HomeMy WebLinkAbout20210058.tiffatm-
COLORADO
Department of Public
Health b Environment
Weld County - Clerk to the Board
1150 O St
PO Box 758
Greeley, CO 80632
December 30, 2020
Dear Sir or Madam:
RECEIVED
JAN 0 4 2021
WELD COUNTY
COMMISSIONERS
On December 31, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for
Bonanza Creek Energy Operating LLC - Longhorn U-10 Production Facility. A copy of this public notice
and the public comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
Jared Polls, Governor I Jill Hunsaker Ryan, MPH, Executive Director
Pu b l . G 2ev e c,J
of /i3 a I
cc: P`(TP),1-CLOS /TR) PcJ(SM/PZ/GH/CK),
oGCSM)
01/07/21
2021-0058
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Bonanza Creek Energy Operating LLC - Longhorn U-10 Production Facility - Weld County
Notice Period Begins: December 31, 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: Longhorn U-10 Production Facility
Oil and Gas well production facility
NENE Section 10 T3N R63W
Weld County
The proposed project or activity is as follows: Applicant proposes to modify synthetic minor facility to
remain under the new non -attainment area major source limit of 50 tpy to remain a synthetic minor facility
The Division has determined that this permitting action is subject to public comment per Colorado
Regulation No. 3, Part B, Section III.C due to the following reason(s):
• permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section
III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area)
• 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 18WE1080 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Christopher Kester
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
1
COLORADO
Department of Public
Health B Etteitonnuere
COLORADO
Air Pollution Control Division
Department of Public Health Er Environment
Dedicated to protecting and improving the health and environment of the
Permit number:
Date issued:
Issued to:
CONSTRUCTION PERMIT
1 8W 1080 Issuance: 4
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General Description:
Bonanza Creek Energy Operating Company,
LLC
Longhorn U-10 Production Facility
123/9FFE
NENE Section 10 T3N R63W
Weld County
Well Production Facility
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
CNDTK-01
001
Three (3) 500 barrel fixed roof storage
vessels used to store condensate.
Enclosed Combustor
PWT-01
002
One (1) 500 barrel fixed roof storage
vessel used to store produced water.
Enclosed Combustor
ECD-01
003
Produced natural gas routed to enclosed
combustor
Enclosed Combustor
L-1
004
Hydrocarbon Liquid Loading
Enclosed Combustor
This permit is granted subject to all rules and regulations of the Colorado Air Quality Control
Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq),
to the specific general terms and conditions included in this document and the following
specific terms and conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen
days of the latter of commencement of operation or issuance of this permit, bar
submitting a Notice of Startup form to the Division for the equipment covered by this
permit. The Notice of Startup form may be downloaded online at
www.cotorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup
of the permitted source is a violation of Air Quality Control Commission (AQCC)
COLORADO
Air Pollution Control Division
Department of Public Health Er Environment
Page 1 of 17
Regulation Number 3, Part B, Section 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 shall
be demonstrated to the Division. It is the owner or operator's responsibility to self -
certify compliance with the conditions. Failure to demonstrate compliance within 180
days may result in revocation of the permit. A self certification form and guidance on
how to self -certify compliance as required by this permit may be obtained online at
www.colorado.ww/cdphe/air-permit-self-certification. (Regulation Number 3, Part B,
Section III .G.2. )
3. This permit shall expire if the owner or operator of the source for which this permit was
issued: (i) does not commence construction/modification or operation of this source
within 18 months after either, the date of issuance of this construction permit or the
date on which such construction or activity was scheduled to commence as set forth in
the permit application associated with this permit; (ii) discontinues construction for a
period of eighteen months or more; (iii) does not complete construction within a
reasonable time of the estimated completion date. The Division may grant extensions
of the deadline. (Regulation Number 3, Part B, Section III.F.4.)
4. The operator shall complete all initial compliance testing and sampling as required in
this permit and submit the results to the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
5. The operator shall retain the permit final authorization letter issued by the Division,
after completion of self -certification, with the most current construction permit. This
construction permit alone does not provide final authority for the operation of this
source.
EMISSION LIMITATIONS AND RECORDS
6. Emissions of air pollutants shall not exceed the following limitations. (Regulation
Number 3, Part B, Section II.A.4. )
Annual Limits:
Facility
Equipment ID
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NOX
VOC
CO
CNDTK-01
001
---
---
6.0
---
Point
PWT-01
002
---
---
0.1
---
Point
ECD-01
003
---
6.7
33.2
30.4
Point
L-1
004
---
---
0.3
---
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 shall not exceed 8.0
tons per year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per
year.
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 2 of 17
The facility -wide emissions limitation for hazardous air pollutants shall apply to all
permitted emission units at this facility.
Compliance with the annual limits, for both criteria and hazardous air pollutants, shall
be determined on a rolling twelve (12) month total. By the end of each month a new
twelve month total is calculated based on the previous twelve months' data. The permit
holder shall calculate actual emissions each month and keep a compliance record on
site or at a local field office with site responsibility for Division review.
7. The owner or operator must use the emission factors found in "Notes to Permit
Holder" to calculate emissions and show compliance with the limits. The owner or
operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified
permit prior to the use of any other method of calculating emissions.
8. The emission points in the table below shall 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
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
CNDTK-01
001
Enclosed Combustor (Make: Crimson Model:
CE1000, Serial Number: BCEI -1807)
VOC and
HAP
PWT-01
002
Enclosed Combustor (Make: Crimson Model:
CE1000, Serial Number: BCEI -1807)
VOC and
HAP
ECD-01
003
Enclosed Combustor (Make: Crimson Model:
CE1000, Serial Number: BCEI -1807)
VOC and
HAP
, L-1
004
Enclosed Combustor (Make: Crimson Model:
CE1000, Serial Number: BCEI -1807)
VOC and
HAP
PROCESS LIMITATIONS AND RECORDS
9. This source shall be limited to the following maximum processing rates as listed below.
Monthly records of the actual processing rates shall be maintained by the owner or
operator and made available to the Division for inspection upon request. (Regulation
Number 3, Part B, II.A.4.)
Process Limits
Facility
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
CNDTK-01
001
Condensate
throughput
85,775 barrels
PWT-01
002
Produced Water
throughput
31,192 barrels
ECD-01
003
Natural gas venting
135.46 MMscf
L-1
004
Condensate loaded
85,775 barrels
The owner or operator shall monitor monthly process rates based on the calendar month.
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 3 of 17
Compliance with the annual throughput limits shall be determined on a rolling twelve
(12) month total. By the end of each month a new twelve-month total is calculated
based on the previous twelve months' data. The permit holder shall calculate
throughput each month and keep a compliance record on site or at a local field office
with site responsibility, for Division review.
10. Point 003: The owner or operator shall continuously monitor and record the volumetric
flow rate of natural gas vented from this point using the flow meter. The owner or
operator shall use monthly throughput records to demonstrate compliance with the
process limits contained in this permit and to calculate emissions as described in this
permit.
11. The owner or operator must operate a flame detection system that monitors the
combustor pilot system for the presence of a pilot light flame. If a flame is not detected,
the facility will shut-in all of the wells serviced by this facility, such that the wells
cannot produce to the facility.
12. At a minimum of a weekly basis, the owner or operator must monitor the control device
for the presence of a pilot light and an operational auto -igniter. These monitoring
records shall be used to calculate control device downtime. During periods without the
presence of a pilot light and/or an operational auto -igniter, the flow volume from
emissions source(s) shall 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
13. The permit number and ten digit AIRS ID number assigned by the Division (e.g.
123/9FB9/xxx) shall be marked on the subject equipment for ease of identification.
(Regulation Number 3, Part B, Section III.E.) (State only enforceable)
14. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
15. Point 001 and 002: This source is subject to Regulation Number 7, Part D, Section I.
The operator must comply with all applicable requirements of Section I and,
specifically, must:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for storage tanks; and
• Ensure that the combustion device controlling emissions from this storage tank
be enclosed, have no visible emissions, and be designed so that an observer
can, by means of visual observation from the outside of the enclosed
combustion device, or by other means approved by the Division, determine
whether it is operating properly. (Regulation Number 7, Part D, Section I.C.)
(State only enforceable)
16. Points 001, 002, 003, and 004: 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
COLORADO
Air Pollution Control Division
Department of Public Health 6 Environment
Page 4 of 17
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.
17. Point 001 and 002: 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.
18. Point 001 and 002: 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.
19. 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.
20. Point 004: Storage tanks must operate without venting at all times during loadout.
(Regulation Number 7, Part D, Section II.C.5.a.(ii))
21. 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.
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 5 of 17
• 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.
22. Point 004: The owner or operator must perform the following observations and training
(Regulation Number 7, Part D, Section II.C.5.a.(iv)):
• The owner or operator must observe loadout to confirm that all storage tanks
operate without venting when loadout operations are active. These inspections
must occur at least monthly, unless loadout occurs less frequently, then as often
as loadout is occurring,
• If observation of loadout is not feasible, the owner or operator must document
the annual loadout frequency and the reason why observation is not feasible and
inspect the facility within 24 hours after loadout to confirm that all storage tank
thief hatches (or other access point to the tank) are closed and latched.
• The owner or operator must install signage at or near the loadout control system
that indicates which loadout control method(s) is used and the appropriate and
necessary operating procedures for that system.
• The owner or operator must develop and implement an annual training program
for employees and/or third parties conducting loadout activities subject to
Section II.C.5. that includes, at a minimum, operating procedures for each type
of loadout control system.
23. 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.
24. 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))
25. Point 003: The separator covered by this permit is subject to Regulation 7, Part D,
Section II. F. On or after August 1, 2014, gas coming off a separator, produced during
normal operation from any newly constructed, hydraulically fractured, or recompleted
oil and gas well, must either be routed to a gas gathering line or controlled from the
commencement of operation by air pollution control equipment that achieves an
COLORADO
Air Pollution Control Division
Department of Public Health Fr Environment
Page 6 of 17
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.
26. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or
operator of oil and natural gas operations and equipment at or upstream of a natural
gas processing plant in Colorado must submit a single annual report that includes actual
emissions and specified information in the Division -approved report format. The
information included in the annual report must be in accordance with the general
reporting requirements of Regulation Number 7, Part D, Section V.B. Beginning July 1,
2020, and each calendar year thereafter, owners or operators must maintain the
information according to Regulation Number 7, Part D, Section V.C. for inclusion in the
annual report. (Regulation Number 7, Part D, Section V)
OPERATING Et MAINTENANCE REQUIREMENTS
27. Upon startup of these points, the owner or operator shall follow the most recent
operating and maintenance (OftM) 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 atM 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
28. This source is not required to conduct initial testing, unless otherwise directed by the
Division or other state or federal requirement.
Periodic Testing Requirements
29. Points 001, 002, 003 and 004: On an annual basis, the owner or operator must conduct
a source compliance test to measure the mass emission rates of the pollutants listed
below, demonstrate compliance with the emissions limit in this permit, and to
demonstrate a minimum destruction efficiency of 98% for volatile organic compounds
(VOC). During the test, the owner or operator must measure:
• volumetric flow rate (scf/hr) to the inlet of the combustion device (V;);
• mass emission rates of VOC (lb/hr) at the inlet of the control device (Mvoc;)
using EPA or other division approved methods;
• mass emission rates of VOC (lb/hr) at the outlet of the control device (Mvoco)
using EPA or other division approved methods;
• mass emission rates of NOx and CO (lb/hr) at the outlet of the control device
(Mr,oX and Mco respectively) using EPA or other division approved methods.
