HomeMy WebLinkAbout20202719.tiff et; 44.4COLORADO
Department of Public
Health&Environment
RECEIVED
Weld County - Clerk to the Board AUG 2 4 2020
1150O St
Box 758 WCOMMISSIONERS
Greeley, CO 80632
August 19, 2020
Dear Sir or Madam:
On August 20, 2020, the Air Pollution Control Division will begin a 30-day public notice period for
Bonanza Creek Energy Operating, LLC - State North Platte T-36 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 &t Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
•
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe i ' '9
Jared Potis,Governor I Jilt Hunsaker Ryan,MPH, Executive Director I1'4 �g,l.
cc:PL�(TP), LIDS)?(' L M/ERk.H/cn1 2020-2719
Ocl P�bi ;c Rev;e�„�
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Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
CDPHE
Comment
Website Title: Bonanza Creek Energy Operating, LLC - State North Platte T-36 Production Facility - Weld
County
Notice Period Begins: August 20, 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, LLC
Facility: State North Platte T-36 Production Facility
Exploration Ft Production Well Pad
SESE SEC 5 T36N R63W
Weld County
The proposed project or activity is as follows: Applicant proposes permit modification to points 002, 003,
and 007 based on a new throughput due to the addition of new wells.
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 14WE0187 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.Rov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd®state.co.us
• Send comments to our mailing address:
Ben Fischbach
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
Department of Public
1 I Health&Environment
a._ l,,,,0�r- ! COLORADO
Air Pollution Control Division
Department of Public Health Er Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
CONSTRUCTION PERMIT
Permit number: 14WE01 87 Issuance: 5
Date issued:
Bonanza Creek Energy Operating
Issued to: Company, LLC
Facility Name: State North Platte T-36 Production Facility (COGCC #433300)
Plant AIRS ID: 123/9BDF
Physical Location: SESE SEC 5 T36N R63W
County: Weld County
Description: Well Production Facility
Equipment or activity subject to this permit:
Facility AIRS Emissions Control
Equipment Point Equipment Description Description
ID
CNDTK-01 002 Sixteen (16) 500 Barrel Fixed Roof Storage Enclosed Flare
Vessels Used to Store Condensate
PWT-01 003 Four (4) 500 Barrel Fixed Roof Storage Enclosed Flare
Vessels Used to Store Produced Water
L-01 004 Truck loadout of condensate by submerged Enclosed Flare
fill using vapor balance
LPGFL 007 Twelve (12) Low Pressure Separators and Enclosed Flare
Two (2) Vapor Recovery Towers (VRTs)
One Sandpiper G1 F pneumatic pump used
for water transfer (SN: 2091608).
P-01 008 Emissions are controlled by enclosed Enclosed Flare
combustors with a minimum control
efficiency of 95%
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
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a
�x*:�;� C O L O R A D O
` /� Air Pollution Control Division
�� Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
specific general terms and conditions included in this document and the following specific terms and
conditions.
REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (Division) no later than fifteen days after
commencement of operation of the activity and equipment covered under this Issuance 5
of this permit by submitting a Notice of Startup (NOS) form to the Division. The Notice of
Startup (NOS) form may be downloaded • online at
https://www.colorado.gov/pacific/cdphe/air/manage-permit. Failure to notify the Division of
startup of the permitted source is a violation of AQCC Regulation Number 3, Part B, III.G.1 and
can result in the revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit must be
demonstrated to the Division. It is the owner or operator's responsibility to self-certify
compliance with the conditions. Failure to demonstrate compliance within 180 days may result
in revocation of the permit. A self certification form and guidance on how to self-certify
compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-
permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.)
3. This permit must expire if the owner or operator of the source for which this permit was issued:
(i) does not commence construction/modification or operation of this source within 18 months
after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit (submitted April 21, 2020); (ii) discontinues construction for a
period of eighteen months or more; (iii) does not complete construction within a reasonable
time of the estimated completion date. The Division may grant extensions of the deadline.
(Regulation Number 3, Part B, Section III.F.4.) The owner or operator must operate as
authorized by Issuance 4 of this permit 14WE0187 (dated December 13, 2016) and GP07 (dated
March 6, 2017) until such time that the Division has received the NOS form(s) required by
Condition 1 of this permit Issuance 5.
4. The operator must complete all initial compliance testing and sampling as required in this
permit and submit the results to the Division as part of the self-certification process.
(Regulation Number 3, Part B, Section III.E.)
5. Points 002, 003, 004, 007: Within one hundred and eighty (180) days of the issuance of this
permit, the operator must install equipment necessary to monitor control device pilot light
status as described in this permit.
6. The operator must retain the permit final authorization letter issued by the Division, after
completion of self-certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
7. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
)
Annual Limits:
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•x° ICOLORADO
Air Pollution Control Division
Department of Public Health fs Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Facility AIRS Tons per Year Emission
Equipment ID Point PM2.5 NO. V0C CO Type
CNDTK-01 002 --- 1.1 16.9 5.0 Point
PWT-01 003 --- 1.1 1.5 4.9 Point
L-01 004 --- --- 2.8 --- Point
LPG FL 007 --- 1.1 11.8 5.2 Point
P-01 008 --- --- 2.3 --- Point
Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits.
Facility-wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons per
year.
Facility-wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year.
The facility-wide emissions limitation for hazardous air pollutants must apply to all permitted
emission units at this facility.
Compliance with the annual limits, for both criteria and hazardous air pollutants, must be
determined on a rolling twelve (12) month total. By the end of each month a new twelve 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.
8. The owner or operator must use the emission factors and calculation methods 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.
9. 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
CNDTK-01 002 One (1) Enclosed combustor (FL-1810, VOC and HAP
Make: IES, Model: 96", SN: 9603-0126)
PWT-01 003 One (1) Enclosed combustor (FL-1810, VOC and HAP
Make: IES, Model: 96", SN: 9603-0126)
L 01 004 One (1) Enclosed combustor (FL-1810, VOC and HAP
Make: IES, Model: 96", SN: 9603-0126)
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„;(E COLORADO
Air Pollution Control Division
Department of Public FfeaIth 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Two (2) Enclosed combustors (FL-
LPGFL 007 1810, Make: IES, Model: 96”, SN: VOC and HAP
9603-0126; FL1820, Make: IES, Model
96", SN: 9603-0127)
P-01 008 Enclosed combustor VOC and HAP
PROCESS LIMITATIONS AND RECORDS
10. 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
CNDTK-01 002 Condensate Throughput 1,168,000 barrels
PWT-01 003 Produced Water Throughput 584,001 barrels
L-01 004 Condensate Loaded 1,168,000 barrels
Total gas vented from seven (7) low
LPGFL 007 pressure separators and two (2) vapor 13.1 MMscf
recovery towers
P 01 008 Venting of natural gas used to drive 5.3 MMscf
pneumatic pump
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.
11. Point 007: The owner or operator must continuously monitor and record the volumetric flow
rate of natural gas vented from the low pressure (LP) separators and vapor recovery towers
(VRTs) using flow meters located at the inlet to each enclosed combustor covered by this
permit. The flow meters must be calibrated and maintained per the manufacturer's
specifications and schedule. The owner or operator must use monthly throughput records to
demonstrate compliance with the process limits contained in this permit and to calculate
emissions as described in this permit.
12. Points 002, 003, 004, 007: The owner or operator must operate a flame detection system
that monitors the pilot system of each control device for the presence of a flame on a
minimum of an hourly basis. If a flame is not detected within the control device FL-1810, the
facility will shut down such that the wells cannot produce to the facility until all pilot lights
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ICOLORADO
Air Pollution Control Division
Department of Pubic Health it Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
are again present. If a flame is not detected within the control device ft-1820, the vapor
flow from all separators covered by Point 007 at this facility must be routed to the control
device FL-1810.
13. Points 002, 003, 004, 007: At a minimum of an hourly basis, the owner or operator must
monitor the control devices for the presence of pilot lights. At a minimum of a weekly basis,
the owner or operator must monitor the control devices for the presence of operational auto-
igniters. These monitoring records shall be used to calculate downtime for each control
device. During periods without the presence of a pilot light and an operational auto-igniter
for either combustion device, the flow volume from all emissions sources controlled by each
device shall be recorded, and those flows which were directed to an unlit control device must
be assigned a 0% control efficiency. These monitoring records must be maintained for a
period of five (5) years, and a summary of monthly pilot light downtime and vapor flow during
pilot light downtime shall be provided to the division upon request.
STATE AND FEDERAL REGULATORY REQUIREMENTS
14. 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.)I.E.) (State only enforceable)
15. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
16. 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. (Regulation Number 1, Section II.A.1. Et 4.)
17. Points 002 & 003: This source is subject to Regulation Number 7, Part D, Section I. The
operator must comply with all applicable requirements of Section I and, specifically, must:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for storage tanks; and
• Ensure that the combustion device controlling emissions from this storage tank be
enclosed, have no visible emissions, and be designed so that an observer can, by means
of visual observation from the outside of the enclosed combustion device, or by other
means approved by the Division, determine whether it is operating properly. (Regulation
Number 7, Part D, Section I.C.) (State only enforceable)
18. Points 002 &t 003: 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 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.
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�•z- COLORADO
+ Air Pollution Control Division
Department of Puhllc Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
19. Points 002 Ft 003: The storage tanks covered by this permit are subject to the venting and
Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7,
Part D, Section II.C.2.
20. Points 002, 003, 007: The combustion device covered by this permit is subject to Regulation
Number 7, Part D, Section II.B.2. General Provisions (State only enforceable). If a flare or other
combustion device is used to control emissions of volatile organic compounds to comply with
Section II, it must be enclosed; have no visible emissions during normal operations, as defined
under Regulation Number 7, Part D, Section II.A.23; and be designed so that an observer can,
by means of visual observation from the outside of the enclosed flare or combustion device, or
by other convenient means approved by the Division, determine whether it is operating
properly. This flare must be equipped with an operational auto-igniter according to the
schedule in Regulation Number 7, Part D, Section II.B.2.d.
21. Point 004: 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.
22. Point 004: Storage tanks must operate without venting at all times during loadout. (Regulation
Number 7, Part D, Section II.C.5.a.(ii))
23. Point 004: The owner or operator must, as applicable (Regulation Number 7, Part D, Section
II.C.5.a.(iii)):
• 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.
24. Point 004: The owner or operator must perform the following observations and training
(Regulation Number 7, Part D, Section II.C.5.a.(iv)):
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C -.4.,x� COLORADO
•y �„/ Air Pollution Control Division
Department of Public Health&rnnronment
Dedicated to protecting and improving the health and environment of the people of Colorado
• 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.
25. Point 004: The owner or operator must retain the records required by Regulation Number 7,
Part D, Section II.C.5.a.(v) for at least two (2) years and make such records available to the
Division upon request.
• Records of the annual facility hydrocarbon liquids loadout to transport vehicles
throughput.
• Inspections, including a description of any problems found and their resolution, required
under Sections II.C.5.a.(iii) and II.C.5.a.(iv) must be documented in a log.
• Records of the infeasibility of observation of loadout.
• Records of the frequency of loadout.
• Records of the annual training program, including the date and names of persons
trained.
26. Point 004: 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))
27. Point 007: The separators and vapor recovery towers covered by this permit is subject to
Regulation 7, Part D, Section II.F. On or after August 1, 2014, gas coming off a separator,
produced during normal operation from any newly constructed, hydraulically fractured, or
recompleted oil and gas well, must either be routed to a gas gathering line or controlled from
the commencement of operation by air pollution control equipment that achieves an average
hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design
destruction efficiency of at least 98% for hydrocarbons.
28. 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
Page 7 of 20
122,y. ..eV:Z. 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
report must be in accordance with the general reporting requirements of Regulation Number 7,
Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or
operators must maintain the information according to Regulation Number 7, Part D, Section
V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V)
OPERATING & MAINTENANCE REQUIREMENTS
29. Upon startup of these points, the owner or operator must follow the most recent operating and
maintenance (O&M) plan and record keeping format approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to
the O&M 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
30. Point 002: The owner/operator must complete site specific sampling including a compositional
analysis of the pre-flash pressurized condensate routed to these storage tanks and, if necessary
for emission factor development, a sales oil analysis to determine RVP and API gravity. Testing
must be in accordance with the guidance contained in PS Memo 05-01. Results of testing must
be used to determine site-specific emissions factors for VOC and Hazardous Air Pollutants using
Division approved methods. Results of the Analysis must be used to demonstrate that the
emissions factor established through the Analysis are less than or equal to, the emission factor
submitted with the permit application and established herein in the "Notes to Permit Holder"
for this emissions point. If any site specific emissions factor developed through this Analysis is
greater than the emissions factor submitted with the permit application and established in the
"Notes to Permit Holder" the operator must submit to the Division within 60 days, or in a
timeframe as agreed to by the Division, a request for permit modification to address this/these
inaccuracy(ies).
31. Point 007: The owner/operator must complete an initial site specific extended gas analysis
("Analysis") within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the commingled gas vented from the Low
Pressure (LP) Separators and Vapor Recovery Towers (VRTs) covered by this permit in order to
verify the VOC content (weight fraction and molecular weight) of this emission stream.
Results of the Analysis must be used to calculate site-specific emission factors for the
pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved
methods. Results of the Analysis must be used to demonstrate that the emissions factor
established through the Analysis are less than or equal to, the emission factor submitted with
the permit application and established herein in the "Notes to Permit Holder" for this
emissions point. If any site specific emissions factor developed through this Analysis is greater
than the emissions factor submitted with the permit application and established in the "Notes
to Permit Holder" the operator must submit to the Division within 60 days, or in a timeframe
as agreed to by the Division, a request for permit modification to address this/these
inaccuracy(ies).
32. Points 002, 003, 007: The owner or operator must conduct initial source compliance tests of
the control devices FL-1810 and FL-1820 to measure the mass emission rates of the pollutants
listed below for each control device used, demonstrate compliance with the emissions limit in
Page 8 of 20
. COLORADO
410 4•41146" Air Pollution Control Division
�3�Jy Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
this permit for each source, and to demonstrate a minimum destruction efficiency of 98% for
volatile organic compounds (VOC) for each operating scenario. During the tests, the owner or
operator must measure:
• mass emission rates of VOC at the inlet of the control device (MI) using EPA or other
division approved methods;
• mass emission rates of VOC at the outlet of the control device (MO using EPA or other
division approved methods; and
• mass emission rates of NOx and CO at the outlet of the control device using EPA or
other division approved methods.
