HomeMy WebLinkAbout20202679.tiff C.
COLORADO
Department of Public
Health&Environment RECEIVED
AUG 1 2 2020
WELD COUNTY
Weld County - Clerk to the Board COMMISSIONERS
1150O St
PO Box 758
Greeley, CO 80632
August 3, 2020
Dear Sir or Madam:
On August 4, 2020, the Air Pollution Control Division will begin a 30-day public notice period for
Bonanza Creek Energy Operating Company, LLC - Latham 14-2 Production Facility. A copy of this
public notice and the public comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
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4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov;cdphe I (1.7-' 3 0`
Jared Potts,Governor I Jilt Hunsaker Ryan,MPH, Executive Director * }'
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Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
CDPHE
Comment
Website Title: Bonanza Creek Energy Operating Company, LLC - Latham 14-2 Production Facility - Weld
County
Notice Period Begins: August 4, 2020
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: Bonanza Creek Energy Operating Company, LLC
Facility: Latham 14-2 Production Facility
Exploration a Production Well Pad
SWSW quadrant of Section 2, Township 4N, Range 63W
Weld County
The proposed project or activity is as follows: Applicant proposes the re-permitting of point 005 (currently
covered under a GP07) under a traditional construction permit, and the modification of point 014 to reduce
throughput while retaining the previously approved emission factors.
The Division has determined that this permitting action is subject to public comment per Colorado
Regulation No. 3, Part B, Section III.C due to the following reason(s):
• the source is requesting a federally enforceable limit on the potential to emit in order to avoid other
requirements
The Division has made a preliminary determination of approval of the application.
A copy of the application, the Division's analysis, and a draft of Construction Permit 12WE3095 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:
Ben Fischbach
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
_Y� 'r COLORADO
j • Department of Public
1 I Health E Environment
STATE OF COLORADO
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COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT �
AIR POLLUTION CONTROL DIVISION
TELEPHONE: (303)692-3150 ` *
*1816*
CONSTRUCTION PERMIT
PERMIT NO: 1 2WE3095
Issuance 8
DATE ISSUED:
ISSUED TO: Bonanza Creek Energy Operating Company, LLC
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Oil and gas exploration and production facility known as the Latham 14-2 Production
Facility (COGCC#429121), located in the SWSW of Section 2 of T4N R63W in Weld
County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
Facility AIRS
Equipment Point Description
ID
Eighteen (18) 500 barrel and six(6) 400 barrel fixed roof
CNDTK-01 001 condensate storage vessels connected via liquid manifold.
Emissions from these vessels are controlled by six (6) enclosed
combustors.
One (1) 300 barrel, two (2) 400 barrel, and two (2) 500 bbl fixed
PWT-01 003 roof produced water storage vessels connected via liquid manifold.
Emissions from these vessels are controlled by six (6) enclosed
combustors.
Truck loadout of condensate by submerged fill using vapor
L-01 005 balance. Emissions from these vessels are controlled by
dedicated vapor balance service and six (6) enclosed combustors.
P-02 007 One (1) Sandpiper G1F pneumatic pump used for heat trace
(serial number 1991657).
LPGFL 014 Six (6) low pressure gas/oil separators and two (2) heater treaters
controlled by six (6) enclosed combustors.
Point 007: This pump may be replaced with another pump in accordance with the provisions of the
Alternate Operating Scenario(AOS) in this permit.
THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR
QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND
CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS
INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS:
AIRS ID: 123/9A7D Page 1 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION
1. Point 005: 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
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 III.F.4.)
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 (as calculated in the
Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4)
Annual Limits:
Facility AIRS Tons per Year
Emission Type
Equipment ID Point NO„ VOC CO
CNDTK-01 001 --- 8.7 --- Point
PWT-01 003 --- 0.5 --- Point
L-01 005 --- 1.0 --- Point
P-02 007 --- 2.7 1.2 Point
LPGFL 014 --- 20.6 3.6 Point
AIRS ID: 123/9A7D Page 2 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
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 be less than 8.0
tpy.
Facility-wide emissions of total hazardous air pollutants must be less than 20.0 tpy.
Compliance with the annual limits must be determined by recording the facility's annual
criteria pollutant emissions, (including all HAPs above the de-minimis reporting level)from
each emission unit, on a rolling twelve (12) month total. By the end of each month a new
twelve-month total must be calculated based on the previous twelve months' data. The
permit holder must calculate emissions each month and keep a compliance record on site
or at a local field office with site responsibility, for Division review. This rolling twelve-
month total must apply to all permitted emission units, requiring an APEN, at this facility.
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 control
equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit (Reference: Regulation No.3, Part B, Section III:E.)
Facility AIRS Pollutants
Equipment Control Device
ID Point Controlled
CNDTK-01 001 Six (6) LEED 48" Enclosed Combustors VOC, HAPs
PWT-01 003 Six (6) LEED 48" Enclosed Combustors VOC HAPs
L-01 005 Vapor Balance and Six (6) LEED 48" Enclosed VOC, HAPs
Combustors
P-02 007 Six (6) LEED 48" Enclosed Combustors VOC, HAPs
LPGFL 014 Six (6) LEED 48" Enclosed Combustors VOC, HAPs
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. (Reference:
Regulation 3, Part B, II.A.4)
AIRS ID: 123/9A7D Page 3 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
Process/Consumption Limits
Facility AIRS
Equipment Point Process Parameter Annual Limit
ID
CNDTK-01 001 Condensate Throughput 162,060 barrels
PWT-01 003 Produced Water Throughput 65,700 barrels
L-01 005 Condensate Loaded 162,060 barrels
P-02 007 Natural Gas to Drive Pneumatic Pump 5.3 MMscf
Natural gas vented from six (6) low
LPGFL 014 pressure separators and two (2) 9.5 MMscf
heater treaters
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 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 014: The owner or operator must continuously monitor and record the volumetric
flow rate of natural gas vented from each low pressure separator and each heater treater
using a flow meter. The flow meter must continuously measure flow rate and record total
volumetric flow vented to the enclosed flares from each low pressure separator and heater
treater. The owner or operator must use monthly throughput records and calculation
methods detailed in the Operating and Maintenance plan to demonstrate compliance with
permit limits and to calculate emissions as described in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
11. Points 001, 003, 007, and 014: The permit number and AIRS ID point number (e.g.
123/9A7D/xxx) must be marked on the subject equipment for ease of identification.
(Reference: Regulation Number 3, Part B, III.E.) (State only enforceable)
12. These sources are subject to the odor requirements of Regulation No. 2. (State only
enforceable)
13. Point 001: This source is subject to Regulation Number 7, Section XII. The operator must
comply with all applicable requirements of Section XII and, specifically, must:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for condensate 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, Section XII.C.) (State only enforceable)
AIRS ID: 123/9A7D Page 4 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
14. Points 001, 003, and 014: 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.B.2.d.
15. Points 001 and 003: The storage tanks covered by this permit are subject to the emission
control requirements in Regulation Number 7, Section XVII.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 efficiency of at least 98% for hydrocarbons except where the
combustion device has been authorized by permit prior to May 1, 2014. The source must
follow the inspection requirements of Regulation Number 7, Section XVII.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.
16. Points 001 and 003: The storage tanks covered by this permit are subject to the venting
and Storage Tank Emission Management System ("STEM") requirements of Regulation
Number 7, Section XVII.C.2
17. Point 005: Visible emissions must not exceed twenty percent (20%) opacity during
normal operation of the source. During periods of startup, process modification, or
adjustment of control equipment visible emissions must not exceed 30% opacity for more
than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.1.
&4.)
18. Point 005: Hydrocarbon liquids loadout from storage tanks to transport vehicles must be
controlled by using (a) submerge fill and (b) a vapor collection and return system and/or
air pollution control equipment. Compliance with Section II.C.5. must be achieved in
accordance with the following schedule: (Regulation Number 7, Part D, Section II.C.5.a.)
• Facilities constructed or modified on or after May 1, 2020, must be in compliance by
commencement of operation.
• Facilities constructed before May 1, 2020, must be in compliance by May 1, 2021.
• Facilities not subject to Sections II.C.5.a.(i)(A) or II.C.5.a.(i)(B) that exceed the
hydrocarbon liquids loadout to transport vehicles throughput of greater than or
equal to 5,000 barrels per year on a rolling 12-month basis must control emissions
from loadout upon exceeding the loadout threshold.
19. Point 005: Storage tanks must operate without venting at all times during loadout.
(Regulation Number 7, Part D, Section II.C.5.a.(ii))
20. Point 005: The owner or operator must, as applicable (Regulation Number 7, Part D,
Section II.C.5.a.(iii)):
AIRS ID: 123/9A7D Page 5 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
• Install and operate the vapor collection and return equipment to collect vapors
during the loadout of hydrocarbon liquids to tank compartments of outbound
transport vehicles and to route the vapors to the storage tank or air pollution control
equipment.
