HomeMy WebLinkAbout20210478.tiffCOLORADO
Department of Public
Health S Environment
Weld County - Clerk to the Board
1150 0 St
PO Box 758
Greeley, CO 80632
February 8, 2021
Dear Sir or Madam:
RECEIVED
FEB 16 2021
WELD COUNTY
COMMISSIONERS
On February 9, 2021, the Air Pollution Control Division will begin a 30 -day public notice period for
Aka Energy Group, LLC - Wiedeman Compressor 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 Ft 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
4_
Pub is Rev; eGJ
oalam /2i
cc: PLem), HL(Ds/rR),Po(sm/sR1cH/OO,
O6Csm)
oa /IV21
2021-0478
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Aka Energy Group, LLC - Wiedeman Compressor Station - Weld County
Notice Period Begins: February 9, 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: Aka Energy Group, LLC
Facility: Wiedeman Compressor Station
Natural gas compressor station
SWNE Section 29, T4N R66W
Weld County
The proposed project or activity is as follows: Applicant requests a permit for a new TEG dehydration unit
(35 MMscfd) at an existing compressor station in the ozone non -attainment area of Weld County. This
modification requests a new synthetic minor limit for NANSR for VOC.
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 20WE0709 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Andy Gruel
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
ICOLORADO
Department of Public
Health 6 Environment
COLORADO
Air Pollution Control Division
Department of public Health Er Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Permit number:
Date issued:
Issued to:
CONSTRUCTION PERMIT
20WE0709 Issuance:
Facility Name:
Plant AIRS ID:
Physical Location:
County:
Description:
Aka Energy Group, LLC
Wiedeman Compressor Station
123/9CD2
SWNE Section 29, T4N R66W
Weld County
Natural Gas Compressor Station
Equipment or activity subject to this permit:
1
Equipment
ID
AIRS
Point
E ui ment Descri tlon
q p p
Emissions Control
Description
---
007
One (1) Triethylene glycol (TEG) natural gas
dehydration unit (Make: Exterran, Model: 1
MMBTU/hr, Serial Number: 12303) with a design
capacity of 35 MMscf per day. This emissions
unit is equipped with 2 (Make: Hydra -Cell,
Model: D15X) electric driven glycol pumps with
a design capacity of 10.83 gallons per minute.
This dehydration unit is equipped with a still
vent, flash tank, and reboiler burner.
Emissions from the still vent
are routed to an air-cooled
condenser and then to an
enclosed combustion device,
or recovered by vapor
recovery unit as backup.
Emissions from the flash tank
are recovered using a vapor
recovery unit, or recycled to
the facility inlet as backup.
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. 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.
Page 1 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit shall be
demonstrated to the Division. It is the owner or operator's responsibility to self -certify
compliance with the conditions. Failure to demonstrate compliance within 180 days may
result in revocation of the permit. A self certification form and guidance on how to self -
certify compliance as required by this permit may be obtained online at
www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section
III.G.2.)
3. This permit shall expire if the owner or operator of the source for which this permit was
issued: (i) does not commence construction/modification or operation of this source within 18
months after either, the date of issuance of this construction permit or the date on which
such construction or activity was scheduled to commence as set forth in the permit
application associated with this permit; (ii) discontinues construction for a period of eighteen
months or more; (iii) does not complete construction within a reasonable time of the
estimated completion date. The Division may grant extensions of the deadline. (Regulation
Number 3, Part B, Section III.F.4.)
4. The operator shall complete all initial compliance testing and sampling as required in this
permit and submit the results to the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
5. The following information shall be provided to the Division within fifteen (15) days of the
latter of commencement of operation or issuance of this permit.
The dehydrator manufacturer name, model number and serial number
The glycol circulation pump manufacturer name and model number
This information shall be included with the Notice of Startup submitted for the equipment.
(Regulation Number 3, Part B, III.E.)
6. The operator shall retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3,
Part B, Section I I.A.4. )
Monthly Limits:
Equipment
ID
AIRS
Point
Pounds per Month
Emission
Type
PM2.5
NO,
VOC
CO
---
007
---
---
1052
797
Point
Note: Monthly limits are based on a 31 -day month.
Page 2 of 14
COLORADO
Air Pollution Control Division
Department of Public Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
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.
Annual Limits:
Equipment
ID
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NO,
VOC
CO
---
007
---
---
6.2
4.7
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 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.
8. The owner or operator must track emissions from all insignificant activities at the facility on
an annual basis to demonstrate compliance with the facility emission limitations as indicated
below. An inventory of each insignificant activity and associated emission calculations must
be made available to the Division for inspection upon request. For the purposes of this
condition, insignificant activities are defined as any activity or equipment, which emits any
amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt.
(Regulation 3, Part C. II.E.)
Total potential emissions from the facility, including all permitted emissions and potential to
emit from all insignificant activities, must be less than:
• 50 tons per year of VOC.
Page 3 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
9. Compliance with the emission limits in this permit shall be demonstrated by running the GRI
GlyCalc model version 4.0 or higher on a monthly basis using the most recent extended wet
gas analysis and recorded operational values, including: dry gas throughput, lean glycol
recirculation rate, vapor recovery unit (VRU) downtime, flash tank temperature and pressure,
wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except
for gas throughput, shall be averaged on a monthly basis for input into the model and be
provided to the Division upon request.
10. On a daily basis, the owner or operator shall monitor and record operational values including:
vapor recovery unit (VRU) downtime, flash tank temperature and pressure, wet gas inlet
temperature and pressure. These records shall be maintained for a period of five years.
11. The owner or operator shall operate and maintain the emission points in the table below with
the emissions control equipment as listed in order to reduce emissions to less than or equal to
the limits established in this permit. The owner or operator shall operate this dehydration
unit so as to prevent any emissions directly to the atmosphere. (Regulation Number 3, Part B,
Section III`.E.)
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
---
007
Still vent
VOC and HAP
Primary: Enclosed combustion device
Secondary: Vapor Recovery Unit
12. The owneroroperator shall operate and maintain the emission points in the table below as a
closed loop system and shall recycle 100% of emissions as described in the table below.
(Regulation Number 3, Part B, Section III.E.)
Equipment
ID
AIRS
Point
Emissions Recycling Description
Pollutants
Recovered
---
007
Flash Tank
VOC and HAP
Primary: Vapor Recovery Unit
Secondary: Recycled to the facility inlet
PROCESS LIMITATIONS AND RECORDS
13. 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. )
Page 4 of 14
COLORADO
Air Pollution Control Division
Department of Public Health fr €nwonment
Dedicated to protecting and improving the health and environment of the people of Colorado
Process Limits
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
Monthly Limit
---
007
Dry Gas Throughput
12,775
MMscf/yr
1,085
MMscf/month
Note: The monthly limit is based on 31 days.
The owner or operator shall monitor monthly process rates based on the calendar month. The
volume of dry gas throughput shall be measured by gas meter at the outlet of the dehydrator.
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 only the 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.
14. This unit shall be limited to the maximum lean glycol circulation rate of 5 gallons per minute.
The lean glycol recirculation rate shall be recorded daily in a log maintained on site and
made available to the Division for inspection upon request. Glycol recirculation rate shall be
monitored by one of the following methods: assuming maximum design pump rate, using
glycol flow meter(s), or recording strokes per minute and converting to circulation' rate. This
maximum glycol circulation rate does not preclude compliance with the optimal glycol
circulation rate (Loft) provisions under MACT HH. (Reference: Regulation Number 3, Part B,
II.A.4)
STATE AND FEDERAL REGULATORY REQUIREMENTS
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. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of
the source. During periods of startup, process modification, or adjustment of control
equipment visible emissions shall not exceed 30% opacity for more than six minutes in any
sixty consecutive minutes. (Regulation Number 1, Section II.A.1. Et 4.)
17. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
18. This source is subject to Regulation Number 7, Part D, Section I.H. The operator shall comply
with all applicable requirements of Section I and, specifically, shall:
Page 5 of 14
COLORADO
Air Pollution Control Division
Department of Pubhc Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for glycol natural gas dehydrators; and
• Ensure uncontrolled actual emissions of volatile organic compounds from the still vent
and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash
tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month
basis through the use of a condenser or air pollution control equipment. (Regulation
Number 7, Part D, Section I.H.1.)
19. The combustion device covered by this permit is subject to Regulation Number 7, Part D,
Section II.B General Provisions (State only enforceable). If a flare or other combustion device
is used to control emissions of volatile organic compounds to comply with Section II, it shall
be enclosed; have no visible emissions during normal operations, as defined under Regulation
Number 7, Part D, II.A.23; and be designed so that an observer can, by means of visual
observation from the outside of the enclosed flare or combustion device, or by other
convenient means approved by the Division, determine whether it is operating properly. This
flare must be equipped with an operational auto -igniter according to the following schedule:
• All combustion devices installed on or after May 1, 2014, must be equipped with an
operational auto -igniter upon installation of the combustion device;
• All combustion devices installed before May 1, 2014, must be equipped with an
operational auto -igniter by or before May 1, 2016, or after the next combustion device
planned shutdown, whichever comes first.
20. The glycol dehydration unit covered by this permit is subject to the emission control
requirements in Regulation Number 7, Part D, Section II.D.3. Beginning May 1, 2015, still
vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator
located at an oil and gas exploration and production operation, natural gas compressor
station, or gas -processing plant subject to control requirements pursuant to Section II.D.4.,
shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling
twelve-month basis through the use of a condenser or air pollution control equipment.
21. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator
of oil and natural gas operations and equipment at or upstream of a natural gas processing plant
in Colorado must submit a single annual report that includes actual emissions and specified
information in the Division -approved report format. The information included in the annual
report must be in accordance with the general reporting requirements of Regulation Number 7,
Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or
operators must maintain the information according to Regulation Number 7, Part D, Section
V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V)
22. The glycol dehydration unit at this facility is subject to National Emissions Standards for
Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities,
Subpart HH. This facility shall be subject to applicable area source provisions of this
regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E,
Subpart A and HH)
Page 6 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Ennronment
Dedicated to protecting and improving the health and environment of the people of Colorado
MACT HH Applicable
Requirements
Area Source
Benzene emissions exemption
563.764 - General
Standards
563.764 (e)(1) - The owner or operator is exempt from the
requirements of paragraph (d) of this section if the criteria listed
in paragraph (e)(1)(i) or (ii) of this section are met, except that
the records of the determination of these criteria must be
maintained as required in 563.774(d)(1).
563.764 (e)(1)(ii) - The actual average emissions of benzene from
the glycol dehydration unit process vent to the atmosphere are
less than 0.90 megagram per year, as determined by the
procedures specified in 563.772(b)(2) of this subpart.
563.772 - Test
Methods,
Compliance ;
Procedures and
Compliance ``
Demonstration
563.772(b) - Determination of glycol dehydration unit flowrate or
benzene emissions. The procedures of this paragraph shall be
used by an owner or operator to determine glycol dehydration
unit natural gas flowrate or benzene emissions to meet the
criteria for an exemption from control requirements under
563.764(e)(1).
563.772(b)(2) - The determination of actual average benzene
emissions from a glycol dehydration unit shall be made using the
procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this
section. Emissions shall be determined either uncontrolled, or
with federally enforceable controls in place.
563.772(b)(2)(i) - The owner or operator shall determine actual
average benzene emissions using the model GRI-GLYCalc TM,
Version 3.0 or higher, and the procedures presented in the
associated GRI-GLYCalc TM Technical Reference Manual. Inputs to
the model shall be representative of actual operating conditions
of the glycol dehydration unit and may be determined using the
procedures documented in the Gas Research Institute (GRI) report
entitled "Atmospheric Rich/Lean Method for Determining Glycol
Dehydrator Emissions" (GRI-95/0368.1); or
563.772(b)(2)(ii) - The owner or operator shall determine an
average mass rate of benzene emissions in kilograms per hour
through direct measurement using the methods in 563.772(a)(1)(i)
or (ii), or an alternative method according to 563.7(f). Annual
emissions in kilograms per year shall be determined by
multiplying the mass rate by the number of hours the unit is
operated per year. This result shall be converted to megagrams
per year.
563.774 -
Recordkeeping
Requirements
563.774 (d)(1) - An owner or operator of a glycol dehydration
unit that meets the exemption criteria in §63.764(e)(1)(i) or
§63.764(e)(1)(ii) shall maintain the records specified in paragraph
(d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for
that glycol dehydration unit.
Page 7 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
563.774 (d)(1)(ii) - The actual average benzene emissions (in
terms of benzene emissions per year) as determined in
accordance with 563.772(b)(2).
OPERATING £t MAINTENANCE REQUIREMENTS
23. Upon startup of these points, the owner or operator shall follow the most recent operating
and maintenance (OB.M) plan and record keeping format approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions
to the 0&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
24. The owner or operator shall demonstrate compliance with opacity standards, using EPA
Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence
of visible emissions. "Visible Emissions" means observations of smoke for any period or
periods of duration greater than or equal to one minute in any fifteen minute period during
normal operation. (Regulation Number 7, Part D, Sections II.B.2. and II.A.23)
Periodic Testing Requirements
25. The owner or operator shall complete an extended wet gas analysis prior to the inlet of the
dehydration unit on an annual basis. Results of the wet gas analysis shall be used to calculate
emissions of criteria pollutants and hazardous air pollutants per this permit and be provided
to the Division upon request.
ADDITIONAL REQUIREMENTS
26. 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 (NOx) in ozone
nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
Page 8 of 14
i
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
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.
27. The requirements of Colorado Regulation Number 3, Part D must apply at such time that any
stationary source or modification becomes a major stationary source or major modification
solely by virtue of a relaxation in any enforceable limitation that was established after August
7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a
restriction on hours of operation; (Regulation Number 3, Part D, Section VI.B.4/V.A.7.B).
With respect to this Condition, Part D requirements may apply to future modifications if
emission limits are modified to equal or exceed the following threshold levels:
AIRS
Point
Equipment Description
Pollutant
Emissions - tons per year
Threshold
Current
Permit Limit
(permit -
required
points only)
001
Caterpillar G3516B
VOC
NOx
50
50
43.5
34.1
002
Caterpillar G3516B
003
Caterpillar G3516B
004
Caterpillar G3516B
005
Caterpillar G3516B
006
Condensate storage tanks
007
TEG dehydration unit
---
Insignificant Sources
(APEN- and/or permit -
exempt)
Page 9 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Note: APEN and permit exempt sources do not have permit limits. However, the PTE of these sources
(excluding fugitives) is still considered in the project increase when evaluating PSD and NANSR.
GENERAL TERMS AND CONDITIONS
28. 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.
29. 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 cornmences'`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.
30. 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.
31. 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.
32. 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.
33. 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
Page 10 of 14
COLORADO
Air Pollution Control Division
Department of PubIto Health Fs Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Division in writing requesting a cancellation of the permit. Upon notification, annual fee
billing will terminate.
34. 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:
Andy Gruel, P.E.
Permit Engineer
Permit History
Issuance
Date
Description
• Issuance 1
This Issuance
Issued to Aka Energy Group, LLC.
Page 11 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Enwonment
Dedicated to protecting and improving the health and environment of the people of Colorado
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder 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: hltris'PA,/ .colorado rto� pacificicdphc:iagc -``egs
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.
Equipment
ID
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(lb/yr)
---
007
Benzene
71432
34,795
1,740
Toluene
108883
44,913
2,246
Ethylbenzene
100414
854
43
Xylenes
1330207
15078
754
n -Hexane
110543
6535
327
224 TMP
540841
<1
<1
Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year
(lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice.
5) The emission levels contained in this permit are based on information provided in the application
and the GRI GlyCalc 4.0 model. Controlled emissions are based on a enclosed combustion device
control efficiency of 95%.
