HomeMy WebLinkAbout20210479.tiffCOLORADO
Department of public
Health b Environment
Weld County - Clerk to the Board
1150 0 St,
PO Box 758
Greeley, CO 80632
January 25, 2021
Dear Sir or Madam:
RECEIVED
FEB 16 2021
WELD COUNTY
COMMISSIONERS
On January 26, 2021, the Air Pollution Control Division will begin a 30 -day public notice period for
Platte River Midstream, Inc - Lucerne West Station. A copy of this public notice and the public
comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health £t Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
Jared Polls, Governor I Jill Hunsaker Ryan, MPH, Executive Director
Pubt:C Rev,eLi
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2021-0479
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Platte River Midstream, Inc - Lucerne West Station - Weld County
Notice Period Begins: January 26, 2021
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: Platte River Midstream, Inc
Facility: Lucerne West Station
Existing condensate and crude oil storage and transport facility
Section 27, Range 65W, Township 6N
Weld County
The proposed project or activity is as follows: Source is lowering permitted emissions for existing internal
floating roof tanks, as well as adding a new loadout of condensate to trucks emissions point. Source will
remain synthetic minor in the new serious non -attainment area
The Division has determined that this permitting action is subject to public comment per Colorado
Regulation No. 3, Part B, Section III.C due to the following reason(s):
• the source is requesting a federally enforceable limit on the potential to emit in order to avoid other
requirements
The Division has made a preliminary determination of approval of the application.
A copy of the application, the Division's analysis, and a draft of Construction Permit 15WE1427 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.Rov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Christian Lesniak
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
Department of Public
Health 6 Environment
Permit number:
Date issued:
Issued to:
Construction Permit
Air Pollution Control Division
15WE 1427
Issuance: 4
Platte River Midstream, Inc
Facility Name: Lucerne West Station
Plant AIRS ID: 123-9E0F
Physical Location: Section 27, Range 65W, Township 6N
County: Weld County
General Description: Crude oil and condensate storage and transport facility
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
T-101 thru
T-120
001
Ten (10) 1,000 BBL internal floating roof
tanks used to store crude oil and
condensate.
Internal Floating Roof
Fugitives
003
Equipment leaks (fugitive VOCs) from a
crude oil/condensate storage and transport
facility.
LDAR as per Reg. 7,
Section XVII.F
T-1501
through
T-1504
005
Four (4) 150,000 barrel internal floating
roof storage vessels connected via liquid
manifold, used to store crude oil and
condensate. Total storage capacity: 600,000
bbl.
Internal Floating Roof
Loadout
006
Truck Loadout of Condensate and Crude Oil
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 (Division) no later than fifteen
days after commencement of operation under this permit by submitting a Notice of
Startup (NOS) form to the Division. The Notice of Startup (NOS) form may be
downloaded online at https://www.colorado.gov/pacific/cdphe/air/manage-permit.
St-ordse Tank Version Syn M o 2017-1
Page 1 of 17
Failure to notify the Division of startup of the permitted source is a violation of AQCC
Regulation Number 3, Part B, III.G.1 and can result in the revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit must be
demonstrated to the Division. It is the owner or operator's responsibility to self -certify
compliance with the conditions. Failure to demonstrate compliance within 180 days may result
in revocation of the permit. A self certification form and guidance on how to self -certify
compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-
permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.)
3. This permit must expire if the owner or operator of the source for which this permit was
issued: (i) does not commence construction/modification or operation of this source within 18
months after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit; (ii) discontinues construction for period of eighteen months or
more; (iii) does not complete construction within a reasonable time of the estimated
completion date. The Division may grant extensions of the deadline. (Regulation Number 3,
Part B, Section III.F.4.)
4. The operator must complete all initial compliance testing and sampling as required in this
permit and submit the results to the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
5. The operator must retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part
B, Section II.A.4.)
Monthly Limits:
Facility
Equipment ID
AIRS
Point
Pounds per Month
Emission
Type
PM2.5
NO,
VOC
CO
T-101 thru T-
120
001
---
---
2,313
---
Point
Fugitives
003
---
---
51
---
Fugitive
T-1501 through
T-1504
005
---
---
4,843
---
Point
Loadout
006
---
---
1,277
---
Point
Note: Monthly limits are based on a 31 -day month.
The owner or operator shall calculate monthly emissions based on the calendar month.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds
per month.
Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per
month.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
COLORADO
Air Pollution Control Division
Page 2 of 17
Annual Limits:
Facility
Equipment ID
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NO.
VOC
CO
T-101 thru T-
120
001
---
---
13.6
---
Point
Fugitives
003
---
---
0.3
---
Fugitive
T-1501 through
T-1504
005
---
---
28.5
---
Point
Loadout
006
---
---
7.5
---
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.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
During the first twelve (12) months of operation, compliance with both the monthly and annual
emission limitations is required. After the first twelve (12) months of operation, compliance with
only the annual limitation is required.
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 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
T-101 thru T-
120
001
Internal Floating Roof
(Reference: 40 C.F.R Part 60.5395(d)(1))
VOC and HAP
T-1501 through
T-1504
005
Internal Floating Roof
(Reference: 40 C.F.R Part 60.112b(a)(1))
VOC and HAP
!COLORADO
j Air Pollution Control Division
1.`epertnntrt of lea4h Er E,krowne^t
Page 3 of 17
8. The emission points in the table below shall be operated and maintained with the emissions
control programs 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
Fugitives
003
LDAR as per Reg. 7, Part B, Section II.E
VOC and HAP
Loadout
006
Enclosed Combustor
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
Monthly Limit
(31 days)
T-101 thru T-
120
001
Total Condensate and
Crude Oil throughput
7,300,000 barrels
620,000 barrels
Fugitives
003
---
---
---
T-1501
through
T-1504
005
Total Condensate and
Crude Oil throughput
85,200,000
barrels
7,236,164 barrels
Loadout
006
Total Condensate and
Crude Oil throughput
loaded
1,460,000 barrels
124,000 barrels
The owner or operator shall monitor monthly process rates based on the calendar month.
During the first twelve (12) months of operation, compliance with both the monthly and annual
throughput limitations is required. After the first twelve (12) months of operation, compliance
with onlythe annual limitation is required.
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 001: The internal roof storage tanks represented by this AIRS Point shall be granted a total
of 10 roof landing events per year.
11. Point 005: The internal roof storage tanks represented by this AIRS Point shall be granted a total
of 4 roof landing events per year.
12. Point 003: The operator shall calculate actual emissions from this emissions point based on
representative component counts for the facility with the most recent gas analysis, as required
in the Compliance Testing and Sampling section of this permit. The operator shall maintain
records of the results of component counts and sampling events used to calculate actual
emissions and the dates that these counts and events were completed. These records shall be
provided to the Division upon request.
llution Control Division
Page 4 of 17
STATE AND FEDERAL REGULATORY REQUIREMENTS
13. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the
source. During periods of startup, process modification, or adjustment of control equipment
visible emissions shall not exceed 30% opacity for more than six minutes in any sixty
consecutive minutes. (Regulation Number 1, Section II.A.1. It 4.)
14. No owner or operator of a smokeless flare or other flare for the combustion of waste gases
shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%
opacity for a period or periods aggregating more than six minutes in any sixty consecutive
minutes. (Regulation Number 1, Section II.A.5.)
15. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001)
shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part
B, Section III.E.) (State only enforceable)
16. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable)
17. This source is located in an ozone non -attainment or attainment -maintenance area and is subject
to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3,
Part B, III.D.2.a.
Point 001: This requirement is fulfilled by the source following the provisions of NSPS 0000.
Point 003: The owner or operator shall comply with a Leak Detection and Repair (LDAR)
program matching the requirements for the LDAR program contained in Regulation 7, Part B,
Section II.E. (Reference: Regulation 3, Part B, III.E)
Point 005: This requirement is fulfilled by the source following the provisions of NSPS Kb.
Point 006: Loadout shall occur by submerged fill at all times and emissions during loadout
shall be routed to an enclosed combustor or thermal oxidizer.
18. Points 001, 005: 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.
19. Points 001, 005: This source is subject to the applicable requirements of Regulation Number 7,
Part B, Section IV.B.2.
20. Point 001: This source is subject to the New Source Performance Standards, Standards of
Performance for Crude Oil and Natural Gas Production, Transmission and Distribution, Subpart
0000. This facility shall be subject to all provisions of this regulation, as stated in 40 C.F.R
Part 60, Subparts A and 0000. These requirements include, but are not limited to the
requirements of 40 C.F.R Part 60.112b(a)(1) and the relevant monitoring, inspection,
recordkeeping, and reporting requirements in 40 C.F.R. Part 60, Subpart Kb. (Regulation
Number 6, Part A, Subparts A and 0000)
21. Point 003: Fugitive component leaks at this facility are subject to the Leak Detection and
Repair (LDAR) program requirements, including but not limited to: monitoring, repair, re -
monitoring, recordkeeping and reporting contained in Regulation 7, Part B, Section II.E. In
addition, the operator shall comply with the General Provisions contained in Regulation 7, Part
B, Section 11.6.1. (Reference: Regulation 3, Part B, III.D.2.a Et III.E)
22. Point 003: Minor sources in designated nonattainment or attainment/maintenance areas that
are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply
Reasonably Available Control Technology (RACT) for the pollutants for which the area is
nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This
ICOLORADO
Air Pollution Control Division
Page 5 of 17
requirement to apply RACT shall be satisfied by installing/implementing the following emission
controls:
a. Directed Inspection a Maintenance as described below shall satisfy the requirement to
apply RACT.
i. For leak screening:
(a.) An auditory/visual/olfactory inspection (AVO) will be performed on a
monthly basis.
