HomeMy WebLinkAbout20194617.tiffCOLORADO
Department of Public
Health Et Environment
Weld County - Clerk to the Board
1150 O St
PO Box 758
Greeley, CO 80632
October 16, 2019
Dear Sir or Madam:
RECEIVED
OCT 2 3 2019
WELD COUNTY
COMMISSIONERS
On October 17, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for
DCP Operating Company, LP - Enterprise 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 Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Clara Gonzales
Regards,
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
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
pub);c Review cc:P4.(rP),,Pw(IH/E&/CH/ck),
l O%x/19 o6(7,4)
1 a/a.ut/l 9
2019-4617
41
TM
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: DCP Operating Company, LP - Enterprise Compressor Station - Weld County
Notice Period Begins: October 17, 2019
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: DCP Operating Company, LP
Facility: Enterprise Compressor Station
This facility is a natural gas compressor station.
SWSW Section 30, T3N, R63W (6 miles northeast of Keenesburg)
Weld County
The proposed project or activity is as follows: Permit replacement dehydration unit and emissions increases
to the stabilized condensate storage tanks and stabilized condensate loadout.
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 19WE0492 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Elie Schuchardt
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
Department of Public
Health Er Exwircrimcnt
COLORADO
Air Pollution Control Division
zrtrnent or Putt c Heath Et Enrcrerontnent
Dedicated to protecting and improving the health and environment of the people of Colorado
CONSTRUCTION PERMIT
Permit number: 1 9WE0492
Date issued:
Issued to:
Facility Name:
Plant AIRS ID:
Physical Location:
County:
Equip
Issuance: 1
DCP Operating Company, LP
Enterprise Compressor Station
123/0277
SWSW Sec 30, T3N, R63W
ita County
tural Gas Compressor Station
subject to this permit:
Emissions Control,
Description
Facility
Equip dent
P013
AIRS''
Point
Equipment Description
Eight (8) 300 barrel fixed roof stabilized
condensate storage vessels
Enclosed Combustor
AtrCospheric'truck Loadout of stabilized
condensate by submerged fill
Enclosed Combustor
D-3
077
One (1) Triethylene glycol (TEG) natural
gas dehydration unit (make, model, serial
number: not submitted) with a design
capacity of 145 MMscf per day. This
emissions unit is equipped with two (2)
FMC Triplex glycol pumps (one primary,
one backup) with a design capacity of 25
gallons per minute each. This unit is
equipped with a flash tank, reboiler and
still vent.
Emissions from the still vent
are routed to a condenser
and then to an enclosed
combustor (COMB -1),
permitted 1% downtime
annually. Emissions from
the flash tank are routed
directly to the VRU and
recycled to plant inlet or
routed to the enclosed
combustor during permitted
periods of VRU downtime,
not to exceed 5% downtime
annually.
Point 077: The glycol pumps may be replaced with another pump in accordance with the provisions
of the Alternate Operating Scenario (AOS) in this permit.
Page 1 of 22
COLORADO,
Air Pollution Control Division
imer: or r;abtc Health (1. Er on n err
Dedicated to protecting and improving the health and environment of the people of Colorado
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. Point 077: YOU MUST notify the Air Pollution Control Division (the Division) nolater than fifteen
days of the latter of commencement of operation or issuance of this permit, by submitting a
Notice of Startup form to the Division for the equipment covered by this permit. The Notice of
Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit.
Failure to notify the Division of startup of the permitted source is a violation of Air Quality
Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the
revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions cot tained in this permit shall b.e
demonstrated to the ;division °lt is the owner or operator's responsibility to ,self -certify
compliance with the conditions ••"Failure to demonstrate compliance within 180 days may result
ink revocation -of the' permit. A self certification form and guidance on how to self -certify
compliance as required by this permit may beaobtained online'at www.colorado.coVicdphe/air-
)Sermit-self-ceficati(oh. (Reference: 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 nor activity was scheduled to commence as set_fin the permit -application
associated,. with this permit; (ii) discontinues construction fora 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. (Reference:'; Regulation
Number 3, Part B, Section
4. Point 077: 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.
(Reference: Regulation Number 3, Part B, Section III.E.)
5. Point 077: 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.
(Reference: 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
Page 2 of 22
COLORADO
Air Pollution Control Division
ent of Pazst c Health & rnvtronment
Dedicated to protecting and improving the health and environment of the people of Colorado
7. Emissions of air pollutants shall not exceed the following limitations. (Reference: Regulation
Number 3, Part B, Section II.A.4.)
Monthly Limits:
Facility
Equipment ID
AIRS
Point
Process
Pounds per Month
Emission
Type
PM2.5
PM10
NO.
V0C
CO
D-3
077
01
---
---
85
3,751
386
Point
02
---
---
165
316
753
03
---
---
4
0.2
4
Note: Monthly limits are based on a 31 -day month.
For Point 077, the following process designations apply:
• (01) Dehydration Unit
2),`Combustor Assist.rGas
(03) Combustor Pilot Gas
A
The owner or operator'shall calculate monthly emissions based on the calendar rn i tth.
Point 063, 077: Emissions of each individual hazardous air pollutant from glycoldehydration
its and storage vessels shalt not exceed 1,359 pounds per month •_
of dehydration units and
Point 063, 077: Emissions of total hazardous air pollutants fray
storage vessels:.shall not exceed 3,398 pounds per month.
The facility wide emissions limitation for hazardous air pollutants shall apply to? the glycol
dehydration unit and storage vessels at this facility only.
Annual Limits:
Facility
Equipment ID
AIRS
Point
Process
Tons: per Year
PM2.5
PM10
NO.
V0C
CO
Emission
Type
P013
063
01
1.68
Point
P016
066
01
0.94
Point
D-3
077
01
0.50
22.08
2.27
02
0.97
1.86
4.43
03
0.02
0.001
0.02
Point
Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits.
For Point 077, the following process designations apply:
• (01) Dehydration Unit
• (02) Combustor Assist Gas
• (03) Combustor Pilot Gas
Point 063, 077: Emissions of each individual hazardous air pollutant from glycol dehydration
units and storage vessels shall not exceed 8.0 tons per year.
Page 3 of 22
COLORADO
Air Pollution Control Division
aramem of Public Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Point 063, 077: Emissions of total hazardous air pollutants from glycol dehydration units and
storage vessels shall not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to the glycol
dehydration unit and storage vessels at this facility only.
Point 077: During the first twelve (12) months of operation, compliance with both the monthly
and annual emission limitations is required. After the first twelve (12) months of operation,
compliance with only the annual limitation is required.
Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be
determined on a rolling twelve (12) month total. By the end of each month a new twelve month
total is calculated based on the previous twelve months' data. The permit holder shall calculate
actual emissions each month and keep a compliance record on site or at a local field office with
site responsibility for Division review.
8. Point 063, 066: The owner or operator must use the emission factors found in "Notes to Permit
Holder" to calculate emissions and show compliance with the limits. The owner or operator
must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the
use of any other method of calculating emissions.
9. Point 077: 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, ,enclosed combustor downtime,
condenser outlet tem;peratur.e, flash ;,tank temperature and pressure, wet gas inlet
temperature, and wet gas inlet pressure. Recorded operational values, except for gas
throughput, VRU downtime and,enclosed combustor downtime, shall be averaged on a monthly
basis for input into the model and be provided to the Division upon request.
10. Point 077: On a weekly basis, the owner or operator shall monitor and record operational values
including: condenser outlet temperature, flash tank temperature and pressure, wet gas inlet
temperature and pressure. These records shall be maintained for a period of five years and
made available to the Division upon request.
11. Point 077: On a daily basis, the owner or operator shall monitor and record hours of VRU
downtime in a log to be made available to the Division upon request. VRU downtime is defined
as periods of time where the waste gas vented from the dehydration unit flash tank is routed
to the enclosed combustor, rather than to the VRU. These records shall be maintained for a
period of five years and made available to the Division upon request.
12. Point 077: On a daily basis, the owner or operator shall monitor and record hours of enclosed
combustor downtime in a log to be made available to the Division upon request. Enclosed
combustor downtime is defined as periods of time where the waste gas vented from the
dehydration unit still vent is routed to atmosphere, rather than to the enclosed combustor.
These records shall be maintained for a period of five years and made available to the Division
upon request.
13. The emission points in the table below shall be operated and maintained with the emissions
control equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit. (Reference: Regulation Number 3, Part B, Section III.E.)
Page 4 of 22
COL0RA0O
Air Pollution Control Division.
ent of *,attic Health ft En tronment
Dedicated to protecting and improving the health and environment of the people of Colorado
Facility
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
P013
063
Enclosed Combustor
VOC and HAP
P016
066
Enclosed Combustor
VOC and HAP
D-3
077
Still Vent: Enclosed Combustor (except
during enclosed combustor downtime - up
to 1% annually)
VOC and HAP
Flash Tank: Enclosed Combustor (during
VRU downtime - up to 5% annually)
VOC and HAP
14. Point 077 =The owner or operator shall operate and maintain.. the emission ;points in he table
below as -a closed loopsystem and shall recycle 100% of emissions as described in the table
below. (Reference: Regulation Number 3, Part B, Section III.E.)
)
Facility
Equipment
ID
AIRS
Point
Emissions Recycling Description
Pollutants
Recovered
D-3
0
Flash Tank: Recycled to Plant Inlet with VRU
(except during VRU downtime - up to 5%
downtime annually)
VOC ;and
HAP:
PROCESS LIMITATIONS AND RECORDS
16. 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. (Reference: Regulation Number 3, Part B,
II.A.4.)
Process Limits
Facility
Equipment
ID
AIRS
Point
Process
Process Parameter
Annual Limit
Monthly Limit
(31 days)
P013
063
01
Stabilized Condensate
Throughput
202,848 barrels
---
P016
066
01
Stabilized Condensate
Loaded
202,848 barrels
---
D-3
077
01
Dry Gas Throughput
52,925 MMscf
4,495 MMscf/month
02
Assist Gas Throughput
28.0 MMscf
2.4 MMscf/month
03
Pilot Gas Throughput
0.44 MMscf
0.04 MMscf/month
For Point 077, the following process designations apply:
Page 5 of 22
ICOLORAQO
Air Pollution Control Division
7ariment of Puz;l:c He k t 4 Et. won?nex t
Dedicated to protecting and improving the health and environment of the people of Colorado
• (01) Dehydration Unit
• (02) Combustor Assist Gas
• (03) Combustor Pilot Gas
The owner or operator shall monitor monthly process rates based on the calendar month.
Point 077: 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.
17. Point 077: The volume of drygas throughput shall be measured by gas meter at the outlet of
the dehydrator. The owner or "operator shall use monthly throughput records'todemonstrate
compliance with the processlimits contained in this permit and to calculate'.em ssions as
•described i this permit.
18. Point 0.77: The; total amount ofIgas throughputto the dehydration unit during'hours of VRU
downtime shall�not exceed 5% of the total gas throughput to the dehydration unition a rolling
twelve (12) month basis. Compliance with- this limit will be monitored monthly using the
monthly dehydration unit gas ` throughput; indicated by the gas meter•` in conjunction with the
total monthly 'hours of VRU downtime Records demonstrating compliance with this limitation
will be maintained an4. made'available tonne Division upon request.