Total actual flash tank and still vent combustion emissions are based on the sum of the emissions for
the still vent primary control, still vent secondary control, flash tank primary control and flash tank
secondary control. Total combustion emissions are based on the following emission factors:
Page 12 of 14
COLORADO
Air Pollution Control Division
Department of Public Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Still Vent Primary Control (Enclosed Combustion Device)
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf Waste
Gas Combusted
Source
PKO
1.5
AP -42 Table 1-4-2
PM2.s
1.5
SOx
0.1
NOx
12.8
TNRCC RG-109
Table 4
CO
109.9
Note: The combustion emission factors are based on a heating value of 200 Btu/scf. Actual emissions are calculated by
multiplying the emission factors in the table above by the waste gas flow from the regenerator overheads stream in the
monthly GlyCalc report and by the hours per month the waste gas was routed to this control device.
Still Vent Secondary Control:
When the enclosed combustion device is down, still vent emissions are sent to the VRU.
Flash Tank Primary Control:
Flash tank emissions are recovered using a vapor recovery unit.
Flash Tank Secondary Control:
Flash tank emissions are sent to the facility inlet using a closed -loop system when the VRU is down.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A
revised APEN shall be submitted no later than 30 days before the five-year term expires. Please
refer to the most recent annual fee invoice to determine the APEN expiration date for each
emissions point associated with this permit. For any questions regarding a specific expiration date
call the Division at (303)-692-3150.
7) This permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration unit
and associated control device per the Colorado Oil and Gas Conservation Commission rule
805b(2)(B) when applicable.
Page 13 of 14
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
8) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of: VOC, CO, HAPs (benzene, toluene,
formaldehyde, and total)
NANSR
Synthetic Minor Source of: VOC
MACT HH
Area Source Requirements: Applicable
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://www.ecfr.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart UUUU
NSPS
Part 60, Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
MALT.
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
Page 14 of 14
Colorado Air Permitting Project
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer:
Package #:
Received Date:
Review Start Date:
For Division Use Only
Addy Gruel
334472:`
3/7/2020'
11/9/2020,:,...:::
Section 01- Facility Information
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
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?
jCD2
'atedernan Compressort
SW NE Section 29 T66JJ =n4N
Section 02 - Emissions Units In Permit Application
Quadrant
Section
Township
Range
23
afs,
AIRS Point #
(Leave blank unless
APCD has already
assigned)
07
Emissions Source Type
Deinincirator'.
Equipment Name
Emissions
Control?
Permit #
(Leave blank unless
APCD has already
assigned)
ENDS
Section 03 - Description of Project
Leave Blank - For Division Use Only
Issuance
Self Cert
Engineering
Action
#
Required?
Remarks
Petder in
1
Yes
' u-.
-
e pplinant: e ,n. sts a cFr:nit for rts n
This modification retie sts are s
TE6 d.atio -, . t ,35 iVIIV SCFD) at an e< sting compressor .ration idlhe awe d.onattainr,;ent area
eiic minor limit for.f;r,41V5R sc
Sections 04, 05 &
06 - For Division Use Only
Section 04 - Public Comment Requirements
Is Public Comment Required? es `
Ifyes, why? -;oju-s.i-g5, +n-trT>f1t c nit
Section 05 - Ambient Air Impact Analysis Requiremer
Was a quantitative modeling analysis required? No
If yes, for what pollutants?
If yes, attach a copy of Technical Services Unit modeling results summary.
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor? No: r
Is this stationary source a synthetic minor? Yes,
If yes, indicate programs and which pollutants: SO2 NOx CO
Prevention of Significant Deterioration (PSD) ❑ 000
Title V Operating Permits (OP) ❑ ❑ 0
Non -Attainment New Source Review (NANSR) ❑
Is this stationary source a major source? ap
If yes, indicate programs and which pollutants: SO2 NOx CO
Prevention of Significant Deterioration (PSD) 00000
Title V Operating Permits (OP) 0000
Non -Attainment New Source Review (NANSR) ❑
VOC
ID
2
VOC
❑
PM2.5
❑
❑
PM2.5
❑
PM10 TSP HAPs
❑
❑ ❑ El
PM30 TSP HAPs
❑
000
_
Glycol Dehydrator Emissions Inventory
Section 01 -Administrative Information
'Facility AlRs ID:
County
seD2
Plant
007
Point
Section 02 -Equipment Description Details
Dehydrator Information
Dehydrator Type:
Make:
Model:
Serial Number:
Design Capacity:
Recirculation Pump Information
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recirculation Rate:
Dehydrator Equipment
Flash Tank
Reboiler Burner
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
MMsd/day
gallons/minute
flash tank,
and reboiier burner
One Ili Tesshylene glycol (t EG, isatinal gas dehydration unit INleke Entoeven 11..novo 1 f1lnRtu.'hr soon, saumhe. 12-10h old. a aann "'panty of 39 nNMSA nor day
.n.>111e.lurpoed with Reba Hvdra.Sell, Model DI5'tt&act, d..ter evta. a de ogn:dowdy of iJ 63 „a:nn, pea minute Tlr•. deft -van tin•
s enn.oded With d so. .ent flasn teen and retold., Wave.
n from Inn ' v r r�led,ondcraer ad .. d _ .:nda.. :ol, ow,. do, .e�t endas1on rN . .doted ..
V9;; :.hen Pare ,ioxn•Ennis un> 4o•h td,.na�..ar:k SI.. - :.led arteCive°.. 4 e vow:.vow:.decoys -f l,nd:l RCy A, a no n thOy coot..;, , r e dash tank en. tslanarara
rained to the closed,loap ardent .
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions- Dehydrator Still Vent and Flash Tank (if present)
IRequested Permit Umit Throughput=
Potential to Emit (PTE) Throughput= 12.775 MMscf per year
MMscf per year Requested Monthly Throughput=
1335 MMsd per month
Secondary Emissions - Combustion Device(s) for Air Pollution Control
Still Vent Control
Condenser:
Condenser emission reduction claimed:
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Still Vent Gas Heating Value:
Still Vent Waste Gas Vent Rate:
Flash tank Control
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
Requested Condenser Outlet Temperature:
' 95% Control Efficiency %
hr/yr Requested TO Temp
100% Control Efficiency %
Section 04 - Emissions Factors & Methodologies
hr/yr
45 Btu/scf
sdh
Degrees F
Degrees
Dehydrator
Thai VIVO. ttsedGRLGIV.ss4.0to estimate emfssionc. Wet gaz.Mposition,pies.. and temperature are based on a site-spear.°etended wet gas
eneiysbLitfacted 3/3/2020. Controlled Ehs assuma95%-control of bath still vent and flash tank emissions. Combustion emission am assumed at the
maXfmpm Gainer ratingof 19 MMBtu/hr and a gas heat content of 2009tu/scf,
ECD burner rating:
Assumed gas heat content:
Maximum waste gas to ECD:
Input Parameters
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
1,85 r . - MMBtu/hr maximum burner rating, plus OAS MMetu/br for pilot
2SKX Btu/sdf from GlyCALC output
slat MMscf/Yr
psig
deg F
gpm
used for NOx/CO/PM/SCA emission wic
STILL VENT
Contml Scenario
Primary
Secondary
Pollutant
Uncontrolled(Ib/hr)
Controlled(Ib/hr)
Controlled (1b/hr)
VOC
16922E
0.8=6
0.03_3
Benzene
3.82
0.191
0.x99
Toluene
4.98
0249
0.0125
Ethylbenzene
9.58E-02 ...
0.035
0.000:
Xylenes
1,7 :.
0.085
0.0044
n -Hexane
3.54E-01 ..
0.018
O.J0e4
224-TP4P
0 -.
-
0J
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled(Ib/hr)
Controlled(Ib/hr)
VOC
1136953
-.
0.568
0.02821
Benzene
0:1620.
.,.008
000041
Toluene
1.47E-31
' _
..._,'
0.00027
Ethylbenzene
-
1.73E-03
5 5551
0.000064
Xyienes
2.12E-02
-..
__..
0.00005
n-Hezane
-
992E-01
..
..._..-
,��.
0 0003
224 -IMP
0
_
0.0
Emission Factors
Pollutant
Toluene
Ethylbenzene
Xylen
n -Hexane
224 TMP 0
Glycol Dehydrator
Uncontrmled
(Ib/MMscf)
Controlled
(Ib/MMscf)
(Dry Gas Throughput) (Dry Gas Throughput)
3.52 0.18
0.07 0.063
1.18 vv".05
0.51 0 03
Emission Factor Source
Dry GasThmuehnut:
Still Vent Primary Control: 12.)75.0 MMscf/yr IA65.-MMsd/month
Still Vent Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 0.0 MMscf/Yr JA MMscf/month
Still Vent Secondary Control: 0 2 MMsd/yr
Dry Gas Throughput:
Flash Tank Primary Control: 12,f 15 - MMscf/yr
Flash Tank Secondary Control: 0 J MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 0 0 MMsd/yr
Flash TankSecandary Control: : e MMscf/yr
Glycol Dehydrator Emissions Inventory
Pollutant
Control Device
Emission Factor Source
Uncontrolled Uncontrolled
(Ib/MMBtu) (Ib/MMsef)
(Waste Heat
Combusted)
(Waste Gas
Combusted)
PM10
0,0075
1.5
rTeble1,4-0171110; I-06.7.5:
.ssabi ii !
T Hlgv2 t )
_ e
PM2.5
0,0075
1.4
sox
O.OOi)fi
0 1
NOx
0641
13.R
CO
0.0496
103 9
Section 05 - Emissions Inventory
Did operator request a buffer?
Requested Buffer (°h):
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tans/year) (tons/year)
Requested Monthly
Limits
Controlled
(Ibs/month)
PM10
0.1
0.1
0.1
0.004
3.064
11
PM2.5
0.1
C I
0.1
6.064
0.003
it
SOx
0.0
CO
0-JOS
0.005
1
NOx
0.5
3
055
_
VOC
123.3
114n
0.2
__._
_
105
CO
4.?
4.649
3.09
297
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
34795
m7.5
1740
36296
MO
44913
44.1?
2138
444913
1:36
854
853
43
353
43
15028
15018
z:.4
150:'8
7S4
6535
317
5535
32:
0
0
a
.,
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Part D, Section II.B & II.D
Regulation 7, Part D, Section II.B.2.e
Regulation 7, Part D, Section I.H
Regulation 8, Part E, MACr Subpart HH (Area)
Regulation 8, Part E, MACF Subpart HH (Major)
Regulation 8, Part E, MACT Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
e i"d,at_r s sublec`to Regulation 7. Parr D. Sect.on II B. D.3
The weir. Mom in-'n:S deiwdemor is not sub'em to Reguiat.en 7 Part D Sactmo n q ,+, z
DeMdrawa subject_o regulation r, Farr C. Seat_e Sri
.:e denv::na ma is the benzepe esmont.or
IYauhave md.c'ated the”lasfacility 0not suo.ect to Mmor Snot: e'egnlrements pt ACT HH,
V. have led'sated that this tardily isnot anb;eJ LJ 1s;4CF HFH
Section 07- Initial and Periodic Sampling and Testing Requirements
Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a year of
application submittal?
If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limits
Does the company requests control device efficiency greater than 95% for a flare or combustion device?
Ryes, the permit will contain initial and periodic compliance testing in accordance with Ps Memo 20-02
lithe company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it?
NO
If yes, the permit will contain an "Initial Compliance" stack testing requirement AND the permit will contain a condition spedfying the minimum combustion chamber temperature for the thermal oxidizer based on
the O&M plan and application. Once a stark test Is approved by the division, the minimum combustion chamber temperature will be based on the most recent stack test results.
Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F?
If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal
oxidizer based on the O&M plan and application. Once a stack test is approved by the division, the minimum combustion chamber temperature will be based on the most recent
stack test results.
Section 08 Technical Analysis Notes
-Applfbaninindetedgash tank and regeneratacsent 6missfatlsex31r150LY.CaIc. Fieghtenk emissiehswi0
' emissions anti im senttoacondenser, and ernimienxfram theonndennervent Will then be sent to nom
e missions assent to the facility inlet using a closed loop nysteen when the VRU is down; candenservent emirs
t ombustion device is dawn fThe aeon. neamornedthat 95hatzamhined SAX and MP- emissions are centraited
Mx and CO ennsstctn factors ere from TNH CPublication hOspdf.'ioble4, for hares Ming fprwBimSas(<1000 httonch,
Section 09-SCC Coding and Emissions Factors (For Inventory Use Only(
AIRS Point p
Process
OS
scC code
ry unft. Regenerator vent
ashtank
hen the
sin requirements to adequamtydemanstrate antra! emissions.
Pollutant
PM10
PM2.5
50x
NOx
VOC
CO
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Uncontrolled
Emissions Factor Control %
O PLC 00
00.0 00
0001 00
a 036
11 6
5.510
6 Cot
1 130
0 5:1
ca
s
v5 d
85.3
35 0
9 .)
31.7
Units
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMsbf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
b/MMscf
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
FACILITY EMISSION SUMMARY
Company Name
County AIRS ID
Plant AIRS ID
Facility Name
Aka Energy Group, LLC
1232
9CD2
Wiedeman Compressor Station
History File Edit Date
Ozone Status
12/7/2020
Non -Attainment
EMISSIONS - Uncontrolled (tons per year)
EMISSIONS With Controls (tons per year)
POINT
AIRS
ID
PERMIT
Description
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug
VOC
CO
Total
HAPs
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug
VOC
CO
Total
HAPs
REMARKS
-
Previous FACILITY TOTAL
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
D.0
0.0
0.0
0.0
0.0
0.0
0.0
No previous history file available
Previous Permitted Facilit i total
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
0.0
0.0
0.0
0.0
0.0
001
GP02
Cat G3516B, sn_ JEF02774
0.5
0.5
0.0
6.7
12.5
33.6
7.1
0.5
0.5
0.0
6.7
6.3
8.4
2.1
Emissions from 3/8/19 APEN Update
002
GP02
Cat G35168, sn: JEF02752
0.5
0.5
0.0
6.7
12.5
33.6
7.1
0.5
0.5
0.0
6.7
6.3
8.4
2.1
Emissions from 3/8/19 APEN UPdate
003
GP02
Cat G3516B, sn: JEF02766
0.5
0.5
0.0
6.7
12.5
33.6
7.1
0.5
0.5
0.0
6.7
6.3
8.4
2.1
Emissions from 3/8/19 APEN Update
004
GP02
Cat G3516B, sn: JEF03326
0.5
0.5
0.0
6.7
12.5
33.6
7.1
0.5
0.5
0.0
6.7
6.3
8.4
2.1
Emissions from 3/8/19 APEN Update
005
GP02
Cat G3516B, sn: JEF03340
0.5
0.5
0.0
6.7
12.5
33.6
7.1
0.5,
0.5
0.0
6.7
6.3
8.4
2.1
Emissions from 3/8/19 APEN Update
006
GP01
Condensate tanks (2 x 30obbl)
5.8
0.3
5.8
0.3
Emissions from 3/8/19 APEN Update. See Note
1 below
007
20WE0709
TEG Dehy, 35 MMscfd
0.1
0.1
0.0
0.6
123.9
4.7
51.1
0.1
0.1
0.0
0.6
6.2
4.7
2.6
Aug 2020: new application
0.0
0.0
0.0
0.0
APEN-Exempt / Insignificants
Tank heaters (2)
0.1
0.1
0.0
0.8
0.0
0.8
0.1
0.1
0.1
0.0
0.8
0.0
0.8
0.1
From Aug 2020 Form 102
Condensate loadout
0.2
0.0
0.2
0.0
From Aug 2020 Form 102
Fugitives
0.1
0.0
0.1
0.0
From Aug 2020 Form 102
FACILITY TOTAL
2.6
2.6
0,0
0.2
34.9
192.5
0.1
173.5
87.0
2.6
2.6
0.0
0.2
34.9
43.7
0.1
47.5
13.4
VOC: Syn Minor (NANSRand OP)
NOx: Minor (NANSR and OP)
CO: Syn Minor (OP), Minor (PSD)
HAPS: Syn 'Minor B, T, HCHO 8 Total
NH: Syn Minor, benzene exemption
ZZZZ: Syn Minor
Permitted Facility Total
2.6
2.6
0.0
0.2
34.1
192.2
0.0
172.7
86.8
2.6
2.6
0.0
0.2
34.1
43.5
0.0
46.7
13.2
Excludes units exempt from permits/APENs
(A) Change in Permitted Emissions
2.6
2.6
0.0
0.2
34.1
43.5
0.0
46.7
Pubcom required based on new syn minor limit
for NANSR for VOC
Note 1
Total VOC Facility Emissions (point and fugitive)
(O) Change in Total Permitted VOC emissions (point and fugitive)
43.9
Facility is eligible for GPO? because < 90 tpy
Project emissions less than 25/50 tpy
43.5
During development of 20WE0709, I contacted the operator about the uncontrolled tanks at point 006, which are now subject to Reg 7 control requirements. The operator does not use those tanks for routine operations a though they remain permitted under GP01. They
track throughput and have not had condensate in the tanks for 6+ years, so actual emissions have remained at 0 as shown in the 2019 APEN renewal. If they ever need to operate them routinely (above the 2 tpy Reg 7 th eshold for controls) they will complete the
required paperwork updates and install any required controls at that time.