(b.) An IR camera inspection or Method 21 monitoring shall be conducted
on an annual basis.
ii. Any detectable leaks found in an AVO or IR Camera inspection shall be
managed in accordance with Items (v;& vi) below, unless it is unfeasible to
make the repair without shutting down the affected operation of the facility.
For such component leaks that require a shutdown to be repaired, repair
shall occur during the first shutdown of the affected operation after the leak
is discovered.
iii. Leaks identified during an AVO inspection may be screened, prior to repair,
using Method 21 within 5 working days of leak detection. In such case, only
component leaks greater than 500 ppm shall require management.
iv. For repair, valves adjacent to the equipment to be repaired will be closed if
practicable, minimizing the volume released.
v. Leaks shall be repaired as soon as practicable, but no later than 5 calendar
days after detection, unless it is technically or operationally infeasible to
make the repair within 5 calendar days. Records documenting the rationale
shall be maintained if it is technically or operationally infeasible to make the
repair within 5 calendar days.
vi. Repaired components shall be rescreened within 15 days of repair to verify
the leak is repaired.
vii. The following records shall be maintained for a period of two years and made
available to the Division:
• The date and site information for each inspection;
• A list of the leaking components and the monitoring method(s) used
to determine the presence of the leak;
• The date of first attempt to repair the leak and, if necessary, any
additional attempt to repair the leak;
The date the leak was repaired;
The delayed repair list, including the basis for placing leaks on the
list;
• The date the leak was remonitored to verify the effectiveness of the
repair, and the results of the remonitoring; and
• A list of components that are designated as unsafe, difficult, or
inaccessible to monitor, as described in Regulation 7, Part B, Section
II.E.5, an explanation stating why the component is so designated,
and the plan for monitoring such component(s).
23. Point 005: This source is subject to the New Source Performance Standards, Standards of
Performance for Volatile Organic Liquid Storage Vessels for which construction, reconstruction
COLORADO
Air Pollution Control Division
Page 6 of 17
or modification commenced after July 23, 1984, Subpart Kb. This facility shall be subject to all
provisions of this regulation, as stated in 40 C.F.R Part 60, Subparts A and Kb. (Regulation Number
6, Part A, Subparts A and Kb)
24. Point 006: Minor sources in designated nonattainment or attainment/maintenance areas that
are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply
Reasonably Available Control Technology (RACT) for the pollutants for which the area is
nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This
requirement to apply RACT shall be satisfied by installing/implementing the following emission
controls:
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.
Storage tanks must operate without venting at all times'during loadout. (Regulation Number 7,
Part D, Section II.C.5.a.(ii))
The owner or operator must:
a. 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.
b. Include devices to prevent the release of vapor from vapor recovery hoses not in use.
c. Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to
transport vehicles unless the vapor collection and return system is in use.
d. Operate all recovery and disposal equipment at a back -pressure less than the pressure
relief valve setting of transport vehicles.
e. 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.
The owner or operator must perform the following observations and training:
f. 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.
h. 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.
i. 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.
The owner or operator must retain the following records for at least five (5) years and make
such records available to the Division upon request.
9•
C01,4RAD0
CAir Pollution Control Division
Page 7 of 17
l•
Records of the annual facility hydrocarbon liquids loadout to transport vehicles~
throughput.
k. Inspections, including a description of any problems found and their resolution, must
be documented in a log.
I. Records of the infeasibility of observation of loadout.
m. Records of the frequency of loadout.
n. Records of the annual training program, including the date and names of persons
trained.
25. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator
of oil and natural gas operations and equipment at or upstream of a natural gas processing
plant in Colorado must submit a single annual report that includes actual emissions and
specified information in the Division -approved report format. The information included in the
annual report must be in accordance with the generalreporting 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
26. Points 001, 005, 006: Upon startup of these points, the owner or operator shall follow the most
recent operating and maintenance pam) plan and record keeping format approved by the
Division, in order to demonstrate compliance on an ongoing basis with the requirements of this
permit. Revisions to the O&M plan are subject to Division approval prior to implementation.
(Regulation Number 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
27. Point 006: 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:
• mass emission rates of VOC at the inlet of the control device (Mi) using EPA or other
division approved methods;
• mass emission rates of VOC at the outlet of the control device (Mo) using EPA or other
division approved methods; and
• mass emission rates of NOx and CO at the outlet of the control device using EPA or
other division approved methods.
Additionally, the following parameters may be required to be measured during the test:
• combustion chamber temperature;
• gas flow rate;
• supplemental fuel flow rate;
• gas heat content; and
• gas composition.
The destruction efficiency (DE) for VOC must be calculated using the following equation:
DE (%) = 100*(Mi-Mo)/Mi
The test protocol, test, and test report must be in accordance with the requirements of the Air
Pollution Control Division Compliance Test Manual. The test protocol must include testing
under all operating scenarios 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
COLORADO
Air Pollution Control Division
Page 8 of 17
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 Limits) 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)
Results of the initial compliance tests must be submitted to the Division as part of the self -
certification. Actual emissions calculations must be completed in accordance with the "Notes
to Permit Holder" section of this permit (for point 006). 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.
Periodic Testing Requirements
28. Point 003: Annual liquids sampling and analysis: On an annual basis, the owner or operator shall
complete an extended liquids analysis of liquids samples that are representative of volatile organic
compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions.
This extended liquids analysis shall be used in the compliance demonstration as required in the
Emission Limits and Records section of this permit.
29. Point 006: 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:
• mass emission rates of VOC at the inlet of the control device (Mi) using EPA or other
division approved methods;
• mass emission rates of VOC at the outlet of the control device (Mo) using EPA or other
division approved methods; and
• mass emission rates of NOx and CO at the outlet of the control device using EPA or
other division approved methods.
Additionally, the following parameters may be required to be measured during the test:
• combustion chamber temperature;
• gas flow rate;
• supplemental fuel flow rate;
• gas heat content; and
• gas composition.
The destruction efficiency (DE) for VOC must be calculated using the following equation:
DE (%) = 100*(Mi-Mo)/Mi
The test protocol, test, and test report must be in accordance with the requirements of the Air
Pollution Control Division Compliance Test Manual. The test protocol must 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
COLORADO
Air Pollution Control Division
ua»^-• -of Pubic; at Enyircrr,e,--,°
Page 9 of 17
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 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.
ADDITIONAL REQUIREMENTS
30. 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
For volatile organic compounds (VOC) and nitrogen oxides sources (NO.) in ozone
nonattainment areas emitting less than 100 tons of VOC or NOX per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on the
last APEN submitted; or
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or activity;
or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
31. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such
time that this source becomes major solely by virtue of a relaxation in any permit condition. Any
relaxation that increases the potential to emit above the applicable Federal program threshold
will require a full review of the source as though construction had not yet commenced on the
source. The source shall not exceed the Federal program threshold until a permit is granted.
(Regulation Number 3, Parts C and D).
GENERAL TERMS AND CONDITIONS
32. 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.
COLORADO
Air Pollution Control Division
Page 10 of 17
33. 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.
34. 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.
35. 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.
36. 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.
37. 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.
38. 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:
Christian Lesniak
Permit Engineer
;COLORADO
Air Pollution Control Division
va,- Pubic 1tr c
Page 11 of 17
Permit History
Issuance
Date
Description
Issuance 4
This Issuance
Initial Approval -Issued to Platte River Midstream,
Inc.
Modification to emissions for Points 001, 005.
Addition of new Point 006 with stack testing
language for 98% control.
Updating Regulatory references due to
reorganization of Regulation 7
Issuance 3
September 3,
2020
Final Approval - Issued to Platte River Midstream,
Inc.
Removing Self -Certification language and cancelled
point 002
Issuance 2
October 4, 2016
Permit modification to construct a new tank source
(point 005) and modify the fugitive emissions
source (point 003) to include components for the
new tanks.
Issuance 1
April 22, 2016
Issued to Platte River Midstream, Inc: Initial
approval construction permit for new synthetic
minor facility (points 001, 002, a 003).
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 form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator 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-reps
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process
limits as indicated in this permit. This information is listed to inform the operator of the Division's
analysis of the specific compounds emitted if the source(s) operate at the permitted limitations.
Note: All non -criteria reportable pollutants in the following table 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.
Air Pollution Control Division
Page 12 of 17
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(Ib/yr)
Controlled
Emissions
(lb/yr)
001
Benzene
71432
243
243
Toluene
108883
836
836
Ethylbenzene
100414
389
389
Xylenes
1130207
1176
1176
n -Hexane
110543
1554
1554
2,2,4-
Trimethylpentane
540841
32
32
003
Benzene
71432
196
4
Toluene
108883
327
6
Ethylbenzene
100414
98
2
Xylenes
1130207
457
8
n -Hexane
110543
1532
28
005
Benzene
71432
479
479
Toluene
108883
1647
1647
Ethylbenzene
100414
766
766
Xylenes
1130207
2315
2315
n -Hexane
110543
3059
3059
2,2,4-
Trimethylpentane
540841
63
63
006
Benzene
71432
4115
135
Toluene
108883
14155
463
Ethylbenzene
100414
6582
215
Xylenes
1130207
19896
651
n -Hexane
110543
26290
861
-2,2,4-
Trimethylpentane `
540841
542
18
COLORADO
Air Pollution Control Division
DepartnIqrlt r- vIr., _,,_
Page 13 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
VOC
3.72E-03
3.72E-03
EPA Tank 4.0.9d
71432
Benzene
3.33E-05
3.33E-05
EPA Tank 4.0.9d
108883
Toluene
1.15E-04
1.15E-04
EPA Tank 4.0.9d
100414
Ethylbenzene
5.33E-05
5.33E-05
EPA Tank 4.0.9d
1330207
Xylene
1.61E-04
1.61E-04
EPA Tank 4.0.9d
110543
n -Hexane
2.13E-04
2.13E-04
EPA Tank 4.0.9d
540841
2'2'4
Trimethylpentane
4.39E-06
4.39E-06
EPA Tank 4.0.9d
Note: The controlled emissions factors for this point are based on site -specific sampling and model run for
this tank roof configuration.
