Turnovers' 294.6369
Turnover Factor: 0.2685
Maximum Liquid Volume(gal): 18,349.7363
Maximum Liquid Height(ft): 13.0000
Tank Diameter(ft):. 15.5000
Working Loss Product Factor: 1.0000
Total Losses Pb): 9,431.2350
TANKS 4.0.9d
Emissions Report - Detail Format
Individual Tank Emission Totals
Emissions Report for: Annual
Boomslang 14B-Vertical Fixed Roof Tank
Denver, Colorado
Losses(Ibs)
ICompanents Working Loss Breathing Loss 1 Total Emissions"
Gasoline(RVP 6) 7,051.26 j 2,379.98 j 9,431.24
•
•
Crud8Tankg,CO Permit Calculation Sheet - -
_ - . .<.. ,' ., .. to - State Entibsioh factors _ -
State Emission Factors(lb/bbl)(PS Memo 14-03)
Operator BtaariC(&-Cesli,IIC. ' Average API Sales Oil '$6,05 deg County VOC Benzene n-Hexaoe
Site Name 'S6Omslurlg<S4B'faokk$attery SOP Sales 0,1 ,, .,,:5877 psi at 100E All Counties 3.2 0.046 0.245
Site AIRS Pending.; ~ .PTE Annual Prod(facility) 643632
Location Description E25E.SectiOn 14 TON 7Y60W, Max Annual Prod(Facility) ;:,530960 BBL/year Est.Annual Uncontrolled Emissions(tpy)-No EF
Lat/Long 40.659073,-'504,o5445S Operation tree(hr/yr) 87611 hr/year lb/yr tpy Source
Num.Tanks(all manifolded
Attainment/Non? Nonattarnment .-,'r,"-i;vessels( ., ;; - =-I VOC 2059622.4 1029,8112 CDPHE'
Storage Tank ID - ,'PTE Throughput(tank) 643632 bbl/yr Benzene 29607.072 14.803536 CDPHE'
tt Vessels in Storage Tank <5 PTE Throughput(tank) 27032544 gal/yr 6406509 gat/yr/vessel n-Hexane 157689,84 78.84492 COPHE'
Vessel Capacity(bbl) �75,0 Tank Color FILM Goer Green _ Est.Annual Controlled Emissions(tpy)-No EF
Height(feet) ^'E4 rank Condition 0r5ot)/New lb/yr tpy Source
Width(ft) -,.15,5 Percent Control ;9 VOC 102981.12 51.49056 CDPHE'
Roof Style Cane .. - . Benzene 14803536 0.7401768 CDPHE'
Max Fill Height(ft) , -- 13 Average Fill Height(ft) ., ;.8 n-Hexane 7884.492 3.942246 CDPHE'
Separation Device Description T)P cep at60.OS powLP Sep at-35 psis,VOT at Ott,tankP at 0:S IL5+81 - ' Site-specific Emission Factor Required? Yes
4x7S0 bbl etmpsphea'ucrdde Ail 7tarage tanks for storage`of bulk produced Crude bilfrom all wells,gtthe$acility.
Tank Design 14,jtlfiblatmosphetc cyudeol)storage tank forstorage of produced crudeoilfrorn retat)np Single well test-. -'_
5 iespte(poresCastor S-597,9ii2416_Higbpr0Fsure Separafpr outlettisodas representativesampefor this<3itesinco prnciuetion has notyet begun-This sarripfewat ebtoredintb a sitaulation in Winlltn Design I)procone srm4lotlgri€oftwareto simulateftesti
emisstOnkl[arn-Che LP,(low Measure hunk)separator.VRT(vapor re056er5tbw6r),and Crude oil storage tanks at an eAtilaiec(Standard LP separator pressbre cif as,pxig"gndV81 pressure oT 5 p0i3 tiasedyal Gperatiortal sef[inbx gift*site.
Calculation Methodologies Working aril btetthing emisuond were caibutated fat a single'kaok usings0.EPATANYS 49dusingtank capacity and anticipated,LACT's60ings at thetite'(or<took capacityond height,and'a0990 sf6 based on saiirples of-saies oil'attire Zpstor.849 tank-,-,,
battery nearby(R110;4,7)4This 4ingletankvalue was multiplied Ey five(nurubosof vessels onsite)r and thenreoleipiiedby!the,rati&ofVbCtototal'gasfloW fFgw1he((ash tank s)mitletiut,to estimate percentage'of tgtai emisstans as VOC:,„
Px`v;ettad crude b%f(pcdrates Waro based on Stsop's nbserdgd we)),perfprmance intho lmriredjita zea$rid use a604$dertirt'et ri,$;'fhesepro)�ected ratzSs4erp mulhpSad by3:2to"'proVidaa"PTE°<Y�q}natad throughpv43ar the site -
Using San Specific Factor?
Emission Factor Development
;.Y
f i? r 111 k�fal' a rtr '. ?tl �,.ft of + )' y t,.�rr 7 's - -
i - + r y. J '. Total Emissions Tank Emission
Pollutant ( .) ll F J . ,.; ' I.::is.: t r i 1Lf;.i ' I .Tank Flask(Ib/hr) Tank Flash(Ib/yr) cc l �(lb/yr) Factor(ib/bbl)
{ '. '"- '� 'n + 7,;;,.,.,,. ''42,126108 369024,7061 < �� 40332.53637 - 409357.2425_ 0.636011327
.t . ...i " d. �,,: . ,, '^..i' .� .� ,•.. 0,265261 2323.68636 253.9671818 .. 0,004004856
235$.48984 257.7710264 2616.260866 0.00406484
` 0^213415 1869.5154 204.32859 2073.84399 0.003222096
)Aft .'' t M r _ 131.5662997 0.002074694
)
- - phr r 1 I':-ii,'.1,::.::.'-:'..,'''111101111111MMICS 11878.2972 1298.237885 13176.53508 0.020472157
2,2,4-Tnmethylpentane w4• i,p_ . ,., ',_ ,.. ym .',i ^ ,?q t 1873.65012 204.780494 2078.430614 0.003229222
Tank Man Annual Throughput: 643632 BBL/year
Emission Factor Development Description .
WOe Gas Vapor _ Flash Gas GOR ,. WOO Gas Heating
Flash Gas Heating Value tstu scf Flash Gas Flow Rate scf/hr)OM= 6
:0
366 6335$bll63d
( f ( rafill
Density(IB/scf) - .,.-.'(scf/bb0 _ _ .Value(btu/scf)
To estimate API Gravity and/or Reid Vapor Pressure,enter known values in yellow
Specific Gravity at 60F- _. . - - API Gravity's. _ ,i, 39'.6
Estimated API Gravity enter SG Source:PS Memo 14-03 Equation 1
Estimated RVP 4.6734 Source:PS Memo 14-03 Equation 2
PIE Calculations.Summary: - ,,., ' ,'-x, .;. _:'a.-.. r. - ,,;:-- :. :;y ., -,: , _, .� '<,APEN%Permit Requirements,,.,-,
Emission Factor(1ti/bbl} Calculated Potential Emissions y Site-Specific EF? Yes
Pollutant uncontrolled(lb/yr) Uncontrolled(tpy) Controlled(Ib/yr) Controlled(tpy} Emission Factor Source OPEN Required? Yes
VOC 0.636011327 409357.242E 204.6786212 20467.86212 10.23393106 WinSim,EPA TANKS 13008 Eligible? No
Benzene 0 004004856 2577.653542 1.288826771 128.8826771 0.064441339 WinSim,EPA TANKs
Toluene 0.00406484 2616.260866 1.308130433 130.8130433 0.065406522 WinSim,EPA TANKS
Ethylbenzene 9.003222096 2073.84399 1,036921995 103.692I995 0.0518461 WinSim,EPA TANKs
Xylene 0.002074694 1315.33922 0.66766961 66.76696099 0,03338346 WinSim,EPA TANKS
n-Hexane 0.020472157 1317653508 6.588267542 658.8267542 0.329413377 WinSim,EPA TANKs
2,2,4-Tnmethylpentane 0.003229222 • 2078.430614 1.039215.307 103.9215307 0.051960765 WinSim,EPA TANKS
I
Emission Factor(1b/mmscf
Combustion Pollutant flash+W&B+ptot) Uncontrolled(Ib/yr) Uncontrolled(tpy) Controlled(Ib/yr) Controlled(tpy) EF Source EF(lb/bbl) EF(Ib/mmscf flash+WB)
NO x 195.096 n/a n/a 832.9488415 0.416474421 AP-42',AP-42' 0,001204128 185,096
CO 843.82 n/a n/a 3797.266778 1.898633389 AP-42',AP-425 0.005899748 843.82
SO2 0 n/a n/a 0 0 AP-42' 0 0
PM,PM10,PM2.5 25.52422547 n/a n/a 91.2689042 0.045634452 AP-42' 0.000141803 25.52422547
Burner Gas Calculations
Pilot Gas Flow Rate ,20,5 scf/hr/burner Flash gas Heating Value 2722 btu/seSimulation
' Flash Gas EF Ratio 2.67 btu/seSimulation
Plot Gas Operating Hours $76r).hr/Year
Pilot Gas HHV 1020 btu/seW&8 Gas Vapor Density 0,0366 lb/seSimulation
Number of Burners . .0 flash Gas Flow Rate 387.912 scf/hr
Pilot Gas EF Ratio 1 Simulation
'Assume standard natural gas HHV of 1020 btu/scf for pilot gas Flash Gas GOR 6.335500634 scf/bbi Simulation
Pilot gas emissions calculated separately Waste/Flash Gas Hours 8760 hr/year
WOO Gas Heating Value 2722 btu/scf Simulation
Flash Gas Combustion Emissions
Standard AP-42 Emission
Factors(AP-42`s) Flash Flow Rate EPA TANKS Flow Rate Total Flow Rates Total Controlled Emissions
Pollutant Ib/mmbtu scf/hr scf/hr mmbtu/hr(Flash) mmbtu/hr(W&e) mmbtu/year lb/hr lb/yr tpy
NO x 0.068 387.912 125.7970169 1.055896464 0.34241948 12249.24767 0.095085484 832.9488415 0.416474421
CO 0,31 387.912 125.7970169 - 1.055896464 0.34241948 12249.24767 0.433477943 3797.266778 1.898633389
Standard AP-42 Emission Adjusted AP-42 Emission EPA TANKS Flow
Factors(AP-42) Factors)AP-42') Flash Flow Rate Rates Total Flow Rates Total Controlled Emissions
Pollutant lb/mmscf Ib/mmscf scf/hr scf/hr sd/hr mmscf/year Ib/hr lb/yr tpy
SO2 0 0 387.912 125,7970169 513.7090169 4.500090988 0 0 0
PM,PM10,PM2.5 7.6 20 387.912 125.7970169 513.7090169 4,500090988 0.010418825 91.2689042 0.045634452
Emission Factor Source References
Reference Description Reference Document
PS Memo 14.03.Oil&Gas Industry Crude Oil,Condensate and Produced Water Atmospheric
CDPHE' Crude oil standard tank emission factors for Colorado Storage Tanks Regulatory Definitions and Permitting Guidance for General Permit GPOB
AP-41 Chapter I,Section 4 Natural Gas.Table 1.4.1 Emission Factors for Nitrogen Oxides(Non)and
Carbon Monoxide(CO)From Natural Gas Combustion
Per Footnote:"The emission factors in this table maybe converted to other natural gas heating
NOs and CO Emission Factors for small(<100 mmbtu/hr heat values by multiplying the given emission factor by the ratio of the specified heating value to this
AP-42' input)uncontrolled boilers(Natural Gas Combustion) average heating value".(Where average heating value is given as 1,020 btu/scf(
AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-2 Emission Factors for Criteria Pollutants and
Greenhouse Gases From Natural Gas Combustion
Per Footnote:"The emission factors in this table may be converted to other natural gas treating
Criteria Pollutant and Greenhouse Gas Emission Factors values by multiplying the given emission factor by the ratio of the specified heating value to this
AP-42' (natural gas combustion) average heating value".(Where average heating value is given as 1,020 btu/scf(
AP-42 Chapter 1,Section 4 Natural Gas.Table 1.43 Emission Factors for Spectated Organic
Compounds From Natural Gas Combustion
Per Footnote:"To convert from Ib/106 scf to Ib/MM8tu,divide by 1020"--Same method used to
AP-42' Organic Compound Emission factors convert to higher HHV as with other AP-42 natural gas combustion calculations.
Crude oil standard tank emission factors for Colorado-Heat PS Memo 14-03:Oil&Gas Industry Crude Oil,Condensate and Produced Water Atmospheric
COPHE' Content and Gas-to-Oil Ratio Storage Tanks Regulatory Definitions and Permitting Guidance for General Permit GROB
AP-42 Table 13,5-1 THC,NO,and soot emissions factors for flare operations for certain chemical
AP-42 Table 13.5-1 THC,NOX,and soot emissions factors for manufacturing processes•
flare operations for certain chemical manufacturing NOx:0.068 lb/105 Otu
AP-42' processes, ' Footnote:Factor developed using the higher(gross)heating value of the vent gas
- AP-42 Table 13.5-2 VOC and CO emissions factors from elevated flare operations for certain
AP-42 Table 13.5-2 VOC and CO emissions factors from refinery and chemical manufacturing processes
elevated flare operations for certain refinery and chemical CO:0.31 Ib/10s Btu
AP-42' manufacturing processes Footnote:Factor developed using the lower(net)heating value of the vent gas
Details for Stream 1
Stream 1 (HP Oil Out)
Thermodynamic Methods K-Value: PENG-ROB Enthalpy: PENG-ROB Density: STD
Liquid 1 Viso: NBS81 Liquid 1 ThC: NBS81 Liquid 1 Den: STD Surface Ten: STEAM
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total K-Value
Ibmol/hr Ibmol/hr Ibmol/hr Ibmol/hr Ibmol/hr mole%
49:CARBON DIOXIDE 0.116428 0 0.116428 0 0 0.091
46:NITROGEN 0 0 0 0 0 0
2:METHANE 1.29607 0 1.29607 0 0 1.013
3:ETHANE 1.69909 0 1.69909 0 0 1.328
4:PROPANE 4.3859 0 4.3859- 0 0 3.428
5:I-BUTANE 0.949339 0 0.949339 0 0 0.742
6:N-BUTANE 4.76845 0 4.76845 0 0 3.727
7:I-PENTANE 2.05733 0 2.05733 0 0 1.608 I
8:N-PENTANE 3.71036 0 3.71036 0 0 2.9
52:2-METHYLPENTANE 1.1323 0 1.1323 0 0 0.885
53:3-METHYLPENTANE 0.768939 0 0.768939 0 0 0.601
38:CYCLOHEXANE 0.765101 0 0.765101 0 0 0.598 I
11:N-HEPTANE 13.4916 0 13.4916 0 0 10.545
12:N-OCTANE 8.42763 0 8.42763 0 0 • 6.587
13:N-NONANE 3.95985 0 3.95985 0 0 3.095
14:N-DECANE 2.36183 0 2.36183 0 0 1.846
40:BENZENE 0.584701 0 0.584701 0 0 0.457
41:TOLUENE 1.49694 0 1.49694 0 0 1.17
45:ETHYL BENZENE 2.27099 0 2.27099 0 0 1.775
43:M-XYLENE 1.23593 0 1.23593 0 0 0.966
44:P-XYLENE 0.199592 0 0.199592 0 0 0.156
42:O-XYLENE 0.308343 0 0.308343 0 0 0.241
10:N-HEXANE 2.67657 0 2.67657 0 0 2.092
82:2,2,4-TRIMETHYLP 0.752307 0 0.752307 0 0 0.588
15:N-UNDECANE 13.4161 0 13.4161 0 ' 0 10.486
16:N-DODECANE 9.94631 0 9.94631 0 0 7.774
17:N-TRIDECANE 7.97982 0 7.97982 0 0 6.237
18:N-TETRADECANE 5.94297 0 5.94297 0 0 4.645
19:N-PENTADECANE 4.10186 0 4.10186 0 0 3.206
20:N-HEXADECANE 3.38538 0 3.38538 0 0 2.646
21:N-HEPTADECANE 23.7552 0 23.7552 0 0 18.567
Total 127.943 0 127.943 0 0 100
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total K-Value
lb/hr lb/hr lb/hr lb/hr lb/hr mass%
49:CARBON DIOXIDE 5.12388 0 5.12388 0 0 0.026794
46:NITROGEN 0 0 0 0 0 0
2:METHANE 20.7928 0 20.7928 0 0 0.108732
3:ETHANE 51.0882 0 51.0882 0 0 0.267156
4:PROPANE 193.392 0 193.392 0 0 1.01131
5:1-BUTANE 55.1756 0 55.1756 0 0 0.28853
6:N-BUTANE 277.142 0 277.142 0 0 1.44926
7:1-PENTANE 148.428 0 148.428 0 0 0.776176
8:N-PENTANE 267.687 0 267.687 0 0 1.39982
52:2-METHYLPENTANE 97.6041 0 97.6041 0 0 0.510402
53:3-METHYLPENTANE 66.2826 0 66.2826 0 0 0.346612
38:CYCLOHEXANE 64.3878 0 64.3878 ' 0 0 0.336704
11:N-HEPTANE 1351.83 0 1351.83 0 0 7.06916
12:N-OCTANE • 962.637 0 962.637 0 0 5.03393
13:N-NONANE 507.85 0 507.85 0 0 2.65571
14:N-DECANE 336.032 0 336.032 0 0 1.75722
40:BENZENE 45.6698 0 45.6698 0 0 0.238822
41:TOLUENE 137.919 0 137.919 0 0 0.72122
45:ETHYL BENZENE 241.089 0 241.089 0 0 1.26073
43:M-XYLENE 131.207 0 131.207 0 0 0,68612
44:P-XYLENE 21.1886 0 21.1886 0 0 0.110802
42:O-XYLENE 32.7337 0 32.7337 0 0 0.171175
10:N-HEXANE 230.646 0 230.646 0 0 1.20612
82:2,2,4-TRIMETHYLP 85.9315 0 85.9315 0 0 0.449362
15:N-UNDECANE 2096.97 0 2096.97 0 0 10.9657
16:N-DODECANE 1694.14 0 1694.14 0 0 8.85916
17:N-TRIDECANE 1471.11 0 1471.11 0 0 7.69291 •
18:N-TETRADECANE 1178.97 0 1178.97 0 0 6.16518
19:N-PENTADECANE 871.26 0 871.26 0 0 4.55609
20:N-HEXADECANE 766.558 0 766.558 0 0 . 4.00857
21:N-HEPTADECANE 5712.14 0 5712.14 0 0 29.8705
Total 19123 0 19123 0 0 100
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total
ft3/hr ft3/hr ft3/hr ft3/hr ft3/hr volume%
49:CARBON DIOXIDE 0.106009 0 0.106009 0 0 0.024611
46:NITROGEN 0 0 0 0 0 0
2:METHANE 1.12917 0 1.12917 0 0 0.262146
3:ETHANE 1.91243 0 1.91243 0 0 0.443987
4:PROPANE 7.26521 0 7.26521 0 0 1.68668
5:1-BUTANE 1.74662 0 1.74662 0 0 0.405491
6:N-BUTANE 8.36422 0 8.36422 0 0 1.94182 A
7:1-PENTANE 4.09123 0 4.09123 0 0 0.949814
8:N-PENTANE 7.29471 0 7.29471 0 0 1.69353
52:2-METHYLPENTANE 2.53082 0 2.53082 0 0 0.587551
53:3-METHYLPENTANE 1.68508 0 1.68508 0 0 0.391206
38:CYCLOHEXANE 1,38423 0 1.38423 0 0 0.321361
11:N-HEPTANE 33.0752 0 33.0752 0 0 7.67867
12:N-OCTANE 22.8538 0 22.8538 0 0 5.30569
13:N-NONANE 11.7645 0 11.7645 0 0 2.73123
14:N-DECANE 7.64097 0 7.64097 0 0 1.77391
40:BENZENE 0.869009 0 0.869009 0 0 0.201748
41:TOLUENE 2.64227 0 2.64227 0 0 0.613426
45:ETHYL BENZENE 4.60838 0 4.60838 0 0 1.06987
43:M-XYLENE 2.51559 0 2.51559 0 0 0.584016
44:P-XYLENE 0.408057 0 0.408057 0 0 0.094734
42:O-XYLENE 0.615404 0 0.615404 0 0 0.142871
10:N-HEXANE 5.89506 0 5.89506 0 0 1.36859
82:2,2,4-TRIMETHYLP 2.07203 0 2.07203 0 0 0.48104
15:N-UNDECANE 46.9537 0 46.9537 0 0 10.9007
16:N-DODECANE 37.4432 0 37.4432 0 0 8.69274
17:N-TRIDECANE 32.1551 0 32.1551 0 0 7.46508
18:N-TETRADECANE 25.5277 0 25.5277 0 0 5.92647
19:N-PENTADECANE 18.7176 0 18.7176 0 0 4.34545
20:N-HEXADECANE 16.3495 0 16.3495 0 0 3.79568
21:N-HEPTADECANE 121.124 0 121.124 0 0 28.1199
Total 430.741 0 430.741 0 0 100
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total
SCF/hr SCF/hr • SCF/hr SCF/hr SCF/hr std vol%
49:CARBON DIOXIDE 0.099947 0 0.099947 0 0 0.024228
46:NITROGEN 0 0 0 0 0 0
2:METHANE 1.11184 0 1.11184 0 0 0,269519
3:ETHANE 2.29838 0 2.29838 0 0 0.557148
4:PROPANE 6.11169 0 6.11169 0 0 1.48153
5:I-BUTANE 1.57163 0 1.57163 0 0 0.380978
6:N-BUTANE 7.60859 0 7.60859 0 0 1.84439
7:1-PENTANE 3.81047 0 3.81047 0 0 0.923692
8:N-PENTANE 6.80119 0 6.80119 0 0 1.64867
52:2-METHYLPENTANE 2.37796 0 2.37796 0 0 0.57644
53:3-METHYLPENTANE 1.58814 0 1.58814 0 0 0.38498
38:CYCLOHEXANE 1.31776 0 1.31776 0 0 0.319438
11:N-HEPTANE 31.4975 0 31.4975 0 0 7.63528
12:N-OCTANE 21.8337 0 21.8337 0 0 5.29269
13:N-NONANE 11.2811 0 11.2811 0 0 2.73463
14:N-DECANE 7.34044 0 7.34044 0 0 1.77939
40:BENZENE 0.827904 0 0.827904 0 0 0.200691
41:TOLUENE 2.53661 0 2.53661 0 0 0.614898
45:ETHYL BENZENE 4.43481 0 4.43481 0 0 1.07504
43:M-XYLENE 2.42163 0 2.42163 0 0 0.587026
44:P-XYLENE 0.392538 0 0.392538 0 0 0.095155
42:O-XYLENE 0.593396 0 0.593396 0 0 0.143845
10:N-HEXANE 5.56961 0 5.56961 0 0 1.35012
82:2,2,4-TRIMETHYLP 1.97205 0 1.97205 0 0 0.478044
15:N-UNDECANE 45.1956 0 45.1956 0 0 10.9558
16:N-DODECANE 36.0329 0 36.0329 0 0 8.73471
17:N-TRIDECANE 30.9357 0 30.9357 0 0 7.49909
18:N-TETRADECANE 24.6282 0 24.6282 0 0 5.97011
19:N-PENTADECANE 18.0404 0 18.0404 0 0 4.37315
20:N-HEXADECANE 15.7491 0 15.7491 0 0 3.81772
21:N-HEPTADECANE 116.545 0 116.545 0 0 28.2516
Total 412.526 0 412.526 0 0 100
Properties
Temperature F 142
Pressure psia 81.696
Enthalpy Btu/hr -1781362
Entropy Btu/hr/R -1001.665
Vapor Fraction 0
Total Liquid 1
Flowrate Ibmolihr 127.9433 127.9433
Flowrate lb/hr 19122.9792 19122.9792
Mole Fraction 1 1
Mass Fraction 1 1
Molecular Weight 149.4645 149.4645
Enthalpy Btulibmol -13923.0525 -13923.0525
Enthalpy Btu/lb -93.1529 -93.1529
Entropy Btullbmol/R -7.829 -7.829
Entropy Btu/lb/R -0.05238 -0.05238
Cp Btu/Ibmol/R 80.7082
Cp Btu/ib/R 0.54
Cv Btu/lbmaUR 72.4826
Cv Btullb/R 0.4849
CpICv 1.1135
Density Ib/ft3 44.3956
Z-Factor 0.042597
Flowrate(T-P) gal/min 53.7027
Flowrate(STP) bbl/hr 73.474
Specific Gravity GPA STP 0.74328
Viscosity cP 0.575817
Thermal Conductivity Btu/hrfft/R 0.063826 ,
Surface Tension dyne/cm 18.5798
Critical Temperature(Cubic E F 728.2841
Critical Pressure(Cubic EOS: psia 428.1577
Dew Point Temperature F 607.5599
Bubble Point Temperature F 209.5936
Hydrocarbon Dew Point Temi F 607.5599
Stream Vapor Pressure psia 56.7302
Latent Heat of Vaporization(t Btu/lb 90.92956
Latent Heat of Vaporization(I Btu/lb 390.6692
CO2 Freeze Up No
CO2 Freeze Temperature F • -69.826
Heating Value(gross) Btu/SCF 8065.04
Heating Value(net) Btu/SCF 7505.59
Wobbe Number Btu/SCF 3192.03
Average Hydrogen Atoms 22.681
Average Carbon Atoms 10.5389
Hydrogen to Carbon Ratio 2.1521
VRT Gas Out
139F
5 psig
643,632 US barrels(STP)/yr 2.09839 MSCFIhr
142 F 2,447 Btu/SCF
67 psig LP Gas Out
HP Oil Out 141.9794 F
35 psig
0.21 MSCF/hr
1,796 Btu/SCF
x x K
iviwoo._
Tank Flash Gas
,( x VRT 138.4 F
x x LP Separator LP Oil Out x x 0.5 psig
387.912 SCF/hr
141.9794 F �,,, / 2,722 BtuISCF
35 psig
VRT Oil Out
139 F , x
5 psig
x
Sales Oil
B 9
oomsIan 14B Air Permit Simulation Tanks
10/10/2019
S. McKibben I Quandary Consultants,
Details for Stream 6
Stream 6 (Tank Flash Gas)
