HomeMy WebLinkAbout20203457.tiff y C .,XY": COLORADO
`_jll° Department of Public
��i1� Health&Environment
Weld County - Clerk to the Board
1150 O St
PO Box 758 RECEIVED
Greeley, CO 80632
NOV 16 2020
November 2, 2020
WELD COUNTY
COMMISSIONERS
Dear Sir or Madam:
On November 3, 2020, the Air Pollution Control Division will begin a 30-day public notice period for
Bonanza Creek Energy Operating Company, LLC - State Seventy Holes T-6 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 a Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
fir A1�
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.cotorado.gov/cdphe (F.7, i _"4 t"%,
Jared Polis,Governor I Jilt Hunsaker Ryan,MPH, Executive Director it .,)#)
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�yy�i/. Air Pollution Control Division
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CDPHE Notice of a Proposed Project or Activity Warranting Public
C
Comment
Website Title: Bonanza Creek Energy Operating Company, LLC - State Seventy Holes T-6 Production Facility
- Weld County
Notice Period Begins: November 3, 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: State Seventy Holes T-6 Production Facility
This facility is classified as a well production facility.
SESE Section 6, T4N, R62W
Weld County
The proposed project or activity is as follows: This modification updates emission and throughput limits for
the condensate storage tanks, condensate truck loadout and separator venting to be reflective of current
facility operations.
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 14WE0328 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:
Elie Chavez
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
Department of Public
1 IMOP c"' Health&Environment
�•— COLORADO
IIP 4 Air Pollution Control Division
iii Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
CONSTRUCTION PERMIT
Permit number: 14WE0328 Issuance: 2
Date issued:
Bonanza Creek Energy Operating
Issued to: Company, LLC
Facility Name: State Seventy Holes T-6 Production Facility
Plant AIRS ID: 123-9BF4
Physical Location: SESE SEC 6 T4N R62W
County: Weld County
Description: Well Production Facility
Equipment or activity subject to this permit:
Facility AIRS Emissions Control
Equipment Point Equipment Description Description
ID
Condensate Nine (9) 500 ba
tankrrel fixed roof atmospheric
storage 004 Enclosed Flare(s)
storage vessels used to store condensate
TL 006 Truck loadout of condensate by submerged Enclosed Flare(s)
fill using vapor balance
One (1) pneumatic water transfer pump
P-1 008 (Sandpiper, Model G1 F, Serial number Enclosed Flare(s)
2076862), rated at 600 scf/hr
Sep 1, 2, 3 010 Three (3) high/low-pressure (HLP) Enclosed Flare(s)
separators
Point 008: 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
the specific general terms and conditions included in this document and the following specific terms
and conditions.
Page 1 of 15
C ��.,- COLORADO
t�, Air Pollution Control Division
urf Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION
1. This construction permit represents final permit approval and authority to operate this
emissions source. Therefore, it is not necessary to self-certify. (Regulation Number 3, Part B,
Section III.G.5.)
EMISSION LIMITATIONS AND RECORDS
2. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
Annual Limits:
Facility AIRS Tons per Year Emission
Equipment ID Point PM2.5 NO,t VOC CO Type
Condensate 004 --- --- 10.0 --- Point
storage tank
TL 006 --- --- 0.65 --- Point
P-1 008 --- --- 2.7 1.4 Point
Sep-1, 2, 3 010 --- -- 18.9 3.9 Point
Facility-wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons
per year.
Facility-wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year.
The facility-wide emissions limitation for hazardous air pollutants must apply to all permitted
emission units at this facility.
Compliance with the annual limits, for both criteria and hazardous air pollutants, must be
determined on a rolling twelve (12) month total. By the end of each month a new twelve
month total is calculated based on the previous twelve months' data. The permit holder must
calculate actual emissions each month and keep a compliance record on site or at a local
field office with site responsibility for Division review.
3. 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.
4. The emission points in the table below must be operated and maintained with the emissions
control equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit. (Regulation Number 3, Part B, Section III.E.)
Facility AIRS Pollutants
Equipment Point Control Device Controlled
ID
Page 2 of 15
.may COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Condensate 004 Enclosed Flare(s) VOC and HAP
storage tank
TL 006 Enclosed Flare(s) VOC and HAP
P-1 008 Enclosed Flare(s) VOC and HAP
Sep-1, 2, 3 010 Enclosed Flare(s) VOC and HAP
PROCESS LIMITATIONS AND RECORDS
5. This source must be limited to the following maximum processing rates as listed below.
Monthly records of the actual processing rates must be maintained by the owner or operator
and made available to the Division for inspection upon request. (Regulation Number 3, Part B,
II.A.4.)
Process Limits
Facility AIRS
Equipment Point Process Parameter Annual Limit
ID
Condensate 004 Condensate Throughput 109,500 bbl
storage tank
TL 006 Condensate Loaded 109,500 bbl
P-1 008 Natural Gas 5.3 MMscf
Sep-1, 2, 3 010 Natural Gas Vented 12 MMscf
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.
6. Point 010: The owner or operator shall continuously monitor and record the volumetric
flowrate of natural gas vented from the low pressure side of the HLP separators to the enclosed
flare(s) using a flow meter. The flow meter shall continuously measure flowrate and record
total volumetric flow of the waste gas(es) routed to the enclosed flare(s). The flow meter must
be calibrated and maintained per the manufacturer's specifications and schedule. The owner
or operator shall use the monthly throughput records, as required by the 08M Plan for this
point, to demonstrate compliance with the process limits contained in this permit and to
calculate emissions as described in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
Page 3 of 15
CCOLORADO
'•.(40N- Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
7. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001)
must be marked on the subject equipment for ease of identification. (Regulation Number 3,
Part B, Section III.E.) (State only enforceable)
8. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
9. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of
the source. During periods of startup, process modification, or adjustment of control
equipment visible emissions shall not exceed 30% opacity for more than six minutes in any
sixty consecutive minutes. Emission control devices subject to Regulation 7, Part D, Sections
I.C.1.d or II.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1.
Et 4.)
10. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall
allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%
opacity for a period or periods aggregating more than six minutes in any sixty consecutive
minutes. (Reference: Regulation No. 1, Section II.A.5.)
)
11. Points 004, 006: 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 property. 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.
12. Point 004: This source is subject to Regulation Number 7, Part D, Section I. The operator
must comply with all applicable requirements of Section I and, specifically, must:'
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for storage tanks;
• Ensure that all hydrocarbon liquids and produced water collection, storage,
processing, and handling operations, regardless of size, must be designed, operated,
and maintained so as to minimize emission of volatile organic compounds to the
atmosphere to the maximum extent practicable. (Regulation Number 7, Part D,
Section I.C.); and
• Ensure that the combustion device controlling emissions from this storage tank be
enclosed, have no visible emissions, and be designed so that an observer can, by
means of visual observation from the outside of the enclosed combustion device, or by
other means approved by the Division, determine whether it is operating properly.
(Regulation Number 7, Part D, Section I.C.) (State only enforceable)
13. Point 004: The storage tank covered by this permit is subject to the emission control
requirements in Regulation Number 7, Part D, Section II.C.1. The owner or operator must
install and operate air pollution control equipment that achieves an average hydrocarbon
control efficiency of 95%. If a combustion device is used, it must have a design destruction
efficiency of at least 98% for hydrocarbons except where the combustion device has been
Page 4 of 15
• COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
authorized by permit prior to March 1, 2020. The source must follow the inspection
requirements of Regulation Number 7, Part D, Section II.C.1.d. and maintain records of the
inspections for a period of two years, made available to the Division upon request. This
control requirement must be met within 90 days of the date that the storage tank commences
operation.
14. Point 004: The storage tanks covered by this permit are subject to the venting and Storage
Tank Emission Management System ("STEM") requirements of Regulation Number 7, Part D,
Section II.C.2.
15. Point 006: This source is located in an ozone non-attainment or attainment-maintenance area
and is subject to the Reasonably Available Control Technology (RACT) requirements of
Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted
by submerged fill. (Reference: Regulation 3, Part B, III.E)
16. Point 006: The owner or operator shall follow loading procedures that minimize the leakage of
VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E):
a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other
liquid or vapor toss during loading and unloading.
b. All compartment hatches (including thief hatches) shall be closed and latched at all
times when loading operations are not active, except for periods of maintenance,
gauging, or safety of personnel and equipment.
c. The owner or operator shall inspect loading equipment and operations on site at the
time of the inspection to ensure compliance with Condition 15 (a) and (b) above. The
inspections shall occur at least monthly.Each inspection shall be documented in a log
available to the Division on request.
17. Point 006: All hydrocarbon liquid loading operations, regardless of size, shall be designed,
operated and maintained so as to minimize leakage of volatile organic compounds to the
atmosphere to the maximum extent practicable.
18. Point 006: 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 006: Storage tanks must operate without venting at all times during loadout. (Regulation
Number 7, Part D, Section II.C.5.a.(ii))
20. Point 006: The owner or operator must, as applicable (Regulation Number 7, Part D, Section
II.C.5.a.(iii)):
Page 5 of 15
COLORADO
C404';401°I Air Pollution Control Division
Department of Public Health Ex Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• 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 006: 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 006: 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.
Page 6 of 15
•r,:fx COLORADO
IP � _ Air Pollution Control Division
Department of Pubiic Health f&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• Records of the annual training program, including the date and names of persons
trained.
23. Point 006: 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 008: This source is subject to the requirements of Regulation Number 7, Part D,
Sections I.C, I.K.2, and I.K.3 including but not limited to:
• Beginning May 1, 2018, the owner or operator of each natural gas-driven diaphragm
pneumatic pump located at a well production facility must reduce volatile organic
compound emissions from the pneumatic pump by 95% if it is technically feasible to
route emissions to an existing control device or process at the well production facility.