Point 003:
Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors
listed in the table below with representative component counts, multiplied by the VOC content from the
most recent gas and/or liquids analyses.
Component count estimate
Component
Gas Service -
Heavy Oil
Light Oil
Water/Oil
Service
Connectors
--
--
300
--
Flanges
--
--
650
--
Open-ended Lines
--
--
30
--
Pump Seals
--
--
30
--
Valves
--
--
300
--
Other*
--
--
50
--
*Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump
arms, hatches, instrument meters, polish rods and vents
Stream HAP Components (weight fraction)
Component
Gas Service
Heavy Oil
Light Oil
Water/Oil
Service
VOC
--
--
1.000
--
Benzene
--
--
0.006
--
Toluene
--
--
0.010
--
Ethylbenzene
--
--
0.003
--
Xylene
--
--
0.014
--
n-Hexane
--
--
0.047
--
COLORADO
Pollution Control Division
Page 14 of 17
TOC Oil and Gas Production Emission Factors
Uncontrolled emission factors are based on the use of Operations Average Emission Factors from EPA -
453/R95 -O17 - Table 2-4. Controlled emission factors are based on the use of Screening Ranges
Emission Factors from EPA -453/R95-017 - Table 2-8.
All emission factors are in units of [kg/hr-component]
Component
Uncontrolled
(Table 2-4)
Controlled
(Table 2-8)
Connectors
2.1E-04
9.7E-06
Flanges
1.1E-04
2.4E-06
Open-ended Lines
1.4E-03
2.4E-06
Pump Seals
1.3E-02
5.1E-04
Valves
2.5E-03
1.9E-5
Other
7.5E-03
1.1E-04
Point 005:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
VOC
6.27E-04
6.27E-04
EPA Tank 4.0.9d
71432
Benzene
5.62E-06
5.62E-06
EPA Tank 4.0.9d
108883
Toluene
1.93E-05
1.93E-05
EPA Tank 4.0.9d
100414
Ethylbenzene
8.99E-06
8.99E-06
EPA Tank 4.0.9d
1330207
Xylene
2.72E-05
2.72E-05
EPA Tank 4.0.9d
110543
n -Hexane
3.59E-05
3.59E-05
EPA Tank 4.0.9d
540841
2'2'4
Trimethylpentane
7.40E-07
7.40E-07
EPA Tank 4.0.9d
Note: The controlled emissions factors for this point are based on site -specific sampling and model run for
this tank roof configuration. The control device is integrated into the unit such that the uncontrolled
emission factors are identical to the controlled.
Point 006•
Pollutant
CAS #,
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
NOx
0.0680 (Ib/mmBtu)
1.26E-03
AP -42 Chapter 13.5
Industrial Flares (NOx)
CO
0.3100 (Ib/mmBtu)
5.76E-03
AP -42 Chapter 13.5
Industrial Flares (CO)
VOC
3.15E-01
1.03E-02
Conservative Source
Calculation
Benzene
71432
2.82E-03
9.23E-05
Conservative Source
Calculation
Toluene
108883
9.70E-03
3.17E-04
Conservative Source
Calculation
COLORADO
Air Pollution Control Division
C_r,Mn,,A , _.z
Page 15 of 17
Pollutant
CAS #
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
Ethylbenzene
100414
4.51E-03
1.48E-04
Conservative Source
Calculation
Xylene
1330207
1.36E-02
4.46E-04
Conservative Source
Calculation
n -Hexane
110543
1.80E-02
5.90E-04
Conservative Source
Calculation
224 TMP
540841
3.71E-04
1.22E-05
Conservative Source
Calculation
The uncontrolled VOC emission factor was more conservative than that calculated using
AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values:
L = 12.46*S*P*M/T
S = 0.6 (Submerged loading: dedicated normal service)
P (true vapor pressure) = 7.54 psia
M (vapor molecular weight) = 50 lb/lb-mot
T (temperature of liquid loaded) = 510.39 R
The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were
calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC
emission factor.
Controlled emissionfactors are based on a flare efficiency of 98% and a collection
efficiency of 98.7%.'
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 facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of VOC, n -Hexane, and Total HAP
PSD
Minor Source
NA NSR
Synthetic Minor Source of VOC
MACT EEEE
Synthetic Minor Source of n -Hexane, and Total HAP
COLORADO
Air Pollution Control Division
Page 16 of 17
8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart KKKK
NSPS
Part 60, Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories
MACT
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
COLORADO
Air Pollution Control Division
Page 17 of 17
Colorado Air Permitting Project
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer:
Package #:
Received Date:
Review Start Date:
For Division Use Only
Christian Lesni_ar
434605
9/4/2020
.11/ 2/2020
Section Ol - Facility Information
Company Name. -Platte River Midstream, Inc.
County AIRS ID: =123 ,
Plant AIRS ID: 4EOF Facility Name: Lucerne West Station - -
Physical
Address/Location:
County:
Type of Facility:
What industry segment?
Is this facility located in a NAAQS non -attainment area?
If yes, for what pollutant?
Section 2", Township 6N, Range 6SW
Weld County
Section 02 - Emissions Units In Permit Application
Quadrant
Section
Township
Range
EN
Leave Blank- For Division Use Only.
AIRS Point #
(Leave blank unless
APCD has already
assigned)
00
Gv5
Emissions Source Type
Equipment Name
T-101 through T-120
T
Tile
Lnadout
Emissions
Control?
Permit #
(Leave blank unless
APCD has already
assigned)
15WE1427
Issuance
15WE=427
Self Cert
Required?
Perm;
Modifice,
Action
"-Permit -
Modiftcatidr
Engineering
Remarks
Modficaton
Modficatien
1427
Y s nn:
New Point
Section 03 - Description of Project
Modification to add tuck loadout t,,,*acil{ty. Modification to ernissions of other points, Puastc Comment is required because of addition of synthetic minor
loadoutpoint. Source is request n greeter than 9"526 genirol of the loadout-pbint, and will be required tastack testin-order to confirm a highereentiol efficiency.
Sections 04, 05 & 06- For Division Use Only
Section 04- Public Comment Requirements
Is Public Comment Required?If yes, why? /Re oestircg'.t=7;t,.tic HBirrnr f*ernsit
Section 05 - Ambient Air Impact Analysis Requiremen
Was a quantitative modeling analysis required?
-
Ifyes,forwhatpollutants? ,
-
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: 502 NOx CO
VOC
PM2.5 PM10 TSP
HAPs
Prevention of Significant Deterioration (PSD) ❑ ❑ ❑
❑
❑
❑
Title V Operating Permits (OP) ❑ ❑ ❑
D
❑
❑ ❑
❑
Non -Attainment New Source Review (NANSR) ❑
D
Is this stationary source a major source?