Thermodynamic Methods K-Value: PENG-ROB Enthalpy: PENG-ROB Density: STD
Vapor Visc: NBS81 Vapor ThC: NBS81 Vapor Den: STD
Flowrates
Component Name Total Vapor Incipient Liquid 1 Liquid 2 Solid Total K-Value
Ibmol/hr Ibmol/hr mol fra Ibmol/hr Ibmol/hr mole%
49:CARBON DIOXIDE 0.012532 0.012532 0.000184 0 0 1.22596 66.7438
46:NITROGEN 0 0 0 0 0 0 1021.29
2:METHANE 0.103642 0.103642 0.000526 0 0 10.139 192.836
3:ETHANE 0.18107 0.18107 0.003919 0 0 17.7136 45.2028
4:PROPANE 0.328468 0.328468 0.020616 0 0 32.1331 15.5863
6:I-BUTANE 0.043036 0.043036 0.005889 0 0 4.21011 7.14886
6:N-BUTANE 0.174842 0.174842 0.031517 0 0 17.1043 5.42701
7:1-PENTANE 0.037066 0.037066 0.015331 0 0 3.62602 2.36515
8:N-PENTANE 0.056136 0.056136 0.028122 0 0 5.49166 1.95283
62:2-METHYLPENTANE 0.008551 0.008551 0.008957 0 0 0.836546 0.93393
53:3-METHYLPENTANE 0.005333 0.005333 0.006103 0 0 0.521714 0.854783
38:CYCLOHEXANE 0.003653 0.003653 0.006145 0 0 0.357403 0.581632
11:N-HEPTANE 0.030569 0.030569 0.109819 0 0 2.99051 0.272314
12:N-OCTANE 0.007329 0.007329 0.069108 0 0 0.716983 0.103749
13:N-NONANE 0.001343 0.001343 0.032562 0 0 0.131341 0.040336
14:N-DECANE 0.000308 0.000308 0.019443 0 0 0.030135 0.015499
40:BENZENE 0.003396 0.003396 0.00467 0 0 0.332228 0.711438
41:TOLUENE 0.002922 0,002922 0.012205 0 0 0.285871 0.234221
46:ETHYL BENZENE 0.00201 0.00201 0.018621 0 0 0.196664 0.105614
43:M-XYLENE 0.00094 0.00094 0.010141 0 0 0.091959 0.090683
44:P-XYLENE 0.000151 0,000151 0.001638 0 0 0.01478 0.090248
42:O-XYLENE 0.000203 0.000203 0.002531 0 0 0.019892 0.078586
10:N-HEXANE 0.015736 0.015736 0.021368 0 0 1.53937 0.720406
82:2,2,4-TRIMETHYLP 0.001873 0.001873 0.006116 0 0 0.183183 0.299498
15:N-UNDECANE 0.000748 0.000748 0.110487 0 0 0.073164 0.006622
16:N-DODECANE 0.000231 0.000231 0.081926 0 0 0.02263 0.002762
17:N-TRIDECANE 0.00007836 0.00007836 0.065733 0 0 0.007665 0.001166
18:N-TETRADECANE 0.00002333 0.00002333 0.048956 0 0 0.002282 0.000466
19:N-PENTADECANE 0.000007106 0.000007106 0.03379 0 0 0.000695 0.000206
20:N-HEXADECANE 0.000002533 0.000002533 0.027888 0 0 0.000248 0.00008887
21:N-HEPTADECANE 0.000009726 0.000009726 0.195691 0 0 0.000951 0.00004862
Total 1.02221 1.02221 1 0 0 100
Flowrates
Component Name Total Vapor Incipient Liquid 1 Liquid 2 Solid Total K-Value
lb/hr lb/hr mass fra lb/hr lb/hr mass%
49:CARBON DIOXIDE 0.551516 0.551516 0.000052 0 0 1.1078 66.7438
46:NITROGEN 0 0 0 0 0 0 1021.29
2:METHANE 1.66273 1.66273 0.000054 0 0 3.33984 192.836
3:ETHANE 5.44442 5.44442 0.00076 0 0 10.9359 45.2028
4:PROPANE 14.4835 14.4835 0.00586 0 0 29.0922 15.5863
5:1-BUTANE 2.50126 2.50126 0.002206 0 0 5.02416 7.14886
6:N-BUTANE 10.1618 10,1618 0.01181 0 0 20.4114 5.42701
7:1-PENTANE 2.67413 2.67413 0.00713 0 0 5.37139 2.36515
8:N-PENTANE 4.05001 4.05001 0.01308 0 0 8.13504 1.95283
62:2-METHYLPENTANE 0.737119 0.737119 0.004977 0 0 1.48061 0.93393
53:3-METHYLPENTANE 0.459706 0.459706 0.003391 0 0 0.923387 0.854783
38:CYCLOHEXANE 0.307456 0.307456 0.003333 0 0 0.617571 0.581632
11:N-HEPTANE 3.06298 3.06298 0.0709 0 0 6.15245 0.272314
12:N-OCTANE 0.837157 0.837157 0.05088 0 0 1.68155 0.103749
13:N-NONANE 0.172186 0.172186 0.02692 0 0 0,345862 0.040336
14:N-DECANE 0.043827 0.043827 0.01783 0 0 0.088034 0.015499
40:BENZENE 0.265261 0.265261 0.002351 0 0 0.532815 0.711438
41:TOLUENE 0.269234 0.269234 0.00725 0 0 0,540796 0.234221
45:ETHYL BENZENE 0.213415 0.213415 0.01274 0 0 0.428676 0.105614
43:M-XYLENE 0.099792 0.099792 0.00694 0 0 0.200447 0.090683
44:P-XYLENE 0.016038 0.016038 0.001121 0 0 0.032216 0.090248
42:O-XYLENE 0.021587 0.021587 0.001732 0 0 0.04336 0.078586
10:N-HEXANE 1.35597 1.35597 0.01187 0 0 2.72367 0.720406
82:2,2,4-TRIMETHYLP 0.213887 0.213887 0.004503 0 0 0.429623 0.299498
15:N-UNDECANE 0.116897 0.116897 0.1113 0 0 0.234805 0.006622
16:N-DODECANE 0.039401 0.039401 0.0899 0 0 0.079143 0.002762
' 17:N-TRIDECANE 0.014445 0,014445 0.0781 0 0 0.029015 0.001166
18:N-TETRADECANE 0.004628 0.004628 0.0626 0 0 0.009297 0.000466
19:N-PENTADECANE 0.001509 0.001509 0.04626 0 0 0.003032 0.000206
20:N-HEXADECANE 0.000574 0.000574 0.04071 0 0 0.001152 0.00008887
21:N-HEPTADECANE 0.002339 0.002339 0.3033 0 0 0.004697 0.00004862
Total 49.7848 49.7848 1 0 0 100
VOC 42.126108
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total
ft3/hr ft3/hr ft3/hr ft3/hr ft3/hr volume%
49:CARBON DIOXIDE 5.22299 5.22299 0 0 0 1.22596
46:NITROGEN 0 0 0 0 0 0
2:METHANE 43.1955 43.1955 0 0 0 10.139
3:ETHANE 75.4654 75.4654 0 0 0 17.7136
4:PROPANE 136.897 136.897 0 0 0 32.1331
5:I-BUTANE 17.9364 17.9364 0 0 0 4.21011
6:N-BUTANE 72.8694 72.8694 0 0 0 17.1043
7:1-PENTANE 15.448 15.448 0 0 0 3.62602
8:N-PENTANE 23.3962 23.3962 0 0 0 5.49166
52:2-NETHYLPENTANE 3.56394 3.56394 0 0 0 0.836546
53:3-METHYLPENTANE 2,22266 2.22266 0 0 0 0.521714
38:CYCLOHEXANE 1.52265 1.52265 0 0 0 0.357403
11:N-HEPTANE 12.7405 12.7405 0 0 0 2.99051
12:N-OCTANE 3.05457 3.05457 0 0 0 0.716983
13:N-NONANE 0.559555 0.559555 0 0 0 0.131341
14:N-DECANE 0.128385 0.128385 0 0 0 0.030135
40:BENZENE 1.4154 1.4154 0 0 0 0.332228
41:TOLUENE 1.2179 1.2179 0 0 0 0.285871
45:ETHYL BENZENE 0.837848 0.837848 0 0 0 0.196664
43:M-XYLENE 0.391774 0.391774 0 0 0 0.091959
44:P-XYLENE 0.062965 0.062965 0 0 0 0.01478
42:O-XYLENE 0.084747 0.084747 0 0 0 0.019892
10:N-HEXANE 6.5582 6.5582 0 0 0 1.53937
82:2,2,4-TRIMETHYLP 0.780418 0.780418 0 0 0 0.183183
15:N-UNDECANE 0.311703 0.311703 0 0 0 0.073164
16:N-DODECANE 0.096411 0.096411 0 0 0 0.02263
17:N-TRIDECANE 0.032656 0.032656 0 0 0 0.007665
18:N-TETRADECANE 0.009724 0,009724 0 0 0 0.002282
19:N-PENTADECANE 0.002962 0.002962 0 0 0 0.000695
20:N-HEXADECANE 0.001056 0.001056 0 0 0 0.000248
21:N-HEPTADECANE 0.004053 0.004053 0 0 0 0.000951
Total 426.031 426.031 0 0 0 100
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total
SCF/hr SCF/hr SCF/hr SCF/hr SCF/hr std vol%
49:CARBON DIOXIDE 4.75566 4.75566 0 0 0 1.22596
46:NITROGEN 0 0 0 0 0 0
2:METHANE 39.3305 39.3305 0 0 0 10.139
3:ETHANE 68.7131 68.7131 0 0 0 17.7136
4:PROPANE 124.648 124.648 0 0 0 32.1331
5:1-BUTANE 10.3315 16.3315 0 0 0 4.21011
6:N-BUTANE 66.3494 66.3494 0 0 0 17.1043
7:1-PENTANE 14.0658 14.0658 0 0 0 3.62602
8:N-PENTANE 21.3028 21.3028 0 0 0 5.49166
52:2-METHYLPENTANE 3.24506 3.24506 0 0 0 0.836546
53:3-METHYLPENTANE 2.02379 2.02379 0 0 0 0.521714
38:CYCLOHEXANE 1.38641 1.38641 0 0 0 0.357403
11:N-HEPTANE 11.6005 11.6005 0 0 0 2.99051
12:N-OCTANE 2.78126 2.78126 0 0 0 0.716983
13:N-NONANE 0.509488 0.509488 0 0 0 0.131341
14:N-DECANE 0.116898 0.116898 0 0 0 0.030135
40:BENZENE 1.28875 1.28875 0 0 0 0.332228
41:TOLUENE 1.10893 1.10893 0 0 0 0.285871
45:ETHYL BENZENE 0.762882 0.762882 0 0 0 0.196664
43:M-XYLENE 0.35672 0.35672 0 0 0 0.091959
44:P-XYLENE 0.057331 0.057331 0 0 0 0.01478
42:O-XYLENE 0.077164 0.077164 0 0 0 0.019892
10:N-HEXANE 5.97141 5.97141 0 0 0 1.53937
82:2,2,4-TRIMETHYLP 0.71059 0.71059 0 0 0 0,183183
15:N-UNDECANE 0.283813 0.283813 0 0 0 0.073164
16:N-DODECANE 0.087784 0.087784 0 0 0 0.02263
17:N-TRIDECANE 0.029734 0.029734 0 0 0 0.007665
18:N-TETRADECANE 0.008854 0.008854 0 0 0 0.002282
19:N-PENTADECANE 0.002697 0.002697 0 0 0 0.000695
20;N-HEXADECANE 0.000961 0.000961 0 0 0 0.000248
21:N-HEPTADECANE 0.003691 0.003691 0 0 0 0.000951
Total 387.912 387.912 0 0 0 100
Properties
Temperature F 138.3501
Pressure psia 15.196
Enthalpy Btu/hr 2099.598
Entropy Btu/hr/R 7.993767
Vapor Fraction 1
Total Vapor
Flowrate lbmol/hr 1.0222 1.0222
Flowrate lb/hr 49.7848 49.7848
Mole Fraction 1 1
Mass Fraction 1 1
Molecular Weight 48.703 48.703
Enthalpy Btu/lbmol 2053.9775 2053.9775
Enthalpy Btu/lb 42.1735 42.1735
' Entropy Btu/lbmol/R 7.8201 7.8201
Entropy Btutlb/R 0.160567 0.160567
Cp Btu/Ibmol/R 21.3317
Cp Btu/lb/R 0.438
Cv Btu/lbmol/R 19.2486
Cv Btu/lb/R 0.3952
CpICv 1.1082
Density Ib/ft3 0.116857
Z-Factor 0.986848
Flowrate(T-P) ft3/s 0.118342
Flowrate(STP) MMSCFD 0.00931
Specific Gravity GPA STP
Viscosity cP 0.009285
Thermal Conductivity Btu/hr/ft/R 0.012804
Critical Temperature(Cubic E F 279.6069
Critical Pressure(Cubic EOS) psia 943.6264
Dew Point Temperature F 138.3583
Bubble Point Temperature F -202.345
Hydrocarbon Dew Point Temp F 138.3583
Stream Vapor Pressure psia 603.6332
Vapor Sonic Velocity ft/s 810.83
CO2 Freeze Up No
CO2 Freeze Temperature F -69.826
Heating Value(gross) Btu/SCF 2722.08
Heating Value(net) Btu/SCF 2508.58
Wobbe Number Btu/SCF 2076.21
Average Hydrogen Atoms 8.4886
Average Carbon Atoms 3.3101
Hydrogen to Carbon Ratio 2.5645
Methane Number 36.05
Motor Octane Number 95.53
SIR
Zedi US Inc
2881 South 31st Ave.
Greeley,CO 80634
i i '" fr-)t- , ii c.-i_ Pot._- ,it 970 460 0055
EXTENDED HYDROCARBON LIQUID STUDY
CERTIFICATE OF ANALYSIS
Company: Quandary Consultants Sample Name: Castor 8-59 19-24-16(API 05-123-
45855)Pressurized Liquid
Sample Date: 4/3/2018 Lab ID Number: 18040430-03
Sample Facility: Not Indicated Date Tested: 4/5/2018
Sample Equipment: Sight Glass Test Method: GPA 2186M
Sample Location: CO Date Reported: 4/16/2018
Sample Pressure: 67 PSIG
Sample Temperature: 142°F
Sampling Method: GPA-2174
Type Sample: Spot
Components Mole % Weight% Liq. Vol. %
Carbon Dioxide 0.091 0.025 0.023
Nitrogen 0.000 0.000 0.000
Methane 1.013 0.101 0.252
Ethane 1.328 0.248 0.520
Propane 3.428 0.939 1.383
iso-Butane 0.742 0.268 0.356
n-Butane 3.727 1.346 1.721
iso-Pentane 1.608 0.721 0.862
n-Pentane 2.900 1.300 1.540
2-Methylpentane 0.885 0.474 0.541
3-Methylpentane 0.601 0.322 0.359
Other Hexanes 0.598 0.320 0.365
Heptanes 10.545 6.330 6.779
Octanes 6.587 4.503 4.691
Nonanes 3.095 2.466 2.544
Decanes+ 55.405 76.138 73.823
Benzene 0.457 0.222 0.187
Toluene 1.170 0.670 0.574
Ethylbenzene 1.775 1.171 1.003
m-Xylene 0.966 0.637 0.548
p-Xylene. 0.156 0.103 0.088
o-Xylene 0.241 0.159 0.134
n-Hexane 2.092 1.120 1.260
2,2,4-Trimethylpentane 0.588 0.417 0.447
Totals 100.000 100.000 100.000
Page 1 of 3
TOTAL C31+EXTENDED REPORT
CERTIFICATE OF ANALYSIS
Components Mole% Weight% Liq.Vol.%
Carbon Dioxide 0.091 0.025 0.023
Nitrogen 0.000 0.000 0.000
Methane 1.013 0.101 0.252
Ethane 1.328 0.248 0.520
Propane 3.428 0.939 1.383
IsoPutane 0.742 0.268 0.356
n-Butane 3.727 1.346 1.721
2,2-Dimethylpropane 0.000 0.000 0.000
IsoPentane 1.608 0.721 0.862
n-Pentane 2.900 1.300 1.540
2,2-Dimethyibutane 0.007 0.004 0.005
2-Methylpentane 0.885 0.474 0.541
3-Methylpentane 0.601 0.322 0.359
Other Hexanes 0.590 0.316 0.361
n-Hexane 2.092 1.120 1.260
Methylcyclopentane 1.549 0.810 0.802
Benzene 0.457 0.222 0.187
Cyclohexane 0.805 0.421 0.401
2,2,4-Trimethylpentane 0.588 0.417 0.447
Other Heptanes 6.480 4.034 4.419
n-Heptane 1.711 1.065 1.156
Methylcyclohexane 1.725 1.052 1.015
Toluene 1.170 0.670 0.574
Octanes 3.228 2.291 2.450
n-Octance 1.635 1.160 1.226
Ethylbenzene 1.775 1.171 1.003
m-Xylene 0.966 0.637 0.548
p-Xylene 0.156 0.103 0.088
o-Xylene 0.241 0.159 0.134
Nonanes 1.950 1.554 1.601
n-Nonane 1.145 0.912 0.943
Decanes 0.856 0.885 0.886
n-Decane 0.990 0.875 0.890
Undecanes(C11) 10.486 10.183 • 10.270
Dodecanes(C12) 7.774 8.227 8.186
Tridecanes(C13) 6.237 7.144 7.052
Tetradecanes(C14) 4.645 5.725 5.600
Pentadecanes(C15) 3.206 4.231 4.106
Hexadecanes(C16) 2.646 3.723 3.594
Heptadecanes(C17) 2.585 3.862 3.709
Octadecanes(C18) 2.432 3.845 3.693
Nonadecanes(C19) 2.178 3.634 3.450
Eicosanes(C20) 2.065 3.625 3.431
Heneicoanes(C21) 1.735 3.197 3.012
Docosanes(C22) 1.543 2.978 2.857
Tricosanes(C23) 1.024 2.064 1.933
Tetracosanes(C24) 0.862 1.814 1.698
Pentacosanes(C25) 0.813 1.781 1.659
Hexacosanes(C26) 0.650 1.481 1.421
Heptacosanes(C27) 0.566 1.338 1.280
Octaconsanes(C28) 0.419 1.028 0.951
Nonacosanes(C29) 0.424 1.076 - 0.994
Triacosanes(C30) 0.321 0.842 0.776
Hentriacontanes Plus(C31+) 0.950 2.579 2.376
Totals 100.000 100.000 100.000
Page 2 of 3
I
CALCULATED SAMPLE CHARACTERISTICS
RELATIVE SPECIFIC GRAVITY 0.74800
API GRAVITY AT 60/60 F 57.7
TRUE VAPOR PRESSURE AT 100 F, PSIA 72.820
AVERAGE MOLECULAR WEIGHT 160.957