• gas heat content; and
• gas composition.
Additionally, the following parameters may be required to be measured during the
test:
• combustion chamber temperature;
• supplemental fuel flow rate;
The destruction efficiency (DE) for VOC must be calculated using the following
equation:
• ego
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 7 of 17
DE (%) = 100* (Mvoci — Mvoco)
Mvoci
The annual emission rate (tpy) of NOx and CO (ENo. and Eco) shall be calculated using
the following equations:
(MNoxl ( 6 SCf l
E1vox = \ Vi / * (10 MMsc f l * P
(MC°l scf l
Eco — \ Vi / * (106* P
MMscf I
Where P = The permitted annual process limit(s) (MMscf/yr or bbl/yr) for each
point subject to this performance test
For any points based on a liquid throughput process limit (bbl/yr), the annual emission
rate (tpy) of NOx and CO (ENoxand Eco) shall be calculated using the following
equations:
ENox = (Mnfoxl * (GOR) * P
\viJ
Eco = (Mcol * (GOR) * P
Vi J
Where GOR = the gas -to -oil ratio (scf/bbl) as calculated in the permitting of that
point, as established in the Notes to Permit Holder section of this permit.
The sum of the annual emission rates of NOx and CO for all points subject to
performance testing, as calculated above, must be less than or equal to the following
annual emissions limits as previously stated in this permit:
Pollutant
Annual Limit (tpy)
NOx
7.1
CO
32.3
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 of the 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
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. (Regulation Number 3, Part B., Section III.G.3)
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 8 of 17
Records of the annual compliance tests must be maintained by the owner or operator
and made available to the Division for inspection upon request. Actual emissions
calculations must be completed in accordance with PS Memo 20-02. If the results of
any periodic compliance test 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.
30. Point 001: On an annual basis, the owner or operator must complete a site specific
analysis ("Analysis"), including a compositional analysis of the pre -flash pressurized
hydrocarbon liquid routed to the equipment covered in this permit. Testing must be in
accordance with the guidance contained in PS Memo 05-01. Results of the Analysis must
be used to demonstrate that the emissions factor established through the Analysis is
greater than or equal to the emissions 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
factors submitted with the permit application and established in the "Notes to Permit
-Holder" the operator must submit to the Division within 60 days, or in a timeframe as
agreed to by the Division, a request for permit modification to address these
inaccuracies.
31. Point 003: On an annual basis, the owner/operator must complete a site specific
extended gas analysis ("Analysis') of the natural gas vented from this emissions unit in
order to verify the VOC content (weight fraction) of this emission stream. Results of
the Analysis must be used to calculate site -specific emission factors for the pollutants
referenced in this permit (in units of lb/MMSCF gas vented) using Division approved
methods. Results of the Analysis must be 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).
ALTERNATIVE OPERATING SCENARIOS
32. Points 001, 002, 003 and 004: 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.
33. Points 001, 002, 003 and 004: 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
COLORADO
Air Poilution Control Division
Department of Public Health Fr Environment
Page 9 of 17
cover letter explaining that the owner or operator is exercising an Alternative
Operating Scenario and has replaced the control device.
34. Points 001, 002, 003 and 004: 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 to
measure the mass emission rates of the pollutants listed below, demonstrate compliance
with the emissions limit in this permit, and to demonstrate a minimum destruction
efficiency of 98% for volatile organic compounds (VOC). During the test, the owner or
operator must measure:
• volumetric flow rate (scf/hr) to the inlet of the combustion device (V;);
• mass emission rates of VOC (lb/hr) at the inlet of the control device (Mvoo)
using EPA or other division approved methods;
• mass emission rates of VOC (lb/hr) at the outlet of the control device (Mvoco)
using EPA or other division approved methods;
• mass emission rates of NOx and CO (lb/hr) at the outlet of the control device
(MNo. and Mco respectively) using EPA or other division approved methods.
• gas heat content; and
• gas composition.
Additionally, the following parameters may be required to be measured during the
test:
• combustion chamber temperature;
• supplemental fuel flow rate;
The destruction efficiency (DE) for VOC must be calculated using the following
equation:
DE (%) = 100 * (Mvoci — Mvoco)
Mvoci
The annual emission rate (tpy) of NOx and CO (ENo. and Eco) shall be calculated using
the following equations:
MNOx6 scf l
ENox = (-) * (10 MMscf
MC°lscfEC°—(V/*(106MMscfl * P
Where P = The permitted annual process limit(s) (MMscf/yr or bbl/yr) for each
point subject to this performance test
For any points based on a liquid throughput process limit (bbl/yr), the annual emission
rate (tpy) of NOx and CO (ENoxand Eco) shall be calculated using the following
equations:
M
ENox = (v * (GOR) * P
Vi
COLORADO
Air Pollution Control Division
Department of Public Health Fr Environment
Page 10 of 17
Eco = (Mco--)*(GOR)* P
Vi
Where GOR = the gas -to -oil ratio (scf/bbl) as calculated in the permitting of that
point, as established in the Notes to Permit Holder section of this permit.
The sum of the annual emission rates of NOx and CO for all points subject to
performance testing, as calculated above, must be less than or equal to the following
annual emissions limits as previously stated in this permit:
Pollutant
Annual Limit (tpy)
NOx
7.1
CO
32.3
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 of the 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
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. (Regulation Number 3, Part B., Section III.G.3)
Records of the initial compliance tests must be maintained by the owner or operator
for a minimum of five (5) years and made available to the Division for inspection upon
request. Actual emissions calculations must be completed in accordance with PS
Memo 20-02. If the results of the initial compliance test 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.
ADDITIONAL REQUIREMENTS
35. A revised Air Pollutant Emission Notice (APEN) shall 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
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Page 11 of 17
For volatile organic compounds (VOC) and nitrogen oxides sources (NO.) in ozone
nonattainment areas emitting less than 100 tons of VOC or NO. per year, a
change in annual actual emissions of one (1) ton per year or more or five percent,
whichever is greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of
five percent or 50 tons per year or more, whichever is less, above the level
reported on the last APEN submitted; or
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above
the level reported on the last APEN submitted to the Division.
• 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.
GENERAL TERMS AND CONDITIONS
36. This permit and any attachments must be retained and made available for inspection
upon request. The permit may be reissued to a new owner by the APCD as provided in
AQCC Regulation 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.
37. If this permit specifically states that final authorization has been granted, then the
remainder of this condition is not applicable. Otherwise, the issuance of this
construction permit does not provide "final" authority for this activity or operation of
this source. Final authorization of the permit must be secured from the APCD in writing
in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation
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.
38. This permit is issued in reliance upon the accuracy and completeness of information
supplied by the owner or operator and is conditioned upon conduct of the activity, or
construction, installation and operation of the source, in accordance with this
information and with representations made by the owner or operator or owner or
operator's agents. It is valid only for the equipment and operations or activity
specifically identified on the permit.
39. Unless specifically stated otherwise, the general and specific conditions contained in
this permit have been determined by the APCD to be necessary to assure compliance
with the provisions of Section 25-7-114.5(7)(a), C.R.S.
COLORADO
Air Pollution Control Division
Department of Public Health Et Environment
Page 12 of 17
40. Each and every condition of this permit is a material part hereof and is not severable.
Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire
permit and upon such occurrence, this permit shall be deemed denied ab initio. This
permit may be revoked at any time prior to self -certification and final authorization by
the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality
Control Act and regulations of the Air Quality Control Commission (AQCC), including
failure to meet any express term or condition of the permit. If the Division denies a
permit, conditions imposed upon a permit are contested by the owner or operator, or
the Division revokes a permit, the owner or operator of a source may request a hearing
before the AQCC for review of the Division's action.
41. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution
Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and
administration. If a source or activity is to be discontinued, the owner must notify the
Division in writing requesting a cancellation of the permit. Upon notification, annual
fee billing will terminate.
42. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution
Prevention and Control Act or the regulations of the AQCC may result in administrative,
civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121
(injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S.
By:
Christopher Kester
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 4
This Issuance
Issued to Bonanza Creek Energy Operating
Company, LLC
Updated all points - updated process limits,
and associated emission limits.
Removed Point 005
Issuance 3
January 8, 2020
Issued to Bonanza Creek Energy Operating
Company, LLC.
Addition of point 005.
Issuance 2
September 17
2019
Issued to Bonanza Creek Energy Operating
Company, LLC.
Modification of points 001and 003. Addition
of point 004 which was previously under a
G P07
Issuance 1
July 30, 2019
Issued to Bonanza Creek Energy Operating
Company, LLC.
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Page 13 of 17
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 shall 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 formmust be submitted with a
request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative
Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall
notify the Division of any malfunction condition which causes a violation of any emission
limit or limits stated in this permit as soon as possible, but no later than noon of the next
working day, followed by written notice to the Division addressing all of the criteria set
forth in Part II.E.1 of the Common Provisions Regulation. See:
https: //www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the
process limits as indicated in this permit. This information is listed to inform the operator of
the Division's analysis of the specific compounds emitted if the source(s) operate at the
permitted limitations.
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(lb/yr)
001
Benzene
71432
2,659
54
Toluene
108883
2,307
48
Ethybenzene
100414
266
6
Xylenes
1330207
669
14
n -Hexane
110543
16,623
334
002
Benzene
71432
218
4
n -Hexane
110543
686
14
003
Benzene
71432
9,060
182
Toluene
108883
14,646
294
Ethybenzene
100414
4,418
90
Xylenes
1330207
15,716
316
n -Hexane
110543
65,580
1,312
004
n -Hexane
110543
309
6
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.
COLORADO
Air Pollution Control Division
Department of Public Health 8 Environment
Page 14 of 17
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
NOx
0.0680
(lb/MMBtu)
0.0680
(lb/MMBtu)
AP -42 Ch. 13.5
CO
0.3100
(lb/MMBtu)
0.3100
(lb/MMBtu)
VOC
6.9892
0.1398
ProMax model
based on a site -
specific
pressurized
liquid sample
71432
Benzene
0.0310
0.00062
108883
Toluene
0.0269
0.00054
100414
Ethylbenzene
0.0031
0.00006
1330207
Xylene
0.0078
0.00016
110543
n -Hexane
0.1938
0.00388
Note: The controlled emissions factors for this point are based on the flare control
efficiency of 98%. The GOR to be used in emissions calculations is 50.5 scf/bbl.
Point 002:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
VOC
0.262
0.0052
Default for Weld
County
71432
Benzene
0.007
0.00014
110543
n -Hexane
0.022
0.00044
Note: The controlled emissions factors for this point are based on the flare control
efficiency of 98%. The GOR to be used in emissions calculations is 36 scf/bbl.
Point 003:
CAS #
Pollutant
Uncontrolled
Emission
Factors
(lb/MMscf)
Controlled
Emission
Factors
(lb/MMscf)
Source
NOx
0.0680
(lb/MMBtu)
0.0680
(lb/MMBtu)
AP -42 Ch. 13.5
CO
0.3100
(lb/MMBtu)
0.3100
(lb/MMBtu)
VOC
24,476.9
489.538
Mass Balance on a
site -specific gas
sample
71432
Benzene
66.9
1.338
108883
Toluene
108.1
2.162
100414
Ethylbenzene
32.6
0.652
1330207
Xylene
116.0
2.320
110543
n -Hexane
484.1
9.682
Note: The controlled emissions factors for this point are based on the flare control
efficiency of 98%.