19. Point 077: The total amount of gas throughput to the"dehydration unit during hourstof enclosed
combustor downtime shall not exceed,1% the total "gas throughput to the dehydration unit
on a rolling twelve (12)°month basis. Compliance with this limitwill be monitored monthly using
the monthly dehydration unit gas.' throughput indicated ; by the gas meter in conjunction with
the total monthly hours of enclosed combustor downtime. Records demonstrating compliance
with this limitation will be maintained and made available to the Division upon request.
20. Point 077: This unit shall be limited to the maximum lean glycol circulation rate of 25 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
21. Points 063, 077: 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. (Reference:
Regulation Number 3, Part B, Section III.E.) (State only enforceable)
Page 6 of 22
COLORADO
Air Pollution Control Division.
brit of Publlc Health C I_,^,ionn-an€
Dedicated to protecting and improving the health and environment of the people of Colorado
22. Points 063, 066, 077: No owner or operator of a smokeless flare or other flare for the
combustion of waste gases shall allow or cause emissions into the atmosphere of any air
pollutant which is in excess of 30% opacity for a period or periods aggregating more than six
minutes in any sixty consecutive minutes. (Reference: Regulation Number 1, Section II.A.5.)
23. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
24. Point 063: The storage tanks covered by this permit are subject to Regulation Number 7,
Section XII.I. The owner or operator must do the following and maintain associated records and
reports for a period of five years:
• Document the maintenance of the air pollution control equipment according to
manufacturer specifications;
• Conduct an annual opacity observation once each year on the air pollution control
equipment to verify opacity does not exceed 20% during normal operations;
Maintain records of the monthly stabilized condensate' throughput and monthly actual
VOCemissions; and
• Report compliance with these requirements . to the Division annually.
Reference: Regulation No. 7, Section XII.I.4)
25. Point 063: The combustion device controlling the condensate storage tanks covered by this
permit is subject to Regulation Number 7, SectionXVII B 2ssGeneral Provisions (State only
"enforceable) If a flare or other combustion device°is used to control emissions of volatile
organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions
during normatloperations, as defined under Regulation Number 7, XVII.A.17; an 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.
26. Point 063: The storage tank covered by this permit is subject to the emission control
requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and
operate air pollution control equipment that achieves an average hydrocarbon control
efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency
of at least 98% for hydrocarbons except where the combustion device has been authorized by
permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation
Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years,
made available to the Division upon request. This control requirement must be met within 90
days of the date that the storage tank commences operation.
Page 7 of 22
COLORADO
Air Pollution Control Division
Department or Public Health tr Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
27. Point 063: The storage tanks covered by this permit are subject to the capture requirements
of Regulation Number 7, Section XVII.C.2.a. The owner or operator must route all hydrocarbon
emissions to air pollution control equipment, and must operate without venting hydrocarbon
emissions from the thief hatch (or other access point to the tank) or pressure relief device
during normal operation, unless venting is reasonably required for maintenance, gauging, or
safety of personnel and equipment. Compliance must be achieved in accordance with the
schedule in Section XVII.C.2.b.(ii) and records must be maintained as required by Section
XVII.C.3.
28. Point 066: This source is located in an ozone non -attainment or attainment -maintenance area
and is subject to the Reasonably Available Control Technology (RACT) requirements of
Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted
by submerged fill. (Reference: Regulation 3, Part B, III.D.2)
29. Point 066: All hydrocarbon liquid loading operations, regardless of size, shall be designed,
operated and maintained; so as to minimize leakage of volatile organic compounds to the
atmosphere to the maximum extent practicable..`
30. Point 066: The owner or operator shall follow loading procedures that minimize the leakage of
VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2):
The owner or operator shall inspect'onsite� loading equipment to ensure that hoses,
couplings, and valves are maintained to prevent dripping, leaking, or other liquid or
vapor toss during loading and unloading. The inspectionshall occur at lest monthly.
Each inspecti•
on: shall be documented in a log available to the"Division on request.
All compartment hatches at the acility (including o f hatches) shall be closed and
latched at all. ;times when loading operation : are not active, except fad' periods of
maintenance, gauging, o safety Of personnel and equipment.
'^spect thief hatch seals annually for integrity and replace as necessary, FThief hatch
covers shall be weighted and properly seated.`
d. Inspect pressure relief devices (PRD) annually for proper operation and replace as
necessary. PRDs shall be set to release at a pressure that will ensure flashing, working
and breathing losses are not vented through the PRD under normal operating conditions.
e. Document annual inspections of thief hatch seals and PRD with an indication of status,
a description of any problems found, and their resolution.
31. Point 066: For this controlled loading operation, the owner or operator shall follow loading
procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to
(Reference: Regulation 3, Part B, III.D.2):
a. Install and operate the vapor collection and return equipment to collect vapors during
loading of tank compartments of outbound transport trucks.
b. Include devices to prevent the release of vapor from vapor recovery hoses not in use.
c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless
the vapor collection equipment is in use.
Page 8 of 22
OLORADO
Air Pollution Control Division
ent of ueec Health -E Errtionment
Dedicated to protecting and improving the health and environment of the people of Colorado
d. Operate all recovery and disposal equipment at a back -pressure less than the pressure
relief valve setting of transport vehicles.
32. Point 077: This source is subject to Regulation Number 7, Section XII.H. The operator shall
comply with all applicable requirements of Section XII and, specifically, shall:
• 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. (Reference:
Regulation Number 7, Section XII.H.1.)
33. Point 077: The combustion device controlling the dehydration unit covered by this permit is
subject to Regulation Number 7, Section XVII.B.2 General Provisions (State only enforceable).
If a flare or other combustion device is used to control emissions of volatile organic o pounds
comply with Section XVII, it shall be enclosed; have no visible emissions during normal
operations, as defined"under Regulation Number 7, XVII.A.17; and be designed so that an
observer can, by means of visual observation from the outside of the enclosed flare or
Combustion device, or by other convenient means approved by the Division, determine whether
it, is operating property'. This flare must be equipped with an operational auto ignitor according
to the followinschedulc
All combustion devices installed on nor 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
rational auto -igniter by or before May 1, 201'6, or after the next combustion device
awned shutdown, whichever comes first.
34. Point 077: The glycol dehydration unit covered by this permit is subject to the emission control
requirements in Regulation Number 7, Section XVII.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 XVII.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.
35. Point 077: 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. (Reference: Regulation Number 8,
Part E, Subpart A and HH)
MACT HH Applicable
Requirements
Area Source
Outside UA/UC boundary
Page 9 of 22
COLORADO
Air Pollution Control Division
.parintent ct runic Re:atth h Ervtrt nmen;s
Dedicated to protecting and improving the health and environment of the people of Colorado
§63.760 - Applicability
and designation of
affected source
§63.760 (f) - The owner or operator of an affected major source
shall achieve compliance with the provisions of this subpart by the
dates specified in paragraphs (f)(1) and (f)(2) of this section. The
owner or operator of an affected area source shall achieve
compliance with the provisions of this subpart by the dates
specified in paragraphs (f)(3) through (f)(6) of this section.
563.764 - General
Standar
§63.764 (d)(2) -Each owner or operator of an area source not
located in a UA plus offset and UC boundary (as defined in
§63.761) shall comply with the provisions specified in paragraphs
(d)(2(i) through (iii) of this section.
§63.764 (d)(2)(i) - Determine the optimum glycol circulation rate
using the following equation:
1.15*3.0 gaTEG *F*(I -O)\
lb 11,0 24hr / day
Where:
LOFT =.; Optimal circulation rate, gat/hr.
F = Gas flowrate (MMSCF/D)
I = Inlet water content (lb/MMSCF)
0 =cutlet water conteh lb/MMSCF
3.0 = The industry accepted rule of thumb for a TEG-to water
7
ratio (gal TEG/lbH2O)
1.15 = Adjustment factor included for a margin of safety.
§63 x,64 (d)(2)(ii) - Operate the TEG
dehydration unit such that
the actual glycol circulation rate does not exceed the optimum
glycol circulation rate determined in accordance with ;paragraph
(d)(2)(i) of this section. If the TEG dehydration unit is unable to
meet the sates gas specification for moisture content using the
glycol circulation rate determined in accordance with paragraph
(d)(2)(i), the owner or operator must calculate an alternate
circulation rate using GRI-GLYCalcTM, Version 3.0 or higher. The
owner or operator must document why the TEG dehydration unit
must be operated using the alternate circulation rate and submit
this documentation with the initial notification in accordance
with §63.775(c)(7).
§63.764 (d)(2)(iii) - Maintain a record of the determination
specified in paragraph (d)(2)(ii) in accordance with the
requirements in §63.774(f) and submit the Initial Notification in
accordance with the requirements in §63.775(c)(7). If operating
conditions change and a modification to the optimum glycol
circulation rate is required, the owner or operator shall prepare a
new determination in accordance with paragraph (d)(2)(i) or (ii) of
Page 10 of 22
COLORADO
Air Pollution Control Division
artmenr o€ lies-faatth Er Envtronment
Dedicated to protecting and improving the health and environment of the people of Colorado
this section and submit the information specified under
§63.775(c)(7)(ii) through (v).
§63.774 -
Recordkeepr�ng
Requirements
§63.774 (b) - Except as specified in paragraphs (c), (d), and (f)
of this section, each owner or operator of a facility subject to
this subpart shall maintain the records specified in paragraphs
(b)(1) through (11) of this section §63.774 (b)(1)
§63.774 (b)(1) - The owner or operator of an affected source
subject to the provisions of this subpart shall maintain files of all
information (including all reports and notifications) required by
this subpart. The files shall be retained for at least 5 years
following the date of each occurrence, measurement,
maintenance, corrective action, report or period.
°§63.774 (b)(1)(i) - All, applicable records shall
such a manner that,they can be readily accesse
§63 774 (b)(1)(i1) Tfle most recent 12 months of records shall
be retained on site or shall be accessible from a central' location
byAmputer or other means that provides access within 2 hours
der a reques_
§63.774 (b)(1)(in) The remaining 4 years of records may be
retained offsite.
§63,x`74 (b)(1)(iv) - Records may be maintained in hard copy or
computer -readable form including, but not limited to qn paper,
microfilm,, computer, floppy disk;:` magnetic tape, or microfiche.
§63.774 (f) - The owner or operator of an area source not
located within a UA plus offset and UC boundary must keep a
record of the calculation used to determine the optimum glycol
circulation rate in accordance with §63.764(d)(2)(i) or
§63.764(d)(2)(ii), as applicable
§63.775 (c) - Except as provided in paragraph (c)(8), each owner
or operator of an area source subject to this subpart shall submit
the information listed in paragraph (c)(1) of this section. If the
source is located within a UA plus offset and UC boundary, the
owner or operator shall also submit the information listed in
paragraphs (c)(2) through (6) of this section. If the source is not
located within any UA plus offset and UC boundaries, the owner
§63.775 - Reporting
Requirements
Page 11 of 22
COLORADO
Air Pollution. Control Division
}gar nent or Pubic Health 4 Fnrz¢ronn<.s n
Dedicated to protecting and improving the health and environment of the people of Colorado
or operator shall also submit the information listed within
paragraph (c)(7).