• Include devices to prevent the release of vapor from vapor recovery hoses not in
use.
• Use operating procedures to ensure that hydrocarbon liquids cannot be transferred
to transport vehicles unless the vapor collection and return system is in use.
• Operate all recovery and disposal equipment at a back-pressure less than the
pressure relief valve setting of transport vehicles.
• The owner or operator must inspect onsite loading equipment to ensure that hoses,
couplings, and valves are maintained to prevent dripping, leaking, or other liquid
or vapor loss during loadout. These inspections must occur at least monthly,
unless loadout occurs less frequently, then as often as loadout is occurring.
21. Point 005: The owner or operator must perform the following observations and training
(Regulation Number 7, Part D, Section II.C.5.a.(iv)):
• The owner or operator must observe loadout to confirm that all storage tanks
operate without venting when loadout operations are active. These inspections
must occur at least monthly, unless loadout occurs less frequently, then as often
as loadout is occurring,
• If observation of loadout is not feasible, the owner or operator must document the
annual loadout frequency and the reason why observation is not feasible and
inspect the facility within 24 hours after loadout to confirm that all storage tank thief
hatches (or other access point to the tank) are closed and latched.
• The owner or operator must install signage at or near the loadout control system
that indicates which loadout control method(s) is used and the appropriate and
necessary operating procedures for that system.
• The owner or operator must develop and implement an annual training program
for employees and/or third parties conducting loadout activities subject to Section
II.C.5. that includes, at a minimum, operating procedures for each type of loadout
control system.
22. Point 005: The owner or operator must retain the records required by Regulation Number
7, Part D, Section II.C.5.a.(v) for at least two (2) years and make such records available
to the Division upon request.
• Records of the annual facility hydrocarbon liquids loadout to transport vehicles
throughput.
• Inspections, including a description of any problems found and their resolution,
required under Sections II.C.5.a.(iii) and II.C.5.a.(iv) must be documented in a log.
• Records of the infeasibility of observation of loadout.
• Records of the frequency of loadout.
• Records of the annual training program, including the date and names of persons
trained.
AIRS ID: 123/9A7D Page 6 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
23. Point 005: Air pollution control equipment used to comply with this Section II.C.5. must
comply with Section II.B., be inspected in accordance with Sections II.C.1.d.(ii) through
(v), and achieve a hydrocarbon control efficiency of 95%. (Regulation Number 7, Part D,
Section II.C.5.a.(vi))
24. Point 014: The low pressure separators and heater treaters covered by this permit are
subject to Regulation 7, Part D, Section II.F. (State Only). 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 date of first production 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.
25. 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 & MAINTENANCE REQUIREMENTS
26. " Points 001, 003, 005, 007,and 014: Upon startup of these points, the owner or operator
must follow the most recent operating and maintenance (O&M) plan and record,keeping
format approved by the Division, in order to demonstrate compliance on an ongoing basis
with the requirements of this permit. Revisions to your O&M plan are subject to Division
approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testinq Requirements
27. Point 014: 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 content (weight fraction) of this emission
stream. Results of the Analysis must be used to calculate site-specific emission factors
for the pollutants referenced in this permit(in units of lb/MMSCF gas vented)using Division
approved methods. Results of the Analysis must be submitted to the Division as part of
the self-certification and must demonstrate the emissions factors established through the
Analysis are less than or equal to, the emissions factors submitted with the permit
application and established herein in the"Notes to Permit Holder"for this emissions point.
If any site-specific emissions factor developed through this Analysis is greater than the
emissions factors 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
AIRS ID: 123/9A7D Page 7 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
28. These sources are not required to conduct periodic testing, unless otherwise directed by
the Division or other state or federal requirement.
ALTERNATE OPERATING SCENARIOS
29. Point 007: This pump may be replaced with a like-kind pump in accordance with the
requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to
this permit or obtaining a new construction permit. A like-kind replacement pump must be
the same make, model and capacity as authorized in this permit.
30. Point 007: The owner or operator must maintain a log on-site or at a local field office to
contemporaneously record the start and stop dates of any pump replacement, the
manufacturer, model number, serial number and capacity of the replacement pump.
31. Point 007: All pump replacements installed and operated per the alternate operating
scenarios authorized by this permit must comply with all terms and conditions of this
construction permit.
ADDITIONAL REQUIREMENTS
32. All previous versions of this permit are cancelled upon issuance of this permit.
33. This permit replaces the following permits and/or points, which are cancelled upon
issuance of this permit.
Existing Permit Existing Emission Point New Emission Point
Number
GP07 123/9A7O/005 123/9A7D/005
34. A revised Air Pollutant Emission Notice(APEN) must be filed:(Reference: Regulation No.
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 NO. per year, a
change in annual actual emissions of one (1) ton per year or more or five percent,
whichever is greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of
five percent or 50 tons per year or more,whichever is less, above the level reported
on the last APEN submitted; or
For any non-criteria reportable pollutant:
If the emissions increase by 50% or five(5)tons per year, whichever is less, above
the level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or
activity; or
AIRS ID: 123/9A7D Page 8 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
• 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.
• Within 14 calendar days of commencing operation of a permanent replacement
engine under the alternative operating scenario outlined in this permit as
Attachment A. The APEN must include the specific manufacturer, model and serial
number and horsepower of the permanent replacement engine, the appropriate
APEN filing fee and a cover letter explaining that the owner or operator is
exercising an alternative-operating scenario and is installing a permanent
replacement engine.
35. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit)
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 No. 3 Part D).
GENERAL TERMS AND CONDITIONS
36. This permit and any attachments must be retained and made available for inspection upon
request. The permit may be reissued to a new owner by the APCD as provided in AQCC
Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the
submittal of a revised APEN and the required fee.
37. If this permit specifically states that final authorization has been granted, then the
remainder of this condition is not applicable. Otherwise, the issuance of this construction
permit does not provide "final"authority for this activity or operation of this source. Final
authorization of the permit must be secured from the APCD in writing in accordance with
the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section
III.G. Final authorization cannot be granted until the operation or activity commences and
has been verified by the APCD as conforming in all respects with the conditions of the
permit. Once self-certification of all points has been reviewed and approved by the
Division, it will provide written documentation of such final authorization. Details for
obtaining final authorization to operate are located in the Requirements to Self-
Certify for Final Authorization section of this permit.
38. This permit is issued in reliance upon the accuracy and completeness of information
supplied by the owner or operator and is conditioned upon conduct of the activity, or
construction, installation and operation of the source, in accordance with this information
and with representations made by the owner or operator or owner or operator's agents. It
is valid only for the equipment and operations or activity specifically identified on the
permit.
39. 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.
40. 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
AIRS ID: 123/9A7D Page 9 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
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.
41. 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.
42. 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: DWI
Ben Fischbach
Permit Engineer
Permit History
Issuance Date Description
Issued to Bonanza Creek Energy Operating Company, LLC. Added
Issuance This point 005 back to this permit from a GP07. Reduced throughput and
8 Issuance annual emissions limits for point 014, retaining original emission factors.
Updated equipment description for point 014 to reflect previous removal
of Vapor Recovery Towers. Synthetic Minor Facility.
Issued to Bonanza Creek Energy Operating Company, LLC. Modified
Issuance April 11, Point 007 to change equipment description and permit limits from two
7 2017 pumps to one pump. Removed Point 005 (loadout) as it is now covered
by GP07. Removed cancelled point 023. Issued as Initial Approval.
Issued to Bonanza Creek Energy Operating Company, LLC.
Increased throughput and emission limits, and site-specific emission
Issuance January factors, for points 001, 003, 005, and 014. Removed cancelled points
6 10, 2017 010, and 015. Modified Point 007 to remove P-01; P-02 remains on
permit and permit retains full emission/process limits for Point 007. Point
023 not changed. Issued as Initial Approval because Point 023 has not
been installed yet.
Issuance June 13, Issued to Bonanza Creek Energy Operating Company, LLC
5 2016 Modification to consolidate vapor recovery towers (point 025) and low
pressure separators (point 014) into single emission point (014). Update
AIRS ID: 123/9A7D Page 10 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
Issuance Date Description
throughput and emission factors for point 014 to account for removal of
VRUs.
Decrease permitted throughput and emission limits for points 001, 003
and 005.
Removed point 004 as it is now covered under a GP02 registration.
Updated Points 001, 003, 005, 007, 010, 014, 015
Issuance November Updated produced water tanks (Pt 003) emissions and throughputs and
4 19, 2015 converted from GP05 to this permit
Added Points 023 (Emergency Flare) and 025 (VRTs)
Updated condensate tanks (Pt 001) emissions and throughputs, added
tanks, and converted from GP01 to this permit.