Additionally, the following parameters may be required to be measured during the tests:
• combustion chamber temperature;
• gas flow rate;
• supplemental fuel flow rate;
• gas heat content; and
• gas composition.
The destruction efficiency (DE)for VOC must be calculated for each control device using the
following equation:
DE (%) = 100*(M;-Mo)/M;
The test protocols, tests, and test reports must be in accordance with the requirements of
the Air Pollution Control Division Compliance Test Manual. The test protocols must include
testing under all operating scenarios at each control device. The test protocols must be
submitted to the Division for review and approval at least thirty (30) days prior to testing. No
compliance tests will be conducted without prior approval from the Division. Within thirty
(30) days following completion of the test(s), a compliance test report must be submitted to
the Division for review. Additional time may be granted upon written request. Any compliance
tests conducted to demonstrate compliance with a monthly or annual emission limitation shall
have the results projected up to the monthly or annual averaging time by multiplying the test
results by the Process Limit(s) for that averaging time as indicated in the Process Limitations
and Records section of this permit.
Results of the initial compliance tests must be submitted to the Division as part of the self-
certification and must demonstrate compliance with the emissions limits contained within this
permit. If the results of the initial compliance tests do not demonstrate compliance with the
emissions limits contained within this permit or do not demonstrate a minimum destruction
efficiency of 98% for Volatile Organic Compounds (VOC) for each operating scenario, the
owner or operator must submit to the Division within 60 days, or in a timeframe as agreed to
by the Division, a request for permit modification to address these inaccuracies. (Regulation
Number 3, Part B., Section III.G.3)
Periodic Testing Requirements
33. Point 007: On an annual basis, the owner/operator must complete a site specific extended
gas analysis ("Analysis") after commencement of operation or issuance of this permit,
whichever comes later, of the commingled gas vented from the Low Pressure (LP) Separators
and Vapor Recovery Towers (VRTs) covered by this permit to verify the VOC content (weight
- Page 9 of 20
C �r.Y•,x. ` COLORADO
•wtatf‘ Air Pollution Control Division
Department of Public Health is Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
fraction and molecular weight) of this emission stream. Results of the Analysis must be used
to calculate site-specific emission factors for the pollutants referenced in this permit (in units
of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis must be
used to demonstrate that the emissions factor established through the Analysis are less than
or equal to, the emission factor submitted with the permit application and established herein
in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor
developed through this Analysis is greater than the emissions factor submitted with the
permit application and established in the "Notes to Permit Holder" the operator must submit
to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for
permit modification to address this/these inaccuracy(ies).
34. Points 002, 003, 007: On an annual basis, the owner or operator must conduct periodic source
compliance tests of the control devices FL-1810 and FL-1820 to measure the mass emission
rates of the pollutants listed below for each control device used, demonstrate compliance with
the emissions limit in this permit for each source, and to demonstrate a minimum destruction
efficiency of 98%for volatile organic compounds (VOC) for each operating scenario. During the
tests, the owner or operator must measure:
• mass emission rates of VOC at the inlet of the control device (W) using EPA or other
division approved methods;
• mass emission rates of VOC at the outlet of the control device (MO using EPA or other
division approved methods; and
• mass emission rates of NOx and CO at the outlet of the control device using EPA or
other division approved methods.
Additionally, the following parameters may be required to be measured during the tests:
• combustion chamber temperature;
• gas flow rate;
• supplemental fuel flow rate;
• gas heat content; and
• gas composition.
The destruction efficiency (DE) for VOC must be calculated for each control device using the
following equation:
DE (%) = 100*(M1-Mo)/M1
The test protocols, tests, and test reports must be in accordance with the requirements of
the Air Pollution Control Division Compliance Test Manual. The test protocols must include
testing under all operating scenarios at each control device. The test protocols must be
submitted to the Division for review and approval at least thirty (30) days prior to testing. No
compliance tests will be conducted without prior approval from the Division. Within thirty
(30) days following completion of the test(s), a compliance test report must be submitted to
the Division for review. Additional time may be granted upon written request. Any compliance
tests conducted to demonstrate compliance with a monthly or annual emission limitation shall
have the results projected up to the monthly or annual averaging time by multiplying the test
results by the Process Limit(s) for that averaging time as indicated in the Process Limitations
and Records section of this permit.
Page 10 of 20
CM
�r�:�z COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Records of the annual compliance tests must be maintained by the owner or operator and
made available to the Division for inspection upon request. If the results of the periodic tests
do not demonstrate compliance with the emissions limits contained within this permit or do
not demonstrate a minimum destruction efficiency of 98% for Volatile Organic Compounds
(VOC) for each operating scenario, the owner or operator must submit to the Division within
60 days, or in a timeframe as agreed to by the Division, a request for permit modification to
address these inaccuracies. (Regulation Number 3, Part B., Section III.G.3)
ALTERNATIVE OPERATING SCENARIOS
35. Points 002, 003, 007: The control device may be replaced with a like-kind control device 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 control
device shall be the same make and model as authorized in this permit. All control device
replacements installed and operated as authorized by this permit must comply with all terms
and conditions of this construction permit. The owner or operator shall maintain a log on-site
or at a local field office to record the start and stop dates of any control device replacement,
the manufacturer, model number and serial number of the replacement control device.
36. Points 002,003, 007: An Air Pollutant Emissions Notice (APEN) that includes the specific
manufacturer, model, and serial number of the replacement control device must be filed with
the Division within 14 calendar days of commencing operation of a replacement control
device under the Alternative Operating Scenario provision. The APEN must be accompanied by
the appropriate APEN filing fee and a cover letter explaining that the owner or operator is
exercising an Alternative Operating Scenario and has replaced the control device.
37. Points 002, 003, 007: Within one hundred and eighty days (180) of startup of the replacement
control device in accordance with the Alternate Operating Scenario provision, the owner or
operator must conduct an initial source compliance test of the replacement control device to
measure the mass emission rates of the pollutants listed below for each replacement control
device used, demonstrate compliance with the emissions limits contained in this permit for
each source, and to demonstrate a minimum destruction efficiency of 98% for volatile organic
compounds (VOC) for each operating scenario. During the test, the owner or operator must
measure:
• mass emission rates of VOC at the inlet of the control device (M;) using EPA or other
division approved methods;
• mass emission rates of VOC at the outlet of the control device (M0) using EPA or other
division approved methods; and
• mass emission rates of NOx and CO at the outlet of the control device using EPA or
other division approved methods.
Additionally, the following parameters may be required to be measured during the test:
• combustion chamber temperature;
• gas flow rate;
• supplemental fuel flow rate;
• gas heat content; and
Page 11 of 20
C ......,::s. COLORADO
•M Air Pollution Control Division
tig� Department of Publac Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• gas composition.
The destruction efficiency (DE) for VOC must be calculated using the following equation:
DE (%) = 100*(MI-Mo)/MI
The test protocol, test, and test report must be in accordance with the requirements of the
Air Pollution Control Division Compliance Test Manual. The test protocol must include testing
under all operating scenarios at each control device. The test protocol must be submitted to
the Division for review and approval at least thirty (30) days prior to testing. No compliance
test will be conducted without prior approval from the Division. Within thirty (30) days
following completion of the test(s), a compliance test report must be submitted to the
Division for review. Additional time may be granted upon written request. Any compliance
test conducted to demonstrate compliance with an annual emission limitation shall have the
results projected up to the annual averaging time by multiplying the test results by the
Process Limit(s) for that averaging time as indicated ins the Process Limitations and Records
section of this permit.
Records of the compliance tests must be maintained by the owner or operator and made
available to the Division for inspection upon request. If the results of the compliance tests do
not demonstrate compliance with the emissions limits contained within this permit or do not ,
demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC) for
each operating scenario, the owner or operator must submit to the Division within 60 days, or
in a timeframe as agreed to by the Division, a request for permit modification to address these
inaccuracies. (Regulation Number 3, Part B., Section III.G.3)
38. 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.
39. 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.
40. 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
41. All previous versions of this permit are cancelled upon the Division's receipt of the NOS form(s)
required by Condition 1 of this permit Issuance 5.
Page 12 of 20
C ��,� COLORADO
+4 Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
42. Point 004: This permit replaces the following permits and/or points, which are cancelled upon
the Division's receipt of the NOS form(s) required by Condition 1 of this permit Issuance 5. The
owner or operator must submit a cancellation notice for the following equipment with the
Notice of Startup for the corresponding new equipment in this permit.
Existing Permit Number Existing Emission Point New Emission Point
GP07 123/9BDF/004 123/9BDF/004
43. 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 NOX per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on the
last APEN submitted; or
For any non-criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or activity;
or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
44. 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).
GENERAL TERMS AND CONDITIONS
45. 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
Page 13 of 20
•r.*:r- COLORADO
0 v W Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
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.
46. If this permit specifically states that final authorization has been granted, then the remainder
of this condition is not applicable. Otherwise, the issuance of this construction permit does not
provide "final" authority for this activity or operation of this source. Final authorization of the
permit must be secured from the APCD in writing in accordance with the provisions of 25-7-
114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization
cannot be granted until the operation or activity commences and has been verified by the APCD
as conforming in all respects with the conditions of the permit. Once self-certification of all
points has been reviewed and approved by the Division, it will provide written documentation
of such final authorization. Details for obtaining final authorization to operate are located
in the Requirements to Self-Certify for Final Authorization section of this permit.
47. 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.
48. 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.
49. 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.
50. 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.
51. 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.
Page 14 of 20
C COLORADO
Air Pollution Control Division
ii Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
By: DRAFT
Ben Fischbach
Permit Engineer
Permit History
Issuance Date Description
Issuance 1 July 21, 2014 Issued to Bonanza Creek Energy Operating
Company, LLC
Issuance 2 June 16, 2105 Modification to change flow rates, remove point
018, and add point 019
Issuance 3 May 31, 2016 Issued to Bonanza Creek Energy Operating
Company, LLC
Modification to consolidate vapor recovery
towers (point 019) and low pressure separators
(point 007) into single emission point (007).
Update throughput and emission factors for
point 007 to account for removal of VRUs.
Decrease permitted throughput and emission
limits for points 002-004.
Removed point 005 which source requested to
cancel (cancellation notice received
08/10/2015).
Removed point 006 which source requested to
cancel (cancellation request received
02/11/2016).
Issuance 4 December 13, Issued to Bonanza Creek Energy Operating
2016 Company, LLC.
Increased emission and throughput limits for
points 002, 003, 004, and 007. Updated
emission factors for points 002 and 007. Point
008 not changed. Issued as Final Approval
Issuance 5 This Issuance Updated throughput and emission limits based
on addition of new wells.
98% control claimed for points 002, 003, 004,
and 007.
Operator will continue to operate under
Issuance 4 of this permit until Condition 1 of this
issuance is met.
Page 15 of 20
C -r�:� COLORADO
.dtro Air Pollution Control Division
Department of Public Health Er Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder must pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit.
(Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator must notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written
notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions
Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-reps
4) The following emissions of non-criteria reportable air pollutants are estimated based upon the
process limits as indicated in this permit. This information is listed to inform the operator of the
Division's analysis of the specific compounds emitted if the source(s) operate at the permitted
limitations.
AIRS Uncontrolled Controlled
Point Pollutant CAS # Emissions Emissions
(lb/yr) (lb/yr)
Benzene 71432 6,041 121
Toluene 108883 5,430 109
Ethylbenzene 100414 397 8
002 Xylenes 1330207 1,877 38
n-Hexane 110543 50,341 1,007
2,2,4-
540841 45 1
Trimethylpentane
Benzene 71432 4,090 82
003
n-Hexane 110543 12,850 257
Benzene 71432 486 10
004
n-Hexane 110543 4,218 84
Benzene 71432 3,536 71
Toluene 108883 3,325 66
007
Ethylbenzene 100414 304 6
Xylenes 1330207 1,235 25
Page 16 of 20
���.;� COLORADO
lit 4 4 Air Pollution Control Division
-� Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
n-Hexane 110543 31,309 626
2,2,4-
540841 18 0
Trimethylpentane
Benzene 71432 213 11
Toluene 108883 158 8
008 Ethylbenzene 100414 18 1
Xylenes 1330207 62 3
n-Hexane 110543 1,255 63
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 002:
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
NOx 1.88 * 10"3 1.88 * 10"3 AP 42
CO 8.56 * 10"3 8.56 * 10"3
VOC 1.446 2.892 * 10"2
71432 Benzene 5.17 * 10-3 1.03 * 10-4
108883 Toluene 4.65 * 10-3 9.30 * 10-5
100414 Ethylbenzene 3.40 * 10-4 6.80 * 10-6 Promax
1330207 Xylene 1.61 *10-3 3.21 * 10"5
110543 n-Hexane 4.31 * 10-2 8.62 * 10"4
540841 2'2'4 3.87 * 10-5 7.73 * 10-'
Trimethylpentane
Note: The controlled emissions factors for this point are based on a control efficiency of 98%. NOx and CO emission
factors are based on a gas heat content of 2,815 Btu/scf.
Actual controlled emissions shall be calculated using the following method:
Monthly Actual Emissions= [(V total—VPLX) X EF x (100%—CE)]+[VPLX x EF]
where:
Moral =Total volume of condensate throughput during the month (bbl)
VPLX =Total volume of condensate throughput while pilot light was not lit
during the same month (bbl)
EF =Most recent approved emission factor(lb/bbl)
CE = Permitted control efficiency greater than 95%
Page 17 of 20
COLORADO
Air Pollution Control Division
C4 A° 111W1 Department of Pubkic Health Er Envwronment
Dedicated to protecting and improving the health and environment of the people of Colorado
Point 003:
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/bbl lb/bbl
NOx 0.0037 0.0037 AP 42
CO 0.0167 0.0167
VOC 0.262 5.24 * 10"3
71432 Benzene 0.007 1.40 * 10-4 CDPHE
110543 n-Hexane 0.022 4.40 * 10"4
Note: The controlled emissions factors for this point are based on a control efficiency of 98%. NOx and CO emission
factors are based on a gas heat content of 1,496 Btu/scf.