4,4.40,7
COLORADO
Air Pollution Control Division
Department of Public Health ft Environment
Page 15 of 17
Point 004:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
VOC
0.236
0.00472
State default
emission factors
n -Hexane
0.0036
0.00072
Controlled emission factors are based on a combustor efficiency of 98%. The GOR to be
used in emissions calculations is 1.79 scf/bbl.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN)
associated with this permit is valid for a term of five years from the date it was received
by the Division. A revised APEN shall be submitted no later than 30 days before the five-
year term expires. Please refer to the most recent annual fee invoice to determine the
APEN expiration date for each emissions point associated with this permit. For any
questions regarding a specific expiration date call the Division at (303)-692-3150.
7) 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
Requirement
Status
Operating Permit
Synthetic Minor Source of: VOC, HAPs
NANSR
Synthetic Minor Source of: VOC
MACT HH
Area Source Requirements: Not Applicable
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations
can be found at the website listed below:
http://ecfr.gpoaccess.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart KKKK
NSPS
Part 60,
Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
MACT
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
COLORADO
Air Pollution Control Division
Department of Public Health 8 Environment
Page 16 of 17
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
COLORADO
Air Pollution Control Division
Department of Pub'lc Health Et Environment
Page 17 of 17
Colorado Ah. Permitting Jed:
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer:
Package #:
Received Date:
Review Start Date:
For Division Use Only
Christopher Rester
428294
3/20/202G!
12/16/2020
Section 01- Facility Information
Company Name:
County AIRS ID: ,
Plant AIRS ID:
Facility Name:
Physical
Address/Location:
County:
Type of Facility: Exploration & Production Well Pad
What industry segment? Oil & Nature, Gas Production, & Processing.
Is this facility located in a NAAQS non -attainment area? Yes
If yes, for what pollutant? Ozone (NOR & VOC}
-:Bonanza Creek Energy Operating Company LLC
9FFE
'Longhorn U-10 Production _Fa^ l
NENE quadrant of Section -,, Range CSov
Weld County
Section 02 - Emissions Units In Permit Application
Quadrant
Section
Township
Range
ENE
0
-
Leave Blank- For Division Use Only
AIRS Point 4
(Leave blank unless APCD
has already assigned)
Emissions Source Type
Equipment Name
Emissions
Control?
Permit #
(Leave blank unless
APCD has already
assigned)
Issuance
4
Self Cert
Required?
Action
Engineering
Remarks
002
Storage Tank
CNDTK-01
Yes
18'WE0843
4
Yes
Permit
Modification
Condensate
002
--
forage Tank
PWT-01
Yes
ISWE0843
4
Yes
Permit
Modification
-
PW
003
-
Separator Venting
ECD-01
Yes
c'0843
4
Yes
Permit
Modification
004
Liquid Loading :
L-1
Yes
13'VVE0843
4
Yes
Permit
Ncdification
Section 03 - Description of Project
Applicant is modifyin_ permit to stay below new non -attainment areamajor source threshold. This will be a newwnthetic minor permit under the new limit of
50tpy
Sections 04, 05 &
06 - For Division Use Only
Section 04 - Public Comment Requirements
Is Public Comment. Required?
If yes, why? Requesting Synthetic Minor Permit
Section 05 - Ambient Air Impact Analysis Requirement
Yes
`
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?
Is this stationary source a synthetic minor?
If yes, indicate programs and which pollutants: SO2
Prevention of Significant Deterioration (PSD) 0000
Title V Operating Permits (OP) ❑
Non -Attainment New Source Review (NANSR)
Is this stationary source a major source?
If yes, indicate programs and which pollutants: 502
Prevention of Significant Deterioration (PSD) ❑
Title V Operating Permits (OP) , ❑
Non -Attainment New Source Review (NANSR)
Yes
Yes
NOx
❑
❑
CO
❑
VOC
®
lA
VOC
❑
❑
❑
PM2.5
❑
❑
PM2.5
❑
❑
PM10 TSP HAPs
❑
❑ ❑
PM10 TSP HAPs
❑
000
No
NOx
❑
-❑
❑
CO
❑
❑
Tanks) Emissions Inventory
Section 01 -Administrative Information
Facility Al Rs ID:
123
County
9F.t
Plant
Point
Section 02 - Equipment Description Details
Storage Tank Liquid
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control Efficiency 96:
Limited Process Parameter
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions -Storage Tank(s)
Actual Throughput= 85,775.0Barrels (bbl) per year
Requested Permit limit Throughput=
.0 Barrels (bbl) per year
Requested Monthly Throughput= 7285.0 Barrels (bbl) per month
Potential to Emit ( PTE) Condensate Throughput =
Secondary Emissions - Combustion Device(s)
Heat content of waste gas =
Volume of waste gas emitted per BBL of liquids
produced =
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
.0.. Barrels (bbl) per year
Btu/scf
scf/bbl
Potential to Emit (PTE) heat,content of waste gas routed to combustion device =
Control Device
9986.0 MMBTU per year
9,986.0 MMBTU per year
3,986.0 MMBTU per year
Pilot Fuel Use Rate:
Pilot Fuel Gas Heating Value:
sefh
Btu/scf
0.0 MMscf/yr
OA MMBTU/yr
Section 04 - Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Emission Factors
Condensate Tank
Emission Factor Source
Pollutant
Uncontrolled Controlled
(lb/bbl) (lb/bbl)
(Condensate
Throughput)
(Condensate
Throughput)
VOC
69892
0.11VE
iee 7s
r rt ludza ff<s �:
�fic (i
_.
Benzene
0310
0530062
Toluene
C 4290
0.00 059
Ethylbenzene
- ,e31
0
Xylene
400'G
n -Hexane
917_8
f. .;„
224 TMP
0.0007 nf0-ib
Pollutant
Control Device
Emission Factor source
Uncontrolled Uncontrolled
(Ib/MMBtu) (lb/bbl)
(waste heat
combusted)
(Condensate
Throughput)
PM10
0.0075
0.6309
`r2,5)
,ZS)
FI�GP
PM2.5
0 0075
0 03--03
SOx
0.0693
NOx
0.0680
00O79
CO
6.3100 6
0.03601
Pollutant
Pilot Light Emissions
Emission Factor Source
Uncontrolled Uncontrolled
(Ib/MMBtu) (Ib/MMscf)
(Pilot Gas Heat
Combusted)
(Pilot Gas
Throughput)
d
PM2.5
=
SOK
011 ,
NOx
0.L:,"::
VOC
0
CO
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(Ibs/month)
PM10
PM2.5
SOx
NOx
VOC
CO
i .0
0.0
G.0
0.0
,.._
6.3
0.0
0.0
1,10
9-0
6.3
0.0
0.0
0.0
0.0
-.0
0.0
0.3
0.3
0.3
9.34
v--
57.7
299.7
295.7
2659.7
6.0
1013.3
1.5
.."
oActual
e._
1,5
1.5
262.9
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Emissions
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
2559._
2659.0
53.2
_..59.0
53,2
2307.3
23073
46.1
2507.3
165.9
255.9
5.3
259.9
5.3
2 of 18
K:\PA\2018\18WE1080.CP4
Storage Tankis Emissions Inventory
xviene
n -Hexane
224 TMP
669.0
569.0
13.4
332.5
6669.0
16623.2
166623.2
15623.1
60.0
60.0
1.2
60.0
3 of 18 - KAPA\2018\18WE1080.CP4
Storage T ank(s) Emissions Inventory
Section 06 - Regulatory Summary AnalYsis
Regulation 3, Parts A, B
Soufce requires a permit
Regulation 7, Part D,Section I.C,. D, E, F
Storag=_ tack is subject to Regulation 7, Part 0, Sexton I.C f
_
Regulation 7, Part D,Section l,G, C
Storage Tang ia not subject to Pagu hal. 7, Section SG
Regulation 7, Part OSection II.B, C.1, C.3
Regulation 7, Part D,Section II.C2
Regulation 7, Part D,Section II.C.4.a.(i)
Sem, i
Regulation 7, Part D,Section II.C.4.a.(ii)
o Repletion 7, Pa ,.
;, 0 -₹
Regulation 6, Part A, NSPS Subpart Kb
Regulation 6, Part A, NSPS Subpart 0000
NSPS Subpart 0000a
Not ansagh informataon
Regulation 8, Part E, MACT Subpart HH
5torags Tank is not strtafccat.,Aga. ..
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Sampling and Testing Requirements
For condensate or crude oil tanks, does the company use the state default emissions factors to
estimate emissions?
If yes, are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the
uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than.or equal to 80 tpy?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being
permitted (for produced water tanks, a pressurize liquid sample must be analyzed using flash liberation analysis)? This sample
should 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 an
older 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?
If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
•
Section 08 - Technical Analysis Notes
Emission factors have not been changed. Only adjusting process limit.
Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only)
AIRS Point #
001
Process# SCC Code
01
k,, Gof?c12i
Uncontrolled
Emissions
Pollutant Factor Comrol % Units
PM30 v._._ a lb/1,000 gallons Condensate throughput
PM2.5 G.02 0 lb/1,000 gallons Condensate throughput
SOx MEG. 0 lb/1,000 gallons Condensate throughput
NOx C.1 0 lb/1,000 gallons Condensate throughput
VOC _ usz lb/1,000 gallons Condensate throughput
CO 0 - 0 lb/1,000 gallons Condensate throughput
Benzene 327. __ lb/1,000 gallons Condensate throughput
Toluene =...4 lb/1,000 gallons Condensate throughput
Ethylbenzene 3,g7 lb/1,000 gallons Condensate throughput
Xylene __7 9C lb/1,000 gallons Condensate throughput
n -Hexane --- 38 lb/1,000 gallons Condensate throughput
224 TMP _ PS lb/1,000 gallons Condensate throughput
4 of 18 KAPA\2018\18WE1080.CP4
Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts and B -PPE. and Perk Requirements
..met. NomAtlalnmm!r:Arm
ATTAINMENT
1. Are ummrtrolledactual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A,Section(LOA..?
2. Is the construrtlan date (service daft) 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)]
3. Are total facility uncontrolled VOC emissions greater than 5 TPY,NOx greater than lO TPY or CO emissions greater than 10TPY(Regulation 3, Part B, Section 11.0.3)7
!Source Requires an APEN. Go to
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this indvidual source greater than l TPY (Regulation 3, Part A, Sertion1113.1.a)?
2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and section 2 for additional guidance on grandfather applicability)?
3. Are total facility uncontrolled VOC emissions greaterthan 2TPY, NOx greater than 5 TPY or C0 emissions greater than lO TPY(Regulation 3, Part B, Section ll.D.2)?
Colorado Regulation], Part D. Section 1.C-F8,G
1. IS this storage tank located in the 84tr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part D, Section IA.1)?
2. Is this storage tank located at oil and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gas processing plant (Regulation 7, Part D, Section IAA)?
3. Is this storage tank located at a neeral gas processing plant (Regulation 7, Part D, Section 1.G)7
4. Does thb storagetank contain condensate?
5. Does this storagetank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions (Regulation 7, part D, SeRlon I.G.2)7
6. Are uncontrolled actual emissions ofthb storage tank equal to orgreater than 2 tons per year VOC Regulation], Part D, Section l.D.3.a(6))?