• All air pollution control equipment used to demonstrate compliance with Section I.K
must meet a control efficiency of at least 95%.
• The combustion device controlling emissions from the pneumatic pump(s) must 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.
• All combustion devices installed on or after January 1, 2018 and used to comply with
Section I.K must be equipped with an operational auto-ignitor upon installation of the
combustion device.
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 Ft MAINTENANCE REQUIREMENTS
26. Upon startup of these points, the owner or operator must follow the most recent operating
and maintenance (OEM) plan and record keeping format approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions
to the OEtM plan are subject to Division approval prior to implementation. (Regulation
Number 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
27. This source is not required to conduct initial testing, unless otherwise directed by the Division
or other state or federal requirement.
Periodic Testing Requirements
Page 7 of 15
xT.•� COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
28. This source is not required to conduct periodic testing, unless otherwise directed by the
Division or other state or federal requirement.
ALTERNATE OPERATING SCENARIOS
29. Point 008: 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 shall be the
same make, model and capacity as authorized in this permit.
30. Point 008: The owner or operator shall maintain a log on-site or at a local field office to
contemporaneously record the start and stop dates of any pump replacement, the
manufacturer, model number, serial number and capacity of the replacement pump.
31. Point 008: 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. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A,
II.C.)
• Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five
(5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) 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
• 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
Page 8 of 15
,•r,� ... COLORADO
_„of Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• No later than 30 days before the existing APEN expires.
34. The requirements of Colorado Regulation No. 3, Part D must apply at such time that any
stationary source or modification becomes a major stationary source or major modification
solely by virtue of a relaxation in any enforceable limitation that was established after August
7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a
restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.B).
With respect to this Condition, Part D requirements may apply to future modifications if
emission limits are modified to equal or exceed the following threshold levels:
Emissions - tons per year
Facility AIRS Equipment Current
p
Equipment Point Description
Pollutant
ID Threshold Permit
Limit
Condensate 004 Storage Tank
storage tank
Liquid
TL 006
Loadout
P-1 008 Pneumatic VOC 50 39.4
Pump Venting
Separator
Sep-1, 2, 3 010 Venting
Insignificant
Sources
Note: APEN and permit exempt sources do not have permit limits. However, the PTE of these sources
(excluding fugitives) is still considered in the project increase when evaluating PSD and NANSR.
GENERAL TERMS AND CONDITIONS
35. This permit and any attachments must be retained and made available for inspection upon
request. The permit may be reissued to a new owner by the APCD as provided in AQCC
Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the
submittal of a revised APEN and the required fee.
36. If this permit specifically states that final authorization has been granted, then the remainder
of this condition is not applicable. Otherwise, the issuance of this construction permit does
not provide "final" authority for this activity or operation of this source. Final authorization
of the permit must be secured from the APCD in writing in accordance with the provisions of
25-7-114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final
authorization cannot be granted until the operation or activity commences and has been
verified by the APCD as conforming in all respects with the conditions of the permit. Once
self-certification of all points has been reviewed and approved by the Division, it will provide
written documentation of such final authorization. Details for obtaining final authorization
Page 9 of 15
:.:r. COLORADO
4 44.4‘00 Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
to operate are located in the Requirements to Self-Certify for Final Authorization section
of this permit.
37. 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.
38. 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.
39. Each and every condition of this permit is a material part hereof and is not severable. Any
challenge to or appeal of a condition hereof must constitute a rejection of the entire permit
and upon such occurrence, this permit must be deemed denied ab initio. This permit may be
revoked at any time prior to self-certification and final authorization by the Air Pollution
Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and
regulations of the Air Quality Control Commission (AQCC), including failure to meet any
express term or condition of the permit. If the Division denies a permit, conditions imposed
upon a permit are contested by the owner or operator, or the Division revokes a permit, the
owner or operator of a source may request a hearing before the AQCC for review of the
Division's action.
40. 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.
41. 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:
Elie Chavez
Permit Engineer
Permit History
Issuance Date Description
Issuance 1 10/14/2014 Issued to Bonanza Creek Energy Operating
Company, LLC
Issuance 2 This Issuance Point 004: Modified throughput and emission
Page 10 of 15
COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
factors
Point 005: Removed point from permit - below
thresholds
Point 006: Modified throughput and emission
factors
Point 007: Removed point from permit - below
thresholds
Point 009: Removed point from permit -
equipment no longer exists
Point 010: Modified throughput and emission
factors
Page 11 of 15
-r•a� COLORADO
Air Pollution Control Division
Department of Public Health&Envtronment
Dedicated to protecting and improving the health and environment of the people of Colorado
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder must pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this
permit. (Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative
Defense Provision for Excess Emissions During Malfunctions. The owner or operator must notify
the Division of any malfunction condition which causes a violation of any emission limit or limits
stated in this permit as soon as possible, but no later than noon of the next working day, followed
by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the
Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non-criteria reportable air pollutants are estimated based upon the
process limits as indicated in this permit. This information is listed to inform the operator of the
Division's analysis of the specific compounds emitted if the source(s) operate at the permitted
limitations.
AIRS Uncontrolled Controlled
Point Pollutant CAS # Emissions Emissions
(Ib/yr) (lb/yr)
Benzene 71432 5,323 266
Toluene 108883 4,240 212
Ethylbenzene 100414 361 18
001 Xylenes 1330207 1,388 69
n-Hexane 110543 29,898 1,495
2,2,4-
540841
Trimethylpentane 1,539 77
Benzene 71432 45 2
Toluene 108883 0 0
Ethylbenzene 100414 0 0
006 Xylenes 1330207 0 0
n-Hexane 110543 394 20
2,2,4-
540841 0 0
Trimethylpentane
008 Benzene 71432 245 12
Page 12 of 15
-- COLORADO
o
N_ r/ Air Pollution Control Division
i Department of Public tfeatth&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Toluene 108883 170 9
Ethylbenzene 100414 16 1
Xylenes 1330207 53 3
n-Hexane 110543 1,543 77
2,2,4-
540841 --- ---
Trimethylpentane
Benzene 71432 2,648 132
Toluene 108883 1,992 100
Ethylbenzene 100414 178 9
010 Xylenes 1330207 719 36
n-Hexane 110543 16,773 839
2,2,4-
540841 10 1
Trimethylpentane
Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year
(lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice.
5) The emission levels contained in this permit are based on the following emission factors:
Point 004:
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
VOC 3.6554 0.1828
71432 Benzene 0.0486 0.0024
108883 Toluene 0.0387 0.0019
100414 Ethylbenzene 0.0033 0.0002 Site Specific
1330207 Xylene 0.0127 0.0006 Sample + ProMax
110543 n-Hexane 0.2730 0.0137
540841 2'2'4 0.0141 0.0007
Trimethylpentane
Note: The controlled emissions factors for this point are based on a control efficiency of 95%. The emission factors
listed above are based on a ProMax simulation conducted on 4/24/2020 using a site-specific extended liquids analysis
obtained on 12/12/2013 at 40 psig and 120'F.
Point 006:
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
VOC 0.236 0.01180 State Default
Emission Factors
110543 n-Hexane 0.0036 0.00018 for Condensate
Note: Controlled emission factors are based on a flare efficiency of 95%and a collection efficiency of 100%.
Page 13 of 15
Ct4;r COLORADO
AO Air Pollution Control Division
ie department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Point 008:
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/MMscf vented lb/MMscf vented
CO AP-42 Chapter
(lb/MMBtu) 0.31 0.31 13.5
V0C 20240.5057 1012.0253 Gas Analysis
71432 Benzene 46.5775 2.3289 Gas Analysis
108883 Toluene 32.3341 1.6167 Gas Analysis
1330207 Xylene 10.0848 0.5042 Gas Analysis
110543 n-Hexane 293.5577 14.6779 Gas Analysis
Note: The controlled emissions factors for this point are based on a control efficiency of 95%.
Point 010:
Weight Uncontrolled Controlled
Fraction of Emission Emission
CAS # Pollutant Gas (%) Factors Factors Source
lb/MMscf lb/MMscf
CO --- 644.18 644.18 AP-42 Chapter
13.5
V0C 65.37% 62,933.79 3,146.69 Gas Analysis
71432 Benzene 0.23% 220.67 11.03 Gas Analysis
108883 Toluene 0.17% 165.99 8.30 Gas Analysis
1330207 Xylene 0.06% 59.89 2.99 Gas Analysis
110543 n-Hexane 1.45% 1,397.79 69.89 Gas Analysis
Note: The controlled emissions factors for this point are based on a control efficiency of 95%. The VOC and HAP
emission factors listed above are based on a site-specific extended gas analysis obtained from the low pressure side of
the HLP separators on 12/12/2013 at 43 psig and 120'F. The weight%values listed in the table above and molecular
weight (36.5 lb/lbmol)were used with the displacement equation (EPA Emission Inventory Improvement Publication,
Volume II, Chapter 10)to determine the emission factors. The CO emission factor was obtained by converting the AP-
42, Chapter 13.5 factor from lb/MMBtu to lb/MMscf using a waste gas heat content of 2,078 Btu/scf.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A
revised APEN must be submitted no later than 30 days before the five-year term expires. Please
refer to the most recent annual fee invoice to determine the APEN expiration date for each
emissions point associated with this permit. For any questions regarding a specific expiration date
call the Division at (303)-692-3150.
7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and
associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A)
when applicable.