Actual controlled emissions shall be calculated using the following method:
Monthly Actual Emissions= [(Vtotal—VPLX) X EF x (100%-CE)]+[VPLx x EF]
where:
Vrotat =Total volume of produced water throughput during the month (bbl)
VPLX =Total volume of produced water throughput while pilot light was not
lit during the same month (bbl)
EF =Most recent approved emission factor (lb/bbl)
CE = Permitted control efficiency greater than 95%
Point 004:
Uncontrolled Controlled
Pollutant CAS # Emission Factors Emission Factors Source
lb/bbl lb/bbl
NOx 3.77 * 10"4 3.77 * 10"4
AP-42
CO 1.44 * 10"3 1.44 * 10-3
VOC 0.236 4.72 * 10"3
Benzene 71432 4.10 * 10"4 8.20 * 10"6 CDPHE
n-Hexane 110543 3.60 * 10-3 7.20 * 10"5
Note: The controlled emissions factors for this point are based on a control efficiency of 98%. NOx and CO emission
factors are based on a gas heat content of 3,095 Btu/scf.
Actual controlled emissions shall be calculated using the following method:
Monthly Actual Emissions= [(V total—VPLX) X EF x (100%-CE)]+ [VPLX x EF
where:
Vtotai =Total volume of condensate loaded out from storage tanks during
the month (bbl)
VPLX =Total volume of condensate loaded out from storage tanks while
pilot light was not lit during the same month (bbl)
Page 18 of 20
Cr COLORADO
��ii Air Pollution Control Division
�iie' Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
EF =Most recent approved emission factor(lb/bbl)
CE = Permitted control efficiency greater than 95%
Point 007:
Uncontrolled Controlled
CAS # Pollutant Emission Factors Emission Factors Source
lb/MMscf lb/MMscf
NOx 172.78 172.78 AP 42
CO 787.46 787.46
VOC 90,306.85 1,806.14
71432 Benzene 270.35 5.41
108883 Toluene 254.185 5.08
100414 Ethylbenzene 23.25 0.47 Extended Gas
1330207 Xylene 94.40 1.89 Analysis
110543 n-Hexane 2393.665 47.87
540841 2, 1.38 1.38 0.03
Trimethylpentane
Note: The controlled emissions factors for this point are based on a control efficiency of 98%. NOx and CO emission
factors are based on a gas heat content of 2,480 Btu/scf.
Actual controlled emissions shall be calculated using the following method:
Monthly Actual Emissions= [(V total—VPLX)X EF x(100%—CE)] +[VPLX x EF]
where:
Vroml =Total volume of gas from the emission source sent to
control device during the month (scf)
VPLX =Total volume of gas from the emission source sent to control
device while pilot light was not lit (scf)
EF =Most recent approved emission factor for gas venting(lb/scf)
CE = Permitted control efficiency greater than 95%
Point 008:
Uncontrolled Controlled
CAS # Pollutant Emissions Emission Factors Emission Source
Factor Unit Factors
NOx lb/MMBtu 0.068 0.068 AP 42
CO lb/MMBtu ' 0.37 0.37
VOC lb/MMscf 16,985.6 849.3
71432 Benzene lb/MMscf 0.07 3.5 * 10-3
108883 Toluene lb/MMscf 0.05 2.5 * 10-3 Eng Calc
1330207 Xylene lb/MMscf 0.02 1.0 * 10-3
110543 n-Hexane lb/MMscf 0.39 2.0 * 10-2
Note: The controlled emissions factors for this point are based on a control efficiency of 95%.
Page 19 of 20
r: COLORADO
Air Pollution Control Division
Department of Public Health&Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A
revised APEN must be submitted no later than 30 days before the five-year term expires. Please
refer to the most recent annual fee invoice to determine the APEN expiration date for each
emissions point associated with this permit. For any questions regarding a specific expiration date
call the Division at (303)-692-3150.
7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated
control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when
applicable.
8) This facility is classified as follows:
Applicable Status
Requirement
Operating Permit Synthetic Minor Source of: VOC, n-Hexane, Total HAPs
PSD Synthetic Minor Source of: VOC
NANSR Synthetic Minor Source of: VOC
MACT HH 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.qov/
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 20 of 20
1
Project Details For Division Use Only
Review Engineer: Ben Fischbach
Package#: 429049
Received Date: 4/21/2020-r-
Review Start Date: 5/13/2020 .,
Section 01-Facility Information
Company Name: Bonanza Creek Energy Operating Company,LLC Quadrant Section Township Range
County AIRS ID: .123 SERE- S- 36N-': ," 63
Plant AIRS ID: 96DF
Facility Name: State North Platte-T-36 Production Facility(COGCC#433300)
Physical
Address/Location: 1 ii.SE .,�zca= - -e >_
County: 'Weld County
Type of Facility: E f
What industry segment?7e[& atrXra4fi*f'ndrj'c£(#fr-*ka2�'ii 'r�zz
Is this facility located in a NAAQS non-attainment area? '.1 Yes"," �
If yes,for what pollutant? Ozone(Nips,„
Section 02-Emissions Units In Permit Application
Leave Blank-For Division Use Only
AIRS Point# Permit
Emissions (Leave blank unless Issuance Self Cert Action Engineering
(Leave blank unless APCD Emissions Source Type Equipment Name
Control? APCD has already # Required? Remarks
has already assigned)
assigned)
002 Storage tank - =CNDTIC-01 -. , Yes: _ 14WE0187 - 5- Yes` :< Modification
003 _ Storage Tanfc _ -PWT-01. " Yet -14WE01B7: S Yes- Modification
Previously on a
-
. Perm
004 - Liquid Loading -- L-01 Yes ,-_ 14NA/E0137 5 Yes Modification
:_007 SeparatorVenting ;. LPGFL - Yes ' - - 14WE0187= 5 _ -•Yes- Modification
Section 03-Description of Project
Applicant proposes permit modification to points 002,003,and 007 based on a new throughput due to the addition of new wells.Applicant is also applying for a
new synthetic minor permit based on the reduced threshold after the DMVINFR NAA"redesignation`(1/27/2020),and this project will therefore require a public
comment period.
Sections 04,05&06-For Division Use Only
Section 04-Public Comment Requirements
Is Public Comment Required? - Yes
If yes,why? Requesting Synthetic Minor Permit
Section 05-Ambient Air Impact Analysis Requirement
Was a quantitative modeling analysis required? No`=
If yes,for what pollutants?
If yes,attach a copy of Technical Services Unit modeling results summary.
Section 06-Facility-Wide Stationary Source Classification
Is this stationary source a true minor? Nut
Is this stationary source a synthetic minor?
If yes,indicate programs and which pollutants: SO2 NOOo CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(P5D) ,d
Title V Operating Permits(OP) _ i / Li LJ
Non-Attainment New Source Review(NANSR) J
Is this stationary source a major source? No _
If yes,indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration(PSD) H _ [111ITitle V Operating Permits(OP)
Non-Attainment New Source Review(NAN5R)
Storage TaflE(s)Emissions in,yentory
Section 01-Administrative Information
Facility A1Rs ID: 429 ROOF <002
County Plant Point
Section 02-Equipment Description Details
Storage Tank Liquid -,',"r
Detailed Emissions Unit Sixteen(16)500 bbl fixed roof tanks used for storage of condensate.Description: _.
Emission Control Device FCC! L,,'x ' '
Description:
Requested Overall VOC&HAP Control Efficiency A:
Limited Process Parameter •...
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Storage Tank(s)
Actual Throughput- 973,333,0 Barrels(bbl)per year
'Requested Permit Limit Throughput= 1,168,0000.Barrels(bbl)per year Requested Monthly Throughput= COL: Barrels(bbl)per month
Potential to Emit(PTE)Condensate Throughput= 1,168,000.0 Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)
Heat content of waste gas= 2815.0 Btu/scf
Volume of waste gas emitted per BBL of liquid's
produced= 9.7 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= ...-.-.t MMBTU per year
Potential to Emit(PTE)heat content of waste gas routed to combustion device= 1... MMBTU per year
Control Device
Pilot Fuel Use Rate: •1f&8:scfh • MMscf/yr
Pilot Fuel Gas Heating Value: . 2815:--Btu/scf .,.i MMBTU/yr
Section 04-Emissions Factors&Methodologies
Will this storage tank emit flash emissions? 5.1424Natt
Emission Factors Condensate Tank
Uncontrolled Controlled
Pollutant (lb/Nap (lb/bbl) Emission Factor Source
(Condensate (Condensate
Throughput) Throughput)
VOC 1.4460 „ 2 391211 i't—,'.tY^ `
Benzene 5.17E-001:33-E-00 IV..4
Toluene 4.6SE03 9.3C€]�
Ethylbenzene 3.40E-04 .,Cr
Xylene 1.61E-03 _ 2 ri.-
n-Hexane 4.31E-02 ,5
224 TMP
Control Device
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source
(waste heat (Condensate
combusted) Throughput)
PM10 - - tF F,t ar
PM2.5 tCt y�f)*
SOx _ 4 3
NOx 0-0680 ,Stei yt�®#.
CO 08100 .,'-_ '.,F --.,' ..- ,.w< a
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (Ib/MUBtu) (lb/MMscf) Emission Factor Source
(Pilot Gas Heat (Pilot Gas
Combusted) Throughput)
PM10 LI. `r;-.: 42;,,t7
PM2.5 Ott
SOx
P100 0,0080 .., „l-: - _, .a •.
VOC
CO 0.3100 `; O.F .0.5 1_'+.-ia Ffa`,1Q »,
2 of 17 K:\PA\2014\14WE0187.CP5
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) (tone/year) (lbs/month)
PM10
PM2.5 ., ,.. Overall Combustion Factors
500
NOB --, 1 .--. _.- 1.88E-03 lb/bbl
VOC _ --_
CO >,. .+ - s0 ,.a. 8.56E-03 lb/bbl
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/year)
Benzene
Toluene .u. - ... - ,,
Ethylbenzene , ..
Xylene ...- _• -.
n-Hexane _.,.,.
224TMP
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B
Regulation 7,Part D,Sectlon I.C,D,E,F
Regulation 7,Part U,Section I.G,C ., ....,.., .. _ .,
Regulation 7,Part D,Section II.B,C.l,C.3
Regulation 7,Part Election II.C.2
Regulation 7,Part D,Section ll.C,4.a.(i) - -- •^'0-'., _ '> _
Regulation 7,Part Election II.C.4.a.(ii)
Regulation 6,Part A,NSPS Subpart Kb ..... ,. - .,
Regulation 6,Part A,NSPS Subpart 0000
NSPS Subpart 00000
Regulation 8,Part E,MACF Subpart Flu
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial and Periodic Sampling and Testing Requirements
For condensate or crude oil tanks,does the company use the state default emissions factors to
estimate emissions?
If yes,are the uncontrolled actual or requested emissions fora crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the
uncontrolled actual or requested emissions fora 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?
If yes and if there are flash emissions,.are the emissions factors based on a pressurized liquid sample drawn at the facility being
permitted(for produced watertanks,a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample
should be considered representative which generally means site-specific and collected within one year of the application received,
date,However,if the facility has not been modified(e.g.,no new wells brought on-line),then it may be appropriate to use en
alder site-specific sample.
If no,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company request a control device efficiency greater than 95%for a flare or combustion device? r
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Manse 20-02
Section 08 Technical Analysis Notes
SSEFs are based on a Promax model of the process,which itself is based one pressurized liquidsample collected at the Wetco Farms A-4 facility,unit ID F4-9MRLNB,The sample was.collected at pressure of 63,1 prig
and a temp of 100F on 10/8/2019,and was analyzed 10/9/2019,Asthis isa representative sample,this permit will require an intial sample of the pressurized liquid routed tuthe VRT atth(sfatility to demnnstratethat
the emission factors from this first rssuance.are not exceeded,
Section 09.-SCC Coding and Emissions Factors(For Inventory Use Only(
Uncontrolled
Emissions
AIRS Point# Process# SCC Code Pollutant Factor Control% Units
01 1 !31 PM10 lb/1,000 gallons Condensate throughput
PM2.5 - lb/1,000 gallons Condensate throughput
Sox - _ .• lb/1,000 gallons Condensate throughput
NOx • lb/1,000 gallons Condensate throughput
VOC • lb/1,000 gallons Condensate throughput
CO - lb/1,000 gallons Condensate throughput
Benzene • lb/1,000 gallons Condensate throughput
Toluene .. -. lb/1,000 gallons Condensate throughput
Ethylbenzene Ih/1,000 gallons Condensate throughput
Xylene -. lb/1,000 gallons Condensate throughput
n-Hexane lb/1,000 gallons Condensate throughput
224 TMP . lb/1;000 gallons Condensate throughput
•
3 of 17 K:\PA\2014\14WE0187.CP5
•
Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below ore determined based on requested emissions.