July 16, Increased emissions and throughput for condensate loadout (Pt 005).
Issuance 2014 Decreased emission limit for pneumatic pumps P-1 and P-2 (Pt 007).
3 Increased throughput and emission limit for pneumatic pump P-3 (Pt
010).
Added new equipment covered under AIRS Point 014, 015, 016 and
017.
Issuance October Addition of pneumatic pump (Pt 010).
2 9, 2013
Issuance May 13, Issued to Bonanza Creek Energy Operating Company LLC
1 2013
AIRS ID: 123/9A7D Page 11 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
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 (Reference:
Regulation No. 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are based
on the consumption rates requested in the permit application. These limits may be revised upon
request of the owner or operator providing there is no exceedance of any specific emission control
regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and
complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator 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 II.E.1 of the Common Provisions Regulation. See:
4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process
limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis
of the specific compounds emitted if the source(s)operate at the permitted limitations.
Uncontrolled
Emission Are the Controlled
AIRS Rate, emissions Emission Rate
Point Pollutant CAS# (lb/yr) reportable? (lb/yr)
Benzene 71432 1921 Yes 96
Toluene 108883 1827 Yes 91
Ethylbenzene 100414 192 No 10
001
Xylenes 1330207 616 Yes 31
n-Hexane 110543 12621 Yes 631
2,2,4-TMP 540841 1264 Yes 63
Benzene 71432 460 Yes 23
003
n-Hexane 110543 1445 Yes 72
Benzene 71432 66 No 3
005
n-Hexane 110543 583 Yes 29
Benzene 71432 351 Yes 18
Toluene 108883 377 Yes 19
Ethylbenzene 100414 88 No 5
007
Xylenes 1330207 193 No 10
n-Hexane 110543 2471 Yes 124
2,2,4-TMP 540841 289 Yes 15
014 Benzene 71432 1844 Yes 92
AIRS ID: 123/9A7D Page 12 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
Uncontrolled
Emission Are the Controlled
AIRS Rate emissions Emission Rate
Point Pollutant CAS# (lb/yr) reportable? (Ib/yr)
Toluene 108883 852 Yes 43
Ethylbenzene 100414 111 No 6
Xylenes 1330207 224 No 11
n-Hexane 110543 13700 Yes 685 •
2,2,4-TMP 540841 899 Yes 45
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
Uncontrolled Controlled
CAS# Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
--- VOC 2.137 0.1069 ProMax
71432 Benzene 0.0119 0.0006 ProMax
108883 Toluene 0.0113 0.0006 ProMax
100414 Ethylbenzene 0.0012 0.0001 ProMax
1330207 Xylenes 0.0038 0.0002 ProMax
110543 n-Hexane 0.0779 0.0039 ProMax
540841 2, 0.0078 0.0078 0.0004 ProMax
Trimethylpentane
Note: The controlled emissions for this point are based on the enclosed combustor control
efficiency of 95%. The emission factors were developed using a pressurized liquids
analysis from the facility as an input to Promax process simulation software.
Point 003:
Uncontrolled Controlled
CAS# Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
VOC 0.262 0.013 CDPHE (PS Memo
71432 Benzene 0.007 0.00035 09-02)
110543 n-Hexane 0.022 0.00110
Note: The controlled emissions for this point are based on the enclosed combustor control
efficiency of 95%.
Point 005:
Uncontrolled Controlled
CAS# Pollutant Emission Factors Emission Factors Source
`Ib/bbl lb/bbl
--- VOC 0.236 1.18* 10-2
71432 Benzene 4.10 * 10-4 2.05* 10-5 CDPHE
110543 n-Hexane 3.60 * 10-3 1.80 * 10-4
Note: The controlled emissions for this point are based on the enclosed combustor control
efficiency of 95%.
AIRS ID: 123/9A7D Page 13 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
Point 007:
Emission Emission
Factors- Factors-
Uncontrolled Controlled
Pollutant lb/MMscf vented lb/MMscf vented Source
NOx 0.068 0.068 AP-42 Ch. 13.5
(lb/MMBTU)
CO 0.31 0.31 AP-42 Ch. 13.5
(lb/MMBTU)
VOC 20050 1002.5
Benzene 66.7 3.33 Site-specific
Toluene 71.7 3.58 sales gas
Ethylbenzene 16.7 0.83 analyses
Xylenes 36.7 1.83 collected
n-Hexane 470.0 23.50 9/15/2014
2,2,4-TMP 55.0 2.75
Note: The controlled emissions for this point are based on the enclosed combustor control
efficiency of 95%.
Point 014:
Weight Emission Emission
Fraction Factors Factors
CAS# Pollutant of Gas Uncontrolled Controlled Source
(%)
Ib/MMscf lb/MMscf
--- NOx --- 164.02 164.02 AP-42
--- CO --- 747.72 747.72 AP-42
VOC 77.6 86763.94 4338.2 Gas Analysis
71432 Benzene 0.17 194.05 9.70 Gas Analysis
108883 Toluene 0.08 89.59 4.48 Gas Analysis
100414 Ethylbenzene 0.01 11.77 0.59 Gas Analysis
1330207 Xylenes 0.02 23.49 1.17 Gas Analysis
110543 n-Hexane 1.29 1441.93 72.10 Gas Analysis
540841 2'2'4 0.08 94.62 4.73 Gas Analysis
Trimethylpentane
Note: The uncontrolled VOC and HAP emissions for this point were calculated using a September
15, 2014 analysis of a site specific separator gas sample from the Latham 14-2 well. The
controlled VOC and HAP emissions factors for point 014 are based on the enclosed
combustor control efficiency of 95%. The emission factors for NOx and CO, found in AP-
42 Table 13.5-1 and Table 13.5-2, were converted to units of lb/MMscf using a heating
value of 2,412 MMBtu/MMscf.
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 facility is classified as follows:
AIRS ID: 123/9A7D Page 14 of 15
Colorado Department of Public Health and Environment
Air Pollution Control Division
Applicable Status
Requirement
Operating Permit Synthetic Minor Source of: VOC and n-Hexane
NANSR Synthetic Minor Source of: VOC
MACT HH Area Source Requirements: Not Applicable
8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found
at the website listed below:
http://ecfr.gpoaccess.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS 60.1-End Subpart A—Subpart KKKK
NSPS Part 60, Appendixes Appendix A—Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories
MACT 63.1-63.599 Subpart A—Subpart Z
MACT 63.600-63.1199 Subpart AA—Subpart DDD
MACT 63.1200-63.1439 Subpart EEE—Subpart PPP
MACT 63.1440-63:6175 Subpart QQQ—Subpart YYYY
MACT 63.6580-63.8830 Subpart ZZZZ-Subpart MMMMM
MACT 63.8980-End Subpart NNNNN-Subpart XXXXXX
AIRS ID: 123/9A7D Page 15 of 15
PRELIMINARY ANALYSIS-PROJECT SUMMARY
Project Details For Division Use Only
Review Engineer: Ben€ischbach.
Package if: 427303
Received Date: X1372020
Review Start Date: 2/2/2620
Section 01-Facility Information
Company Name: Bonanza Creek Energy Operating tC Quadrant Section Township Range
County AIRS ID: 125 SWS1e 2 4N 53
Plant AIRS ID: PAM
Facility Name: Latham 14.2 Production Facility
Physical
Address/Location: .
County: Weld County
Type of Facility: Exploration A Production Well Pad
What industry segment?Oil&Natural Gas Production&Processing
Is this facility located in a NAAOS non-attainment area? Yes
If yes,for what pollutant? Drury l(1Oc&VOC)
Section 02-Emissions Units In Permit Application
Leave Blank-For Division Use Only
Permit#
AIRS Point#
Emissions (Leave blank unless Issuance Self Cert Engineering
(Leave blank unless APCD Emissions Source Type Equipment Name Action
Control? APCD has already # Required? Remarks
has already assigned) assigned)
APEN reports
'transition from
Permit GPG7 coverage
005 Liquid Loading L-01 Yes 12W53055 8 Modification to IP
- Permit
014 Separator Venting - „PGR Yes 12W33045 S Modification •
Section 03-Description of Project
Applicant proposes the re-permitting o€point OOS(currently covered ander a GPM under a traditional construction permit,and the modification of point 014 to
reduce throughput but retain the previously approved emission factors.
Sections 04,05&06-For Division Use Only
Section 04-Public Comment Requirements
Is Public Comment Required? Yes
If yes,why? Requesting Synthetic Minor Permit
Section 05-Ambient Air Impact Analysis Requirement
Was a quantitative modeling analysis required? No
If yes,for what pollutants?