8) This facility is classified as follows:
Page 14 of 15
,,-7 COLORADO
Air Pollution Control Division
Department of Public Health C Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Applicable Status
Requirement
Operating Permit Synthetic Minor Source of: VOC, HAP
PSD Synthetic Minor Source of: VOC
NANSR Synthetic Minor Source of: VOC
MACT HH Area Source Requirements: Not Applicable
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://www.ecfr.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS 60.1-End Subpart A - Subpart UUUU
NSPS Part 60, Appendixes Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
MACT 63.1-63.599 Subpart A - Subpart Z
MACT 63.600-63.1199 Subpart AA- Subpart DDD
MACT 63.1200-63.1439 Subpart EEE - Subpart PPP
MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY
MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM
MACT 63.8980-End Subpart NNNNN - Subpart XXXXXX
Page 15 of 15
Cobrado Air Permitting Project
PRELIMINARY ANALYSIS-PROJECT SUMMARY
Project Details For Division Use Only
Review Engineer: Elie Chavez
Package 8: 431118
Received Date: 5/8/2020
Review Start Date: 10/9/2020
Section 01-Facility Information
Company Name: Bonanza Creek Energy Operating Company,LLC Quadrant Section Township Range
County AIRS ID: 123 SESE 6 4N 62
Plant AIRS ID: 98F4
Facility Name: State Seventy Holes T-6 Production Facility ...r�� ,,0 .,
Physical
Address/Location: , , :uisge 62W
County: Weld County
Type of Facility: Exploration&Production Well Pad
What industry segment?Oil&Natural Gas Production&Processing
Is this facility located in a NAAQS non-attainment area? Yes
If yes,for what pollutant? Ozone(NOx&VOC)
Section 02-Emissions Units In Permit Application
Leave Blank-For Division Use Only
Permit 3
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(
Condensate Storage Permit
004 Storage Tank Tank Yes 14WE0328 2 No Modification
Permit
006 Liquid Loading TL Yes 14WE0328 2 No Modification
Permit
010 Separator Venting SEP-1,2,3 Yes 14WE0328 2 No Modification
Section 03-Description of Project
This modification permits new emission factors and throughput limitations the condensate storage tanks(AIRS 004),condensate truck Ioadout(AIRS 006)and
high/low pressure(HLP)separators(AIRS 010).In addition,the following changes were made to the construction permit:
1.Facility-wide HAP limits were included with this issuance of 14WE0328 as uncontrolled potential HAP emissions from this facility exceed the major source
threshold of 10 tons/year individual HAP(n-Hexane)and 25 tons/year total HAP.Because control devices are used to achieve controlled HAP emissions below the
major source thresholds,synthetic minor HAP limitations of 8 tons/year individual HAP and 20 tons/year total HAP were included in this issuance of 14WE0328.
2.Removed all permit limitations and conditionsrelated to fugitive equipment leaks FUG(AIRS 007)as this point dropped below APEN and permitting thresholds in
accordance with Colorado Regulation No.3,Part A,Section II.D.1.a.and Part B,Section II.D.1.a.,pursuant to a cancellation request received 8/27/2015.
3.Removed all permit limitations and conditions related to produced water storage tanks PW Tanks(AIRS 005)as this point dropped below APEN and permitting thresholds in
accordance with Colorado Regulation No.3,Part A,Section II.D.1.a.and Part B,Section II.D.1.a.,pursuant to a cancellation request received 11/9/2018.
4.Removed all permit limitations and conditions related to the emergency flare FL-1(AIRS 009)as this point no longer exists on site,pursuant to a cancellation
request received 11/9/2018.
5.Included Colorado Regulation No.7,Part D,Section I.K.for pneumatic pump requirements. It should be noted that the Section I.K.requirements did not exist at
the time of previous permit issuance on 10/14/2014.Although this modification request did not alter any permitted limitations for pneumatic pump P-1(AIRS 008),
this pump is subject to the requirements of Section I.K.,as noted in the permit application received 5/8/2020.As such,these applicable requirements were
incorporated into this issuance of the construction permit.
6.Included Colorado Regulation No.7,Part D,Section V.for facility-wide inventory requirements. It should be noted that the Section V.requirements did not exist at the time of
previous permit issuance on 10/14/2014.This facility is subject to the requirements of Section V.,as noted in the permit application received 5/8/2020.As such,these applicable
requirements were incorporated into this issuance of the construction permit.
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
Colorado Air Permitting Project
Section 05-Ambient Air Impact Analysis Requirement
Was a quantitative modeling analysis required? 7ro-
If yes,for what pollutants? av
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? Mo A ,nI
Is this stationary source a synthetic minor? Yes
If yes,indicate programs and which pollutants: S02 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(PSD) DODD ❑ ❑
Title V Operating Permits(OP) ❑ DOR ❑ ❑ ❑ 0
Non-Attainment New Source Review(NANSR) U U.
Is this stationary source a major source?
If yes,indicate programs and which pollutants: S02 NOa CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(PSD) U U IJ U U U
Title V Operating Permits(OP) U U U U U ULU
Non-Attainment New Source Review(NANSR) ❑
Section 01-Administrative Information
(Facility AIRS ID:
County Plant Point
Section 02-Equipment Description Details
Storage Tank Liquid jy ,- pdens2t₹ ;
Detailed Emissions Unit Nine(9)500 barrel fixed roof atmospheric storage vessels used to store condensate
Description: -
Emission Control Device Six(6)LEED L30-0010 Enclosed Flares
Description:
Requested Overall VOC&HAP Control Efficiency at 95.0
Limited Process Parameter 4411,,i' a' }
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Storage Tank(s)
Actual Throughput= 109,500.0 Barrels(bbl)per year
(Requested Permit Limit Throughput= 109,500.0 Barrels(bbl)per year Requested Monthly Throughput= S,:''2. Barrels(bbl)per month
Potential to Emit(PTE)Condensate Throughput= 109,500.0 Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)
Heat content of waste gas= 2968.0 Btu/scf
Volume of waste gas emitted per BBL of liquids
produced= 29;8 scf/bbl
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: 100.8 scfh .-'MMscf/yr
Pilot Fuel Gas Heating Value: 2968.02 Btu/scf . .MMBTU/yr
•
MW (. 53,5 Ib/Ib-mol
Mass Flow From ProMax
Argon/Oxygen 0,0 lb/hr
CO2 0.4 lb/hr
N2 - 0.2 lb/hr
methane 0.9 lb/hr
ethane 5.4 lb/hr
propane 12.0 lb/hr
isobutane 2.3 lb/hr
n-butane 7.7 lb/hr
isopentane 1:9 lb/hr
n-pentane 2.4 lb/hr
cyclopentane 1.1 lb/hr
n-Hexane 3.4 lb/hr
cyclohexane 1.0 lb/hr
Other hexanes 6.7 lb/hr
heptanes 2.7 lb/hr
methylcyclohexane 0.0 lb/hr
224-TMP _ 0.2 lb/hr
Benzene 0.6 lb/hr
Toluene - 0,5 lb/hr
Ethylhenzene 0.0 lb/hr
Xylenes 0.2 lb/hr
CB+Heavies : 1.3 lb/hr
Total
VOC -
Section 04-Emissions Factors&Methodologies ,
Will this storage tank emit flash emissions?
Emission Factors Condensate Tank
Uncontrolled Controlled
Pollutant (lb/bbl) (lb/bbl) Emission Factor Source
(Condensate (Condensate
Throughput) Throughput)
VOC 3:6554: i i Site Specific E.F,(includes flash) E..,
Benzene " 0,0486 0."=)24 Site:Specific E,F,(includes flash)
Toluene 0.0387 :'f iRe Specific E.F,(includes flash)
Ethylbenzene 0.0033 'Specific&F.(includes Flash) -.
Xylene 0.0127 .,,,CC, E.F.(includes flash)
n-Hexane 0,2730 a7 Specific OF.(includes flash)
224TMP 0.0L41r .-liar 0pedfic E.Ft,includes flash)2.; -2
Control Device
Uncontrolled Uncontrolled
Pollutant (lb/MMBtu) (lb/bbl) Emission Factor Source
3 of 14 K:\PA\2014\14W E0328,CP2
- -,'e Tank(s)Emissions Inventory
(waste heat (Condensate
combusted) Throughput)
PM10 :0:0015 AP42Tabtmt4-2(PM10/PM.25)
PM2.5 0.0075 AP42Ta)rle„i4-S(PM10/PM.25)
50x 0.0006 AP-42 1'461 442(5042-2:4O'7,, a. es
NOn 0.0680 _ AP-42 Chanptet 13.5 lndustraaolFlares(NOx) -
CO :0:3100 AP-42 t3tapt6e 13.5 lndan6rid}Flares(CO)
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) (Ib/MMscf) Emission Factor Source
(Pilot Gas Heat (Pilot Gas
Combusted) Throughput)
PM10 ::0.0075 AP-42Tabfe324-2(PM10/PM.ZS)
PM2.5 0.0075 AP-42 Talil 4.2)PM10/PM 25)
50x 0.0006 AP-42Tab(',4-2(50x) -:,y
NOx 0.0680 AP-42 Cli e"t23.5 lndustriol'Flares(N0u}
VOC 0:0054 - AP-42 Taile'1.4-2(VOC)
CO 0.3100 AP-42 Chalker 13.5 Industrial Flares(CO).-
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
PM2.5 ... .:
SOx .. _ _.
NOx _ ..- - -.
VOC ,. .. ...
CO .. .
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(lbs/year) IIbs/year) (Ihs/year) (Ihs/year) (lbs/year)
Benzene -- __.
Toluene _ _ ,
Ethylbenzene .. _ ..