Note 2
Page 4 of 5
Printed 1/21/2021
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY - HAPs
Company Name Aka Energy Group, LLC
County AIRS ID 1232
Plant AIRS ID 9CD2
Facility Name Wiedeman Compressor Station
Emissions - uncontrolled (Ibs per year
POINT PERMIT Description
Formaldehyde
Acetaldehyde
Acrolein
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
McOH
224 TMP
H2S
TOTAL (tpy)
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
GP02
Cat G3516B, sn: JEF02774
11727
757
466
'I'18
738
4
25
101
226
23
7.1
002
GP02
Cat G3516B, sn: JEF02752
11727
757
466
118
738
4
25
10'1
226
23
7.1
003
GP02
Cat G3516B, sn: JEF02766
11727
757
466
'118
738
4
25
10'1
226
23
7.1
004
GP02
Cat G3516B, sn: JEF03326
11727
757
466
'118
738
4
25
101
226
23
7.1
005
GP02
Cat G3516B, sn: JEF03340
11727
757
466
118
738
4
25
101
226
23
7.1
006
GP01
Condensate tanks (2 x 300bb1)
144
105
1
53
255
0.3
007
20WE0709
TEG Dehy, 35 MMscfd
34795
44913
854
15078
6535
51.1
0.0
0.0
APEN-Exempt / Insignificants
0.0
Tank heaters (2)
14
12
14
18
38
24
30
16
50
0.1
Condensate loadout
3
,..
'I
7
0.0
Fugitives
3
5
9
,.,
0.0
0.0
TOTAL (tpy)
29.3
1.9
1.2
17.8
24.4
0.5
7.6
3.7
0.6
0.1
0.0
0.0
87.0
*Total Reportable = all HAPs where uncontrolled emissions > de minimus values
Red Text: uncontrolled emissions < de minlmus
Emissions with controls (Ibs per vear
POINT PERMIT Description
Formaldehyde
Acetaldehyde
Acrolein
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
McOH
224 TMP
H2S
TOTAL (tpy)
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
GP02
Cat G3516B, sn: JEF02774
2932
379
233
5g
369
2
12
50
113
'11
2.1
002
GP02
Cat G35166, sn: JEF02752
2932
379
233
59
369
2
12
50
113
'11
2.1
003
GP02
Cat G3516B, sn: JEF02766
2932
379
233
59
369
2
12
50
113
1'1
2.1
004
GP02
Cat G3516B, sn: JEF03326
2932
379
233
59
369
2
12
50
113
1'I
2.1
005
GP02
Cat G3516B, sn: JEF03340
2932
379
233
59
369
2
12
50
'I 1:13
'11
2.1
006
GP01
Condensate tanks (2 x 300bb1)
144
'105
1
53
255
0.3
007
20WE0709
TEG Dehy, 35 MMscfd
1740
2246
43
754
327
2.6
0.0
0.0
APEN-Exempt / Insignificants
0.0
Tank heaters (2)
14
12
14
'18
38
24
30
16
50
0.1
Condensate loadout
3
2
'1
7
_ 0.0
Fugitives
3
5
9
5
t0.0
0.0
TOTAL (tpy) -
7.3
1.0
0.6
1.1
2.1
0.0
0.5
0.4
0.3
0.1
0.0
0.0
13.4
5
20 W 50709. CP1
1/21/2021
redlined AGG 1/21/2021
Glycol Dehydration Unit APEN
Form APCD-2(72
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
av� - 1ai�
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 glycol dehydration (dehy) units 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, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: Z ? 4V E -
AIRS ID Number: 123 / 9CD2 / 007
. _.
Section 1 - Administrative Information
Company Name': Aka Energy Group, LLC
Site Name: Wiedeman Compressor Station
Site Location: SW/4 NE/4 Section 29, R66W, T4N
Mailing Address:
(Include Zip Code) 125 Mercado Street, Suite 201
Durango, CO 81301
Site Location
County: Weld
NAICS or SIC Code: 1311
Contact Person: Graham Stahnke
Phone Number: (720) 946-0244
E -Mail Address2: gstahnke@akaenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on atl 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.
(-13(-/q-76
PCD-2.v? Rr _ i 202?
COLORADO
nann►moeaI.ua
Permit Number:
AIRS ID Number: 123 / 9CD2 /
Section 2 - Requested Action
Q NEW permit OR newly -reported emission source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
- OR
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑✓ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes: New combustion device (ECD) included in APEN for the facility's still vent emissions
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: Dehydration of natural gas
Company equipment Identification No. (optional):
For existing sources, operation began on:
December 17, 2014
For new or reconstructed sources, the projected start-up date is:
Q Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day
Will this equipment be operated in any NAAQS nonattainment area?
(See APCD website for NAAQS nonattainment area boundary map)
Is this unit located at a stationary source that is considered a Major
Source of (HAP) Emissions?
D
days /week
Yes
❑ Yes
weeks/year
❑ No
No
i �®!COLORADO
2
o..R..w.aomk
'� e«xn�n,.wn.w.,
Permit Number:
AIRS 1D Number: 123 / 9CD2 /
Section 4 - Dehydration Unit Equipment Information
Manufacturer: EXterrari
Dehydrator Serial Number:
12303
Model Number:
Reboiler Rating:
1 MMBTU/hr
1.0
MMBTU/hr
Glycol Used: ❑ Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) 0 TriEthylene Glycol (TEG)
Glycol Pump Drive: 0 Electric ❑ Gas If Gas, injection pump ratio:
Pump Make and Model:
Hydra -Cell D15X
Glycol Recirculation rate (gal/min):
Lean Glycol Water Content:
Max: 10.83 Requested: 5
1.5 wt.%
Acfm /gpm
# of pumps: 2
Dehydrator Gas Throughput:
Design Capacity: 35 MMSCF/day
Requested5:
35 12771MSCF/year
5
Actual: 35K 1277CF/year
Inlet Gas:
Water Content: Wet Gas:
Flash Tank: Pressure: 35
Pressure: 990
Cold Separator: Pressure:
Stripping Gas: (check one)
prig
lb/MMSCF
psis
psig
Q None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen
Flow Rate:
scf m
Temperature:
El Saturated
Temperature:
Temperature:
AGG 12/8/20
120 .F
Dry gas: 6.5 lb/MMSCF
150 • F
°F
per attached email
NA
NA
Additional Required Documentation:
✓❑ Attach a Process Flow Diagram (this item is not required for APEN updates)
❑✓ Attach GRI-GLYCaIc 4.0 Input Report Ft Aggregate Report (or equivalent simulation report/test results)
❑ Attach the extended gas analysis (including BTEX Ft n -Hexane, temperature, and pressure)
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
-702
3 I a®y COLORADO
'.„a.LI.=
Permit Number:
AIRS ID Number: 123 / 9CD2 /
Section 5 - Geographical/Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.283237 / -104.801186
❑ 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.
(aF)
Flow Rate
(ACFM)
Velocity
(ft/seC)
EF-888
25
Indicate the direction of the stack outlet: (check one)
Q Upward
❑ Horizontal
❑ Downward
Other (describe):
Indicate the stack opening and size: (check one)
0 Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches): 24
Interior stack width (inches): Interior stack depth (inches):
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.
Ei Condenser:
Used for control of: Regenerator vent
Type:
Maximum Temp:
Make/Model: Jatco BTEx Eliminator/ Model 5-120 Duplex
*F Average Temp: °F
Requested Control Efficiency: 0 %
✓❑ VRU:
Used for control of: flash tank, condenser vent (when combustion device is down)
Size: Make/Model: Rotorcomp Verdichter/ Model NK100-GAS
Requested Control Efficiency: 95 %
VRU Downtime or Bypassed: 5 %
a Combustion
Device:
Used for control of: condenser vent
Rating: 1.9 MMBtu/hr
Type: enclosed Make/Model: Flare King 24"
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98 %
Minimum Temperature: °F Waste Gas Heat Content: Btu/scf
Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: 0.05 (max) MMBtu/hr
Closed Used for control of: flash tank (when VRU is down)
❑ Loop Description:
System: System Downtime:
❑ Other:
Used for control of:
Description:
Requested Control Efficiency:
PFN
07/2020
-:COLORADO
4 0 w" wnsmR.
Permit Number:
AIRS ID Number: 123 / 9CD2 /
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? []✓ Yes ❑ No
If yes, describe the control equipment AND state the 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
(% redrxtion in emissions)
PM
SO,
NO,
CO
V C
VRU, condenser, combustor
95%
HAPs
VRU, condenser, combustor
95%
Other:
From what year is the following reported actual annual emissions data?
2020
Use the following table to report the criteria pollutant emissions from source:
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)s
Uncontrolled
Basis
Units
Source
(AP -42•
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions°
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
de mi
imis
SO,
NO,
12.4
lb/MMscf
TNRCC
0.55
0.55
0.55
0.55
CO
109.9
lb/MMscf
TNRCC
4.69
4.69
4.69
4.69
VOC
19.4
W/MMscf
calculated
123.92
6.2
123.92
6.2
5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider
future process growth. Requested values are required on all APENs, including APEN updates.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
AGG
1/21/2021
per attached
email
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?
Q 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 -42,
Mfg., etc.)
Uncontrolled
Emissions
(lbs/year)
Controlled
Emissions°
(lbs/year)
Benzene
71432
2.73
lb/MMSCF
calculated
34,832
1,742
Toluene
108883
3.52
lb/MMSCF
calculated
44,930
2,247
Ethylbenzene
100414
0.07
lb/MMSCF
calculated
854
43
Xylene
1330247
1.19
lb/MMSCF
calculated
15,103
755
n -Hexane
110543
0.51
lb/MMSCF
calculated
6,530
327
2,2,4-Trimethylpentane
540841
0
lb/MMSCF
calculated
0
0
Other:
6 Annual emission fees wilt be based on actual controlled emissions reported. If source has not yet started operating, provide
projected emissions.
Unit ADEN -
y� 'COLORADO
5 I n,p.la.a.a rulft
Health Y Lemon,*
Permit Number:
r
AIRS ID Number: 123 / 9CD2 /
rift p E_S?s]
Section 9 - Applicant Certification
hereby certify that all information contained herein and information submitted with this apptication is complete,
true, and correct.
G ra h a m Stahnke Digitally signed by Graham Stahnke
�7 Date: 2020.08.07 11:09:53 -06'00'
8/7/2020
Signature of Legally Authorized Person (not a vendor or consultant) Date
Graham Stahnke Senior Environmental Compliance Specialist
Name (print) Title
Check the appropriate box to request a copy of the:
Draft permit prior to issuance
Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $216.00 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175
OR
(303) 692-3148
APCD Main Phone Number
(303)692-3150
s0_}
lebark!coLofts„coo
5 i ' Departrosat et vonxic
wants m..,wrm..n
12/8/2020 State.co.us Executive Branch Mail - Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
STATE QE
COLORADO
Gruel - CDPHE, Andrew <andrew.gruel@state.co.us>
Wiedeman CS - TEG Dehy - 20WE07O9, 123-9CD2-007
Stahnke, Graham <gstahnke@akaenergy.com> Tue, Dec 8, 2020 at 8:53 AM
To: Andy Gruel - CDPHE <andrew.gruel@state.co.us>
Thanks for the update Andy. Yes, please go ahead and make the redlines for 1 and 2 below. I will check on 3 and 4 and
get back to you.
Best Regards,
Graham
On Dec 7, 2020, at 2:50 PM, Andy Gruel - CDPHE <andrew.gruel@state.co.us> wrote:
Graham,
I have begun working through the application for the TEG Dehy at Wiedeman CS. Similar to the Kersey
CS application, there are a few things to resolve:
1) The requested dry gas throughput is 35 MMscf/yr on the APEN -- please give your OK to redline that to
12775 MMscf/yr.
2) The actual dry gas throughput is 35 MMscf/yr on the APEN -- please give your OK to redline that actual
to 12775 MMscf/yr.
3) We need to account for combustion emissions. It may be, similar to the Kersey applications, that the
max capacity of the combustor was accounted for under the GP01 at point 006. We need to account for
those NOx/CO/PM emissions here on this point 007. Please provide a calculation sheet that reflects the
combustor specs, and I can redline the APEN as needed.
4) As you did for Kersey CS, please provide the ECD sizing calculations for the Wiedeman CS ECD.
Thank you!
Andy
Andy Gruel, P.E.
Permit Engineer
Oil and Gas Program
P 303.692.3143
4300 Cherry Creek Drive South, Denver, CO 80246-1530
andrew.gruel@state.co.us I www.colorado.gov/cdphe/apcd
Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to leam more.
https://mail.google.com/mail/u/0?ik=9030c1528b&view=pt&search=all&permmsgid=msg-f%3A1685525984588989525&dsqt=1 1/1
12/8/2020 State.co.us Executive Branch Mail - Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
STATE OF
COLORADO
Gruel - CDPHE, Andrew <andrew.gruel@state.co.us>
Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
Stahnke, Graham <gstahnke@akaenergy.com> Tue, Dec 8, 2020 at 8:53 AM
To: Andy Gruel - CDPHE <andrew.gruel@state.co.us>
Thanks for the update Andy. Yes, please go ahead and make the redlines for 1 and 2 below. I will check on 3 and 4 and
get back to you.
Best Regards,
Graham
On Dec 7, 2020, at 2:50 PM, Andy Gruel - CDPHE <andrew.gruel@state.co.us> wrote:
Graham,
I have begun working through the application for the TEG Dehy at Wiedeman CS. Similar to the Kersey
CS application, there are a few things to resolve:
1) The requested dry gas throughput is 35 MMscf/yr on the APEN -- please give your OK to redline that to
12775 MMscf/yr.
2) The actual dry gas throughput is 35 MMscf/yr on the APEN -- please give your OK to redline that actual
to 12775 MMscf /yr.
3) We need to account for combustion emissions. It may be, similar to the Kersey applications, that the
max capacity of the combustor was accounted for under the GP01 at point 006. We need to account for
those NOx/CO/PM emissions here on this point 007. Please provide a calculation sheet that reflects the
combustor specs, and I can redline the APEN as needed.
4) As you did for Kersey CS, please provide the ECD sizing calculations for the Wiedeman CS ECD.
Thank you!
Andy
Andy Gruel, P.E.
Permit Engineer
Oil and Gas Program
P 303.692.3143
4300 Cherry Creek Drive South, Denver, CO 80246-1530
andrew.gruel@state.co.us I www.colorado.gov/cdphe/apcd
Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more.
https://mail.google.com/mail/u/0?ik=9030c1528b&view=pt&search=all&permmsgid=msg-P/03A16855259845889895258,dsqt=1 1/1
1/11/2021 State.co.us Executive Branch Mail - Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
STATE OF
COLORADO
Gruel - CDPHE, Andrew <andrew.gruel@state.co.us>
Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
Stahnke, Graham <gstahnke@akaenergy.com> Thu, Jan 7, 2021 at 5:24 PM
To: Andy Gruel - CDPHE <andrew.gruel@state.co.us>
Hi Andy,
The NOx/CO/PM calculations are attached, can you redline the APEN with these values? Please let me know if you need
any other information.