If yes,attach a copy of Technical Services Unit modeling results summary.
Section 06-Facility-Wide Stationary Source Classification
Is this stationary source a true minor? No
Is this stationary source a synthetic minor? Yes
If yes,indicate programs and which pollutants: 502 NOx CO__VOC PM2.5_ PM10 TSP HAPs
Prevention of Significant Deterioration(P5D) H
a1
Title V Operating Permits(OP) 1 E I
I"A
Non Attainment New Source Review(NANSR) +f
Is this stationary source a major source? No
If yes,indicate programs and which pollutants: S02 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(PSD) H ` H H H ❑ D D
Title V Operating Permits(OP) IL JI
Non-Attainment New Source Review(NANSR) j
Hydrocarbon Loadout Emissions inventory
Section 01-Administrative Information
Facility Allis ID; County Plant Point
Section 02-Equipment Description Details
D t I tl Emi ro U t r. �n
Description: k4aUdtg�fF�% -af$atv`p&s' :,. ..
Emission Control Device -
Description: . ! .,....'
Is this loadout controlled? -
Requested Overall VOC&HAP Control Efficiency A: 9 -
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Hydrocarbon Loadout
Actual Volume Loaded= ;#.02j290 Barrels(bbl)per year
'Requested Permit Limit Throughput= :`3A-2oA.Barrels(bbl)per year Requested Monthly Throughput= -:._, Barrels(bbl)per month
Potential to Emit(PTE)Volume Loaded= ` "152060 Barrels(bbl)per year
Secondary Emissions-Combustion Devices)
Heat content of waste gas= .329'1 Btu/scf
Actual Volume of waste gas emitted per year= __....,7 scf/year
Requested Volume of waste gas emitted per year= scf/year
Actual heat content of waste gas routed to combustion device= MMBTU per year
Requested heat content of waste gas routed to combustion device= MMBTU per year
Potential to Emit(PTE)heat content of waste gas routed to combustion device= MMBTU per year
Control Device
Pilot Fuel Use Rate: - scfll _'MMscf/yr
Pilot Fuel Gas Heating Value: - Btu/scf =3: MMBTU/yr
Section 04-Emissions Factors&Methodologies
Does the company use the state default emissions factors to estimate emissions?
Does the hydrocarbon liquid loading operation utilize submerged fill?
•
IMEMIZES Hydrocarbon Loadout
Uncontrolled Controlled
Emission Factor Source
Pollutant
(10/001) (lb/bbl)
(Volume Loaded) (Volume Loaded)
Pollutant Uncontrolled Uncontrolled Emission Factor Source
(Ib/MMBtu) (lb/bbl)
(waste heat combusted) (Volume Loaded)
®` O4680
Da*. ' =ME=ifiligigrZnaitellta="enkiitar,
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant )lb/MMBtu) (lb/MMscf) Emission Factor Source
(Pilot Gas
(Waste Heat Combusted) Throughput)
: O V 31)
,)'36.50 MEEMictiiAlaWiagatV,ANita -
0_3-1N'
2 of 11 K:\PA\2022\12WE3095.CP8
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) (cons/year) (tons/year) (tons/year) (tons/year) (Ibs/month)
PM10
PM2.5
SOx _
NOx
VOC =-
CO _
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Art Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(Ibs/year) (Ibs/yearl (Ibs/year) (Ibs/year) Ilbs/year)
Benzene --
Toluene -
Ethylbenzene .
Xylene -
n-Hexane
224 TMP
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B - -....
Regulation 7 Part D Section II.C.S. -
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial and Periodic Sampling and Testing Requirements
miv
Does the company request a control device efficiency greater than 95%for a flare or combustion devce? ` $ :;
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08-Technical Analysis Notes
Operator's calculation sheet shows slightly higher combustion em issions calculations than given by original PA equation(see cell C24 for original equation).Operator instead reports a tank vent gas flowrate of 33.2 scf/hr and multiplied this value by 8760 hr/yr
and the reported HHV of 3,299.Values calculated by operator are oonservativeand relatively close to those calculated by PA,so the annual requested and PTE heat contents of waste gas(cells E25&E28)were overwritten with that calculated by the operator,
and will be used in permitting.
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
Uncontrolled
Emissions
AIRS Point# Process R SCC Code Pollutant Factor Control% Units
005 01 - _ - ,. - - - - PM10 - lb/1,000 gallons transferred
PM2.5 lb/1,000 gallons transferred
SOx - lb/1,000 gallons transferred
NOx lb/1,000 gallons transferred
VOC lb/1,000 gallons transferred
CO - lb/1,000 gallons transferred
Benzene lb/1,000 gallons transferred
Toluene - lb/1,000 gallons transferred
Ethylbenzene lb/1,000 gallons transferred
Xylem - lb/1,000 gallons transferred
n-Hexane - lb/1,000 gallons transferred
224 TMP - lb/1,000 gallons transferred
3 of 11 K:\PA\2012\12 W E3095.CP8
Hydrocarbon Loadout Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions and throughput.
[olgleJp Regulation 3 Parts A nag-AM and Permit Requirements
ISavAti rp alonatttai(aictit Attic
ATTAINNANI
1.Are uncontrolled actual emissions from and criteria pollutants from this Individual source grea ter than 2 TPY(Regulatipn 3,Part A,Section ll.0.1.a)?
2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Seetlon II.0.1 I/'
3. Is the loadout operation loading less than COO00 gallons OS BBLs)of crude all per day on en annual average basis?
q. Is the loadout operation loading less than 6,]50 bbls per year of condensate via splash fill'?
5. Is the loadout operation loading less than 16,3061,as per year of condensate via submerged fill procedure?
a. Are total facility uncontrolled VOL emissions greater that,TPY,NOR greater than lO TM or CO emissions greater than2O TW(Regulation 3,Pais%Section AAA?
IYou I.ve.n._tee.batsecri,s n-b.,_na..am-...r_rca
NPICAMINIMI
trolled emissions from and criteria pollutants from this individual source greater than 1 WY IRegulatlon 3,Part A Seaton 11D 1,11)? sib*261 Go In next question.
z Is the loadout located at anexyioratlon and,dacaonsitelog,.wen pad)(Regulation 3,Part B,sectbnll.O.1.11+ Go to Pat nein question
he loadouloperadon loading less than To,000 gallons 1238 BBIs)of erode oil per day anen annual average bask? fiW"11,-.**,Gob next question
4. Is the loadout operation lowing less than 6,750 bola per year or condensate vla splash ml? ?Rli Go w nextquesann
5. tithe loaawr operation loading less than 16,308 obis par year ctoo,denote via submerged fill Ptocadure? VW-2W g
s. Are total facility uncontrolled VOCemisstmsfrom diegreater than 2TIN,NOR greater than s Moo CO emissions greater than 10TPY IRegulabon3,-rc e,5eosn 1102/' 05*-:;P.y.:Tnocadotreglrires a permit
colon sdegxlan0R',Pao osgctIon ends.
1. Is this condensate storage pink hydrocarbon liquids 1200, Located at a wellproductia,faclgty,,nalumlgaz compressor sta.,'Pr,atural gaspmcezang want? •
1 /004„;`:;;_1G uesunn. _.
_. Nos the facility have a throughputorbrdrrcarbonlHolds loadout to transport venues greater than or equal to 5,000 barrels? ac, 'Source sadsject to Regulation)Partpsection lt.es.
It: togas,toe.._Aasbieer-n a,_n Part',Rau.IC:
Section �a.(i)-Compliance Schedule
Section II.C.5.a.(iil.Operation without venting
Section II.C.S.a.liii Load°,Equipment°Pa...nand Maintenance
Sections.a.bv7-Ioadeutobservadons and Operator Training
Section ll.c.5.a.N1-Retools
Section II.e.5.a.vll Requirements for Air Pollution Control Equipment
Disclaimer
This document assists operators with*Merminirg applicability d certain requirements d the Clean Air Act,its Implementing regulations,and AV Quality Control Commission regulations.This dxvmentis not a
rule or regulation.end the anelysrs it contains may not apply toe particular situation based upon the Individualladts and circumstances.This document does not change or...nth,for any law,regulation,a
any other legally binding requirement and Moot legally en/eable.In Hie event of any conflict between the language of this document and Um language or the Clean Air Act„its implementing regulations,
and Air Quality Control Commission regulations.the language of the statute wmguletlo,will control.The use ofnm'mendatoy language such as"recanmend,""may,""shroud,"end"can,"is intended to
describe APCD interpretations and recommendations.Mandatory tevminabgy such es,,,mrend'Iegsred"are intehddto dexnbe ncnhdlirg requirements under the terms of the Clean All Act art Air
quality Ddmrd Canmiasion regulation.,but this daurrent dads not establish legally bind'rg requiromersha In end of6self.