§63.775 (c)(1) - The initial notifications required under
§63.9(b)(2) not later than January 3, 2008. In addition to
submitting your initial notification to the addressees specified
under §63.9(a), you must also submit a copy of the initial
notification to EPA's Office of Air Quality Planning and Standards.
Send your notification via e-mail to CCG-ONG@EPA.GOV or via
U.S. mail or other mail delivery service to U.S. EPA, Sector
Policies and Programs Division/Coatings and Chemicals Group
(E143-01), Attn: Oil and Gas Project Leader, Research Triangle
Park, NC 27711.
§63.775 (c)(7) - The information listed in paragraphs ;(c)(1)(i)
F,n through (v) of this'section. This inf'ormatioshall"be submitted'
with the initial notification.
§63.775 (c)(7)(i) Documentation;of the source's location
relative to the nearest UA plus offset and UC boundaries. This
information shall include the latitude andlongitude (lithe
affected source; whether the source is located in an urban
cluster with 19,000 people or more;`the distance in miles to the
nearest urbanized area boundarythe source is not Located in
an urban cluster with 10,000 people or more; and the names of
the nearest.'urban cluster with 10,000 people or more and
nearest urbanized area.
§63.775 (c)(7)(ii) - Calculation of the optimum glycol Circulation
rate determined in accordance with §63.764(d)(2)(i).
§63.775 (c)(7)(iii) - If applicable, documentation of the
alternate glycol circulation rate calculated using GRI-GLYCalcTM,
Version 3.0 or higher and documentation stating why the TEG
dehydration unit must operate using the alternate glycol
circulation rate.
§63.775 (c)(7)(iv) - The name of the manufacturer and the
model number of the glycol circulation pump(s) in operation.
§63.775 (c)(7)(v) - Statement by a responsible official, with that
official's name, title, and signature, certifying that the facil,ity
will always operate the glycol dehydration unit using the
optimum circulation rate determined in accordance with
§63.764(d)(2)(i) or $63.764(d)(2)(ii), as applicable.
Page 12 of 22
COLORADO
Air Pollution Control Division
I Department of Puel c Health & Emaronree t.
Dedicated to protecting and improving the health and environment of the people of Colorado
§63.775 (f) - Notification of process change. Whenever a process
change is made, or a change in any of the information submitted
in the Notification of Compliance Status Report, the owner or
operator shall submit a report within 180 days after the process
change is made or as a part of the next Periodic Report as
required under paragraph (e) of this section, whichever is sooner.
The report shall include:
§63.775 (f)(1) - A brief description of the process change;
§63.775 (f)(2) - A description of any modification to standard
procedures or quality assurance procedures
§63.775 (f)(3) - Revisions to any of the information reported in
the original Notification of Compliance Status Report under
paragraph (d) of this section; and
wvi
§63.775 (f)(4) - Information required by the Notification of
Compliance Status Report under paragraph (d) of this section for
changes involving the addition of processes or equipment.
OPERATING &t MAINTENANCE REQUIREMENTS
36. on startup offthese points, the owner or operatorrshall follow the most recent operating and
maintenance (O&tM) plan and record " keeping format' approved by the Division, -'?;n order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to
e&tM plan'`are subject to Division approval prior to implementation. (Reference: Regulation
llaer 3 .-Part B, Section
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
37. Point 077: 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. (Reference: Regulation Number 7, Sections XVII.B.2. and XVII.A.17)
38. Point 077: The owner or operator shall complete the initial extended wet gas analysis within
one hundred and eighty days (180) of the latter of commencement of operation or issuance of
this permit. The owner or operator shall use this analysis to calculate actual emissions, as
prescribed in the Emission Limitation and Records section of this permit, to verify initial
compliance with the emission limits. The owner or operator shall submit the analysis and the
emission calculation results to the Division as part of the self -certification process. (Reference:
Regulation Number 3, Part B, Section III.E.)
Page13of22
COLORADO
Air Pollution Control Division.
Department of F tItc Health tt flmbonreent
Dedicated to protecting and improving the health and environment of the people of Colorado
39. Point 077: The owner or operator shall complete the initial extended gas analysis of the fuel
gas used for assist and pilot gas within one hundred and eighty days (180) of the latter of
commencement of operation or issuance of this permit. The owner or operator shall use this
analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records
section of this permit, to verify initial compliance with the emission limits. The owner or
operator shall submit the analysis and the emission calculation results to the Division as part of
the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.)
Periodic Testing Requirements
40. The owner or operator shall demonstrate compliance with opacity standards, using EPA
Reference Method 22, 40 C.F.R. Part 60, Appendix A, on a daily basis 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. (Reference: Operating Permit 95OPWE103 Condition 4.3 and Regulation
Number 7, Sections X1 I B.2. and XVII.A.17)
if opacityls observed,, the owner or operator shall perform EPA Reference` Method 9, 40 C.F.R.
Part 60, Appendix A to measure opacity from the flare for one continuous hour. (Reference:
Regulation Number 1, Section II.A.5.)
)
41. Print 077: Thee owner or operator shall complete an extended wet gas analysisrior to the
inlet of the dehydrate unit on an annual basis. Results of the wet gas analysisjshall be used
to calculate emissions of criteria pollutants and hazardous air, pollutants per this permit and be
provided to the Division upon request.
42. Point 077: The owner or operator shall complete an extended gas analysis on the fuel gas used
as' assist and pilot gas on an annual basis. Results of the extended gas analysis shalt be used to
calculate emissions of criteria pollutants
`and hazardous air pollutants per this permit and be
provided to the Division upon request.
ALTERNATE OPERATING SCENARIOS
43. Point 077: The dehydration unit's electric pumps may be replaced with another electric glycol
pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without
applying for a revision to this permit or obtaining a new construction permit. A replacement
pump shall operate at the same or lower glycol recirculation rate as authorized in this permit.
44. Point 077: The owner or operator shall maintain a log on -site or at a local field office to
contemporaneously record the start and stop dates of any pump replacement, the
manufacturer, model number, serial number and capacity of the replacement pump.
45. Point 077: All pump replacements installed and operated per the alternate operating scenarios
authorized by this permit must comply with all terms and conditions of this construction permit.
ADDITIONAL REQUIREMENTS
46. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation Number 3,
Part A, II.C.)
Page 14 of 22
COLORADO
Air Pollution Control Division
t e ,ar4rnent of P' btc Health 6 En -Aram -hem
Dedicated to protecting and improving the health and environment of the people of Colorado
• Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five
(5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone
nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on the
last APEN submitted; or
r,any non -c. eportable pollutant:
If tl emissionsiincrease y 50% or five (5) tons per year, whichever is less, above the
level:: reported on the last,APEN submitted to the Division.
Whenever ther is a change in the owner or.operator of any facility, process or activity;
or
Whenever new c ntro equipment is instal or whenever a different t of control
equipment replaces an existing type of control equipment; or
Whenever a permit limitation must be modified; or
No latter than 30 days before the existing APEN.expire
47. ' his source is subject to the provisions of Regulation Number 3 Part C, Operating Permits (Title
he 1990 Federal°:Clean Air Act Amendments). TheproViitons of this construction permit
must be incorporated into the Operating Permit. The application for the modification to the
Operating Permit is due within one year of the issuance of this permit.
48. The requirements of Colorado Regulation No. 3, Part D shall apply at such time that any
stationary source or modification becomes a major stationary source or major modification
solely by virtue of a relaxation in any enforceable limitation that was established after August
7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a
restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.8).
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:
Facility
Equipment
ID
AIRS
Point
Equipment
Description
Pollutant
Emissions - tons per year
Threshold
Current
Permit Limit
Page 15 of 22
;COLORADO
Air pollution Control Division
Dedicated to protecting and improving the health and environment of the people of Colorado
P013
063
Stabilized
Condensate
Storage Tanks
P016
066
Stabilized
Condensate
Loadout
D-3
077
TEG
Dehydration
Unit
PW
075
Produced
Water
Storage Tank
'AAMBtu/hr
eboi ler
VOC
40
1.68
0.94
23.95
2.11
The produced water storage tank (AIRS 075) is',a permit exempt source (18WE08 XP) pursuant
to the Colorado egulation No. 3, Part B, Section ll.D.1 m exemption (wastewaters<1,% crude oil).
However,; with the addition` of the new, larger,,dehydration unit, throughput o,this tank is
expecte,to increase Therefore, the PTE of this source is still considered in the project increase
when evaluating NANSR applicability '
The 1 vlMBtu/hr reboiler :associatedE with dehydration unit D-3 is both an APEN and permit
exemptIsource pursuant to Colorado Regulation No. 3, Part A, Section II.D.1 k and Part B, Section
II.D.1 because this source was installed with 1Y-... as a part of this modification, the
PTEsi f this source must considered in thee project ' increase when evaluating NANSR
*ability. '
P Y•
GENERAL TERMS AND CONDITIONS
49. 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.
50. If this permit specifically states that final authorization has been granted, then the remainder
of this condition is not applicable. Otherwise, the issuance of this construction permit does not
provide "final" authority for this activity or operation of this source. Final authorization of the
permit must be secured from the APCD in writing in accordance with the provisions of 25-7-
114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization
cannot be granted until the operation or activity commences and has been verified by the APCD
as conforming in all respects with the conditions of the permit. Once self -certification of all
points has been reviewed and approved by the Division, it will provide written documentation
of such final authorization. Details for obtaining final authorization to operate are located
in the Requirements to Self -Certify for Final Authorization section of this permit.
Page 16 of 22
COLORADO
Air Pollution. Control Division
; tunvnt of ` ub tc Health b C• nvLonrnett
Dedicated to protecting and improving the health and environment of the people of Colorado
51. 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.
52. 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.
53. 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
erm or condition of the permit. If the Division denies a Permit,, conditionseimpose tupon a
permit are,contested by the owner or operator, or the Division revokes a permit, t e owner or
operator of a source may request i hearing before the AQCC tor review of the Division's action.
54. Section 25-7-14.7(2)a), C.R.S requires that all sources required to file an,Air Pollution
Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and
administration.if a source or activity is to be discontinued, the owner must notify the Division
in writing requesting la:cancellation of the permit. ,Upon notification annual fee billing will
terminate.
55. Violation of the terms of a permit or of the provisionsof the. Colorado Air Pollutio'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
enalties -122.1 (criminal pena ties C.R.S.
By:
Elie Schuchardt, P.E.
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to DCP Operating Company, LP for the
construction of a new dehydration unit (D-3) and
to permit increased emissions from the
stabilized condensate storage tanks (P013) and
condensate truck loading (P016).
Page 17 of 22
'COLORADO
Air Pollution. Control Division
ra c t:1,,.71:c HealthEt r. ironnien
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.
(Reference: 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 PartxlI.E.1 of the Common Provisions
Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of;non-criteria reportable airpollutants are estimated based, upon the
process limits as indicated in this permit. This information is listed to inform the operator of the
Division's analysis of the specific compounds emitted if the source(s) operate at the permitted
limitations.