AVERAGE BOILING POINT, F 350.715
RELATIVE SPECIFIC GRAVITY OF DECANES+(C10+) FRACTION 0.77204
AVERAGE MOLECULAR WEIGHT OF DECANES+(C10+)FRACTION 222.046
BTU/GALLON OF LIQUID AT 14.73 PSIA 78,499.82
LBS/GALLON OF LIQUID 6.236
NOTATION:ALL CALCULATIONS PERFORMED USING PHYSICAL CONSTANTS FROM GPA 2145-
16,THE TABLES OF PHYSICAL CONSTANTS FOR HYDROCARBONS AND OTHER COMPOUNDS
OF INTEREST TO THE NATURAL GAS INDUSTRY.
FLASHED CRUDE OIL LIQUID STUDIES
Sample Name: Castor 8-59 19-24-16 (API 05-123-45855) Unpressurized Liquid
Sample Number: 18040430-03
TEST PERFORMED RESULTS DATE TESTED
REID VAPOR PRESSURE (ASTM D5191), PSI AT 100 F,measured 5.625 4/16/2018
Page 3 of 3
a
iiiii 0 I Zedi US Inc
2881 South 31st Ave.
Greeley,CO 80634
Rt i? 'f,:a Pt t ) ';i, °i i, f i P t't 1.1: 970 460 0055
EXTENDED HYDROCARBON LIQUID STUDY
CERTIFICATE OF ANALYSIS
Company: Quandary Consultants Sample Name: Castor 8-59 19-24 Tank(Sales)
Unpressurized Liquid
Sample Date: 4/3/2018 Lab ID Number: 18040430-02
Sample Facility: Not Indicated Date Tested: 4/16/2018
Sample Equipment: Tank Test Method: GPA 2186M
Sample Location: CO Date Reported: 4/16/2018
Sample Pressure: Ambient
Sample Temperature: 65°F
Sampling Method: ASTM D 4057
Type Sample: Spot
Components Mole /c Weight % Liq. Vol. %
Carbon Dioxide 0.000 0.000 0.000
Nitrogen 0.017 0.003 0.003
Methane 0.000 0.000 0.000
Ethane 0.185 0.035 0.073
Propane 1.759 0.489 0.719
iso-Butane 0.712 0.261 0.346
n-Butane 4.126 1.512 1.931
iso-Pentane 2.207 1.004 1.198
n-Pentane 3.913 1.780 2.106
2-Methylpentane 1.152 0.626 0.714
3-Methylpentane 0.760 0.413 0.460
Other Hexanes 0.779 0.423 0.483
Heptanes 12.036 7.323 7.827
Octanes 8.197 5.719 5.976
Nonanes 3.126 2.528 2.605
Decanes+ 53.964 73.541 71.366
Benzene 0.522 0.257 0.217
Toluene 0.000 0.000 0.000
Ethylbenzene 1.920 1.285 1.099
m-Xylene 0.958 0.641 0.551
p-Xylene 0.155 0.104 0.089
o-Xylene 0.255 0.171 0.144
n-Hexane 2.617 1.422 1.598
2,2,4-Trimethylpentane 0.643 0.463 0.496
Totals 100.000 100.000 100.000
Page 1 of 3
TOTAL C31+EXTENDED REPORT
CERTIFICATE OF ANALYSIS
13/0
Components Mole%
Weight% Liq.Vol.
0.000
0.000 0.000
Carbon Dioxide 0.003 0.003
0.017 0.0003 0.003
MeNitthane
0.0000.003
Ethane 0.185 0.035 073
Propane 1.759 0.489 0.7190.Is°Bu9
0.712 0.261 0.346
n-Butanetane 4.126 1.512 1.931
2, 0.000 0.000 0 1.198
0 I
lsoPemafle ropane 2.207 1.004
IsoPentane
Pentane 1.780 2.106
2, 0.011 0.006 0.007 3.913 2-Dimethylbutane14
0.626 0.7
1.152 0. 14
2-Methylpentane 0.760 0.413
3-Methylpentane 0 417 0.476
460
0.768 0.417 0.476
Other Hexanes 2.617 1.598
8
MHexane 1.832 0.972 062
Benzene
0.522 0.257 0.217
CycloBenzene 0.952 0.505 0.4810.496
2,2,4- rimet 0.643 0.463 5.089
Other Heptan 1pentane 7.361 4.651
Other Heptanes 1.195 1.296
1.891 1.09126
MHeptane 1 828 1.132
Toluenelethylcyclohexane 0.000 0.000
0.000 3.388 3.619
4.704 1.2661
n-Octa
Octanes 1.665 1.199 1.266
Ethylb nz 1.920 1.285 1.099
m-Xyl enzene 0,955 0.641
m-Xylene 0.104 0.089
51
0.155 0.14409
o-Xylene-Xylene p255 0.171
1.621 1.668
Nona 2.004 1.668
n-No n n 1.122 0.907 0.7957
n-Nonane 0.758 0.795
Decanes 0.840 0.853
0.936 8.4730 8.535
U
n-Decane 8 59611.048
Dndecanes(C11) 10.350 11.116 1.0 8
Dodecanes(C13) 6.393 7.432 7.328
Tetrad ca (C13)s(C14) 4.281 5.355
Tetradecanes 64
4.606 4.4
Pentadecanes(C15) 3.438 4 66 4. 6
9
Hexadecanes(C16) 2.985 4.074 3.9091
Heptadecanes(C17) 2.687 2.299 3.690
3.540
Octadecanes(C18) 2.919 2.768
1,724 2.768
Eicosallonad es(C20)es(C 1.649 2.938
Eicosanes 3.053 2.873
1.633 3.053 2.873
Docosoanes(C21) 1.536 1.882
Docosanes(C22) O 960 1.965
Tricosanes(C23) 1.578 1.476
38
0.739 1.36957 1.476
Te ntaco apes(C24) 0.6151.274
Pentacosanes(C25) 0 482 1.113
Hexacosanes(C26) 0 913 1.067
904
0.394 0.7344 0.678
OctaconHeptacosanes(C27)8 0.2950.676
Octaconsanes(C28) 0 284 0.733
Tr
Nonacosanes(C29) 0.58673 0. 6
0.220 . 6 0.539
Hentriacont (C30) 0.710 100.0001.81
Totalacontanes Plus(C31+) 100.000 100.000
Totals
Page 2of3
CALCULATED SAMPLE CHARACTERISTICS
TRUE VAPOR PRESSURE AT 100 F, PSIA 10.180
AVERAGE MOLECULAR WEIGHT 158.592
AVERAGE BOILING POINT, F - 351.094
RELATIVE SPECIFIC GRAVITY OF DECANES+(C10+)FRACTION 0.77057
AVERAGE MOLECULAR WEIGHT OF DECANES+(C10+)FRACTION 216.834
BTU/GALLON OF LIQUID AT 14.73 PSIA 83,699.49
LBS/GALLON OF LIQUID 6.229
NOTATION:ALL CALCULATIONS PERFORMED USING PHYSICAL CONSTANTS FROM GPA 2145-
16,THE TABLES OF PHYSICAL CONSTANTS FOR HYDROCARBONS AND OTHER COMPOUNDS
OF INTEREST TO THE NATURAL GAS INDUSTRY.
FLASHED CRUDE OIL LIQUID STUDIES
Sample Name: Castor 8-59 19-24 Tank (Sales) Unpressurized Liquid
Sample Number: 18040430-02
TEST PERFORMED RESULTS DATE TESTED
REID VAPOR PRESSURE (ASTM D5191), PSI AT 100 F, measured 5.977 4/11/2018
SPECIFIC GRAVITY AT 60/60°F (ASTM D-7777) 0.8445 4/24/2018
API GRAVITY AT 60/60°F (ASTM D-7777),calculated from SG 36.05 4/24/2018
Page 3 of 3
Produced Water Tanks CO Permit Calculation Sheet .„.: x :.. ; *. ff°.`; State Emission Factors
c State Emission Factors(ib/bbl)
Operator Bi0RA9.64 i4-4 . Average API Sales Oil -;i,pe,,:,v-'s., ...r -.a,.,yyx County VOC Benzene n-Hexane
tom" 1' .' nt "' •• , Adams,Arapahoe,Boulder,Broomfield,Denver,
Site Name Soo .19"`att nl"0aftery "RVP Sales Oil Douglas,Jefferson,Lorimer,&Weld 0.262 0.007 0.022
Site AIRS Cret d3Ofl x,' PTE Annual Prod(Facility) 488357,6 BBL/year Garfield,Mesa,Rio Bianco,&Moffat 0.178 0.004 0.010
Location Description � ? atf tk80kf Max Annual Prod(Facility) s s Awls'eat/year Remainder of CO 0.262 0.007 0,022
hfi,Lat/long . ,& �458, W:,Operation time(hr/yr) n ,hr/year Estimated Uncontrolled Emissions-No EF
Num.Tanks(all manifolded
Attainment/Non? Fyon3LEdtdhte0k , vessels) `°. lb/yr tpy Source
Storage Tank ID (*WTnrrke Throughput(tank) 488337.6 bhl/yr VOC 1279445 63.97223 CDPHE
N Vessels in Storage Tank .', Throughput(tank) 20510179 gal/yr Benzene 3418.363 1.709182 CDPHE5
Most recent vessel install date :: .Sep10:Tank Color/Condition ll(,# fmftlir nn,New/food • n-Hexane 10743.43 5,371714 CDPHE5
Height(feet) • 24 Tank Material Stem( • 0. Estimated Controlled.Emissions-No EF
Width(ft) .r 15.5 Percent Control ,. ' 95% lb/yr tpy Source
Vessel Capacity(bbi) mo 2,750.Total Tank Capacity(hid) 2250 VOC 6397.223 3,198611 CONE''
t, Benzene 1709182 0.085459 CDPi1E
'[ierett(il'odo8tioissf#t rrieticts llflowste6 Mite-led three phaueheated separator ittise9paaater).Produced watef= :
Separation Device Description n-Hexane 537.1714 0,268586 CDPHE
frorrteadhsePulawilsedettgeWritmonprddueedweterheader4whish flows to the produced Water storage tanks, ..
Site Specific Emission Factor Required? No
Two)2.#75Dksbiatrriosphentcotdfagekertksferbulk produced watereref7)i),756-hbiatmosphericstarege tank fvr"xest° - -r
Tank Design - - :�
✓, xttnatit'prtSditced muter.All throe tanks are ligiid*manifpldedtogether,.... APEN Required?
Permit? Rae ,..
PTE Calculations
Site-specific Emission Factors not required for produced water at this location.Burner pilot gas emissions calculated as part of other point source calculations.
Pollutant Emission Factor(Ib/bbl) Calculated Potential Emissions Emission
Uncontrolled(ib/yr) Uncontrolled(tpy) Controlled lib/yr) Controlled(tpy) Factor Source
VOC 0.262 127944.4512 63.9722256 6397.22256 3.19861128 CDPHE
Benzene 0.007 3418.3632 1.7091816 170.91.816 0.08545908 CDPHE7
n-Hexane 0.022 10743.4272 5.3717136 537.17136 0.26858568 CDPHE
Combustion Pollutant EF(lb/mmbtu) EF Adjusted(lb/mmscf) Est.Flash Gas Volume immscf/yr} Controlled(lb/yr) Controlled(tpy) EF Source
NO x 0.068 101.728 17.5803536 1788.39 0.894196933 AP-42°
CO 0.31 463.76 17.5801536 8152,97 4.076486017 AP-425
Flash Gas Values for Produced Water Tank Combustion Emissions
Source
Heat Content 1496 btu/scf CDPHE°
Gas to Water Ratio(GOR) 36 scf/bbl CDPHE°
Emission Factor Source References
Reference Number Description Reference Document
PS Memo 14-03:Oil&Gas Industry Crude Oil,Condensate and Produced Water Atmospheric
CDPHE5 Produced Water standard tank emission factors for Colorado Storage Tanks Regulatory Definitions and Permitting Guidance for General Permit GP08
Heat content and Gas-to-Water Ratio standard values for PS Memo 14-03:Oil&Gas Industry Crude Oil,Condensate and Produced Water Atmospheric
CDPHE° Produced Water tanks in Colorado Storage Tanks Regulatory Definitions and Permitting Guidance for General Permit GP0&
AP-42 Table 13.5-1 THC,NOx,and soot emissions factors for flare operations for certain chemical
manufacturing processes.
AP-42 Table 13.5.1 THC,PDX,and soot emissions factors for NOe:0,068 lb/10°Btu
AP-42° flare operations for certain chemical manufacturing processes. Footnote:Factor developed using the higher(gross)heating value of the vent gas
AP-42 Table 13.5-2 VOC and CO emissions factors from elevated flare operations for certain
AP-42 Table 13.5-2 VOC and CO emissions factors from refinery and chemical manufacturing processes
elevated flare operations for certain refinery and chemical CO:0.31 lb/t0°8tu
AP-42' manufacturing processes Footnote:Factor developed using the lower(net)heating value of the vent gas
Separator Venting Calculations
• Calculation Sheets for PTE
• WinSim Simulation Results
Pressurized liquid sample data in included later in this Section
CO Vending and Flaring A7EN WorkSheet,:
Operates WORM g[0311010 Burner Calculations Burner Operational Hours Estimate
Site Name SuHhrSlgHC84874M166e{tefy An Foal Heat Value 2447 btu/set Production Start Date
Site AIRS Pehditrg.. Max gas rate 2.098.tout/hr Hare Start Date
Location Description 623h Section 147UN ROW Max gas rate mscf/day VRU Downtime Hours(initial) 0
lat(long 4p559674*1tNd,A5A95g Max gas rate SSW msd/year Est.VRU downtime hours(future) 876
Attainment/Non? I04B8Gariednent Operation Hours 876 hrs(yeer Total Est.VRU Downtime Hours 876
Equipment ID (9t86 ill l'atiVRT Downtime throughput 643$3.bbt future Downtime Hours Calculation
Nuer burners Molecular Wt.ai `. 43,P4 Hours in year 8760
Pilot gas/burner(msd/hour} _ _ in
Heat Output 5 mmbtu/ter Initial Downtime 0
Pilot annual hours `�",.,, Total Hours Year 89RO Renaming Hours 8760
Pilot fuel heat value(8TU/s'cl) _ VRUUptime 9096
pilot Heat Output IMMBTU/years(ail
boners) 0 Contour Percentage ..' 9674 Future Hours 876
#allfit wetrorneachweeekitu$n(ndM 4Dettil#t pre8tuen S.phcxcsaparataropsrs8rs0DiDitawt 54661pai8 Cm*alttmndhel+A separators flows into either 5616 iralnarates80r819/0n#trime
wettat ants}.InthebUActrein,werisHFBersarator4antlfiaroMtoitiittda4utkAcatlin'whtaia tiowshltaacamrnon$P awimP'rersme$uikj3.ghese zepx at0'f oner8Hpiat#m0xtrt16t1t6835 Mt
then Nen the Dolksemen:dor into nbulkVRTorS.patgaotlinto thebuikrnri#enN stop*tAnktlitintheaSs titre The LP saparazoeaiesentihrough the bulk YU wheat they nominee with VRT
flub ituirthnuWantteresentro attfilttimpor mammyitinmoot/fe4Ser.in'MeretttaRLthemink,allsintrilmCtlyfrom the HDseporotar#ba test VR70peretingatiapsf"and Menlo a'Yast°
snad##llstingsStati whtdt313kutdimantfaYdedtawU'w6rdk storage rennk3,.CNerhsutsQrcm the restVRTerezammingled matt thehUikWIend snot totD M,
8ecati€athsgpuvnrirn8dsatascett0hr8H(sVtifiabrd6VRT,thesimulation ahowndnodtffeenntetestw000 modeling it 8870eeleresttkreens nod mstteToy Slreentire sitevts thyhuik zoreetwro0Xhe
parr:H4 q/aUpermrillopkheretm^sthebnflc8Rieammerlalwaaschesanfor 01004
Process Descnytion iIr3Ft8eumj46$Villa A0Ytnt30P 0a148ru111,8pettteaiin8Vl67698t1804 Roa bat*oftrnutnnur4Tetrthnxflynsrlas(81905). '.....x triple irotwarstar$49194416141 mvistre3zFeeainr#utterusedasrepresenzztiuesatrg7tefcrtbtssitesinre production Darns lies begun.This semplewasomered into asimutannoin
WisitirriDerlistiprodesssintinetismoftwaroloisinsultitefthisinissionsfrom thot.plinienbSsnrBbrdki$operatarMrivetiorrerowetycAWBrb and cmiingil storagelaffies al ant$DMAICif
Calculation Methodologies 4Wntten4LP sersin8Er0W'X35i0r'9MP9Srisi&4H9u4Tpres93IIH of+p5lg based on 9perdtioneisPttib6Ratl64 site. .]