Colorado Re:lotion 3 Parts A and B-APES end Permit Requirements
1 otirreisinueSlonsfosa:r,unn_gam
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from thls individual source greater than 7.TPY(Regulation 3,Part A,Senior lLD.1.a)? Source Requires an APES.Go to
2. Is theconstruction 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 guidance on grandfather applicability)? Go to next question
3. Are total facility uncontrolled VOC embslons greater than S TPY,NOx greater than 10 TPY or CO emissions greater than 10 Tint(Regulation 3,Partg,Section 11.03)? Source Requires a permit
NON-ATTAINMENT •
1. Are uncontrolled emissions fro many criteria pollutants from this lndw dual source greater than 1 TPV(Regulation 3,Part A,Section II.D.S.a)? Yes.....,n Source Requites an OPEN.Gam
�3:
2.. sthe construction date(service date)prior to 12/30/2002 and net modified after 12/31/2002(See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? No.,.,y...n"g-,,='Go to next question
3. Aretotal facilty.uncontrolled VOC emissions greater than 2 TPY,NOR greater than 5 TPY or CO emissions greater than lO Tpy(Regulation 3,Part 4l,Section 11.0.2)? y4i.maSource Requires a permit
'Source requires e&mks
Colorado Regulation 7,Pert 0,Section I.C-F&G
1. Is thlsstorage tank located in thee-hr ozone control area or any ozone non-attainment area or attainment/maintenance area(Regulation 7,Part D,Section I.A.1)? fit, Continue-you have indicated th
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 gas processing plant(Regulation 7,Part D,Section l.A.1)? Mast Continue-You have Indicated th
3. Isthis storage tank located at a natural gas processing plant(Regulation 7,Part D.Section 1.51? -a:. Storage Tank is not subject to Re
4. Does this storage tank contain condensate? -.
5. Does this storagetank exhibit"Flash"leg...rag non-stabilized liquids)emissioes(Regulation 7,part 0,section 1.0.217 -.
6 Are uncontrolled actual emissions&this storagetank equal to or greater than Alone per year VOC(Regulation?,Part D,Section l.03.a(ii))7 Yes
o
Part°,section 1,0.1—General Requirements for Air Pollution Control Equipment—Prevention of Leakage
Part 0,Section 1.0.2—Emission etimationProcedures
Part D,Section I.D—Emissions Control Requirements
Part 0,Section LE—Monitoring
Part O,Section I.F—Recordkeope,g and Reporting
Porto,Section 1.0.2-Emissions Control Requirements
Part D,Section I.C.1.a and b—General Requirements for Air Pollution Control Equipment—Prevention of Leakage
Colorado Regulation?,Parts,Section II
1. Is this storage tank located at atransmission/storage facility? Continue-you have indicated th
2. Is this storage tank'located at en oil and gas exploration and production operation,well production feeilityz,natural gaz compressor stations or natural gas processing plant`IRegulatlon 7,Part 0,Section ILO? Go to the next question-You ka
3. Does this storage tank have a fixed roof(Regulation 7,Part 0,Section ll.A.20)? Yes'• Go to the next question
4 Are uncontrolled actual emissions ofth t ag tank equrt to or greater than 2Yons per year VDC(Regulallon 7,Part D,Section 11.0.1.07 Yes Source Is subject to parts of no
Part e,Section 11.0-General Provisions for Air Pollution Control Equipment anddPrevention of Emissions
Part 0,Section li.C.l I:rnl.ssinnlCvntral and Monitoring Provisions
Pant),Section 11.0.3-Recnrdkeeping Requirements
S. Does thestorage tank contain only"stabilised"liquids(Regulation 7,Part D,Section 11.0.2.117 No _(:'Source Is subject to allprovsim
Part D,Section II.C.2-Cap,urn and Monitoring for Storage ranks fined with Air Pollution Control Equipment
Isthe controlled storage tank located at a well production facility. -ural gas compressor station,or natural gas proceszng plant constructed on or after May 1,2020 or located at a facility that was modified on or after May 1,2020,such
6. that an additional controlled storage vessel s constructed to receive an anticipated increase n throughput of hydrocarbon liquids or produced water(Regulation 7,Part D,5ection ll.L.4.a.(i)? No Storage Tank is not subject to Re
is Me controlled storage tanklocated at a wellproduction facility,natural gas compressor station,or natural gas processing plant constructed poor after lanuary12021.or I cated at a facility that was modified on or after January 1,
7 2021such that an additional controlled storage vessel Is COnStrllietedt anticipated increase In throughput of hydrocarbon lquids or produced water(Regulation 7,Part 0,Section 11.0.4.a.00?
40 CFR,Part60,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(ms)1-4?28BLsl(40 CFR 60.110b(a))? Yes- Oslo the next question
2. Does the storage vessel meet the following exemption in 60.111b(d)(4)7 Yes Storage Tank Is not subject NSPS
a.Doesthe vessel has a design capacity less than or equal to 1,589.874 m°1-10,000 BBL)used for petroleum'or condensatestored,processed,or treated prior to custody transfer'as defined in 00.111b?
3. Was this storage vessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after July 23,1984(40 CFRfio.11ot(a))?
4. Does the tank meet the definition of"storage vessel"'In 50.1111?
5. Does the storage vessel store a"volatile organic liquid(VOL)"'as defined in 60.1115?
6. Does the storage vessel meet any one ofthe100owingaddoionai exemptions:
a.Isthe storage vessel a pressure vessel designed to operate in excess of 204.9 kPa 1-29.7 psi)and without emssions to the atmosphere(60.110b(d)(2))?;or
b.The design capacity 3 greater than or equal to 151 ma 1-950 BBL)and stores a liquid with a maximum true vapor pressure'less than 05 kPa(60.11ob(b))?;or
c.The design capacity Is greater than or equal to 75 Mt 1-472 BBL]but less than 151 ms(`950 BBL)and stores a liquid with a maximum true vapor pressure'less than 15.0 kPa(60.1.10b(b)l? ..
7. Doesthe storage tank meet either one of the following exemptions from control requirements:
a.The design capacity Is greater than or equal to 151 ms(-950 BBL)and stores a liquid with'inax imam true vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa?;or
b.The design capacity is greater than or equal to 75 he["4?2 BBL)but less than 151 ms 1-950 BBL)and stores a liquid with a maximum Cue vapor pressure greater than or equal to 15.0 kPa but less than 27.6 bra?
40 CFR,Part60,Subpart0000/0000a,Standards of Performance far Crude Oil and Natural Gas Production,Transmission and OfaVibution
1. Is this storage vessel located at afacility in the onshore oil and natural gas production segment,natural gas processing segment or natural gas transmission and storage segment of the Industry? ns Continue-You have Indicated tit
2 Was this storage vessel constructed reconstructed,or modified(see definitions 40 CFR,60.2)between August 23,2011 and September 18,2015? No-r,`-,'. &Storage Tank is net subject NSPS
3, Was this storage vessel constructed,reconstructed,or modified(see deflnitions 40 CFR,6021 after September 18,2015? y 7.10 yit7.10 Go to the next question
4. Are potential VOC emissions1 freer the individual storage vessel greater than or equal to 6tons per year? N t's'„a'Storage Tanks not subject NSPS
5 Does tiffs storage vessel meet the definition of"storage vessel'per 60.5430/60.5430a?
6 sthe storage v ubject to and controlledi accordance with requirements for storage vessels in 40CFR Part 60 Subpart Kb en 40CFR Part 63 Subpart HH7
sooirtt
[Note:If a storage vessel is previously determined to be subject to NSPS 0000/0000a due to emissions above 6 eons per year VOC on the applicability determination date,It should remain subject to NIPS 0000/0000e per
60.5365(e)l2)/60.536SaIe)(2)even If potential VOC emissions drop below 6 tons per yearl
40 CFR,Part 63,Subpart MALT HH,Oil and Gas Production Facilities
1. sthe storage tank boated at an oil and natural gas production facility that meets either of the following criteria: I-eu (Condone-You have indicated th
a.A facility that processes,upgrades or stores hydrocarbon liquids'(63.760(')(2));OR
b.Afaciliy that processes,upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user'(63.760la)(3)1?
2. sthe tank located at a facility that is major'for HAPs7 No --Storage Tank's not subject MAC
3. Doesthetank meet the definition of"storage vessel"a in 63.761?
4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"'per 63.76(?
5 Is the tank subject t ntrol requirements under 40 CFR Part 60 Subpart Kb or Subpart 0000? '.
Subpart A,General Wnvisions per§63.764(a)Table 2
§63.756-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 RACE requirements.
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act its implementing regulations,and Air Quality Control Commission regulations.This document is not
role or regulation.and the analysis it contains may not apply to a particular situation based upon the individual facts end circumstances.This document does not change or substitute for any law,regulation.
or any other legally binding requirement and is not legally enforceable.In the event of any conflict between the language sit this document end the language of the Clean AM Act„its implementing regulations,
and Air Quality Control Commission regulations.the language of the statute or regulation will control.The use ofnon-mandatory language such as"recommend,""may,""should,"and"cen,"is intended to
describe APCO interpretations and recommendations.Mandatory terminology such as"must"end"required"are intended to describe controlling requirements under the terms of the Clean Air Act and Air
Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself.
Sts:age ant' s A=i}I}ai Sif)[i Y'>r >Ci
Section 01-Administrative Information
!Facility AlRs ID:
County Plant Point
Section a2-Equipment Description Details
Storage Tank Liquid -tiy °i, y
Detailed Emissions Unit Four L456QbLii liked roof T ksn 3fodstorag xrf P[drkced ilPater`` `'
Emission Control Device Ed7
Description: ... ..`j. ...
Requested Overall VOC&HAP Control Efficiency A: '98,O�
Limited Process Parameter
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Storage Twirls)
Actual Throughput= 486,6670 Barrels(bbl)per year
!Requested Permit Limit Throughput= 584,0010 Barrels(bbl)per year Requested Monthly Throughput= .,_6•n.„ Barrel(bbl)per month
Potential to Emit(PIE)Condensate Throughput= 584,001.0 Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)
Heat content of waste gas= 1496.0 Btu/scf
Volume of waste gas emitted per BBL of liquids
produced= -36.0 scf/bbl
Actual heat content of waste gas routed to combustion device= z,___.5 MMBTU per year
Requested heat content of waste gas routed to combustion device= 3 MMBTU per year
Potential to Emit(PIE)heat conhent of waste gas routed to combustion device= > MMBTU per year
Control Device
Pilot Fuel Use Rate: 1.5 MMscf/yr
,Pilot Fuel Gas Heating Value: .';--Btu/scf ...J MMBTU/yr
Section 04-Emissions Factors&Methodologies
Will this storage tank emit flash emissions?
Produced Water Tank
Uncontrolled Controlled
Pollutant (Ib/hhl) (Ih/bhl( Emission Factor Source
(Produced Water (Produced Water
Throughput) Throughput)
f'e3^fi4At fi
MOBEZ
Control Device
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) (lb/bbl) Emission Factor Source
(waste heat (Produced Water
combusted) Throughput)
s
pk I
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) (Ib/MMscf) Emission Factor Source
(Pilot Gas Heat (Pilot Gas
Combusted) Throughput)
r,..^°s a.,.
5 of 17 K:\PA\2014\14WE0 87.CP5
Star ag Tank(si Em:ssiun,)nf.'ntory
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) (Ibs/month)
PM10 0.'t 0 0 (C .:03
PM2.5 _.. .. .. :.
SOX ., ...03 .. ,. 01.
Noe .- _. ._ , r
VOC , _ 5030 _ Li
CO 4.- 4.0 1,
Potential to Emit Actual Emissions Requested Permit Omits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(Ibs/year) (Ibs/year) (lbs/year) (lbs/year) (Ibs/year) Operator calculated actual uncontrolled:
Benzene 18088 042., 08
Toluene 0.,
Ethylbenzene ,.
Xylene U C.,0 :'.1 _
n-Hexane 1.:0080 3270.. 211_
224TMP 80 7, . .
Section 06-Regulatory Summary Analysis
Regulation 3,Parts A,B :2222.
Regulation 7,Part D,Section I.C,D,E,F _0. 2:27::,s 't to
Regulation 7,Part D,Sectlon I.G,C 0" ta. atto,,t:r try.ia,0•. 3,a.ana,.,
Regulation 7,Part D,Sectlon II.B,0.1,C.3 30:0:3000:0.:00,00,0 to 4=v a.:.., U.,... _. ... _22 a
Regulation 7,Part 0,5ection II.C.2 a,_ 000.=,0.ubiert to ang:.lat.:n!n_:T 0 0,.,O,.-,','3'_
Regulation 7,Part D,Section II.C.4.a.(i) 3322—o -_ ..Ir;%'a;,:,,/20-;, ,,
Regulation 7,Part D,Sectlon ll.C.4.a.(ii) _-.._ 0 5on,,,:sct;ent+0rg.:'0.::"Or'- -- .. _
Regulation 6,Part A,N5PS Subpart Kb
Regulation 6,Part A,NSPS Subpart 0000 ^:..:agr:.a'. +:t e.n•''...'.:..C:;ti
N5P55ubpart 0000a 00.00,0 2,0.:.rutc .._ ,::',,03,
Regulation B,Part E,MACT Subpart HH ..;m•_.:,age;,:
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial and Periodic Sampling and Testing Requirements
For condensate or crude oil tanks,does the company use the state default emissions factors to
estimate emissions?
s � 0
If yes,are the uncontrolled actual or requested missions fora crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the • _
uncontrolled actual or requested emissions Fora condensate storage tank estimated to be greater than or equal to 80 tpy? •z
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.
isl
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash missions,are the emissions factors based on a pressurized liquid sample drawn at the facility being x- s3)F2
permitted(for produced watertanks,a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample r .t:-
should be considered representative which generally means site-specific and collected within one year of the application received s0 .'.
date.However,ifthe facility has not been modified(e.g„no new wells brought on-IIneI then it maybe appropriate to use an „„ifj- y
Vg
alder site-specific sample. ,{.y.,z er
If no,the permit will contain en"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company request a control device eficiency ter than 95%for flare or combustion device?pay quesgrea d
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08-Technical Analysis Notes
State Default factors used. •
•
•
7222.
•
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only)
Uncontrolled
Emissions
AIRS Point t Process H SCC Code Pollutant Factor Control% Units
c,. 01 Pled Roof Tank,Produced Water,w rkn "`: 5 's4T�E ' ., i§ g�3� eq �,�� " g�t PM30 _ _ lb/1,000 gallons Produced Waterthroughput
PM2.5 0'30 .0 lb/1,000 gallons Produced Water throughput
SOx 0,1,0 0 lb/1,000 gallons Produced Water throughput
NOx lb/1,000 gallons Produced Water throughput
VOC ._0 rig lb/1,000 gallons Produced Water throughput
CO ._. 0 lb/1,000 gallons Produced Water throughput
Benzene lb/1,000 gallons Produced Water throughput
Toluene de. lb/1,000 gallons Produced Water throughput
Ethylbenzene _.. lb/1,000 gallons Produced Water throughput
Xylene dB lb/1,000 gallons Produced Water throughput
n-Hexane _ .. lb/1,000 gallons Produced Water throughput
224 TMP _. -, lb/1,000 gallons Produced Water throughput
6 of 17 K:\PA\2014\14WE0187.CP5
Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below ore determined based on requested emissions.