AIRS
Point
063
Pollutant
Benzene
CAS #
71432
Incontrolled
Emissions'
(tb/yr)°
Controlled
Emissions
(lb/yr)',
41
Toluene
108883
3,043
152
Ethylbenzene
100414
203
10
Xylenes
1330207
2,231
112
n -Hexane
110543
6,491
325
066
Benzene
71432
105
5
Toluene
108883
129
6
n -Hexane
110543
734
37
077
Benzene
71432
133,283
7,773
Toluene
108883
199,611
11,751
Ethylbenzene
100414
6,227
369
Xylenes
1330207
45,786
2,725
n -Hexane
110543
26,253
922
Page 18 of 22
?COLORADO
Air Pollution Control Division
Department of rP b c Hean & Fr; inar.l Hutt
Dedicated to protecting and improving the health and environment of the people of Colorado
2,2,4-Trimethylpentane
540841
18
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) Point 063: The emission levels contained in this permit are based on the following emission factors:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
--
VOC
0.332
0.0166
Mass Balance
71432
Benzene
0.004
0.0002
Mass Balance
108883
Toluene
0.015
0.0008
Mass Balance
1330207
Xylene
0.011
0.0006
Mass Balance
11,054 .
n -Hexane ...
0.032 .:
0.00.16
Masi Balance
Note The controlled emissions` factors for this point are based°on a control=,e
0.
6) Point066: The emission levels contained in thispermitare based on the following emission factors:
Pollutant
ncontrolled
ission Factors
lb/bbl
.: Controlled
Emission Factors
lb/bbi
Source
VOC
0.186
0.009
x.0003;
Mass Balance
Mass Balance
n -Hexane
110543
0.006
uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.
verson.1 /95) using the following values:
L = 12.46*S*P*M/T
S = 0.6 (Submerged loading: dedicated normal service)
P (true vapor pressure) = 4.65 psia
M (vapor molecular weight) = 66 lb/lb-mol
T (temperature of liquid loaded) = 520 °R
Equation 1
The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated
by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor.
Controlled emission factors are based on an enclosed combustor efficiency of 95% and a
collection efficiency of 100%.
Page 19 of 22
COLORADO
Air Pollution Control Division
n €n£ ct a In Health ft Err onme=:t
Dedicated to protecting and improving the health and environment of the people of Colorado
7) Point 077: The emission levels contained in this permit are based on information provided in the
application, the emission factors listed below and the GRI GlyCalc 4.0 model.
VOC and HAP Emissions:
Total actual VOC and HAP emissions for the dehydration unit will be the sum total of the emissions
generated by the flash tank, still vent, assist gas and pilot gas. The following summarizes the
calculation methodologies for each source of VOC and HAP emissions:
• Flash Tank VOC and HAP Emissions: Actual controlled VOC and HAP emissions from the
flash tank are based on 100% control efficiency when the emissions are routed to the
VRU, and a 95% control efficiency when the emissions are routed to the enclosed
combustor during periods of VRU downtime. VRU downtime is not to exceed 5% of total
annual dehydration unit operation. To determine actual flash tank emissions, the hourly
flowrate of the "Flash Tank Off Gas" stream obtained from the most recent GlyCalc run
will be multiplied by the total number of hours during which the VRU was not operating
and flash gas emissions were routed to the enclosed' combuustor, to' whichha control
efficiency of 95% will'be,applied.
Still Vent VOC and HAP Emissions: Actual,controlledVOC and HAP emissions from the
still vent are based on a 95% control efficiency when the emissions are routed to the
enclosed, combustor, and, +a 0% control efficiency when the emissions are routed to
atmosphere during enclosed combustor downtime. Enclosed combustor downtime is not
to exceed 1% of total°annual dehydration unit operation."To;deetermine actual still vent
emissions, the hourly�`flowrate of the "Uncontrolled' Regenerator Emissions" stream
obtained from the most recent GlyCalc run will be multiplied by the total number of
hours during which the enclosed combustor was operating and still vent emissions were
routed to it, to which a control efficiency of will be applied. Emissions generated
during enclosed, combustor downtime will be added to this value, and will be determined
by multiplying the hourly -flowrate of the "Uncontrolled Regenerator Emissions" stream
obtained from the most recent GlyCalc run by the number of hours during which the
enclosed combustor was not operating and emissions were routed to atmosphere.
• Assist Gas VOC and HAP Emissions: Actual controlled VOC and HAP emissions from the
combustion of assist gas are based on a 95% control efficiency for the enclosed
combustor. Note that assist gas is only used when the enclosed combustor is operating;
assist gas emissions are not generated during periods of permitted enclosed combustor
downtime. To determine actual assist gas emissions, the assist gas flowrate (based on a
set value of 3,200 scfh) will be multiplied by the VOC and HAP content indicated by the
most recent extended analysis of the fuel gas used as assist gas and the hours of enclosed
combustor operation, to which a control efficiency of 95% will be applied.
• Pilot Gas VOC and HAP Emissions: Refer to the combustion emissions section below.
Combustion Emissions:
Total actual NOx and CO emissions for the dehydration unit will be the sum total Qf the emissions
generated from flash tank, still vent, assist gas and pilot gas combustion. The following tables and
notes set forth the calculation methodologies for each source of combustion emissions:
Page 20 of 22
COLORADO
Air Pollution Control Division
t-Pahl₹c Wealth b Er a onment
Dedicated to protecting and improving the health and environment of the people of Colorado
Still Vent Primary Control (Enclosed Combustor; permitted 1% annual downtime):
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMbtu
Source
NOx
0.068
AP -42 Chapter 13.5 Industrial Flares
CO
0.31
AP -42 Chapter 13.5 Industrial Flares
Note: The combustion emission limits listed in this permit are based on a heating value of 1,549 Btu/scf. Actual emissions
are calculated using the emission factors in the table above, the heat content of the "Condenser Vent Stream" obtained
from the most recent GlyCalc run, the hourly flowrate of the "Regenerator Overheads Stream" obtained from the most
recent GlyCalc run and the hours per month that the still vent was routed to the enclosed combustor. Note that NOx and
CO emissions are not produced during periods of permitted downtime, since still vent emissions are routed to atmosphere
and not combusted.
Flash Tank Secondary Control (Enclosed Combustor; during permitted 5% annual VRU
downtime):
S #
Pollutant
Uncontrolled
: Emission Factors
lb/MMbtu
ource
NOx
„
0.068
k ..
AP -42 Chapter 13.5 Industrial Flares
CO
0.31
AP -42 Chapter 13.5 Industrial Flares
Note The combustion emission limits listed in this permit are based on a heating value of 1,360 Btu/s;„Actual emissions
are calculated using the`emission facto in the table above, the heat content and hourly,flowrate of the "Flash Tank Off
yea �
Gas" obtained from the°most recent GlyCalc run, and the hours per month that the flash tank gas was routed to the
enclosed combustor. Nate that NOx and COemissions are.not produced during periods of VRU operation, Where the flash
gas ts`recycled to inlet and not combusted.
Assist Gas Combustion (Enclosed Combustor)
CA' #
` Pollutant'
Uncontrolled
Emission' Factors
lb/MMbtu
Source
NOx
0.068
AP -42 Chapter 13.5 Industrial Flares
CO
0.31
AP -42 Chapter 13.5 Industrial Flares
Note: The combustion emission limits listed in this permit are based on a heating value of 1,020 Btu/scf. Actual emissions
are calculated using the emission factors in the table above, the heat content of the fuel gas obtained from the most
recent analysis, a constant assist gas flowrate of 3,200 scfh and the hours of enclosed combustor operation.
Pilot Gas Combustion (Enclosed Combustor):
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf
Source
NOx
100
AP -42 Chapter 1.4 External Combustion
CO
84
AP -42 Chapter 1.4 External Combustion
VOC
5.5
AP -42 Chapter 1.4 External Combustion
Note: The combustion emission limits listed in this permit are based on a heating value of 1,020 Btu/scf. Actual emissions
are calculated using the emission factors in the table above, the heat content of the fuel gas obtained from the most
recent analysis, a constant pilot gas flowrate of 50 scfh and the hours of enclosed combustor operation.
8) 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
Page 21 of 22
COLORADO}
Air Pollution Control Division
Porto Health rr Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
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.
9) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated
control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when
applicable.
10) This facility is classified as follows:
Applicable
Requirement
Status
Operating, Permit
Major Source of: NOx, CO, VOC, HAP
PSD
v
NANSR
True Minor Source of: NOx
;'Synthetic,Minor Source of:' VOC, CO
Major Source of: NOx
MACT HH
,Major Source Requirements Not Applicable
AreaSource Requirements: Applicable
11) Full text of the Tltte 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the webste listed below:
http //ecfr.gpoaccess gov/
Part 60 Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart KKKK
NSPS
Part 60, Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
MACT
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
Page 22 of 22
Colorado Air Permitting Project
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer:
Package 6:
Received Date:
Review Start Date:
Elie Schuchardt
386033
5/17/2019
5/22/2019,;, _.
Section 01- Facility Information
Company Name: DCP Operating Company, LP
County AIRS ID: 123
Plant AIRS ID: 0277
Facility Name: Enterprise Compressor Station
Physical
Address/Location:
County:
Type of Facility: NatunatGas Compressor Station
What industry segment?Oil &:"NaturalGas Production & Processing
Is this facility located in a NAAQS non -attainment area? Yes
If yes, for what pollutant? L Carbon Monoxide (CO)
SWSW quadrant of Section 30, Township 3N, Range 63W
Weld County
Section 02 - Emissions. Units In Permit Application
Particulate Matter (PM) E
Quadrant
Section
Township
Range
SWSW
Ozone (NOx & VOC)
3N ...
63
AIRS Point #
Emissions Source Type
Equipment Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
063
Condensate Tank
P013
-- Yes
I9WE0492
CPI
No -:.
Permit '
Modification
Permitted
under
95OPWE103
066
,..
Liquid Loading
P016
..
Yes
19W50492
CP1
No
'._ ...
Permit
Modification
Permitted
under
95OPWE103
077
Dehydrator
0-3
Yes
19WE0492
CP1
yes
Permit initial
Issuance
New defy to
replace D-2
Section 03 - Description of Project
This modification requests the permitting of a new TEG dehydration unit (AIRS 077) rated at 145 MMSCFD to replace TEG dehydration unit D-2 (AIRS 068) rated at 11r
MMSCFD for increased dehydration capacity. Enclosed flare COMB -1 (previously AIRS 074) will no longer be its own point, but will instead be grouped under the new
dehydration unit AIRS ID (077), as requested. This modification also permits additional throughput for Stabilized Condensate Storage Tanks (AIRS 063) and Stabilized
Condensate Loadout (AIRS 066) as a result of the increased dehydration capacity. Note that an increase in V0C emissions from the permit -exempt produced water storage
tanks (AIRS 075,18VUE0877.XP) is also expected with this modification, but as a permit exempt unit, is not addressed in this PA.