Xylene .. .._ __ = -
n-Hexane -
224 TMP .
4 of 14 K:\PA\2014\14WE0328.CP2
e Tanks;Emissions inventory
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B
Regulation 7,Part D,Section I.C,0,E,F
Regulation 7,Part D,Section I.G,C
Regulation 7,Part D,Section I6B,C.1,C.3 ;
Regulation 7,Part D,Section II.C.2
Regulation 7,Part D,Section II.C.4.a.(i)
Regulation 7,Part D,Section II.C.4.a.(ii(
Regulation 6,Part A,NSPS Subpart Kb
Regulation 1,Part A,NSPS Subpart 0000
NSPS Subpart 0000a
Regulation 8,Part E,MACE Subpart HH
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial and Periodic Sampling and Testing Requirements
For condensate or crude oil tanks,does the company use the state default emissions factors t
estimate emissions? te,
If yes,are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the
uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than or equal to 80 tpy?
If yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company use a site specific emissions factor to estimate emissions? o:#`
If yes and if there re flash emissions,are the emissions factors based on a pressurized liquid sample drawn atthe facility being
permitted(for produced water tanks,a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample •
should he considered representative which generally means site-specific and collected within one year tithe application r I.;"
received date.However,if the facility has not been modified(e.g.,no new wells brought on-line),then it maybe appropriate to : u jj
use an alder site-specific sample.
If no,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Maine 14-03.
•
Does the company requesta control device efficiency greater than 95%for a flare or combustion device? k, .
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20.02
•
Section 08-Technical Analysis Notes
1.Emission calculations based on a site specific sample obtained on 12/12/2013 at 40 psig and 120°F.As indicated in the permit application received 5/8/2020,no changes to these wells(i.e.,additional wells
added,hydraulic refracturing,etc.)have occurred since the wells were originally commissioned.As such,this site-specific sample is considered to be"representative"for the purposes of this application and an
initial requirement to obtain a new sample was not included in the construction permit.
2.The gas to oil ratio(GOR)was updated from the GOR listed in the 5/8/2020 application based on operator correspondence received 10/19/2020.The GOR presented in the 5/8/2020 application of 22.21
scf/bbl was based on the flowrate of VOCs only from the"Total Condensate Tank Emissions"stream calculated by ProMax.It was determined that the GOR should Re based on the total flow of emissions,not just
the VOC emissions,as non-VOC components(i.e.,methane and ethane)contribute to both the total volume of emissions as well as the NO0 and CO generation from combustion of the emissions stream.
Therefore,the GOR was calculated by dividing the total standard volumetric flowrate of the"Total Condensate Tank Emissions"stream in ProMax by the condensate throughput limitation to obtain an updated
GOR(0.00894107 MMscf/day x 1,000,000 scf/MMscf/300 bbl/day=29.8 scf/bbl).As a result,this GOR was used in the Division's preliminary analysis and a redlined APEN with modified NOx and CO emissions
was routed to the operator for approval,
3.NOx and CO emissions from this source are below APEN reporting thresholds.As a result,limits and emission factors are not included in the permit for NOx or CO.
4.It should be noted that an emission factor for VOC associated with pilot light combustion is not incorporated into the permit This is due to the fact that the pilot light only results in a negligible contribution of
VOC(0.007 tpy).This minimal amount of emissions does not impact the total VOC limit for this source and therefore can be ignored.
5.Initial and periodic visible emissions checks for the control device are addressed by the O&M plan.As a result,the permit does not contain initial or periodic opacity testing.
6.This facility is not yet subject to the storage tank measurement system requirements of Colorado Regulation No.7,Part D,Section II.C.4.These requirements apply to existing controlled storage tanks that are
modified after 5/1/2020 such that an additional condensate storage vessel is added.Pursuant to the APEN received with the 5/8/2020 application,the date of last storage vessel installation was 7/2013.As such,
these condensate storage tanks are not subject to the provisions of Section II.C.4.
7.This facility is not subject to the storage vessel provisions of NSPS Kb as the vessels meet the exemption set forth in§60.110b(d)(4)which excludes storage vessels with a capacity less than or equal to
1,589.874 m3(^10,000 bbl)storing condensate prior to custody transfer.Each condensate storage vessel at this facility has a capacity of 500 bbl.Custody transfer is defined in§60.111b as"the transfer of
produced petroleum and/or condensate,after processing and/or treatment in the producing operations,from storage vessels or automatic transfer facilities to pipelines or any other forms of transportation."By
definition,a transfer of condensate from one facility to another must occur.Because the condensate stored at this facility is first treated at this facility and no transfer of facilities has occurred,the storage
vessels are located prior to custody transfer.As such,these storage vessels fulfill both the capacity and custody transfer criteria of this exemption and are therefore not subject to NSPS Kb.
6.This facility is not subject to the storagevessel provisions of NSPS 0000/a as potential VOC emissions,when considering enforceable controls in accordance with 460.5365(e)and§60.5365a(e),are less than 6
tons/year.
9.This facility is not subject to the storage vessel provisions of MACT HIS as individual and total HAP emissions from this facility are below the 10 ton/year individual HAP and 25 tons/year total HAP major source
thresholds.Storage vessel requirements apply only to major sources of HAP.Because facility-wide HAP emissions at this facility are below the major source thresholds for HAP,this facility is not subject to the
storage vessel provisions of MACT 411.
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only) 1.
Uncontrolled
Emissions
AIRS Point# Process# SCC Cade Pollutant Factor Control%Units
444 01 " ^'' ,. v s' PM10 0.02 9 lb/1,000 gallons Condensate throughput
PM2.5 0.02 9 lb/1,000 gallons Condensate throughput
SOx 0.00 0 lb/1,000 gallons Condensate throughput
NOx 0.10 0 lb/1,000 gallons Condensate throughput
VOC 87.04 95 lb/1,000 gallons Condensate throughput
CO 0.83 0 Ib/1,000 gallons Condensate throughput
Benzene 1.16 94 lb/1,000 gallons Condensate throughput
Toluene 0.92 95 lb/1,000 gallons Condensate throughput
Ethylbenzene 0.08 95 lb/1,000 gallons Condensate throughput
Xylene 0.30 OS lb/1,000 gallons Condensate throughput
n-Hexane 6.50 95 lb/1,000 gallons Condensate throughput
224 TMP 0.33 95 lb/1,000 gallons Condensate throughput
5 of 14 K:\PA\2014\14W E0328.CP2
Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
•
Colorado Regulation 3 Parts A and B-APEN and Permit Requirements
Source is in the Non-Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section II.D.1.a)?
Is the construction date(service date)prior to 12/30/2002 and not modified after 12/31/2002(See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional gi
2. grandfather applicability)?
3. 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 B,Section II.D.3)?
'You have indicated that source b in the NomAttainment Aces
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3,Part A,Section II.D.1.a)?
Is the construction date(service date)prior to 12/30/2002 and not modified after 12/31/2002(See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional gi
2. grandfather applicability)?
3. Are total facility uncontrolled VOC emissions greater than 2 TPY,NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3,Part B,Section II.D.2)?
'Source requires a permit
Colorado Regulation 7,Part D,Section I.C-F&G
1. Is this storage tank located in the 8-hr ozone control area or any ozone non-attainment area or attainment/maintenance area(Regulation 7,Part D,Section I.A.1)?
2. Is this storage tank located at oil and gas operations that collect,store,or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural i
3. Is this storage tank located at a natural gas processing plant(Regulation 7,Part D,Section I.G)?
4. Does this storage tank contain condensate?
5. Does this storage tank exhibit"Flash"(e.g.storing non-stabilized liquids)emissions(Regulation 7,part D,Section I.G.2)?
6. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC(Regulation 7,Part D,Section I.D.3.a(ii))?
'Storage tank is subject to Regulation 7,Part 0,Section I.C-F -
Part D,Section I.C.1—General Requirements for Air Pollution Control Equipment—Prevention of Leakage
Part D,Section I.C.2—Emission Estimation Procedures
Part D,Section I.D—Emissions Control Requirements
q
Part D,Section I.E—Monitoring
Part D,Section I.F—Recordkeeping and Reporting
Storage leek is not subject to Regulation 7,Section I:S
Part 0,Section I.G.2-Emissions Control Requirements
Part D,Section I.C.1.a and b —General Requirements for Air Pollution Control Equipment—Prevention of Leakage
Colorado Regulation 7,Part D,Section II
1. Is this storage tank located at a transmission/storage facility?
2. Is this storage tank"located at an oil and gas exploration and production operation ,well production facility',natural gas compressor station'or natural gas processing pli
3. Does this storage tank have a fixed roof(Regulation 7,Part D,Section II.A.20)?
4. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC(Regulation 7,Part D,Section II.C.1.c)?
'Storage Rbek is su :a Regulation 7,Part D Section II,R. 5.1&C 3
Part D,Section II.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part D,Section II.C.1-Emissions Control and Monitoring Provisions
Part D,Section II.C.3-Recordkeeping Requirements -
5. Does the storage tank contain only"stabilized"liquids(Regulation 7,Part D,Section II.C.2.b)?
Storage tank is subject to Regulation 7,Part 0,Section
Part D,Section II.C.2-Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
Is the controlled storage tank located at a well production facility,natural gas compressor station,or natural gas processing plant constructed on or after May 1,2020 or lc
6. facility that was modified on or after May 1,2020,such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydra
Storage Tank is not subject r Part D,Sectio^ii.C.4.as
Is the controlled storage tank located at a well production facility,natural gas compressor station,or natural gas processing plant constructed on or after January 1,2021 i
7. a facility that was modified on or after January 1,2021,such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of
Storage Tank is not subject to Regulation 7,Part 0,Section
40 CFR,Part 60,Subpart Kb,Standards of Performance for Volatile Organic Liquid Storage Vessels
1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters(m 3)["'472 BBLs](40 CFR 60.110b(a))?
2. Does the storage vessel meet the following exemption in 60.111b(d)(4)?
a. Does the vessel has a design capacity less than or equal to 1,589.874 m'("10,000 BBL]used for petroleum'or condensate stored,processed,or treated prior ti
3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after July 23,1984(40 CFR 60.110b(a))?