Sep-1ra
Section 01-Administrative Information
12.4
Facility AIRs ID: 9A70 171$
County Plant Point
Section 02-Equipment Description Details
Low pressure gas front separators.
Detailed Emissions Unit Description:
EOtb
Emission Control Device Description:
Requested Overall VOC&HAP Control Efficiency%: 93 •
Limited Process Parameter
Gas meter
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Separator
Actual Throughput= 9.5 MMscf per year
Requested Permit Limit Throughput= .3 MMscf per year Requested Monthly Throughput= E:3 MMscf per month
Potential to Emit(PTE)Through put= >MMscf per year
Secondary Emissions-Combustion Device(s)for Air Pollution Control
Separator Gas Heating Value: .34.12.0 Btu/scf
Volume of waste gas emitted per BBL of I aF
liquids throughput: 12,44trikiirig scf/bbl
RWirsellItRO
Control Device
Pilot Fuel Use Rate: scfh MMscf/yr
Pilot Fuel Gas Heating Value:
Section 04-Emissions Factors&Methodologies
•
Description
EfniStionfactors are based ad prbbriuusty approved fsctdn which were last approved by issEtance 6(issuance 7 did not involve anycpndiffyotions to this point).T(toseemfssion faetory are biased an a site-specific gas safnpfe
which waSeo!(ec$EC('ooR/1E/l9,t4podunatyaeds3nf/tsjzG.t4,Given the,nve of tbebe saTnples,perrnit wilt require IOW eutopting to may the continued acennory of the enn$sibo factors MCI
MW 42.41lb/lb-mol Displacement Equation
Ex=Q*MW*Xx/C
Weight
HeliumO,p.
CO2 1.4
N2 57,5
methane 6.7�
ethane 15.0
propane 30.8
isobutane 3.8
n-butane 23.2
isopentane 5.7
n-pentane 7,0
cyclopentane - US
n-Hexane 1.3
cyclohexane
Other hexanes 2.I
heptanes
methylcyclohexane
224-TMP t�
Benzene 0.2
Toluene 0-1
Ethylbenzene C.Cl
Xylenes 0.0
C8+Heavies 0,0
Total
VOC Wt%
5 of 11 K:\PA\2012\12WE3095.CP8
Separator Venting Emissions invents-,
Emission Factors Separator Venting APEN Listed Factors
Uncontrolled Controlled Uncontrolled Emission Factor Source
Pollutant (lb/MMscf) (lb/MMscf) lb/MMscf
(Gas Throughput) (Gas Throughput) Gas
VOC 96773.5606 t" 86763.94
Benzene 194,0884 't''_ 194.06
Toluene _ _ 89,59
Ethylbenzene L_s4 s qa 11.77
Xylene2-3.'5,338 ` - _ 23.49
n-Hexane - <:2,'C3 } °�
Ic^ 1441.93
224TMP .-,5191 — .,.: - _ 94.62
Primary Control Device
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Gas Throughput)
'- -
PM10 _
PM2.5
SOx
NOx 0.088*
CO {E.`3Q4 u, AP- .... �_..
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (lb/MMBtu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Pilot Gas Throughput)
PM10 0,..m0 ,.. ., _
SOx _,33 R 0}
NOx i3.068O -
O '�VOC - b 3p
CO :334₹2 n ooce . i1.'> .» , ,Y+ l 1
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 0.G 0.0 OA _,0 9
PM2.5 0,0 C.C 0 0 94
5Ox .,,', 9C D.1 0<0 5,P
NOx 0.3 0.5 ._ 5 9 _s 132
VOC 412,2 412.2 412.18 20.:5 35:11
CO 3.6 s,. 3 5 3 6 t?s
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year)
Benzene _a< 1844 42 1944 9_
Toluene sa.2 5. 8,2 4?
Ethylbenzene ___ r 111 6
Xylene 2,4 224 __ 2°4 55
n-Hexane 13700 13750 ..,_ 15700 845
224 TMP 5,,, 595 ., 339 45
•
Section 06-Regulatory 5ummary Anal iris
Regulation 3,Parts A,B
Regulation 7,Part D,Section 11.0,F
Regulation 7,Part D,Section 11.8.2.e :he,,,.cr,'•ievite fu.:h,a�apar.a-.: ,, _ er n,,7 Fart^Secz e,,r!4,1,3
(See regulatory applicability worksheet for detailed analysis)
6 of 11 K:\PA\2012\12WE3095.CP8
SepArfL0r '.rating r'pl';s'C,t5 inventory
Section 07-Initial and Periodic Sampling and Testing Requirements
Using Gas Throughput to Monitor Compliance
Does the company use site specific emissidn factors based on a gas sample to estimate emissions?
This sample should represent the gas outlet of the equipment covered under this AIRS ID,and 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 Testing Requirement"to collect a site-specific ga5,sample from the equipment being permitted 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.
Are facility-wide permitted emissions of VOC greater than or equal to 40 tons per year in the ozone nonattainment
area OR are emissions greater than or equal to 90 tons per year in the ozone attainment area?
If yes,the permit will contain:
-An"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted 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.
-A"Periodic Testing Requirement"to collect a site-specific gas sample from the equipment being permitted 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 on an annual basis.
Will the operator have a meter installed and operational upon startup of this point? Son
If no,the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational(not to exceed 180
days).This condition will use the"Volume of waste gas emitted per BBL of liquids throughput"(scf/bbl)value in section 03.
Does the company request a control device efficiency greater than 95%for a flare or combustion device? OPS
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
..".e frd3c....d a'3a„ 5.5.......', ,..,.:e.t..cst h_
a;
Section 08-Technical Analysis Notes
From PA workbook for CPO issuance,iime operator was asked if any of the wells at this facility were newly constructed,hydraulcally fractured or recompleted after 08/01/14-The operator expressed that-here are wells at Ihis faciity that
came online after 8/1/14.As a result,the separator and VRT are subject to Re7Jlatior 7 Section XVILG."Therefore,dos points sib act to Reg 7,Part D,Sections L'.B.?and F. - -
•
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
AIRS Point 0 Process 0 SCC Code Pollutant Uncontrolled Emissions Factor Control% Units
014 01 3-%04361:>0'15-r5 PM10 r5.1 0 tk:Ta7 e[L'z
PM2.5 2:
NOx .1 r515C.
VOC .. 5 lit:fa!v;S0F ..
CO .1:.:' li t'k'tat'TF
Benzene
Toluene •s.
Ethylbenzene 1.., 9 .,.`,O1V9i_t
Xylene
n-Hexane 11=22
224 TMP
•
7 of Si K:\PA\2012\12WE3095.CP8
Separator Venting Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts A and B-APES and Permit`Requirements
Sava.is in the Area
ATTAINMENT
1. Are uncontrolled actual emissionsfrom y criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section 11.0.1.a)? �y�
2. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOx greater than 10 TPY or CO emissions greater than 10 TPY(Regulation 3,Part 5,Section 0.0.3)? r'F'!n
Hu?lay, diut is in ,ion-Attairim≥rizi
NON-ATTAINMENT
1. Are trolled emissions from any criteria pollutants from this individual source greater than 1TPY(Regulation 3,Part A Section 11:0.1)x)? SourceRe
2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY,NOx greater than 5 TPY or CO emissions greater than.10 TPY(Regulation3,Part B,Section 11.0.2)? tlixar0 Source Re
Ifiaiiice tarnzra p=-C
Colorado Regulation 7,Part 0 Section II
1. Was the well newly constructed,hydraulically f t d or recompleted on or after August 1,2014? It.5VillSource is..
ISovxxx is aub'ac
Section 11.0.2—General Provisions for Air Polluter Control Equipment Used to Comply with Section II
Section II.F-Control of emissions from well production facilities
Alternative Emissions Control(Optional Section/
e. 15 the separator controlled bye backup or alternate combustion deuce lit.,not primary control device)that is not enclosed? The carts
ltiroet �yb r ��,.�
Section II.B.2.e—Alternative emissionscontrol 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 toe 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 recomm nd'"may,""should,"and"can,"is
intended to describe APCD interpretations and recommendations.Mandatory tenninology 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
Bonanza Creek Energy Operating
Company Name Company.LLC
County AIRS ID 123 History File Edit Date 7/8/2020
Plant AIRS ID 9A7D Ozone Status Non-Attainment
Latham 14-2 Production Facility
Facility Name
EMISSIONS-Uncontrolled(tons per year) EMISSIONS With Controls(tons per year)
POINT PERMIT Description PM10 PM2.5 112S SO2 NOx VOC Fug CO Total PM70 PM2.5 H2S SO2 NOx VOC Fug CO Total REMARKS
AIRS VOC HAPs VOC HAPs •
ID
Previous FACILITY TOTAL 07 07 00 00 20.9 1.146.8 0.6 38.0 318 07 07 00 00 114 882 06 _272 2.5
Previous Permitted Facilit total I 0.1 0.1 0.0 00 136 1,1203 00 14 7 31.0 01 0.1 00 00 42 65.4 00 14.0 1.7
001 12WE3095 Eighteen(18)500 bbl and Six(9) 03 1732 1.4 92 03 8.7 1.4 05 No Change
400 bbl condensate storage vessels
002 12WE3095 Two(24400 bbl condensate storage 0.0 0-O Source is now covered under Point 001.
tanks
003 12WE3095 One(1)300bbl,two(2)400 bbl and 0.0 8.6 01 1.0 00 04 01 0.05 year APEN update-no change in emissions.
two(2)500 bbl produced water
storage vessels.