If yes, indicate programs and which pollutants: SO2 NOx CO
VOC
PM2.5
PM10 TSP
HAPs
Prevention of Significant Deterioration (PSD) ❑ ❑ ❑
❑
❑
❑
Title V Operating Permits (OP) - ❑ ❑ ❑
❑
❑
❑ ❑
❑
Non -Attainment New Source Review (NANSR) 0
0
Storage Tank(s) Emissions --.inventory
Section 01 -Administrative Information
'Facility Allis ID:
123
County
9EOf
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 far Emissions Estimates
Primary Emissions -Storage Tank(s)
Actual Throughput=
(Requested Permit Limit Throughput=
T rsttloj'1;00098Linternal floanng'r4,,,,
loafing Roof Tanks considered intrinsic
Potential to Emit (PTE) Condensate Throughput =
7,3[6;000:0 Barrels (bbl) per year
7,30W000.0 Barrels (bill) per year
Secondary Emissions - Combustion Device(s)
Heat content of waste gas=
Volume of waste gas emitted per BBL of liquids
produced =
Actual heat content of wastages routed to combustion device =
Requested heat content of waste gas routed to combustion device =
Barrels (bbl) per year
Btu/scf
scf/bbi
Potential to Emit (PTE) heat content of waste gas routed to combustion device =
Control Device
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Requested Monthly Throughput=
0.0 MMBTU per year
0.0 MMBTU per year
0.0 MMBTU per year
Pollutant
Pollutant
(Ib/bbl)
(Ib/bbl)
(Condensate
Throughput)
(Condensate
Throughput)
0.0037
0.0000
0.0001
0.0001
0.0002
0.0002
0.0000
Control Device
(waste heat
combusted)
IIMMOMMIIMIEMEMMINI
MEMIEMEMMIIMMINIMI
MIMMIMMI
IMIIMMEMEMEMMIE
(Pilot Gas Neat
Combusted)
Pollutant
(Condensate
Throughput)
0.0000
0.0000
0.0009
0.0000
0.0000
Section 05 - Emissions Inventory
(Pilot Gas
Throughput)
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
Emission Factor Source
Emission Factor Source
Emission Factor Source
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
fibs/month)
PM10
PM2.5
30x
NOx
VOC
CO
0,0
0.0
0.0
0.0
0.0
0.0
0,0
0.0
0.0
0.0
0.0
Cha
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
- 0,0
13.6
13.6
13.0
13.6
2313-3
OA
0.0
0.0
0.0
0.0
3 0
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) ' fibs/year)
Benzene
Toluene
Ethylbenzene
%ylene
n -Hexane
224 TMP
OA
243.2
243.2
243
243
0-0
836.5
836.5
836
836
0.0
388.9
388.9
389
389
0.0
1173,7
1175.7
1176
1176
0.0
1553.5
1553,5
1554
1554
0.0
32.0
32.0
32
32
620000.0 Barrels (bbl) per month
TANKS 4,0.9d Emissions Report
Components Losses(lb/yr per tank) (VFR= vertical fixed roof tank, IFR =internal floating roof tank, —=n•
IFR EPA Tanks input mai%
Condensate
(VOC) 2714.03 100.0000` 12.5742
Benzene
Toluene
Ethylbenzene
xylene (-m)
Hexane (-n)
224 -IMP
' Unidentified
components
number of
tanks:
10
Landing losses (per tank)
true vapor press
stock liquid densi
volume of vapor
ideal gas constam
average tempera'
stock vapor mole
saturation factor
landing events
event filling loss
15.05
60.4
6.36
82.68
110.13
5.54
2433.87
number of tanks:
0.8960
3.0820
1.4330
4.3320
5.7240
0.1180
10
1.0475
2.7323
0.5168
2.7033
5.0357
0.5386
•
liquid properties from TANKS 4.0.9d tun at RVP of 11
6.59 psia
7.1 lb/gal
1038 ft^3
10.731 psia-Ft^3/Ib-mol-R
510.39 deg 50.72 F
50.0 Ib/Ib-mol
0.15 Applicant assumed drain -dry tank: no liquid remaining in t=ank when
1 /yr/tank landing events. From AP -42 p 7.1-28: "A drain -dry condition is attain,
9.37 Ib/yr AP -42 Ch 7, eon 3-18
event standing (c 0.337607563 Ib/yr
AP -42 Ch 7, eqn 7-11 0.006 aingage factor (bbl/
Total Landing lost 97.0 Ib/yr AP -42 Chapter 7, total landing losses for entire tank battery
2 of 13
DATake Home \Current Projects \434605 (Pilate River Mid COGA)\115WE1427.CP4
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Soarce rearines a per:nd
Regulation 7, Part D,Section I.C, D, E, F
ntoiage Tank is not subject tx; RegWation 7, Part C Se, t.on =.C F
Regulation 7, Part D,Section I.G, C
Storage Teak is not subject to Regulation 7, Section I.G
Regulation 7, Part D,Sectlon II.B, C.1, C.3
" age rank ,s ntot subieit to Regulation 7, Pert D. Section it
Regulation 7, Part D,Section II.C2
Tank nat. subject to Regulation 7 Part 0 Scsticn ii.C.2.
Regulation 7, Part D,Section II.C4.a.(i)
Storage Tank is not subject to Regulation J, Part D. Sir bon ii E x.afg
Regulation 7, Part O,Section ll.C.4.a.(il)
Horage Tank la Oe +0bya:.t to Regulation 7. cart D Se. Bate' -4C 4. an, . b f
Regulation 6, Part A, NSPS Subpart Kb
Storage Tang is nor subject to NSPS kb
Regulation 6, Part A, NSPS Subpart 0000
Stui age tank is subject to NSPS 0000
NSPS Subpart 00002
Storage cans isauLies". {0 ASPS, 000a.
Regulation 8, Part E, MACE Subpart HH
Storage Tank is no, subject to MA:: Nit
(See regulator/applicability worksheet for detailed analysis)
Section 07- Initial and Periodic Sampling and Testing Requirements
For condensate or crude ofl 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 alder site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08 -Technical Analysis Notes
Operator has calculated floating roof tank emissions using art assumed RVP ofll, in EPA Tanks4.0,The operator submitted a liquid sample showing an adjusted RVP(perASTM method) of 10, so the RVP af11
appears to be in line with the liquid sample, taken March 2020.
Section 09 -SCC Coding and Emissions Factors (For Inventory Use Only(
AIRS Point #
001
Process #
01
SCC Code
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM30 000 0 b/1,000 gallons Condensate throughput
PM2.5 0 00 0 b/1,000 gallons Condensate throughput
SOx _ 6/1,000 gallons Condensate throughput
NOx 000 0 6/1,000 gallons Condensate throughput
VOC ..._ _ 6/1,000 gallons Condensate throughput
CO ai0 0 6/1,000 gallons Condensate throughput
Benzene 0.00 0 b/1,000 gallons Condensate throughput
Toluene Ou0 0 b/1,000 gallons Condensate throughput
Ethylbenzene ?CO 0 b/1,000 gallons Condensate throughput
Xylene _00 C b/1,000 gallons Condensate throughput
n -Hexane .a C1 .. b/1,000 gallons Condensate throughput
224 TMP a0 0 b/1,000 gallons Condensate throughput
3 of 13 D:\Take Home \Current Projects\434605 (Pilate River Mid COGA)\15WE1427.CP4
Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
'Source is in the Non=Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo OS -01 Definitions 1.12 and1.14 and Section 2 for additional guidance on
2. grandfather applicability)?
3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)?
'You have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
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
2. grandfather applicability)?
3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II,D.2)?
'Source requires a permit
Colorado Regulation 7, Part D, Section LC -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 Ti
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
3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I.G)? A
4. Does this storage tank contain condensate? —
5. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions (Regulation 7, part D, Section I.G.2)? —
6. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section I.D.3.a(ii))?
'Storage Tank is not subject to Regulation 7, Part D, Section I.C-F
Part D, Section I.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of Leakage
Part D, Section I.C.2— Emission Estimation Procedures
Part D, Section I.D — Emissions Control Requirements
Part D, Section I.E— Monitoring
Part D, Section I.F— Recordkeeping and Reporting
'Storage Tank is not subject to Regulation 7, Section I.G
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 D, Section II
1. Is this storage tank located at a transmission/storage facility? Y
2. Is this storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor station"' natural gas processing plant° or class II dis i\
3. Does this storage tank have a fixed roof (Regulation 7, Part D, Section II.A.20)?
4. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section II.C.1.c)?
'Storage Tank is not subject to Regulation 7, Part D, Section II
Part D, Section 11.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part D, Section II.C.1- Emissions Control and Monitoring Provisions
Part I), Section II.C.3 - Recordkeeping Requirements
5. Does the storage tank contain only "stabilized" liquids (Regulation 7, Part D, Section II.C.2.b)?
'Storage Tank is not subject to Regulation 7, Part D, Section II.C.2
Part D, Section II.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
Is the controlled storage tank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed on or after May 1, 2020 or located at a
6. facility that was modified on or after May 1, 2020, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon
'Storage Tank is not subject to Regulation 7, Part D, Section #I.C.4.a(i)
a facility that was modified on or after January 1, 2021, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon
7. liquids or produced water (Regulation 7, Part D, Section II.C.4.a.(ii)?
'Storage Tank is not subject to Regulation 7, Part D, Section II.C.4.a(ii), b - f
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 (m3) [-472 BBLs] (40 CFR 60.110b(a))?
2. Does the storage vessel meet the following exemption in 60.111b(d)(4)7
a. Does the vessel has a design capacity less than or equal to 1,589.874 m3 [-10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfr
3. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984 (40 CFR 60.110b(a))?
4. Does the tank meet the definition of "storage vessel"' in 60.111b?
5. Does the storage vessel store a "volatile organic liquid (VOL)"5 as defined in 60.111b?
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa [^29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or
b. The design capacity is greater than or equal to 151 m3 ["'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 is greater than or equal to 75 M" (-472 BBL] but less than 151 m" ["'950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(61
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 m3 [-950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa
b. The design capacity is greater than or equal to 75 M31-472 BBL] but less than 151 m3 [^'950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal
'Storage Tank is not subject to NSP5 Kb
40 CFR, Part 60, Subpart OOOO/0000a, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
Is this storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the
1. industry?
2. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015?
3. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 2015?
4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? _
5. Does this storage vessel meet the definition of "storage vessel'' per 60.5430/60.5430a? Y
6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH?
'Storage tank is subject to NSPS OOOO
Subpart A, General Provisions per §60.5425 Table 3
§60.5395 - Emissions Control Standards for VOC
§60.5413 - Testing and Procedures
§60.5395(g) - Notification, Reporting and Recordkeeping Requirements
§60.5416(c) - Cover and Closed Vent System Monitoring Requirements
§60.5417 - Control Device Monitoring Requirements
[Note: If a storage vessel is previously determined to be subject to NSPS OOOO/0000a due to emissions above 6 tons per year VOC on the applicability determination date, it
should remain subject to NSPS OOOO/0000a per 60.5365(e)(2)/60.5365a(e)(2) even if potential VOC emissions drop below 6 tons per year]
40 CFR, Part 63, Subpart MACT NH, Oil and Gas Production Facilities
1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria:
a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is
b. 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 vessel4 in 63.761?
4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"' per 63.761?
5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart OOOO?
C
'Storage Tank is not subject to MACT HH
Subpart A, General provisions per §63.764 (a) Table 2
§63.766 - Emissions Control Standards
§63.773 - Monitoring
§63.774 - Recordkeeping
§63.775 - Reporting
RACT Review
RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements.