I=TM 10-7.nxrc D.ScamMgi.C.-T
Part D, Section I.GS —General Requirements for Air Pallution Control Equipment —Prevention of Leakage
Part %Section I.C.2—Emission Estinatian Procedures
Part D, Section I.D—Emissions Control Requirements
Part. D, Section I.E—Monitoring
Part 0, Section I.F— Recordkeeping and Reporting
"-imbibe Tank is nor, subject to Rsjgdachas V- cu.n..o
Part 0, Section l.G.2- Emissions Control Requiremenft
Part D, Section l.C.1.a and b —General Requirements for Air Pollution Control Equipment— Prevention of Leakage
Colorado Regulation 7, Part D. Section II
1. Is this storage tank located at attansmission/storagefaciltly?
2. Is this storage tanks located at an oil and gas exploration and production operation, well production facility', natural gas comprmsar nation' or natural gas processing plant (Regulation 7, Part 0, Section !LC)?
3. Does this storage tank have a fixed roof (Regulation 7, Part D, Section II.A.20)7
4 Are uncontrolled actual emnsons of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section ll.C.1,)?
Part D, Section 11.0 — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part 0, Section II.C.1- Emissions Control and Monitoring Provisions
Part D, Section ILC.3 - Remrdkeepng Requirements
5. Does the storagetank contain only"stabllized" liquids (Regulation 7, Part 0, Section II.C.2.b)?
Part D, Section lLC.2-Capture and Monitoring for Storage Tanks fitted with Alr Pollution Control Equipment
Is the controlled storage tank located at a well production facility, natural gas compressor station,or natural gas processing plant constructed on or after May 1, 2020 or located at a facility that was modified on or after May 1, 2020, such
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 D, Section ll.C4.a.(i)?
V2s.�Y
Yes
Yes
Ida
re,t
Ga to next question
Source Requires a permit
Source Requires an APEN. Go to
Ga to next question
Source Requires a permit
Continue - You have indicated th
Continue- You have indicated th
Storage Tank Is not subject to Re
Continue - You have indicated th
Ga to the next question -You ha
Go to the next question
Source b subject to parts of Regi
'Source is subject to all provision.
Is the controlled storage tank lotted at a well production facility, natural gas compressor station, or natural gas processing plant m ructed on or Orel -January 1, 2021 ar located at a facility that was modified on or after -January 1,
7. 2021, such that an additional controlled storage vessel's constructed to receive an anticipated increase in throughput of hydracarban liquids or produced water (Regulation], Part 0, Sertion II.C4.a.(li)?
40 CFR, Part 60, Subpart Kb. Standards of Performance for Volatile Organic Liquid Storage Vessels
1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m') [M72 BBL. (40 CFR 60.110b(a))7
2. floes the storage vessel meet the following exemption in 60.1116(d)(4)?
a. Does the vessel has a design capacity less than or equal to 1,589.874m' 1-10,000 BBL) used for petroleum or condensate stored,processed, or treated prior to custody transfer' as defined In 60.111b?
3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984(40 CFR60.1106(a))?
4. Does the tank meet the definition of"storage vessel"' in 60.1116?
5. [lees the storage vessel store a"volatile organic liquid(VOIr'as defined In 60.111b?
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa (-29.7 psi) and without emissions to the atmosphere (60.110bldl(2))7;car
b. The design capacity is greater than or equal to 151 m'I-950 BBL) and stores a liquid with a maximum true vapor pressure` less than 3.5 kPa(60.110b(b))7; or -
c. The design capacity's greater than or equalto 75 M' (-472 BBL) but less than 151 m' (-950 BBL) and stares a liquid with a maximum true vapor pressure' less than 15.0 kna(60.110b(b))7
Does the storage tank meet either one of the following exemptions from control requirements:
a. The design capacity Is greaterthan or equalto. 151 m' (-950 BBL] and stares a liquid with a maximum true vapor pressure greaterthan ar equal to 35 kPa but less than 5.2 kPa?; or
b. The design capacity Is greater than or equalto 75 M' x472 BBL) but less than 151 m' (-950 BBL) and stares a liquid with a maximum true vapor pressure greater than or equal to 15.0 kPa but less than 27.6 kPa?
IStora3, Tank is not sutdennto ninsb K1;
40 CFR, Part 6D. Subpart O0OO/000Cm. Standards of Performance for Conde Oil and Natural Gas Production, Transmission and Distribution
1. Is the storage vessel located at a facility in the onshare nil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry?
2. Was this storagevessel constructed,reconstructed, or modified (see definitions. CFR, 60.2)between August 23, 2011 and September 15, 2015?
3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after September 10, 20157
4. Are potential VOC emissions' from -the Individual storage vessel greater than or equal to 6 tans per year?
5. Does the storage vessel meet the definition of"storage vessel"' per 50.5430/60.5430a?
6. Is the rtorage vessel subject to andcontrolied in accordance with requirements for storage vessels in 40 CFR Part 60 Sub art Kb or 40 CFR Part 63 Sub art HH7
(Note: N a storage vessel is previously determined to be subject to IMPS 0000/0000a due to emissions above 6 tons per year VOC anthe applicability determination date, it should remain subject to MPS 0000/0000a per
60.5365(e)(21/60.5365a(e)(2) even ifpoteMial VOC emissions drop below 6 tans nerve.)
40 CFR, Part 63, Subpart MALT HH, Oil and Gas Production Facilities
I. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria:
a. A facility that processes, upgrades or stares hydrocarbon liquids' (63.760(a)(2)); OR
b. Afacility thatprocesses, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or 6 delivered to a final end user'(63.760(a)(3))?
2. Is the tank located at a facility that is major' for HAPs?
3. Does the tank meet the definition of "storage vessel"a in 63.7617
4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"' per 63.7617
5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000?
Sea
Storage Tank is not subject to I,
Storage Tank Ls not subject NSPS
Continue -You have indicated th
Ives 'Continue- You have indicated th
Subpart A, General provisions per §63.764 (a) Table 2
463.766 - Emissions Control Standards
§63.773 -Monitoring
§63.774-Recordkeeping
§63.775 - Reporting
RACT Review
RACT review is required If Regulation 7 does not apply AND ifthe tank Is in the non -attainment area. If the tank meets both crterie, then review PACT requirements.
Disclaimer
Storage Tank is not subject MAC
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementingragulations, and Air Quality Control Commission regulations. This document is not
a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation,
or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ is implementing regulations,
and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such es"recommend,""hey,""should,"and "can,"is intended to
describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required"are intended fa 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.
Storage Tank(s) Emissions Inventor,
Section 01- Administrative Information
Facility AIRS ID:
123
County
9FFE 002
Plant Point
Section 02 - Equipment Description Details
Storage Tank Liquid
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control Efficiency %:
Limited Process Parameter
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tan(*)
Actual Throughput=
'Requested Permit Limit Throughput=
One fi) Sd0 barret
Potential to Emit (PTE) Condensate Throughput =
Secondary Emissions - Combustion Device(s)
Heat content of waste gas =
Volume of waste, gas emitted per BBL of liquids
produced =
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
5,596.0 Barrels (bbl) per year
31,192.0 Barrels (bbl) per year
92.0.. Barrels (bbl) per year
Potential to Emit (PTE) heat content of waste gas routed to'combustion device =
Control Device
Requested Monthly Throughput= 2,49.2 Barrels (bbl) per month I
839 9 MMBTU per year
1.679.9 MMBTU per year
1,679.9 MMBTU per year
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Pollutant
Produced Water Tank
Uncontrolled
Controlled
(lb/bbl)
(lb/bbl)
(Produced Water
Throughput)
(Produced Water
Throughput)
0.262D
0.0070
0MINI=INIMIMIMEM
-®
I=MEEtEIMIIMMIM=EEMMI
1.2=IIMMIEIMIN SEMI
Pollutant
Control Device
Uncontrolled
(Ib/MMBtu)
(waste heat
combusted)
Uncontrolled
(Ib/bbh
(Produced Water
Throughput)
MIIIM2MIII®
0.0075
IMEIMMMIIMM=IMIEMIE
MIIIIMMEINIMEllill .1:)343
Pollutant
Pilot Light Emissions
Uncontrolled
(Ib/MMBtu)
Uncontrolled
(lb/MMscf)
(Pilot Gas
Throughput)
(Pilot Gas Heat
Combusted)
Emission Factor Source
Emission Factor Source
Emission Factor Source
Section OS - Emissions Inventory
Criteria Pollutants
Potential m Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(Ibs/month)
PM10
PM2.5
SOx
HOx
VOC
CO
0.0
OD
-._
0.0
11
0.0
0.0
0.0
0.0
1..
0.0
0.0
0.0
0,0
C.0
0.0
0.1
0
0.0
0:06
0.1
9.7
4.1
2.0
0.0
4.1
0.1
13.9
0.3
] 1
0.1
0.25
0.3
-.
Hazardous Air Pollutants
Potential bo Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
218.3
...i9.2 -
2.2
213.3
...,
0.0
0.0
0.0
0.0
0.0
0.0
0.0
DO
0.9
0,0
7 of 18
ICAPA\2018\18W E1080. CP4
Storage Tan (s} Emissions Inventory
Xylene
n -Hexane
224 TMP
0.0
0.0
13.7
0.0
486.2
343.1
0.0
€.5
ce
686.2
0.0
0.0
t
8 of 18 KAPA\2018\18WE1080.CP4
Storage Tank(s) Emissions Inventory
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Source ra root_oermit
Regulation 7, Part D,Section I.C, D, E, F
Storage iga to Regulation 7, Part D,Section I.C-1-
Regulation 7, Part D,Section I.G, C
S_out subject to Regina -NMI 7, Section I.G
Regulation 7, Part D,Section II.B, C.1, C.3
Smrage -_ ..:,,tent to Regulation 7, Pan' D, Section II, B, C.1 8, C.3
Regulation 7, Part D;Section II.C,2
Storage h.._:ext to Regulation 7, Part D, Secton 11 C.2 "
Regulation 7, Part D,Section II.C.4.a.(i)
Storage au o o nog subject to Regulation 7, Part D, Section II.C.4.41
Regulation 7, Part D,Section ILC4.a,(ii)
_-orage: au%is not subject to Reguta to_n 7, Part D, Section II.C.4.ai ff, b - f
Regulation 6, Part A, N5PS Subpart Kb
Storage .* Is not subject to N5PS Kb
Regulation 6, Part A, NSP5 Subpart 0000
of enough information
NSP5 Subpart 0000a
ktot enough information
Regulation B, Part E, MACE Subpart HH
Froditted Water Storage tank is not subvert to MACT HH
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Samplin¢ and Testing Requirements
For condensate or crude oil tanks, does the company use the state default emissions factors t
estimate emissions?1-'ors
If yes, are the uncontrolled actual or requested emissions. for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the
uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than or equal to 80 tpy?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03,
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being
permitted (for produced water tanks, a pressurize liquid sample must be analyzed using flash liberation analysis)?This sample
should be considered representative which generally means site -specific and collected within one year ofthe application received
date. However, if the facility has not been modCed (e.g., no new wells brought on-line), then it may be appropriate to use an
older site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in P5 Memo 14-03.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08 - Technical Analysis !Rotes
Section 09 - SCC Coding and Emissions Factors (For Inventory Use 004
AIRS Point #
Process #
O1
SCC Code
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 ^z'=l. 16/1,000 gallons Produced Water throughput
PM2.5 S_?i lb/1,000 gallons Produced Water throughput
SOx P.7PFI 0 lb/1,000 gallons Produced Water throughput
NOx gatui 0 lb/1,000 gallons Produced Waterthroughput
VOC 5.24 98 lb/1,000 gallons Produced Water throughput_
CO 0.40 _ lb/1,000 gallons Produced Water throughput
Benzene 0.17 98 lb/1,000 gallons Produced Water throughput
Toluene OJO 98 lb/1,000 gallons Produced Water throughput
Ethylbenzene .riot° 98 lb/1,000 gallons Produced Water throughput
Xylene 0._? 98 lb/1,000 gallons produced Water throughput
n -Hexane 0.5d 98 lb/1,000 gallons Produced Water throughput
224 TMP 0 OD 98 lb/1,000 gallons Produced Water throughput
9 of 18 KAPA\2018\18WE1080.CP4
StorageTank Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts A and B -APEN and Permit Requirements
u.,,._n:I,e fJnn.ilt,+--3a vraa
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.I.a)? ® Source Requires an APEN. Go to
2. Produced Water Tanks have no grandfathering provisions
3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 1041, or CO emissions greater than to TPY(Regulation 3, Part B, Section ILD.3)7
I': meat „ma
NON -ATTAINMENT
1. Are uncontrolled emissionsfrom any criteria pollutants from this Individual source greater than l TPY (Regulation 3, Part A, Section ll.D.l.M7
2. Produced WaterTanks have no grandfathering provisions
3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOR greater than 5TPY or CO emissions greater than to TPY (Regulation 3, Part B, Section ll.D.2)7
Colorado Regulation 7, Part D. Section I.C-F &G
1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part D, Section I.A.1)7
2. Is this storagetanklocated at oil and gas operations that collect, store, or handle hydromrbon liquids or produced water AND that are located at or upstream of a natural gas processing plant (Regulation 7, Part D, Section IA.117