A project emissions accounting analysis was received with this modification to demonstrate that this project falls below the significance threshold of 40 tons/year VOC for a
moderate ozone non -attainment area (Colorado Regulation No. 3, Part D, Section ILA.44). Because the combined potential to emit (PTE) of each of the sources permitted
under this modification, the permit exempt produced water tanks and and APEN and permit exempt dehydration unit reboiler cumulatively fall below the40 ton/year
significance threshold for VOC in moderate ozone non -attainment areas, the project emissions accounting analysis was not evaluated in detail. Because emissions
associated with this project when evaluating each unit at PTE are below the significance threshold for VOC (cumulative potential to emit= 28.72 tons/year (including the
permit -exempt produced water tanks)), this modification does not constitute a major modification for the purposes of NANSR. Note that the NOx and CO emission increases
from this project are well below their respective significance levels of 40 tons/year and 100 tonslyear as welt.
Section 04- Public Comment Requirements
Is Public Comment Required?
If yes, why? Req€ estingSynthetic Mina r P
Section 05 - Ambient Air Impact Analysis Requirement
Was a quantitative modeling analysis required? Ifio
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
Is this stationary source a synthetic minor? Yes
If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration IPSO)
Colorado Air Permitting Project
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
LI Li ULU LI U L
L L
Is this stationary source a major source?
If yes, explain what programs and which pollutants herSO2
Prevention of Significant Deterioration (PSD) ❑
Title V Operating Permits (OP) L
Non -Attainment New Source Review (NANSR)
NOx CO VOC PM2.5 PM10 TSP HAPs
❑ ❑ ❑ O O
Li Li L L U L4 L
u L
Condensate Storage Tank(s) Emissions Inventory
063 Condensate Tank
'Facility AIRs ID:
f128$% t
county
Plan
06
Poi
Section 02 - Equipment Description Details
Detailed Emissions Unit Fight (8) 300 bbl Fixed Roof Stabilized Condensate Storage Tanks (P013)
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control
Efficiency 56:
,Endosed Flare (mfg: LEED):
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Condensate Throughput =
IRequested Permit Limit Throughput=
Potential to Emit (PTE) Condensate
Throughput =
Secondary Emissions - Combustion Device(s)
MW of Butane
MW of Pentane
Heat content of Butane
Heat content of Pentane
Heat content of waste gas=
Universal Gas Constant=si'ft3/IbmoCR
Atmospheric Pressure =
MW of Vapors= °RB lb/Ibmol
Temperature=
Vented 474188 scf/yr
Volume of waste gas emitted per BBL of
liquids produced = 2.338 scf/bbl
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
S 1 . 5. Barrels (hall per year
202,8481 Barrels (bbl) per year
Barrels (bbl) per year
58.127b/Ibmol
5 Ib/Ibmol
iii Btu/scf
9 Btu/scf
TBtu/scf
Potential to Emit (PTE) heat content of waste gas routed to combustion device =
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Actual Condensate Throughput While Emissions Controls Operating= 54,165: Barrels (bbl) per year
Requested Monthly Throughput= 17228 Barrels (bbl) per month
430 MMBTU per year
.1,5.7.,1. MMBTU per year
.1,6.1.1. MMBTU per year
Pollutant
Uncontrolled
Controlled
(Ib/bbl)
(Ib/bbl)
(Condensate
Throughput)
0.004
(Condensate
Throughput)
0.0166
0.0002
MIIIM112212M =EMI
MMIERTEMIIM
MIESEEMIIMI11
0.001
0.011
Pollutant
mmzEmm
0.00.1::.;..
0.0001
0,0000
0.0000
Control Device
Uncontrolled Uncontrolled
(lb/MMBtu)
waste heat
combusted)
(lb/bbl)
U3`
(Condensate
Throughput)
0.0001
0.0001
0.0005
0.0025
Emission Factor Source
Emission Factor Source
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
VOC
PM10
PM2.5
NOx
CO
33.07
8.99
8.45
33.67
.1.68
786
0.01
0.00,
0.00
0.01
0.01
0.00
0.00
0.01
0.01
1
0.05
0.01
0.01
0.05
0.05
9
0.25
0.07
0.07
0.25
0.25
42
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
811
217
11
811
41
3043
812
41
3043
152 '
203
54
3
203
10
22:31
546
30
22:3.3,
112
6491
1733
87
6481
325
0
0
0
0
0
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
'Source requires a porntit
3 of 16
K:\PA\2019\19 W E0492. C P 1
Condensate Storage Tank(s) Emissions Inventory
Regulation 7, Section XII.C, D, E, F
Storage Tank is not subject to Regulation 7. Section X€I.C-F; Subject to Section XII.I
Regulation 7, Section XII.G, C
Storage Tank is not subject to Regulation 7, Section XII,0
Regulation 7, Section XVII. B, C.1, C.3 '
Storage tank is subject to Regulation 7, Section XVI€, B, C.1 & CS
Regulation 7, Section XVII.C.2
Storage Tank is subject to Reuglation N. 7, Section XVII.C.2.a
Regulation 6, Part A, NSPS Subpart Kb
Storage Tank is not subject to P157510,
Regulation 6, Part A, NSPS Subpart 0000
Storage Tank is not subject to NSPS 0000
Regulation B, Part E, MACT Subpart H H
Storage Took is not subject to MALT NH
(See regulatory applicabiliy worksheet for detailed analysis)
4 of 16 K,\PA\2019\19WE0492.CP1
Condensate Storage Tank(s) Emissions Inventory
Section 07 - Initial and Periodic Sampling and Testing Requirements
Does the company use the state default emissions factors to estimate emissions?
If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-0
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the
facility being permitted? This sample should be considered representative which generally means site -specific and
collected within one year of the application received date. However, if the facility has not been modified (e.g., no
new wells brought on-line), then It may be appropriate to use an older site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
2N/A- site specific EF used
Section 08 - Technical Analysis Notes
L In operator correspondence received 7/79/2019, it was verified that the correct'condendsate throughput value is 202,840bhl/yr, as listed vs the APEN submitted with the 5/17/2079 applicati
in
I., This modiflaatien servgsonly su increasethe permitted throughput to these tangs. Note that this increase i n throughput should theere} rally only result in an increase in working losses from these
tanks; breathing lasses should remain unchanged. As a conservative approach, the operator elected to ratio the Total working and breathing losses by the throughput to.arrive at the new emissierr
limitations, as opposed to ratioing the working losses only.
3, 591 aI samplingwas not included In this permitter the condensate storage n since -these tanksstore only stabilized condensate. Because this condensate is stabilized down to an RVP seciScation,
it is not expected that the composition of condensate would vary significaMly, sincethis RVP specification is not changing. Note that ail emission factors listed in this permit were obtained from a
site-sper fissamp€e dated 5/26/2011, which was included in a construction permit application received 1/5/2012 (this application was incorporated directly into the 8/1/2012 renewal of opera? rig"-.
permit 9SOPWE103),
4. As a conservative approach, the operator assume
approximation for the stabilized condensate),
ha
00% he hydrocarbon emissions estimated using EPA Tanks 4.0.9d were VOC emissions (notethatRVP 10 gasoline was used as an
5. interpolation between butane and pentane was used to arrive at the heat content of the -super stream from these condensate storage tanks. Since the vapor molecular weightof 66 Ib/lbmol
estimated from EPA Tanks4.0.9d falls between butane (MW = 58.12 Ib/Ibmei) and; pentane._ (MIN =72.15), it was assumed that the heat content of the tank vapors should fall between a heat content
of 3010.8 Stu/soffor butane and 3'6998t5/scf for pentane. Interpolation between these two values was used to arrive at the heat content of the tank vapor stream of39978tu/scfr Note that the heat
contents used for "interpolation are the lower (net) heating values of butane and pentane,: since the AP -47 Chapter 13.5 emission factors are applicable to the lower heatingvalue of the stream
combusted, _ .. _..
6. These condensate storage tanks are not located at pipeline orrailcar injection facility and is therefore not subject to Colorado Regulation No 7, Section Vl.B.2.
ZThe EoterpnseCompressor Station is major source of HAP, for the purposes of Title V. However, because it is classified as a production field facility under MACTHH, only HAP emissions produced
Ytum dehydration dolts and storage Vessels are aggregated for the purposes of major source determination for this rule (563.761 definition -of major source). Total HAP emissions from The dehydration
unit D-3 and condensate storage tanks P013, when taking into account federally enforceable controls,donot produce emissions in excess of the majorsource thresholds. As such, for the purposes of
MAC( HH, the Enterprise Compressor Station is considered to bean area source of HAP emissionssubject only tOTE6 dehydration unit requirements.Syothetic minor HAP limits -were introduced into
the permitter hese toe emission_ points only to ensure major source MACT H H requirements are not triggered during the permit term.
8. The condensate storage tanks are exempted from the requirements of Colorado Regulation No 7, Section XII.0 Fpursuant to Section 11151. Because air pollution control equipment is installed and
operated on these tanks (Section Xlt.t.1),the air polllution control equipment achieves a 95% HOC control efficiency (Section X11.12, note that the SEED combustor is rated to a design destruction
efficiency for hydrocarbons of 88% In accordance with the Section XVII.C.1,4requirement), and OCP does not own or operate any exploratiion and production facilities within the B Hour Ozone Control
area (Section Xt1,1.3),these condensate stofage tanks are exempted from the system -wide controlrequirements of Section Xl4C F. in accordance with Section XII.ifthese storage tanks are instead
subject to Sections Xlf.I.4arid Xll.t3- Note that the engine, fugitive emission and compressor requirements under Section Xil.t.5 are tsi de the scope of this construction permit and were therefore not ".
included in the permit,
3 Because thesestorage tanks exclusively hold stabilized condensate, these tanks are not subject }o the STEM plan requirements of Colorado Regulation No. 7, Section XVII.C.Lb However, these tanks
are subfectM the capture requirementsset forth in Section XVILC2.a. Compliance with these capture requirements will be achieved in accordance with the same schedule as required for those storage
tonics that are regpired to.Hevelap a STEM plan and records shall be kept pursuant to the requirements i Section )0/11,C,S,
50. Method 22 readings to monitor compliance against the no visible emissions reggirements of Colorado Regulation Na 7, Section XVII.82will be condpcc d on a daily basis, pursuant to the .I
f₹equencyset forth in the 8/1/2012 Issuance of the operating permit.
11. For the purposes of SOPS regulations, the definition of modification per 40 CFR'part 60.2 isa any physics₹ change in, or change in the method of operation of, an existing farshty,ohicIs increases the
amount of any air pollutant (to whidt a standard applies) emitted into the atmosphere by that facility or which results in the emission of any air pollutant (to which a standard applies) into the
atmosphere not previously emitted." Note that the operator is requesting to increase condensate. throughput witch increases the VOC emitted Asa result, the storage vessels would be considered
modified per the definition above. Since this source will be modified after the applicability date for NSPS 0000 (September IS, 2015) the source would be potentially subject to NSPS 0000a Based on
the regulatory analysis, it was determined these storage vessels are not subject to NSPS0000a because the potential VOC _emissions per storagevessel are less than 6tpy
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point # Process # SCC Code
063 01 - 5.f,�"-tS.