TWO Pdtantta!Em:sshaar _.'. ._.- ...
Uncontrolled Emission Factors Uncontrolled Controlled Venting Only Uric.EFs One OF(per 684 basis)
Pollutant Factor Units Source Ih/ter lb/year tpy !b/hr lb/yr tpy Factor Units Factor Units
NOx 166.3961b/mmsd AP-42',AP-42' 305.87 0,153 0.0097522091b/bbl
CO 758571b/mmsd AP-47',AP-42' 139440 0.697 O.021669484 lb/bbl
VOC 89791.66968 lb/mmsef AP-42`,Site-specific 0 164962 82.5 0.0 8248.1 4.124 89741.66968 lh/mmsef 2.562989526 lb/bbl
SO2 0 0 0
PM,PMI0,PM2.5 1823259902 lb/mmsef AP-422,Sdespecific 33.51 0.017
Benzene 537 203767 Ib/mmsef 60-42',Site-specific 0 987 4915901 0493745795 0 49,3745795 0.02468729 537,209767 lb/mmsef 0.01534248733/bbl
Toluene 544,9946514 lb/mmsef AP242',Site-specific 0 1001.803522 0500901761 0 5O0901761 0025095083 544.9946514 lb/mmsut 0.0155648516/1abl
Ethyibenzene 432.8049123 lb/mud AP-42',Slta.speditc 0 795 577653 0.397788827 0 39.7783827 0019889441 432.80499233b/mmsd 0 012360754 11 bi
Xylene 278 7815891 lb/mmsd AP-42',06e-specific 0 512 453429 0255225714 0 25.6226714 0.012811336 278.7315891 lb/mmsef 0.007961901 ib/bbl
n-9e84ne 2799.225785 Ib mmsd A17-42',Stir--s7e011ic 0 5053.598559 2.526799179 0 252.679918 0.126339969 2749.225786 Ib/mmsef 0.073515251 ib/bbi
224-1MP 433.4238143 Ib/Inmsct AP-42',Site•spectftc 0 796 7151651 0.398357583 0 39.8357583 0.019917879 433 9138143 Ib/mmsef 0.0123739271b/hhi
Total HAPs 0 9147.639718 4.57381%839 0 957.331986 02/8690993
"Vant0e0 Enriselons Calculations " '
VR70Mithna6Flph314e4 - Operating Parameters Uncontrolled Controlled
Combustion Pollutant Emission Factor(Ib/mmbti4 EF Source Adjusted EF ilb/mmset3 mmsef/yr Years ib/hr lb/year tpy (b/hr ib/yr tpy
NO it 0.068 AP-42' 166.398 1.83816964 1 305.3674033 305 8674033 0.162933702
CO 0.31 AP•42' 768.57 1.83818964 1 1394.395515 1394.395515 0.657197758
Combustion Pollutant Emission Factor(tb/mmset) EF Source Adjusted EF(Ib/mmsef( mmuf/yr Veen ih/hr lb/Year tpy tb/hr Ib/yr tpy
502 0 AP-42' 0 183818969 1 0 0 0
PM,PM10,PM2.5 7.6 461-42' 18.23254902 1.83818969, 1 33.51488272 33.51488272 0.016757441
General Gas Conversion Factors
Ideal Gas Conversion 379A sd/lb-mol tow.2441, btu/sd Wetly*Dens8y MW of Air 289647 g/� mol lib/IS-moi)
Total Got Flow 1838185 64 sof/yr OF Ratio 2.3990196 Avg.Molecular Weight 43:6396 Ib/ibmal
UnaSample-spad8eor Gemmel?t#annfat. _.,. 1N gy uses the Displacement ER ate:"Goners!enelhadalo nation IEiIC`)Non-Combustion Pollutant Overheads Composition Data Calculated Flows Uncontrolled Totet Controlled Total
Marl% Weight% mot/ye total lb/yr total lb/hr lb/year tpy lb/ter lb/yr tpy
Alcohols '� m . 0 0 0 0 0 0
Oxygen 0 0 0 0 0 0
002 1,1286g, „T,4886D 71,49656531 3146,468409 3146.468409 1.573234205 157.3234205 0,07856171
Harmon@.,;. A ' 0 0 0 0 0 0
Melharlo ikn pg ,ry 988.8723825 15864 4034 15864,4034 7.932291698 793.2201698 0.396610085
Ethane .. :.. r . .
188496 _ ,1 913.2759656 27460 3455 274603955 13.7303.7275 1373,017275 0.686508638
Propene 2,5(7 .. }y4 1362.30O075 60069 59613 60069.09613 30.03454807 3003454807 1.501727403
i•8utana ,.%4 . P 1� 167,706946 9747.104365 9747.104355 4.873552182 4873532182 0.243677909
n-8utane Rl94099' r 672.6737254 39035.74109 35095.79109 19.54787055 1954.787055 0.977393527
ePaton 2,87 Q9' ..'4.'4 139,4916555 7.0063.76828 10063.75828 5.031884141 503.1834141 0.251594207
loPentane ,4149%2 "'7n$; 210,7193233 16202.95319 15202 55319 7.601276594 ,760,1276594 0.33006363
2-0ethy0e0tann „99;666474� ._1,5 $ . ,,_ 31.90300698 2750030643 2750,030693 1.375015321 137,5015321 0.063750766
'iti
aMathylpmfaro , { t$4'50463 00750179' 198869929 1714.258239 17140E219 0,857129109 8511291093 0.042356455
YV ,fni' 0 0 0 0 0 0
Oyoluhanoov 3 73+8898,1 F 4tut ,r 73,541165 ( 13 5962564 1144 203968 1144 203968 0,572101984 57 21(119839 0.028605099 :.
n-Her/Wm 1t0s,19E 4 y ;'6943 A 113 9149473. 11414.04585 11414.04589 5.70/022943 570 7022943 0.285351147
3ctane° .4 8 007' w y;;'t`- A`(2-17820 27.36538533 3125578782. 3125.576782 1.562789391 156,2789391 0.07813947
0onanee L i54.oR y922- _ 59269d9oi1 649,7071822 :644.7071822 0.322353591 3223535921 0.03671768
000aeeeo i yt t O " i I. 5,310400993 843,4800232. 843.4800212 0421740011 4217400106 0,021087001
g & 4 0 0 0 0 0 0
Benzene '' 0 4'67046 1 12 64766574 987 4915901 98]4915901 0,493745795 49.3745795 0-02468729
Toluene 15,9.01 10 8/3322'32 1001.803522 -1001.803522 0,500901761 50.0901761 002S045088
7186tEtthylb n ens 1y f.,,kij47 b a$7G01.. 7.494135402 7955/'7653 795.577653 0.397733827 39 77838265. 0019889441
b.6;;:gr,q 3.505157293 372.1060022 3721060022 0-1136053001 13 8053011 000930265
,.yens ' A 1,0 ¢ 056347247 5932087323 59.82087323 0.029910437 2,991043451 0.101495522
0,059enn e 0.758531813 S0.52655349 80.52655349 0.040263277 4.026327674 0002013164
fist-Wane.
.36677726* 585457103 5053.598359 5053,598359 2.526759179 252.5799179 0.126339959
2,2.4oTnmelhvlpelnena v ,gvcb„q. ,4a9.",e .g.1,: ;. ti 6.97504305 796,7151651 796.7151651 0.398357583 39.33575326 0.019917879
IOW VOC 59.264 78.021 28/1.352024 164962.2075 164962.2075 82,48110374 8243,110374 4.124055187
Total(all comp00ents) 100.00 100:000 4844.996958 211433.4248 211433 4243 105.7167124 10571.67124 5.285835619
0
ISemplo Calculations 1
Molar Flow Rate-General
Unit conversion using general natural gas converslon factor
1/h- nul!(tnhof) F lb 7nl(a) lb-m921(al
.._- 3_ x IV0.1.f;.41,11 r{Mural)( -)x 1---.
71i.Isrf If/r 2b-mfdiLRnt) rpraar
Mass Flow Rate-General
Unit;omrveraion using general natural gas Conversion factor(Displacement Equation(EIIP`))
1.11)-rood • sr.:f rnassper cent lb lb
xAloxGasItatc:(total)( )x xMWtotal( )_-
370.4.sef lcr 100percent lb-meal fav
A1117total( !b )=MWair2&96471L x Rill alive Da'resitgt
lb-mat lb-vrsol
Emission Factor Source References
Reference Description Reference Document
AP-42 Chapter 1,Section 4 Natural Gas,Table 1,4-1 Emission Factors for Nitrogen Oxides(Nos)and Carbon Monoxide(CO)
From Natural Gas Combustion
Per Footnote:"The emission factors in this table may be converted to other natural gas heeling values by multiplying the
given emission factor:by the ratio of the specified heating value to this average heating value".(Where average heating
AP-42` NOs and CO Emission Factorstor small(4100 mmbtu/hr heat Input)uncontrolled boilers(Natural.Gas Combustion}value Is given as 1,020 btu/scf)
AP-42 Chapter 1,Section 4 Natural G. Table 1.4:2 Emistlun Factors for Criteria Pullotants and G nhouse Gases From
Natural Gas Combustion
Per Footnote:"rho emission factors in this table may be converted to other natural gas heating values by multiplying the
given emission factor by the ratio of the specified heating value to this average heating value".(Where:average heating
AP-42' Criteria Pollutant and Greenhouse GasEmlesion Factors(natural gas combustion) slue is give as 1,020 btu/set) .
AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-3 Emission Factors for Speciated Organic Compounds From Natural Gas
Cembuntlon
Per Footnote:"To convert from lb/106 scf to ib/MMBtu,divide by 1020"..Same method used to convert to higher HHV as
AP-4? Organic Compound Emission Factors with other AP-42 natural gas ccmbustion.satculations.
AP-42 Table 13.5-1 INC,NOX,and soot emissions faciorsfor flare pperatlons for certain chemical manufacturing processes.
N0X:.00068 lb/106 Btu
AP-42" 42 Table 13.5-1 THC,NOX,and soot emissions factors for flare operations for certain chemical manufacturing pro es Footnote Factor developed using the higher(gross)heating value of the vent gas
AP-42 Table 13,5-2 VOC and CO ensismons factors from-elevatedfl a operations:for certain refinery and chemical
manufacturing processes
AP-42 Table 13.5.2 V0C and CO anllsaion3 factors from elevated flare operations for certain refinery and chemical CO 0.31 lb/1068tu
AP-42' manufacturng processes Footnote',Factor developed using the lower(net):heating value of the vent gas •
"Volume II:Chapter 10,Preferred and Alternative Methods for Estimating Air Emissions from Ott and Gas Reid Production
and Processing Operations",Eastern Research Group,:Inc for.Point Sources Committee,:Emission Inventory Improvement
EPP' Displacement Equation(eq.10.4-3) Program.September 1999.
l;
1,
1
F
VRT Gas Out
139 F
643,632 US barrels(STP)/yr 5 09ig
142 F 2.0839 MSCF/hr
67 psig 2,447 Btu/SCF
LP Gas Out
HP Oil Out 141.9794 F 1
35 psig
A 0.21 MSCF/hr
1,796 Btu/SCF
x x x
c / Tank Flash Gas
` x ix x x 138.4E
r, x :VRT
LP Separator LP Oil Out x x 0.5 psig
141.9794 F .
35 psig
2,722387912 Btu/SCFSCF/hr
P
VRT Oil Out
fir• x x
139 F
5 psig x x
x x
Sales Oil
Boomslang 14B Air Permit Simulation Tanks
10/10/2019
S. McKibben I Quandary Consultants.
Details for Stream 5
Stream 5 (VRT Gas Out)
Thermodynamic Methods K-Value: PENG-ROB Enthalpy: PENG-ROB Density: STD
Vapor Visc: NBS81 Vapor ThC: NBS81 Vapor Den: STD
Flowrates
Component Name Total Vapor Incipient Liquid 1 Liquid 2 Solid Total K-Value
Ibmol/hr Ibmol/hr mol fra Ibmol/hr Ibmol/hr mole%
49:CARBON DIOXIDE 0.081599 0.081599 0.000285 0 0 1.47568 51.8652
46:NITROGEN 0 0 0 0 0 0 789.861
2:METHANE 1.1286 1.1286, 0.001368 0 0 20.4102 149.191
3:ETHANE 1.04232 1.04232 0.005365 0 0 18.8499 35.134
4:PROPANE 1.55479 1.55479 0.023127 0 0 28.1177 12.1578
5:1-BUTANE 0.191404 0.191404 0.006192 0 0 3.46145 5.59056
6:N-BUTANE 0.767722 0.767722 0.032682 0 0 13.8839 4.24818
7:1-PENTANE 0.159202 0.159202 0.015506 0 0 2.87909 1.85678
8:N-PENTANE 0.240494 0.240494 0.028345 0 0 4.34922 1.53437
52:2-METHYLPENTANE 0.036411 0.036411 0.008952 0 0 0.658474 0.735534
53:3-METHYLPENTANE 0.022697 0.022697 0.006096 0 0 0.410465 0.673328
38:CYCLOHEXANE 0.015517 0.015517 0.006123 0 0 0.280625 0.458285
11:N-HEPTANE 0.130011 0.130011 0.109151 0 0 2.35119 0.215407
12:N-OCTANE 0.03123 0.03123 0.06859 0 0 0.564783 0.082342
13:N-NONANE 0.005737 0.005737 0.032301 0 0 0.103756 0.032121
14:N-DECANE 0.001321 0.001321 0.019283 0 0 0.023886 0.012387
40:BENZENE 0.014429 0.014429 0.004659 0 0 0.260943 0.560136
41:TOLUENE 0.01241 0.01241 0.012127 0 0 0.224424 0.18506
45:ETHYL BENZENE 0.008553 0.008553 0.018482 0 0 0.154678 0.083692
43:M-XYLENE 0.004 0.004 0.010064 0 0 0.072346 0.071888
44:P-XYLENE 0.000643 0.000643 0.001625 0 0 0.01163 0.071562
42:O-XYLENE 0.000866 0.000866 0.002512 0 0 0.015656 0.06233
10:N-HEXANE 0.066932 0.066932 0.021318 0 0 1.21044 0.567794
82:2,2,4-1RIMETHYLP 0.007961 0.007961 0.006081 0 0 0.143964 0.23676
15:N-UNDECANE • 0.003217 0.003217 0.10957 0 0 0.058173 0.005309
16:N-000ECANE 0.000998 0.000998 0.081243 0 0 0.018051 0.002222
17:N-TRIDECANE 0.000339 0.000339 0.065185 0 0 0.006133 0.000941
18:N-TETRADECANE 0.000101 0.000101 0.048547 0 0 0.001832 0.000377
19:N-PENTADECANE 0.00003096 0.00003096 0.033508 0 0 0.00056 0.000167
20:N-HEXADECANE 0.00001107 0.00001107 0.027655 0 0 0.0002 0.00007241
21:N-HEPTADECANE 0.00004262 0.00004262 0.194057 0 0 0.000771 0.00003972
Total 5.52959 5.52959 1 0 0 100
Flowrates
Component Name Total Vapor Incipient Liquid 1 Liquid 2 Solid Total K-Value
lb/hr lb/hr mass fra lb/hr lb/hr mass%
49:CARBON DIOXIDE 3.59108 3.59108 0.000081 0 0 1.48816 51.8652
46:NITROGEN 0 0 0 0 0 0 789.861
2:METHANE 18.1061 18.1061 0.000142 0 0 7.50326 149.191
3:ETHANE 31.3405 31.3405 0.001046 0 0 12.9877 35.134
4:PROPANE 68.557 68.557 0.00661 0 0 28.4104 12.1578
5:I-BUTANE 11.1244 11.1244 0.002333 0 0 4.61001 5.59056
6:N-BUTANE 44.62 44.62 0.01231 0 0 18.4908 4.24818
7:1-PENTANE 11.4858 11.4858 0.00725 0 0 4.75978 1.85678
8:N-PENTANE 17.3507 17.3507 0.01326 0 0 7.19023 1.53437
52:2-METHYLPENTANE 3.13862 3.13862 0.005003 0 0 1.30066 0.735534
53:3-METHYLPENTANE 1.95649 1.95649 0.003407 0 0 0.810779 0.673328
38:CYCLOHEXANE 1.30588 1.30588 0.003341 0 0 0.541165 0.458285
11:N-HEPTANE ,13.0269 13.0269 0.0709 0 0 5.39841 0.215407
12:N-OCTANE 3.56724 3.56724 0.05079 0 0 1.47828 0.082342
13:N-NONANE 0.735806 0.735806 0.02686 0 0 0.304922 0.032121
14:N-DECANE 0.187922 0.187922 0.01779 0 0 0.077876 0.012387
40:BENZENE 1.12703 1.12703 0.002359 0 0 0.467046 0.560136
41:TOLUENE 1.14336 1.14336 0.00724 0 0 0.473815 0.18506
45:ETHYL BENZENE 0.907994 0.907994 0.01272 0 0 0.376278 0,083692
43:M-XYLENE 0.424684 0.424684 0.00693 0 0 0.175992 0.071888
44:P-XYLENE 0.068273 0.068273 0.001119 0 0 0.028293 0.071562
42:O-XYLENE 0.091904 0.091904 0.001729 0 0 0.038086 0.06233
10:N-HEXANE 5.76767 5.76767 0.01191 0 0 2.39016 0.567794
82:2,2,4-TRIMETHYLP 0.909293 0.909293 0.004503 0 0 0.376816 0.23676
15:N-UNDECANE 0.502778 0.502778 0.111 0 0 0.208354 0.005309
16:N-DODECANE 0.170011 0.170011 0.0897 0 0 0.070453 0.002222
17:N-TRIDECANE 0.062524 0.062524 0.0779 0 0 0.02591 0.000941
18:N-TETRADECANE 0.020101 0.020101 0.06244 0 0 0.00833 0.000377
19:N-PENTADECANE 0.006576 0.006576 0.04614 0 0 0.002725 0.000167
20:N-HEXADECANE 0.002507 0.002507 0.0406 0 0 0.001039 0.00007241
21:N-HEPTADECANE 0.010248 0.010248 0.3025 0 0 0.004247 0.00003972
Total 241.309 241.309 1 0 0 100
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total
ft3/hr ft3/hr ft3/hr ft3/hr ft3/hr volume%
49:CARBON DIOXIDE 26.2549 26.2549 0 0 0 1.47568
46:NITROGEN 0 0 0 0 0 0
2:METHANE 363.132 363.132 0 0 0 20.4102
3:ETHANE 335.372 335.372 0 0 0 18.8499
4:PROPANE 500.262 500.262 0 0 0 28.1177
5:I-BUTANE 61.5852 61.5852 0 0 0 3.46145
6:N-BUTANE 247.019 247.019 0 0 0 13.8839
7:I-PENTANE 51.2241 51.2241 0 0 0 2.87909
8:N-PENTANE 77.3802 77.3802 0 0 0 4.34922
52:2-METHYLPENTANE 11.7154 11.7154 0 0 0 0.658474
63:3-METHYLPENTANE 7.30289 7.30289 0 0 0 0.410465
38:CYCLOHEXANE 4.9928 4.9928 0 0 0 0.280625
11:N-HEPTANE 41.8318 41.8318 0 0 0 2.35119
12:N-OCTANE 10.0485 10.0485 0 0 0 0.564783
13:N-NONANE 1.846 1.846 0 0 0 0.103756
14:N-DECANE 0.424982 0.424982 0 0 0 0.023886
40:BENZENE 4.64263 4.64263 0 0 0 0.260943
41:TOLUENE 3.9929 3.9929 0 0 0 0.224424
45:ETHYL BENZENE 2.752 2.752 0 0 0 0.154678
43:M-XYLENE 1.28715 1.28715 0 0 0 0.072346 •
44:P-XYLENE 0.206925 0.206925 0 0 0 0.01163
42:O-XYLENE 0.278548 0.278548 0 0 0 0.015656
10:N-HEXANE 21.5358 21.5358 0 0 0 1.21044
82:2,2,4-TRIMETHYLP 2.56137 2.56137 0 0 0 0.143964
15:N-UNDECANE 1.03499 1.03499 0 0 0 0.058173
16:N-OODECANE 0.321156 0.321156 0 0 0 0.016051
17:N TRIDECANE 0.109124 0.109124 0 0 0 0.006133
18:N-TETRADECANE 0.032603 0.032603 0 0 0 0.001832
19:N.PENTADECANE 0.009962 0.009962 0 0 0 0.00056
20:N-HEXADECANE 0.003563 0.003563 0 0 0 0.0002
21:N-HEPTADECANE 0.013712 0.013712 0 0 0 0.000771
Total 1779.17 1779.17 0 0 .0 100
Flowrates
Component Name Total Vapor Liquid 1 Liquid 2 Solid Total
SCF/hr SCF/hr SCF/hr SCF/hr SCF/hr std vol%
49:CARBON DIOXIDE 30.9655 30.9655 0 0 0 1.47568
46:NITROGEN 0 0 0 0 0 0
2:METHANE 428.284 428.284 0 0 0 20.4102
3:ETHANE 395.543 395.543 0 0 0 18.8499
4:PROPANE 590.017 590.017 0 0 0 28.1177
5:1-BUTANE 72.6345 72.6345 0 0 0 3.46145
6:N-BUTANE 291.338 291.338 0 0 0 13.8839
7:1-PENTANE 60.4145 60.4145 0 0 0 2.87909
8:N-PENTANE 91.2635 91.2635 0 0 0 4.34922
52:2-METHYLPENTANE 13.8173 13.8173 0 0 0 0.658474
53:34VIETHYLPENTANE 8.61315 8.61315 0 0 0 0.410465
38:CYCLOHEXANE 5.88859 5.88859 0 0 0 0.280625
11:N-HEPTANE 49.3371 49.3371 0 0 0 2.35119
12:N-OCTANE 11.8513 11.8513 0 0 0 0.564783
13:N-NONANE 2.1772 2.1772 0 0 0 0.103756
14:N-DECANE 0.501231 0.501231 0 0 0 0.023886
40:BENZENE 5.47559 5.47559 0 0 0 0.260943
41:TOLUENE 4.70929 4.70929 0 0 0 0.224424
45:ETHYL BENZENE 3.24575 3.24575 0 0 0 0.154678
43:M-XYLENE 1.51809 1.51809 0 0 0 0.072346
44:P-XYLENE 0.24405 0.24405 0 0 0 0.01163
42:O-XYLENE 0.328524 0.328524 0 0 0 0.015656
10:N-HEXANE 25.3996 25.3996 0 0 0 1.21044
82:2,2,4-TRIMETHYLP 3.02092 3.02092 0 0 0 0.143964
15:N-UNDECANE 1.22069 1.22069 0 0 0 0.058173
16:N-000ECANE 0.378776 0.378776 0 0 0 0.018051
17:N-TRIDECANE 0.128702 0.128702 0 0 0 0.006133
i
18:N-TETRADECANE 0.038452 0.038452 0 0 0 0.001832
19:N-PENTADECANE 0.011749 0.011749 0 0 0 0.00056
20:N-HEXADECANE 0.004202 0.004202 0 0 0 0.0002
21:N-HEPTADECANE 0.016172 0.016172 0 0 0 0.000771
Total 2098.39 2098.39 0 0 0 100
Properties
Temperature F 139.0363
Pressure psia 19.696
Enthalpy Btu/hr 10345.55
Entropy Btu/hr/R 37.9746
Vapor Fraction 1
Total Vapor
Flowrate lbmol/hr 5.5296 5.5296
Flowrate Ib/hr 241.3093 241.3093
Mole Fraction 1 1
Mass Fraction 1 1
Molecular Weight 43.6396 43.6396
Enthalpy Btu/lbmol 1870.9444 1870.9444
Enthalpy Btu/lb 42.8726 42.8726
Entropy Btu/lbmol/R 6.8675 6.8675
Entropy Btu/lb/R 0.157369 0.157369
Cp Btu/lbmol/R 19.3582
Cp Btu/Ib/R 0.4436
Cv Btu/Ibmol/R 17.2689
Cv Btu/lb/R 0.3957
CpICv 1.121
Density Ib/ft3 0.13563
2-Factor 0.986338
Flowrate(T-P) ft3/s 0.494215
Flowrate(STP) MMSCFD 0.050361
Specific Gravity GPA STP
Viscosity cP 0.009889
Thermal Conductivity Btu/hr/ft/R 0.013696
Reid Vapor Pressure(ASTM-A) unconverged
True Vapor Pressure at 100 F psia 802
Critical Temperature(Cubic E F 250.3675
Critical Pressure(Cubic EOS) psia 1128.0323
Dew Point Temperature F 139.0446
Bubble Point Temperature F -216.9067
Hydrocarbon Dew Point Temp F 139.0446
Stream Vapor Pressure psia 936.0039 .