Thanks,
Graham
From: Andy Gruel - CDPHE <andrew.gruel@state.co.us>
Sent: Tuesday, December 29, 2020 4:08 PM
To: Stahnke, Graham <gstahnke@akaenergy.com>
Subject: Re: [EXTERNAL] Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
Sounds good, thank you. Happy New Year!
Andy Gruel, P.E.
Oil and Gas Program
Colorado Air Pollution Control Division
(303) 692-3143 andrew.gruel@state.co.us
On Tue, Dec 29, 2020 at 4:07 PM Stahnke, Graham <gstahnke@akaenergy,com> wrote:
Thanks for checking in Andy. Yes, holidays have slowed things down a bit but I should have a calculation sheet by
early next week for you.
Happy Holidays and Happy New Year!
From: Andy Gruel - CDPHE <andrew.gruel@state.co.us>
Sent: Tuesday, December 29, 2020 3:45 PM
To: Stahnke, Graham <gstahnke@akaenergy.com>
Subject: Re: [EXTERNAL] Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
https://mail.google.com/mail/u/0?ik=9030c1528b&view=pt&search=all&permmsgid=msg-f%3A1688276022828102141 &dsgt=1 &simpl=msg-f%3A1688... 1/3
1/11/2021 State.co.us Executive Branch Mail - Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
Hi Graham,
Just checking in to see if you've had a chance to develop NOx/CO/PM emissions at point 007 at Wiedeman CS.
However I understand if the holidays are delaying this. Please let me know, and I should have some time in early
January to advance the permit development.
Thanks,
Andy
Andy Gruel, P.E.
Oil and Gas Program
Colorado Air Pollution Control Division
(303) 692-3143 andrew.gruel@state.co.us
On Wed, Dec 16, 2020 at 7:04 AM Stahnke, Graham <gstahnke@akaenergy.com> wrote:
Hi Andy,
The ECD sizing information and simulation run details for the Wiedeman ECD are attached: I'm still working on item
3 below, but should have something for you by the end of the week.
Thanks,
Graham
From: Andy Gruel - CDPHE <andrew.gruel@state.co.us>
Sent: Monday, December 07, 2020 2:50 PM
To: Stahnke, Graham <gstahnke@akaenergy.com>
Subject: {EXTERNAL] Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
Graham,
I have begun working through the application for the TEG Dehy at Wiedeman CS. Similar to the Kersey CS
application, there are a few things to resolve:
1) The requested dry gas throughput is 35 MMscf/yr on the APEN -- please give your OK to redline that to 12775
MMscf/yr.
https://mail.google.com/mail/u/0?ik=9030c1528b&view=pt&search=all&permmsgid=msg-f%3A1688276022828102141 &dsgt=1 &simpl=msg-f%3A1688... 2/3
1/11/2021 State.co.us Executive Branch Mail - Wiedeman CS - TEG Dehy - 20WE0709, 123-9CD2-007
2) The actual dry gas throughput is 35 MMscf/yr on the APEN -- please give your OK to redline that actual to
12775 MMscf/yr.
3) We need to account for combustion emissions. It may be, similar to the Kersey applications, that the max
capacity of the combustor was accounted for under the GP01 at point 006. We need to account for those
NOx/CO/PM emissions here on this point 007. Please provide a calculation sheet that reflects the combustor
specs, and I can redline the APEN as needed.
4) As you did for Kersey CS, please provide the ECD sizing calculations for the Wiedeman CS ECD.
Thank you!
Andy
Andy Gruel, P.E.
Permit Engineer
Oil and Gas Program
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
P 303.692.3143
4300 Cherry Creek Drive South, Denver, CO 80246-1530
andrew.gruel@state.co.us I www.colorado.gov/cdphe/apcd
Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more.
Wiedeman_ECD.pdf
126K
https://mail.google.com/mail/u/0?ik=9030c1528b&view=pt&search=al I&permmsgid=msg-f%3A1688276022828102141 &dsgt=1 &simpl=msg-f%3A1688... 3/3
energy group, Ilc
Submitted via email: cdphe apcd ssp application@state.co.us
August 7, 2020
Air Pollution Control Division
Colorado Department of Public Health and Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246
Re: APEN for the Wiedeman Compressor Station (123/9CD2)
Dear Sir or Madam:
Aka Energy Group, LLC (Aka) is providing an APEN for a TEG dehydration unit at the Wiedeman
Compressor Station, located in Weld County, Colorado.'
Attached, please find the following in support of this effort:
• Form APCD-100: "Construction Permit Application Checklist";
• Attachment A: Credit Card Receipt for the APEN filing fee;
• Attachment B: APEN & Application(s) for Construction Permit(s):
o Form APCD-202 (Glycol Dehydration Unit);
• Attachment C: Emissions Calculations and Supporting Documentation;
• Attachment D: Form APCD-101: "Company Contact Information";
• Attachment F: Form APCD-102: "Facility Wide Emission Inventory";
• Attachment G: Process description, flow diagram and plot plan; and
• Attachment H: Operating & Maintenance (O&M) Plan:
o Form APCD-302: "Glycol Dehydration Systems".
Due to the current issues surrounding the COVID-19 pandemic this APEN has been submitted via
email with a digital signature.
' This unit was installed in 2014 as a non -emitting unit that recovered flash tank and regenerator vent
emissions using a vapor recovery unit (VRU). Aka is requesting to send regenerator vent emissions to a new
enclosed combustion device (ECD) and to permit the unit at 95% control for both the flash tank and the
regenerator vent. (The VRU will continue to service the flash tank.)
125 Mercado Street, Suite 201, Durango, CO 81301
(970) 375-6405 - (970) 375-2216 (fax)
A� _
energy group, Ilc
Please let me know if you have any questions regarding this submittal.
Sincerely,
Aka Energy Group, LLC
Graham Stahnke
Senior Environmental Compliance Specialist
Attachments:
As described above
125 Mercado Street, Suite 201, Durango, CO 81301
(970) 375-6405 - (970) 375-2216 (fax)
Form APCD-100
Colorado Department of Public Health and Environment
Air Pollution Control Division
Oil & Gas Industry
Construction Permit Application Completeness Checklist
Company Name:
Source Name:
Date:
Ver. November 29, 2012
Aka Energy Group, LLC
t:olorado Deparunent
of Public I Iealth
and Environment
Wiedeman Compressor Station
August 7, 2020
Are you requesting a facility wide permit for multiple emissions points?
Yes No
❑ El
In order to have a complete application, the following attachments must be provided, unless stated
otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded.
Attachment
Application Element Applicant
APCD
A
APEN Filing Fees
x
❑
B
Air Pollutant Emission Notice(s) (APENs) &
Application(s) for Construction Permit(s) — APCD Form Series 200
❑
x
C
Emissions Calculations and Supporting Documentation
x
❑
D
Company Contact Information - Form APCD-101
x
❑
E
Ambient Air Impact Analysis NA; emissions below levels triggering this analysis
❑ Check here if source emits only VOC (Attachment E not required)
❑
❑
F
Facility Emissions Inventory — Form APCD-102
❑ Check here if single emissions point source (Attachment F not required)
x
❑
G
Process description, flow diagram and plot plan of emissions unit and/or
facility
❑ Check here if single emissions point source (Attachment G not required)
❑
x
H
Operating & Maintenance (O&M) Plan — APCD Form Series 300
❑ Check here if true minor emissions source or application is for a general
permit (Attachment H not required)
x
❑
I
Regulatory Analysis
Check here
❑
x
x to request APCD to complete regulatory analysis
(Attachment I not required)
J
Colorado Oil and Gas Conservation Commission (COGCC) 805 Series Rule
Requirements— Form APCD-105
Check here if is COGCC
❑
❑
x source not subject to 805 Series requirements
(Attachment J not required)
Send Complete Application to:
Colorado Department of Public Health & Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Check box if facility is an existing Title V source: n Send an additional application copy
Check box if refined modeling analysis included: n Send an additional application copy
Check box if application is for major NA NSR or PSD permit: n Send eight (8) total application copies
Page 1 of 1 FormAPCD-100-AppCompleteChecklist-Ver.l I -29-20 I 2.docx
TEG Dehydration Unit Emissions
Aka Energy Group, LLC
Wiedeman Compressor Station
The TEG dehydration unit will process 35 MMSCFD of natural gas. Flash tank emissions will be recovered using a vapor recovery unit. Regenerator vent
emissions will be sent to a condenser, and emissions from the condenser vent will then be sent to a combustion device at 95% control. (Flash tank
emissions are sent to the facility inlet using a closed loop system when the VRU is down; condenser vent emissions are sent to the VRU when the
combustion device is down.)
Emission calculations from GRI-GLYCaIc Version 4.0 are presented below assuming 95% control for both regenerator vent and flash tank emissions
from the unit.
35 MMSCFD
TEG Dehydrator
Emissions
Potential Emissions *
Uncontrolled
Controlled
Flash Tank
Regenerator Vent
Total
Total
(Ib/yr)
(ton/yr)
(Ib/yr)
(ton/yr)
(Ib/MMSCF)
(Ib/yr)
(ton/yr)
(Ib/yr)
(ton/yr)
VOC
n -hexane
224-TMP
benzene
toluene
ethylbenzene
xylenes
99510.4
49.7552
148330
74.165
19.40
247840.4
123.9202
12392
6.20
3432
1.716
3098.4
1.5492
0.51
6530.4
3.2652
327
0.16
0
0
0
0
0.0
0
0
0
0.00
1419.2
0.7096
33412.8
16.7064
2.73
34832
17.416
1742
0.87
1283.4
0.6417
43646.8
21.8234
3.52
44930.2
22.4651
2247
1.12
15.2
0.0076
839
0.4195
0.07
854.2
0.4271
43
0.02
185.4
0.0927
14917.8
7.4589
1.18
15103.2
7.5516
755
0.38
* Potential emissions from GRI-GLYCaIc run. Controlled emissions assume 95% control for flash tank and regenerator vent.
Page: 1
GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES
Case Name: WIE TEG Dehy July 2020
File Name: M:\EHS\ Colorado\ Wiedeman\Air\WIE Permit\200620_Dehy and ECD APEN\G1yCalc
20200326\WIE TEG Dehy GlyCalc Model 20200709.ddf
Date: July 10, 2020
DESCRIPTION:
Description: Wiedeman Inlet Contactor
Empact extended analysis from March 3, 2020.
Annual Hours of Operation: 8760.0 hours/yr
WET GAS:
Temperature:
Pressure:
120.00 deg. F
990.00 psig
Wet Gas Water Content: Saturated
Component
Conc.
(vol %)
Carbon Dioxide 2.9700
Nitrogen 0.1600
Methane 76.2896
Ethane 11.6103
Propane 4.6140
Isobutane 0.8882
n -Butane 1.6884
Isopentane 0.5778
n -Pentane 0.5453
Cyclopentane 0.0145
n -Hexane 0.1536
Cyclohexane 0.0279
Other Hexanes 0.2635
Heptanes 0.0865
Methylcyclohexane 0.0223
Benzene 0.0246
Toluene 0.0213
Ethylbenzene 0.0003
Xylenes 0.0038
C8+ Heavies C.0240
DRY GAS:
Flow Rate: 35.0 MMSCF/day
Water Content: 6.5 lbs. H2O/MMSCF
LEAN GLYCOL:
Glycol Type: TEG
Water Content:
Flow Rate:
PUMP:
1.5 wt% H2O
5.0 gpm
Page: 2
Glycol Pump Type: Electric/Pneumatic
FLASH TANK:
Flash Control: Recycle/recompression
Temperature: 150.0 deg. F
Pressure: 35.0 psig
REGENERATOR OVERHEADS CONTROL DEVICE:
Control Device: Condenser
Temperature: 205.0 deg. F
Pressure: 13.6 psia
Control Device: Combustion Device
Destruction Efficiency: 95.0 %
Excess Oxygen: 5.0
Ambient Air Temperature: 60.0 deg. F
Page: 1
GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT
Case Name: WIE TEG Dehy July 2020
File Name: M:\EHS\ Colorado\ Wiedeman\Air\WIE Permit\200620_Dehy and ECD APEN\GlyCalc
20200326\WIE TEG Dehy GlyCalc Model 20200709.ddf
Date: July 10, 2020
DESCRIPTION:
Description: Wiedeman Inlet Contactor
Empact extended analysis from March 3, 2020.
Annual Hours of Operation: 8760.0 hours/yr
EMISSIONS REPORTS:
CONTROLLED REGENERATOR EMISSIONS
Component
lbs/hr lbs/day tons/yr
Methane 0.0110 0.264 0.0481
Ethane 0.0242 0.580 0.1059
Propane 0.0429 1.029 0.1878
Isobutane 0.0174 0.418 0.0762
n -Butane 0.0505 1.211 0.2211
Isopentane 0.0206 0.495 0.0903
n -Pentane 0.0276 0.663 0.1210
Cyclopentane 0.0056 0.135 0.0246
n -Hexane 0.0177 0.424 0.0775
Cyclohexane 0.0222 0.534 0.0974
Other Hexanes 0.0208 0.499 0.0912
Heptanes 0.0243 0.583 0.1064
Methylcyclohexane 0.0212 0.510 0.0931
Benzene 0.1906 4.575 0.8350
Toluene 0.2490 5.977 1.0908
Ethylbenzene 0.0048 0.115 0.0210
Xylenes 0.0851 2.043 0.3728
C8+ Heavies 0.0460 1.104 0.2014
Total Emissions 0.8816
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
UNCONTROLLED REGENERATOR EMISSIONS
0.8816
0.8464
0.5473
0.5296
21.158 3.8613
21.158
20.314
13.134
12.710
3.8613
3.7073
2.3970
2.3196
Component
lbs/hr lbs/day tons/yr
Methane 0.2197 5.273 0.9622
Ethane 0.4837 11.609 2.1187
Propane 0.8575 20.580 3.7558
Isobutane 0.3480 8.352 1.5242
n -Butane 1.0095 24.228 4.4216
Isopentane 0.4122 9.893 1.8055
n -Pentane 0.5524 13.257 2.4194
Cyclopentane 0.1122 2.694 0.4916
n -Hexane 0.3537 8.489 1.5492
Page: 2
Cyclohexane 0.4447 10.672 1.9476
Other Hexanes 0.4162 9.990 1.8232
Heptanes 0.4859 11.663 2.1284
Methylcyclohexane 0.4250 10.200 1.8614
Benzene 3.8142 91.542 16.7064
Toluene 4.9825 119.580 21.8234
Ethylbenzene 0.0958 2.298 0.4195
Xylenes 1.7030 40.871 7.4589
C8+ Heavies 0.9199 22.077 4.0290
Total Emissions 17.6361
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
FLASH GAS EMISSIONS
17.6361
16.9326
10.9492
10.5955
423.265 77.2459
423.265
406.383
262.780
254.292
77.2459
74.1650
47.9574
46.4082
Note: Flash Gas Emissions are zero with the
Recycle/recompression control option.