3. Is tho storage tank located at a natural gas processing plant(Regulation 7, Part 0, section l.G)? .
4. Domthis storage tank contain condensate?
5. Doesth's storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions (Regulation 7, part D, Section l.G.2)?
6. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, section l.D.3.a a))7
Part D, Section I.C.1 — General Requirements for Air Pollution Control Equipment —Prevention of Leakage
Part D, Section I.C.2—Emission Estimation Procedures
Part 0, Section 1.0 — Emissions Control Requirements
Part D, Section I.E—Monitoring
Part D, Section I.F— Recordkeeping and Reporting
xe Tarsl•is not epill:) - 7. Section ..v
Part D, Section I.G.2- Emissions Control Requirements
Part D, Section I.C.l.a and b —General Requirements for Air Pollution Control Equipment —Prevention of leakage
Colorado Regulation 7. Part O, Section II
1. Isthis storage tank located at a transmission/storage facility?
2. Is this storage tank' located at an oll and gas exploration and production operation, well production facilityz, natural gas compressor station' or natural gas processing plant (Regulation 7, Part D, Section II.C)?
3. Does this rtorage tank have a fixed roof (Regulation], Part D, Section ll.A.2017
4. Are uncontrolled actual emissions of this storage tank equal t0 or greater than 2tons per year VOC (Regulation 7, Part D, Section ll.Cl.c)7
Part D, Section11.8—Genral Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part 0, 5ection II.C.1- Emissions Control and Monitoring Provisions
Partn, Section II.c.3 - Recordkeeping Requirements
5. Doesthe storage tank contain only "stabilized" liquids (Regulation 7, Part 0, Section lLG2.6)?
Y1^r3..: «.z
Go to next question
Source Requires a permit
Source Requires an APEN. Go to
Continue - You have indicated th
Continue - You have indicated th
Storage Tank is not subject to Rc
Continue - You have indicated th
Go to the next question - You ha
Go to the next question
Source's subject to parts of Reg
Part D, Sectionll.C.2 Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
Is the controlled storage tank located at a well production facility, natural gas compressor station, or natural gas processing plant mnstmcted on or after May 1, 2020 or located at a facility that was modified on or after May 1, 2020, such
G. that an additional controlled storage vessel constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation], Part D, Section ll.C4.a(117 ac -.'.Storage Tank '¢ not subject to Re
Is the controlled storage tank located at a well production faility, natural gas compressor station, or natural gas procrosng plant constructed on or afierlanuary 1, 2021 or located at a facility that was modified an or after January 1, .�
] 2021such that an additionalt II d storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water(Regulation 7, Part D, Section llC4a.l )? ......
korats Took is not, bcri toP g»1.:
40 CFR. Part 60. Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels
1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m) ["472 BMA (40 CFR 60.110b(a))?
2 Does the storage vessel meet the following exemption in 60.1116(d)(417
a, Does the vessel has a design capacity less than or equal to 1,560674 m3("10,000 BBL] used for petroleum' or condensate stored,processed, or treated prior to custody transfer' as defined in 60.1316?
3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40CFR, 60.2) after July 23, 1984(40 CFR60.11oh(a))7
4. Doestheiank meet the definition of"storage vessel.' in 60.111b7
5. Doesthe storage vessel store a"volatile organic liquid(VOL)"'as defined In 60.111b7
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate In excess of 204.9 kPa (-29.7 psi] and without emissions to the atmosphere (60.1306(d)(2117; or
b. The design capacity is greaterchan or equalto 151 m' (^950 BBL) andstores a liquid with a maximum true vapor pressure` less than 3.5 kna (60.11ob(b))7; o
c. The design capacity is greater than or equal to 75 M' I"472 861.] but lessthan 151 m' 1-950 BBL) and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(b))?
7. Does the storage tank meet either one of the following exemptions from control requirements:
a. The design capacity is greater than or equal to 151 m'' [`950 BBL] and stares a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa7i or
b. The design capacity is greater than or equal to 75 M' [^472 BBL] but lessthan 151 m' ['950 BBL) and stares a liquid with a maximum true vapor pressure greater than or equal t015.0 kPa but less than 27.6 kPa?
'Storage Tank is nut tibia-ۥ.,,':>?b:'b
"///f;kO
VS=
Storage Tanks not subject NSPS
40 CFR, Part 60, Subpart 0000/OOOOa.Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
1. Is this storage vessel located at a facility in the onshore ail and natural gas production segment, natural gas processing segment or natural gas transmisslon and storage segment of the industry?
2. Was this storage vessel constructed reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 20157
3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR; 60.2) after September 18, 2015?
4. Are potential VOC emissions' from the Individual storage vessel greater than or equal to 6 tons per year?
5. Does this storage vessel meet the definition of"storage Vessel"' per 60.5430/60.5430a?
6 Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HI -17
[Nate: If a storage vessel Is previously determined to be subject to NSPS 0000/0000a due to emissions above 6 tons per year VOC on the applicabiity determination date, it should remain subject to NSPS 0000/0000a per
60.5365(e)(2)/60.5365a(e)(2) even if potential VOC emissions drop below 6 tans per year]
40 CFR, Part 63, Subpart MACT NFL Oil and Gas Production Facilities
1. Is the rtoragetank located at an oil and natural gas production facility that meets either of the following criteria:
a. Afacilitythat processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); Oft
b. Afacility that processes, upgrades or storm natural gas',dart° the point M which natural gas enters the natural gastransmbsion and storage source category or n delivered to a final end user' (63.760(a)(3))?
2. Is thetank located at a facility that's major' for HAPs?
3- Does the tank meet the definition of"storage vessel.' in 63.7617
4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"' per 63.7617
5. Is the tank subject to control requirements under -40 CFR Part 60, Subpart Kb or Subpart 00007
lyrr ta020polsubk, to MACY Hhi
Subpart A, General provisions per §63.764 (a) Table 2
§63.766 - Emissions Control Standards
§63.773 -Mon kering
§63.7]4-Recordkeeping
§63.775 -Reporting
RACT Review
RACT review Is required HRegulation 7 does not apply AND tithe tank is In the non -attainment area. lithe tank meets both criteria, then revlewRACT requirements.
Disclaimer
##„
Continue - You have indicated th
°minim -you have indicated th
Storage Tank is not subject MAC
This document assists operators with determining applicability of certain requirements of the Clean AirAct, its implementing regulations, end Air Quality Control Commission regulations ]his document is not
a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts end circumstances. This document does not change or substitute for any law, regulation,
r any otherlegally 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 Ad„ its implementing regulations,
and Air Quality Control Commission regulations, the language of the statute or regulation will control. The usa ofnandnendatory language such as 'recommend," "may," 'should," and "can,"is intended to
descdbe APCD interpretations and recommendations. Mandatory terminology such as "must" and'required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air
Quaffy Control Commission regulations, but this document does not establish legally binding requirements in and of itself
Separate Venting Emissions Inventory
Section 01- Administrative Information
'Facility AlRs ID:
Cou
Y
9FFE
Plant
.Mt `.
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit Description:
Emission Control Device Description: E
Requested Overall VOC & HAP Control Efficiency %:
Limited Process Parameter
Gas meter
Section 03 - Processing Rate Information for Emissions Estimates
ued combustor
Actual Throughput = MMscf per year
Requested Permit Limit Throughput =
Y5? MMscf per year
Requested Monthly Throughput= 11.5 MMscf per month
Potential to Emit (PTE) Throughput =
z35 MMsd per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
Separator Gas Heating Value:
Volume of waste gas emitted per BBL
liquids throughput:
Control Device
Pilot Fuel Use Rate:
Pilot Fuel Gas Heating Value:
sdh
Btu/sd
_.0 MMsd/yr
445.0, Btu/scf
sd/bbl
timiUlirereetver
ImmerarmeemeM
Section 04 -Emissions Factors & Methodologies
MW
Weight
Helium
CO2
N2
methane
ethane
propane
isobutane
n -butane
isopentane
n -pentane
cyclopentane
n -Hexane
cyclohexane
Other hexanes
heptanes
methylcyclohexane
224 -TM P
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
Total
VOC Wt
Ib/Ib-mol
Displacement Equation
Ex=Q•MW•Xx/C
12 of 18
K:\PA\2018\18 W E1080.CP4
Separator Venting Emissions Inventory
Pollutant
Pollutant
Separator Venting
Uncontrolled
(Ib/MMscf)
Controlled
(Ib/MMscf)
Primary Control Device
Uncontrolled
(Ib/MMBtu)
(Waste Heat
Combusted)
Uncontrolled
Ib/MMscf
(Gas Throughput)
10.7657
r' t
0.3100
Pollutant
98.2600
Emission Factor Source
Emission Factor Source
Pilot Light Emissions
Uncontrolled
(Ib/MMBtu)
(Waste Heat
Combusted)
Uncontrolled
Ib/MMscf
(Pilot Gas Throughput)
Emission Factor Source
Section OS - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(Ibs/month)
PM10
PM2.5
Sox
NOx
VOC
CO
0,7
0.7
0.7
0.7
0.7
124
0.7
0.7
0.7
0.7
0.7
124
0.1
0.1 '
0.1
0.1
0.1
10
6,7
6.7
5.7
6.7
6,7
1130
1557.8
1657.3
33.2
1557.8
33.16
5032
30.3
30.3
30.3
30.3
30.3
5154
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
)Ibs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (Ills/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224TMP
_.
9062
_._
3362
_a..
_
_ 12643
_..,
_4643
293
4416
88
4415
88
._.._.
15713
314
15713
314
;.;.6
.5575
1312
55576
1312
5.