Colorado Re:lotion Parts A and B-APEN and Permit Requirements
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2TPY(Regulation 3,Part A,Section I1.0.1.a)? Source Requires an APEN.Go to
2. Produced Water Tanks have no grandfathering provisions Go to next question
3. Are total facility uncontrolled VOC emissions greaterthan 5 TPY,NOx greater than to TPY or CO emissionsgreater than lO TPY(Regulation 3,Part B,Section 11.0.3)? Source Requires a permit
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from thu individual source greater than l TPY(Regulation 3,Part A,Section ll.D.S.a)? Yes. - '.Source Requires en APEN.Go to
2. Produced Water Tanks have no grandfathering Provisions
3. Are total facility uncontrolled VOC emissions greaterthan2TPY,NOR greater than 5 TPY or CO emissions Beater char.°TPY[Regulation 3,Part B,Section ll.D.21? Yee. .'Source Requires permit
Colorado Reeulation7,Part D.Section I.C-F&G
1. Is tills storage tank located in the t.hr ozone control area or any ozone non attainment area or attainment/maintenance area(Regulation],Part D,Section l.A.1)? Continue-you have indicated th
2. Is this storagetank 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 gas processing plant(Regulation 1,Part D.Section 005)? c Continue-You have indicated th
3, Is this storage tank located at a natural gas processing plant(Regulation 7,Part 0,Section 1.0)? Storage Tank is not subject to Re
4. Dom thlsstoragetank contain condensate? •
5. Does this storage tank exhibit"Flash"(e.g.storing non-stabilized liquids)emissions(Regulation],part 0,Section 1.0.2)?
6. Are uncontrolled actual embsionsof this storage tank equal to or greater than 2 tons per year VOC(Regulaion 7,Part D,5ettion l.0.3.alo))? Yes'.
Part 5.Section Ira-General Requirementsfor Air Pollution Control Equipment-Prevention of Leakage
Pert 0,Section IC.2-Emission Estimation Procedures
Part D,Section ISS-Emissions Control Requirements
Part 0,Section tr-Monitoring
Part 0,Section IE-Recordkeeping and Reporting
Part➢,Sectmn IG.2-Emissions Control Requirements
Part 0,Sect0On l C.l.e and b'General Requirements for Air Pollution Control Equipment--Prevention of leakage
Colorado Reeulatlon7,Part 0,Section II
1. Is this storage tank located at a transmission/storagefacility? Continue•You have indicated th
2. Isthis storage tank'located at en oil and gas exploration and production operation,well production facility,natural gas compressor station or natural gas processing plan['(Regulation 0,Part D,Section 11.1)7 • Go tothe next question You ha
3. Does thisstoagetank have a fixed roof(Regulation 7,Part D,Section 11.6.20)? Yes Go to the next question
4. Are uncontrolled actual emissionsof this storagetank equal to or greater than 2 tons per year VOC(Reeuletlon 7,Part D,Section 11.0.1.01? Yes Source Is subject to parts of Reg
Fart D,Section ICS-General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part 0,Section 160.1.Emissions Control and Monitoring Provisions
Part 0,Section ILC.3-Recordkeeping Requirements
5. Does the storage tank contain only"stabilized"liquids(Regulation 7,Part D,Section ll.C.O.b)? No .I source is subject to all provision
Part 0,Section 100,2.Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
Isthe controiledstorage tank located at a well production facility,natural gas compressor station,or natural gas processing plant constructed an or after May 1,2020 or located at a facility that was modified on or after May 1,2020,such r.
6. that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7,Part 0,Section ll.C.4.a.(i)? 'NO - Storage Tanks not subject to Re
'S:ox
Is the controlledatomge tank located a[a well production facility,natural gas compressor station,op natur sea processing plant cons[ruted on or of ter January 3,2021 or[mated at a facility that was modified on vrafterjanuary 1, '
7. 2021,suchthat an additional controlled storage vessel is constructed to receve an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7,Part D,Section ll.C.4.a.liil?
4o CFR,Part 60,Subpart Kb.Standards of Performance for Volatile Organic Liquid Storage Vessels
1. Is the ind Nichol storage vessel capacity greaterthan or equal to 75 cubic meters(0)[-472 BBLs](40CFR 60.110b(a))? You -Go to the next question
2. Does the storage vessel meet the following exemption In 60.111b(d)(4)? Yes-- ;-.;Storage Tank is not subject NSPS.
a.Doesnhe vessel has a design capacity less than or equal to 1,589.874 ms[-10,0]0 BBL]used for petroleum or condensate stored,processed,or treated prior to custody transfer'as defined in 60.11lb?
3. Was this storagevessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after July 23,1984(40 CPR60.130bla))?
4. Doesthetank meet the definition of"storage vessel"a in 60.1116?
S. Does the storage vessel store a"volatile organic liquid(VOL]"'as defined in 60.1316?
6. Doesthe storage vessel meet any one ofthefollowing additional exemptions:
a.Isthestorage vessel a pressure vessel designed to operate in excess 01204.9 kPa[`29.7 psi]and without emissions tothe atmosphere(60.110b(d)(2)l?;or '
b.The design capacity is greater than or equal to 151 ma(`950 BBL]and Mores a liquid with a maximum true vapor pressures less than 35 kPa(60.110b(bl)7;or
c.The design capacity is greater than or equalto 75 Ma['472 BBL]but less than 1510[-950 BBL]end stores a liquid well a maximum true vapor pressures less than 15.0 kPa(60.110b(b))?
7. Does the storagetank meet either one of the following exemptions from control requirements:
a.The design capacity is greater than or equalto 151 m(-950 BBL]and stores a liquid with a maximum true vapor pressure greaterthan or equal to 3.5 kPa but less than 5.2 kOa?;or
b.The design capacity Is greater than orequalto 75 he[-472 BBL]but less than 151 m('950 BM)and stores a liquid with a maximum true vapor pressure greater than or equal to.15.0 kPa but less than 27.6kPa? •
•
40 CFR,Part60,Subpart 0000/0000a,Standards of Perfonnencefar Crude OR and Natural Gas Production,Transmission and Distribution
1. Is this storage vessel located at a facility in the onshore oil and natural gas production segment,natural gas processing segment or natural gas transmission and storage segment of the industry? Continue-You have indicated tit
2. Was this storageoessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)between August 23,2011 and September 18,2015? NO • Storage Tank is not subject NSPS
3. Was thisatoragewessel constructed,reconstructed,or modified(see definitions 40 CFR,60.2)after September 18,2015? Yes -:Go the next question
4. Are potential VOC emissions'from the individual storage vessel greater than or equal to 6tons per year? No 7 Storage Tank is not subject NSPS
5. Does this storage vessel meet the definition of"storage vessel"'per 60.5430/60.5430a?
•
6. Is the storage vesel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart 111?
[Note:If a storage vessel is previously determined to be abject to NSPS 0000/OOO0a dueto emissions above S tons per year VOC on the applicability determination date,it should remain subject to NSPS 0000/0000a per
60.S36S(ef(2)/60.5365a(e)(2)even If potential moo emissions drop below 6 tons per year.
40 CFR,Part 63,Subpart MAR HH,011 and Gas Production Facilities
1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: ). 'Continue.You have Indicated th
a.A facility that processes,upgrades or stores hydrocarbon liquids'(63.700)e)121);OR
b.Afacifity that processes,upgrades or stores natural gas prior to the point at which natural gas emters the natural gas transmission and storage source category or is delivered to a final end user°(63.?60(a)(3))?
2. Is the tank located at afaciliy that is major'for HAPs? 'No:' Storage Tank 6 not subject MAC
3. Does the tank meet the definition of"storage vessel"'in 63.761?
4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"'per63.761?
5. Is the tank subject to control requirements under40 CFR Part 60,Subpart Kb or Subpart 0000? .
Subpart A,General provisions per 463.764(a)Table 2
463.766.Emissions Control Standards
463.773-Monitoring
§63.774-Recordkeepine
§63.775-Reporting
RACT Review
RACT review is required if Regulation 7 does not apply AND if thetank Is In the non-attainment area.It the tank meets both criteria,then review PACT requirements.
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 documents not
a rule or regulation,and the analysis it contains may not apply to a particular situation teemed upon the individual facts and circumstances.This document does not change or substitute for any law.regulation,
or other legally binding requirement and is not legally enforceable.In the event of any conflict between the language of this document and the language of the Clean Air Act„its implementing regulations,
and Air Quality Control Commission regulations,the language of the statute or regulation will control.The use of non-mandatory language such as"recommend,"rnay,"'should,"and"can,-is intended to
describe APCD interpretations and recommendations.Mandatory terminology such as'must"and'required"are intended to describe controlling requirements under the tens of the Clean Air Act end Air
Quality Control Commission regulations,but this document does not establish legally binding requirements in end of itself.
Section 01-Administrative Information
Facility AIRS 10: 123'_ SHOP 004
County Plant Point
Section 02-Equipment Description Details
Detailed Emissions Unit Loadout of condensate to tank trucks -
Description:
Emission Control Device •
ECD
Description:
Is this laadoutcontrolled? Yes
Requested Overall VOC&HAP Control Efficiency%: 98
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Hydrocarbon Loadout
Actual Volume Loaded= 1,168,000 Barrels(bbl)Per Veer
RequestedPermitLimitThroughput= 1,168,000 Barrels(bbl)per year Requested Monthly Throughput= di:'1. Barrels(bbl)per month
Potential to Emit(PTE)Volume Loaded= 1,168,000 Barrels(bbl)per year
Secondary Emissions-Combustion Device(s)
Heat content of waste gas= 3095 Btu/scf
Actual Volume of waste gas emitted per year r scf/year
Requested Volume of waste gas emitted per year= 'scf/year.
Actual heat content of waste gas routed to combustion device= s MMBTU per year
Requested heat content of waste gas routed to combustion device= a MMBTU per year
Potential to Emit(PTE)heat content of waste gas routed to combustion device= I • MMBTU peryear
Control Device
Pilot Fuel Use Rate: 16.8 scfh i MMscf/yr
Pilot Fuel Gas Heating Value: .3005 Btu/sd MMBTU/yr
Section 04-Emissions Factors&Methodologies
Does the company use the state default emissions factors to estimate emissions7
Does the hydrocarbon liquid loading operation utilize submerged fit!? Y•j;;,+ �'
Emission Factors Hydrocarbon Loadout
Uncontrolled Controlled
Emission Factor Source
Pollutant
(Ib/bbl) (lb/bbl)
(Volume Loaded) (Volume Loaded)
VOC 16E^i t 716103 byt State E.F.
Benzene :;.OE 05 3, E 00 - out State E F ab
Toluene 0ilat•Ot` i.tiC`edo
Ethylbenzene 00f:00 1i)OF 0.`0
Bylene O(ICE•'10 ..00: 1
n-Hexane
224 TMP ,f
Control Device
Pollutant Uncontrolled Uncontrolled Emission Factor Source
(lb/MMItu) (lb/bbl)
(waste heat combusted) (Volume Loaded)
PM10 0 zt"F'
PM2.5 F 00, Ma9elg•t''1-11ikfalT1V‘e,
SOx a rI V eg
NOx 0.0680 I s e
CO __ _, 51nd'faH`taI Ftar'es`
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (Ib/MMltu) (lb/MMsef) Emission Factor Source
(Pilot Gas
(Waste Heat Combusted) Throughput)
PM10 ^CCOo
PM2.5 IulIIIG Combined Efs in lb/bbl
SOx 00000 1e lee
NOx 0.0680 210.1600 5 industrial Flares(NO(/ 3.77E-04 •
VOC 6'0200
CO 0.3100 359 t i00 v .5 Industrial Flares(CO) " 1.44E-03
00117 K:\PP,\2014\14WE0187.CPS
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) (Ibs/month)
PM1O .
PM2.5 .. .. ,.
SOx
NOx .. Operator estimates slightly higher emissions.which are acceptable and will be used in permit.
VOC ..
CO .. Operator estimates slightly higher emissions,which are acceptable and will be used in permit.
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/year) Ooperator '
Benzene .. . Operator estimates slightly higher emissions.which are acceptable and will be used In permit.
Toluene
Ethylbenzene . z .
Xylem
n-Hexane ..
224TMP . •
Section 06-Regulatory SummaryAnalysis
Regulation 3,Parts A,B
Regulation 7 Part DSection II.C.5.
(See regulatory applicability worksheet for detailed analysis)
Section 07-Initial end Periodic Sampling and Testing Requirements ��"'qg�
Do.the company request a control device efficiency greater than 9536 for a flare combustion device? t'�i"Sr
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08-Technical Analysts Notes _
Statedegiltfactoralio *..
•
•
Section 09-5CC Codingand Emissions Factors(For Inventory Use Only)
Uncontrolled
Emissions
AIRS Point it Process P SCC Code Pollutant Factor Control 90 Units
004 Ol . PM10 b/1,000 gallons transferred
PM2.5 b/1,000 gallons transferred
SOx . b/1,000 gallons transferred
NOx b/1,000 gallons transferred
VOC b/1,000 gallons transferred
CO b/1,000 gallons transferred
Benzene b/1,000 gallons transferred
Toluene 6/1,000 gallons transferred
Ethylbenzene '' 6/1,000 gallons transferred
Xylene b/1,000 gallons transferred
n-Hexane fl b/1,000 gallons transferred
224 TMP b/1,000 gallons transferred
9 of 17 K:\PA\2014\14WE0.87.CP5
•
Hydrocarbon Loedout Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions and throughput.
Colorado Reaglengn 3less Aand B..APFIY end vermitRe4g(releme
ATTAINMENT Ape uncontrolled
S. actual an exploration
any criteriaion site
is from 11 pad)
lti coon (Regulation 3,Part A,Section II.0.1 a(}
1 Is the Iwdou[located at an egpMratlon end production site(e.g.,well patl)(Regulation 3,Paola,5ectioa
3. Is the loadout operation loading less than 10.000 gallons(2.38 BOLO of crude of per day an an annual average basis?
4. Is the loadwt operation loading less stun 5,750 bbls per year of condensate via splash fill,
5. Is the Ioadout operation boding less than 16,308 bMs per year of condensate via submergerlilll procedure?
6. Neetuncontrolledcility uncontrolled VOC emissions greater Man 5 TPY;NOx greater Man to TP1'orCO emissions greater Man In MY(Regulation 3,Pan arsecb'on 1.0,3)}
NONATTAp'1Mejjt,o
1.Are uncorstmllud ors Morn any criteria polio,.!rem this individual source greater than l TPr(Reg A,Section 0.0.1.ala Yet-rte,,Go eIst at si theextquon
ISIMlmaoIs the loadnutneration loaand prduao1,00(ssln well pad)nt(Regulation idsot t.,o an annual
*WAX
tt tnate quesuestion
Ost
3. Is the loadout operationload,g less than snSsbbts per1ear loo,ssns5 a iapershyonanannual average basis? Nd hit Got,next question
4. Is the loadout operation loadre less than 16,306 bids
per yearof condensatete viasubherg hinw`w n'Go,next question
5. Iilthe 1pado,onttn oIpeationlmdon less 1 neater than r year ON greater
reater than submerged MI procedure?grey MTh question
fi. Are total faculty uncontrolled VOC emissions fiom[hegreater tFan?TPV,NON HrealerMan5 TPY or CO em2zimztlrea[arthan lOTPy(Regulation 3,Part 5,Session ll.0.21? Y'K;z�:`S The loadmttrequlresa permit
mbts. ite•M Oesa Perto_S,ra((elLOCb
0 Is thIs vanclensare storage tank hydrocarbonlquds loadcut looted at a well production facility,natural gas compressor sbtl0n or natural gaspmcessng pant, Y Ys�swto question.