004 0102 RICE Arrow A-02 01 0.1 114 0.3 4,5 01 0.1 01 1.9 0.3 3.7 0.0 No change(SN.6512D000373)
005 121603095 Hydrocarbon Loadeut 0 0 19 1 02 0 3 0 0 1 0 0 2 0.0 Moved front 0107 coverage back to CP
006 15WE0168 XA Fugitives 06 00 0.6 0.0 Not change
007 12WE3095 One(/)Sandpiper G1F pneumatic 03 52.7 1.1 19 0.3 2.6 11 0.1 No Change
pump
008 13WE1040CN RICE GASJACK GJ230 0.0 0.0 Point Cancelled-Cancellation request received
09/03/2016,Source no longer exists atthe
facility,(5N:63754)
009 13WE10410N =RICE GASJACKGJ230 - 0-0 00 Point Cancelled-Cancellations¢quest received
06003/20/3$6uree no longer exists at the
fagillty)SN 50859)
010 12W03055 One(1)Sandpiper GIF pneumatic 0.0 0.0 Point C7ancenod-Canoelfation request reoeived
pump 00/03/2006.Source no leingerextstset,the
facility.(SN:2040601)
011 GP02.Gist R/CECHtetpiltar034081A 0.0 00 Point Cancelled-Cancellation request received
09/19/2014.Source no longer exists at the
€acilfty,(SN:6N605112)
012 010209 RICE Caterpiltar 03408TA 00 DS Point Conceited-Cancellation request received
09/09/201q Source no longer exists at the
facility.(SN.6N805110)
053 03WE2855.CPi Process Flare 00 94 Point Cancelled-Cancelfa110 request received
10/29113.Source no longer exists atthefaellity.
014 120.183096, Six(3)low pressure separators, 0 8 412 2 3 6 8.8 0 8 20 6 3.6 0.4 Modification to reduce throughput and
two(2)heater treaters and two(2) emission limits while retaining original
vapor recover towers emission factors,
045 12WE3095 0ne(1)Sandpiper 01F pneumatic' 0.0 0,0 Point Cancelled-Canceltatfao request received
•
pomp({'1-4"j 10/00/2508,source na imager exists atthe
facility.(5612091584)..
019 12WE3095 Low pressure separator - 0.0 DO Point Cancelled-Cancellation request received
11/0712014.Seume is now eovered under point
014.
017 12WE3095 Low pressure separator 0.0 0.0 Point Cancelled-Canceflafon request rzcebved
11107/2014.Source is now covered under point
014.
018 GP02.CN RICE Caterpllar 03508 ULB 0.0 0.0 Point Cancelled-Cancellation request received
03/0612015.Source no tenet exists at the
facility.(SN'RBK00103)
019 0102GN RICE Caterpillar G3508 MS 00 d.➢Pomt Cancelled'-Cancellation request received
0410E/2016.Source no longer exists at the
facility.46f0 RBK01301/
020 14WE1334.05 RICE GASJACK 0223046HP 0.0 00 Point Cancelled-Cancellation request received
02/24/2056 Source no longer exists at the
facility.(SN:53340)
021 14WE1335.CN RICE GASJACK GJ23046HP 00 00 Point Cancelled•Cancellation request r00eiVed
02/24/10,Source 00/508er exists.atthe facility,
(SN:633581
022 GP02.CN RICECaterpllar G3512 ULB 00 OO Para Cancelled-Cancellation request received,
12/23/2015.Sourceno longer exists Who
facility.(SN7N4200762)
023 12WE3095 Process Flare - 0.0 0.0 Cancellation notice redd 3127/17-never
installed.
024 12WE3095 Process Flare - 0.0 00 Point Cancelled-Cancellation request received
/7/2014.Source no longer exists at the facility.
025 12WE3095 Two(2)vapor recovery towers 0.0 0.0 Point Candled-Cancellafon request received
04/29/201E,Source is now CeOered under point
014.
026 GP02 RICE Caterpillar G3508B Cancellation reed 3115/2018-Replaced by 027
027 0102 RICE G35088 03 03 3.3 8.4 20.1 0.3 0.3 3.3 4.7 10.0 No change
XA Heated Separators 0.3 0.3 3.9 0.2 3.2 01 03 0.3 3.9 0.2 3,2 01 APEN Exempt/Insignificant Source
XA Pneumatic Devices 16 5 0 6 15.5 0 6 APEN Exempt/Insignificant Source
XA Compressor Slowdowns 0.5 0.0 0.5 0.0 APEN Exempt/Insignificant Source
XA Produced Water Vaults 0.9 0 1 0 9 0.1 APEN Exempt/Insignificant Source
FACILITY TOTAL 0.7 0.7 0.0 0.0 20.0 692.6 0.6 34.2 22.1 0.7 0.7 0.0 0.0 10.6 58.4 0.6 23.3 1.9 VOC:Syn Minor(NANSR and OP)
NOx:Minor(NANSR and OP)
CO:Minor(PSD and OP)
HAPS:Syn Minor total and n-Hexane
MCI Not applicable(Area Source)
7777:Area Source
Permitted Facility Total O 1 O 1 0.0 0.0 12 8 666 1 0.0 1O 8 21 3 0.1 0 1 0.0 0 0 3.3 336 0.0 10 1 1.1 Excludes oats exempt from perints/APENs
(A)Change in Permitted Emissions 0.0 0.0 0.0 0.0 -0.8 -31 8 0.0 -3.9 Pubcom not required
Total VOC Facility Emissions(point and fugitive) 57.0 Facility is eligible for GPO2 because s 90 tpy
/5/Change in Total Permitted 000 emissions(point and fugitive) -31 8 Protect emissions less than 25 tpy
Note 1
Note 2
Page 9 of 11 Printed 7/30/2020
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY-HAPs
Company Name Bonanza Creek Energy Operating Company,LLC
County AIRS ID 123
Plant AIRS ID 9A7D
Facility Name Latham 14-2 Production Facility
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 12WE3095 Eighteen(18)500 bbl and Six(6)400 1921 1821 192 616 12621 1264 9.2
bbl condensate storage vessels
002 12WE3095 Two(2)400 bbl condensate storage 0.0
tanks
003 12WE3095 One(1)300bb1,two(2)400 bbl and 460 1445 1.0
two(2)500 bbl produced water
storage vessels.
004 GP02 RICE Arrow A-62 139 16 15 i) 3 1 I8 _ 0.1
005 12WE3095 Hydrocarbon Loadout 66.4 583.4 0.3
006 15WE0168.XA Fugitives 4 7 2 6 25 4 0.0
007 12WE3095 One(1)Sandpiper G1F pneumatic 351 377 88 193 2471 289 1.9
pump
008 13W51040,ON RICE GASJACK OJ230 0.0
009 13WE1041,CN RICE GASJACK OJ230 0.0
010 12WE3095 One(1)Sandpiper GIF pneumatic 0.0
pump
011 GP02.CN RICE Caterpillar G3408TA 0.0
012 GP02.CN RICE Caterpillar 034081A _ 0.0
013 13WE2855.CN Process Flare 0.0
014 12WE3095 Six(6)low pressure separators,two 1844 852 111 224 13700 899 8.8
(2)heater treaters and two(2)vapor
recover towers
015 12WE3095 One(1)Sandpiper 41F pneumatic 0.0
prsnp(°P-4°)
016 12W53095 Low pressure separator 0.0
017 12WE3095 Low pressure separator 0.0
018 GP02.CN RICE Caterpillar G3508 ULf3 0.0
019 GP02.CN RICE Caterpillar G3508 ULB 00
020 14WE1334.ON ,RICE GASJACK GJ23046HP 0.0
021 14WE1335,CN RICE GASJACK GJ230 46HP 0.0
022 GP02,,0N RICE Caterpillar 03512 ULB 0.0
023 12WE33095 Process Flare 0,0
024 ,12WE3095 Process Flare 0,0
025 12WE3095 Two(2)vapor recovery towers 0.o
026 GP02 RICE Caterpillar G3508B 0.0
027 GP02 RICE G3508B 3864 382
XA Heated Separators 4 104 0.1
XA Pneumatic Devices 109 119 21 60 777 92 0.6
XA Compressor Blowdowns 3 3 1 2 23 3 0.0
XA Produced Water Vaults 47 149 0.1
0.0
0.0
TOTAL(tpy) 2.0 0.2 0.0 2.4 1.6 0.2 0.6 15.9 0.0 1.3 0.0 0.0 24.2
*Total Reportable=all HAPs where uncontrolled emissions>de minimus values
Red Text uncontrolled emissions,.de minions
10 12WE3095.CP8 7/30/2020
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY-HAPs
Company Name Bonanza Creek Energy Operating Company,LLC
County AIRS ID 123
Plant AIRS ID 9A7D
Facility Name Latham 14-2 Production Facility
123-9A7D Emissions with controls(lbs per year)
POINT IPERMIT IDescription 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 12WE3095 Eighteen(18)500 bbl and Six(6)400 96 91 10 31 631 63 0.5
bbl condensate storage vessels
002 12WE3095 Two(2)400 bbl condensate storage 0.0
tanks
003 12WE3095 One(1)300bb1,two(2)400 bbl and 23 72 0.0
two(2)500 bbl produced water
storage vessels.