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 0.00 ' 0 lb/1,000 gallons condensate throughput
PM2.5 .0.00 0 lb/1,000 gallons condensate throughput
NOx 0.01 0 lb/1,000 gallons condensate throughput
VOC 7.9 95 lb/1,000 gallons condensate throughput
CO 0.06 0 lb/1,000 gallons condensate throughput
Benzene 0.10 95 lb/1,000 gallons condensate throughput
Toluene 0.36 95 lb/1,000 gallons condensate throughput
Ethylhenzene 0.02 95 lb/1,000 gallons condensate throughput
Xylene 0.26 95 lb/1,000 gallons condensate throughput
n -Hexane - 0.76 95 lb/1,000 gallonscondensate throughput
224 TMP 0.00 95 Ib/1,000 gallons condensate throughput
5 of 16
K:\PA\2019\19 W E0492.CP1
Condensate Tank Regulatory Analysis Worksheet
Colorado Regulation Parts A and 8 - APEN and Permit Requirements
ounce is in e:,s 4o -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emtsions from any criteria pollutants from this individual source greater than 2 TPY(Regulatian 3, Part A, Section ll.D.I.a)?
2. Is the construction date (service date) priorto 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and114 and Section 2 for additional guidance on grandfather applicability(?
3. Are totalfacllhy uncontrolled VOC emissions greater than TPY, NOx greater than lO TPY or CO emssions greater than lO IVY (Regulation 3, Part B, Section 11.0.3)?
I'cor.h,Lve:nmc'atod thatsou:oe isistiherce-Attainment Ataa
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than l TPY (Regulation 3, Part A, Section ll.Dl.e)?
2. Is the canstmdian date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)?
3. Are total facility uncontrolled VOC emissions greaterthan 2 TPY, NO4greaterthan 5TPY or CO emissions greaterthan lO Try (Regulation 3, Part B, Indian 11.0.2)?
'Sow -cc reaulres a permit
Colorado Regulation 7, Section XILc-F
• 1. Is this storage tank looted in Cie 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area)
2. 'stills storagetank located at an oil and gas exploration and production operation`, natural gas compressor station or natural gas drip station?
3. Is this storage tank located upstream of a natural gas Processing Plant?
Iurn+age tank is cuir( t to Rcgulatirn i, Section Xii,C.F
Section 011.1.1 -General Requirements for Air Pollution Control Equipment- Prevention of Leekags
Section XII.C.2-Emission Estimation Procedures
Section )(11.0- Emissions Control Requirements
section NILE - Monitoring
Section XILF-Recordkeeping and Reporting
Source Is NOT subject to Xll.C-F see PA notes for condensate tank; subjectta XII.I
Colorado Regulation?. Section MI.
1. Is this storage tank lasted in the 8 -hr ozone control area or any axone non -attainment area or attainment/maintenance area)
2. Is this storage tank located at anatural gas processing plant?
3. Does this storage tank eshibtFlash°(e.g. storing nan-stabiliaed liquids) emissions and have uncontrolled actual emissions greaterthan or equal to 2 tons per year %/CC?
o g'Lark .;rattublecttr,Reguiatfen7,Snxi::nX0.ti
Section 011.0.2- Emissions Control Requirements
Section XII.C.1 —General Requirements for Air Pollution Control Equipment —Prevention of Leakagr
Section XII.C2—Emission Estimation Procedures
Colorado Regulation?. Section WI)
1, Is this tank located at a transmission/storage facility?
2. Is the condensatestaragetank' located at an oil and gas exploration and production operation, well production faciliuf, natural gas compressor station' or natural gas processing plant?
3. Is the condensate storage tank a fried roof storage tank?
4. Are uncontrolled actual emissions of this storage tank equal to or greater than S tons per year VOC?
Iat0-aga tares It subject to Neguiaticn 1, Semfon XVii, N. C.L. A C5
Section XVila —General Provisuns for Air Pollution Control Equipment and Prevention of Emission,
Section XMI.C1- Emissions Control and Monitoring Provisions
Section XVII.t.3 - Remrdkeepilg Requirements
Dom the condensate storage tank cancan only "stabllized" liquids?
'Stooge Tanks th,, uisjeet t:: Pygpiatian 7, 9act'inu ( Vd.f.2
section XVII.C2 - Capture and Monitoring for Storage Tanks fined with Air Pollution Control Equipment
Storage tanks are subject to capture requirements inflection XVII.C2.e only; STEM does not apply
40 CFR. Part 60. Suboen rib. Standards of Performance for Volatile Organic Liquid Storage Vessels
1. lithe individual storage vessel apathy greaterthan or equal to 75 cubic meters (ma) (-4T2 Bats)?
2. Does the storage vessel meet the following exemption in 60.111b(d)(4)?
a. Does the vessel has a design capacity less than or equal to 1589.874 ma 1'"10,000 BBL) used for petroleum' or condensate stored, processed, ortreated prior to custody transfe? as defined in 60.1116?
3. Wasthe condensate storage tank constructed, reconstructed, or modd"ed(see definitions 40 CFR, 60.2) afteruuN 23, 1984?
4. Does the tank meet the definition of 'storage vessel. in 60.1116?
5. Does the storage vessel store a"volatile organic liquid (VOL). as defined in 60.1111?
6. Does the storage vessel meet any one of the following additional exemptions:
a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa ("29.7 psij and without emissions to the atmosphere (60.110b(d)(2))?; or
b. The design capacity is greaterthan or equal to ]51 ma (550 BBL] and stores a liquid with a maximum true vapor pressure` less than 35 kPa (60.11ob(b)I?; or c. The design capacity is greaterthan or equal to 75 ref (^471 BBL) but less than 151 m3 ('-950 BBL) and stores a liquid with a maximum true vapor pressure° less than 15.0 kPa(60.110b(b))?
Yes
Na
tae
lye......,,..
Steepgo Tana is rants subinrita MPS Kb
Subpart A, General Provisions
46o.112b - Emissions Control Sttardarat for V0C
§601136 -Testing and Procedures
§60.1156- Reporting and Recordkeeping Requirement
460.116b - Monitoring of Operations
40 CFR, Part SO, Subpart 0000. Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
1. Is this condensate storage vesellocated at a facility In the onshore ail and natural gas production segment, natural gas processing segment or natural gas transmission and Adage segment of the industry?
2. Was the condensate storage vessel constructed, reconstructed, or modified( see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015?
3. Are potential VOC emissionsirow the Individual storage vessel greaterthan or equalto 6. tons peryear?
4. Does this condensate storage vessel meet the definition of"storage vessel's per 60,5430?
5. Is the storage vessel sub)ed to and controlled In accordance with requirements forstorage vessels in d0 CFR Part 6oSubpart Kb or 40 CFR Part 63 Subpart FM?
'Std gel'
0000
Subpart A. General Provisions per 6605425Table 3
450.5395- Emissions Control Standards far VOC
460.5413 -Testing and Procedures
4605395(g) - Nmifiatlan, Reporting and Recordkeeping Requirements
660.5416(c) -Cover and Closed Vent System Mennodng Requirements
460.541? -Control Device Monitoring Requirements
INme: If a storage vessel Is preubusly determined to be subject to NIPS 0000 due to emissions above 6 tons per year VOC on the appllability determination date, It should remain subject to NSPS 0000 per 60.5365(e)(2) even If
potential VOL emissions drop below6 tans per year]
40 CFR, Part 63, Subpart MAR NH, Oil and Gas Production Facilities
1. Is the storage tank located at an oil and natural gas praductionfacility that meets either of the following criteria:
a. Afadlt that processes, upgrades or stores hydrocarbon liquid? (63.?50(a)(2)); OR
b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end use? (63.760(a)(3)l?
2. Is the tank looted at a facility that Is major. for HAP'?
3. Does the tank meet the definitionof"storage vessel• In 63.761?
4. Does the tank meet the definhionof"storage vessel with the potential forflash emissions. per 63.261?
5. Is the tank subject to control requirements under40 CFR Part 50, Subpart lb or Subpart 0000i
'6toraga Tank is notsuclect tc MCI Hy
Subpart A, General prav''eians per 463.764 (a) Table 2
§63.766 -Emissions Contra) ltandards
463.773 -Monitoring
§63274- Recordkeeping -
§63.775 -Reporting
RACE Review
RAC] review Is required If Regulation 7 does not apply AND lithe tank is In the non -attainment area. If the tank meets both criteria, then review RACr requirements.
Wsddirnet
This document assists operators With determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not
a role or regulation, and the analysis d contains may net apply to a particular situation based upon the indtuiduel facts and circumstances. This document does not change or substitute for any law, regulation,
or any other legallybinding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations,
end Air Qualify Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as 'recommend," 'may,' ...should," and 'Wan," is intended to
describe APCD interpretations and recommendations. Mandatory terminology such as "must" and °required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air
Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself.
hone
Iran I
Hydrocarbon Loadout Emissions Inventory
066 Liquid Loading
(Facility AIRS ID:
Coun
Plan
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Is this loadout controlled?
Collection Efficiency:
Control Efficiency:
95.00
Requested Overall VOC & HAP Control Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Hydrocarbon Loadout
Actual Volume Loaded =
Requested Permit Limit Throughput=
Potential to Emit (PTE) Volume Loaded =
v yposi lee:: Barrels (bbl) per year
f VOIN4f1'L,ax$48iBarrels (bbl) per year Requested Monthly Throughput =
Actual Volume Loaded While Emissions Controls Operating =
G
54,16; Barrels (bbl) per year
17228 Barrels (bbl) per month
Secondary Emissions - Combustion Device(s)
MW of Butane
MW of Pentane
Heat content of Butane
Heat content of Pentane
Heat content of waste gas=
Universal Gas Constant=
Atmospheric Pressure =
Volume of waste gas emitted per year =
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
$- d2;u ,Barrels (bbl) per year
58.12`. Ib/Ibmol
72.15 Ib/Ibmol
3010..8'. Btu/scf
3699 Btu/scf
3397 Btu/scf
.0.731psi*ft3/Ibmol'R
2 psia
scf/year
Potential to Emit (PTE) heat content of waste gas routed to combustion device =
Section 04- Emissions Factors & Methodologies
Does the company use the state default emissions factors to estimate emissions?
Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility
being permitted?
Loading Loss Equation
L = 12.46" S'P•M/1
240 MMBTU per year
900 MMBTU per year
900 MMBTU per year
The stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors.
Factor
Meaning
Value
Units
Source
5
Saturation Factor
0.5
{ y
yaI4P�42Lhagtta'5.2T
i 5ubtt6eged €fldt'Ltng: fid
[ate4Ncast a[Secy o(S:0:
,.'"""
P
True Vapor Pressure
4.65-.::.
.,..
psia
M
Molecular Weight of Vapors
66
Ib/Ib-mol
T
Liquid Temperature
.519.67.