Disclaimer
Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual
facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally
enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air
Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,"
"may,""should," '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
Storage Tar,k(s) Emissions Inventory
Section 01 -Administrative Information
Facility AIRS 10:
123
County
9EOF
Plant
Point
Section 02 - Equipment Description Details
Storage Tank Liquid
Detailed Emissions Unit
Description:
Four (4) 150,000 bar
condensate. Totat st
nternal floating roof storag
ge capacity: 600,000 bb,.....:
Emission Control Device internal Flooring Roo- Tank is considered intrinsic: and: not a control device
Description: "
Requested Overall VOC & HAP Control Efficiency %:
Limited Process Parameter
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Throughput =
(Requested Permit Limit Throughput=
85,200,000:0 Barrels (bbl) per year
85,200,000,0 Barrels (bbl) per year
Potential to Emit (PTE) Condensate Throughput- 107-,240,000,0• Barrels (bbl) per year
Secondary Emissions - Combustion Device(s)
Heat content of waste gas =
Volume of waste gas emitted per BBL of liquids
produced = scf/bbl
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
Btu/scf
Potential to Emit (PTE) heat content of waste gas routed to combustion device=
Control Device
Requested Monthly Throughput=
O.G MMBTU per year
0.0 MMBTU per year
0.0 MMBTU per year
Pilot Fuel Use Rate:
Pilot Fuel Gas Heating Value:
scfh -
,Btu/scf
0.0 MMscf/yr
0.0 MMBTU/yr
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Pollutant
IIMMEIZIMMENE
Toluene
Ethylbenzene
n -Hexane
Pollutant
MIIIMIEZEIMMEN
Condensate Tank
Uncontrolled
Controlled
(Ib/bbl)
(lb/bbl)
(Condensate
Throughput)
5.62E-06'
1.93E-05.....:.`.'1.
1.101033.1
2.72E-05 t°'11
(Condensate
Throughput)
0.0006
0.0000
0.0000
O.0000
0.0000
0.0000
0.0000
Control Device
Uncontrolled
(Ib/MidBtu)
Uncontrolled
(lb/bbl)
Pollutant
IIMMZEIMMI
PM2.5
SOx
NOx
CO
0.0000
0.0000
0.0000
0.0000
0.0000
Pilot Light Emissions
Uncontrolled
(Ib/MMBtu)
Uncontrolled
(Ib/MMscf)
0.0000
0.0000
0.0000
0.0000
0.0000
0.0000
Emission Factor Source
Emission Factor Source
Emission Factor Source
Section 05 - Emissions Inventory
Criteria Pollutants
Potential bo 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
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.3
0.0
0.0
0.0
0.0
0.0
6613
0.0
'_- -
0.0
0.0
0.0
0.0
OA
ri,a
0.0
32.1
26.7
;26.7
28.5
283
4843.1
0.0
0.0
0.0
0.0
0.0
0.0
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)
7236164 Barrels (bbl) per month
TANKS 4.0.9d Emissions Report
Components Losses(lb/yr per tank) (VFR= vertical fixed roof tank, IFR= intemal Floating ro
IFR EPA Tanks mol%
Condensate
(VOC) 13359.24 100.0000
number of
tanks: 4
Benzene
Toluene
Ethylbenzene
Xylene (-m)
Hexane (-n)
224-TMP
Unidentified
components
number of tanks: a
Landing losses (per tank)
true vapor pressu
stock liquid densi
volume of vapor:
ideal gas constant
average temperas
stock vapor moles
saturation factor
landing events
event filling loss
6.59
7.1
95901
10:731
513.39
50.3
0.15
1 /yr/tank
865.42 lb/Vi
91.57
272.22
39.77
147.87
663.6
3981.88
0.8960
3.0820
1.4330
4.3320
5.7240
0.1180
liquid properties from TANKS 4.0.9d run at VP of 11
psia
lb/gal
ft^3
psia-Ft^3/Ib-mol-R
deg R 50.72 F
Ib/Ib-mol
Applicant assumed drain -dry tank: no liquid remaining
during roof landing events. From AP -42 p 7.1-28: "A dre
AP -42 Ch 7, eqn 3-18
event standing(cl 31.19760878 Ib/yr AP -42 Ch 7, eqn 3-11 0.006 Clingage factor(bbU
Total Landing i0SE 3586.5 Ib/yr AP -42 Chapter 7, total landing losses. for entire tank bat
6 of 13
DATake Home \Current Projects \434605 (Pilate River Mid COGA)\1SWE1427.CP4
Storage Tank(s) missions Inventor.
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
574.6
1476.3
918.9
2777.9
3670.5
478.8
1648.3
764.8
2314.9
30583
478.8
1645,9
765.8
2314.9
3059.7
479
1647
766
2315
3059
479
1647
766
2315
3059
75.7
63.'_
63,1
63
63
7 of13
DATake Horne \Current Projects \434605 (Pilate River Mid COGAA15WE1427.CP4 )
Storage Tank(s) Errdssions Inventory
Section 06 - Regulatory Sum
Regulation 3, Parts A, B
source requires a permit
Regulation 7, Part D,Section LC, D, E, F
Storage Tank is not subject to Regulation 7, Part D, Section I.C.D
Regulation 7; Part D,Section I.G, C
Storage Tank is not subject to Regulation 7, Section I G
Regulation 7, Part D,Section II.B, C.1, C.3
Storage Tank is not subject to Regulation 7, Part D, Section I
Regulation 7, Part D,Section II.C.2
Storage Tank is not subject to Regulation 7, Part le, Section DC_2
Regulation 7, Part D,Section II.C.4.a.(i)
Storage Tank is not subject to item,!ation 7, Part O. Section il.C.4.afb
Regulation 7, Part D,Section II.C.4.a.(ii)
Storage Tank is not subject to Regolation 7, Part D, Section ) _µ,ggig, ,. f
Regulation 6, Part A, NSPS Subpart Kb
Storage tank is subject to rageg gb
Regulation 6, Part A, N5P5 Subpart 0000
Storage tank is subject to •.SPS 0000
NSP5 Subpart 0000a
Storage tank is not subject to ,'-=SP5 co
Regulation B,Part E, MALT Subpart HH
(See regulatory applicability worksheet for detailed analvsisl
Storage Tank is not n;bjeb
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 actuator requested emissions for a condensate storage tank estimated to begreater 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 dawn 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 permitwill_containan "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03.
Does the company request wcontrol device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contan initial and periodic compliance testing in accordance with PS Memo 20-02
Section 08 - Technical Analysis Notes
Section 09 - SCC Coding and Grnissions Factors (For Inventory Use Only)
AIRS Point #
Process A SCC'Code
005 01
Uncontrolled
Emissions
Pollutant Factor Control% Units
PM10 0.09 0 lb/1,000 gallons Condensate throughput
PM2.5 0.00 0 Ib/1,000.gallons Condensate throughput
50x 0:00. 0 Ib/1,000gallons condensate throughput
NOx 0.00 0 Ib/1,000 gallons Condensate throughput
VOC 0-02 0 lb/1,000 gallons Condensate throughput
CO 0.30 0 lb/1,000 gallons Condensate throughput
Benzene 0.000 0 lb/1,000 gallons Condensate throughput
Toluene 0.00 0 lb/1,000 gallons Condensate throughput
Ethylbenzene 0.90 0 lb/1,000 gallons Condensate throughput
Xylene 0.90 0 lb/1,000 gallons Condensate throughput
n -Hexane 9.00 9 lb/1,000 gallons Condensate throughput
224 TMP 3.00 0 lb/1,000 gallons Condensate throughput
8 of 13 D:\Take Home \Current Projects \434605 (Pilate River MidCOCA)\15WE1427.CP4
Storage Tank Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions.
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
Source is in the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on
2. grandfather applicability)?
3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)?
'You have indicated that source is in the NoreAttainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
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
2. grandfather applicability)? ft
3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)?
'Source requires a permit
Colorado Regulation 7, Part D, Section I.C-F & G _
1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Regulation 7, Part D, Section I.A.1)? Y
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
3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I.G)?
4. Does this storage tank contain condensate?
5. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions (Regulation 7, part D, Section I.G.2)?
6. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section I.D.3.a(ii))?
'Storage Tank is not subject to Regulation 7, Part O, Section LC -F
Part D, Section I.C.1 —General Requirements for Air Pollution Control Equipment— Prevention of Leakage
Part D, Section I.C.2— Emission Estimation Procedures
Part D, Section I.D — Emissions Control Requirements
Part D, Section I.E— Monitoring
Part D, Section I.F — Recordkeeping and Reporting
Storage Tank is not subject to Regulation 7, Section I.G
Part D, Section I.G.2 - Emissions Control Requirements
Part D, Section I.C.1.a and b — General Requirements for Air Pollution Control Equipment— Prevention of Leakage
Colorado Regulation 7, Part D, Section II _
1. Is this storage tank located at a transmission/storage facility? Y
2. Is this storage tanks located at an oil and gas exploration and production operation , well production facilityz, natural gas compressor station3' natural gas processing plant.' or class II dis
3. Does this storage tank have a fixed roof (Regulation 7, Part D, Section II.A.20)?
4. Are uncontrolled actual emissions of this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section II.C.1.c)?
'Storage Tank is not subject to Regulation 7, Part D, Section 11
Part D, Section II.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Part D, Section II.C.1- Emissions Control and Monitoring Provisions
Part D, Section II.C.3 - Recordkeeping Requirements
5. Does the storage tank contain only "stabilized" liquids (Regulation 7, Part D, Section II.C.2.b)?
'Storage Tank is not subject to Regulation 7, Part D, Section II.C.2
Part D, Section II.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment _
Is the controlled storage tank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed on or after May 1, 2020 or located at a
6. facility that was modified on or after May 1, 2020, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon
'Storage Tank is not subject to Regulation 7, Part D, Section Ii.C.4.0)
a facility that was modified on or after January 1, 2021, such that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon
7. liquids or produced water (Regulation 7, Part D, Section II.C.4 a.(ii)?