4. Does the tank meet the definition of"storage vessel"'in 60.111b?
5. Does the storage vessel store a"volatile organic liquid(VOL)"s as defined in 60.111b?
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa['"29.7 psi]and without emissions to the atmosphere(60.110b(d)(2))?;or
b.The design capacity is greater than or equal to 151 m'[ 950 BBL]and stores a liquid with a maximum true vapor pressure a less than 3.5 kPa(60.110b(b))?;or
c.The design capacity is greater than or equal to 75 M3[^'472 BBL]but less than 151 m3[ 950 BBL]and stores a liquid with a maximum true vapor pressure a less
7. Does the storage tank meet either one of the following exemptions from control requirements:
a.The design capacity is greater than or equal to 151 m'[^'950 BBL]and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa but I
b.The design capacity is greater than or equal to 75 M5['472 BBL]but less than 151 m5[-950 BBL]and stores a liquid with a maximum true vapor pressure great
Storage Tan: `c•NSPS Kb
40 CFR,Part 60,Subpart OOOO/OOOOa,Standards of Performance for Crude Oil and Natural Gas Production,Transmission and Distribution
Is this storage vessel located at a facility in the onshore oil and natural gas production segment,natural gas processing segment or natural gas transmission and storage sel
1. industry?
2. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)between August 23,2011 and September 18,2015?
3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after September 18,2015?
4. Are potential VOC emissions'from the individual storage vessel greater than or equal to 6 tons per year?
5. Does this storage vessel meet the definition of"storage vessel"2 per 60.5430/60.5430a?
6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH?
Storage Tank is not subject to NSPS OOOO
[Note: If a storage-vessel is previously determined to be subject to NSPS OOOO/OOOOa due to emissions above 6 tons per year VOC on the applicability determinatior
should remain subject to NSPS OOOO/OOOOa per 60.5365(e)(2)/60.5365a(e)(2)even if potential VOC emissions drop below 6 tons per year]
40 CFR,Part 63,Subpart MACT HH,Oil and Gas Production Facilities
1. It the storage tank located at an oil and natural gas production facility that meets either of the following criteria:
a.A facility that processes,upgrades or stores hydrocarbon liquids'(63.760)a)(2));OR
A facility that processes,upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category
b.delivered to a final end user'(63.760(a)(3))?
2. Is the tank located at a facility that is major3 for HAPs?
3. Does the tank meet the definition of"storage vessel"4 in 63.761?
4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"s per 63.761?
5. Is the tank subject to control requirements under 40 CFR Part 60,Subpart Kb or Subpart OOOO?
(Storage Tank is not subject to MACT HH
Subpart A,General provisions per§63.764(a)Table 2
§63.766-Emissions Control Standards
§63.773-Monitoring
§63.774-Recordkeeping
§63.775-Reporting
RACT Review
RACT review is required if Regulation 7 does not apply AND if the tank is in the non-attainment area. If the tank meets both criteria,then review RACT requirements.
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Q,
Commission regulations. This document is not a rule or regulation,and the analysis it contains may not apply to a particular situation based upon t,
facts and circumstances. This document does not change or substitute for any law,regulation,or any other legally binding requirement and is not I
enforceable.In the event of any conflict between the language of this document and the language of the Clean Air Act„its implementing regulation
Quality Control Commission regulations,the language of the statute or regulation will control. The use of non-mandatory language such as"recoil',
"may,"'should,"and"can,"is intended to describe APCD interpretations and recommendations.Mandatory terminology such as"must"and"requir
intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations,but this documr
_lout Emissions inventory
Section 01-Administrative Information
123 96F4 006
Facility AIRs ID:
County Plant Point
Section 02-Equipment Description Details
Detailed Emissions Unit Truck loadout of condensate by submerged fill using vapor balance
Description: -
Emission Control Device
Six(6)LEED L30-0010 Enclosed Flares
Description:
Is this loadout controlled? Yes
Requested Overall VOC&HAP Control Efficiency%: 95
Section 03-Processing Rate Information far Emissions Estimates
Primary Emissions-Hydrocarbon Loadout
Actual Volume Loaded= 109,500 Barrels(hbl)per year
'Requested Permit Limit Throughput= 109,500.Barrels(bbl)per year Requested Monthly Throughput= 3300 Barrels(bbl)per month
Potential to Emit)PTE)Volume Loaded= -109,500 Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)
Heat content of waste gas= 2424;Btu/scf
Gas to Oil Ratio= 1,79:scf/bbl
Actual Volume of waste gas emitted per year= scf/year
Requested Volume of waste gas emitted per year= scf/year
Actual heat content of waste gas routed to combustion device= :11 MMBTU per year
Requested heat content of waste gas routed to combustion device= 425 MMBTU per year
Potential to Emit(PTE)heat content of waste gas routed to combustion device= 415 MMBTU per year
Control Device
Pilot Fuel Use Rate: - y �+ * scfh 0.0 MMscf/yr Pilot combustion accounted far at condensate storage tanks(Point 004)
Pilot Fuel Gas Heating Value: (Btu/scf 0.i3 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? The._en default e.- ,>>,.,c, to .,_.-ca to estimate eon,.s
Emission Factors Hydrocarbon Loadout
Uncontrolled Controlled
Emission F actor Source
Pollutant
(lb/bbl) (lb/bbl)
(Volume Loaded) (Volume Loaded)
VOC _.3`0E-01 _._u=__ Condensate Loadout State.C.F.
Benzene _35'e4 _ Condensate Loadout State E.F.
Toluene .,,3=.,[-O0 i3E-O0 Condensate Loadout State E.F.
Ethylbenzene •v:;C I I ?.0E<-UJ Condensate:Loadout State E.F.
Xylene _E+Oil -205-d3 Condensate Loadout Sate E.F.
n-Hezane .�__33 1..0E-04 Condensate Loadout State E.F.
224TMP -F^o0 Condensate Loadout State E.F.
Control Device
Uncontrolled Uncontrolled
Pollutant Emission Factor Source
(Ib/MMBtu) (lb/bbl)
(waste heat combusted) (Volume Loaded)
PM10 0.0075 _, AP-42 Table 5.4-2(PMSO/PM.2.5)
PM2.5 0.0075 .-, AP 42 Table SA-2(PN110/PM.2.5)
SOx 0.0006 :- AP-42 Tahie 1.4-2)50x1
NOx 0.0680 AP-42 Chapter 13.5 Industrial Flares(NO3)
CO 0.3100 _. AP-42 Chapter 13.5Indushial Flares(CO)
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant )lb/MMBtu) )Ib/MMscf) Emission Factor Source
(Pilot Gas
(Waste Heat Combusted) Throughput)
PM10
PM2.5
SOx Yi
NOx kze
vac yr
co
3 of 14 K:\PA\2014\14WE0328.CP2
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
PM2.5
50x
NOx
VOC _:! -1= ;S ?'_ -
CO
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(Ibs/year) (Ibs/year) (Ibs/year) (Ibs/year) (Ibs/yearl
Benzene ..
Toluene
Ethylbenzene
Xylene
n-Hex - ._
224 TMP
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B
Regulation 7 Part D Section II.C.S. _. -quids Ica, _..,u,-_is subject to i end I. ,. _..
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial and Periodic Sampling and Testing Requirements
Does the company request a control device efficiency greater than 95%for a flare or combustion device?
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08-Technical Analysis Notes
1.The heat content used in this application was obtained from a site-specific sample analyzed in 2014,as noted in operator correspondence received 10/19/2020.Note that this heat content is more conservative than the state-default value of 2,255
Btu/scf for condensate storage tanks(PS Memo 14-03).As such,this heat content was considered to be acceptable for the purposes of this application.
2.Note that pilot gas emissions from the 6.combustors are calculated with the condensate tank point(AIRS 004).
3.NOx and CO emissions from this source are below APEN reporting thresholds.Asa result,limits and emission factors are not included in the permit for NOx or CO.
4.n-Hexane is the only reportable HAPs for this unit.As a result,this is the only HAP for which emission factors are included in the permit.
5.Initial and periodic visible emissions checks for the control device are addressed by the O&M plan.Asa result,the permit does not contain initial or periodic opacity testing.
6.This source is subject to the hydrocarbon liquid loading requirements of Colorado Regulation No.7,Part D,Section II.C 5,as liquid loadout at this facility exceeds 5,000 bbl/year.These requirements were therefore included in the construction permit.
Note that the compliance date for this facility is 5/1/2021.
7.Included requirement to operate and maintain the control device in order to reduce emissions to less than or equal to the limits established in the construction permit(Condition 4).Because the truck loading point utilizes a control device,it was
added to the control device table of this.Condition 4.
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
Uncontrolled
Emissions
AIRS Point# Process# SCC Code Pollutant Factor Control% Units
006 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 4,2 35 lb/1,000 gallons transferred
CO 03 0 lb/1,000 gallons transferred
Benzene __ 35 lb/1,000 gallons transferred
Toluene .3 lb/1,000 gallons transferred
Ethylbenzene ,. lb/1,000 gallons transferred
Xylene lb/1,000 gallons transferred
n-Hexane _. lb/1,000 gallons transferred
224 TMP lb/1,000 gallons transferred
9 of 14 K:\PA\2014\14WE0328.CP2
Hydrocarbon Loadout Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions and throughput.
Colorado Regulation 3 Parts A and B-APEN and Permit Requirements.
Sources in the Non-Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section ll.D.1.a)?
2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Section II.D.1.1)?
3. Is the loadout operation loading less than 10,000 gallons(238 BBLs)of crude oil per day on an annual average basis?
4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill?
5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure?
6. 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 B,Section ll.D.3)?