Rankine
;Qy
L
Loading Losses
4.4555055?
lb/1000 gallons
0.185433342 lb/bbl
Component
Mass Fraction
Emission Factor
Units
Source
Benzene
0.00270
0.001
lb/bbl
Site Specific Sample
Toluene
0.003
0.001
lb/bbl
Site Specific Sample
Ethylbenzene
-::0.000
0.000
lb/bbl
:Site Specific Sample
Xylene
0.001
0.000
Ib/bbl
Site Specific Sample
n -Hexane
0.020 J 0.004
lb/bbl
Site Specific Sample
224TMP
:.0.000 0.080
lb/bbl
Site Specific Sample
Emission Factors
Pollutant
VOC
Benzene
Toluene
Ethylbenzene
Xylene
Hydrocarbon Loadout
Uncontrolled Controlled
(lb/bbl)
(Volume Loaded)
(lb/bbl)
(Volume
Loaded)
Br4 0.009
00
.0000
n -Hexane 0.0036
224 TMP 5,0000
Pollutant
Control Device
0.0000
0.0
0.0000
Uncontrolled Uncontrolled
(Ib/MMBtu) (lb/bbl)
(waste heat combusted)
(Volume
Loaded)
PM10 0.007
PM2.5
500
NOx 0,0680
CO 0.3100 ,
0.0075 i..
0.0006`
E-
3.02E -
4
3.020: 114
E
Emission Factor Source
Emission Factor Source
7 of 16
K:\PA\2019\19 W E0492.CP1
Hydrocarbon Loadout Emissions Inventory
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
0.00
0.00
0.00
0.00
0.00
1
PM2.5
0.00
0,00
0.00
0.00
0.00
1
SOx
0,101
0,00
11,00
11,00
0,00
II
NOx
0.03
0.01
0.01
0,03
0.03
VOC
10.81
5,02
0.20
18,81
0,94
160
CO
0..14
0,114
0.04
0.14
4,14
24
Potential to Emit
Actual Emissions
Requested Permit Limits
Hazardous Air Pollutants
Uncontrolled
Uncontrolled Controlled
Uncontrolled Controlled
(lbs/year)
(lbs/year) (lbs/year)
(lbs/year) (lbs/year)
Benzene
105
28
1
105
5.
Toluene
120
34
2
129
6
Ethylbenzene
4
T _
0
4
0
Xylene
20
5
0
20
1
n -Hexane
734
196
10
734
3'2
224TMP
0
0
0
0
0
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
bounce requires a permit
RACr- Regulation 3, Part B, Section 111.0.2.a
(See regulatory applicability worksheet for detailed analysis)
The loaduut mast be operated with submerged RIl to satisfy RACr.
Section 07 - Initial and Periodic Sampling and Testing Requirements
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section 09 - Inventory 5CC Coding and Emissions Factors
AIRS Point#
066
Process#
31
5CC Code
4-06-001-22 Crude Oil: Submerged Loading Normal Service (S-0.6)
Uncontrolled
Emissions
Pollutant - Factor Control % Units
PM10 0.00 0 lb/1,000 gallons transferred
PM2.5 0.00 0 lb/1,000 gallons transferred
5Ox 11.00 i) lb/1,000 gallons transferred
NOx 0.01 0 lb/1,000 gallons transferred'
VOC 4.4 95 lb/1,000 gallons transferred
CO 0.33 0 lb/1,000 gallons transferred
Benzene 0;01 45 lh/1,000 gallons transferred
Toluene 0,02 95 lb/1,000 gallons transferred
Ethylhenzene 0.00 95 lb/1,000 gallons transferred
Xylene 0.00 95 lb/1,000 gallons transferred
n -Hexane 0.09 95 lb/1,000 gallons transferred
224TMP 0.00 95 lb/1,000 gallons transferred
8 of 16 lU\PA\2019\19WE0492.CP1
Hydrocarbon Loadout Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
Source is in the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.l.a)i
2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section 11.0.1.1)7
3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis?
4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill?
5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure?
6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)'
(You have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)i
2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section
3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis?
4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill?
5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure?
6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)'
(Source requires a permit
7. RAT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)i
(The loadout must be operated with submerged fill to satisfy RACT.
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act its implementing regulations, and Air Quality Control Commission regulations. This document is
not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its
implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,""may,""should,"
and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as must" and "required" are intended to describe controlling requirements under the terms of
the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself.
Glycol Dehydrator Emissions Inventory
077 Dehydrator
Facility Alto ID:
0}72.... 077.:.
County Plant Paint
Section 02 -Equipment Description Details
Dehydrator Information
Dehydrator Type:
Make:
Model:
Serial Number.
Design Capacity:
Recirculation Pump Irdormation
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recrculation Rate:
Dehydrator Equipment
Flash Tank
Reboiler Burner
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
MMsd/day
gallons/minute
, flash tank,
and reboller burner
One (I)Triethyiene glycolfTEG) natural gas dehydration unit (Make: TOD, Modo:TBD, Serial Nonber.'BD)with a desiin capacity of_4SMMecf per day. This
cuipped with 2 t1 primary,1 backup) (Make: FMC, Med.: Stip@x) electric driuen giycol pumps with a deign cspacity of 20 gallons per "lint.. 'Chi
ctehyd aeon unit Is equipped with a null vent, HasSPank. end mboaor home:..
Emission
s from thestll vent are routed to a.4endensar, end then to the fnclotoA Gate. 3niesiens from the flash monk are reisfod directly to the Vapor Recovery Unit
;WW1. Ate encondery control devoe. fresh toot nnni sel.,rn ere ratted to the Enclosed Flare.
Section 03-Proeessing Rate Information for Emissions Estimates
Primary Emissions Dehydrator Still Vent and Flash Tank (If pent
'Requested Fermi Limit Throughput = ° A2923p :i MMscf per year Requested Monthly Throughput= 5455 MMscf per month
Potential to Emit (FM) Throughput= 52,525 MMsct per year Actual Throughput= 0 MMscf neryeen
Secondary Emissions -Combustion Device(s)for Alr Pollution Control
. Still Vent Control
Condenser.
Condenser emission reduction claimed:
Primary control deulce,
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:
Assist Gas
Assist Gas Routing:
Assist Gas Operation:
Assist Gas Heating Value
Assist Gas Rate:
Pilot Gas
Pilot GasRoudng:
Pilot Gas Operation:
Pilot Gas Heating Value
Pilot Gas Vent Rate:
Section 04 -Emissions Factors & Methodologies
,°,1'07n„,
nod from the
mungui0.§i Control Efficiency %
hr/vr Requested TO TemPo,,.°. �e
._. _ t., Control fVlnhennt%
Btu/srt
iids7:isdh
<: :8]60 I,rlVr
ii 0073 Btu/sd
iii 3203 0Th
26.032 MMsd/yr
0760 hr/yr
2020. Btu/set
scfh
0.438 MMsd/yr
0.0572 MMscf/month
Control Efficiency %
Control Efficiency %
Input Parameters
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
STILL VENT
Pollutant
VOC
Benzene
Toluene
Ethylbenzene
Bylenes
n -Hexane
224-TMP
Uncontrolled llb/hrl
..:::81.6559
Control Scenario
Primary
Controlled (lb/hr)
4,t 07n5
0.755495
1.11.1
0.07512
0.253:'OS
0.0TT335
0.(530`03
Secondary
Controlled llb/hrl
&1.0553
4.7899
22.3302
0.7014
5.1&37
1.5661
0.0:111
34.7699
23382
0.2024
i0 251837
' 1,5061
I'IDlOin
FLASH TANK
Pollutant
VOC
Benzene
Toluene
Ethylhenzene
Xylenes
n-Hesane
224-TMP
Control Scenario
Primary
Secondary
Uncontrolled llb/hrl
tka57,O743' y;.'R;
ESAMOIROM
Controlled (lb/hr)
Controlled lib/hrl
0
0
2.853755
0.022205
0.022423
0.03'0042
0,00215
0.06344.5
3982537
Dry Gas Thmuehout
Still Vent Primary Control 52.325.0 MMsct/yr
Still Vent Secondary Control: 529.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 0.6 MMscf/ter
Still Vent Secondary Control: 0.0 MMscf/yr
Dry Gas Throughout
Flash Tank Primary Control: 50,270.0 MMsd/yr
Flash Tanknecondary Control: 2,546.3 MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 0.0 MMscf/Yr
Flash Tank Secondary Control: 0.5 MMsd/yr
4,435.^ MMscf/month
0.0 MMscf/month
Glycol Dehydrator Emissions Inventory
Throughput (0)
MW
20.052
10.303
MMscf/yr
Ibdh-nwl
3200
scf/hr
MMscf/d
0,0708
Mol %
MW
MW Gas
Wt%
tonnelize far H(
VOC Wt%
lia/hr
lis/yr
tpy
Helium
0.01
4
0.00
000
—
—
—
—
—
0O2
1.18
43.99
0.52
2.83
-
-
-
-
-
N2
0.38
28.02
0,11
0.58
-
-
-
-
-
methane
86,85876
16.01
13.91
75.71
78.38
-
-
-
-
ethane
9.5372
30.02
2,86
15.59
16.14
-
-
-
-
propane
1.5989
4403
0.70
3.83
3.97
3,97
6.15
57035,0:
23.52
isobulane
0.1041
58.04
0.06
0.33
0,36
0.34
0,53
4020,50
2.01
n -butane
- 0,2321
58.04
0.13
0,73
0.76
0.76
1.100
10201,00
6.10
isopentane
0.0395
72.05
0.03
0,15
0.16
0.16
0,25
2120.33
149
n -pentane
0,038
72.05
0,03
0.15
0.15
0.15
0.24
2001.52
1.05
cydopemane
0
—
—
—
—
—
—
—
—
n -Hexane
0.0214
86.18
0,02
0.10
0.10
0.10
0,15
1410.35
0,71
63406 one
0
—
—
—
—
—
—
—
—
Other hexanes
0
86.06
0.00
0,00
0.00
0.00
4.00
0,00
0,05
heptane
0
—
—
—
—
—
— -
—
—
methylcyclohexane
0
—
—
—
—
—
—
—
—
224-TMP
0
—
—
—
—
—
—
—
Benzene
0
78.12
0.00
0.00
0.00
0,00
0,0:0
0,00
9,00
Toluene
0
92.1
0.00
0.00
0,00
0.00
5,00
0.00
0,00
Elhyiberizene
0
106.1
0.00
0.00
0,00
0,00
0,00
0,00
0,00
Xylene6 i
0
106.1
0.00
0.00
0.00
0.00
0,00
0,00
8,00
coe Heavies
0
—
—
—
—
—
—
—
—
VOC mass fraction:
Still Vent P
Control Device
Uncontrolled Uncontrolled
Pollutant
P
PM2,5
504
NO4
CO
Pollutant
(Ih/MMBtu)
Illa/MMscf)
Still Vent Secondary Control Device
Uncontrolled Uncontrolled
(Ih/MMBtul (Ib/MMscf)
(Waste Heat
Combusted)
(Waste Gas
Combusted)
10,363
Emission Factor Source
Emission Factor Source
PM10
PM2,5
50
NO4
CO
:00
0000
Emission Factor Source
Pollutant
Flash Tank Primary Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu(
(Waste Heat
Combusted)
(Ih/(40Mscf)
(Waste Gas
Combusted(
PMI0
PM2.5
500
NO4
CO
lash Tank Secondary Control Device
Pollutant
Uncontrolled Uncontrolled
(Ib/MMBtul (Ib/M
(Waste Heat
Combusted)
(Waste Gas
Combusted(
Emission Factor Source
Pilaf Ge
Pollutant
Uncontrolled E.F. Uncontrolled EC.