FLASH TANK OFF GAS
Component
lbs/hr lbs/day tons/yr
Methane 6.9770 167.447 30.5591
Ethane 4.9687 119.248 21.7628
Propane 3.8182 91.637 16.7238
Isobutane 1.0997 26.393 4.8167
n -Butane 2.4868 59.684 10.8922
Isopentane 0.9334 22.402 4.0883
n -Pentane 1.0259 24.621 4.4932
Cyclopentane 0.0577 1.386 0.2529
n -Hexane 0.3918 9.403 1.7160
Cyclohexane 0.1350 3.239 0.5912
Other Hexanes 0.5999 14.398 2.6276
Heptanes 0.2869 6.887 1.2568
Methylcyclohexane 0.1049 2.518 0.4596
Benzene 0.1620 3.888 0.7096
Toluene 0.1465 3.516 0.6417
Ethylbenzene 0.0017 0.042 0.0076
Xylenes 0.0212 0.508 0.0927
C8+ Heavies 0.0879 2.111 0.3852
Total Emissions 23.3053
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
23.3053
11.3596
0.7232
0.3314
COMBINED REGENERATOR VENT/FLASH GAS EMISSIONS
559.327 102.0771
559.327
272.631
17.357
7.954
102.0771
49.7552
3.1676
1.4516
Component
lbs/hr lbs/day tons/yr
Methane
Ethane
0.0110
0.0242
0.264 0.0481
0.580 0.1059
Page: 3
Propane 0.0429 1.029 0.1878
Isobutane 0.0174 0.418 0.0762
n -Butane 0.0505 1.211 0.2211
Isopentane 0.0206 0.495 0.0903
n -Pentane 0.0276 0.663 0.1210
Cyclopentane 0.0056 0.135 0.0246
n -Hexane 0.0177 0.424 0.0775
Cyclohexane 0.0222 0.534 0.0974
Other Hexanes 0.0208 0.499 0.0912
Heptanes 0.0243 0.583 0.1064
Methylcyclohexane 0.0212 0.510 0.0931
Benzene 0.1906 4.575 0.8350
Toluene 0.2490 5.977 1.0908
Ethylbenzene 0.0048 0.115 0.0210
Xylenes 0.0851 2.043 0.3728
C8+ Heavies 0.0460 1.104 0.2014
Total Emissions 0.8816
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
0.8816
0.8464
0.5473
0.5296
21.158 3.8613
21.158
20.314
13.134
12.710
COMBINED REGENERATOR VENT/FLASH GAS EMISSION CONTROL REPORT:
3.8613
3.7073
2.3970
2.3196
Component Uncontrolled Controlled a Reduction
tons/yr tons/yr
Methane 31.5213 0.0481 99.85
Ethane 23.8815 0.1059 99.56
Propane 20.4796 0.1878 99.08
Isobutane 6.3409 0.0762 98.80
n -Butane 15.3138 0.2211 98.56
Isopentane 5.8937 0.0903 98.47
n -Pentane 6.9126 0.1210 98.25
Cyclopentane 0.7445 0.0246 96.70
n -Hexane 3.2652 0.0775 97.63
Cyclohexane 2.5388 0.0974 96.16
Other Hexanes 4.4507 0.0912 97.95
Heptanes 3.3852 0.1064 96.86
Methylcyclohexane 2.3210 0.0931 95.99
Benzene 17.4160 0.8350 95.21
Toluene 22.4652 1.0908 95.14
Ethylbenzene 0.4271 0.0210 95.09
Xylenes 7.5516 0.3728 95.06
C8+ Heavies 4.4142 0.2014 95.44
Total Emissions 179.3230
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
EQUIPMENT REPORTS:
179.3230
123.9202
51.125C
47.8598
3.8613 97.85
3.8613
3.7073
2.3970
2.3196
97.85
97.01
95.31
95.15
Page: 4
CONDENSER AND COMBUSTION DEVICE
Condenser Outlet Temperature:
Condenser Pressure:
Condenser Duty:
Produced Water:
Ambient Temperature:
Excess Oxygen:
Combustion Efficiency:
Supplemental Fuel Requirement:
205.00
13.60
9.68e-002
4.29
60.00
5.00
95.00
9.68e-002
Component Emitted
deg. F
psia
MM BTU/hr
bbls/day
deg. F
%
MM BTU/hr
Destroyed
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
Other Hexanes
Heptanes
Methylcyclohexane
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
ABSORBER
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
5.00%
95.00°%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00%
95.00°%
95.00%
95.00%
95.00%
95.00%
Calculated Absorber Stages:
Specified Dry Gas Dew Point:
Temperature:
Pressure:
Dry Gas Flow Rate:
Glycol Losses with Dry Gas:
Wet Gas Water Content:
Calculated Wet Gas Water Content:
Calculated Lean Glycol Recirc. Ratio:
Component
1.62
6.50 lbs. H2O/MMSCF
120.0 deg. F
990.0 psig
35.0000 MMSCF/day
2.0323 lb/hr
Saturated
103.21 lbs. H2O/MMSCF
2.13 gal/lb H2O
Remaining
in Dry Gas
Absorbed
in Glycol
Water
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
6.28%
99.83%
99.98%
99.98%
99.96%
99.94%
99.93%
99.91%
99.92%
99.90%
99.57%
93.72%
0.17%
0.02%
0.02%
0.04%
0.06%
0.07%
0.09%
0.08%
0.10%
0.43%.
n -Hexane
Cyclohexane
Other Hexanes
Heptanes
Methylcyclohexane
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
FLASH TANK
99.85%
99.36%
99.88%
99.77%
99.37%
94.62%
93.20%
92.04°%
88.88%
99.36%
Page: 5
0.15%
0.64%
0.12%
0.23%
0.63%
5.38%
6.80%
7.96%
11.12%
0.64%
Flash Control:
Flash Temperature:
Flash Pressure:
Component
Recycle/recompression
150.0 deg. F
35.0 psig
Left in
Glycol
Removed in
Flash Gas
Water
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
Other Hexanes
Heptanes
Methylcyclohexane
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
REGENERATOR
99.89%
24.73%
2.88%
3.05%
8.87%
18.34%
24.04%
28.87%
30.98%
35.32%
66.20%
47.71%
77.46%
41.55%
63.06%
80.99%
96.13%
97.37%
98.41%
98.93%
92.32%
0.11%
75.27%
97.12%
96.95%
91.13%
81.66%
75.96%
71.13%
69.02%
64.68%
33.800
52.29%
22.54%
58.45%
36.94%
19.01%
3.87%
2.63%
1.59%
1.07%
7.68%
No Stripping Gas used in regenerator.
Component
Remaining Distilled
in Glycol Overhead
Water
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
23.01%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
76.99%
100.00%
100.00%
100.00%
100.00%
100.00%
100.00%
100.00%
Page: 6
Isopentane 1.61% 98.390
n -Pentane 1.420 98.580
Cyclopentane 0.760 99.24°%
n -Hexane 1.05% 98.95%
Cyclohexane 4.13% 95.87%
Other Hexanes 2.41% 97.59%
Heptanes 0.790 99.21%
Methylcyclohexane 4.940 95.06%
Benzene 5.20% 94.80%
Toluene 8.12% 91.88%
Ethylbenzene 10.59% 89.41%
Xylenes 13.09% 86.91%
C8+ Heavies
STREAM REPORTS:
13.05% 86.95%
WET GAS STREAM
Temperature:
Pressure:
Flow Rate:
120.00 deg. F
1004.70 psia
1.46e+006 scfh
Component
Conc. Loading
(vol%) (lb/hr)
Water 2.17e-001 1.51e+002
Carbon Dioxide 2.96e+000 5.03e+003
Nitrogen 1.60e-001 1.72e+002
Methane 7.61e+001 4.71e+004
Ethane 1.16e+001 1.34e+004
Propane 4.60e+000 7.82e+003
Isobutane 8.86e-001 1.98e+003
n -Butane 1.68e+000 3.77e+003
Isopentane 5.77e-001 1.60e+003
n -Pentane 5.44e-001 1.51e+003
Cyclopentane 1.45e-002 3.91e+001
n -Hexane 1.53e-001 5.09e+002
Cyclohexane 2.78e-002 9.03e+001
Other Hexanes 2.63e-001 8.73e+002
Heptanes 8.63e-002 3.33e+002
Methylcyclohexane 2.23e-002 8.42e+001
Benzene 2.46e-002 7.39e+001
Toluene 2.13e-002 7.55e+001
Ethylbenzene 2.99e-004 1.22e+000
Xylenes 3.79e-003 1.55e+001
C8+ Heavies 2.40e-002 1.57e+002
Total Components 100.00 8.48e+004
DRY GAS STREAM
Temperature:
Pressure:
Flow Rate:
120.00 deg. F
1004.70 psia
1.46e+006 scfh
Page: 7
Component
Conc. Loading
(vole) (lb/hr)
Water 1.37e-002 9.48e+000
Carbon Dioxide 2.97e+000 5.02e+003
Nitrogen 1.60e-001 1.72e+002
Methane 7.63e+001 4.70e+004
Ethane 1.16e+001 1.34e+004
Propane 4.61e+000 7.82e+003
Isobutane 8.88e-001 1.98e+003
n -Butane 1.69e+000 3.77e+003
Isopentane 5.78e-001 1.60e+003
n -Pentane 5.45e-001 1.51e+003
Cyclopentane 1.44e-002 3.89e+001
n -Hexane 1.53e-001 5.08e+002
Cyclohexane 2.77e-002 8.97e+001
Other Hexanes 2.63e-001 8.72e+002
Heptanes 8.63e-002 3.33e+002
Methylcyclohexane 2.22e-002 8.37e+001
Benzene 2.33e-002 6.99e+001
Toluene 1.99e-002 7.03e+001
Ethylbenzene 2.76e-004 1.13e+000
Xylenes 3.38e-003 1.38e+001
C8+ Heavies 2.39e-002 1.56e+002
Total Components 100.00 8.46e+004
LEAN GLYCOL STREAM
Temperature: 120.00 deg. F
Flow Rate: 5.OOe+000 gpm
Component
Conc. Loading
(wta) (lb/hr)
TEG 9.85e+001 2.77e+003
Water 1.50e+000 4.22e+001
Carbon Dioxide 3.06e-011 8.60e-010
Nitrogen 1.08e-013 3.03e-012
Methane 8.59e-018 2.42e-016
Ethane 9.15e-008 2.57e-006
Propane 6.77e-009 1.90e-007
Isobutane 1.54e-009 4.34e-008
n -Butane 3.08e-009 8.67e-008
Isopentane 2.40e-004 6.76e-003
n -Pentane 2.82e-004 7.93e-003
Cyclopentane 3.04e-005 8.54e-004
n -Hexane 1.33e-004 3.75e-003
Cyclohexane 6.81e-004 1.92e-002
Other Hexanes 3.65e-004 1.03e-002
Heptanes 1.38e-004 3.88e-003
Methylcyclohexane 7.85e-004 2.21e-002
Benzene 7.44e-003 2.09e-001
Toluene 1.57e-002 4.40e-001
Ethylbenzene 4.03e-004 1.13e-002
Xylenes 9.12e-003 2.57e-001
C8+ Heavies 4.91e-003 1.38e-001
Total Components 100.00 2.81e+003
Page: 8
RICH GLYCOL STREAM
Temperature: 120.00 deg. F
Pressure: 1004.70 psia
Flow Rate: 5.38e+000 gpm
NOTE: Stream has more than one phase.
Component
Conc.
(wt %)
Loading
(lb/hr)
TEG 9.22e+001 2.77e+003
Water 6.12e+000 1.84e+002
Carbon Dioxide 2.86e-001 8.60e+000
Nitrogen 1.01e-003 3.02e-002
Methane 2.40e-001 7.20e+000
Ethane 1.82e-001 5.45e+000
Propane 1.56e-001 4.68e+000
Isobutane 4.82e-002 1.45e+000
n -Butane 1.16e-001 3.50e+000
Isopentane 4.51e-002 1.35e+000
n -Pentane 5.28e-002 1.59e+000
Cyclopentane 5.69e-003 1.71e-001
n -Hexane 2.50e-002 7.49e-001
Cyclohexane 1.99e-002 5.99e-001
Other Hexanes 3.42e-002 1.03e+000
Heptanes 2.59e-002 7.77e-001
Methylcyclohexane 1.84e-002 5.52e-001
Benzene 1.39e-001 4.19e+000
Toluene 1.86e-001 5.57e+000
Ethylbenzene 3.63e-003 1.09e-001
Xylenes 6.60e-002 1.98e+000
C8+ Heavies 3.82e-002 1.15e+000
Total Components 100.00 3.OOe+003
FLASH TANK OFF GAS STREAM
Temperature:
Pressure:
Flow Rate:
150.00 deg. F
49.70 psia
3.63e+002 scfh
Component
Conc. Loading
(vol%) (lb/hr)
Water 1.18e+000 2.03e-001
Carbon Dioxide 1.54e+001 6.47e+000
Nitrogen 1.10e-001 2.94e-002
Methane 4.54e+001 6.98e+000
Ethane 1.73e+001 4.97e+000
Propane 9.04e+000 3.82e+000
Isobutane 1.98e+000 1.10e+000
n -Butane 4.47e+000 2.49e+000
Isopentane 1.35e+000 9.33e-001
n -Pentane 1.49e+000 1.03e+000
Cyclopentane 8.60e-002 5.77e-002
n -Hexane 4.75e-001 3.92e-001
Cyclohexane 1.68e-001 1.35e-001
Other Hexanes 7.27e-001 6.OOe-001
Heptanes 2.99e-001 2.87e-001
Page: 9
Methylcyclohexane 1.12e-001 1.05e-001
Benzene 2.17e-001 1.62e-001
Toluene 1.66e-001 1.47e-001
Ethylbenzene 1.71e-003 1.73e-003
Xylenes 2.08e-002 2.12e-002
C8+ Heavies 5.39e-002 8.79e-002
Total Components 100.00 3.00e+001
FLASH TANK GLYCOL STREAM
Temperature: 150.00 deg. F
Flow Rate: 5.32e+000 gpm
Component
Conc. Loading
(wt%) (lb/hr)
TEG 9.31e+001 2.77e+003
Water 6.17e+000 1.83e+002
Carbon Dioxide 7.15e-002 2.13e+000
Nitrogen 2.93e-005 8.71e-004
Methane 7.39e-003 2.20e-001
Ethane 1.63e-002 4.84e-001
Propane 2.89e-002 8.57e-001
Isobutane 1.17e-002 3.48e-001
n -Butane 3.40e-002 1.01e+000
Isopentane 1.41e-002 4.19e-001
n -Pentane 1.89e-002 5.60e-001
Cyclopentane 3.81e-003 1.13e-001
n -Hexane 1.20e-002 3.57e-001
Cyclohexane 1.56e-002 4.64e-001
Other Hexanes 1.44e-002 4.27e-001
Heptanes 1.65e-00? 4.90e-001
Methylcyclohexane 1.50e-002 4.47e-001
Benzene 1.35e-001 4.02e+000
Toluene 1.82e-001 5.42e+000
Ethylbenzene 3.60e-003 1.07e-001
Xylenes 6.59e-002 1.96e+000
C8+ Heavies 3.56e-002 1.06e+000
Total Components 100.00 2.97e+003
FLASH GAS EMISSIONS
Control Method: Recycle/recompression
Control Efficiency: 100.00
Note: Flash Gas Emissions are zero with the
Recycle/recompression control option.
REGENERATOR OVERHEADS'STREAM
Temperature:
Pressure:
Flow Rate:
212.00 deg. F
14.70 psia
3.08e+003 scfh
Component
Conc. Loading
(vol%) (lb/hr)
Page: 10
Water 9.65e+001 1.41e+002
Carbon Dioxide 5.95e-001 2.13e+000
Nitrogen 3.83e-004 8.71e-004
Methane 1.69e-001 2.20e-001
Ethane 1.98e-001 4.84e-001
Propane 2.39e-001 8.57e-001
Isobutane 7.37e-002 3.48e-001
n -Butane 2.14e-001 1.01e+000
Isopentane 7.03e-002 4.12e-001
n -Pentane 9.42e-002 5.52e-001
Cyclopentane 1.97e-002 1.12e-001
n -Hexane 5.05e-002 3.54e-001
Cyclohexane 6.50e-002 4.45e-001
Other Hexanes 5.94e-002 4.16e-001
Heptanes 5.97e-002 4.86e-001
Methylcyclohexane 5.33e-002 4.25e-001
Benzene 6.01e-001 3.81e+000
Toluene 6.66e-001 4.98e+000
Ethylbenzene 1.11e-002 9.58e-002
Xylenes 1.97e-001 1.70e+000
C8+ Heavies 6.65e-002 9.20e-001
Total Components 100.00 1.61e+002
CONDENSER PRODUCED WATER STREAM
Temperature: 205.00 deg. F
Flow Rate: 1.25e-001 gpm
Component
Conc. Loading
(wto) (lb/hr) (ppm)
Water 1.OOe+002 6.26e+001 999946.