Vapor Sonic Velocity ft/s 861.61
CO2 Freeze Up No
CO2 Freeze Temperature F -69.826
Heating Value(gross) Btu/SCF 2446.5
Heating Value(net) Btu/SCF 2251.28
Wobbe Number Btu/SCF 1975.6
Average Hydrogen Atoms 7.7618 ,
Average Carbon Atoms 2.9428
Hydrogen to Carbon Ratio 2.6376
Methane Number 37.78
Motor Octane Number 96.6
Barrier Pilot Gas Combustioq-CO Permit Calcination Sheet-c.-:',., -,� � �-
Operator Bison Oil&Gas ft,11C Gas Flow Rate 20.5 scf/hr/burner Flow rate source Manufacturer
Site Name Elbetbs)ang148 Tank Battery Fuel HHV 1421 btu/scf HHV source Castor sales Gas Sample.3/2019
Site AIRS Pending Operating Hours 8760 Type EnciaSedQDmbustion Device
Location Description E2SESection 14T8N R60W Number Burners 4 Make 'CimaMrpn
Lat/Long 40.659078,-104.050458 Heat Output(per burner) mmbtu/hr Model 48"HV ECD
Attainment/Non? Nonattainment Heat Output(total) _mmbtu/hr Rating 11,71mmbtu/hr(max)
Burners used for: Combustion of tank and VRT Overhead vapors
Pilot Combustion Emissions(all burners)
Pollutant Emission Factor(lb/mmscf) Adjusted EF(Ib/mmscf) lb/hr lb/yr tpy EF Source
NO x 100 139.3137255 0.011424 100.0718353 0.050036 AP-422
CO 84 117.0235294 0.009596 84.06034165 0.04203 AP-422
VOC 5.5 7.662254902 0.000628 5.503950941 0.002752 AP-422
502 0 0 0 0 0 AP-422
PM,PM10,PM2.5 7.6 10.58784314 0.009868 7.605459482 0.003803 AP-422
Benzene 0.0021 0.002925588 2.4E-07 0.002101509 1.05E-06 AP-42'
Dichlorobenzene 0.00012 0.000167176 1.37E-08 0.000120086 6E-08 AP-423
Formaldehyde 0.075 0.104485294 8.57E-06 0.075053876 3.75E-05 AP-42'
Hexane 1.8 2.507647059 0.000206 1.801293035 0.000901 AP-42'
Toluene 0.0034 0.004736667 3.88E-07 0.003402442 1.7E-06 AP-42'
Total HAP 0.000215 1.881970949 0.000941
Methane 2.3 3.204215686 0.000263 2.301652212 0.001151 AP-422
CO2 120000 167176.4706 13.70847 120086.2024 60.0431 AP-42`
Total CO2e 13.72292 120212.7932 60.1064
Calculation Methodologies
Adjusted emission factor developed per instructions in footnote for AP-42 Table 1.4-1:"The emission factors in this table may be converted to other natural gas heating values by
multiplying the given emission factor by the ratio of the specified heating value to this average heating value(1020 btu/scf)"
Emission Factor Source References
Reference Description Reference Document
NO,,and CO Emission Factors for small(<100 mmbtu/hr heat AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-1 Emission Factors for Nitrogen Oxides
AP-42' input)uncontrolled boilers(Natural Gas Combustion) (Non)and Carbon Monoxide(CO)From Natural Gas Combustion
Criteria Pollutant and Greenhouse Gas Emission Factors AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-2 Emission Factors for Criteria Pollutants
AP-422 (natural gas combustion) and Greenhouse Gases From Natural Gas Combustion
'... AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-3 Emission Factors for Speciated Organic
''.� AP-423 Organic Compound Emission Factors Compounds From Natural Gas Combustion
Fugitives Calculation'Sheet for CO Air Permit,. , t ; a�_ ti r
Site Name: Boomslang 14B Tank Battery Type:Tank Battery Location: Weld Cty,CO;E2SE Section 14 T8N R60W
Final Fugitives Counts. .. - . .,w , + .-. + •,= Equipment Type Counts
Component Type Service Source Count Emissions(ib/hr) Operating Hours Emissions(lb/yr) Emissions(tpy) Source Horizontal Separator,small A
Valves Gas 184 0.010 8760 85.3 0.043 EPA' Horizontal Separator(bulk/LP) 1
Pump Seals Gas 0 0.000 8760 0.0 0.000 EPA' Vertical Separator,light crude service 2
Other Gas 30 0.008 8760 69.5 0.035 EPA' VRT(inc.header assembly)
Connectors Gas 426 0.009 8760 82.3 0.041 EPA' Burner Drip Pot(inc.blowcase) 2
Flanges Gas 92 0.001 8760 10.1 0.005 EPA' Oil Tank(includes loadout assembly) S
Open Ended Lines Gas 20 0.001 8760 5.8 0.003 EPA' Water Tank(includes loadout assembly) 3
Valves Light Oil 189 0.008 8760 69.4 0.035 EPA' Header,light crude service 2
Pump Seals Light Oil 9 0.010 8760 88.6 0.044 EPA' Header,gas service 2
Other Light Oil 109 0.026 8760 231.6 0.116 EPA' Header,oil/water service . 1
Connectors Light Oil 247 0.005 8760 46.3 0.023 EPA' Compressor-Gas Lift(EPA) 1
Flanges Light Oil 320 0.002 8760 14.8 0.007 EPA' Compressor-VRU(EPA) 1
Open Ended Lines Light Oil 70 0.002 8760 18.9 0.009 EPA' Water Pump 1
Valves Water/Oil 32 0.001 8760 6.0 0.003 EPA' Wellhead 4
Pump Seals Water/Oil 2 0.000 8760 0.9 0.000 EPA' Burner Assembly(inc.header from drip i 4
Other Water/Oil 13 0.002 8760 14.8 0.007 EPA' Generator,natural gas 0
Connectors Water/Oil 37 0.001, 8760 7.1 0.004 EPA` LACT Unit,light crude 1
Flanges Water/Oil 54 0.000 8760 3.0 0.002 EPA'
Open Ended Lines Water/Oil 18 0.000 8760 1.2 0.001 EPA'
Total' 0.38 tpy
individual Equipment Component Counts . - Table 2-8:Oil and Gas Production Operations Screening Ranges Emission Factors(EPA) ., -,,k.-,
210,000 <10,000 <10,000
ppmv ppmv ppmv
Emission Emission Emission
Component Type Service Count(ind) Count Total Factor Factor 210,000 ppmv Emission Factor Factor
Horizontal Sep 4 Equipment Type Service (kg/hr/sc(kg/hr/sow(Ib/hr/source) (Ib/hr/sou.
Valves Light Oil 16 64 Valves Gas 0.098 0.000024 0.21605374 5.29E-05
Pump Seals Light Oil 0 0 Heavy Oil n/a 0.0000084 n/a 1.85E-05
Other Light Oil 11 44 Light Oil 0.087 0.000019 0.19180281 4.19E-05
Connectors Light Oil 25 100 Water/Oil 0.064 0.0000097 0.14109632 2.14E-05
Flanges Light Oil 18 72 Pump Seals Gas 0.074 0.00035 0.16314262 0.000772
Open Ended Lines Light Oil 4 16 Heavy Oil n/a n/a n/a n/a
. Light Oil 0.1 0.00051 0.220463 0.001124
Header,light c 2 Water/Oil n/a 0.000024 n/a 5.29E-05
Valves Light Oil 7 14 Other Gas 0.089 0.00012 0.19621207 0.000265
Pump Seals Light Oil 0 0 Heavy Oil n/a 0.000032 n/a 7.05E-05
Other Light Oil 1 2 Light Oil 0.083 0.00011 0.18298429 0.000243
Connectors Light Oil 4 8 Water/Oil 0.069 0.000059 0.15211947 0.00013
Flanges Light Oil 20 40 Connectors Gas 0.026 0.00001 0.05732038 2.2E-05
Open Ended Lines Light Oil 3 6 Heavy Oil n/a 0.0000075 n/a 1.65E-05
Light Oil 0.026 0.0000097 0.05732038 2.14E-05
Header,gas se 2 Water/Oil 0.028 0.00001 0.06172964 2.2E-05
Valves Gas 7 14 Flanges Gas 0.082 0.0000057 0.18077966 1.26E-05
Pump Seals Gas 0 0 Heavy Oil n/a 3.9E-07 n/a 8.6E-07
Other Gas 1 2 Light Oil 0.073 0.0000024 0.16093799 5.29E-06
Connectors Gas 4 8 Water/Oil n/a 0.0000029 n/a 6.39E-06
Flanges Gas 20 40 Open-Ended Lines Gas 0.055 0.000015 0.12125465 3.31E-05
Open Ended Lines Gas 3 6 Heavy Oil 0.03 0.0000072 0.0661389 1.59E-05
Light Oil 0.044 0.000014 0.09700372 3.09E-05
Header,oil/wa 1 Water/Oil 0.03 0.0000035 0.0661389 7.72E-06
Valves Water/Oil 7 7
Pump Seals Water/Oil 0 0 Emission Factor Sources
Other Water/Oil 1 1 EPA' EPA"EPA-453:Protocol for Equipment Leak Emission Estimates".1995.
Connectors Water/Oil 4 4
Flanges Water/Oil 20 20
Open Ended Lines Water/Oil 3 3
Sum of Count Total Column Labels
Wellhead 4 Row Labels Gas Light Oil Water/Oil Grand Total
Valves Light Oil 7 28 Connectors 426 247 37 710
Pump Seals Light Oil 0 0 Flanges 92 320 54 466
Other Light Oil 2 8 Open Ended Lines 20 70 18 108
Connectors Light Oil 4 16 Other 30 109 13 152
- Flanges Light Oil 10 40 Pump Seals 0 9 2 11
Open Ended Lines Light Oil 0 0 Valves 184 189 32 405
Grand Total 752 944 156 1852
Compressor-C 1
Valves Gas 73 73
Pump Seals Gas 0 0
Other Gas 10 10
Connectors Gas 179 179
Flanges Gas 20 20
Open Ended Lines Gas 3 3
Compressor-k 1
Valves Gas 73 73
Pump Seals Gas 0 0
Other Gas 10 10
Connectors Gas 179 179
Flanges Gas 20 20
Open Ended Lines Gas 3 3
Water Pump 1
Valves Water/Oil 6 6
Pump Seals Water/Oil 2 2
Other Water/Oil 2 2
Connectors Water/Oil 4 4
Flanges Water/Oil 10 10
Open Ended Lines Water/Oil 1 1
l
1
VRT(inc.heath 2
Valves Light Oil 5 10
Pump Seals Light Oil 0 0
Other Light Oil 2 4
Connectors Light Oil 4 8
Flanges Light Oil 20 40
Open Ended Lines Light Oil 2 4
Oil Tank(incluc 5
Valves Light Oil 3 15
Pump Seals Light Oil 0 0
Other Light Oil 2 10
Connectors Light Oil 3 15
Flanges Light Oil 6 30
Open Ended Lines Light Oil 4 20
Burner Assemt 4
Valves Gas 6 24
Pump Seals Gas 0 0
Other Gas 2 8
Connectors Gas 15 60
Flanges Gas 3 12
Open Ended Lines Gas 2 8
Burner Drip Po 2
Valves Water/Oil 5 10
Pump Seals Water/Oil 0 0
Other Water/Oil 2 4
Connectors Water/Oil 10 20
Flanges Water/Oil 3 6
Open Ended Lines Water/Oil 1 2
Water Tank(ir 3
Valves Water/Oil 3 9
Pump Seals Water/Oil 0 0
Other Water/Oil 2 6
Connectors Water/OII 3 9
Flanges Water/Oil 6 18
Open Ended Lines Water/Oil 4 12
Vertical Separa 2
Valves Light Oil 6 12
Pump Seals Light Oil 0 0
Other Light Oil 5 10
Connectors Light Oil 10 20
Flanges Light Oil 10 20
Open Ended Lines Light Oil 4 8
Generator,nat 0
Valves Gas 0
Pump Seals Gas 0
Other Gas 0
Connectors Gas 0
Flanges Gas 0
Open Ended Lines Gas 0
Horizontal Sep 1
Valves Light Oil 16 16
Pump Seals Light Oil 0 0
Other Light Oil 11 11
Connectors Light Oil 25 25
Flanges Light Oil 18 18
Open Ended Lines Light Oil 4 4
LACT Unit,ligh 1
Valves Light Oil 30 30
Pump Seals Light Oil 9 9
Other Light Oil 20 20
Connectors Light Oil 55 55
Flanges Light Oil 60 60
Open Ended Lines Light Oil 12 12
BurnerPlbtGas:Combustion=„CO Permit CalculationSheet::>
3-Phase Separator Burners
Operator & S tf/U.0 Gas Flow Rate 232 scf/hr/burner Flow rate source 1ttu#tft�
motes has e
Site Name $o00 s(atf$24B an ttety":;",Fuel HHV 1421 btu/scf HHV source :aAkar
Site AIRS Pending Operating Hours 4780 Type F(rettibefti* atfi tdbt r U
Location Description L25C- ti tl14,T ki.88,)W-, Number Burners , Make fXrPoint
Lat/Long ,48:650078 1Q4490-4 - `Heat Output(per burner) O18 mmbtu/hr Model
Attainment/Non? lithe .ta< ntent� ,Heat Output(total) 0.9375 mmbtu/hr Rating 37 mmbtu/hr
Burners used for: iilairfifiWngtemperatdir*'setpointinthrei-ihaseseparators.Aastirbb-W fmaRr tingduringnormetOperatit5
Pilot Combustion Emissions(all burners)
Pollutant Emission Factor(lb/mmscf) Adjusted EF(Ib/mmscf) lb/hr lb/yr tpy EF Source
NO x 100 139.3137255 0.091912 805:1470588 0.402574 AP-421
CO 84 117.0235294 0.077206 676.3235294 0.338162 AP-42'
VOC 5.5 7.662254902 0.005055 44.28308824 0.022142 AP-42?