'Storage Tank is not subject to Regulation 7, Part O, Section ILC.4.afii), b -f
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 (m3) ['"472 BBLs] (40 CFR 60.110b(a))? Y
2. Does the storage vessel meet the following exemption in 60.111b(d)(4)?
a. Does the vessel has a design capacity less than or equal to 1,589.874 m3 [^'10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfi
3. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984 (40 CFR 60.110b(a))? V
4. Does the tank meet the definition of "storage vessel"' in 60.111b? 1
5. Does the storage vessel store a "volatile organic liquid (VOL)"sas defined in 60.111b? Y
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa [^'29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or
b. The design capacity is greater than or equal to 151 m3 [^'950 BBL] and stores a liquid with a maximum true vapor pressure' less than 3.5 kPa (60.110b(b))?; or
c. The design capacity is greater than or equal to 75 M3 [-472 BBL] but less than 151 m3 [-950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 I<Pa(61
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 m3 ["'950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa
b. The design capacity is greater than or equal to 75 M3 ["'472 BBL] but less than 151 m3 [^'950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal
Storage tank is subject to NSPS Kb
Subpart A, General Provisions
§60.112b - Emissions Control Standards for VOC
§60.113b - Testing and Procedures
§60.115b - Reporting and Recordkeeping Requirements
§60.116b - Monitoring of Operations
40 CFR, Part 60, Subpart OOOO/OOOOa, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
Is this storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the
1. industry?
2. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015?
3. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 2015?
4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year?
5. Does this storage vessel meet the definition of "storage vessel"' per 60.5430/60.5430a?
6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH?
Storage tarsi€ is subject to NSPS OOO0
Subpart A, General Provisions per §60.5425 Table 3
§60.5395 - Emissions Control Standards for VOC
§60.5413 -Testing and Procedures
§60.5395(g) - Notification, Reporting and Recordkeeping Requirements
§60.5416(c) - Cover and Closed Vent System Monitoring Requirements
§60.5417 - Control Device Monitoring Requirements
[Note: If a storage vessel is previously determined to be subject to NSPS OOOO/OOOOa due to emissions above 6 tons per year VOC on the applicability determination date, it
should remain subject to NSPS OOOO/OOO0a per 60.5365(e)(2)/60.5365a(e)(2) even if potential VOC emissions drop below 6 tons per year]
40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities
1. 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 stores hydrocarbon liquids' (63.760(a)(2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is
b. delivered to a final end user' (63.760(a)(3))?
2. Is the tank located at a facility that is major3 for HAPs?
3. Does the tank meet the definition of "storage vessel"° in 63.761?
4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"' per 63.761?
5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart OOOO?
'Storage Tank is not subject to MACT HH
Subpart A, General provisions per §63.764 (a) Table 2
§63.766 - Emissions Control Standards
§63.773 - Monitoring
§63.774-Recordkeeping
§63.775 - Reporting
RACT Review
RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements.
Disclaimer
Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon -the individual
facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally
enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air
Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,"
"may,""should,"and "can," is intended to describe APCD interpretations and 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
Hvtirocarbon Load out E.ntis,,ioo; inventory
Section 01 -Administrative Information
'Facility AIRS ID:
123
County
4EOF
Plant
006
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
out of Condensate and Crude Oil
Emission Control Device ' EnfAc
Description: ued tgmiFuatgT
Is this loadout controlled?
Requested Overall VOC& HAP Control Efficiency%: ,96.73 98% control 98.7% capture
Section 03 -Processing Rate Information for Emissions Estimates
Primary Emissions - Hydrocarbon Loadout
Actual Volume Loaded = .. .
(Requested Permit UmitThroughput=
Potential to Emit (PTE) Volume Loaded =
0 Barrels (bbl) per year
1,460,000 Barrels (bbl) per year
1,752,000 Barrels (bbl) per year
Requested Monthly Throughput=
124000 Barrels (bbl) per month
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 =
Btu/scf
scf/year
348:§W scf/year
Potential to Emit (PTE) heat content of waste gas routed to combustion device =
18263 Btu/lb
Heat Value of waste
Combusted Amount
G MMBTU per year
MMBTU per year
MMBTU per year
Control Device
Pilot Fuel Use Rate:
Pilot Fuel Gas Heating Value:
scfh
Btu/scf
0 G MMscf/yr
u MMBTU/yr
Section 04 - Emissions Factors & Methodologies
Does the company use the state default emissions factors to estimate emissions?
Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being
permitted?
Loading Loss Equation
L =12.46"S"P"M/T
Factor
Meaning
Value
Units
Source
Calculated
S
Saturation Factor
0.5
;5110yMS,„"
;,''°
$w+, .
_,'qmo'-�:.
Saturation Factor
P
True Vapor Pressure
7:54
psia
:.,;7'-..
--`"''+--:"`"„T.'?r':-
time Vapor Pressure
M
Molecular Weight of Vapors
.,50
Ib/Ib-mol
>_
'. -" - `";
xr
Molecular Weight
T
Liquid Temperature
$1039
.Rankine
-
='
Liquid Temperature
L
Loading Losses
15
lb/1000 gallons
Conservative source calcmatlon
loading Losses
_.5:3 lb/bbl
Component
Mass
Fraction
Emission Factor
Units
Source
Benzene
0,00896
0.002818637
lb/bbl
Toluene
0,03082
0.009695356
lb/bbl
Ethylbenzene
0.01433
' -
0.004507931
lb/bbl
'-
Xylene
-
0.04332
:.-
0013627606
lb/bbl
n -Hexane
0.05724
-
0.018006559
lb/bbl
".
2Z4TMP
0,00118
0.000371204
lb/bbl
Pollutant
Hydrocarbon Loadout
(Ib/bbl)
(lb/bbl)
o urne Loaded
Volume Loade
®'EMaMMMI =MM
MEICEMMNIII MIMI=qq
®k
Emission Factor Source
Pollutant
Pollutant
Control Device
(Ib/MMBtu)
(lb/bbl)
(waste heat combusted)
0,0075
0:0075 ,
0:0006
0.0680 .
0.3100
0.00E+00
Pilot Light Emissions
Uncontrolled
(Ib/MMBtu)
Uncontrolled
(Ib/MMscf)
(Pilot Gas
Throughput)
(Waste Heat Combusted)
Emission Factor Source
Emission: Factor Source
28,263 Btu/lb in BTU/gal (from Ent
1,484,53.63 Ib/yr estimated emissions
0.6
7.54
50
510.39
5.522154
0.23193
11 of 13 D:\Take Home \Current Projects \434605 (Pilate River Mid COGA)\15WE1427.CP4
Hydrocarbon Loadout Emissions Inventory
Section 05 - Emissions Inventory
Potential to Emit
Actual Emissions
Requested Permit Limits
Requested Monthly Limits
Criteria. Pollutants
Uncmtrolled
Uncontrolled Controlled
Uncontrolled Controlled
Controlled
(tons/year)
(tons/year) (tons/year)
(tons/year) (tons/year)
(Ibs/month)
PM10
0.00
0,00
0- 0
0.00
IILO
0
PM2.5
0.00
ROO
2 1
030
0.80
0
SO8
0.00
0.00
,...._
0.20
0.00
1
N0x
000
0.00
;.92
0,92
57
VOC
2;5.47
0,00
200
229.54
7.52
1277
CO
0.00
0.00
0.00
4.20 _
4-20
714
Potential to Emit
Actual,Emissions
Requested Permit Limits
Hazardous Air Pollutants
Uncontrolled
Uncontrolled Controlled
Uncontrolled Controlled
Ohs/year)
(Ibs/year) (Ibs/year)
(Ibs/year) (Ibs/year)
Benzene
4938
0
0
4113
135
Toluene
16985
..
0
14155
453
Ethylbenzene
7838
C
0
6582
215
XYlene
23876
0
0
19896
651
n -Hexane
31547
0
20290
863
224 TMP
- 650
C
C
542
18
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7 Part D Section II.C.5.
(See regulatory applicability worksheet for detailed analysis
Source requires a permit
The hydro 43 —
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
P of subject to Regulation 7 Part 3 Seftc^ 11.1.5.
Section 08 - Technical Analysis Notes
Source provided calculations for pilot light / pilot light equivalent that showed negligible emissions. Source based this on
Section 09 - SCC Coding and Emissions Factors ( For Inventory Use Onlyl
AIRS Point #
006
Process #
01
SCC Code
4 s-sol32 CJnde O'sis Submerged, Loading Rlovmal Service (S=0.6)
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 0.00 0 lb/1,000 gallons transferred
PM2.5 9.00 0 lb/1,000 gallons transferred
SOx 0^0 0 16/1,000 gallons transferred
NOx 0.03 0 lb/1,000 gallons transferred
VOC 7.5 97 lb/1,000 gallons transferred
CO 9.14 0 lb/1,000 gallons transferred
Benzene 0:-07- 97 lb/1,000 gallons transferred
Toluene 0.23 97 lb/1,000 gallons transferred
Ethylbenzene - 0,11 97 lb/1,000 gallons transferred
Xylene 0,32 97 16/1,000 gallons transferred
n -Hexane 97 16/1,000 gallons transferred
224 TMP R.OS 97 lb/1,000 gallons transferred
12 of 13 D:\Take Home \Current Projects \434605 (Pilate River Mid COCA)\15WE1427.CP4
Hydrocarbon Loadout Regulatory Analysis Worksheet
The regulatory requirements below are determined based on requested emissions and throughput.