4
1
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Part D, Section ILB, F
Regulation 7, Part D, Section 11.B.2.e
(See regulatory applicability worksheet for detailed analysis)
>6Ur<E requires a permit
source is subject to Resoles. iiur, 7, Part D, Section 41 9.2, p
The control device e,r this separator is not subject to Regulation 7, Part D, Section if.B.Le
13 of 18
KAPA\2018\18W E1080.CP4
Separator Venting Emissions inventory
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 shouldrepresent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if the facility has
not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample.
If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate
that the emission factors are less than or equal to the emissions factors established with this application.
Are facility-widepermittedemissions 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?
If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08 - Technical Analysis Notes
AIRS Point #
003
Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only)
Process # SCC Code
01 3-10-OG1 G Fklr.
Pollutant Uncontrolled Emissions Factor Control % Units
PM10
PM2.5 _
SOx -
NOx
VOC
CO 4,* 0
Benzene 6'6.9 : VISC
Toluene 108.1 .< b/M vtsCrr
Ethylbenzene 3'2.5 '?8 1=s/'aliSCF
Xylene 135.=; credR•}SCF
n -Hexane 484.1 98 f:`.If'is₹5LF
224 TMP 0.4 98 ibiNIMSCF
14 of 18 K:\PA\2018\18WE1080.CP4
Separator Venting Regulatory Analysis Worksheet
The regulatory requirements below are determined based an requested emissions.
Colorado Regulation 3 Parts A and 0 -APEN and Permit Requirements
Is .irm i5 hr tha Non-A1taInmant Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, section ll.O.l.a)?
2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section ll.D.3)?
IYou hay. indicated that source t=_`on-Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than STPY(Regulation 3, Part A, Section ll.D.S.a)7
2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than SO TPY (Regulation 3, Part B, Section ll.D.2)?
o,ca requires a permit
Colorado Regulation 7, Part 0, Section II
1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1,2014?
IScsc _ _> subject to Reguia non 7. Par i;, 5ac'tlon 11.8.2, F
Section 11.0.2— General Provisions for Air Pollution Control Equipment Used to Comply whit Section II
Section II.F- Control of emissions from well production facilities
Ahemative Emissions Control (Optional Section),
a. Is this separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed?
_.- _ _ _s.leci to Ree4;ation Z , Ss__an
Section II.B.2.e—Alternative emissions control equipment
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is
not a rule orregulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ Its implementing
regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will controll. The use of non -mandatory language such as "recommend,""may,""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 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.
Source Re
Source Re
'Source is s'
The contn
Hydrocarbon Loadout Emissions inventory
Section 01 -Administrative Information
Facility AIRS ID:
123
County
9FFE
Plant
^,u4
Point
Section 02 -Equipment Description Details
Detailed Emissions Unit
Description: . ,
Emission Control Device
Description:
Is this Loadout controlled?
Requested Overall VOC & HAP Control Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Hydrocarbon Loadout
Actual Volume Loaded .=
(Requested Permit Limit Throughput=
Potential to Emit (PTE) Volume Loaded =
;775 Barrels (bbl) per year
85,775 Barrels (bbl) per year Requested Monthly Throughput=
U5,776. Barrels (bbl) per year
7255 Barrels (bbl) per month
I
Secondary Emissions - Combustion Device(s)
Heat content of waste gas=
Actual Volume of waste gas emitted per year =
Requested Volume of waste gas emitted per year =
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
2X90 Btu/scf
15353; scf/year
_5353, scf/year
Potential to Emit (PTE) heat content of waste gas routed to combustion device =
1.79
352 MMBTll per year
352 MMBTU per year
352 MMBTU per year
Control Device
Pilot Fuel Use Rate:
Pilot Fuel Gas Heating Value:
scfh
Btu/scf
..5 MMscf/yr
0.9 MMBTU/yr
Section 04- Emissions Factors & Methodologies
Doesthe company use the state default emissions factors to estimate emissions?
Does the hydrocarbon liquid loading operation utilize submerged fill?
Pollutant
Control Device
Pollutant
Hydrocarbon Loadout
Uncontrolled
Controlled
(Ib/bbl)
(Ib/bbl)
(Volume Loaded)
0.00Er0
(Volume Loaded)
0.00E+00
Pollutant
Uncontrolled
(Ib/MMBtu)
Uncontrolled
(lb/hbl)
(waste heat combusted)
(Volume Loaded)
Pilot Light Emissions
Uncontrolled
Ilb/MMBtu)
Uncontrolled
(Ib/MMscf)
(Pilot Gas
Throughput)
(Waste Heat Combusted)
Emission Factor Source
Emission Factor Source
Emission Factor Source
16 of 18
IC:\PA\2018\18W E1080.CP4
ssions -rove or;`
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) . (tons/year)
Requested Monthly Limits
Controlled
(Ibs/month) -,
PM10
PM2.5
SOx
NOx
VOC
CO
0,00
0.00
0.00
0.00
0
5,00
0.00
0,00
0.00
G
0.00
... _
0.00
0,03
0.00
001
..3553
9.01
0311
031
2
1012
3055_
0,20
10512
0.20
y
_.05
0.05
0.05
005
0,05
�.
Hazardous Air Pollutants
Potential to Emit •
Uncontrolled
(Ibs/Year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
3J
35
_31S
5
00
.,
_
0
0
3
u
_
.,
0
4
9
G
_v_
30,9
509
0
0
.,
.0
0
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7 Part D Section ILC.S.
(See regulatory applicability wovksheet for detailed analysis)
zdat cn 7 Paf' O Section 110.5.
Section 07 - Initial and Periodic Sampling and Testing Requirements
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08 - Technical Analysis Notes
,Switching to state default emission factors. -
AIRS Point it
004
Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only)
Process It
01
SCC Code
Uncontrolled
Emissions
Pollutant Factor Control% Units
PM10 3.00 G 16/1,000 gallons transferred
PM2.5 0.00 o 16/1,000 gallons transferred
50x +2.00 0 lb/1,000 gallons transferred
NOx 0.01 lb/1,000 gallons transferred
VOC ..6 98 16/1,000 gallons transferred
CO 0,93 16/1,000 gallons. transferred
Benzene 98 lb/1,0I10 gallons transferred
Toluene 0.00 98- lb/1,000 gallons transferred
Ethylhenzene '#-'n' 93 lb/1,000 gallons transferred
Xylene 2.2G 9£ lb/1,000 gallons transferred
n -Hexane 0.93 au 16/1,000 gallons transferred
224 TMP 3.22 _„ Ih/1,000 gallons transferred
17 of 18
KAPA\2018\18VfE1080.CP4
Hydrocarbon Loadout Regulatory Analysis Worksheet
The regulatory requirements below are determined based an requested emissions and throughput.
colored° Regulation 3 Parts A and -APEN and Permit Requirements
ATTAINMENT
Are uncontrolled actual emissions from animateriapollutants from Mis individual source. greaMfithan 2 TPY (Regulation 3, Part A', Section II.N.l.a)?
2. Is the load. located at an exploration and producton site e.g., well pad) (Regulation 3, Part B, Section II.0.1.p?
3. Is the load's, operation loading less than 10,006 gallons 1238 Bats) of mule oil per day on an annual average basis?
4. stholoa'''. operation loading less than 6,7SO(ibis per year of condensate via splash fill?
the loadoutoperadon leading less than 16,300 bids per year o)condensateva submerged fill procedure?
6. Are total facility uncontrolled VOC emissions greater Man 5 TN,, NOx greater than 10TPV or Co emissions sr...ham 16T%(Regeletlon0, Part%See.. 40.3I7
NON-ATTAINMENTt
. Are uncontrolled emissions from env criteria pollutants from this individual source greater than l TPY(Regulation5 Peak section ll.O.I.a)? Cs`-'t1v'*','. Go to nortquestion.
2. Is the IoadouCbcated at. exploration and production site (e.g., well pad)(Regulation 3, Part R, Section II.O.1.p? "y"r `?%,` Go to the nod question
3.s theloadoutoperatian loading less than loco. galmns(230 BB1a) of crude ail per day on an annual average basis? ?!$ Go to nest question
Do to next question
Grata next question
T. lloadoutrequires a permit
4. s the loadout operation loading less than 6,]50 bbls per year of condensate via splash fill? -
5. Is the load. 'operation loading less Man 15,308 bids per year of condensate via submerged fill procedure?
6. Are total radii ly uncontroled VOC emissions from the greater than 2TPY,NOx. greater than 5T. or CO emissions greater Man 10TIM 3; Part0, Section ll.C.ZI?
Colorado Regulation ] Part 0 Section II.C5.
is Mis condensate storage tank hydrocarbon liquids load. located at a well production facility, nnrat gas comPressers.cinernahsral gas processing plant.
2. floes the facility have a throughput.) hydrocarbon liquids loadout M transportvehicles greater tan or quel to 5,000 barrels?
Section E.e.s.a.(i1- Compliance sheave -
Section .app- opeatiun without venting
Section s.a.86)-Loadout Equipment Operation and Maintenance
Seefion.a.(ivl-load. observations and OperamrTraining
Section5.a.(v)-Records
Section II.G5.a.dvi)-Requirements for Air Pollution Control Equipment
Disclaimer
This document assists operators with determining applicability ofcertain requirements of the Clean Air Act, its Implementing regulations, and Air quality COMmI Commissim regulations. This document is not e
tote orregulation, and the analysis it contains may not apply ba particular situation based upon the i dvduallacts and circumstances. This document dress r V change or subsNute for any law, regulation or
any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations,
and Air Qualify Control Commission regulations, the languages, the statute or regulation will control The use ofnoremandatory language such. `recommend," "may,"'shouts,. and "can,"is intended.
describe PPM interpretafioms and recommendations. Mandatoy terminology such as smust'and "ngrdred'are intended todascdbe controlling r spiremants under the farms of the Cleen Air Act a. Air
Quality Control Commission regulations, but this document hies not establish legally binding requirements in and cos itself.
) Go to next question
Source is subject to Regulation] Part 0:Section II.C5.
Condensate Storage Tank(s) APEN
Form APCD-205
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled
out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment
for a new filing fee.
This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your
emission source does not fall into this category, there may be a more specific APEN available for your source (e.g.
crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General
APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all
available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD)
website.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE /001
Section 1 - Administrative Information
COmpany Name: Bonanza Creek Energy Operating Company, LLC (BCEOC)
Site Name: Longhorn U-10 Production Facility (COGCC #450201)
Site Location:
Site Location
NENE, 3N, 10, 63W County: Weld
40.2465, -104.416044
Mailing Address:
(include zip Code) 410 17th Street, Suite 1400
Denver, CO 80202
a
NAICS or SIC Code: 1311
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.
112.1114
COLORADO
o.p.w.�x.+w wair
xruacn.s.on...,n
Permit Number: 18WE1080
AIRS ID Number:
123 /9FFE/001
Section 2 - Requested Action
❑ NEW permit OR newly -reported emission source
❑ Request coverage under traditional construction permit
❑ Request coverage under a General Permit
❑ GP01 ❑ GP08
If General Permit coverage is requested, the General Permit registration fee of $312.50 must be
submitted along with the APEN filing fee.
-OR-
❑✓ MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name3
p Change permit limit ❑ Transfer of ownership^ ❑ 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:
Updating throughput and permit limits.
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:
Company equipment Identification No. (optional):
For existing sources, operation began on:
Condensate storage tank battery used to store condensate.