IYou hay,indicated -t sauced is in the Nan•Attainrrent Area
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY(Regulation 3,Part A,Section II.D.1.a)?
2. Is the loadout located at an exploration and production site(e.g.,well pad)(Regulation 3,Part B,Section II.D.1.1)?
3. Is the loadout operation loading less than 10,000 gallons(238 BBLs)of crude oil per day on an annual average basis?
4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill?
5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure?
6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY,NOx greater than 5 TPY or CO emissions greater than 10 TPY(Regulation 3,Part B,Section ll.D.2)?
Ier;rit
Colorado Regulation 7 Part D Section II.C.5.
1. Is this condensate storage tank hydrocarbon liquids loadout located eta well production facility,natural gas compressor station or natural gas processing plant? •
2. Does the facility have a throughput of hydrocarbon liquids loadout to transport vehicles greater than or equal to 5,000 barrels?
IThe hydrocarbon liquids loadout source is sub)ert to Regulation Pert C Satceo.r .3
Section II.C.5.a.(i)-Compliance Schedule
Section II.C.5.a.(ii)-Operation without Venting
Section II.C.S.a.(iii)-Loadout Equipment Operation and Maintenance
Section II.C.5.a.(iv)-Loadout observations and Operator Training
Section II.C.5.a.(v)-Records
Section II.C.5.a.(vi)-Requirements for Air Pollution Control Equipment
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This
note rule or regulation,and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances.This document does not change or substitute for
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,,,
regulations,and Air Quality Control Commission regulations,the language of the statute or regulation will control. The use of non-mandatory language such as"recommend,""may,""should,"
intended to describe APCD interpretations and recommendations.Mandatory terminology such as'must"and"requited"are intended to describe controlling requirements under the terms of tl
Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself.
Separator Venting Emissions Inventory
y
Section 01-Administrative Information
Facility AIRS ID: 123 9BF4 010
County Plant Point
Section 02-Equipment Description Details
Three(3)high/low pressure(HLP)separators
Detailed Emissions Unit Description
Six(6)LEED L30-0010 Enclosed Flares
Emission Control Device Description:
Requested Overall VOC&HAP Control Efficiency% 95
Limited Process Parameter Natural Gas Vented a'"',. ' "'*zm, t
Gas meter ,yes,meter is currently installed and operational
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Separator
Actual Throughput= 12.0 MMscf per year
Requested Permit Limit Throughput= 12.0 MMscf per year Requested Monthly Throughput= MMscf per month
Potential to Emit(PTE)Throughput= 12.,0 MMscf per year
Secondary Emissions-Combustion Device(s)for Air Pollution Control
Separator Gas Heating Value: 2078.0 Btu/scf
Volume of waste gas emitted per BBL of
liquids throughput: scf/bbl
Control Device f Pilot combustion accounted for at condensate storage tanks(Point 004)
Pilot Fuel Use Rate: scfh 0.1 MMsd/yr
Pilot Fuel Gas Heating Value: Btu/scf
Section 04-Emissions Factors&Methodologies
Description
Three(3)wells at this facility produce to three(3)heater treaters,which separate high pressure gas from liquids.The high pressure liquids are routed to three(3)high/low pressure(HLP)separators.The high pressure
gas from the high pressure side of the HLP separators and the high pressure gas from the heater treaters are routed to the sales line.If this sales line becomes unavailable,the facility shuts in.The low pressure gas from
the low pressure side of the HIP separators is typically routed to a vapor recovery unit(VRU)for compression,and then routed to the sales line.During vapor recovery unit downtime,the low pressure gas vented from
the low pressure side of the HLP separators is routed enclosed flare(s)for control.In order to develop site specific emission factors,the operator obtained a gas sample from the low pressure side of the HLP separators on.
12/12/2013,The molecular weight and weight%values from the sample were used in conjunction with the Displacement Equation listed below to develop the site specific emission factors.
MW I 36.5 Ib/Ib-mol Displacement Equation
Ex=Q*MW*Xx/C
Weight%
Helium '.0.0
CO2 2.5
N2 0.1
methane 14.2
ethane -17.9
propane 28.5
isobutane 4.7
n-butane 15.3
isopentane 3.9
n-pentane 5.1
cyclopentane 0.4
n-Hexane 1.5
cyclohexane 0.4
Other hexanes 2.4
heptanes 1.5
methylcyclohexane - 0.3
224-TMP 0.0
Benzene 0.2
Toluene '0.2
Ethylbenzene :°0.0
Xylenes 0.1
C8+Heavies 1.0
Total
VOC Wt%
•
11 of 14 K:\PA\2014\14WE0328.CP2
Separator Venting Emissions -s_r tor,
Emission Factors Separator Venting
Uncontrolled Controlled
Emission Factor Source
Pollutant (lb/MMscf) (Ib/MMscf)
(Gas Throughput) (Gas Throughput)
VOC 99953-739- _ .6536 Extended gas analysis
Benzene 71756.6'3=_s 1.033-7 Extended gas analysis
Toluene 105.5862 8.2553 Extended gas analysis
Ethylbenzene 14597_71 0.7414: Extended gas analysis
Xylene 59.88110 29943 ,x5,Extended gas analysis
n-Hexane J757 7SO4 69.8958 r Extended gas analysis
224 TMP e 1665 0 53 Extended gas analysis
Primary Control Device
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Gas Throughput)
PM10 0.0075 _ 15,48331 > AP-42 Table 1.4-2(PMiO/PM.2.5)
PM2.5 0.0075 AP-42 Table 1.4-2(PM10/PM.2.5)
SOx 0.0006 AP-42 Table 1.4-2(50x)
NOx 0.0680 _ .-42 Chapter 13.5 Industrial Flares(Non)
CO 0.3100 _ -42 Chapter 13.5 Industrial Flares(CO)
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Pilot Gas Throughput)
PM10 0.0009
PM2.5 n r-,,,--
-e.
SOx
NOx 95 116671461V36714,595 .0.56:959.,6I5511t16-7:431991-I-65-56691
VOC
. 65 6-3766,5160197-795,7513536534665657-66'5,667:96,6-535653.65 s
CO
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 a 0 i G.! Cl. ,,,,
PM2.5 0.= 0.1 0.1 0.7. .. 16
SOx 3.,, 0.0 0.0 0.:, __ 1
NOx .... 0,8 0.8 0.3 0.' 144
VOC - 3 3 377.1 1550 3676 __._ 3137
CO :. 3.9 3..9 3.9 _ 757
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(lbs/year) (1hs/year) (Ibs/year) (Ibs/year) (Ibs/year)
Benzene 26,1e _s4? 132 2649 132
Toluene !902 100 1932 103
Ethylbenzene .. .. 178 9 1'18
Xylene 713 36 719 36
n-Hexane 10773 039 16773 939
224 TMP _.. 10 _ 13 1
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,8 50 requires 3 pc-n`it ,
Regulation 7,Part D,Section II.B,F -'1 not sub;e_ _.. 4 _.: ,__-
Regulation 7,Part D,Section 11.8.2.e :The cot-7,701 device r-this sec„ra,. s not sv't 3egul.. :.-Part D E--'=cn.1 S.2.e
(See regulatory applicability worksheet for detailed analysis)
12 of 14 K:\PA\2014\14WE0328.CP2
Separator Venting Emissions inventory
Section 07-Initial and Periodic Sampling and Testing Requirements
Using Gas Throughput to Monitor Compliance
zm
Does the company use site specific emission factors based on a gal 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 may be appropriate to use an older site-specific sample.
If no,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.
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? 3m
If yes,the permit will contain:
-An"Initial Testing Requirement"to collect a site-specific as 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?
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?
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
EirF'y1 y w.e✓Url r �,�U//ia_("./rte/ / //,
.i14° x. . t° / ,yPt s s ri't� €)j. ,, s/ /,
4
°s
4,'",06:ATMATe/X5cMilf-00410104414-40.4.4#140110,0W*Atiffi4e,K$V010,70025
4v- a,. - �� }/x,. / ��'
%fl,'/Ed.sp/'3 .,a , .n ',,5'/'? i=%1 000c%i.i,₹=:t a mx 4t ° ,s i'z i sf° ,
Section 08-Technical Analysis Notes
1.Emission calculations are based on a site-specific sample obtained on 12/12/2013 at 43 psig and 120°F.As indicated in the permit application received 5/8/2026,no changes to these wells(i.e.,additional wells added,hydraulic
refracturing,etc.)have occurred since the wells were originally commissioned.As such,this site-specific sample is considered to be"representative"for the purposes of this application and an initial requirementto obtain a new sample was.
not included in the construction permit.
2.Total permitted emissions from this facility are<40 tons/yearVOC.As such,initial and periodic extended gas analyses are not required.
3.Note that pilot gas emissions from the 6 combustors are calculated with the condensate tank point(AIRS 004).
4.NOx emissions from this source are below APEN reporting thresholds.As a result,limits and emission factors are not included in the permit for NOx.
S.Benzene,toluene,xylene and n Hexane are the only reportable HAPs for this unit.As a result,they are the only HAPs for which emission factors are included in the permit.
6.Removed initial compliance requirementto install a flowmeter(Previous Condition 6 of 14WE0328).This flowmeter was installed in accordance with the self-certification requirements and continues to operate in the field.As such,this
one-time requirement has been met and it was therefore removed from the construction permit.
7.Included requirementto calibrate and maintain the flowmeter installed per manufacturer specifications,pursuant to the most current Division-standard language for construction permits.
8.Initial and periodic visible emissions checks for the control device are addressed by the O&M plan.As a result,the permit does not contain initial or periodic opacity testing.