Carbon Dioxide 4.82e-004 3.02e-004 5.
Nitrogen 8.96e-009 5.61e-009 0.
Methane 3.59e-006 2.25e-006 0.
Ethane 8.33e-006 5.21e-006 0.
Propane 2.OOe-005 1.25e-005 0.
Isobutane 4.07e-006 2.55e-006 0.
n -Butane 1.44e-005 8.99e-006 0.
Isopentane 3.72e-006 2.33e-006 0.
n -Pentane 5.13e-006 3.21e-006 0.
Cyclopentane 5.66e-006 3.54e-006 0.
n -Hexane 2.37e-006 1.48e-006 0.
Cyclohexane 1.30e-005 8.16e-006 0.
Other Hexanes 2.36e-006 1.48e-006 0.
Heptanes 1.65e-006 1.03e-006 0.
Methylcyclohexane 5.64e-006 3.53e-006 0.
Benzene 2.17e-003 1.36e-003 22.
Toluene 2.05e-003 1.28e-003 21.
Ethylbenzene 2.67e-005 1.67e-005 0.
Xylenes 6.05e-004 3.79e-004 6.
C8+ Heavies 3.90e-008 2.44e-008 0.
Total Components 99.99 6.26e+001 999904.
CONDENSER RECOVERED OIL STREAM
Page: 11
Temperature: 205.00 deg. F
The calculated flow rate is less than 0.000001 #mol/hr.
The stream flow rate and composition are not reported.
CONDENSER VENT STREAM
Temperature:
Pressure:
Flow Rate:
205.00 deg. F
13.60 psia
1.76e+003 scfh
Component
Conc. Loading
(vol%) (lb/hr)
Water 9.39e+001 7.86e+001
Carbon Dioxide 1.04e+000 2.13e+000
Nitrogen 6.69e-004 8.71e-004
Methane 2.94e-001 2.20e-001
Ethane 3.46e-001 4.84e-001
Propane 4.18e-001 8.57e-001
Isobutane 1.29e-001 3.48e-001
n -Butane 3.73e-001 1.01e+000
Isopentane 1.23e-001 4.12e-001
n -Pentane 1.65e-001 5.52e-001
Cyclopentane 3.44e-002 1.12e-001
n -Hexane 8.82e-002 3.54e-001
Cyclohexane 1.14e-001 4.45e-001
Other Hexanes 1.04e-001 4.16e-001
Heptanes 1.04e-001 4.86e-001
Methylcyclohexane 9.31e-002 4.25e-001
Benzene 1.05e+000 3.81e+000
Toluene 1.16e+000 4.98e+000
Ethylbenzene 1.94e-002 9.57e-002
Xylenes 3.45e-001 1.70e+000
C8+ Heavies 1.16e-001 9.20e-001
Total Components 100.00 9.84e+001
COMBUSTION DEVICE OFF GAS STREAM
Temperature:
Pressure:
Flow Rate:
1000.00 deg. F
14.70 psia
4.48e+000 scfh
Component
Conc. Loading
(vol%) (lb/hr)
Methane 5.80e+000 1.10e-002
Ethane 6.81e+000 2.42e-002
Propane 8.23e+000 4.29e-002
Isobutane 2.54e+000 1.74e-002
n -Butane 7.35e+000 5.05e-002
Isopentane 2.42e+000 2.06e-002
n -Pentane 3.24e+000 2.76e-002
Cyclopentane 6.78e-001 5.61e-003
n -Hexane 1.74e+000 1.77e-002
Cyclohexane 2.24e+000 2.22e-002
Other Hexanes 2.05e+000 2.08e-002
Heptanes 2.05e+000 2.43e-002
Methylcyclohexane 1.83e+000 2.12e-002
Page: 12
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
2.07e+001 1.91e-001
2.29e+001 2.49e-001
3.82e-001 4.79e-003
6.79e+000 8.51e-002
2.29e+000 4.60e-002
Total Components
100.00 8.82e-001
'l lll�V` a
PRIMARY DB KEY:
LEASE #:
FIELD/AREA:
tMrtj.
1 k "!! I nv 7
S, 4111,,t1
`\\ \\\1111/
EMPACT1
l
EXTENDED NATURAL GAS ANALYSIS (*DHA)
MAIN PAGE
NAME/DESCRIP : WIEDEMAN INLET CONTACTOR
PROJECT NO. : 202003023
COMPANY NAME : AKA ENERGY
OFFICE / BRANCH: PLATTEVILLE, CO
CUSTOMER REF:
PRODUCER :
***FIELD DATA***
SAMPLE. CYCLE:
SAMPLE PRES.: 993 prig
FLOW PRES.: psig
LAB PRES: psig
SAMPLE TEMP.: 120 °f
AMBIENT "TEMP.: of
H2O BY STAIN TUBE: #/mmef
FIELD COMMENTS:
LAB COMMENTS:
COMPONENT
ALCOHOLS
HELIUM
HYDROGEN
OXYGEN/ARGON
NITROGEN
CARBON DIOXIDE
METHANE
ETHANE
PROPANE
I -BUTANE
N -BUTANE
I -PENTANE
N -PENTANE
HEXANES PLUS
TOTALS
MOLE % MASS %
0.0041
0.01
0.00
0.00
0.16
2.97
76.28960
11.6103
4.6140
0.8882
1.6884
0.5923
0.5453
0.6278
0.0061
0.00
0.00
0.00
0.20
5.94
55.64000
15.8716
9.2498
2.3470
4.4615
1.9414
1.7887
2.5539
100.00000 100.00000
ANALYSIS NO.: 02
ANALYSIS DATE: MARCH 07, 2020 10:37
SAMPLE DATE : MARCH 3, 2020
TO:
EFFECTIVE DATE:
SAMPLE TYPE: SPOT
PROBE: NO
CYLINDER NO.: 1030
SAMPLED BY : JOHN POWELL
SAMPLING COMPANY: AKA ENERGY
H2S BY STAIN TUBE: ppm
CO2 BY STAIN TUBE: Mol
BTEX COMPONENTS STOLE% WT% BTU (a
BENZENE 0.0246 0.0874 LHV NET DRY REAL :
TOLUENE 0.0213 0.0892 NET WET REAL :
ETHYLBENZENE 0.0003 0.0015 HHV GROSS DRY REAL :
XYLENES 0.0038 0.0184 GROSS WET REAL
GPM @ GPM @
14.65 14.73
0.0010 0.0010
3.0986
1.2686
0.2901
0.5313
0.2151
0.1971
0.2480
3.1155
1.2756
0.2917
0.5342
0.2162
0.1982
0.2494
5.8498 5.8818
14.65 14.73
1136.3 /scf
1116.4 /scf
1252.3 /scf
1230.4 /scf
TOTAL BTEX 0.0500 0.1965 NET DRY REAL : 19618.7 /Ib
GROSS DRY REAL : 21615.1 /Ib
RELATIVE DENSITY (AIR=1):
*(DETAILED HYDROCARBON ANALYSIS/NJ 1993) DENSITY
Mod ASTL1 D673o,GPA 2261 & GPA 2286. COMPRESSIBILITY FACTOR :
WALcGPA2n2,GPA2145&TP-v 14.696&60Fj REGULAR WOBBE INDEX
1142.5 /scf
1122.6 /scf
1259.2 /scf
1237.3 /scf
19725.9 /1b
21733.1 /lb
0.7590
0.05796 Ib/scf
0.99636
1442.0
The Bakupte,euted herein has been a.iltrircd hr mean, of anti eat rutahlieal teahniyue, and represent, the fudi.iuu, cam avian Elfr 1C7 .l nitlythal.S}_,ren!., lilt.
Rectths r/ the analysis can be affected kr the saupiigl conditions. theredore, are only warranted thi(ni,h proper lub prototoL 1.:11:01(1 rroumes 2222 responsibility
fur intent elation el any cunseyneu.es from upplirarion gfthe repo fed information and is the sole liability tit the tiler. The reprardnetion in out' rurrlia of rhi_,
reperted informorion may 'tot he made, in pertian or e -o a whole. without the written pernti,einu of F. 111'ACT .lnulrtirat Cl'stenre, Lrz-.
EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150
i
1411,_
'l1c .!1 !IMP-
�i ; l�lki
��m
PROJECT NO. :
COMPANY NAME :
ACCOUNT NO. :
PRODUCER :
LEASE NO. :
NAME/DESCRIP :
***FIELD DATA***
SAMPLE PRES. :
H2S BY STAIN TUBE:
COMMENTS .
Componet
Helium
Hydrogen
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
Other Hexanes
Heptanes
Methylcyclohexane
2,2,4 Trimethylpentane
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
Subtotal
Oxygen/Argon
Alcohols
Total
EMPACT
1_,_A
EXTENDED NATURAL GAS ANALYSIS (*DHA)
GLYCALC INFORMATION
202003023
AKA ENERGY
WIEDEMAN INLET CONTACTOR
993
SPOT
PPm
NO PROBE
Mole %
0.01
0.00
2.97
0.16
76.28960
11.6103
4.6140
0.8882
1.6884
0.5778
0.5453
0.0145
0.1536
0.0279
0.2635
0.0865
0.0223
0.0000
0.0246
0.0213
0.0003
0.0038
0.0240
99.99590
0.00
0.0041
ANALYSIS NO. :
ANALYSIS DATE:
SAMPLE DATE :
CYLINDER NO. :
SAMPLED BY :
SAMPLE TEMP. :
AMBIENT TEMP.:
Wt%
0.00
0.00
5.94
0.20
55.64000
15.8716
9.2498
2.3470
4.4615
1.8952
1.7887
0.0462
0.6018
0.1067
1.0290
0.3934
0.0996
0.0000
0.0874
0.0892
0.0015
0.0184
0.1269
99.99390
0.00
0.0061
100:00000 100.00000
02
MARCH 07, 2020 10:37
MARCH 3, 2020
1030
JOHN POWELL
120
BDL - Below Detection Limit. The HIS LOS has a detection limit of 0.15 ppm..4 _ (an uderscore) indicates there was no tube pulled for HIS.
The data presentee he!ein has been ueyuirc<t hr means of cnmrul una(cti,at te1tniyues one'represent, thePt:Gcium con..roiiw E 4d1':1CT .inahviral Systems. Inc.
Xe+alh of the anadt=sis can be ul1,,,ted b} the santplinG conditions, therefore. rr, e only war ',mkd throuf h proper lob p•nmeai, LW'. 1(7 assume,. no respoadhiliti•
for interpretation err any roneepleacas font application of the reported ininrnattion and i% the mitt' eiaAGih' of the aver. The veprndnction in an}' Media of this
reported htfOrnholina rna,p not he made. in pardon Or. u nJude, Witham dye n•ritot permission . f Et7P. St') 1nuAYi.:ul 'ijoe ts. lnc_
EMPACT Analytical Systems Inc. 365 S Main St
Brighton, CO 80601 303-637-0150
EXTENDED NATURAL GAS ANALYSIS (*DHA)
DHA COMPONENT LIST
PRIMARY DB KEY:
LEASE #:
FIELD/AREA:
PROJECT NO. :
COMPANY NAME :
OFFICE / BRANCH:
CUSTOMER REF:
PRODUCER :
***FIELD DATA***
SAMPLE CYCLE:
SAMPLE PRES. :
FLOW PRES. :
LAB PRES:
SAMPLE TEMP. :
AMBIENT TEMP.:
H2O BY STAIN TUBE:
FIELD COMMENTS:
LAB COMMENTS:
COMPONENT
Helium
Hydrogen
Oxygen/Argon
Nitrogen
Carbon Dioxide
Methane
Ethane
Propane
i-Butane
Methanol
n -Butane
2,2-Dimethylpropane
i-Pentane
Acetone
n -Pentane
2,2-Dimethylbutane
Cyclopentane
2,3-Dimethylbutane
2-Methylpentane
3-Methylpentane
n -Hexane
2,2-Dimethylpentane
Methylcyclopentane
2,4-Dimethylpentane
2,2, 3 -Trimethylbutane
Benzene
202003023
AKA ENERGY
PLATTEVILLE, CO
993
120
Psig
prig
psig
°f
°f
#/mmcf
NAME/DESCRIP : EDEMAN INLET CONTACTOR
ANALYSIS NO.: 02
ANALYSIS DATE: MARCH 07, 2020 10:37
SAMPLE DATE : MARCH 3, 2020
TO:
EFFECTIVE DA'L'E
SAMPLE TYPE: SPOT
PROBE: NO
CYLINDER NO.: 1030
SAMPLED BY : JOHN POWELL
SAMPLING COMPANY: AKA ENERGY
H2S BY STAIN TUBE: ppm
CO2 BY STAIN TUBE: Mol %
PIANO # MOLE % MASS %
0.01 0.00
0.00 0.00
0.00 0.00
0.16 0.20
-- 2.97 5.94
P 1 76.28960 55.64000
P2 11.6103 15.8716
P3 4.6140 9.2498
14 0.8882 2.3470
XI 0.0040 0.0058
P4 1.6884 4.4615
15 0.0062 0.0203
15 0.5716 1.8749
X3 0.0001 0.0003
P5 0.5453 1.7887
16 0.0118 0.0462
NS 0.0145 0.0462
16 0.0203 0.0795
16 0.0675 0.2645
16 0.1275 0.4995
P6 0.1536 0.6018
17 0.0001 0.0005
N6 0.0364 0.1393
17 0.0050 0.0228
17 0.0005 0.0023
A6 0.0246 0.0874
Page 1
GPM @
14.65
3.099
1.269
0.290
0.001
0.531
0.002
0.209
0.000
0.197
0.005
0.004
0.008
0.028
0.052
0.063
0.000
0.013
0.002
0.000
0.007
GPM @
14.73
3.116
1.276
0.292
0.001
0.534
0.002
0.210
0.000
0.198
0.005
0.004
0.008
0.028
0.052
0.063
0.000
0.013
0.002
0.000
0.007
EMPACT Analytical Systems, Inc
365 S. Main Street, Brighton, CO 80601 303-637-0150
3,3-Dimethylpentane 17 0.0003 0.0014 0.000 0.000
Cyclohexane N6 0.0279 0.1067 0.009 0.009.