_. Does thE facility hese a throughput of hydrocarbon liquids loadout to transport vehicles greater than orequalto 5,000 barrels} rceusublect to Regulation 7 Par[['Section,C.S.
I ' - .. __-.... .a+.• Fa s.s,....
Section IITS.a.(n-compliance schedule
Section .a(ii)Operator(Mthout Venting
Section .a.(iiil-Lwdout E9?omen Operate and Maintenance
section a.gYl•toadootobseryaboos and Operator Training •
Sections.elvl-Records
Section II.c5.e(vi-Requirements for Ale 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 Centre?Cemmissim regulalioss.This document is not a
rule®ulation,and lheenelyais it contains may not apply to a particular situation based upon the individual races end circumstances.This document des not change or substitutetar any law,regulation,or
• any other legally binding requitement and is no legally enforceable In the event a any conflict between the language of this document and the language stilts Clean Air Act„its implementing regulations.
and Air Quality Control Commission regulations,the language of the shah,te or regulation Mn control The use of non-mandatary language such as frreanmevd'"may"'shad,"and"cant"is intended le
desenheAPCD interpretations and*aliens.Mandatory terminology such as"must"and'Yaqui:ed.are intended todesc be controlling requlrements under the tams otl}e Clean AlrAct and Air
Quality Control Connate,,regulations.but this document does not establish legally bindng requirements in end ofitself.
•
Separator Venting Emissions)nve tort'
Section 01-Administrative Information
Facility AIRs ID: 323 _ 96DF 007
County Plant Point
Section 02-Equipment Description Details
Twelve(12)low pressure gas/oil separators(five from new wells)and two(2)vapor recovery towers controlled by two(2)enclosed flares.
Detailed Emissions Unit Description:
ECD
Emission Control Device Description:
Requested Overall VOC&HAP Control Efficiency%: 98
Limited Process Parameter Natural Gas.„;-
Gas meter Yes,meter,.,+- rt{, tnd operations,
Section 03-Processing Rate Information for Emissions Estimates
Primary Emissions-Separator
Actual Throughput= 10.9 MMscf per year
Requested Permit LimitThroughput= 13.1 MMscf per year Requested Monthly Throughput= ..... MMscf per month
Potential to Emit(PTE)Throughput= 13_MMscf per year
Secondary Emissions-Combustion Device(s)for Air Pollution Control
Separator Gas Heating Value: 2480.0 Btu/scf
Volume of waste gas emitted per BBL of
liquids throughput: scf/bbl
Control Device I
Pilot Fuel Use Rate: 33.6 scfh MMscf/yr
Pilot Fuel Gas Heating Value: 2480-Btu/scf
Section 04-Emissions Factors&Methodologies
Description
Operator calculated emission factors by taking a weighted average of two samples,one sample from the LP Separator,and one from the VRT,with both pulled from the Wetco Farms 0-4 facility.Weighted average was
calculated by assigning 25%weight to the LP sep gas composition,and 75%to the VRT gas composition as a conservative estimate.An average mol%was calculated for each component,and the resulting composition used to
calculate emission faders.The results of this method were compared to calculating emission factors for each sample,and taking a weighted average of those emission factors.While that method results in a slightly higher VOC
emission factor,the difference is negligible(i.e.using that method along with a standard gas volume of 379.8 instead of 379(both values are generally accepted)results in a lower factor than calculated by the operator),and the
operator calculated values will be used in this permit.The operator will be required to conduct semi-annual sampling of the commingled VRT/LP gas stream in order to demonstrate compliance with the emission factors used in
this application.
Combined/Weighted Gas LP GAS I I VRT GAS
MW I '43.8 Ib/Ib-mol Displacement Equation 32.30031 MW(lb/lb-m00 I 47.5938
Ex=O'MN"Xx/C
Weight% wt% wt%
Oxygen/Argon 0.2 0.4395 Helium. 0.1794
CO2 1.4 2.9709 CO2 0,8552
N2 0.9 1.7418 N2 0.5755
methane 7.8 22.8038 methane 2.7427
ethane 13.4 18.1694 ethane 11.8332
propane 27.6 20.292 propane 30.0971
isobutane 6.0 3,4938 isobutane 6.8937
n-butane 18.8 10.2029 n-butane 21.7056
isopentane 5.4 2.9789 isopentane 6.1637
n-pentane 6.9 4.1114 n-pentane 7.87
cyclapentane 0.4 0.3141 cyclopentane 0.4825
n-Hexane 2.1 1.9187 n-Hexane 2.1W5
cyclohexane 0:5 0.5905 cyclohexane 0.4812
Other hexanes 3.2 2.6988 Other hexanes 3.3553
heptanes 2.6 2.1216 heptanes 2.707
methylcyclohexane 0.5 0.8485 methylcyclohexane 0.4236
224-IMP -0.0 0.0019 224-TMP 0.0011
Benzene 0.2 0.2523 Benzene 0.2299
Toluene 0.2 0.4374 Toluene 0.1709
Ethylbenzene 0.0, 0.0543 Ethylbenzene 0.0125
Xylenes 0.1 0.2235 Xylenes 0.0498
C8+Heavies 1.6 3.334 C8(Heavies 1.0488
Total
VOC Wt% 0.25 Calculation Weight 0.75
11 of 17 K:\PA\2014\14WE0787.CP5
I
Separator•v'eIrtlsg Emis-;oirc I=.:.e^tar'/
Emission Factors Separator Venting
Uncontrolled Controlled Emission Factor Source
Pollutant (Ib/MMscf) (Ib/MMscf)
(Gas Throughput) (Gas Throughput) PA Calculated Unctrlled Emission Factors
VOC c_ 1305 13/5. F •qsa iy is 88147.80374 Conservative,acceptable
Benzene 170,1 5 5C5C Eatnr9 larratysis 271.9771791 Within rounding error,acceptable
APEN VALUES LISTED IN CELLS
Toluene 254 1,... 1 C8,7Exte analysis 274.3158304 Conservative,acceptable
872-878,DIVISION
Ethylbenzene 23.22 .. Extende Jas analysis 26.50478242 Conservative,acceptable
Xylene 1-.h Extended-vas.analysis CALCULATED VALUES IN CELLS
5. 107.6648515 Conservative,acceptable
5::n-Hexane 0393 s n, Extended 172 78
gas ana ysis 2379.424977 Conservative,acceptable
224 TMP _..4 ,.3. ., Extended gas analysis 1.501360224 Conservative,acceptable
Primary Control Device
Uncontrolled Uncontrolled
Pollutant (Ib/MMBtu) Ib/MMscf Emission Factor Source
(Waste Heat
Combusted) (Gas Throughput) Combined Combustion Efs
PM10 `.3109 :?x
PM2.5
500 '3.OOL'.'
NOx 0.0680 AP42 ChapLeO.3Sfndustrial Flares(NO0) 172.7828746 lb/MMscf
CO 0.3100 >O _.:G r `dustrial Flares(CO) 787.4617737 Ib/MMscf
Pilot Light Emissions
Uncontrolled Uncontrolled
Pollutant (Ib/MM6tu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Pilot Gas Throughput)
.. ....
PM2.5 212,'
500 3•525,
NOx 0.0680 - '-8 540,3 AP-42 Chapter 13,5'.Industrial Flares(NOx)
VOC _ ....r. _
CO 0.3100 .n_ AP-42 Chapter 135 industrial Flares(CO)
Section 05-Emissions Inventory
Potential to Emit Actual Emissions Requested PermitLimits Requested Monthly Limits
Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled
(tans/year) (tons/year) (tons/year) (tons/year) (tons/year) (Ibs/month)
PM10 U -,
PM2.5 ,
SOx >.,- 13
NOx 1 1. :a;
, , Operator estimates slightly higher combustion emissions(NOx,CO),which
VOC 5',:r E-
are acceptable and will be used In permit.
CO 5_t C:4 dt'
Potential to Emit Actual Emissions Requested Permit Limits
Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(lbs/year) (113s/year) (lbs/year) (Ibs/year) (113s/year)
Benzene 35=4 ,. .. >-- 0'
Toluene 3325 .. . '
Ethylbenzene 304 213
Xylene 1:35 132_ -. ,5 -
n-Hexane 3..3„_ 2...3,-,, .._ 1:... ..'2
224 TMP ,,. -- _
Section 06-Regulatory Summary Analysis ..
Regulation 3,Parts A,B .-, ...,.,. .=,i c:�.:s.•er t•,x«•.
Regulation 7,Part 0,Section 11.8,F
Regulation 7,Part D,Section 11.8.2.e "- '•c: --'-._:: --U_ >;
(See regulatory applicability worksheet for detailed analysis)
12 of 17 K:\PA\2014\14WE0187,CPS
SI'parltol VerrtirigEni,.;'iiosis''s,entory
Section 07-Initial and Periodic Sampling and Testing Requirements
Using Gas Throughput to Monitor Compliance
Does the company use site specific emission factors based on a gas sample to estimate emissions?
This sample should represent the gas outlet of the equipment covered under this AIRS ID,and should have been collected within one year of the application received date.However,if the facility has not
been modified(e.g.,no new wells brought on-line),then it may be appropriate to use an older site-specific sample.
If na,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?
If yes,the permit will contain:
-An"Initial Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are
less than or equal to the emissions factors established with this application.
-A"Periodic Testing Requirement"to collect a site-specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors
are less than or equal to the emissions factors established with this application on an annual basis.
Will the operator have a meter installed and operational upon startup of this point?
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? ` .r*•' ,"
If yes,the permit will contain initial and periodic compliance testing in accordance with PS Mono 20-02
have f l acm,ffmonitored h
ryg m r rlrrfrPraargrp nir Jrrlrrq rrrr9r�r r / ey �' j
_ l JJ'3.
WOW4i4,444...A.,43.44.140/00640r44MalitA,KOVAIKOS:t0f•Aggegr,g4W444''340,4' 4fii2t 0:
1414
'�, ..,
Section 08-Technical Analysis Notes
Operator based emission factors on representative samples,so this permit will require initial sampling of the combined LP/VRT gas stream.Flow meter for these points measures commingled streans.and cannot distinguish flows.Therefore the
operator will be periodically required to sample downstream of the mixing point of these two streams to demonstrate emission factor accuracy.
Section 09-SCC Coding and Emissions Factors(For Inventory Use Only).
AIRS Point tt Process It SCC Code Pollutant Uncontrolled Emissions Factor Control% Units
007 01 . . . . PM10 .. .. .
PM2.5 -. _ .
500 .. .... .
NOx
VOC .f.., ...
CO f,.- _
Benzene
Toluene - ...
Ethylbenzene 21.'
xylene . . ._
n-Hexane
224 TMP _, _a '
13 0017 K:\PA\2014\14W E0787.CP5
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 Ism the lion-Arta rt,er,€tes
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.e)?2. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOR greater than TO TPY or CO emissions greater than So Icy(Regulation 3,Part B,Section il.D3)? ip., `Jh
IYou!IaJo mutate:1 rna:s:>:t?°s.0 the ia•,-Attelnrnanr Ames
NON-ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY(Regulation 3,Part A,Section ll.D.1.a)? Yes (Source Re
2. Are total facility uncontrolled VOC ons fr the greater than 2 TPY,NOR greater than 5 TPY or CO emissions greater than 10 TPY(Regulation 3,Part%Section ll.D.2)? No l Source isl
Colorado Regulation 2,Part D.Section II
1. Was the well newly constructed,hydraulically fractured,or recampleted on or after August 1,20147 Yes '.'i]S urce is.
.:uLle,:. So„trot d,8.2,F
Section 11.0.2—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 notenciosed? Nd5k iThe contra
control device Fa-this, .>notsJbrect touafu;alc=l?:. u.,e.., ,5. ,
Section II.B.2.e—Alternative.emisslons control equipment
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act,its implementing regulations,and Air Quality Control Commission regulations.This document is
not a rule or repletion.and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances.This document does not change or substitute for any law,
regulation,or any other legally binding requirement and is notlegally enforceable.In the event of any conflict between the language of this document and the language of the Clean Air Act„its implementing
regulations.and Air Quality Control Commission regulations,the language of the statute or regulation will control.The use of non-mandatory language such as"recommen7,""may""should,"and"can.'is
intended to describe APCD interpretations and recommendations.Mandatory terminology such as'mest"and'required"are intended to describe controlling requirements lender the terms of the Clean Air
Act and Air Quality Control Commission regulations,but this document does not establish legally binding requirements in and of itself.
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
FACILITY EMISSION SUMMARY
Company Name Bonanza Creek Energy Operating Company,LLC
County AIRS ID 123 History File Edit Date 4/9/2018
Plant AIRS ID 9BDF Ozone Status Non-Attainment
Facility Name State North Platte T-36
EMISSIONS-Uncontrolled(tons per year) EMISSIONS With Controls(tons per year)
AIRS PERMIT Description PM10 PM2.5 H2S SO2 NOx VOC Fug CO Total PM10 PM2.5 H25 SO2 NOx VOC Fug CO Total REMARKS
ID VOC HAPs VOC HAPs
Previous FACILITY TOTAL 0.3 0.3 0.0 0.0 10.2 966.7 0.0 48.7 31.3 0.3 0.3 _ 0.0 0.0 10.2 77.6 0.0 30.4 4.4
Previous Permitted Facility total 0.2 0.2 0.0 _ 0.0 8.7 954.8 0.0 47.5 30.9 0.2 0.2 0.0 0.0 8.7 65.7 0.0 29.2 4.0
001 GP02.CN RICE Caterpillar G3306TA(SN:R6S01001) :,;-} -
002 14WE0187 Condensate storage,8000 bbl 1.1 844.5 5.0 32.1 1.1 16.9 5.0 0.6 Updated throughout,96/control claimed,
003 14WE0187 Produced water storage,2000 bbl 1.1 76.5 j 4.9 8.5 1.1 1.5 4.8 0.2 Updated air ouphp ut 98%control clalrnorl
004 14WE0187 Loadout 0.2 137.8 0.8 2.4 0.2 2.8 1.0 0.0 Updated throughput,98%control claimed.