SO2 0 0 0 0 0 AP-422
PM,PM10,PM2.5 7.6 10.58784314 0.006985 61.19117647 0.030596 AP-422
Benzene 0.0021 0.002925588 1.93E-06 0.016908088 8.45E-06 AP-423
Dichlorobenzene 0.00012 0.000167176 , 1.1E-07 0.000966176 4.83E-07 AP-423
Formaldehyde 0.075 0.104485294 6.89E-05 0.603860294 0.000302 AP-423
Hexane 1.8 2.507647059 0.001654 14.49264706 0.007246 AP-423
Toluene 0.0034 0.004736667 3.13E-06 0.027375 1.37E-05 AP-423
Total HAP 0.001729 15.14175662 0.007571
Calculation Methodologies
Adjusted emission factor developed per instructions in footnote for AP-42 Table 1.4-1:"The emission factors in this table may be converted to other natural gas heating
values by multiplying the given emission factor by the ratio of the specified heating value to this average heating value(1020 btu/scf)"
Emission Factor Source References
Reference Description Reference Document
NO),and CO Emission Factors for small(<100 mmbtu/hr heat AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-1 Emission Factors for Nitrogen
AP-421 input)uncontrolled boilers(Natural Gas Combustion) Oxides(Nox)and Carbon Monoxide(CO)From Natural Gas Combustion
Criteria Pollutant and Greenhouse Gas Emission Factors AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-2 Emission Factors for Criteria
AP-422 (natural gas combustion) Pollutants and Greenhouse Gases From Natural Gas Combustion
AP-42 Chapter 1,Section 4 Natural Gas.Table 1.4-3 Emission Factors for Speciated
AP-423 Organic Compound Emission Factors Organic Compounds From Natural Gas Combustion
TrudttoWeut-CO ParMt6kschtbn Short ., r s. �„ .z a .. ..
Operator 811.0n011&403 ei API Sales Oil A6.05 deg
Site Name BOOMS1en$log 7.ank8ettery: RVP Sales Oil .5.977 psi at 100F APEN/GP07 Eligibility Determination
Site AIRS Pending Facility Annual Prod(POE) 18000 BBL/year Material/Conditions l H yes to any.OPEN required lif yea to any,ark for GPO]
Location Description E250 Section-1471N.MOW Tank Annual Prod(PTE) 180000B1/year Crude Oil
let/long 40i859078,10(.050/58 Operation tune(hr/yrt 8760 hr/Year
Attainment/Non?NOnattatnmeM Tank Max Daily Prod(PIE) 49 BBL/day 10 Spy VOC or less? :�`n/a-not A►EN tatpdnd
Storage Tank ID for Loadout Tank Max Daily Prod(PTE) 2071 gal/day Condensate
A Vessels in Storage Tank Tank Annual Prod)PTE) 18000 bbl/year (splash l)> 50 '
loadout System ID fill Method Submerge FMconfildensatethan per yearb1t '^r Ali�tfOdl OR t 5 f.rhVC^;3"+%'
Emission Control Method +yy ,aa C
Emission Control Percent Using Man Factor?Yes (submerge fill)more than16308 nG,' T R/a MIMI O8 c Yall, y� �f ,,k a,%,oar:
Loadouk System Design barrels of condensate peryear? 'c,+4 . ` ' _ .a q 'ill OQA ''>'a"
IO t0y VOC or 1365) , >n/8watudeg4.'. _
State Embalm factors(PS Memo 14-02)
Liquid Type VOC)8t/bbi) Benzene(16/661) n-Neaane(ib/bbl)
Crude Oil 0104 0.000181 0.0016
Condensate 0.236 0.000416 0.00361
liquid Type for this facility: Dude 09::..
Stet.Emission Factor Cakuletions
Uncontrolled Controlled _
Pollutant lb/hr 1Ofye toy Ib/hr lb/yr tpy EF Source
VOC 0.213698133 1872 0.936 0.11969863 1872 0.936 COPHE'
Benzene 0.000371918 3.258 0.001629 0,000371918 3.258 0001629 COPHE'
mHelene 0.003287671 28.8 0.0144 0.003287671 1 28.8 0.0144 COPHE'
PEE CekuMbne-Truck Loadout ...
EmNabn Factor(Ib/bbl) Calculated Potential Emissions Emission FactorSeurce
Pollutant Uncontrolled(lb/yr) Uncontrolled(tpy) Controlled(lb/yr) Controlled(Spy)
VOC 0.104 1872.00 0.94 1872.03 0.94 CDPHE(51
Benzene 0030181 3.26 0.00 3.26 0.00 CDPHE(5)
n.Hexane 0.0016 28.80 001 28.80 0.01 COPHE(5)
Est.Flesh Gas Relume
Combustion Pollutant EF jib/mmbtu) EF Adjusted(Ib/mmsci) (mmarf/yr) Controlled(1bM) Controlled(toy) EF Source
NOx 0.068 185.096 0 0.00 0 APd2a
CO 0.31 843.82 0 0.00 0 APd2'
Nash Gas Values for Oil/Condensate Standout Combustion Emissions Use state beat and GOR values?No
Source Manual Entry Heat Content and GOR Values
Heat Content 2722 btu/scf CDPHE(4) Heat Content. 2722 btu/scf Simulation
Gas/OII Ratio(GOR) 6.335500634 scf/bbl CDPHE(4) Gas/Oil Patio(GOR) 6,34 scf/bbl Simulation
Emission factor Source References
Reference Number Description Reference Document
Produced Water standard tank emission factors for PS Memo 14-03-Oil&Gas Industry Crude Oil,Condensate and Produced Water Atmospheric Storage
CDPHE' Colorado Tanks Regulatory Definitions and Permitting Guidance for General Permit GP08
Heat content and Gas-to-Water Ratio standard values for PS Memo 14-03.Oil&Gas Industry Crude Ill,Condensate and Produced Water Atmospheric Storage
CDPHE' Crude Oil and Condensate tanks in Colorado Tanks Regulatory Definitions and Permitting Guidance for General Permit GP08
AP-42 Table 13.5.1 THC,NO,and soot emissions factors for flare operations for certain chemical
AP-42 Table 13.5-1 THC,NOO,and soot emissions factors nufatturind Processes.
for flare operations for certain chemical manufacturing NO):0.068 lb/10'Btu
AP-42a processes. Footnote:Factor developed using the higher(gross)heating value of the vent gas
APd2 Table 1352 VOC and CO emissions factors from elevated flare operations for certain refinery
AP-42 Table 13.5 2 VOC and CO emissions factors from and chemical manufacturing processes -
elevated flare operations for certain refinery and chemical CO:0.31 Ib/10'Btu
AP-42' manufacturing processes Footnote:Factor developed using the lower(net)healing value of the vent gas
Standard emission rectors for crude oil loadout for COPHE APCD PS Memo 14-02:011&Gas Industry Hydrocarbon Liquid bailout General Permit GPO?
CDPHE' Colorado Regulatory Definitions and Permitting Guidance
APd2' AP-42 Loading Loss Equation AP-42 Section 5.2:liquid loading Equation
AP-42 Section 7.1,Figure 7.14313 Equation for true vapor pressure of crude oils with a Reid vapor
`APd2' AP-42 TVP from RVP calculations pressure of 2 to IS pounds per square inch
CDPHE COLORADO
Form APCD-101 �
CO Department of Public
Health & Environment
Company Contact Information Form
Ver.September 10,2008
Company Name: Bison Oil & Gas II, LLC
Source Name: Boomslang 14B Tank Battery
Permit Compliance
Shannon McKibben
Contact': Contact': Abigail Wenk
55 E 4th Ave 518 17th St, Ste 1800
Address: Street Address: Street
Denver CO 80203 Denver CO 80202
City State Zip City State Zip
Phone Number: (720) 937-5429 Phone Number: (720) 644-6997 x4
Fax Number: Fax Number:
E-mail: smckibben@quandaryconsultants.com E-mail: awenk@bisonog.com
Billing Contact: Abigail Wenk Billing Contact: Abigail Wenk
(Permit Fees)3 g (Annual Fees
518 17th St, Ste 1800 518 17th St, Ste 1800
Address: Street Address: Street
Denver CO 80202 Denver CO 80202
City State Zip City State Zip
Phone Number: (720) 644-6997 x4 Phone Number: (720) 644-6997 x4
Fax Number: Fax Number:
E-mail: awenk@bisonog.com E-mail: awenk@bisonog.com
Check how would you like to receive your permit fee invoice?
Mail: ❑ E-mail: Q Fax: ❑
Footnotes:
' The permit contact should be the point of contact for technical information contained in the permit application.
This may be a company representative or a consultant.
2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted
facility.
3 The billing contact(Permit fees)should be the point of contact that should receive the invoice for fees
associated with processing the permit application&issuing the permit.(Reg. 3,Part A, Section VI.B)
The billing contact(Annual fees)should be the point of contact that should receive the invoices issued on an
annual basis for fees associated with actual emissions reported on APENs for the facility.(Reg.3,Part A,
Section VI.C)
Page 1 of 1 AP_Fonn-APC D-101-Company-Contact-Information(2).doc
Ambient Air Impact Analysis
Boomslang 14B Tank Battery
According to the Colorado Modeling Guideline for Air Quality Permits document developed by CDPHE,
new sources are not required to complete an ambient air impact analysis if emission thresholds will be
below listed modeling thresholds.
These modeling thresholds are listed in the table below:
Pollutant Requested Emission Rate from New Source or Facility-Wide Net
Emissions Increase from a Modification
Long Term (tons per year) Short Term(pounds per hour)
Carbon Monoxide(CO) 23 pounds per hour
Nitrogen Oxides(NOx) 40 0.46
Sulfur Dioxide(SO2) 40 0.46
Particulate Matter< 101-rm (PMlo) 82 pounds per day
Particulate Matter<2.5 µm (PM2.$) 5 11 pounds per day
Lead (Pb) 25 pounds per 3 months
In addition,an Ambient Air Impact may be required for sources below listed threshold but with the
following characteristics:
• Sources of SO2,NO2,PM10, PM2.5,CO,or Pb where a substantial portion of the new or modified
emissions have poor dispersion characteristics (e.g., rain caps, horizontal stacks,fugitive
releases,or building downwash) in close proximity to ambient air at the site boundary
• Sources located in complex terrain(e.g.,terrain above stack heights in close proximity to the
source)
• Sources located in areas with poor existing air quality
• Modification at existing major sources, including grandfathered sources that have never been
modeled before
This source generates emissions less than the threshold quantities of all pollutants listed in this table.
The Boomslang 14B Tank Battery facility is located in the 8-Hour Ozone Nonattainment Area but
because it is not an existing major source and emission levels of all listed pollutants are significantly
below threshold quantities,an Ambient Air Impact Analysis is not required.
•
L jorm AP4'D.102,__j Colorado Department of Public Health and Environment
Air Pollution Control nlnla.nm L. P H.
•
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Process Description and Flow Diagram
Boomslang 14B Tank Battery well production facility
The following summary describes the proposed process flow of the`Boomslang 14B Tank Battery"well
production facility.
The facility will have four(4) crude oil wells.Oil flows from each well into an individual high-pressure 3-
phase separator operating between 60-80 psig.Crude oil from the HP separators flows into either a bulk
train or a test train (only one well at a time). In the bulk train,each HP separator sends crude oil into a
bulk header which flows into a common LP(Low Pressure Bulk)3-phase separator operating at a
maximum of 35 psig,then from the bulk separator into a bulk VRT operating at between 1 and 6 psig
(average maximum 5 psig)and into the bulk crude oil storage tanks. In the test train,the crude oil is sent
directly from the HP separator to a test VRT operating at between 1 and 6 psig(average maximum S
psig)and then to a"test"crude oil storage tank,which is liquid-manifolded to the bulk storage tanks.
Crude oil is pumped through an electrically-powered LACT unit into a pipeline offsite.Crude oil and
produced water tank vapors go into a vapor header which sends them to a bank of enclosed combustion
units(ECUs).
Overheads from the LP separator are sent through the bulk VRT where they commingle with VRT flash
overheads and are sent to an electrically-powered VRU (vapor recovery unit)compressor which
compresses the vapors and sends them into the gas sales pipeline.Overheads from the test VRT are
commingled with the overheads from the bulk VRT and sent to the VRU. In the event of VRU downtime,
a valve will open at 6 psig at each VRT overhead gas outlet,sending VRT overheads to a bank of enclosed
combustion units(ECUs).
Produced water is sent from each of the individual HP separators into a common produced water
header and then into a set of produced water storage tanks. Produced water is then pumped from these
storage tanks through an electrically-powered LACT unit to a disposal well located offsite.
Gas from the sales line can be bought back and reinjected to the wellbores via an electrically-driven gas-
lift compressor.
41/41/4 cDPHE ' C O L O R A D O Form APCD-308
CO ( Air Pollution Control Division
•
D1:paru, r t PUbil. :{<•�Ith b E ri._rnment
Air Pollution Control Division
Operating and Maintenance Plan Template for
Crude Oil Storage Tanks
Ver. January 1, 2018
The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (0&M Plan) for crude
oil storage tanks that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the
State of Colorado.An O&M Plan shall be submitted with the permit application when required. One O&M Plan may
be used for multiple tanks at one facility if each are controlled and monitored in the same manner.
If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit
will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed
correctly, the Division will work with the operator to make corrections. Once a construction permit is issued, the
facility operator must comply with the requirements of the 0&M Plan upon commencement of operation. An
existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator
must adhere to the requirements of the existing approved O&M Plan until an approval letter is issued for the new
O&M Plan.
The operator is required to use the Division-developed O&M Plan template forms in order to meet minimum
expectations within a standard, organized format. Do not modify the structure and/or content of this template.
If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the
operator shall follow the most stringent regulatory requirement.
For sources that are subject to the Title V Operating Permits program: in accordance with Colorado
Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this 0&M plan will be
incorporated as specific conditions in the sources Operating Permit, and in some cases permit limits will be
established for certain operational parameters.
Submittal Date: 10/14/2019
Section 1 - Source Identification
For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the
time of application. Please only fill in the fields that are known and leave the others blank.
Company Name: Bison Oil&Gas II,LLC Facility E2SE Section 14 T8N R6OW;Weld Cty,
Location: CO
Facility Name: Boomslang 14B Tank Battery Facility AIRS ID(for existing facilities) -
Emission Units Covered by this O&M form
Facility Equipment ID Crude Oil
Tanks
Permit Number /9wEa09
AIRS Point ID 6GI
Page 1 of 4
APCD Internal Use Only
Approved?❑ Initial Date
CDPHE COLORADO
CO Air Pollution Control Division
;rtr>t,crd 1,AM L.Ern.ror
Section 2 - Maintenance Schedules
Check one of the following:
Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions
• unit and control devices. These schedules and practices, as well as all maintenance records showing
compliance with these recommendations, shall be made available to the Division upon request.
Facility shall follow individually developed maintenance practices and schedules for the operation and
maintenance of equipment and control devices. These schedules and practices, as well as all
❑ maintenance records showing adherence to these practices, shall be made available to the Division upon
request and shall be consistent with good air pollution control practices for minimizing emissions as
defined in the New Source Performance Standard (NSPS) general conditions.
Section 3 - Recordkeeping Requirements
The following box must be checked for the O&M Plan to be considered complete:
Synthetic minor and major sources are required to maintain maintenance and monitoring records for
® the requirements of this O&M Plan for a period of five (5) years. If applicable state requirements or
any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply
with the longest record retention requirement.
Section 4 - Monitoring Requirements
Check one of the following two boxes:
Check this box to confirm that the storage vessel(s)are subject to the requirements of Regulation No.
7, Sections XVII.C.2. and C.3. By checking this box, the operator confirms adherence to the operating,
® maintenance, and recordkeeping requirements of the Storage Tank Emission Management System
("STEM") as developed and implemented by the operator, as required by Regulation No. 7, Sections
XVII.C.2. and C.3.
Check this box if the storage vessel(s)are not subject to the requirements of Regulation No.7,Sections
XVII.C.2. and C.3. ("STEM"). Leakage to the atmosphere shall be minimized as follows:
• Thief hatch seals shall be inspected monthly for integrity and replaced as necessary;
• Thief hatch covers shall be properly weighted and seated to ensure flashing,working,and breathing
losses (as applicable) are routed to the control device under normal operating conditions;
• Pressure relief valves (PRV) shall be inspected monthly for proper operation and repaired or
replaced as necessary;
• PRVs shall be set to release at a pressure that will ensure flashing, working, and breathing losses
(as applicable)are routed to the control device under normal operating conditions; and
• Inspections shall be documented with an indication of status, a description of any problems found,
and their resolution (e.g., adjustments made to thief hatch weight cover weight or PRV setpoint,
including the modified settings).
Page 2 of 4
A CDPHE ! COLORADO
CO Air Pollution Control Division
,
up_partrert cf P b I fea''11&',rvi'
Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of
control equipment and the requested permitted emissions at the facility. Indicate the storage tank emissions
control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency"
based on the facility-wide permitted VOC emissions.
Table 1
Emissions Control Monitoring Frequency
or Parameter n Permitted ® Permitted
Recycling Method Facility Emissions Facility Emissions
80 tpy VOC < 80 tpy VOC
Pilot Light and Auto-igniter
Enclosed Flare or Daily Weekly
ElCombustor Monitoring b
Visible Emissions Observation C Daily Weekly
Pilot Light and Auto-igniter Daily Weekly
Elevated Open Flare a ❑ Monitoring
Visible Emissions Observation C Daily Weekly
Vapor Recovery Unit Monitoring requirements,including parameters and frequency,to be determined
(VRU)or Recycled or n by the operator and listed below,and approved by the Division
Closed Loop System d
Monitoring requirements including specific parameters and frequency to be
Other n determined by the operator and described in Section 5 below,and approved by
the Division
a Elevated Open Flare
If the storage tank is subject to Regulation No. 7, Section XII or Section XVII, the use of an open flare must be
approved by the Division as an alternate emission control device prior to operation in accordance with
Regulation No. 7 Section XVII.B.2.e.; see PS Memo 15-03. Open flares permitted prior to May 1, 2014 are
approved for operation. All new open flares permitted on or after May 1, 2014 are required to obtain Division
approval prior to operation.
b Pilot Light Monitoring Options
If the tanks are controlled by flare or combustor, then the operator must indicate in Table 2 the method by
which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be
checked and, optionally, up to two backup methods may be checked.
Table 2: Pilot Light Monitoring
Primary Back-up Monitoring Method
❑ Visual Inspection
n ❑ Optical Sensor
U ® Auto-Igniter Signal
❑ ❑ Thermocouple
Visible Emissions Observation and Method 22 Options
At the frequency specified in Table 1,the operator is required to conduct an inspection of the subject combustion
device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible
emissions inspection, the operator has the option to either(1)immediately shut-in the equipment to investigate
the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed;
or(2)conduct a formal Method 22 observation to determine whether visible emissions(as defined per Regulation
No. 7, Section XVII.A.16.) are present.
Page 3 of 4
cDPF1E , COLORADO
CO Air Pollution Control Division
r partrr.':.nt cif Put f.t -t.
If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this
O1tM Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the
operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed;
if repair cannot be immediately completed, the operator shall shut-in the equipment, conduct any necessary
repairs, and maintain records of the specific repairs completed.
d Vapor Recovery Unit(VRU)or Recycled or Closed Loop System
In the space provided below, please provide a brief description of the emission control or recycling system,
including an explanation of parameters monitored, monitoring frequency, and how the system design ensures
that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also,
provide a description of how downtime is tracked and recorded.
Tank vapors are sent to a common tank vapor header sized according to APCD's"Storage Tank and Vapor Control
Sstems Guidelines"document(May 4,2018).All vapors are controlled by enclosed combustion units.No VRU or
recycle or closed loop system will be in use to control tank emissons.
Section 5 - Additional Notes and O&M Activities
Please use this section to describe any additional notes or operation and maintenance activities, or if additional
space was required from a previous section. Attach additional pages if necessary.
Page 4 of 4
CDPHE C O L O R A D O
CO 1j Air Pollution Control Division Form APCD-309
17cpartme.!'r fiubl;c I l alth&Em:^.r r,rrwnt
Air Pollution Control Division
Operating and Maintenance Plan Template for
Separators'
Ver. January 1, 2018
1 This term "separators"is intended throughout to include two-phase separators, three-phase separators, high/low pressure
separators, heater-treaters,vapor recovery towers, etc., and the associated air pollution control equipment.
The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (OEM Plan) for
separator(s)that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State
of Colorado. An OEM Plan shall be submitted with the permit application when required. One OEM Plan may be
used for multiple separators at one facility if each are controlled and monitored in the same manner.
If the OEM Plan template is completed correctly, the Division will approve the OEM Plan and a construction permit
will be issued with the requirement to follow the OEM Plan as submitted. If the template is not completed
correctly, the Division will work with the operator to make corrections. Once a construction permit is issued, the
facility operator must comply with the requirements of the OEM Plan upon commencement of operation. An
existing approved OEM Plan may be modified without a permit modification or permit reissuance, but the operator
must adhere to the requirements of the existing approved OEM Plan until an approval letter is issued for the new
OEM Plan.