2-Methylhexane 17 0.0189 0.0861 0.009 0.009
2,3-Dimethylpentane 17 0.0041 0.0187 0.002 0.002
1,1-Dimethylcyclopentane N7 0.0030 0.0134 0.001 0.001
3-Methylhexane 17 0.0164 0.0747 0.008 0.008
1 c,3-Dimethylcyclopentane N7 0.0028 0.0125 0.001 0.001
It,3-Dimethylcyclopentane N7 0.0025 0.0111 0.001 0.001
3-Ethylpentane 17 0.0001 0.0005 0.000 0.000
lt,2-Dimethylcyclopentane N7 0.0046 0.0206 0.002 0.002
n-Heptane P7 0.0268 0.1221 0.012 0.012
1 c,2-Dimethylcyclopentane N7 0.0002 0.0009 0.000 0.000
Methylcyclohexane N7 0.0223 0.0996 0.009 0.009
2,2-Dimethylhexane 18 0.0005 0.0026 0.000 0.000
1,1,3-Trimethylcyclopentane N7 0.0006 0.0031 0.000 0.000
Ethylcyclopentane N7 0.0006 0.0027 0.000 0.000
2,2,3-Trimethylpentane I8 0.0009 0.0047 0.000 0.000
2,4-Dimethylhexane I8 0.0010 0.0052 0.001 0.001
Ic,2t,4-Trimethylcyclopentane N8 0.0004 0.0021 0.000 0.000
3,3-Dimethylhexane 18 0.0003 0.0016 0.000 0.000
lt,2c,4-Trimethylcyclopentane N8 0.0005 0.0026 0.000 0.000
Toluene A7 0.0213 0.0892 0.007 0.007
2,3-Dimethylhexane 18 0.0001 0.0005 0.000 0.000
2-Methyl-3-ethylpentane 18 0.0004 0.0021 0.000 0.000
1,1,2-Trimethylcyclopentane N8 0.0001 0.0005 0.000 0.000
2-Methylheptane 18 0.0032 0.0166 0.002 0.002
4-Methylheptane 18 0.0010 0:0052 0.001 0.001
3-Methyl-3-ethylpentane 18 0.0001 0.0005 0.000 0.000
3-Methylheptane 18 0.0007 0.0036 0.000 0.000
Ic,2t,,3-Trimethylcyclopentane N8 0.0036 0.0184 0.002 0.002
3-Ethylhexane 18 0.0002 0.0011 0.000 0.000
1t,4-Dimethylcyclohexane N8 0.0009 0.0046 0.000 0.000
1,1-Dimethylcyclohexane N8 0.0004 0.0021 0.000 0.000
3t-Ethylmethylcyclopentane N8 0.0001 0.0005 0.000 0.000
2t-Ethylmethylcyclopentane N8 0.0001 0.0005 0,000 0.000
1,1-Methylethylcyclopentane N8 0.0001 0.0005 0.000 0.000
]t,2-Dimethylcyclohexane N8 0.0005 0.0026 0.000 0.000
n -Octane P8 0.0042 0.0218 0.002 0.002
1c,4-Dimethylcyclohexane N8 0.0003 0.0016 0.000 0.000
2,3,5-Trimethylhexane 19 0.0001 0.0006 0.000 0.000
2,3,4-Trimethylhexane 19 0.0001 0.0006 0.000 0.000
1c,2-Dimethylcyclohexane N8 0.0001 0.0005 0.000 0.000
1,1,4-Trimethylcyclohexane N9 0.0004 0.0023 0.000 0.000
4,4-Dimethylheptane I9 0.0003 0.0017 0.000 0.000
Ethylcyclohexane N8 0.0001 0.0005 0.000 0.000
n-Propylcycl open tane N8 0.0004 0.0021 0.000 0.000
lc,3c,5-Trimethylcyclohexane N9 0.0001 0.0006 0.000 0.000
Ethyl benzene 18 0.0003 0.0015 0.000 0.000
1 c,2t,4t-Trimethylcyclohexane N9 0.0001 0.0006 0.000 0.000
2,3-Dimethylheptane 19 0.0001 0.0006 0.000 0.000
1,3-Dimethylbenzene(m-Xylene) A8 0.0026 0.0126 0.001 0,001
1,4-Dimethylbenzene(p-Xylene) A8 0.0008 0.0039 0.000 0.000
3,4-Dimethylheptane (2) 19 0.0002 0.0012 0.000 0.000
4-Methyloctane I9 0.0002 0.0012 0.000 0.000
2-Methyloctane 19 0.0003 0.0017 0.000 0.000
1 c,2t,4c-Trimethylcyclohexane 19 0.0003 0.0017 0.000 0.000
1,2-Dimethylbenzene (o-Xylene) A8 0.0004 0.0019 0.000 0.000
i-Butylcyclopentane N9 0.0001 0.0006 0.000 0.000
n-Nonane P9 0.0006 0.0035 0.000 0.000
Page 2
EMPACT Analytical Systems, Inc
365 S. Main Street, Brighton, CO 80601 303-637-0150
i-Propylbenzene
n-Butylcyclopentane
1,3-M etlrylethylbenzene
1,3,5-Trimethylbenzene
t-Butylbenzene
UnknownC9s
n-Decane
UnkllownCl Os
TOTAL
BTF.X COMPONENTS
BENZENE
TOLUENE
ETHYLBENZENE
XYLENES
MOLE%
0.0246
0.0213
0.0003
0.0038
A9 0.0001 0.0006
N9 0.0001 0.0006
A9 0.0001 0.0006
A9 0.0001 0.0006
A10 0.0001 0.0006
U9 0,0002 0.0012
P10 0.0001 0.0006
U10 0.0001 0-0006
100.00000 100.00000 5.8498
WT%
0.0874
0.0892
0.0015
0.0184
TOTAL BTEX
0.0500 0.1965
.(DET 41LED HYDROCARBON Abi lLYSISNI 1993)
Mod ASTMD6730,GPA 2261 & GPA 2286.
(CAC: GPA 2172, GPA 2!d & TP-17 (iii>14.696 & 60 F)
0.000
0,000
0.000
0.000
0.000
0.000
0.000
0.000
BTU 4i 14.65
LHV NET DRY REAL :
NET WET REAL :
HH V GROSS DRY REAL :
GROSS WET REAL :
NET DRY REAL :
GROSS DRY REAL :
RELATIVE DENSITY (AIR=1 ):
DENSITY
COMPRESSIBILITY FACTOR :
REGULAR WOBBE INDEX
C6+ Fraction of DHA Gas Analysis @60°F, 14.696 psia
1136.3 /scf
1116.4 /scf
1252.3 /scf
1230.4 /scf
19618.7 /lb
21615.1 /lb
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
5.8818
14.73
1142.5 /scf
1122.6 /scf
1259.2 /scf
1237.3 /scf
19725.9 /tb
21733.1 /Ib
0.7590
0.05796 lb/scf
0.99636
1442.0
Net Dry Ideal BTU 4510.3 /scf Relative Density - SG (Air=1) 3.0887
Gross Dry Ideal BTU 4854 /scf Z Compressiblity Factor 0.98985
Net Dry Ideal BTU 19228.7 /lb Density Factor 235.702 Ibm/1000 ft3
Gross Dry Ideal BTU 20694.1 /Ib Molar Mass or MW 89.443 g/mol
Volume Liquid Ideal gas 0.248 scf/gal
This hexases plus fraction may be applied in place of published C6+ factors. The Z & GPM need additional talc for C6+ factors.
#DIV/0 or 0 (zero) will appear in this section when there is no hexanes plus in the sample to calculate C6+ factors.
C6+factors
0.98936
24.4
The data proented hcrein ha% been acquired by menna of current analysled1 techniques and rept ert ents the f ylich ttr ennclraina Elf?' If 7. tout draI.S:olnn. Iun
Result_,the a ra11?i, an be atfeeted he the sompling condf c en+, there/Me. ore only karranted throwzh proper litlt protec 1. Ell? 1( 7-ass+tnee, np resynniAility
J<+r interin etatitnr or -ally cotoer7uenc, fivni application at the reported infarnrnrian and i the sole Mobility of the user. The repo odactiaa in any media d fhb;
',parted in fermatinn may nal he made, in pea ticur ,!r ns a a%hole, uathwri the miller' permission al ElIP.1( T Analytical 8),tem,.. Inc.
Page 3
EMPACT Analytical Systems, Inc
365 S. Main Street, Brighton, CO 80601 303-637-0150
PLANT: Weideman Compressor Station
SUBJECT: BTEX Combustor
AFE NO.: 19C20011 DATE: 3/3/2020
BY: RGA
TAG NO. EF-888
SERVICE: BTEX Combustion off TEG Reboiler
DESCRIPTION:
One (1), vertical, enclosed flare unit to combust hydrocarbon emissions generated from TEG Reboiler as BTEX
Emissions. Nominal destruction efficiency of hydrocarbons shall be greater than 98`)/o. Unit shall include burner
controls with shutdowns included for proof of flame and failure to ignite burner. The flare should be enclosed and
include a self -supported vent stack along with adequate measures for prevention of personnel contact with hot
surfaces. A flame arrestor is required for prevention of flame flash back.
LOCATION: Weld Co., CO
ELEVATION: 4770 ft.
SEISMIC: ASCE 7-10, Site Class D, Occupancy III, Seismic Group II, IF = 1.25
WIND: ASCE 7-10, Exp. C, Occupancy III, IF = 1.15, Topographical Factor 1.0
AMBIENT: -20°F / 100° F. (min / max) Air Temperature
PROCESS DESIGN
Gas Stream
Rate, SCFH
Flowing Density, Ib/ft3
Pressure, psig
Temperature, ° F
TEG Regeneration Vapors / BTEX
1068 / 5340 (see note) Add 50% capacity for final design with Methanol
0.973 flowing conditions change with seasons and connected gas streams.
0.5 to 1.75
180 to 205 Normal operating temperature is 199 °F
COMPONENTS Mole %
H2 0.000
N2 trace < 1 ppmv
O2 0.000
CO2 1.188
H2S trace < 8 ppmv
C1 0.614
C2 0.686
C3 0.754
iC4 0.223
nC4 0.598
iC5 0.390
nC5 0.491
C6+ 1.531 Methanol (MeOH), is possible to be present ahead of the TEG Regeneration system.
Benzene 1.694 When present it tends to fall out in the TEG Reboiler and exit with BTEX vapors in
Toluene 2.227 a significant volume comprising up to 71 mai% with a volume increase of 5x.
Ethylbenzene trace The volume indciated is with Methanol, which is worst Winter time case.
o-Xylene 0.685
H2O 88.919
TOTAL
OUTLET
NOx
CO
VOC
Destruction Temp
(Optional) WHRU Duty
Flue Gas Pressure Drop
100.00 Design Bumer for 1740 Btu/ft3 Gas Vapors
Manufacturer: TBD
P.O.:
EXPECTED GUARANTEE
mfr. std. No Specification
<10 ppm <10 ppmdv operating on clean residue gas
<2% Inlet <2% Inlet flow rate
>1100 ° F.
None Required MBTU/Hr
nil Inches Water
REVISION
ENGINEER/DATE
ISSUED FOR
0
RGA I 3/3/2020
Quote
1
RGA I 6/8/2020
Quote with modifcations
2
RGA I 6/25/2020
Purchase
A
IKA
PLANT: Weideman Compressor Station
SUBJECT: BTEX Combustor
AFE NO.: 19C20011 DATE: 3/3/2020
BY: RGA
TAG NO.: EF-888
SERVICE: BTEX Combustion off TEG Reboiler
BURNER One (1) Burner assembly .
Mfg. / Model NGSG: FKEF-H25-R4S-1,9MMBTU/HR-EPTKA W/ Flare King Air Assisted / Variable Port Tip
Rating, MMBtu/hr 1.9 BTU/HR
Draft Loss Nil Inches H2O
Turndown burner must be capable of light off with two continuous pilots.
Material 304SS
Pilot Two (2) continuous duty retractable pilots with electronic ignition
Blast / Paint n/a
Insulation n/a
Connections 3" FNPT
Flame Enclosure Flame to be enclosed (not visible) during maximum design conditions.
Corrosion Allow. Mfr. Std. inches
Material: Carbon Steel
Paint: Mfr. Std. with Frontier Tan Top Coat
Insulation: Mfr. Std.
Burn Protection: Mfr. Std.
Connections: Mfr. Std.
1) Two Pilots with type K Thermocouple for proof of pilot flame is required.
2) Burner, continuos pilots and Flame Management System with electronic ignition to be included.
3) A flame arrestor should be provided on the inlet feed line for adequate protection against flame flash back. Flame
arrestor should be eccentric to prevent pooling condensate.
4) Vendor should provide adequate means of supply of combustion air and flame adjustment. Inlet air flame arrestors are
preferable.
5) Vendor to provide a foundation footprint with design loads based upon wind and seismic design scope.
6) Providie means for lifting equipment and placing it on a foundation.
7) Combustor controller to be capable of Modbus communication with the plant control system.
Available Utilities
Instrument Air: Available clean dry air 80-130 psig.
Electricity: 480 VAC / 3 Ph. / 60 Hz
120 VAC / 1 Ph / 60 Hz.
Dimensions 24" Dia, X 25 ft. Tall
Shipping Weight 3,800 lbs.
REVISION
ENGINEER/DATE
ISSUED FOR
0
RGA I 3/3/2020
..........
Quote
1
RGA ( 6/25/2020
Purchase
Form APCD-101
Colorado Department of Public Health and Environment
Air Pollution Control Division
Company Contact Information Form
Ver. September 10, 2008
Company Name: Aka Energy Group, LLC
n�,,,jN76
C:oloradn Deparunent
of Public l leaf&
and Environment
Source Name: Wiedeman Compressor Station (123/9CD2)
Permit
Contact':
Graham Stahnke
Address:
1331 17th Street
Street
Denver
CO
80202
City
State
Zip
Phone Number:
720-946-0244
Fax Number:
E-mail:
gstahnke@akaenergy.com
Billing Contact:
(Permit Fees
Graham Stahnke
Address:
1331 17th Street
Street
Denver
CO
80202
City
State
Zip
Phone Number:
720-946-0244
Fax Number:
E-mail:
gstahnke@akaenergy.com
Compliance
Contact2:
Graham Stahnke
Address:
1331 17th Street
Street
Denver
CO
80202
City
State
Zip
Phone Number:
720-946-0244
Fax Number:
E-mail:
gstahnke@akaenergy.com
Billing Contact:
jAnnual Fees,'
Graham Stahnke
Address:
1331 17th Street
Street
Denver
CO
80202
City
State
Zip
Phone Number:
720-946-0244
Fax Number:
E-mail:
gstahnke@akaenergy.com
Check how would you like to receive your permit fee invoice'?
Mail: ❑
E-mail: EZI
Fax: ❑
Footnotes:
The permit contact should be the point of contact for technical information contained in the permit application.
This may be a company representative or a consultant.
2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted
facility.
3 The billing contact (Permit fees) should be the point of contact that should receive the invoice for fees
associated with processing the permit application & issuing the permit. (Reg. 3, Part A, Section VI.B)
a The billing contact (Annual fees) should be the point of contact that should receive the invoices issued on an
annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3, Part A,
Section VI.C)
Page 1 of 1
AP_Forrn-APCD- 1 01 -Company-Contact-Infonnation.doc
Form APCD-102
Company Name: xk., }..u:*x,-I0,stp 1.1+
Source Name: A wdo mt
Source AIRS ID: I. 3
Colorado Department of Public Health and Environment
Air Pollution Control Division
Facility Wide Emissions Inventory Form
We April, 2015
Eneonkoikd Poteatbl to EMI (PIE,
Controlled Potential to EMI (P'1 El
Criteela( el': 11.51 s(111501
Criteria CI PIS IIAPI(11..!51)
A110 110
OriOt
E;.....'4'1.7.:t.4u1.7.:tn
TSP
PM10
I.Vf].i
SO2
NOa
V(1('
co1153'1O
Aeex.t
Acry
a%
l'al
E8
X5224-104Pa-Ilea
Iletb
224-1P
TSP
155410
1':112.5
SO2
501
VOC
CO HCIIO
Venal
Val
hero
e],
lot
1541
151
uEtel
Meth
1'
224 -MP
121MC112A1Di
C'at C'1516H
0.5
(1.5
11.
001
6.7
175
111: 11727
757
4116
112
732
4
25
100
226
2.1
OS
05
D5
001
n .7
6.1
8 2,032
119
" i
59
164
,
17
SO
113
II
,3N
12C•02A1R2
Cat
0-5
0.5
05
11.03
67
1 5
,11.6 1 11,727
757
46i.
112
732
J
?4
ills
22A
71
05
D_S
(IS
11.11,1
A]
6.i
3J f 2932
219
+'1
59
364
12
50
113
it
121HCO2,011,1
Crt 53151611
0.5
0
0.5
001
6,7
12.5
,1'1.1, 111,727
757
466
IIN
738
V
25
101
226
�3
0.5
0..5
0
00;1
0.7
6.3
x4 I --,932
.119
21,1
54
.169
1
11
50
111
11
12,.09(71'2r0o4
Cat 4135160
05
0.5
0..5
0.01
M17
12.5
11.0 111.727
757
466
112
1.11
J
7_.S
101
?26
11
0.5
0.3
0.5
003
6,7
6,3
8.4 12,9.12
379
211
54
769
12
50
111
it
123/453024'21.5
Cat 531.15160
u.
11.,5
0..5
0.03
0.7
12.,4
330 111,727
757
466
IIN
138
4
15
IDI
226
..r
0,$
11.5
0
0.03
6.7
61
N.4 2,912
1
379
213
S4
164
12
50
113
II
12151(315111.816C'2nndO]Wbbiosntc
Tanks
s
—5
—
_
_
..