005 Cancelled Fugitive Equipment Leaks:.
006 Cancelled Emergency flare -
007 14WE0187 Separators and VRTs 1.1 590.6 5.2 19.9 1.1 11.8 5.2 0.4 Updated throughput 48%»control claimed.
008 14WE0187 Pneumatic pump 2091608 0.2 45.3 1.1 1.2 0.2 2.3 1.1 0.0 No change
009 GP02.CN RICE Caterpillar G3508 ULB(SN:RBK00103)`
010 GPO2.CN RICE Caterpillar G3508 ULB(SN:RBK01301)
011 14WE1099.CN RICE GasJack01230(SN:50867)
012 14WE1100.CN RICE GasJack GJ230(SN:11559)
013 GP02.CN RICE GM 5,7L(ON:10CHMM312090031)014 GP02.CN RICE GM 5.7L(SN:10CHMM310070017)
015 GP02.CN RICE Caterpillar G3306B(ON:R6501665)016 GP02.CN RICE Caterpillar G33066(SN:R6501205)
017 GP02.CN RICE Caterpillar G3306B JSN:R6S01833)
018 Cancelled Temporary candlestick flare
019 Cancelled Vapor recovery tower
020 GP02.CN RICE Caterpillar 63508 ULB(SN:RBK01209) 0.0 0.0
021 GP02.CN RICE 690 Hp 0.0 0.0 Cancellation received 7/17/2020-no longer exists.
APEN-Exempt/Insigniflcants:
XA Produced Water Vaults 0.5 0,1 0.5 0.1
XA Heated Separators 0.4 j 0.4 5.4 0.3 4.5 0.1 0.4 0.4 5.4 0.3 4.5 0.1
XA Pneumatic Devices I j 5.7 0.3 5.7 0.3
XA Compressor Slowdown 0.2 0.0 0.2 0.0
VOC: Syn Minor(NANSR and OP)
NOx:True Minor(NANSR and OP)
FACILITY TOTAL 0.4 0.4 0.0 0.0 9.1 1,701.4 0.0 21.5 64.3 0.4 0.4 0.0 0.0 9.1 42.0 0.0 21.6 1.7 CO:True Minor IPSO and OP)
HAPS:Syn Minor n-hexane and Total
MACT HH:Not applicable-Area Source
MACT ZZZZ:Area Source
Permitted Facility Total 0.0 0.0 0.0 0.0 3,7 1,694,7 0.0 17.0 63.9 0.0 0.0 0.0 0.0 3.7 35.3 0.0 17.1 1.3 Excludes units exempt from permits/APENs
Modeling not requited based on A change in emissions,
(G)Change in Permitted Emissions -0.2 -0.2 0.0 0.0 -5.0 -30.4 0.0 -12.1 Pubcom required due to requesting new federally
enforceable Syn Minor Permit limits.
Total VOC Facility Emissions(point and fugitive) _ 42.0 Facility is eligible for GP02 because 0 90 tpy
(A)Change in Total Permitted VOC emissions(point and fugitive) -30.4 Project emissions less than 25 tpy
Page 15 of 17 printed 8/17/2020
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY-HAPs
Company Name Bonanza Creek Energy Operating Company,LLC
County AIRS ID 123
Plant AIRS ID 9BDF
Facility Name State North Platte T-36
Emissions - uncontrolled (lbs per year)
POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP TOTAL(tpy)
001 GP02.CN RICE Caterpillar G3306TA(SN:R6S01001)
002 14WE0187 Condensate storage, 8000 bbl 6041 5430 397 1877 50341 45 32.1
003 14WE0187 Produced water storage,2000 bbl 4088 12848 8.5
004 14WE0187 Loadout 486 10 4218 2.4
005 Cancelled Fugitive Equipment Leaks
006 Cancelled Emergency flare
007 14WE0187 Separators and VRTs 3536 3325 304 1235 31309 18 19.9
008 14WE0187 Pneumatic pump 2091608 198 168 25 54 1662 150 1.2
009 GP02.CN RICE Caterpillar G3508 ULB(SN: RBK00103)
010 GP02.CN RICE Caterpillar G3508 ULB(SN: RBK01301)
011 14WE1099.CN RICE GasJack OJ230(SN:50867)
012 14WE1100.CN RICE GasJack GJ230(SN: 11559)
013 GP02.CN RICE GM 5.7L(SN: 10CHMM312090031)
014 GP02.CN RICE GM 5.7L(SN: 10CHMM310070017)
015 GP02.CN RICE Caterpillar G3306B(SN: R6S01665)
016 GP02.CN RICE Caterpillar G3306B(SN: R6S01205)
017 GP02.CN RICE Caterpillar O3306B(SN: R6501833)
018 Cancelled Temporary candlestick flare
019 Cancelled Vapor recovery tower
020 GP02.CN RICE Caterpillar G3508 ULB(SN: RBK01209) 0.0
021 GP02.CN RICE 690 Hp 0.0
APEN-Exempt/Insignificants:
XA Produced Water Vaults 26 80 0.1
XA Heated Separators 7 157 0.1
XA Pneumatic Devices I 25 21 6 12 209 19 0.1
XA Compressor Blowdown 2 2 I 15 1 0.0
TOTAL(tpy) 0.0 0.0 0.0 7.2 4.5 0.4 1.6 50.4 0.0 0.1 64.2
16 14WE0187.CP5 8/17/2020
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY-HAPs
Company Name Bonanza Creek Energy Operating Company,LLC
County AIRS ID 123
Plant AIRS ID 9BDF
Facility Name State North Platte T-36
Emissions with controls (abs per year)
POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n-Hexane McOH 224 TMP TOTAL(tpy)
001 GP02.CN RICE Caterpillar G3306TA(SN: R6S01001)
002 14WE0187 Condensate storage,8000 bbl 121 109 8 38 1007 1 0.6
003 14WE0187 Produced water storage,2000 bbl 82 257 0.2
004 14WE0187 Loadout 10 1 86 0.0
005 Cancelled Fugitive Equipment Leaks
006 Cancelled Emergency flare 0.0
007 14WE0187 Separators and VRTs 71 66 626 1 0.4
008 14WE0187 Pneumatic pump 2091608 i(3 10 34
009 GP02.CN RICE Caterpillar G3508 ULB(SN:RBK00103)
010 GP02.CN RICE Caterpillar G3508 ULB(SN:RBK01301)
011 14WE1099.CN RICE GasJack GJ230(SN:50867)
012 14WE1100.CN RICE GasJack GJ230(SN: 11559)
013 GP02.CN RICE GM 5.7L(SN: 10CHMM312090031)
014 ,GP02.CN RICE GM 5.7L(SN: 10CHMM310070017)
015 GP02.CN RICE Caterpillar G3306B(SN: R6S01665)
016 GP02.CN RICE Caterpillar G3306B(SN: R6S01205)
017 GP02.CN RICE Caterpillar G3306B(SN: R6501833)
018 Cancelled Temporary candlestick flare
019 Cancelled Vapor recovery tower
020 GP02.CN RICE Caterpillar G3508 ULB(SN:RBK01209) 0.0
021 GP02.CN RICE 690 Hp 0.0
APEN-Exempt/Insignificants:
XA Produced Water Vaults 26 80 0.1
XA Heated Separators 157 0.1
XA Pneumatic Devices I 25 21 6 12 209 11D 0.1
XA Compressor Blowdown 2 15 i 0.0
TOTAL(tpy) 0.0 0.0 0.0 0.2 0.1 0.0 0.0 1.3 0.0 0.0 1.6
17 14WE0187.CP5 8/17/2020
Condensate Storage Tan (s) APEN 0 2 ry
Form P -205
CD ' 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 wilt 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: 14WE0187 AIRS ID Number: 123 / 9BDF/002
Section 1 - Administrative Information
Company Name: Bonanza Creek Energy Operating Company, LLC
Site Name: State North Platte T-36 Production Facility(COGCC#433300)
Site Location
Site Location:
SESE, 5N, 36, 63W County: Weld
40.35036, -104.37943
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.
42909-
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/002
Section 2 - Requested Action
❑ NEW permit OR newly-reported emission source
❑ Request coverage under traditional construction permit
O Request coverage under a General Permit
❑ GP01 O 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-
1❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment O Change company name3
O Change permit limit O Transfer of ownership4 ❑ Other(describe below)
-OR-
❑ APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
▪ APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit (PTE)
Additional Info&Notes: Requesting new throughput due to addition of new wells.
II 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): CNDTK-01
For existing sources, operation began on: 9/5/2013
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 Ft Production(E&P)site O Midstream or Downstream (non E&P)site
Will this equipment be operated in any NAAQS nonattainment area? Q Yes O No
Are Flash Emissions anticipated from these storage tanks? 0 Yes O No
Is the actual annual average hydrocarbon liquid throughput a 500 bbl/day? 0 Yes O No
If"yes", identify the stock tank gas-to-oil ratio: 0.0017 m3/liter
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) O Yes Q 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 ElYes ❑ No
emissions≥6 ton/yr(per storage tank)?
COLORADO
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/002
/002
Section 4 - Storage Tank(s) Information
Actual Annual Amount Requested Annual Permit Limits ,
(bbl/year) (bbl/year)
Condensate Throughput: 973,333 1,168,000
y Projected 2020
From what year is the a,:toot annual amount?
Average API gravity of sales oil: 43.4 degrees RVP of sates oil: 6.9
Tank design: 0 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)
CNDTK-01 Sixteen(16)500 bbl 8,000 7/2013 9/2013
Wells Serviced by this Storage Tank or Tank Battery°(E&P Sites Only)
API Number Name of Well Newly Reported Well
05 - 123 - 37577 State North Platte 34-31-6HNB O
05 - 123 - 39006 State North Platte 44-41-36HNB 0
05 - 123 - 39008 State North Platte T34-P31-36HNC 0
05 - 123 - 39007 State North Platte T44-P41-36HNC O
05 - 123 . 39009 State North Platte T-P-36HNB 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)
40.35036,-104.37943
❑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 05 -35 500 TBD TBD
Indicate the direction of the stack outlet: (check one)
✓❑Upward O Downward O Upward with obstructing raincap
❑Horizontal O Other(describe):
Indicate the stack opening and size: (check one)
p Circular Interior stack diameter(inches): 96
❑Square/rectangle Interior stack width(inches): Interior stack depth(inches):
❑Other(describe):
'.COLORADO
Ned•1,6En uanmer..
Permit Number: 1 4WE0187 AIRS ID Number: 123 /9BDF/002
/002
Section 6 - Control Device Information
0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Pollutants Controlled:
Vapor
Size: Make/Model:
❑ Recovery
Unit (VRU): Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
Pollutants Controlled: VOC, HAPs
Rating: 3.68 MMBtu/hr
Type: Enclosed Combustor Make/Model: One(1) IES 96"
❑ Combustion Requested Control Efficiency: 98
Device:
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: 500 Waste Gas Heat Content: 2,815 Btu/scf
Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: 0.05 MMBtu/hr
Description of the closed loop system:
0 Closed Loop System
Pollutants Controlled:
❑ Other: Description:
Control Efficiency Requested:
Section 7 - Gas/Liquids Separation Technology information (E&P Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? -4 psig
Describe the separation process between the well and the storage tanks: Oil produces to high/low pressure
separators where gas, condensate, and water are separated. Condensate, and any water left, are sent
to the vapor recovery tower for further separation. Condensate is sent to the storage tank battery prior to being
trucked off site.
kip,'C0L0RAD0
4 • =
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/002
Section 8 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form7.
Is any emission control equipment or practice used to reduce emissions? p✓ 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):
Pollutant Control Equipment Descri Description Collection Efficiency Control Efficiency
p (%of total emissions captured (%reduction of captured
by control equipment) emissions)
VOC ECD 100 98
NOx
CO ECD 100 98
HAPs
Other:
From what a- s the toll :i"y,to o Led co tool cn,r ,,,t et issinns date.
Projected 2020
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 ('tP 12r Emissions Emissions$ Emissions Emissions
Basis Mfg.,etc.)
(tons/year) (tons/year) (tons/year) (tons/year)
VOC 1.4460 Ib/bbl ProMax 703 72 14.08 844 47 16 89
NO,, 0.0680 Ib/MMBtu AP-42 0.92 0.92 1.10 1.10
CO 0.310 Ib/MMBIu AP-42 4 18 4 18 5 00 5.00
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.
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.
Section 9 - Non-Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non-criteriaEI 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 Factor7 Actual Annual Emissions
Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled
Service(CAS) Basis Units (AP-42, Emissions Emissions8
Number Mfg.,etc.) (lbs/year) (lbs/year) -BF
Benzene 71432 0.0052 lb/bbl ProMax 5,,304 5,034 102- 101 8/17/2020
Toluene 108883 0 0046 Ibrobl ProMax 4.525 92 Per attached;mail
Ethylbenzene 100414 0 0003 lb/bbl ProMax 331 8
Xylene 1330207 00016 lb/bbl ProMax 1.564 32
n-Hexane 110543 0.0431 lb/bbl ProMax 41,951 840
2,2,4-Trimethylpentane 540841 0.00003866 lb/bbl ProMax De M,nimis De Winos
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
a. rwwm
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/002
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.