004 GP02 RICE Arrow A-6234 16 15 0 3 18 0.0
005 12WE3095 Hydrocarbon Loadout 3 29 0.0
006 15WE0168.XA Fugitives 4 7 2 6 25 4 0.0
007 12WE3095 One(1)Sandpiper G1F pneumatic 18 19 5 10 124 15 0.1
pump
008 13WE1040.CN RICE GASJACK GJ230 0.0
009 13WE1041.CN RICE GASJACK GJ230 0.0
010 12WE3095 One(1)Sandpiper G1F pneumatic 0.0
pump
011 GP02_CN RICE Caterpillar G3408TA 0.0
012 GP02.ON RICE Caterpillar G3408TA 0.0
013 13WE2855.CN Process Flare 0.0
014 12WE3095 Six(6)low pressure separators,two 92 43 6 11 685 45 0.4
(2)heater treaters and two(2)vapor
recover towers
015 12WE3095 One(1)Sandpiper G1F pneumatic 0.0
pump("P-4")
016 12WE3095 Low pressure separator 0.0
017 12WE3095 Low pressure separator 0.0
018 GP02.ON RICE Caterpillar G3508 ULB 0.0
019 GP02.CN RICE Caterpillar G3508 ULB 0.0
020 14WE1334.ON RICE GASJACK GJ230 46HP 0.0
021 14WE1335.ON RICE GASJACK GJ230 46HP 0.0
022 GP02,CN RICE Caterpillar G3512 ULB 0.0
023 12WE3095 Process Flare 0.0
024 12WE3095 Process Flare 0.0
025 12WE3095 Two(2)vapor recovery towers 0.0
026 GP02 RICE Caterpillar G3508B 0.0
027 GP02 RICE G3508B 3870 382
XA Heated Separators 4 104 0.1
XA Pneumatic Devices 109 119 21 60 777 92 0.6
XA Compressor Slowdowns 3 3 1 2 23 3 0.0
XA Produced Water Vaults 47 149 0.1
0.0
0.0
TOTAL(tpy) 2.0 0.2 0.0 0.2 0.1 0.0 0.1 1.3 0.0 . 0.1 0.0 0.0 4.0
11 12WE3095.CP8 7/30/2020
Hydrocarbon Liquid Loading APEN
• 4440 it,
Form APCD-208
CDPHE 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
fora new filing fee.
This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category,
there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit,
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.
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: .113O--- 1 i.(Al E 3 c2,9 5AIRS ID Number: 123 9A7D /005
Section 1 - Administrative Information
Company Name': Bonanza Creek Energy Operating Company, LLC
Site Name: Latham 14-2 Production Facility(COGCC#429121)
Site Location
Site Location:
SWSW, 4N, 2, 63W County: Weld
40.33782, -104.41442
NAICS or SIC Code: 1311
Mailing Address:
(Include Zip Code) 410 17th Street, Suite 1400
Denver, CO 80202 Contact Person: Alisson Soehner
Phone Number: (303) 803-1752
E-Mail Address2: asoehner@bonanzacrk.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.
427300
A¢® COLONLDO
MW.1
moment
Permit Number: TBD AIRS ID Number: 123 /9A7D/005
Section 2 - Requested Action
O NEW permit OR newly-reported emission source
Request coverage under construction permit O Request coverage under General Permit GP07
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 fuel or equipment O Change company name3
❑ Change permit limit O Transfer of ownership4 O Other(describe below)
-OR-
❑ APEN submittal for update only(Note blank APENs will not be accepted)
-MOTIONAL PERMIT ACTIONS-
❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE)
Additional Info&Notes: Currently permitted under GP07. Requesting coverage under traditional construction permit.
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: Truck loadout of condensate.
Company equipment Identification No. (optional): L-01
For existing sources, operation began on: 8/14/2012
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area? El Yes O No
Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes (] No
emissions?
Does this source load gasoline into transport vehicles? O Yes El No
Is this source located at an oil and gas exploration and production site? 0 Yes O No
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual Yes O No
average?
Does this source splash fill less than 6,750 bbl of condensate per year? El Yes O No
Does this source submerge fill less than 16,308 bbl of condensate per year? O Yes ❑Q No
.. .COtOR�00
fbtl A.6 Emma ewrM
Permit Number: TBD AIRS ID Number: 123 /9A7D/005
Section 4 - Process Equipment Information
Product Loaded: 0 Condensate ❑ Crude Oil 0 Other:
If this APEN is being filed for vapors displaced from cargo carrier, complete the following:
Requested Volume Loaded5: 162,060 bbl/year Actual Volume Loaded: 162,060 bbl/year
This product is loaded from tanks at this facility into: tank trucks
(e.g. "rail tank cars"or"tank trucks")
If site specific emission factor is used to calculate emissions,complete the following:
Saturation Factor: N/A Average temperature of N/A F
bulk liquid loading:
True Vapor Pressure: N Psia @ 60 `F Molecular weight of N/A
/A lb/Ib-mol
displaced vapors:
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume Loaded5: N/A bbl/year Actual Volume Loaded: N/A bbl/year
Product Density: N/A lb/ft3
Load Line Volume: NSA ft3/truckload Vapor Recovery Line Volume: NSA ft3/truckload
5 Requested values will become permit limitations or wilt be evaluated for exempt status,as applicable,and should consider
future process growth. Requested values are required on all APENs,including APEN updates.
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.33782,-104.41442
❑Check box if the following information is not applicable to the source because emissions will not be emitted
from a stack. If this is the case, the rest of this section may remain blank.
Operator , Discharge Height Above Temp. Flow Rate Velocity
Stack ID No. Ground Level(Feet) ('F) (ACFM) (ft/sec)
ECD 01-03,&06-08 -35 500 N/A N/A
Indicate the direction of the stack outlet: (check one)
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): 48
❑Square/rectangle Interior stack width (inches): Interior stack depth(inches):
❑Other(describe): • COLORADO
- .. ! NNeh 6 tn.rmment
Permit Number: TBD AIRS ID Number: 123 /9A7D/005
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.
0 Loading occurs using a vapor balance system: Requested Control Efficiency: 100
Used for control of: VOC,HAPs
Rating: 0.11 MMBtu/hr
Type: Enclosed Combustor Make/Model: Six(6)LEED 48"
Combustion
Device: Requested Control Efficiency: 95
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: N/A F Waste Gas Heat Content: 3,299 Btu/scf
Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: N/A MMBtu/hr
Pollutants Controlled:
0 Other: Description:
Requested Control Efficiency: %
Section 7 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? El Yes 0 No
If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or
combined,values if multiple emission control methods were identified in Section 6):
Collection Efficiency Control Efficiency
Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured
by control equipment) emissions)
PM
SOX
NOx
CO
VOC ECU 100 95
HAPs ECD 100 95
Other:
0 Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane
Ei Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL
0 Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL
From what year is the following reported actual annual emissions data? 2019
Use the following table to report the criteria pollutant emissions from source:
Requested Annual Permit
Emission Factor Actual Annual Emissions
Emission Limit(s)5
Pollutant Source Uncontrolled Controlled Uncontrolled Controlled
Uncontrolled Units (AP-42, Emissions Emissionsb Emissions Emissions
Basis Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year)
PM 40.0 u9/L AP-42 0.004 0.004 0 004 0.004
SO,, 0.00017 lb/MMBtu AP-42 <0 01 <0.01 <0 01 <0 01
NO 0 068 Ib/MMBtu AP-42 0.033 0.033 0.033 0 033
CO 0.310 ib/MMBtu AP-42 015 015 0.15 0.15
VOC 0,236 lb/bbl State EF 19.17 0 96 19.17 0.96
5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider
future process growth. Requested values are required on all APENs,including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
COLORADO
INpomment Pub.