Colorado Regulation 3 Parts A and B- APEN and Permit Requirements
'Somme 1s €n the NorrAttatnme tares
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the Ioadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)?
3. 'Is the Ioadout operation loading less than 10,000 gallons (238 BBIs) of crude oil per day on an annual average basis?
4. Is the loadoutoperation loading less than 6,750 bbls per year of condensate via splash fill?
5. Is the Ioadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure?
6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section ll.D.3)?
'Mott base indicated that 5c€via. is irr tie No Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the Ioadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)?
3. Is the Ioadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis?
4. Is the Ioadout operation loading less than 6,750 bbls per year of condensate via splash fill?
5. Is the Ioadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure?
6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, N0x greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section ll.D.2)?
ISoures requires a permit
Colorado Regulation 7 Part D Section II.C.5.
1. Is this hydrocarbon liquids Ioadout located at a well production facility, natural gas compressor station or natural gas processing plant?
2. Does the facility have a throughput of hydrocarbon liquids Ioadout to transport vehicles greater than or equal to 5,000 barrels?
IThe hmdrocarboc liquid=_ Madout source is not suh€est'n •fttcpl i it 7 Pare D Section SI.C.S.
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is
not a rule or regulation, and the analysis it contains may not apply to a particularsituation based upon the individual facts and circumstances. This document does not change or substitute foranylaw,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing
regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may,""should,"and"can,"rs
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.
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: 15WE1427
AIRS ID Number: 123 / 9E0F /001
[Leave blank unless APCD has already assigned a permit u and AIRS ID)
Section 1 - Administrative Information
Company Name: Platte River Midstream, Inc.
Site Name: Lucerne West Station
Site Location: 21474 Co Rd 66
Greeley, CO 80631
Mailing Address:
(Include Zip Code) 501 South Coltrane Rd, Suite A
Edmond, OK 73034
Site Location
County: Weld
NAILS or SIC Code: 486110
Contact Person: Bret R. Sholar
Phone Number: 405-834-7825
E -Mail Addresst: Dret.Sholar@arbmidstream.com
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Forrn APCD 105 condensate Storage Iank(si APEN Revision 07;2020
11
434601
'COLORADO
ia�rawvee..s a
Permit Number: 15WE1427
AIRS ID Number: 123 / 9E0F / 001
{Leave blank unless APCD has all assigned a pernnt and AIRS ID]
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 $353.13
must be submitted along with the APEN filing fee.
-OR-
❑ MODIFICATION to existing permit (check eoch box below that applies)
Change in equipment ❑ Change company name;
▪ 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 Et Notes:
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
Section 3 - General Information
General description of equipment and purpose:
Company equipment Identification No. (optional):
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is: N/A
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7
❑ Exploration Et Production (E&P) site
days/week 52
weeks/year
❑� Midstream or Downstream (non E&P) site
Will this equipment be operated in any NAAQS nonattainment area?
Yes
No
O
■
Are Flash Emissions anticipated from these storage tanks?
Yes
No
■
SI
Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day?
Yes
No
O
■
If "yes', identify the stock tank gas -to -oil ratio:
N/A
m'/liter
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
■
D
Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
D
■
Farm .APCD•2O5 Condensate Storage TaniOs) APEN Revision 07/202.0
COLORADO
Permit Number: 15WE 1427 AIRS ID Number: 123 / 9E0F / 001
[Leave blank unless APCD has already assigned a permit = and .AIRS ID]
Section 4 - Storage Tank(s) Information
Actual Annual Amount
(bbl/year)
Requested Annual Permit Limits
(bbl/year)
Condensate Throughput:
7,300,000
From what year is the actual annual amount?
Average API gravity of sales oil: 60 degrees
l] Internal floating roof
N/A
Tank design: ❑ Fixed roof
RVP of sales oil: 11
❑ 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)
10
1,000(ea)
10/2016
10/2016
Wells Serviced by this Storage Tank or Tank Batteryb (E&P Sites Only)
API Number
Name of Well
Newly Reported Well
_
_ _
■
_
•
- -
■
-
■
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 EEtP 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)
40.463019, -104.648523
El 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)
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches):
Interior stack width (inches): Interior stack depth (inches):
Form APCb•2O5 Condensate Storage rank{si APEN • Revision 07/2020
coLon:OO
3 I >�i a
Permit Number: 15WE1427
AIRS ID Number: 123 / 9EOF / 001
[Leave blank unless APCD has abeady assigned a permit = and AIRS ID]
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:
Rating: MMBtu/hr
Type: Make/Model:
Requested Control Efficiency: %
Manufacturer Guaranteed Control Efficiency: %
Minimum Temperature: Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating:
Btu/scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled: VOC and HAP
Description: Internal Floating Roof
Control Efficiency Requested:
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)? psig
Describe the separation process between the well and the storage tanks:
Form APCD 205 Condensate Storage Tankts) APEN Revision 07/2020
AnkicoLokAoo
Permit Number: 15WE1427
AIRS ID Number: 123 /9E0F/ 001
[Leave. blank unless .APCD has alteady assigned a permit and AIRS ID]
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 requested control efficiencies (report the overall, or
combined, values if multiple emission control methods were identified in Section 6):
Pollutant
Control Equipment Description
Overall Requested
Control Efficiency
(% reduction in emissions)
VOC
Internal Floating Roof
NOx
N/A
CO
N/A
HAPs
Internal Floating Roof
Other:
N/A
From what year is the following reported actual annual emissions data? N/A
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
Unfts
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions$
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
VOC
AP -42
13.62
13.62
NO.
AP -42
CO
AP -42
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?
❑✓ 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
(AP -s2,
Mfg., etc.)
Uncontrolled
Emissions
(11,s/year)
Controlled
Emissions8
abs/year)
Benzene
71432
AP -42
244
244
Toluene
108883
AP -42
839
639
Ethylbenzene
100414
AP -42
390
390
Xylene
1330207
AP -42
1160
1180
n -Hexane
110543
AP -42
1559
1559
2,2,4-Trimethylpentane
540841
AP -42
32
32
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.
Form APC.D•2U5 C.onriensate Storage Tank(;) APEN Revision 07;2020
ICO�ORADO
5I ,co
Permit Number: 15WE1427
AIRS ID Number: 123 / 9E0F / 001
[Leave blank unless APCD has air each,' assigned a permit and AIRS ID]
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.
9/3/2020
Signature of Legally Authorized Person (not a vendor or consultant) Date
Bret R. Sholar
Environmental Manager
Name (print) Title
Check the appropriate box to request a copy of the:
Q Draft permit prior to issuance
E✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $216.00 and the General
Permit registration fee of $353.13, 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:
Cobrado 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
Form APCD-205 Condensate Storage Tank(s) APEN Revision 07/2020
6 I oICOIORADO
I>.ate,
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: 15WE 1427
AIRS ID Number: 123 / 9E0F / 005
[Leave blank unless APCD has abeady assigned a permit = and AIRS ID]
Section 1 - Administrative Information
Company Name': Platte River Midstream, Inc.
Site Name: Lucerne West Station
Site Location: 21474 Co Rd 66
Greeley, CO 80631
Mailing Address:
(Include Zip Code) 501 South Coltrane Rd, Suite A
Site Location
County: Weld
NAICS or SIC Code: 486110
Edmond, OK 73034 Contact Person: Rrpt R Shnlar
Phone Number: 405-834-7825
E -Mail Address?: Bret.Sholar@arbmidstream.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.
Fot APCD 205 Condensate Storage Tank(s) APED! Revision 07/2020
434602
eI`�:�
COLORADO
Permit Number: 15WE1427
AIRS ID Number: 123 / 9E0F / 005
[Leave blank unless APCD has already assigned a permit = and AIRS ID]
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 $353.13
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
• 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:
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:
For new or reconstructed sources, the projected start-up date is: Construction scheduled through August 2024
Normal Hours of Source Operation: 24 hours/day 7 days/week 52
Storage tank(s) located at:
❑ Exploration Et Production (E&P) site
n
weeks/year
Will this equipment be operated in any NAAQS nonattainment area?
Yes
No
GI
IN
Are Flash Emissions anticipated from these storage tanks?
Yes
No
■
n
Is the actual annual average hydrocarbon liquid throughput 2 500 bbl/day?
Yes
No
&I
■
If "yes", identify the stock tank gas -to -oil ratio:
N/A
m3/liter
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
■
n
Are you requesting 2 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions 2 6 ton/yr (per storage tank)?
Yes
No
GI
■
Foim AP(1) 205 Condensate Storage Tank(s) APEN Rev!<_ion 01/2020
COLORADO
2 nzra.
Permit Number: 15WE1427
AIRS ID Number: 123 / 9E0F / 005
[Leave blank unless APCD has alieacly assigned a permit and AIRS ID]
Section 4 - Storage Tank(s) Information
Actual Annual Amount
(bbf/year)
LCondensate Throughput:
From what year is the actual annual amount?
Average API gravity of sales oil: 60 degrees
ID Internal floating roof
N/A
Tank design: ❑ Fixed roof
Requested Annual Permit Limits
(bbUyear)
85,200,000
RVP of sales oil: 11
❑ External floating roof
Storage
Tank ID
if 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)
T-1501-1504
4
150,000(ea)
08/2017
N/A
Wells Serviced by this Storage Tank or Tank Battery6 (E&P Sites Only)
API Number
Name of Well
Newly Reported Well
■
■
■
■
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 EEtP 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)
40.463019, -104.648523
0 Check box if the following information is not applicable to the source because emissions will not be emitted
from a stack. If this is the case, the rest of this section may remain blank.