5.N
— —
I
—
—
144
105
53
255
—
?'
_
_
_
-.
-.
5.2
— I —
--
—
144
105
1
53
255
..
—
,wu
fl..1"; ikluAr5s,s.
' <,
I
-
u 6^.'.
:;9
',.•0
11,,
;. .1,
t.
.-
—
..
_
,,
.- I —
—
—
Permitted Source. Subtolal-
APES Only. Permit Exempt Sources
21
21
2.3
0.2
11.5
192.2
168.0 1s 52,635
5,125
2.310
35,566
48,225
875
15;281
7,240
1,130
115
2J
2.3
23
0.I
11.5
41.5
42.0 1I 14,660
1,495
1,165
2,181
4,197
54
MR
812
565
5<
APES Only Subtotal-
APE -58 Exempt; IasiBWOcant sourm
0.0
I_ 0.0
0.0
0.0
0.0 I
0,0 I
0.0 : 0
0
0
0
[ 0 1-
0
0
0
OD
1
0.0
1 0.0
0.0
0.0
I 0.0
0.0 �
0.0 1, 0
[ 0
f 0 1
0
0
0
0[
0
1 01
0
—
Tanl'lkaur
003
0.03
OO3
O!all
DA
0.02
OA 3. 7
—
7
4
14
12
IS
N
0.03
003
001
00 01
0.4
OO7
0.4 5 1
14
25
—
Tael II..
0.01
003
0.01
0001
04
0.02
0,4 1 7
M1
_
7
9
15
12
IS
2
?3
01O1
0.01
0.01
0.001
0.4
OO2
0.4 I 7
e-
'
4
1')
12
15
ti
23
-
Condensete tuadout
-
-
_
-
--
OE
- I -
_
_
1
-
0
I
7
-
-
-
-
-
-
-
0:2
- I -
-
_
1
2
-
Eytipn\ttxl snR5 of
_
_
_
..
_
0.11
_ I _
_
..
1
5
0
4
S
_
_
_
_
_
_
_
011
_ I _
_
_
5
6
9
1
1
I
I
Insignificant Subtotal-
look Alt Souters-
0.1
0.1
0.1
0.D
0.8
0.4
DI ! 14
12
0
20
IS
18
14
42
16
SO
0.1
0.1
0,1
0.0
041
OA
9.2 ! 14
12
0
20
25
38
14
♦2
12
50
2J 2.3 2.3 0.2 W 1 192.6 168.8 ! 52,649 1.797 2.330 15,586 48,750 911 115,1151 7,132 1,146 165 21 2.1 2.3 0.2 34..1 41.9 42.8 ! 14,674 1,907 1,165 2,201 4,222 42 902 874 541 1O5
E'oconlrolled 11.1PS Sumury(CPVI
l:nconlrolled Total, All H.5Ps(mil
enntr+aled NAP5Sunmulr5(ITV,-I
Controlled Total, All IIAYI(TPV)
-I 291 I 1.9 I 1.2 117.8 I 24.4 I 0.5 I 7.7 I 3.7 I 0.0 I al I
71 I IA 10.6 I 1,1 12.1 10.0 10.5 I 0.4 10.1 I 0.1
I
- 1 1
alb
Footnotes:
I. This corm should be completed to include bah existing sources and all proposed new or motlifiealions to existing emissions sonmrs
2. If the Cn1iS8ial9 sauce is new then enter "proposed" under the Perna No. and AIRS ID diem colunms
3. HAPahbrevi:dons include:
0'L = Benzene 224-TMP = 2 :p= frimelhylpmutine
Tot = Toluene Atrial = Acetaldehyde
E6 = Ethylbenzene Acro = Acrolcin
Xyl = Xylem n•Nex = n -Hexane
tICHO = Formaldehyde Meth = Melhanel
4. APEN Exempt/Insignificant Sources should be included when warranted.
Company Name
7/10/2020 Page 1 of i
Wiedeman Compressor Station. Process Description
Gas enters the compressor station where it is routed to an inlet separator slug catcher. The inlet
separator slug catcher separates gas from any hydrocarbon/water condensate. The vapor exiting the
inlet separator is then routed through a station inlet meter and then into the compressors suction
header.
From the compressors suction header gas is compressed by five Cat35166/Ariel JGT4 compressors. Gas
is discharged from each compressor into a common discharge header. From there it is routed through a
gas/condensate heat exchanger where heat is passed from the discharged gas to the
hydrocarbon/water condensate gathered from the inlet separator slug catcher and all separators
located on the individual compressor skids.
The gas exits the heat exchanger and is then passed to the TEG (Tri-ethylene glycol) dehydration
absorber. In the absorber the gas is in contact with TEG which allows the gas stream to be dehydrated
to a water content of 7lb H2O/ mmscfd or less. Gas is then passed through filtration and then exits the
facility.
TEG is regenerated by removing absorbed water by use of a direct fired reboiler. Water vapor and small
amounts of hydrocarbon vapor released from the TEG regeneration skid are routed to a small condenser
where the majority of hydrocarbon vapors and some water are condensed and then pumped back into
the hydrocarbon/water condensate header system. Any hydrocarbon and water vapor that is not
condensed is routed to a VRU compressor which discharges back into the inlet gas stream.
Hydrocarbon/water condensate from the various separators located in the facility will be gathered by a
common condensate header system. The header system will route the condensate to the
gas/condensate heat exchanger. The heat exchanger's function is to pass heat from the gas discharged
from compression into the condensate in order to stabilize the condensate. Stabilized condensate is
then passed into a pipeline where it is transported to the Aka Gilcrest Gas Plant for storage and trucking.
In the event of a pipeline interruption the stabilized condensate can be stored in on site atmospheric
tanks.
Vapors generated in the gas/condensate heat exchanger will be routed to a VRU compressor which
discharges back into the inlet gas stream. Vapors from the tanks are less than 6 ton/yr of VOCs and will
be routed to atmosphere.
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Form APCD-302
APCD Internal Use Only
Received Date
Approved? ❑ Approval Date
Operating and Maintenance Plan Template for
Glycol Dehydration Systems
Ver. June 22, 2020
The Air Pollution Control Division developed this Operating and Maintenance Plan (OaM Plan) for glycol dehydration
systems that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of
Colorado. One oam Plan may be used for multiple dehydration systems at one facility if each are controlled and
monitored in the same manner.
An OFtM Plan shall be submitted with the permit application when required. The facility operator must comply
with the requirements of the OI}M Plan upon commencement of operation. An existing approved oam Plan may
be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements
of the existing approved oam Plan until an approval letter is issued for the new OftM Plan.
The operator is required to use the division -developed atm Plan template forms in order to meet minimum
expectations within a standard, organized format. Do not modify the structure and/or content of this template.
If the facility or emission unit is subject to other state or federal regulations with duplicative requirements, the
operator must follow the most stringent regulatory requirement.
Please note that O&M requirements are different for facilities in the Denver Metro and North Front Range 8 -hour
ozone nonattainment area.
For sources that are subject to the Title V Operating Permits program: In accordance with Colorado
Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this O&M plan will be
incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring
not listed in this O&M Plan may be included in the source's Operating Permit in order to satisfy the periodic
monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b.
Submittal Date: August 7, 2020
Section 1 - Source Identification
For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the
time of application. Please only fill in the fields that are known and leave the others blank.
Company Name: Aka Energy Group, LLC Facility
Location:
Wiedeman Compressor
Facility Name: Station
Is this facility located in the Denver
Metro and North Front Range 8 -hour
ozone nonattainment area?
® Yes
❑ No
SW/4 NE/4 Section 29, R66W,
T4N
Facility AIRS ID (for existing facilities) 123 - 9CD2
Emission Units Covered by this OFtM Form
Facility Equipment ID
TEG Dehy
Permit Number (if known)
2fIstnifir7q9
AIRS Point ID (if known)
(267
Glycol Type Used a
TEG
Equipped with Flash Tank? (Y/N)
Y
a Glycol types are Ethylene Glycol (EG), Diethylene Glycol (DEG), or Triethylene Glycol (TEG).
Page 1 of 5
CDPHE
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Section 2 - Maintenance Schedules
Check one of the following:
Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions
unit and control devices. These schedules and practices, as well as all maintenance records showing
compliance with these recommendations, shall be made available to the division upon request.
Facility shall follow individually developed maintenance practices and schedules for the operation and
maintenance of emissions unit and control devices. These schedules and practices, as well as all
maintenance records showing adherence to these practices, shall be made available to the division upon
request and shall be consistent with good air pollution control practices for minimizing emissions as
defined in the New Source Performance Standard (NSPS) general conditions.
Section 3 - Recordkeeping Requirements
The following box must be checked for the 08M Plan to be considered complete:
Synthetic minor and major sources are required to maintain maintenance and monitoring records for
the requirements of this oam Plan for a period of five (5) years. If applicable state requirements or
any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply
with the longest record retention requirement.
Page 2 of 5
COLORADO
Air Pollution Control Division
Department of Public Health 8 Environment
Section 4 - Monitoring Requirements
Control Equipment Information
Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of
control equipment and the requested permitted emissions at the facility. Indicate the emissions control type(s)
by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on
the facility attainment area status and facility -wide permitted VOC emissions.
Table 1
Emissions Control
or
Recycling Method
Parameter
Monitoring_Frequency
Ozone Nonattainment Area
Ozone Attainment Areas
Still
Vent
Flash
Tank
of
present)
► Permitted
Permitted
Facility
Emissions
< 40 tpy VOC
Permitted
Facility
Emissions
≥ 80 tpyVOC
Permitted
Facility
Emissions
< 80 tpy VOC
Facility
Emissions
≥ 40 tpy VOC
Condenser b
Condenser
Outlet
Temperature
Weekly
Monthly
Weekly
Monthly
►�
Enclosed
Flare or
Elevated
Open Flare c
Pilot Light /
Auto -igniter
Monitoring
and
Visible
Emissions
Observation
Daily d' e
Weekly d' a
Daily d' e
Weekly d, e
lir
Thermal
Oxidizer f
Combustion
Chamber
Temperature
and
Visible
Emissions
Observation
Daily e' f
Weekly e' f
Daily e' f
Weekly e' f
Vapor
Recovery Unit
(VRU) or
Recycled or
Closed Loop
System s
Monitoring requirements, including parameters and frequency, to be determined
by the operator and listed below in footnote g.
Routed to
Reboiler
Burner as
Fuel h
n
Monitoring requirements, including parameters and frequency, to be determined
by the operator and listed below in footnote h.
Other
n
Monitoring requirements, including specific parameters and frequency, to be
described in Section 5 below, and approved by the division.
Page 3 of 5
CDPHE
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
b Condenser Maximum Outlet Temperature
If the emissions unit is controlled with a secondary control device and no control efficiency is being claimed
for the condenser, then the condenser outlet temperature does not need to be monitored and there is no
maximum condenser outlet temperature. If a control efficiency is claimed for the condenser, the maximum
condenser outlet temperature shall be:
Table 2: Condenser Maximum Outlet Temperature
❑
160 °F
❑
°F
A maximum temperature greater than 160 °F requires approval from the division.
Supporting documentation must be submitted with the permit application and made
available to the division upon request.
Elevated Open Flare
An open flare permitted after May 1, 2014 and used to comply with Regulation No. 7 Section XVII must be
approved by the division as an alternate emission control device prior to operation, in accordance with
Regulation No. 7 Section XVI1.6.2.e.; see PS Memo 15-03.
d Pilot Light Monitoring Options
If emissions are controlled by combustion device, then the operator must indicate in Table 3 the method by
which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be
checked and, optionally, secondary methods may be checked.
Table 3: Pilot Light Monitoring
Primary
Secondary
Monitoring Method
❑
/2
Visual Inspection
❑
❑
Optical Sensor
L
❑
Auto -Igniter Signal
�1
Thermocouple
e Visible Emissions Observation and Method 22 Options
At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject combustion
device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible
emissions inspection, the operator has the option to either (1) immediately shut-in the emissions unit to
investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs
completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined
per Regulation No. 7, Section XVII.A.17.) are present.
If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this
OaM Plan. If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary
repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the
operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific
repairs completed.
The division has historically approved a "check box" to satisfy the Method 22 documentation procedures. The
division will continue to accept the "check box" recordkeeping format in instances where no visible emissions
are observed in order to demonstrate compliance.with the Method 22 requirement.
If a flare is not subject to Regulation No. 7 requirements (as described in the permit), a similar approach may
be employed where the operator may conduct an inspection for presence or absence of smoke, and, if smoke is
observed, the operator has the option to (1) immediately conduct repairs and maintain records of the specific
repairs completed; (2) shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary
repairs, and maintain records of the specific repairs completed; or (3) conduct a formal Method 9 observation
to determine the opacity of the visible emissions, and conduct repairs if necessary.
Page 4 of 5
CDPHE
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
f Thermal Oxidizer: Minimum Combustion Chamber Temperature
If emissions are controlled by thermal oxidizer, the minimum combustion chamber temperature shall be:
Table 4: Thermal Oxidizer Minimum Combustion Chamber Temperature
U
1400 °F
Equal to the average combustion chamber temperature observed during the most recent division -
approved stack testing.
g Vapor Recovery Unit (VRU) or Recycled or Closed Loop System
In the space provided below, please provide a description of the emission control system, including an
explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions
are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a
description of how downtime is tracked and recorded. Attach additional pages if necessary.
Vapors from the flash tank are recovered using the VRU.
Operators will verify that the VRU is functioning properly on a daily basis.
Downtime is tracked and recorded in an operating log when the VRU is down.
h Routed to Reboiler Burner as Fuel
In the space provided below, please provide a description of the emission control system, including an
explanation of how the system design ensures that emissions are being held or rerouted when the reboiler is
not firing. Describe the cycling frequency of the burner. Describe the other parameters and frequency for
monitoring of this emissions control approach. Attach additional pages if necessary.
Section 5 - Additional Notes and oam Activities
Please use this section to describe any additional notes or operation and maintenance activities, or if additional
space is needed from a previous section. Attach additional pages if necessary.
No control efficiency is claimed for the condenser. Flash tank emissions are
sent to the facility inlet using a closed loop system when VRU is down.
Condenser vent emissions are sent to VRU when combustion device is down.
Page 5 of 5
Emission Control Device (ECD) Emission Calculations
Aka Energy Group, LLC
Wiedeman Compressor Station
Enclosed Combustion Device (ECD) Emissions
ECD
Burner rating a:
Pilot rating:
Pilot + burner total:
Operating hours:
Waste gas heat content:
1.9 mmBTU/hr (manufacturer)
0.05 mmBTU/hr (estimated)
1.95 mmBTU/hr
8,760 hr/yr (potential)
200 BTU/SCF (GLYCalc condenser vent estimate)
Pollutant
Emission Factor
Potential Emissions
NO„
0.0641 Ib/mmBTU b
0.12 lb/hr
0.5 ton/yr
CO
0.5496 Ib/mmBTU b
1.07 lb/hr
4.7 ton/yr
PM10
7.45E-03 Ib/mmBTU `
0.01 lb/hr
0.064 ton/yr
5O2
5.88E-04 Ib/mmBTU `
0.00 lb/hr
0.005 ton/yr
Formaldehyde
0.00028 Ib/mmBTU d
0.001 lb/hr
0.002 ton/yr
a Burner rating based on maximum design burner heat input.
b Emission factors for flares firing low BTU gas (5_ 1,000 BTU/scf) from "Flares and Vapor Oxidizers", Texas Natural Resource Conservation
Commission, Publication RG-109, Table 4.
c Emission factor for external natural gas combustion from AP -42 Table 1.4-2 (7/98 rev.). All PM is expected to be < 1 micron diameter, and the PM10
emission factor therefore also provides an estimate of PM and PM2.5 emissions.
d Emission factor for flare from "Technical Guidance Package for Chemical Sources: Flare Sources", Texas
Natural Resource Conservation Commission, New Source Review Division, July 1996, as presented in GRI HAPCaIc 3.0
Page 1 of 1 1/6/2021
Hello