CNDTK-01
07/13/2018
For new or reconstructed sources, the projected start-up date is:
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7 days/week
0 Exploration & Production (E&P) site
52
weeks/year
❑ Midstream or Downstream (non EEtP) site
Will this equipment be operated in any NAAQS nonattainment area?
p
Yes
■
No
Are Flash Emissions anticipated from these storage tanks?
p
Yes
■
No
Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day?
■
Yes
0
No
If "yes", identify the stock tank gas -to -oil ratio:
m3/ liter
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)II
805 series rules? If so, submit Form APCD-105.
Yes
No
D
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
❑
Yes
No
GI
COLORADO
ve a.wr
SW *Mir xarMa
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 001
Section 4 - Storage Tank(s) Information
Actual Annual Amount
(bbl/year)
Requested Annual Permit Limits
(bbl/year)
Condensate Throughput:
85,775
85,775
From what year is the actual annual amount?
2019
Average API gravity of sales oil: 56.3 degrees
❑ Internal floating roof
Tank design: El Fixed roof
RVP of sales oil: 9.4
❑ External floating roof
Storage
Tank ID
# of Liquid Manifold Storage
Vessels in Storage Tank
Total Volume of
Storage Tank
(bbl)
Installation Date of Most
Recent Storage Vessel in
Storage Tank (month/year)
Date of First
Production
(month/year)
CNDTK 01-03
Three (3) 500 bbl
1,500
04/2018
07/2018
Wells Serviced by this Storage Tank or Tank Battery6 (E&P Sites Only)
API Number
Name of Well
Newly Reported Well
05 - 123 - 44703
Longhorn V41-10-9XRLNB
❑
■
■
■
■
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)
40.2465, -104.416044
❑ 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
ID No.
Discharge Height Above
Ground Level (Feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
ECD-01
—35
500
TBD
TBD
Indicate the direction of the stack outlet: (check one)
Upward ❑ Downward
❑ Horizontal ❑ Other (describe):
Indicate the stack opening and size: (check one)
El Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches): 96
Interior stack width (inches):
Interior stack depth (inches):
ABIgrCOLOR/DO
Hag** FAavwr
xwm a u,n.a,.,m
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 001
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Vapor
❑ Recovery
Unit (VRU):
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
ro
❑ Combustion
Device:
Pollutants Controlled: VOC, HAPs
Rating: 1.18
MMBtu/hr
Type: Enclosed Combustor Make/Model: One (1) Crimson CE 1000
Requested Control Efficiency: 98 %
Manufacturer Guaranteed Control Efficiency: gg q
Minimum Temperature: 500
Waste Gas Heat Content:
Constant Pilot Light: Q Yes ❑ No Pilot Burner Rating:
2,304
0.04
Btu/scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
90
Section 7 - Gas/Liquids Separation Technology Information (MP Sites Only)
What is the pressure of, the final separator vessel prior to discharge to the storage tank(s)? —90
psig
Describe the separation process between the well and the storage tanks: The well produces to a
single stage 3 -phase separator where oil, gas, and water are separated out. Condensate is routed to the
condensate tanks before being trucked off site.
®COLORADO
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 001
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? 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):
Pollutant
Control Equipment Description
Collection Efficiency
(% of total emissions captured
by control equipment)
Control Efficiency
(% reduction of captured
emissions)
VOC
ECD
100
98
NOx
CO
HAPs
ECD
100
98
Other:
From what year is the following reported actual annual emissions data? 2019
Use the following table to report the criteria pollutant emissions from source:
Pollutant
Emission Factor?
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP 42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions8
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
VOC
6.9892
lb/bbl
Permit#18wE1080
299.75
6.00
299.75
6.00
NOx
0.068
Ib/MMBtu
AP -42
0.36
0.36
0.36
0.36
CO
0 310
Ib/MMBtu
AP -42
1.61
1.61
1 61
1.61
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
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 -criteria
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 Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor?
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(lbs/year)
Controlled
Emissionse
(ibs/year)
Benzene
71432
0.0310
lb/bbl
Permit #18W61080
2,669
54
Toluene
108883
0.0269
Ib/bbl
Permit #18WE1080
2.307
48
Ethylbenzene
100414
0.0031
lb/bbl
Permt#18WE1080
266
6
Xylene
1330207
0.0078
lb/bbl
Permit#18N/E1080
669
14
n -Hexane
110543
0.1938
lb/bbl
Permit#18WE1080
16,623
- 334
2,2,4-Trimethylpentane
540841
0.0007
lb/bbl
Permit#18N1E1080
De Mmimis
De Mlnimis
Yes ❑ No
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.
E Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
COLORADO
AWAle‘M# n.a� maamn �m�
Permit Number: 18WE 1080
AIRS ID Number: 123 / 9FFE / 001
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.
3/19/2020
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
0 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
registration fee of $312.50, if applicable, to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303)692-3175
OR
(303) 692-3148
APCD Main Phone Number
(303) 692-3150
COLORADO
of Pul..
w.au e.
Produced Water Storage Tank(s) APEN
Form APCD-207
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled
out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment
for a new filing fee.
This APEN is to be used for tanks that store 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-2OO) 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: 18WE1080
AIRS ID Number: 123 / 9FFE /002
Section 1 - Administrative Information
Company Name: Bonanza Creek Energy Operating Company, LLC (BCEOC)
Site Name: Longhorn U-10 Production Facility (COGCC #450201)
Site Location: NENE, 3N, 10, 63W
40.2465, -104.416044
Mailing Address:
(Include zip code) 410 17th Street, Suite 1400
Denver, CO 80202
0
Site Location
County: Weld
NAICS or SIC Code: 1311
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.
427775
GC
COLOR100
Devon... Pub.
Da.* Enneanmme
Permit Number: 1 8WE 1 080
AIRS ID Number: 123 / 9FFE / 002
Section 2 - Requested Action
❑ NEW permit OR newly -reported emission source
❑ Request coverage under traditional construction permit
❑ Request coverage under a General Permit
❑ GP05 ❑ GP08
If General Permit coverage is requested, the General Permit registration fee of 5312.50 must be
submitted along with the APEN filing fee.
- OR
Q MODIFICATION to existing permit (check each box below that applies)
❑ Change in equipment ❑ Change company name3
Ej Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes: Updating throughput and permit limits.
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:
Company equipment Identification No. (optional):
For existing sources, operation began on:
Produced water tank battery used to store produced water.
07/13/2018
For new or reconstructed sources, the projected start-up date is:
Normal Hours of Source Operation: 24
hours/day 7 days/week
Storage tank(s) located at: Exploration & Production (E&P) site
52
weeks/year
❑ Midstream or Downstream (non E&P) site
Will this equipment be operated in any NAAQS nonattainment area?
•
Yes
■
No
Are Flash Emissions anticipated from these storage tanks?
IS
Yes
■
No
Are these storage tanks located at a commercial facility that accepts oil production
wastewater for processing?
Yes
No
■
p
Do these storage tanks contain less than 1% by volume crude oil on an annual average basis?
❑r
Yes
■
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
■
p
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
■
p
6
COLORADO
Oeperttranl b Public
Haa1U 6 [nngnnm.
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 002
Section 4 - Storage Tank(s) Information
Produced Water Throughput:
Actual Annual Amount
(bbl/year)
15,596
Requested Annual Permit Limits
(bbllyear)
31,192
From what year is the actual annual amount?
Tank design:❑ Fixed roof
2019
❑ Internal floating roof
❑ External floating roof
Storage
Tank ID
# of Liquid Manifold Storage
Vessels in Storage Tank
Total Volume of
Storage Tank
(bbl)
Installation Date of Most
Recent Storage Vessel in
Storage Tank (month/year)
Date of First
Production
(month/year)
PWT-01
One (1) 500 bbl
500
04/2018
07/2018
Wells Serviced by this Storage Tank or Tank Battery6 (El}P Sites Only)
API Number
Name of Well
Newly Reported Well
05 - 123 - 44703
Longhorn V41-10-9XRLNB
■
■
■
■
■
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 EEO' 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/Lonyitude or UTM)
40.2465,-104.416044
❑ 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
ID No.
Discharge Height Above
Ground Level (Feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
ECD-01
—35
500
TBD
TBD
Indicate the direction of the stack outlet: (check one)
Q Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
❑ Upward with obstructing raincap
Indicate the stack opening and size: (check one)
✓❑ Circular Interior stack diameter (inches): 96
❑ Square/rectangle Interior stack width (inches):
❑ Other (describe):
Interior stack depth (inches):
se COLORADO
`
N�Md Ni �'iem.rN
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 002
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Vapor
❑ Recovery
Unit (VRU):
Pollutants Controlled:
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented):
❑ Combustion.
Device:
Pollutants Controlled: VOC, HAPs
Rating: 0.19
Type: Enclosed Combustor
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature: 500
MMBtu/hr
Make/Model:
98
99
%
One (1) Crimson CE 1000
Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes 0 No Pilot Burner Rating:
1,496
N/A
Btu / scf
MMBtu / hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
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)? ^-90
psig
Describe the separation process between the well and the storage tanks: The well produces to a
single stage 3 -phase separator where oil, gas, and water are separated out. Produced water is routed to the
produced water tank before being trucked off site.
COLORADO
thpa.• ille. d n
Hamr
U � Lnneenmmt
Permit Number: 18WE 1080
AIRS ID Number: 123 / 9FFE / 002
Section 8 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form'.
Is any emission control equipment or practice used to reduce emissions? ✓t] 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):
Pollutant
Control Equipment Description
Collection Efficiency
(% of total emissions captured
by control equipment)
Control Efficiency
(% reduction of captured
emissions)
VOC
ECD
100
98
NOx
CO
HAPs
ECD
100
98
Other:
From what year is the following reported actual annual emissions data? 2019
Use the following table to report the criteria pollutant emissions from source:
Pollutant
Emission Factor'
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
('4P 42,
Mfg-, etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions$
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
VOC
0.262
lb/bbl
State EF
2.04
0.04
4.09
0.08
NOx
0.00366
lb/bbl
State EF
0.03
0.03
0.06
0.06
CO
0.0167
lb/bbl
State EF
0.13
0.13
0 26
0.26
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.
' 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 -criteria
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 Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor'
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
Os/year)(ibs/year)
Controlled
Emissionse
Benzene
71432
0.0070
lb/bbl
State EF
De Minimis
De Minimis
Toluene
108883
NIA
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
Ib/bbl
State EF
344
7
2,2,4-Trimethylpentane
540841
N/A
N/A
N/A
N/A
N/A
Yes ❑ No
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.
g COLORADO
NWN62nn.mwM
Permit Number: 18WE 10$0
AIRS ID Number: 123 / 9FFE / 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 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.
3/19/2020
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
ID 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
registration fee of $312.50, if applicable, to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303)692-3175
OR
(303) 692-3148
APCD Main Phone Number
(303) 692-3150
ink ,COLORADO
V6Gnranrnene
Gas Venting APEN - Form APCD-211
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled
out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment
for a new filing fee.
This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, btowdown 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: 1 8WE1080
Oa 3
AIRS ID Number: 123 / 9FFE /.904 -
Section 1 - Administrative Information
Company Name: Bonanza Creek Energy Operating Company, LLC (BCEOC)
Site Name: Longhorn U-10 Production Facility (COGCC #450201)
Site Location: NENE, 3N, 10, 63W
40.2465, -104.416044
Mailing Address: 410 17th Street Suite 1400
(Include Zip Code)
Denver, CO 80202
/to
Site Location
County: Weld
NAICS or SIC Code: 1311
Contact Person:
Phone Number:
E Mail Address2:
Alisson Soehner
(303) 803-1752
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.