Operator Stack
ID No.
Discharge Height Above
Ground Level (Feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
❑ Upward with obstructing raincap
Indicate the stack opening and size: (check one)
❑ Circular Interior stack diameter (inches):
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD•2O5 Condensate Storage lank(si APEN • Revision 07/2020
�/S► 'COLORADO
3 >�r�litztr=
Permit Number: 15WE1427
AIRS ID Number: 123 / 9EOF /005
(Leave blank unless APCD has already assigned a permit and AIRS ID]
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:
Rating: MMBtu/hr
Type: Make/Model:
Requested Control Efficiency: %
Manufacturer Guaranteed Control Efficiency: %
Minimum Temperature:
Waste Gas Heat Content:
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating:
Btu/scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled: VOC and HAP
Description: Internal Floating Roof
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)? psig
Describe the separation process between the well and the storage tanks:
Form APC D•205 Condensate Storage Tank(si APEN Revision 07/2020
R/A00
4 I gel="�.�re.
Permit Number: 15WE1427
AIRS ID Number: 123 / 9E0F / 005
[Leave blank unless APCD has alreadv assigned a permit and AIRS ID)
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 requested control efficiencies (report the overall, or
combined, values if multiple emission control methods were identified in Section 6):
Pollutant
Control Equipment Description
Overall Requested
Control Efficiency
(% reduction in emissions)
VOC
Internal Floating Roof
NOX
N/A
CO
N/A
HAPs
Internal Floating Root
Other:
N/A
From what year is the following reported actual annual emissions data? N/A
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
Emissions 8
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
VOC
AP -42
28:5
28.5
NO„
AP -42
CO
AP -42
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?
r❑ Yes ❑ No
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
Chemical Name
Chemical
Abstract CAS
Service ( )
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(Ibs/year)
Controlled
Emissions8
(Ibs/year)
Benzene
71432
AP -42
479
479
Toluene
108883
AP -42
1647
1847
Ethylbenzene
100414
AP -42
788
788
Xylene
1330207
AP -42
2315
2315
n -Hexane
110543
AP 42
3058
3058
2,2,4-Trimethylpentane
540841
AP -42
63
63
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.
CFL -1119121
Form .APCD 205 Condensate Storage Tank(s) APEN Revision 07/2020
SO COLORADO
5 I ,r°'a�
Permit Number: 15WE 1427
AIRS ID Number: 123 / 9E0F / 005
[leave blank unless APCD has al, eady assigned a permit = and AIRS ID]
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.
9/3/2020
Signature of Legally Authorized Person (not a vendor or consultant) Date
Bret R. Sholar Environmental Manager
Name (print) Title
Check the appropriate box to request a copy of the:
El Draft permit prior to issuance
El Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $216.00 and the General
Permit registration fee of $353.13, 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
Form .APCD•205 Condensate Storage Tank(s) APED! • Revision 07/2020
OLORADO
61so:CD•petnet@W
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: 15WE1427
AIRS ID Number:
OD(o 8cG
/Islam
123 / 9E0F /.603 •
[Leave blank unless APCD has atready assigned a permit and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Site Location:
Platte River Midstream, Inc.
Lucerne West Station
21474 Co Rd 66
Greeley, CO 80631
Mailing Address:
(Include Zip Code) 501 South Coltrane Rd, Suite A
Edmond, OK 73034
Site Location
County: Weld
NAICS or SIC Code: 486110
Contact Person:
Phone Number:
E -Mail Addressz:
Bret R. Sholar
405-834-7825
Bret_Sholar@arbmidstream.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.
z Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD 208 Hydrocarbon Liquid Loading APEN - Revision 07/2020
434603
118.1
COLORADO
Weftlbl Weft lb
Additional Info 1-t Notes:
Permit Number: 15WE1427
AIRS ID Number:
[Leave blank unless APCD has aheady assigned a permit » and AIRS ID]
123 /9E0F/003
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 $353.13 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 ownership' ( 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)
9cc, "115 it
pa eVaV lG e✓
qd.J Ae‘A/ (o ada-t4-4-palKt, PY-4LVIDVS P0itAkownced.4 2-017
(062-)
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:
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
Yes
No
l7
■
Is this equipment located at a stationary source that is considered a Major Source of (HAP)
emissions?
Yes
No
■
GI
Does this source load gasoline into transport vehicles?
Yes
No
■
GI
Is this source located at an oil and gas exploration and production site?
Yes
No
■
p
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual
average?
Yes
No
■
GI
Does this source splash fill less than 6,750 bbl of condensate per year?
Yes
No
El
■
Does this source submerge fill less than 16,308 bbl of condensate per year?
Yes
❑✓
No
■
rolm .APCD•208 Hydrocarbon Liquid Loading APEN Revision 07!2020
21ift41111
COLORADO
c,.r.w<e,mee
Haft lo Zwrinmaral
Permit Number: 15WE1427
AIRS ID Number: 123 / 9EOF / 003
[Leave: blank unless APCD has already assigned a permit and AIRS ID]
Section 4 - Process Equipment Information
Product Loaded: ❑Q Condensate ❑✓ Crude Oil ❑ Other:
If this APEN is being filed for vapors displaced from cargo carrier, complete the following:
Requested Volume Loadeds:
see ie l ishb pee e-" Vr
This product is loaded from tanks at this faci ity into:
(e.g. "rail tank cars" or "tank trucks")
I ttgo, Oc0
bbl/year
Actual Volume Loaded:
bbl/year
If site specific emission factor is used to calculate emissions, complete the following:
Saturation Factor:
Average temperature of
bulk liquid loading:
F
True Vapor Pressure:
Psia @ 60 F
Molecular weight of
displaced vapors:
lb/lb-mol
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume Loadeds:
bbl/year
Actual Volume Loaded:
bbl/year
Product Density:
lb/ft3
Load Line Volume:
ft3/truckload
Vapor Recovery Line Volume:
ft3/truckload
s 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)
40.463019, -104.648523
❑ 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.
,Opeotor
Stack' D No. -:
Discharge Height Above
Ground Level (Feet)
Temp
ir' ,,.....: • .
Flow Rate
otam)
Velocity
(fusee)
005
22
900
46
Indicate the direction of the stack outlet: (check one)
0 Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches): 12
Interior stack width (inches): Interior stack depth (inches):
Form .APCC1•208 Hydrocarbon Liquid Loading APEN Revision 07/2020
ICOlORA00
3I I�
Permit Number: 15WE1427
AIRS ID Number: 123 / 9E0F / 003
[Leave blank unless APCD has already assigned a permit ; and AIRS ID]
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.
❑ Loading occurs using a vapor balance system:
Requested Control Efficiency: %
a Combustion
Device:
Used for control of: Truett Loading
Rating: 12 MMBtu/hr
Type: Enclosed Flare Make/Model: TBD
Requested Control Efficiency: 98 %
Manufacturer Guaranteed Control Efficiency: 99 %
Minimum Temperature: 900 F Waste Gas Heat Content: 1970 Btu/scf
Constant Pilot Light: ❑ Yes No Pilot Burner Rating: MMBtu/hr
Pollutants Controlled:
Description:
Requested Control Efficiency:
❑ Other:
Section 7- Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? El Yes ❑ No
If yes, describe the control equipment AND state the requested control efficiencies (report the overall, or
combined, values if multi ole emission control methods w '
ere id entif
led in Section 6):
Pollutant
Control Equipment Description
P
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SO.
NO.
CO
VOC
vcu
98%
HAPs
Other:
❑ Using State Emission Factors (Required for GP07)
❑ Condensate
❑ Crude
VOC Benzene n -Hexane
0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL
0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL
From what year is the following reported actual annual emissions data?
Use the following table to re
Pollutant
Emission
- -----'--.•,••�.....♦S...
Factor
uaalVlfa Ilvlll Jvul LC.
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -4Z,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissionsb
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
0.03
0.03
SOx
0.22
0.22
NO.
028
0.26
CO
1.501.50
VOC
229.6
7.52
5 Requested values will become permit limitations or wilt be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
Form .APCD 208 Hydrocarbon Liquid Loading APEN Revision 07/2020
4
COLORADO
�iWo
Permit Number: 151NE1427
AIRS ID Number:
[Leave blank unless APCD has already assigned a permits and AIRS ID]
123 /9E0F/003
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 reoort the non -
❑r Yes ElNo
Chemical Name
Chemical
Abstract (CAS
( )
Number
_..__. .-. �..„..
Emission
,,,,.... 1.,r., 7 ,uuaawiq II VIII
Factor
WAX I.C.
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(ibs/year)
Controlled
Emissionsb
(ibs/year)
Benzene
71432
Mau Bal.
4115
135
Toluene
108883
Mass Bel.
14155
463
Ethylbenzene
100414
Mass Bal.
6561
215
Xylene
1330207
Mass Bat.
19897
651
n -Hexane
110543
Mass Bal.
26288
661
2,2,4-Trimethylpentane
540841
Mass Bal.
542
18
Other:
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
Section 9 - Applicant Certlficatlon
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source
is and will be in full compliance wit,each condition of General Permit GP07.
9/3/2020
Signature of Legally Authorized Person (not a vendor or consultant) Date
Bret R. Sholar Environmental Manager
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 $216.00 and the General
Permit registration fee of $353.13, 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
Foram APCD•208 Hydrocarbon liquid Loading APEN Revision 07/2020
Ogg
> gg
COLORADO
14601110•Ontesomant
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