The operator is required to use the Division-developed OEM Plan template forms in order to meet minimum
expectations within a standard, organized format. Do not modify the structure and/or content of this template.
If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the
operator shall follow the most stringent regulatory requirement.
For sources that are subject to the Title V Operating Permits program: in accordance with Colorado
Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this OEM plan will be
incorporated as specific conditions in the source's Operating Permit, and in some cases permit limits will be
established for certain operational parameters.
Submittal Date: 10/14/2019
Section 1 - Source Identification
For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the
time of application. Please only fill in the fields that are known and leave the others blank.
Company Name: Bison Oil&Gas I1,LLC Facility E2SE Section 14 T8N R60W;Weld Cty,
Location: CO
Facility Name: Boomslang 14B Tank Battery Facility AIRS ID(for existing facilities) -
Emission Units Covered by this OEM form
Facility Equipment ID - Bulk VRT Test VRT
Permit Number /9wricc`tvt/El16"
AIRS Point ID Oc C"-
APCD Internal Use Only Page 1 of 6
Approved?El Initial Date
* COPHE : COLORADO
yv
1r ''‘e Air Pollution Control Division
L 2..1.
Section 2 - Maintenance Schedules
Check one of the following:
Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions
® unit and control devices. These schedules and practices, as well as all maintenance records showing
compliance with these recommendations, shall be made available to the Division upon request.
Facility shall follow individually developed maintenance practices and schedules for the operation and
maintenance of equipment and control devices. These schedules and practices, as well as all
maintenance records showing adherence to these practices, shall be made available to the Division upon
request and shall be consistent with good air pollution control practices for minimizing emissions as
defined in the New Source Performance Standard (NSPS)general conditions.
Confirm the following requirement, if the separator has a pressure relief valve (PRV):
The operator shall inspect the separator pressure relief valve (PRV) at a minimum once every calendar
® year. The inspection shalt include a check that the PRV set point is adequate to ensure that emissions
are routed to the emissions control device during normal operation. Records of these inspections, and
any repairs, shall be made available to the Division upon request.
Section 3 - Recordkeeping Requirements
The following box must be checked for the O&M Plan to be considered complete:
Synthetic minor and major sources are required to maintain maintenance and monitoring records for
® the requirements of this OM Plan for a period of five (5) years. If applicable state requirements or
any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply
with the longest record retention requirement.
Page 2 of 6
441/4 cDPHE COLORADO
CO Air Pollution Control Division
Dep rtment of Pu lto Hialtit a Enk,irn -m,mr
Section 4 - Monitoring Requirements
Process Equipment Information
The following boxes must be checked for the O&M Plan to be considered complete:
Attach a diagram or plot plan of the configuration of the separator(s), control device(s), and vapor
® recovery unit(s), as well as the location(s)of flow meters. This diagram is required in addition to the
facility-wide diagram required for new permit applications. This diagram shall be retained with the
0&M Plan for reference by the operator and Division inspector.
The permit requires calculation and recordkeeping of actual emissions from this source, but the calculation
methods are not incorporated into the permit. In the space below, describe the formulas used to calculate the
volume of gas vented from the separator and sent to the control device, using data from the meter if required.
If using a vapor recovery tower(VRT), describe the method used to calculate the volume of gas vented from the
VRT. If the permit throughput limit is in terms of hydrocarbon liquid, then in the space below describe how the
liquid throughput shall be tracked.
Examples:
Flow meter at enclosed flare directly measures the volume of gas sent to flare from a single separator.
OR
Volume from low pressure separator sent to control device=(Metered volume through high pressure separator)-(Metered volume through low pressure separator)
OR
Volume vented from VRT=(Total gas volume metered at flare)-(Metered volume to flare from low pressure separator)-(Volume to flare from tanks)
OR
Permit throughput limit is based on hydrocarbon liquid,which is tracked by tank inlet meter,with backup of sales/haul tickets.
OR etc.
Please be clear and specific about the sources of input data,and describe how the input data is collected and recorded.Attach additional pages if needed.
Permitted point is for overheads sent to the ECD's in the event of VRU downtime.
VRU downtime is tracked using on-skid instrumentation provided by the VRU compressor vendor.
Liquid throughput during VRU downtime is tracked using the oil meters at the outlet of each High-Pressure
Separator (4 total - one for each well). Because all overheads from both the test and bulk streams are
combined in this point, total oil throughput from all HP separators at the site will be the representative
factor.
The sum of daily crude oil throughput at the HP Separator meters will be correlated with the period of
recorded VRU downtime to calculate emissions during that downtime period.
Page 3 of 6
CDPHE C O L O R A D O
CO vi Air Pollution Control Division
I epartrne,t o`f`,D't s ieai n E fe lvu rr,
Control Equipment Information
Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of
control equipment and the requested permitted emissions at the facility. Indicate the separator emissions control
by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency"based on
the facility-wide permitted VOC emissions.
Table 1
Emissions Control or
Recycling Method Monitoring Frequency
Parameter ❑ Permitted ® Permitted
Facility Emissions Facility Emissions
Primary Backup t 80 tpy VOC < 80 tpy VOC
Pilot Light and Auto- Daily Weekly
Enclosed Flare or n ® igniter Monitoring
Combustor Visible Emissions
Observation Daily Weekly
Pilot Light and Auto- Daily Weekly
Elevated Open igniter Monitoring
Flare a ❑ El igniter
Emissions
Observation Daily Weekly
Vapor Recovery Monitoring requirements, including parameters and frequency,
Unit(VRU)or ® ❑ to be determined by the operator and listed below, and
Recycled or Closed approved bythe Division
Loop System d PP
Monitoring requirements including specific parameters and
Other ❑ n frequency to be determined by the operator and described in
Section 5 below, and approved by the Division
a Elevated Open Flare
An open flare permitted after May 1, 2014 and used to comply with Regulation No. 7 Section XVII must be
approved by the Division as an alternate emission control device prior to operation, in accordance with
Regulation No. 7 Section XVII.B.2.e.; see PS Memo 15-03.
b Pilot Light Monitoring Options
If emissions are controlled by flare or combustor, then the operator must indicate in Table 2 the method by
which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be
checked and, optionally, up to two backup methods may be checked.
Table 2: Pilot Light Monitoring
Primary Back-up Monitoring Method
❑ _ Visual Inspection
❑ ❑ Optical Sensor
❑ ® _ Auto-Igniter Signal
Li U _ Thermocouple
Visible Emissions Observation and Method 22 Options
At the frequency specified in Table 1,the operator is required to conduct an inspection of the subject combustion
device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible
emissions inspection, the operator has the option to either(1)immediately shut-in the equipment to investigate
Page 4 of 6
CDPHE LORADO
CO Air Pollution Control Division
Depart,t;:•nt of 1't(1).tc 14.a th fr t•tvircnrr;nt
the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed;
or(2)conduct a formal Method 22 observation to determine whether visible emissions(as defined per Regulation
No. 7, Section XVII.A.16.)are present.
If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this
0&M Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the
operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed;
if repair cannot be immediately completed, the operator shall shut-in the equipment, conduct any necessary
repairs, and maintain records of the specific repairs completed.
If the equipment is subject to Regulation No. 7, Section XII.E, operators must document the required inspections
for the presence or absence of smoke. The Division has historically approved a "check box" to satisfy the
documentation procedures referenced in Section XII. The Division will continue to accept the "check box"
recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance
with Regulation No. 7 Section XII.E.4.a.
If a flare is not subject to Regulation No. 7 requirements (as described in the permit), a similar approach may
be employed where the operator may conduct an inspection for presence or absence of smoke, and, if smoke is
observed, the operator has the option to (1) immediately conduct repairs and maintain records of the specific
repairs completed; (2) shut-in the equipment to investigate the cause of the smoke, conduct any necessary
repairs, and maintain records of the specific repairs completed; or (3) conduct a formal Method 9 observation
to determine the opacity of the visible emissions, and conduct repairs if necessary.
d Vapor Recovery Unit(VRU)or Recycled or Closed Loop System
In the space provided below, please provide a brief description of the emission control or recycling system,
including an explanation of parameters monitored, monitoring frequency, and how the system design ensures
that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also,
provide a description of how downtime is tracked and recorded. Attach additional pages if necessary.
The overhead vapors from the VRT's are combined into a gas header which is sent to the suction of the electrically-
driven rental Vapor Recovery Unit compressor.In the event that the VRU compressor goes down,the suction valve will
close,causing pressure to build in the VRT overhead lines.A valve in each VRT overhead line is set to open to the bank
of high pressure combustors if pressure in the overhead line builds to 6 psig.VRT overheads will continue to go to the
combustors until pressure in the line drops below 6 psig,which would occur either upon cessation of production or
reopening of the VRU suction valve and restarting the VRU.
VRU downtime is tracked through an on-unit computer provided by the compressor vendor which will either
be downloaded from the unit on a monthly basis or sent in realtime to a website from which the data can
be downloaded by Bison personnel.
Section 5 - Additional Notes and OEM Activities
Please use this section to describe any additional notes or operation and maintenance activities, or if additional
space is needed from a previous section. Attach additional pages if necessary.
Page 5 of 6
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OIL&GAS II
COLORADO AIR PERMIT DETAILED
REGULATORY ANALYSIS
CONSTRUCTION PERMIT FOR OIL& GAS TANK BATTERY
Owner/Operator: Bison Oil & Gas II, LLC
Facility Name: Boomslang 14B Tank Battery
Facility Weld County, CO
Location: E2SE Section 14 T8N R6OW
Analysis Date: 10/13/2019
Prepared by:
Quandary Consultants, LLC
55 E 4th Ave, Denver, CO 80203
SITE SUMMARY
The Boomslang 14B Tank Battery is a proposed newly-constructed crude oil-producing tank battery
located in Weld County,CO within the 8-Hour Ozone Nonattainment Area.This analysis encompasses a
proposed facility in which initial upstream processing(separation,storage,and gas and liquids
transportation)will be performed for four(4)newly-drilled wells.
The proposed facility utilizes a"bulk and test"method in which each well flows to an individual high-
pressure 3-phase separator,which performs initial separation of crude oil,produced water,and produced
gas. Produced water is sent to atmospheric storage tanks and then pumped via pipeline LACT to a
disposal facility. Before flowing to atmospheric storage tanks,crude oil flows either to a crude oil header
and then to a low-pressure 3-phase polishing separator and then to a lower-pressure bulk vapor recovery
tower,or directly from the individual high pressure 3-phase separator to a test stream vapor recovery
tower.The test stream will flow to one crude oil tank while the bulk stream will flow to a bank of four
crude oil tanks. All the crude oil storage tanks are liquid-manifolded together and sold via pipeline LACT.
Low-pressure overheads are sent to a VRU compressor and then to the sales gas pipeline.Tank vapors are
controlled by enclosed combustion devices.A gas lift compressor will be utilized for enhanced
production. All engines at the site will be electrically-driven.
The proposed facility will have estimated actual uncontrolled tank emissions greater than 6 tpy for the
highest-emitting set of crude oil production tanks.The facility will have five(5)total crude oil production
vessels,all liquid-manifolded together,so the facility is considered to have one(1)crude oil storage
"tank"per the definition of a tank as a bank of vessels liquid-manifolded together.
Pneumatic devices at the facility are natural gas-actuated and are all either intermittent-bleed or
continuous low-bleed rated devices.
The facility has no internal combustion engines,glycol dehydrators,or natural gas-operated pneumatic
pumps.
1 FEDERAL OPERATING PERMITS
1.1 NEW SOURCE REVIEW (NSR)
This facility is a newly-constructed source in a designated moderate nonattainment area for VOC
and NOx,for which New Source Review is required if emissions of either NOx or VOC exceed
100 tpy.The facility will emit less than 100 tpy of both NOx and VOC and is therefore not
subject to New Source Review for criteria pollutants.
1.1.1 GHG TAILORING
New Source Review is also required for sources with PTE greater than 100,000 tpy of
CO2 equivalent emissions(CO2e)and greater than 250 tpy of Greenhouse Gas emissions.
This facility will emit CO2,below 100,000 tpy and is therefore not subject to New Source
Review under the GHG Tailoring provision.
1.2 PREVENTION OF SIGNIFICANT DETERIORATION (PSD)
The source type for this facility is subject to PSD review if calculated Potential To Emit(PTE)
exceeds 250 tpy for any criteria pollutant.The PTE for this facility does not exceed 250 tpy for
any criteria pollutant and is therefore not subject to PSD review.
2 FEDERAL NEW SOURCE PERFORMANCE STANDARDS
(NSPS)
2.1 SUBPART KB
Standards of Performance for Volatile Organic Liquid Storage Vessels(Including Petroleum
Liquid Storage Vessels)for Which Construction, Reconstruction, or Modification Commenced
After July 23, 1984
The storage vessels at this facility are located prior to custody transfer at an exploration and
production site so they are not subject to this subpart.
2.2 SUBPART 0000
Standards of`Performance for Crude Oil and Natural Gas Production, Transmission and
Distribution for which Construction, Modification or Reconstruction Commenced after August
23, 2011, and on or before September 18, 2015
All wells and surface operations at this site commenced after September 18,2015 so this facility
is not subject to this subpart.
2.3 SUBPART 0000A
Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction,
Modification or Reconstruction Commenced after September 18, 2015
Affected Facilities
The wells associated with this site are classified as hydraulically fractured oil wells with a
completion date after September 18,2015 and are therefore an affected facility under this subpart.
This facility was constructed after September 18, 2015 and therefore an affected subpart for
fugitives monitoring under this subpart.The storage vessels associated with this site individually
emit greater than 6 tpy VOC when controlled and are therefore an affected facility under this
subpart.
Non-affected Facilities
Any associated compressors are located at the well site and are not an affected facility under this
subpart.The natural gas-actuated pneumatic devices at this site are either intermittent,low,or no
bleed and emit less than 6 scf/hr and are therefore not an affected facility under this subpart.
2.4 SUBPART 1111
Standards of Performance for Stationary Compression Ignition Internal Combustion Engines
The facility has no compression-ignition driven engines and is not subject to this subpart.
2.5 SUBPART JJJJ
Standards of Performance for Stationary Spark Ignition Internal Combustion Engines
This facility has no spark-ignition internal combustion engines and is therefore not subject to this
subpart.All engines at this site are electric.
3 FEDERAL NATIONAL EMISSION STANDARDS FOR
HAZARDOUS AIR POLLUTANTS (NESHAPS)
3.1 SUBPART HH
National Emission Standards for Hazardous Air Pollutants from Oil and Natural Gas Production
Facilities
This facility is designated as an area source of Hazardous Air Pollutants(HAPs). For area
sources,potentially affected equipment is triethylene glycol(TEG)dehydration units.This
facility has no TEG dehydration units and is therefore not subject to HH requirements.
3.2 SUBPART ZZZZ
National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal
Combustion Engines
This facility does not have any internal combustion engines and is not subject to this regulation.
4 MANDATORY GREENHOUSE GAS REPORTING [40 CFR
98]
This facility is an oil and gas production facility located in a basin in which the operator has operations
that exceed the threshold for mandatory greenhouse gas reporting as of Reporting Year 2019.Operations
at this facility will be reported under Subpart W.
5 BLM
This facility includes federal minerals and is subject to BLM regulations and orders regarding onshore oil
and gas production.
6 STATE OF COLORADO REGULATION 3
6.1 PART A
Air Pollution Emission Notice(APEN)documents are included in this application for all non-
APEN-exempt sources: crude oil storage tanks,produced water tanks,and venting from VRT
separators.
6.2 PART B (CONSTRUCTION PERMITS)
This application requests a combination of general permits and individual construction permits
for applicable point sources.This application for general permits and individual construction
permits is being submitted prior to the initiation of production at the facility but after initial
construction has begun. Per AQCC Regulation Number 3 (5 CCR 1001-5)Part B,Section
II.D.l.l1l this is an oil and gas exploration and production operation that is not required to submit
an APEN until ninety days following the first day of production.
6.3 PART C (OPERATING PERMITS)
This facility is not a major source for any criteria pollutants and is therefore not required to obtain
an operating permit.
6.4 PART D (MAJOR STATIONARY SOURCES AND PSD)
This facility is not a major source for any criteria pollutants and therefore this section does not
apply to this facility.
7 STATE OF COLORADO REGULATION 6
Regulation 6 incorporates by reference the EPA's New Source Performance Standards.This facility's
applicability to these standards is discussed in the corresponding section of this Analysis.
8 STATE OF COLORADO REGULATION 7
8.1 SECTION XII: VOLATILE ORGANIC COMPOUND EMISSIONS
FROM OIL AND GAS OPERATORS
This facility is a crude oil production facility in the designated 8-Hour Ozone Nonattainment
Area and is therefore not subject to the individual control requirements,system-wide control
strategy,inspection requirements,and recordkeeping and reporting requirements Regulation 7,
Section XII.
8.2 SECTION XVII: STATEWIDE CONTROLS FOR OIL AND GAS
OPERATIONS AND NATURAL GAS-FIRED RECIPROCATING
INTERNAL COMBUSTION ENGINES
8.2.1 XVII.B: GENERAL PROVISIONS
1. The site will abide by all applicable control requirements in this section
2. Open-ended valves or lines at this facility will be either equipped with a cap,
blind flange,plug,or second valve that seals the open end at all times except
during operations requiring process fluid flow or are monitored as components.
3. The proposed site has no centrifugal compressors and has one reciprocating
compressor but is not subject to XVII.B.3.c because the facility is not a natural
gas compressor station.
8.2.2 XVII.C: EMISSION REDUCTION FROM STORAGE TANKS
1. This site will abide by all control,inspection,and recordkeeping requirements of
this plan.
2. This site will develop and implement a STEM plan within ninety(90)days of the
date of first production,which will be on file at the Bison corporate office in
Denver,CO.
8.2.3 XVII.D: GLYCOL DEHYDRATORS
This facility has no glycol dehydrators and is not subject to this section.
8.2.4 XVII.E: NATURAL GAS-FIRED RICE
All engines at the site are electric so the site is not subject to this section.
8.2.5 XVILF: LDAR
This site has instituted an LDAR program incorporating AIMM and AVO methods and is
inspecting,tracking,recording,and repairing all leaks according to the requirements of
this regulation. Leak detection and repair records are maintained at the Bison corporate
offices in Denver,CO.
8.2.6 XVII.G: CONTROL OF EMISSIONS FROM WELL PRODUCTION FACILITIES
All separator gas from this site is either sold down a pipeline or combusted with
combustion devices with a design destruction efficiency greater than 98%for
hydrocarbons.
8.2.7 XVII.H: VENTING DURING DOWNHOLE WELL MAINTENANCE AND
LIQUIDS UNLOADING EVENTS
This location abides by the requirements of this section.
8.3 SECTION XVIII: NATURAL GAS-ACTUATED PNEUMATIC
CONTROLLERS ASSOCIATED WITH OIL AND GAS
OPERATIONS
This facility is located upstream of a natural gas processing plant,in the 8-Hour Ozone
Nonattainment Area.All natural gas-actuated pneumatic controllers are intermittent or continuous
low-bleed and have been inventoried and are being inspected and enhanced response activities
performed according to the requirements of this regulation.Records of pneumatic device
specifications and inspection results are maintained at the Bison corporate offices in Denver,CO.
9 STATE OF COLORADO REGULATION 8
Regulation 8 incorporates by reference the EPA's National Emission Standards for Hazardous Air
Pollutants(NESHAPs).This facility's applicability to these standards is discussed in the corresponding
section of this Analysis.
Colorado Department of Public Health and Environment 1 COP H E
Form APCD-105 Air Pollution Control Division
Colorado Oil & Gas Conservation Commission (COGCC)
805 Series Requirements
Ver.March 30,2015
Company Name: Bison Oil & Gas II LLC
Source Name(s): Boomslang 14B Tank Battery
Source AIRS ID(s)1:
PART A—COGCC Applicability to Tanks(Condensate,Crude Oil,and Produced Water)2
Yes No
1. Are uncontrolled actual emissions of volatile organic compounds(VOCs) 5 tons per
year or greater? (Note that for the purposes of Rule 805"uncontrolled actual ✓
emissions"are as defined in Colorado Regulation 3, Part A, Section I.B.46. For new
sources, annual projected uncontrolled actual emissions shall be used.)