427777
geCOLORADO
Montt 6Department nr nwk.
N6/N 6 Enri�w,meN
Permit Number: 18WE 1080
AIRS ID Number: 123 / 9FFE /Dee'
Section 2 - Requested Action
❑ NEW permit OR newly -reported emission source
-OR -
O MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
0 Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
OR -
▪ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
Updating throughput and permit limits.
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: Process flare
Company equipment Identification No. (optional):
For existing sources, operation began on:
ECD-01
07/13/2018
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: hours/day
Will this equipment be operated in any NAAQS
nonattainment area?
Is this equipment located at a stationary source that is
considered a Major Source of (HAP) Emissions?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
days/week weeks/year
0 Yes
❑ Yes
E3 Yes
❑ No
0 No
❑ No
COLOR•DO
o.n.mnm a wex<
Mu.6 fn-rantmnt
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE /.(0"4
Section 4 - Process Equipment Information
El Gas/Liquid Separator
❑ Well Head Casing
❑ Pneumatic Pump
Make: Model:
❑ Compressor Rod Packing
Make: Model:
❑ Blowdown Events
# of Events/year:
❑ Other
Description:
Serial #:
# of Pistons:
Volume per event:
Capacity: gal/min
Leak Rate: Scf/hr/pist
MMscf/event
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/tiquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? Yes
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑ No
Vent Gas
1445
BTU/SCF
Heating Value:
,
Requested:
135,46
MMSCF/year
Actual:
135.46
MMSCF/year
-OR-
Requested:
bbl/year
Actual:
bbl /year
Molecular Weight:
25.4
VOC (weight %)
36.5658
Benzene (weight %)
0.0999
Toluene (weight %)
0.1615
Ethylbenzene (weight %)
0,0487
Xylene (weight %)
0.1733
n -Hexane (weight %)
0.7232
2,2,4-Trimethylpentane (weight %)
0.0006
Additional Required Documentation:
❑r 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.
goCOLORADO
x+r w
El Upward
❑ Horizontal
Permit Number: 18WE1080
AIRS ID Number: 123 /9FFEt20-4
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.2465, -104.416044
❑ 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.
{i er3ter
Disc#targe Heigf�t
Above GrourW ,i rtel
Ted.
flow Rate
Velocit
ECD-01
-35
500
TBD
TBD
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
❑ Upward with obstructing raincap
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):
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑ VRU:
Pollutants Controlled:
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed: %
❑ Combustion
Device:
Pollutants Controlled: VOC, HAPS -
Rating: 22.35
MMBtu/hr
Type: Enclosed Combustor Make/Model: One (1) Crimson CE 1000
Requested Control Efficiency: 98 %
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: 500 Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes El No Pilot burner Rating:
1,445
N/A
Btu/scf
MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
:Cola Ri►DO
DeparemtW mmK a.ma
f4W.6Yl,Enr� .meN
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 00-4""
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? ID 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):
Pollutant
Control Equipment Description
Collection Efficiency
(% of total emissions captured
by control equipment)
Control Efficiency
(% reduction of captured
emissions)
PM
SOX
NO.
CO
VOC
ECD
100
98
HAPs
ECD
100
98
Other:
From what year is the following reported actual annual emissions data?
2019
Use the following table to report the criteria pollutant emissions from source:
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Pollutant
Source
Uncontrolled
Controlled
Uncontrolled
Controlled
Uncontrolled
Basis
Units
( 2,
Mfg., etc.)
Emissions
(tons/ye ar)
Emissions6
(tons/year)
Emissions
(tons/year)
Emissions
(tans year)
PM
7.6
Ib/MMsd
AP -42
0.52
0.52
0.52
0.52
SOX
<0.001
Ib/MMBtu
AP -42
<0601
<0.001
<0.001
<0.001
NO.
0.068
Ib/MMBtu
AP -42
666
6.66
6.66
6.68
CO
0.310
Ib/MMBtu
AP -42
30.35
30.35
30.35
30.35
VOC
24.476.9
IblMMscf
Permit #18WE1080
1.657.88
33 16
1 657.88
33.16
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
Section 8 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
❑✓ Yes ❑ No
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
Mfg etc.) 42,
Uncontrolled
Emissions
Controlled
Emissionsb
(1bs/year)
Benzene
71432
66.9
Ib/MMscf
Perrnit 818WE 1080
9.060
182
Toluene
108883
108.1
lb/MSAsef
Permit 018WE1080
14646
294
Ethylbenzene
100414
32.6
IIMMMscf
Permit#18WE1080
4,418
90
Xylene
1330207
116.0
Itt/SAMscf
Permit #181/4E1080
15716
316
n -Hexane
110543
484.1
lb/MMscf
Permit#18WE1080
65.580
1.312
2,2,4-Trimethylpentane
540841
0.4
IbiMMscf
Permit#18WE1080
. 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
HeHA 6 E„n,amrnt
Permit Number: 18WE1080
AIRS ID Number:
123 / 9FFE i
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
3/19/2020
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
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303)692-3175
OR
(303) 692-3148
APCD Main Phone Number
Make check payable to: (303) 692-3150
Colorado Department of Public Health and Environment
COLORADO
.ne
ttm h elIanwr
HkitiWN6tn-v�srt»wu
Hydrocarbon Liquid Loading APEN
Form APCD-208
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled
out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment
for a new filing fee.
This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category,
there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit,
condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN
options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution
Control Division (APCD) website.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE /004
Section 1 - Administrative Information
COrripany Namet: Bonanza Creek Energy Operating Company, LLC (BCEOC)
Site Name: Longhorn U-10 Production Facility (COGCC #450201)
Site Location: NENE, 3N, 10, 63W
40.2465, -104.416044
Mailing Address:
(Include Zip code) 410 17th Street, Suite 1400
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 1311
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 wilt appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
427776
seCOLORADO
o.u.m�.oiawmK
Nae1M 6 En�nemme,u
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 004
Section 2 - Requested Action
❑ NEW permit OR newly -reported emission source
❑ Request coverage under construction permit
❑ Request coverage under General Permit GP07
If General Permit coverage is requested, the General Permit registration fee of 5312.50 must be
submitted along with the APEN filing fee.
-OR-
• MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3
Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
- OR
▪ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Ft Notes: Updating throughput and permit limits.
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Truck loadout used t0 load condensate off site.
Company equipment Identification No. (optional): L-1
For existing sources, operation began on:
07/13/2018
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
Q
Yes
❑
No
Is this equipment located at a stationary source that is considered a Major Source of (HAP)
emissions?
❑
Yes
No
p
Does this source load gasoline into transport vehicles?
Yes
No
■
p
Is this source located at an oil and gas exploration and production site?
a
Yes
No
■
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual
average?
Yes
No
O
■
Does this source splash fill less than 6,750 bbl of condensate per year?
Yes
No
p
■
Does this source submerge fill less than 16,308 bbl of condensate per year?
❑
Yes
No
IS
i.., COLOR ADO
Department . Pun.
xru. at ca.+.a.m..m
Permit Number: 18WE1080
AIRS ID Number: 123 / 9FFE / 004
Section 4 - Process Equipment Information
Product Loaded: Condensate
❑ Crude Oil ❑ Other:
If this APEN is being filed for vapors displaced from cargo carrier, complete the following:
Requested Volume Loaded5: 85,775
bbl/year
Actual Volume Loaded:
This product is loaded from tanks at this faci ity into: Tank Trucks
(e.g. "rail tank cars" or "tank trucks")
85,775
bbl /year
If site specific emission factor is used to calculate emissions, complete the following:
Saturation Factor:
N/A
Average temperature of
bulk liquid loading:
A, , A
I V bk
F
True Vapor Pressure:
N/A
Psia @ 60 F
Molecular weight of
displaced vapors:
Nr'A
lb/lb-mol
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume Loaded5:
bbl/year
Actual Volume Loaded:
bbl/year
Product Density:
lb/ft'
Load Line Volume:
ft'/truckload
Vapor Recovery Line Volume:
ft'/truckload
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.2465, -104.416044
❑ 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 ID Ho.
Discharge Height Above
Ground Level (Feet)
Temp.
rF)
Flow Rate
WM)
Velodty
fftlsec)
ECD-01
—35
500
TBD
TBD
Indicate the direction of the stack outlet: (check one)
❑r Upward ❑ Downward
❑ Horizontal ❑ Other (describe):
Indicate the stack opening and size: (check one)
Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches): 96
Interior stack width (inches): Interior stack depth (inches):
COLORADO
n a wnr
Permit Number: 18WE1080
AIRS ID Number:
123 /9FFE/004
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Ej Loading occurs using a vapor balance system:
Requested Control Efficiency: 100 %
❑ Combustion
Device:
Used for control of: VOC. HAPs
Rating: 0.04
Type: Enciosed Combustor
MMBtu/hr
Make/Model: One (1) Crimson CE 1000
Requested Control Efficiency: 98
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: 500 F Waste Gas Heat Content: 2,290 Btu/scf
Constant Pilot Light: ❑ Yes 0 No Pilot Burner Rating: N/A MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Section 7 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑✓ 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):
Pollutant
Control Equipment Description
Collection Efficiency
(% of total emissions captured
by control equipment)
Control Efficiency
(% reduction of captured
emissions)
PM
SO„
NO„
CO
VOC
ECD
100
98
HAPs
ECD
100
98
Other:
El Using State Emission Factors (Required for GP07) VOC Benzene n -Hexane
Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL
❑ Crude 0.104 Lbs/BBL 0.0001& Lbs/BBL 0.0016 Lbs/BBL
From what year is the following reported actual annual emissions data? 2019
Use the following table to report the criteria pollutant emissions from source:
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(M-42, •
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tans/year)
PM
40.0
ug/L
AP -42
0.002
0.002
0.002
0.002
Sox
0.00025
Ib/MMBtu
AP -42
<0.001
<0.001
<0.001
<0-001
NOx
0.068
Ib/MMBtu
AP -42
0.012
0.012
0.012
0.012
CO
0-310
Ib/MMBtu
AP -42
0.06
0.06
0.06
0.06
VOC
0.236
lb/bbl
State EF
10.12
0.21
10.12
0.21
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
COLORADO
Permit Number: 18WE1080
AIRS ID Number:
123 /9FFE/004
Section 8 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
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 Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
fibs/year)
Controlled
Emissions6
Ohs/year)
Benzene
71432
0.00041
Ib/bbl
State EF
De Minimis
De Minimis
Toluene
108883
N/A
N/A
N/A
WA
N/A
Ethylbenzene
100414
N/A
N/A
N/A
N/A
NIA
Xylene
1330207
N/A
N/A
N/A
N/A
N/A
n -Hexane
110543
0.0036
tb/bbl
State EF
309
7
2,2,4-Trimethylpentane
540841
N/A
N/A
N/A
N/A
N/A
Other:
Yes ❑ No
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source
is and v, lition of General Permit GP07.
3/19/2020
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:
✓E 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
registration fee of $312.50, if applicable, to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303)692-3175
OR
(303) 692-3148
APCD Main Phone Number
(303) 692-3150
COLORADO
Amer
N WU 6 N�xmmmt
Hello