9.This source is not subject to the Colorado Regulation No.7,Part D,Section lI.F.control of emissions from well production facilities requirements.All wells located at this facility were constructed and stimulated prior to 8/1/2014 and
have not been restimulated since.As such,these separators are not subject to the separator control requirements of Section II.P.It should be noted,however,that these separators are controlled by six enclosed flares to meet the emission
limitations required by 14WE0328.
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
AIRS Point# Process# SCC Code Pollutant Uncontrolled Emissions Factor Control% Units
010 01 ":'0-G .v.- PM10 _. _
PM2.5 I C._
500 C
NOx c
VOC
CO c+ 0 lb/M vii:"-
Benzene ems_. :5 Pb/Mss sue;
Toluene 95 Ib/'.'
Ethylbenzene .4 3 9.9 I °'S?₹r c
Xylene 59,9 95 In/M,,,-,
n-Hexane 139'.E
224TMP _-9 95 _.,=
13 of 14 K:\PA\2014\14WE0328.CP2
Separator Venting Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts A and B-APEN and Permit Requirements
'Source t e Non-Attainment Are
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY(Regulation 3,Part A,Section II.D.1.a)?
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 I
IYou have indicated that source is in the Non-Attainment Area
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3,Part A,Section II.D.1.a)?
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 (Regulation
'Source requires a permit
Colorado Regulation 7,Part D,Section II
1. Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014?
- 'cc is not subject to Regulation 7,Part D,Section l3.B.2;F
Section ll.B.2—General Provisions for Air Pollution Control Equipment Used to Comply with Section II
Section II.F-Control of emissions from well production facilities
Alternative Emissions Control.(Optional Section)
a. Is this separator controlled by a back-up or alternate combustion device(i.e.,not the primary control device)that is not enclosed
'The control devi. yt subject to Regulation 7,Part D,Section 11.5.e
Section II.B.2.e—Alternative emissions control equipment
Disclaimer
and Air Quality Control Commission regulations. This document is not a rule or regulation,and the analysis it contains may nc
particular situation based upon the individual facts and circumstances. This document does not change or substitute for any h
or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of th
and the language of the Clean Air Act„its implementing regulations, and Air Quality Control Commission regulations, the lanc
statute or regulation will control. The use of non-mandatory language such as"recommend,""may,""should,"and"can,"is ini
describe APCD interpretations and recommendations.Mandatory terminology such as"must"and"required"are intended to c
controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations,but this documi
Condensate Storage e Tan (s) APEN
Form APCD-205
cPFHE Air Pollutant Emission Notice (APEN) and.
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled
out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment
for a new filing fee.
This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your
emission source does not fall into this category, there may be a more specific APEN available for your source(e.g.
crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General
APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all
available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD)
website.
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: 14WE0328 AIRS ID Number: 123 / 9BF4 /004
Section 1 - Administrative Information
Company Name': Bonanza Creek Energy Operating Company,LLC(BCEOC)
Site Name: State Seventy Holes 7-6 Production Facility(COGCC#433001)
Site Location
Site Location:
SESE, 4N, 6, 62W County: Weld
40.33549, -104.363
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.
431113 •
COLORADO
RWU B Grtrvmmm
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/004
Section 2 - Requested Action
O NEW permit OR newly-reported emission source
❑ Request coverage under traditional construction permit
❑ Request coverage under a General Permit
O GP01 ❑ GP08
If General Permit coverage is requested, the General Permit registration fee of$312.50 must be
submitted along with the APEN filing fee.
-OR-
✓❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name3
D Change permit limit 0 Transfer of ownership4 O Other(describe below)
-OR
• APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
CD APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes: Requesting new throughput and emission limits based on
updated 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: Condensate tank battery used to store condensate.
Company equipment Identification No. (optional): Condensate storage tank
For existing sources, operation began on: 11/11/2013
For new or reconstructed sources, the projected start-up date is:
Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year
Storage tank(s) located at: ✓❑ Exploration Et Production (EEtP)site O Midstream or Downstream (non E&P)site
Will this equipment be operated in any NAAQS nonattainment area? ❑ Yes O No
Are Flash Emissions anticipated from these storage tanks? ❑✓, Yes ❑ No
Is the actual annual average hydrocarbon liquid throughput≥ 500 bbl/day? O Yes ❑✓ No
If"yes", identify the stock tank gas-to-oil ratio: m3/liter
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) ❑ Yes 0 No
805 series rules?If so, submit Form APCD-105.
Are you requesting≥6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual ❑ Yes ❑✓ No
emissions a 6 ton/yr(per storage tank)?
0O64%.x.
Permit Number: 14WEO328 AIRS ID Number: 123 /9BF4/004
Section 4 - Storage Tank(s) Information
Actual Annual Amount Requested Annual Permit Limits
(bbl/year) (bbl/year)
Condensate Throughput: 109,500 109,500
From what year is the actual annual amount? 2019
Average API gravity of sales oil: 39.5 degrees RVP of sales oil: 7
Tank design: Q Fixed roof O Internal floating roof O External floating roof
Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First
Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production
(bbl) Storage Tank(month/year) (month/year)
CNDTK01-09 Nine(9)500 bbl 4,500 7/2013 11/2013
Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only)
API Number Name of Well Newly Reported Well
05 - 123 - 37914 State Seventy Holes 34-31-6HNB O
05 - 123 - 37928 State Seventy Holes O-K-6HNB O
05 - 123 • 37405 State Seventy Holes T-P-6HNB O
O
O
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 The E$P Storage Tank APEN Addendum (Form APCD-212)should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.33549,-104.363
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.
Operator Stack Discharge Height Above Temp. Flow Rate Velocity
ID No. Ground Level(Feet) (°F) (ACFM) (ft/sec)
ECD 01-06 —25 500 TBD TBD
Indicate the direction of the stack outlet: (check one)
0 Upward ❑Downward O Upward with obstructing raincap
❑Horizontal ❑Other(describe):
Indicate the stack opening and size: (check one)
Q Circular Interior stack diameter(inches): 48
❑Square/rectangle Interior stack width(inches): Interior stack depth(inches):
❑Other(describe): COLORxw er,,,a, �..n
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/004
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:
Vapor Size: Make/Model:
❑ Recovery
Unit(VRU): Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
Pollutants Controlled: VOC, HAPs
Rating: 1.12 MMBtu/hr
Type: Enclosed Combustor Make/Model: Six(6) LEED L30-0010
❑ Combustion Requested Control Efficiency: 95 %
Device:
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: 500 Waste Gas Heat Content: 2,968 Btu/scf
Constant Pilot Light: 0 Yes ❑ No Pilot Burner Rating: 0.30 MMBtu/hr
Description of the closed loop system:
❑ Closed Loop System
Pollutants Controlled:
❑ Other: Description:
Control Efficiency Requested:
Section 7 - Gas/Liquids Separation Technology Information (EEtP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 40 psig
Describe the separation process between the welt and the storage tanks:
Well produces to a separator where condensate is separated out and routed to the condensate tank battery.
COLORADO
- Na�sltn6Cnrrtm�inen
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/004
Section 8 - 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? ❑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 (X reduction of captured
by control equipment) emissions)
V0C ECD 100 95
NOx
CO
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:
Emission Factor Actual Annual Emissions Requested Annual Permit
Emission Limit(s)5
Pollutant Source Uncontrolled Controlled Uncontrolled Controlled
Uncontrolled AP-4Y
Basis Units ( Emissions Emissions8 Emissions Emissions
Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tans/year)
VOC 3.6550 lb/bbl ProMax 200.11 10.01 200.11 10.01
NOx 0.068 Ib/MM8tu AP-42 0 34 0.34 a34 0.4 034 0.4
CO 0.370 Ib/MMBtu AP-42 153 7.53 1-33 1.9 1-53 1.9
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. EJC per
7 Attach condensate liquid laboratory analysis,stack test results,and associated emissions calculations if you are requesting site email rec'd
specific emissions factors according to the guidance in PS Memo 14-03. 1 0/28/2020
Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
Section 9 - Non-Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non-criteria0 Yes O 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 Emissions8
Number Mfg.,etc.) Ohs/year) (lbs/year)
Benzene 71432 00486 lb/bbl ProMax 5,323 268
Toluene 108883 0,0387 lb/bbl ProMax 4,240 212
Ethylbenzene 100414 0.0033 lb/bbl ProMax 361 20
Xylene 1330207 00127 lb/bbl ProMax 1 388 70
n-Hexane 110543 02730 b,bbl ProMax 29.894 1,496
2,2,4-Trimethylpentane 540841 0.0141 lb/bbl ProMax 1.538 78
7 Attach condensate liquid laboratory analysis,stack test results,and associated emissions calculations if you are requesting site
specific emissions factors according to the guidance in PS Memo 14-03.
8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
... - .. COLORADO
....-.,==--
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/004
Section 10- 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 GP01 or GP08, I further certify that
this source is and will be operated in full compliance with each condition of the applicable General Permit.
a .- �y � 5/04/2020
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:
Q Draft permit prior to issuance
Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made(significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 and the General Permit For more information or assistance call:
registration fee of$312.50, if applicable, to:
Small Business Assistance Program
Colorado Department of Public Health and Environment (303)692-3175
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
ice.....COLORADO
i a Harr
Hydrocarbon Liquid Loading APEN
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 locks payment for the filing fee. The re-submittal will require payment
for a 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: 14WE0328 AIRS ID Number: 123 / 9BF4 /006
Section 1 -Administrative Information
Company Name': Bonanza Creek Energy Operating Company.LLC(BCEOC)
Site Name: State Seventy Holes T-6 Production Facility(COGCC#433001) t4_
Site Location: Site Location
SESE, 4N, 6, 62W County: Weld
40.33549, -104.363
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
t 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.