2. Is the tank located within 'A mile of a Building Unit4 or Designated Outside Activity
Area4? I y I
If answers to both questions are"yes",COGCC Section 805.b.(2).A is applicable to this source.
PART B—COGCC Applicability to Glycol Dehydrators)
Yes No
1. Are uncontrolled actual emissions of volatile organic compounds(VOCs) 5 tons per
year or greater?(Note that for the purposes of Rule 805 "uncontrolled actual
emissions"are as defined in Colorado Regulation 3, Part A, Section I.B.46. For new 1;11
sources, annual projected uncontrolled actual emissions shall be used.)
2. Is the glycol dehydrator located within 'A mile of a building unit, educational
facility, assembly building,hospital,nursing home,board and care facility,jail, or n 1
designated outside activity area?
If answers to both questions are"yes", COGCC Section 805.b.(2).B is applicable to this source.
PART C—COGCC Section 805 Series3
Crude Oil,Condensate,and Produced Water Tanks-COGCC Section 805.b.(2)A: "Crude Oil,
Condensate, and Produced Water Tanks.All crude oil, condensate, and produced water tanks with
uncontrolled actual emissions of volatile organic compounds(VOC) offive (5) tons per year(tpy)or
greater, located within 1,320 feet of a Building Unit, or a Designated Outside Activity Area shall use an
emission control device capable of achieving 95%control efficiency of VOC and shall obtain a permit
as required by Colorado Department of Public Health and Environment,Air Pollution Control
Commission Regulation as set forth in 805. b. (1). "
Glycol Dehydrators-COGCC Section 805.b.(2).B: "All glycol dehydrators with uncontrolled actual
emissions of VOC offive (5) tpy or greater, located within 1,320 feet of a Building Unit, or a
Page 1 of 2FormAPCD-105-COGCC805SeriesRules-Ver.3-30-2015-Branded.doc
Colorado Department of Public Health and Environment i CD P H E
Air Pollution Control DivisionCO
> ►
Designated Outside Activity Area shall use an emission control device capable of achieving 90%control
efficiency of VOC and shall obtain a permit as required by Colorado Department of Public Health and
Environment, Air Pollution Control Commission Regulation as set forth in 805.b.(1)."
Footnotes:
Source Aerometric Information Retrieval System Identification(AIRS ID)refers to the 10-digit ID,made up of county,
source,and equipment codes. If an AIRS ID has not been assigned by the APCD,equipment ID(s)provided by the
applicant on corresponding Air Pollutant Emission Notices(APENs)may be provided in place of AIRS ID(s). Provide all
applicable IDs on this form,as described by the Guidance Document for Form APCD-100.
2 Section A or B may be left blank if the application does not include this type of emission source
3 Section C is provided for general information. The complete 805 series rules may be found at http://cogcc.state.co.us/
°. Definitions of Building Unit and Designated Outside Activity Area are contained in the COGCC Series 100 rule.
Page 2 of 2FormAPCD-105-COGCC805SeriesRules-Ver.3-30-2015-Branded.doc
r M1
CDPHE Crude Oil Storage Tank(s) APEN .
Form APCD-210
CO 1 Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is
filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require
payment for a new filing fee.
This APEN is to be used for tanks that store crude oil associated with oil and gas industry operations. If your
emission source does not fall into this category, there may be a more specific APEN available for your source(e.g.
condensate storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the
General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A
list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division
(APCD)website at:www.colorado.gov/pacific/cdphe/air-permits.
This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term,or when a reportable change is made(significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: (9 WE,00 l AIRS ID Number: 123 /Am + / C (
[Leave blank.unless APCD has already assigned a permit n and AIRS ID]
Section 1 - Administrative Information
Company Name': Bison Oil & Gas II, LLC
Site Name: Boomslang 14B Tank Battery
Site Location'
Site Location:
E2SE Section 14 T8N R6OW County: Weld
NAICS or SIC Code: 211120
Mailing Address:
(Include Zip Code) 518 17th Street, Suite 1800
Denver, CO 80202 Contact Person: Abigail Wenk
•
Phone Number: 720-644-6997 x41
E-Mail Address2: awenk@bisonog.com
1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear
on all documents issued by the APCD.Any changes will require additional paperwork.
2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided.
70
IlIl COLORA OO
Form APCD-210 Crude Oil Storage Tanks)APEN Revision 3/2019 1 I ma
Permit Number: AIRS ID Number:
[Leap=e blank unless APCD has already assigned a permit and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly-reported emission source
L] Request coverage under traditional construction permit
❑ Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of$312.50 must be
submitted along with the APEN filing fee.
-OR-
❑ MODIFICATION to existing permit(check each box below that applies)
❑ Change in equipment ❑ Change company name3
❑ Change permit limit ❑ Transfer of ownership' 0 Other(describe below)
-OR-
❑ APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
❑ APEN submittal for permit exemptfgrandfathered source
❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE)
Additional Info Et Notes: Site has not begun production. Emission factors and other site-specific data estimated
from data at Castor 8-59 19 tank battery for permitting purposes.
3 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted.
4 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted.
Section 3 - General Information
General description of equipment and purpose: Crude oil storage tanks
Company equipment Identification No. (optional):
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year
Storage tank(s)located at: Q Exploration&Production(E&P)site ❑ Midstream or Downstream(non EEtP)site
Will this equipment be operated in any NAAQS nonattainment area? Q Yes ❑ No
Are Flash Emissions anticipated from these storage tanks? ❑✓ Yes ❑ No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 0 Yes ✓❑ No
805 series rules? If so, submit Form APCD-105.
Are you requesting a 6 ton/yr VOC emissions(per storage tank), or are uncontrolled actual ❑✓ Yes ❑ No
emissions>_6 ton/yr(per storage tank)?
COLORADO
Form APCD-210 Crude Oil Storage Tank(s)APFN - Revision 3/2019 2 I LORA
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has alread j assigned a permit=and AIRS ID)
Section 4 - Storage Tank(s) Information
Actual Annual Amount Requested Annual Permit Limits
(bbl/year) (bbl/year)
Crude Oil Throughput: 643632
From what year is the actual annual amount? n/a
Average API gravity of sales oil: 36.05 degrees RVP of sales oil: 5.977
Tank design: 0 Fixed roof ❑ Internal floating roof ❑ External floating roof
Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First
Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production
(bbl) Storage Tank(month/year) (month/year)
Crude Tanks 5 3750 9/2019 tbd
Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only)
API Number Name of Welt Newly Reported Well
05 - 123 -47111 Boomslang Fed 8-60#14B-13-18-2 0
05 - 123 -47120 Boomslang Fed 8-60#14B-13-18-3 ❑✓
05 - 123 -47116 Boomslang Fed 8-60#14B-13-18-4 0
05 - 123 -47117 Boomslang Fed 8-60#14B-13-18-5 0
- ❑
5 Requested values wilt become permit limitations. Requested limit(s)should consider future growth.
6 The EEtP Storage Tank APEN Addendum(Form APCD-212)should be completed and attached when additional space is needed to
report all webs that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.659078, -104.050458
Operator Stack Discharge Height Above Temp. Flow Rate Velocity
ID No. Ground Level(feet) (°F) (ACFM) (ft/sec)
Indicate the direction of the stack outlet: (check one)
0 Upward 0 Downward 0 Upward with obstructing raincap
❑Horizontal ❑Other(describe):
Indicate the stack opening and size: (check one)
0 Circular Interior stack diameter(inches):
❑Square/rectangle Interior stack width(inches): Inte(inc hrior stack depth
es):
0 Other(describe):
[O1ORADO
Form APCD-210 Crude Oil Storage Tank(s)APEN - Revision 3/2019 3 1 AV
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assiii3ned a permit and AIRS ID]
Section 6 - Control Device Information
0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Pollutants Controlled:
Vapor Size: Make/Model:
❑ Recovery
Unit(VRU): Requested Control Efficiency:
VRU Downtime or Bypassed(emissions vented): %
Pollutants Controlled: VOC, HAPs (BTEX, n-Hexane, 2,2,4-TMP)
Rating: 11.7 MMBtu/hr
Type: Enclosed Burner Make/Model:Cimarron 48" HV ECD
Combustion Requested Control Efficiency: 95 %
Device:
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: Waste Gas Heat Content: 2722 Btu/scf
Constant Pilot Light: El Yes ❑ No Pilot Burner Rating: MMBtu/hr
Description of the closed loop system:
❑ Closed Loop System
Pollutants Controlled:
❑ Other: Description:
Control Efficiency Requested: %
Section 7 - Gas/Liquids Separation Technology Information (E&P Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 1-6 psig
Describe the separation process between the well and the storage tanks: Oil flows from each well into an individual high pressure
3-phase separator operating between 60-60 psig.Crude oil from the HP separators flows into either a bulk train or a test train(only one well at a time).In the bulk train,each HP separator sends
crude oil into a bulk header winch lbws into a common LP(Low Pressure Bulk)3-phase separator operating at a maximum of 35 pstg.then from me bulk separator Into a bulk VRT et 5 pslg and Into the bulk crude oll storage tanks.
In the test train,the crude oil is sent directly from the HP separator to a test VRT operating at 5 psig and then to a'test'crude oil storage tank,which is liquid-manifotded to the bulk storage tanks.
COLORADO
Form APCD-210 Crude Oil Storage Tanks) APEN - Revision 3/2019 4 I e'
Permit Number: AIRS ID Number: / /
[_ease blank unless APCD has already assigned a permit a and AIRS ID}
Section 8 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall(or combined)control efficiency(%reduction):
Overall Requested Control
Pollutant Description of Control Method(s) Efficiency
(%reduction in emissions)
VOC Enclosed Burner 95%
NOx
CO
HAPs (BTE9.n-Hexane.2,2.4-IMP)Enclosed Burner 95%
Other:
From what year is the following reported actual annual emissions data? n/a
Criteria Pollutant Emissions Inventory
Emission Factor? Actual Annual Emissions Requested Annual Permit
Emission Limit(s)s
Pollutant
Source Uncontrolled Controlled Uncontrolled Controlled
Uncontrolled Units (AP-42, Emissions Emissions Emissions Emissions
Basis Mfg.,etc.) (tons/year) tons! ear (tons/year)
Y ) (tons/year) (tons/year)) ( Y )
VOC 0.636 lb/bbl Simulation 205 10.2
NOx 0.068 Ib/mmbtu AP-42 0.42 0.42
CO 0.31 Ib/mmbtu AP-42 1.9 1.9
Non-Criteria Reportable Pollutant Emissions Inventory
Chemical Emission Factor? Actual Annual Emissions
Chemical Name Abstract Source Uncontrolled Controlled
Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions8
Number Basis Mf
g.,etc.) (pounds/year) (pounds/year)
Benzene 71432 4.00E-3 lb/bbl Simulation 2578 129
Toluene 108883 4.06E-3 lb/bbl Simulation 2616 131
Ethylbenzene 100414 3.22E-3 lb/bbl Simulation 2074 104
Xylene 1330207 2.07E-3 lb/bbl Simulation 1335 66.8
n-Hexane 110543 2.05E-2 lb/bbl Simulation 13177 659
2,2,4 540841 3.23E-3 lb/bbl Simulation 2078 104
Trimethylpentane
5 Requested values will become permit limitations. Requested limit(s)should consider future growth.
7 Attach crude oil laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific
emissions factors according to the guidance in PS Memo 14-03.
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave
blank.
pp coioaAaa
Form APCD-210 Crude Oil Storage Tank(s)APEN Revision 3/2019 5 I Li TOR
,
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit`and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. If this is a registration for coverage under General Permit GP08, I further certify that this source
is and will be operated in full compliance with each condition of General Permit GP08.
Signature of Legally Authorized Person(not a vendor or consultant) Date
Abigail Wenk Manager of Compliance
Name(print) Title
Check the appropriate box to request a copy of the:
Ej Draft permit prior to issuance
Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term,or when a reportable change is made (significant emissions increase, increase production,
new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with$191.13 and the General Permit For more information or assistance call:
registration fee of$312.50, if applicable, to:
Small Business Assistance Program
Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148
Air Pollution Control Division
APCD-SS-B1 APCD Main Phone Number
4300 Cherry Creek Drive South (303)692-3150
Denver, CO 80246-1530
Make check payable to: Or visit the APCD website at:
Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/aped
COLORADO
Form APCD-210 Crude Olt Storage Tanks) APEN - Revision 3/2019 6 I a� F'-'"-
,
CDPHE Gas Venting APEN - Form APCD-211
CO
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is
filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require
payment for a new filing fee.
This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators,well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source(e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200)is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division(APCD)website at: www.colorado.gov/cdphe/aped.
This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term,or when a reportable change is made(significant emissions increase, increase production,
new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: OWE/065'y AIRS ID Number: !-2- /AM j t02
[Leave blank unless APCD has already assigned a permit r and AIRS ID]
Section 1 - Administrative Information
Company Name': Bison Oil & Gas II, LLC
Site Name: Boomslang 14B Tank Battery
Site l ocation: E2SE Section 14 T8N R60W Site Location Weld
County:
NAICS or SIC Code: 211120
Mailing Address:(Include Zip Code) 518 17th Street, Suite 1800
Denver, CO 80202 Contact Person: Abigail Wenk
Phone Number: 720-644-6997 x41
E-Mail Address2: awenk@bisonog.com
1 Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that wilt appear
on all documents issued by the APCD.Any changes will require additional paperwork.
2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided.
71
COLOR ADO
Form APCD-211 Gas Venting APEN Revision 3/2019 1 I hi A
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit 4-and AIRS ID]
Section 2 - Requested Action
O NEW permit OR newly-reported emission source
-OR-
❑ MODIFICATION to existing permit(check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
❑ Change permit limit 0 Transfer of ownership4 0 Other(describe below)
-OR-
❑ APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE)
Additional Info(t Notes: Site-specific emission data estimated from samples taken at Castor 8-59 19 tank battery
as this facility has not yet started production.
3 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted.
4 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted.
Section 3 - General Information
General description of equipment and purpose: Venting from VRT separators to combustors
during periods of VRU downtime
Company equipment Identification No. (optional): Bulk VRT, test VRT
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
• Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source hours/day days/week weeks/year
Operation:
Will this equipment be operated in any NAAQS
nonattainment area? 0 Yes 0 No
Is this equipment located at a stationary source that is ❑ Yes 1 No
considered a Major Source of(HAP)Emissions?
Is this equipment subject to Colorado Regulation No. 7, 0 Yes ❑ No
Section XVII.G?
pp COLORADO
APCD-21 I Gas Venting APEN - Revision 3/2019 2 l31 COL ;xmO
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a per mit x and AIRS ID]
Section 4 - Process Equipment Information
❑✓ Gas/Liquid Separator
❑ Well Head Casing
❑ Pneumatic Pump
Make: Model: Serial#: Capacity: gal/min
❑ Compressor Rod Packing
Make: Model: #of Pistons: Leak Rate: Scf/hr/pist
❑ Blowdown Events
#of Events/year: Volume per event: MMscf/event
❑ Other
Description:
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes ❑✓ No
Vent Gas BTU/SCF
Gas Venting Heating Value:
Process Parameters5:
Requested: MMSCF/year Actual: MMSCF/year
-OR-
Liquid Throughput 64363
Process Parameters5: Requested: bbl/year Actual: bbl/year
Molecular Weight: 43.64
VOC(Weight%) 78.02
Benzene(Weight%) 0.467
Vented Gas Toluene(Weight%) 0.474
Properties: Ethylbenzene(Weight%) 0.376
Xylene(Weight%) 0.242
n-Hexane(Weight%) 2.39
2,2,4-Trimethylpentane(Weight%) 0.377
Additional Required Information:
❑ Attach a representative gas analysis(including BTEX Et n-Hexane, temperature, and pressure)
❑ Attach a representative pressurized extended liquids analysis(including BTEX>t n-Hexane, temperature, and
pressure)
5 Requested values will become permit limitations. Requested limit(s)should consider future process growth.
COLORADO
3 „.
Form APCD 211 Gas Venting APEN - Revision 3/2019 3 I .,M,- .,,.,,
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit x and AIRS IDi
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.659078/-104.050458
Operator - Discharge.Height Temp �' Flo*Rate `�` 4s.Ve1ociti a
Above Ground Level •
5taekiD No /Feetj �� '� (scrag a(ft/se0` z
Indicate the direction of the stack outlet: (check one)
Upward ❑Downward ❑Upward with obstructing raincap
❑Horizontal ❑Other(describe):
Indicate the stack opening and size: (check one)
❑✓ Circular Interior stack diameter(inches): 48"
❑Other(describe):
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Pollutants Controlled: VOC, HAPs (BTEX, n-Hexane, 2,2,4-TMP)
Size: Make/Model: Flogistix FX12V125 Standard(Electric)
VRU:
Requested Control Efficiency: 1 00 %
VRU Downtime or Bypassed: 10
Pollutants Controlled: VOC, HAPs (BTEX, n-Hexane, 2,2,4-TMP)
Rating: 11.7 MMBtu/hr
Type: Enclosed burner Make/Model: Cimarron 48" HV ECD
Combustion
Device: Requested Control Efficiency: 95
Manufacturer Guaranteed Control Efficiency: 99
Minimum Temperature: Waste Gas Heat Content: 2472 Btu/scf
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating: MMBtu/hr
Pollutants Controlled:
❑ Other: Description:
Requested Control Efficiency:
COLORADO
Form APCD-211 Gas Venting APEN - Revision 3i2019 4 I
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit r and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall(or combined)control efficiency(%reduction):
Overall Requested
Pollutant Description of Control Method(s) Control Efficiency
1 (%reduction in emissions)
PM
SOx
•
NOx
CO
VOC Enclosed Burner 95%
HAPs (BTEX,n-Hexane,2,2,4-IMP)Enclosed Burner 95%
Other:
From what year is the following reported actual annual emissions data? n/a
Criteria Pollutant Emissions Inventory
Emission Factor Actual Annual Emissions Requested Annual Permit
Emission Limit(s)5
Pollutant
Source Uncontrolled Controlled Uncontrolled Controlled
Uncontrolled Units (AP•42, Emissions Emissions6 Emissions Emissions
Basis Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year)
PM
SOx
NOx 0.068 lb/mmbtu AP-42 0.15 0.15
CO 0.31 lb/mmbtu AP-42 0.70 0.70
VOC 2.56 lb/bbl Simulation 82.5 4.12
Non-Criteria Reportable Pollutant Emissions Inventory
Chemical Emission Factor Actual Annual Emissions
Chemical Name Abstract Source Uncontrolled Controlled
Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions6
Number Basis Mfg.,etc.) (pounds/year) (pounds/year)
Benzene 71432 1.53E-2 lb/bbl Site specific 987 49.4
Toluene 108883 1.56E-2 lb/bbl Site specific 1002 50.1
Ethylbenzene 100414 1.24E-2 lb/bbl Site specific 796 39.8
Xylene 1330207 7.96E-3 lb/bbl Site specific 512 25.6
n-Hexane 110543 7.85E-2 lb/bbl Site specific 5054 253
2,2,4- 540841 1.24E-2 lb/bbl site specific 797 39,8
Trimethylpentane
Other:
5 Requested values will become permit limitations. Requested limit(s)should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
COLORADO
®
Form APCD-21I G.as Venting APEN - Revision 3/2019 5 I H._ .,
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit#and AIRS ID]
Section 8 -Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
Signature of Legally Authorized Person (not a vendor or consultant) Date
Abigail Wenk Manager of Compliance
Name (please print) Title
Check the appropriate box to request a copy of the:
❑✓ Draft permit prior to issuance
E✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five year term, or when a reportable change is made(significant emissions increase, increase production,
new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with$191.13 to: For more information or assistance call:
Colorado Department of Public Health and Environment Small Business Assistance Program
Air Pollution Control Division (303)692-3175 or(303)692-3148
APCD-SS-B1
4300 Cherry Creek Drive South APCD Main Phone Number
Denver, CO 80246-1530 (303)692-3150
Make check payable to: Or visit the APCD website at:
Colorado Department of Public Health and Environment https://www.colorado.gov/cdphetapcd
COLORADO
Form APCD-211 Gas Venting APEN - Revision 3/2019 6I alibef
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