�1ryh �`G2- 4/20/2020
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
COLORADO
6 nib
�erUbP v.mrm n
E&P Storage Tank Air Pollutant Emissions Notice(APEN) Addendum Form'
Company Name: Bonanza Creek Energy Operating Company,LLC
Source Name: State North Platte T-36 Production Facility(COGCC#433300)
Emissions Source AIRS ID2: 123/9BDF/002
Wells Services by this Storage Tank or Tank Battery (E&P Sites Only)
API Number Name of Well Newly Reported Well
05-123-39010 State North Platte Y44-U41-36HNC ❑
05-123-50035 Latham U41-1-12XRLNB
05-123-50036 Latham P-1-12XRLNC
05-123-50034 Latham K31-1-12XRLNB
05-123-50032 Latham K-1-12XRLNC
05-123-50033 Latham K21-1-12XRLNB
05-123-37578 State North Platte Y-U-36HC ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
Footnotes:
Attach this addendum to associated APEN form when needed to report additional wells.
If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter
N/A
Form APCD-212 APCD 212 CNDTK.docx
Produced Water Storage Tank(s) APEN
Form APCD-207
(VW 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-submittai will require payment
for a new filing fee.
This APEN is to be used for tanks that store produced water 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, condensate 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 Cont-ol 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: 14WE0187 AIRS ID Number: 123 /9BDF /003
Section 1 -Administrative Information
Company Name': Bonanza Creek Energy Operating Company, LLC
Site Name: State North Platte T-36 Production Facility(COGCC#433300)
Site Location
Site Location:
SESE, 5N, 36, 63W County: Weld
40.35036, -104.37943
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
' 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 wilt be issued by the APCD via e-mail to the address provided.
429091
'COLOPADO
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/003
Section 2 - Requested Action
❑ NEW permit OR newly-reported emission source
O Request coverage under traditional construction permit
O Request coverage under a General Permit
O GP05 O 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 O Change company name3
❑ Change permit limit ❑ Transfer of ownership' O Other(describe below)
-OR-
❑ APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
❑ APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE)
Additional Info& Notes: Requesting new throughput due to addition of new wells.
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: Produced water tank battery used to store produced water.
Company equipment Identification No. (optional): 'PWT-01
For existing sources, operation began on: 9/5/2013
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: 0 Exploration&Production(E&P)site O Midstream or Downstream (non E&P)site
Will this equipment be operated in any NAAQS nonattainment area? El Yes ❑ No
Are Flash Emissions anticipated from these storage tanks? 0 Yes O No
Are these storage tanks located at a commercial facility that accepts oil production ❑ Yes (] No
wastewater for processing?
Do these storage tanks contain less than 1%by volume crude oil on an annual average basis? ❑Q Yes ❑ No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) O 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≥6 ton/yr(per storage tank)?
�^` ,COLORADO
1 as o yak
H.ateF b£nroemm
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/003
Section 4 - Storage Tank(s) Information
Actual Annual Amount Requested Annual Permit Limits
(bbl/year) (bbl/year)
Produced Water Throughput: 486.667 584,001
From what yea, is llt<? CICtOO!arlouut arnotint? Projected 2020
Tank design: ❑r Fixed roof ❑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 TankRecent Storage Vessel in Production
(bbl) Storage Tank(month/year) (month/year)
PWT-01 Four(4)500 bbl 2,000 8/2014 9/2013
Wells Serviced by this Storage Tank or Tank Battery6(EEtP Sites Only)
API Number Name of Well Newly Reported Well
05 - 123 - 37577 State North Platte 34-31-6HNB O
05 - 123 - 39006 State North Platte 44-41-36HNB O
05 - 123 - 39008 State North Platte T34-P31-36HNC O
05 - 123 - 39007 State North Platte T44-P41-36HNC O
05 - 123 - 39009 State North Platte T-P-36HNB ❑
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 addi:ional 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)
40.35036,-104.37943
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) (OF) (ACFM) (ft/sec)
ECD 05 -35 500 TBD TBD
Indicate the direction of the stack outlet: (check one)
Q Upward ❑Downward ❑Upward with obstructing raincap
❑Horizontal ❑Other(describe):
Indicate the stack opening and size: (check one)
✓❑Circular Interior stack diameter(inches): 96
❑Square/rectangle Interior stack width(inches): Interior stack depth(inches):
❑Other(describe):
COLORADO
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/003
/003
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:
Vapor Size: Make/Model:
O Recovery
Unit(VRU): Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
Pollutants Controlled: VOC, HAPs
Rating: 3.59 MMBtu/hr
Type: Enclosed Combustor Make/Model: One(1) IES 96"
❑ Combustion Requested Control Efficiency: 98
Device:
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: 500 Waste Gas Heat Content: 1,496 Btu/scf
Constant Pilot Light: O Yes Q No Pilot Burner Rating: N/A 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 (EftP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? —65 psig
Describe the separation process between the well and the storage tanks: Oil produces to high/low pressure
separators where gas, condensate, and water are separated. Condensate, and any water left, are sent
Water is sent to the produced water storage tank battery prior to being trucked off site.
e COLO'RSDO
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Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/003
Section 8 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form7.
Is any emission control equipment or practice used to reduce emissions? E]Yes ❑No
If yes, describe the control equipment AND state the collection and control efficiencies(report the overall, or
combined, values if multiple emission control methods were identified in Section 6):
Collection Efficiency Control Efficiency
Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured
by control equipment) emissions)
VOC ECD 100 98
NOx
CO
HAPs EGO 100 98
Other:
Front what year is thE' of 'rar rep rLed u -uo/ f 1 s data?
Projected 2020
i h:Q. ER)IyS1Jl7_ £7v
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 Emissions8 Emissions Emissions
Basis Mfg.,etc.)
(tons/year) (tons/year) (tons/year) (tons/year)
VOC 0 262 Ib/bbl State Factor 63 75 1.28 76 51 1.53
NO. 0 0036 lb/6bl Stale Factor 0 88 0 88 1 05 1 05
CO 0.0166 lb/bbl State Factor 4 04 4 04 4 85 4.85
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.
7 Attach produced water 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.
Section 9 - Non-Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non-criteriaEl 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
Abstract Source Uncontrolled Controlled
Chemical Name Service(CAS) Uncontrolled Units Basis (AP-42, Emissions Emissions8
Number _ Mfg.,etc.) (lbs/year) (lbs/year)
Benzene 71432 _ 0.0070 lb/bbl State Factor 3.408 70
Toluene 108883 N/A N/A N/A N/A N/A
Ethylbenzene 100414 - N/A N/A N/A N/A N/A
Xylene 1330207 N/A N/A N/A N/A N/A
n-Hexane 110543 0.0220 lb/bbl State Factor 10,708 216
_
2,2,4-Trimethylpentane 540841 N/A N/A N/A N/A N/A
7 Attach produced water 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.
a '..COIO ti1POO
CO1O ��.
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF/003
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 GP05 or GP08, I further certify that
this source is and will be operated in
full compliance with each condition of the applicable General Permit.
� ri` C_ ✓ 2i 4/20/2020
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
Q 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
COLORADO
. - 6 Nc4�Fb Gnv+ronmen
E&P Storage Tank Air Pollutant Emissions Notice(APEN) Addendum Form'
Company Name: Bonanza Creek Energy Operating Company,LLC
Source Name: State North Platte T-36 Production Facility(COGCC#433300)
Emissions Source AIRS ID2: 123/9BDF/003
Wells Services by this Storage Tank or Tank Battery(E&P Sites Only)
API Number Name of Well Newly Reported Well
05- 123-39010 State North Platte Y44-U41-36HNC ❑
05-123-50035 Latham U41-1-12XRLNB
05-123-50036 Latham P-1-12XRLNC
05-123-50034 Latham K31-1-12XRLNB
05-123-50032 Latham K-1-12XRLNC
05-123-50033 Latham K21-1-12XRLNB
05-123-37578 State North Platte Y-U-36HC ❑
- - ❑
- - ❑
- - ❑
- - ❑
- - ❑
❑
- - ❑
Footnotes:
Attach this addendum to associated APEN form when needed to report additional wells.
2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter
N/A
Form APCD-212 APCD 212 PWT.docx
*,s Gas Venting APE - Form APCD-211
400 Air Pollutant Emission Notice (APEN) and
COPH Application for Construction Permit ` ' ,
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled
out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment
for a new filing fee.
This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events- If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD)website.
This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: 14WE0187 AIRS ID Number: 123 /9BDF /007
Section 1 - Administrative Information
Company Name: Bonanza Creek Energy Operating Company, LLC
Site Name: State North Platte T-36 Production Facility(COGCC#433300)
Site Location: SESE, 5N, 36, 63W Site Location Weld
County:
40.35036, -104.37943
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
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.
429097
C OLORADO
tenant
Nc.:n6 En.ronment
Permit Number: 1 4WE0 1 87 AIRS ID Number: 123 /9BDF/007
Section 2 - Requested Action
❑ NEW permit OR newly-reported emission source
-OR-
i
Q MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment 0 Change company name3 ❑ Add point to existing permit
El Change permit limit ❑ Transfer of ownership4 0 Other(describe below)
-OR
▪ APEN submittal for update only(Note blank APENs will not be accepted)
-ADDITIONAL PERMIT ACTIONS-
[3 Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit (PTE)
Additional Info a Notes: Requesting new throughput due to addition of new wells.
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: Twelve(12)low pressure gas/oil separators(5 from new wells)
and two (2) vapor recovery towers controlled by two (2) enclosed flares.
Company equipment Identification No. (optional): LPGFL
For existing sources, operation began on: 9/5/2013
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
Will this equipment be operated in any NAAQS
r❑ Yes ❑ No
nonattainment area?
Is this equipment located at a stationary source that is
considered a Major Source of(HAP) Emissions? ❑ Yes 0 No
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G? Yes ❑ No
!COlORAElO
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Permit Number: 14WEO 1 87 AIRS ID Number: 123 /9BDF,007
Section 4 - Process Equipment Information
El 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 Gas Venting Heating Value: 2,480 BTU/SCF
Process Parameters5: Requested: 13.08 MMSCF/year Actual: 10.90 MMSCF/year
-OR-
Liquid Throughput
Requested: bbl/year Actual: bbl/year
Process Parameters5
Molecular Weight: 43.6
VOC(Weight%) 78.4467
Benzene(Weight%) 0.2348
Vented Gas Toluene(Weight%) 0.2208
Properties: Ethylbenzene(Weight%) 0.0202
Xylene(Weight%) 0.0820
n-Hexane(Weight%) 2.0793
2,2,4-Trimethylpentane (Weight%) 0.0012
Additional Required Documentation:
0 Attach a representative gas analysis (including BTEX Et 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 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.
4OLOR ADO
HeaiUbL+.xm..men„
Permit Number: 14WE01 87 AIRS ID Number: 123 /9BDF/007
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.35036,-104.37943
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 Discharge Height Temp. Flow Rate Velocity
Stack ID No. Above Ground Level ( F) (ACFM) (ft/sec)
(Feet)
ECD 05-06 -35 500 TBD TBD
Indicate the direction of the stack outlet: (check one)
0 Upward O Downward O Upward with obstructing raincap
O Horizontal ❑ Other(describe):
Indicate the stack opening and size: (check one)
0 Circular Interior stack diameter(inches): 96
O 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:
O VRU:
Requested Control Efficiency:
VRU Downtime or Bypassed:
Pollutants Controlled: VOC, HAPs
Rating: 3.79 MMBtu/hr
Type: Enclosed Combustor Make/Model: Two(2) IES 96"
0 Combustion Requested Control Efficiency: 98
Device:
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: 500 Waste Gas Heat Content: 2,480 Btu/scf
Constant Pilot Light: O Yes ❑✓ No Pilot burner Rating: N/A MMBtu/hr
Pollutants Controlled:
❑ Other: Description:
Requested Control Efficiency:
4 �/� COLON A0O
�L`97 aa.mm,o,wwY
Permit Number: 1 4WE0 1 87 AIRS ID Number: 123 /9BDF/007
Section 7 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑No
If yes, describe the control equipment AND state the collection and control efficiencies(report the overall, or
combined, values if multiple emission control methods were identified in Section 6):
Collection Efficiency Control Efficiency
Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured •
by control equipment) emissions)
PM
SO.
NO,,
CO
VOC ECD 100 98
HAPs ECD 100 98
Other:
Projected 2020
From what year :s the tuttrywrIg reported oct001 00000c (mission:,cht,a? l
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 N►p 42' Emissions Emissions6 Emissions Emissions
Basis Mfg.,etc.)
(tons/year) (tons/year) (tons/year) (tons/year)
PM 40 0 ug/L AP-42 0 15 0 15 0 18 0 18
SO. <0.001 Ib/MMBtu AP-42 <0 001 <0.001 <0 001 <0.001
NOx 0 068 Ib/MMBtu AP-42 0 95 0 95 1 13 1.13
CO 0.310 Ib/MMBtu AP-42 4.31 4.31 5.15 5.15
VOC 90.306.85 Ib/MMscf Gas Analysis 49218 9.85 59062 11.82
5 Requested values wilt become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are rewired on all APENs,including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide
projected emissions.
Section 8 - Non-Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non-criteria Yes ❑No
pollutants(e.g. HAP - hazardous air pollutant)equal to or greater than 250 lbs/year?
If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source:
Chemical Emission Factor Actual Annual Emissions
Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled
Service(CAS) Basis Units (AP-42, Emissions Emissions6
Number Mfg.,etc.) (lbs/year) (lbs/year)
Benzene 71432 270 30 lb/MMscf Gas Analysis 2,948 60
Toluene 108883 25418 lb/MMscf Gas Analysis 2,772 56
Ethylbenzene 100414 23 25 lb/MMscf Gas Analysis 254 6
Xylene 1330207 94 40 lb/MMscf Gas Analysis 1,030 22
n-Hexane 110543 2,393 66 Itr/MMsd Gas Analysis 26,092 522
2,2,4-Trimethylpentane 540841 1.38 lb/MMscf Gas Analysis 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
Zrmrcn+=,
f
Permit Number: 14WE0187 AIRS ID Number: 123 i 9BDF i 007
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
4/20/2020
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:
❑✓ Draft permit prior to issuance
❑� Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration
of the five year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to: For more information or assistance call:
Colorado Department of Public Health and Environment Small Business Assistance Program
Air Pollution Control Division (303)692-3175
APCD-SS-B1 OR
4300 Cherry Creek Drive South (303)692.3148
Denver, CO 80246-1530
APCD Main Phone Number
Make check payable to: (303) 692-3150
Colorado Department of Public Health and Environment
j/1t COLORADO
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