431114
COLORADO
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/006
Section 2 - Requested Action
0 NEW permit OR newly-reported emission source
0 Request coverage under construction permit ❑ 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-
0 MODIFICATION to existing permit (check each box below that applies)
0 Change fuel or equipment 0 Change company name3
❑Q Change permit limit 0 Transfer of ownership4 O Other(describe below)
-OR-
❑ APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
El Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE)
Additional Info ft Notes: Requesting new throughput and emission limits using state 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: Truck loadout used to loadout condensate offsite.
Company equipment Identification No. (optional): TL
For existing sources, operation began on: 11/11/2013
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area? 0 Yes 0 No
Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes 0 No
emissions?
Does this source load gasoline into transport vehicles? 0 Yes 0 No
Is this source located at an oil and gas exploration and production site? 0 Yes ❑ No
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual 0 Yes 0 No
average?
Does this source splash fill less than 6,750 bbl of condensate per year? 0 Yes 0 No
Does this source submerge fill less than 16,308 bbl of condensate per year? ❑ Yes 0 No
ICC COLORADO
drystrtanen.a vm.r
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/006
Section 4 - Process Equipment Information
Product Loaded: 0 Condensate 0 Crude Oil 0 Other:
If this APEN is being filed for vapors displaced from cargo carrier, complete the following:
Requested Volume Loaded5: 109,500 bbl/year Actual Volume Loaded: 109,500 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: Average temperature of F
bulk liquid loading:
Molecular weight of
True Vapor Pressure: Psia @ 60 'F lb/lb-mol
displaced vapors:
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year
Product Density: lb/ft3
Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload
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.
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.33549,-104.363
0 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) ('t7 (ACFM) (ft/sec)
ECD 01-06 -25 500 TBD TBD
Indicate the direction of the stack outlet: (check one)
0 Upward 0 Downward 0 Upward with obstructing raincap
❑ Horizontal ❑Other(describe):
Indicate the stack opening and size: (check one)
0 Circular Interior stack diameter(inches): 48
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑Other(describe):
iota* COLORADO
MEP VIff peal. En.r nme
Hwm u u..,,.n,..,n
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/006
/006
Section 6 - Control Device Information
O 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: 0.05 MMBtu/hr
Combustion Type: Enclosed Combustor Make/Model: Six(6)LEED L30-0010
ElDevice: Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98 %
Minimum Temperature: 500 'F Waste Gas Heat Content: 2,424 Btu/scf
Constant Pilot Light: O Yes El No Pilot Burner Rating: N/A MMBtu/hr
Pollutants Controlled:
❑ 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? 0 Yes O 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.
NO,,
CO
VOC EGO 100 95
HAPs ECD 100 95
Other:
Ei Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane
❑Q Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL
O 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 Emissions6 Emissions Emissions
Basis Mfg.,etc.) (tons/year) (tons/year) tons/ ear tons/ ear
(tons/year)) (tons/year)
)
PM 40.0 ug/L AP-42 0.003 0.003 0 003 0 003
SOx 0.00024 Ib/MMEtu AP-42 <0.001 <0.001 <0.001 <0 001
NOx 0.068 Ib/MMBtu AP-42 0.017 0017 0.017 0.017
CO 0.310 Ib/MMBtu AP-42 0 074 0.074 0.074 0.074
VOC 0.236 lb/bbl State EF }2.95 12.9 0.65 12.95 12.9 0.65
5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider EJC per
future process growth. Requested values are required on all APENs,including APEN updates. email rec'd
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide 1 Q,28�202a
projected emissions.
as COIORaDo
d wur
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/006
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) Basis Units (AP-41, Emissions Emissions6
Number Mfg.,etc.) (lbs/year) (lbs/year)
Benzene 71432 0 00041 lb/bbl State EF De Minimis De Minimis
Toluene 108883 N/A N/A N/A N/A NIA
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 IbIbbl State EF 394 20
2,2,4-Trimethylpentane 540841 NIA 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 condition of General Permit GP07.
62441.'i 1-- - 5/04/2020
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:
El 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 5191.13 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
COLORADO
�r�:,„ Gas Venting APEN - Form APCD-211
0 C
Air Pollutant Emission Notice (APEN) and
CDPHE 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 wilt 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: 14WE0328 AIRS ID Number: 123 I 9BF4 /010
. r
Section 1 -Administrative Information
Company Name': Bonanza Creek Energy Operating Company,LLC(BCEOC)
Site Name: State Seventy Holes T-6 Production Facility(COGCC#433001)
Site Location
Site Location: SESE, 4N, 6, 62W Weld
County:
40.33549, -104.363
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.
431115
1 ®-Deportment MU".i a D
COLOR4DO
N i nwronMa
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/O 1 O
Section 2 - Requested Action
O NEW permit OR newlyareported 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
0 Change permit limit ❑ Transfer of ownership' 0 Other(describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
• Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes: Requesting new throughput and emission limits.
3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted.
'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: Three (3) high/low pressure separators controlled by
six (6) enclosed combustors.
Company equipment Identification No. (optional): Sep-1 , 2, 3
For existing sources, operation began on: 11/11/2013
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
Wilt this equipment be operated in any NAAQS
nonattainment area? Q Yes 0 No
Is this equipment located at a stationary source that is
considered a Major Source of(HAP) Emissions? ❑ Yes No
Is this equipment subject to Colorado Regulation No. 7, 0 Yes ❑ No
Section XVII.G?
L� COLORADO
Permit Number: 14WE0328 AIRS ID Number: 123 /9BF4/010
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
Vent Gas 2 078 BTU/SCF
Gas Venting Heating Value: ,
Process Parameters5: Requested: 12 MMSCF/year Actual: 12 MMSCF/year
-OR-
Liquid Throughput
Requested: bbl/year Actual: bbl/year
Process Parameters5:
Molecular Weight: 36.5
voC (Weight%) 65.3656
Benzene (Weight%) 0.2292
Vented Gas Toluene(Weight%) 0.1724
Properties: Ethylbenzene(Weight%) 0.0154
Xy(ene(Weight%) 0.0622
n-Hexane(Weight%) 1.4518
2,2,4-Trimethylpentane(Weight%) 0.0009
Additional Required Documentation:
0 Attach a representative gas analysis(including BTEX a n-Hexane, temperature, and pressure)
❑ Attach a representative pressurized extended liquids analysis(including BTEX Et n-Hexane, temperature, and
pressure)
5 Requested values will become permit(imitations 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.
g® COLORADO
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Permit Number: 1 4WE0328 AIRS ID Number: 1 23 /9BF4/010
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.33549,-104.363
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.
Discharge Height
Operator Temp. Flow Rate Velocity
Above Ground Level _
Stack Ili No. en (ACFM) (ft/sec)
(Feet)
ECD 01-06 —25 500 TBD TBD
Indicate the direction of the stack outlet: (check one)
0 Upward ❑ Downward O Upward with obstructing raincap
❑ Horizontal ❑Other(describe): •
Indicate the stack opening and size: (check one)
❑ Circular Interior stack diameter(inches): 48
❑ Square/rectangle Interior stack width (inches): Interior stack depth(inches):
❑Other(describe):
Section 6 - Control Device Information
O 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:
❑ VRU:
Requested Control Efficiency:
VRU Downtime or Bypassed:
Pollutants Controlled: VOC, HAPs
Rating: 2.85 MMBtu/hr
Type: Enclosed Combustor Make/Model: Six(6) Leed L30-0010
❑ Combustion Requested Control Efficiency: 95
Device:
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: 500 Waste Gas Heat Content: 2,078 Btu/scf
Constant Pilot Light: ❑ Yes ✓❑ No Pilot burner Rating: N/A MMBtu/hr
Pollutants Controlled:
❑ Other: Description:
Requested Control Efficiency:
COLORADO
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Permit Number: 14WE0328 AIRS ID Number: 123 i 9BF4/010
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 0 No I
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
NO.
CO
VOC ECD 100 95
HAPs ECD 100 95
Other:
From what year is the following reported actual annual emissions data? 2019
Use the following table to report the criteria pollutant emissions from source:
Emission Factor Actual Annual Emissions Requested Annual Permit
Emission Limit(s)5
Pollutant Source Uncontrolled Controlled Uncontrolled Controlled
Uncontrolled Units (AP-42, Emissions Emissions6 Emissions Emissions
Basis Mfg.,etc.)
(tons/year) (tons/year) (tons/year) (tons/year)
PM 40.0 ug/L AP-42 016 016 0.16 0.16
SOx <0.001 Ib/MMBtu AP-42 <0.001 <0.001 <0.001 <0.001
NO„ 0.068 Ib/MMBtu AP-42 085 0.85 0.85 0.85
CO 0.310 Ib/MMBtu AP-42 3.87 3.87 3.87 3.87
VOC 62.933.79 Ib/MMscf Gas Analysis 377 61 18.89 377.61 18.89
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 I
Does the emissions source have any uncontrolled actual emissions of non-criteria Yes ❑No i
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
Abstract Source Uncontrolled Controlled
Chemical Name Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions6
Basis Mfg.,etc.) (lbs/year)
Number (lbs/year)
Benzene 71432 22067 lb/MMact lb/bbl 2.650 134 l
Toluene 108883 16599 Ib/MMscf lb/bbl 1,992 100
Ethylbenzene 100414 14 83 Ib/MMscf Ib/bbl De Minimis De Minimis
Xylene 1330207 59.89 lb/MMscf lb/bbl 720 36
n-Hexane 110543 1,39779 Ib/MMscf lb/bbl 16,774 840
2,2,4-Trimethylpentane 540841 0.87 Ib/MMscf lb/bbl De Minimis De Minimis
Other:
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
COLORADO
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Permit Number: 1 4WE0328 AIRS ID Number: 123 i 9BF4/010
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
a �y 5/04/2020
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:
Q Draft permit prior to issuance
❑r 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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