EMiU 8 Fnsrmmmr
Permit Number: TBD AIRS ID Number: 123 /9A7D/005
Section 8 - Non-Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non-criteriari Yes ❑ No
pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year?
If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source:
Chemical Emission Factor Actual Annual Emissions
Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled
Service(CAS) Basis Units (AP-42, Emissions Emissions6
Number Mfg.,etc.) (tbs/year) (tbslyear)
Benzene 71432 0.00041 lb/bbl State EF De Minimis De Minimis
Toluene 108883 N/A N/A N/A N/A N/A
Ethylbenzene 100414 N/A N/A N/A N/A N/A
Xylene 1330207 N/A N/A N/A N/A N/A
n-Hexane 110543 0.0036 Ib/bbl State EF 563 29
2,2,4-Trimethylpentane 540841 N/A N/A N/A N/A N/A
Other:
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
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 GP07, I further certify that this source
is and will be operated in full compliance with each con ition of General Permit GP07. + • O
Signature of Legally Authorized Person (not a vendor or consultant) Date
Alisson Soehner Environmental Engineer, Air Quality
Name(print) Title
Check the appropriate box to request a copy of the:
(]Draft permit prior to issuance
El 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
Air Pollution Control Division OR
APCD-SS-B1 (303)692.3148
4300 Cherry Creek Drive South
Denver, CO 80246-1530 APCD Main Phone Number
(303) 692.3150
Make check payable to:
Colorado Department of Public Health and Environment
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Gas Venting APEN - Form APCD-211
0 .44k4IIT Ill Air Pollutant Emission Notice (APEN) and
C
COPHE 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.
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: 12WE3095 AIRS ID Number: 123 /9A7D /014
Section 1 - Administrative Information
Company Name': Bonanza Creek Energy Operating Company, LLC
Site Name: Latham 14-2 Production Facility(COGCC#429121)
Site Location
Site Location: SWSW, 4N, 2, 63W Weld
county:
40.33782, -104.41442
NAICS or SIC Code: 1311
Mailing Address: 410 17th Street, Suite 1400
(Include Zip Code)
Denver, CO 80202 Contact Person: Alisson Soehner
Phone Number: (303) 803-1752
E-Mail Address2: asoehner@bonanzacrk.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.
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Permit Number: 1 2WE3O95 AIRS ID Number: 1 23 /9A7D/014
Section 2 - Requested Action
0 NEW permit OR newly-reported emission source
-OR-
• MODIFICATION to existing permit(check each box below that applies)
0 Change fuel or equipment 0 Change company name3 0 Add point to existing permit
❑✓ Change permit limit ❑ Transfer of ownership4 ❑ 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&Notes: Requesting lower throughput and emissions using previously established emission factors.
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: Low pressure gas from separators controlled by enclosed combustion devices
Company equipment Identification No. (optional): LPGFL
For existing sources, operation began on: 8/14/2012
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 Operation: 24 hours/day 7 days/week 52 weeks/year
Will this equipment be operated in any NAAQS
(] Yes 0 No
nonattainment area?
Is this equipment located at a stationary source that is ❑ Yes i No
considered a Major Source of(HAP) Emissions?
Is this equipment subject to Colorado Regulation No. 7, 0 Yes 0 No
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Permit Number: 12WE3O955 AIRS ID Number: 123 /9A7D/O 1 4
Section 4 - Process Equipment Information
0 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? 0 Yes 0 No
Gas
Vent Ga
II : 241 2 BTU/SCF
Gas Venting Heating Value. ,
Process Parameters: Requested: 9.5 MMSCF/year Actual: 9,5 MMSCF/year
•
-OR-
Liquid Throughput
Requested: N/A bbl/year Actual: N/A bbl/year
Process Parameters:
Molecular Weight: 42.4
voC (Weight%) 77.5738
Benzene(Weight%) 0.1735
Vented Gas Toluene (Weight%) 0.0801
Properties: Ethylbenzene(Weight%) 0.0104
Xylene(Weight%) 0.0210
n-Hexane (Weight°%) 1.2892
2,2,4-Trimethylpentane (Weight%) 0.0846
Additional Required Documentation:
❑✓ Attach a representative gas analysis(including BTEX li n-Hexane, temperature, and pressure)
❑ Attach a representative pressurized extended liquids analysis(including BTEX b n-Hexane, temperature, and
pressure)
5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider
future process growth. Requested values are required on all APENs,including APEN updates.
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Permit Number: 12WE3095 AIRS ID Number: 123 /9A7D/014
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.33782,-104.41442
O Check box if the following information is not applicable to the source because emissions will not be emitted
from a stack. If this is the case, the rest of this section may remain blank.
Discharht
Operator Temp. Flow Rate Velocity
Stack ID No. Above Ground Level (•F) (ACFM) (fttsetj
ECD 01-03, & 06-08 -35 500 N/A N/A
Indicate the direction of the stack outlet: (check one)
❑ Upward O Downward O Upward with obstructing raincap
❑ Horizontal ❑ Other(describe):
Indicate the stack opening and size: (check one)
❑r Circular Interior stack diameter(inches): 48
❑Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑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:
Size: Make/Model:
O VRU:
Requested Control Efficiency:
VRU Downtime or Bypassed: %
Pollutants Controlled: VOC, HAPs
Rating: 2.62 MMBtu/hr
Type: Enclosed Combustor Make/Model: Six(6) LEED 48"
❑
Combustion Requested Control Efficiency: 95 %
Device:
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: N/A Waste Gas Heat Content: 2,412 Btu/scf
Constant Pilot Light: ❑ Yes ✓❑ No Pilot burner Rating: N/A MMBtu/hr
Pollutants Controlled:
❑ Other: Description:
Requested Control Efficiency:
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Permit Number: 1 2WE30955 AIRS ID Number: 123 /9A7D/014
Section 7 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No
If yes, describe the control equipment AND state the collection and control efficiencies(report the overall, or
combined, values if multiple emission control methods were identified in Section 6):
Collection Efficiency Control Efficiency
Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured
by control equipment) emissions)
PM
SO.
NOx
CO
VOC ECD 100 95
HAPs ECD 100 95
Other:
From what year is the following reported actual annual emissions data? 201 9
Use the following table to report the criteria pollutant emissions from source:
Requested Annual Permit
Emission Factor Actual Annual Emissions
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 40 0 ug/L AP-42 0.13 0.13 0 13 0.13
SOX 0.00003 Ib/MMBtu AP-42 0.01 0.01 0.01 0.01
NOx 0.068 Ib/MMBtu AP-42 0.79 0.79 0 79 0.79
CO 0.310 lb/MMEitu AP-42 3.56 3.56 3.56 3.56
VOC 86.763.94 lb/SAMscf Permit 17 412 14 20.61 412.14 20.61
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs,including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
Section 8 - Non-Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non-criteria Yes ❑ No
pollutants(e.g. HAP - hazardous air pollutant)equal to or greater than 250 lbs/year?
If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source:
, Chemical Emission Factor Actual Annual Emissions
Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled
Service(CAS) Units (AP-42, Emissions Emissions
6
Basis Mfg.,etc.) (lbs/ (lbs/year)
year) (ltrs/ ear)
Benzene 71432 194.05 lb/MMscf Permit 17 1,844 94
Toluene 108883 89 59 Ib/MMscf Permit 17 852 44
Ethylbenzene 100414 1177 lb/MMscf Permit 17 De Minimis De Minimis
Xylene 1330207 23.49 Ib/MMscf Permit 17 De Minimis De Minimis
n-Hexane 110543 1,441.93 Ib/MMscf Permit 17 13.700 686
2,2,4-Trimethylpentane 540841 94.62 Ib/MMscf Permit 17 900 46
Other:
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
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Permit Number: 12WE3095 AIRS ID Number: 123 /9A7D/014
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
• 11 • 2O
Signature of Legally Authorized Person(not a vendor or consultant) Date
Alisson Soehner Environmental Engineer, Air Quality
Name (print) Title
Check the appropriate box to request a copy of the:
0 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 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
APCD-SS-B1 OR
4300 Cherry Creek Drive South (303)692-3148
Denver, CO 80246-1530
APCD Main Phone Number
Make check payable to: (303) 692-3150
Colorado Department of Public Health and Environment
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