(Ibs/MMBtu waste (lbs/MMscf waste gas
heat combusted( volume combusted)
Emissions Factor Source Citation
PM10
NO
Vac
SC0 02 ``UVk
n Hexane L,kit ,
Mel
Gas
,0061
Pollutant
PM10
PM3,5
SO
N00
VOC
Section OS - Emissions Inventory
Old operator request a buffer?'
Requested Buffer (°b):
Benzene
Toluene
Ethylbe
len
n -Hexane
224TMP
Emission Factor Source
Uncontrolled Uncontrolled
(Ih/MMBtul (Ih/MMscf(
{Waste Heat
Combusted)
(ILL/MM
10
20
(Waste Gas
Combusted)
(Ib/MMscf)
S2
5.400
Total VOC (Unoontro0 37,22
I vent emissions routed to atmosphere - nocombostion
Flash Tank Primary Control Device 6 330 - no combustion
YOVIPM ICBM
I Potential to Emit
Criteria Pollutants Uncontrolled
Actual Emissions Requested Permit Limits equested Monthly Limits
Uncontrolled Controlled Uncontrolled Controlled Controlled
Glycol Dehydrator Emissions Inventory
(cons/year)
(sons/year) (tons/year)
(tons/year) (tons/year)
(lbs/monthl
PBL10
PM2.5
004
Noe
Co
VOC
005
0.1))
1.00
0.05
0.85
0.00
0,00
045
11,05
.
0.50
0.08
0.80
_. :
8.511
05
2.27
0.20
0.00
2.27
2.37
005
007,80
0.00
0.00
007,04
2„x:838
37.81
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Pe ink Limits
Uncontrolled Controlled
lbs/year) (lbs/year)
Benzene
Toluene
Ethylbemene
Xylene
a -Hexane
224 TMP
133203
8)82
2AU
133003
1720
130011
0.005
^00
' 188511
17'851
0227
0.00
0,08
027-.7
0tH
35720
0:x
2.00
08701
2725
24840
0.00
0.70
01432
851
., <,.
m.�;c%rr�- 334233424313
Criteria Pollutants
Paten tialto Ems
Actual Emissions
Requested Pe mil Limits
Requested Monthly Limits
Uncontrolled
Uncontrolled
Controlled
Uncontrolled
Controlled
Controlled
(tons/year)
(tons/veer)
(tons/year)
(tors/veer)
(sons/year)
(lbs/month)
PM10
PM2.5
50x
NO5
CO
VOC
0.11
0.00
0.00
0.10
±:,1.0
10
0,11
0.00
0.00
0.11
11.11
Y0
0:01
0.00
000
0.01
0,01
8.07
0.00
0.00
0.87
037
165
0..93
0.00
0,00
4.43
Aka
753
32,22 _
0,00
1 00
37,.22.
1.3E
014
Hazardous Air Pollutants
Potential to Emit.
Actual Emissions
Requested Permit Limits
_ Uncontrolled
Uncontrolled Controlled
Uncontrolled , Controlled
(lbs/year)
(lbs/year) (lbs/year)
(Ibs/Year) , (Ibs/year)
Benzene
Toluene
Etiylbenaene
Xylem
a -Hexane
224 TMP
0:s?
0.10 - 0,10
048 0.00
000
0.10 ::,20
0,06 8.00
17.89
0.80 0.00
0.00 0.00
0.07
0.00 0,00
000 0.00
1410.53
8.08 000
141033 70.92
...
0,14 0.00
.. ...
Criteria Pollutants
Potential to Ems
Uncontrolled
(tans/year)
Actual Emissions
Uncontrolled Controlled
(toes/year) (tons/year)
Requested Pe mit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(Ibs/month)
PM10
10012
4.00017
0.001?
04017
0.0.017
0
PM2.5
0.001;
0,0017
0,0017
0.0017
037017
0
502
0.0021
0.0021
0,0081
0.0001
0.8001
NOx
0.0219
71.0210
0.0210
0,021?.
0.0113
4
CO
0.0024
0.0104
0,0304
00104
0,0104
3
000 _ _
0.0050
7.8800
il.0012
0.0010
0EOO12
0.2
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/yearl (lbs/year)
Requested Pe mit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
n -Hexane
1 1. 0
0
((so(((m((�rra(.. " ,,, ,'I
. d::.° W> u// , :334 ,,0T ( 3 (7.:...i.\� 2333333,33 , - -: :
Criteria Pollutants
Potential to Emit
Actual Emissions
Requested Perms Limits
Requested Monthly Limits
Uncontrolled
Uncontrolled
Controlled'
Uncontrolled
Controlled
Controlled
(tons/year)
(tons/year)
(tons/year)
(tons/year)
(tons/year)
(Ibs/month)
PMSO
PMZ.5
505
NO0
CO
VOC
7.70
0.00
0.00
810
0.14
07.54
010
8,00
0.28
0._0
0.10
2'1,04
0.01
0.00
000
0.01
101
2,00
1.10
0.02
0.00
0.4e
1.40
05336
5.70
0.02
0.02
5.72
0.72
1141.17
580.£70
0.08
0.00
604.06
23.45.
4067.50
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(0s/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (Ibs/yearl
Requested Pe mit Limos
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
303385
073
O.S
183203
'1223
1000::1
0.0)
0.
19051.',
S:f761
4227
0.20
COO
5227
350
40103
0.03
0.33
-
?5100
8175
247x33
0.19
O.Ot5
26250
521.
' 10
0.00
Section 06 - Reeul atory Summary Analysis
Regulation 3, Parts 4,B
Regulation 7, Section XVII.B4O
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 0, Part E, MACr Sub paste30 (Area)
Regulation 8, Part y, MALT 5ubpart0H (Major)
Regulation 8, Part E, MACE SubparfllHH
(See regulatory applicability worksheet for detailed analysis)
Source regoffee permit
0elnterater 70 325(£:: to Regulation 7, 52010010x'11, 0, 0.3
The control desitt for :his dei0A-atar is not subtou i to Reosdstion 7, 60121011 X00.0.2.0
Dehydrator is suajac-to Regulation'?, Seetio,=. 80.ti
Oehy .suleet 5t, 30euurr4 MEET HN, per the (33,3o,ne,xa t,Rl64lnrool
You haw (ndicatad Mat OWfacility is fell suf jece to t a or Source rveuirements of MGCT HH,
You have indicated that this facility is not subject to MACY 11110.
action 07 - Initialand Periodic Sampling and Testing Requirements
Was the etoended wet gas sample used in the 0108410 model/Process model site-spectfic and collected within a year of application
If no, the permit will contain an"Initial Compllance" testing requirement to demonstrate compliance with emission limits
If the company has requested control device efficiency greaterthen 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve MI No I
If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer
Is the company using a thermal oxdizerAND requesting amnimum combustion chambertemperature lower than 1,400 degrees Ft kiie,.�"_
It yes, the permit will contain an "Initial Compliance(' testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer.
Analvs,
YEersj'udF,h,.
4
doubt ms. emall{ioi
rig '21/ 3oos/year( 7N'e
q £Ge 1 d(fare. f3 g e£the p" i tt k g lit far y yep)'a
a Is mode Incalrulatd ncaism114VDC end HAP emnsmn dunnga0%ser
rogtlett P t tab Imo d I" lEota 00100 0 :fits
ns'Ptillecte0 110100 0loded a he wnr aa,100 ti -,,,,
xe
d Ifth stree
ga am"propeYles:resuhlnry
"X.eterled the use of the ce
PR a
d yredd
h drfF nu raacebet s
P�'d#arperhn gpamas
(I
/140 4400)41
and wuheut tens.
setts in sbghtlti
me, A8n1egwhlchstlli'yentem'
glohle,)S
Glycol Dehydrator Emissions Inventory
Lore ertendedgas nneNs
@= app,Bva 6 receipttha, t}te
o
In den
rrf=leda
dniware3',u
h h trovdess IoM&tp lyy rtF dund AhS074'h gnedi Fhed hyd t 9uAIR5Yfi-(k(N567'J,j It 1 '
h Same AP toe PY9YiffIgSC£L Se h,?n def vd tfag - IId fn cta a9.,ems l6a dEh g59 iGfitd��ard'$OW
peY M1W telliacakheugh h pit gas dassrstg p doff {gas ih m ceswe dd edsgjj rateh9
HbU�jlq��sswkeaeddyNlaemfs�fdA factcr5iPAP-q"14hayterl4re, exteA+i an6uskfoRs d(gs.Assisi sar; mk snort arni 5,inns<jn ca
vllefrotfi E i2r'¢riSe:
aaz an Nstasamnleinf EYxain
ytp i ,ice nPHAP forthe purp�sesvfirtlr
edFv she pmpasas'bf ajar source de€ rretivnfo
@(r(grceabiatpntr.is do notPEodv<e mwsk+M jn.
dratdration n ent5-Suns
thi I (46'a 6
-ess vfYhe ma}e
e[k finer HAPI
Dehydrator Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
Source is in the Non -Attainment Area
ATTAINMENT •
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)?
You have indicated that sourceis in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY (Regulation 3, Part A, Section 11.111.a)?
2., Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2)?
(Source requires a Permit
Colorado Regulation 7, Section XII.H
1. Is this glycol natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Reg 7, Section XII.H.1 and 2)?
2. Is this glycol natural gas dehydrator located at an oil and gas exploration and productionoperation, natural gas compressor station, natural gas drip stationor gas -processing plant (Reg 7 Section
3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy (Reg 7, Section XII.H.3.b)?
4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section XII.H.3.a)?
Dehydrator is subject to. Regulation 1, Section Xli.H
Section XII.H — Emission Reductions from glycol natural gas dehydrators
MACT Analysis
1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria:
a. A facility,that processes, upgrades or stores hydrocarbon liquids (63.760(a((2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final
b. end user' (63.76D(a)(3)(?
2. Is the dehydrator located at a facility that is a major source for HAPs?
(Go to MACT NH Area Source Requirement section to determine MACT NH applicability
Yes
Yes
40 CFR. Part 63. Subpart MACE HH. Oil and Gas Production Facilities
Area Source Requirements
1. Is the dehydrator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))?
Exemptions
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.764(e)(1)(i)?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.764(e)(1)(ii)?
3. Is the unit located inside of a UA plus offset and UC boundary area?
'Dehy Is subject to area source MACT Hit per the requirements in 63.764(d((2(
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards Do Not Apply
§63.773 - Monitoring Standards Do Not Apply
§63.774- Recordkeeping
§63.775 - Reporting
Malor Source Requirements
1. Does the facility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility -wide actual annual average hydrocarbon liquid throughput less than
Small or Large Dehv Determination
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.761)?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.761)?
Small Dehv Requirements
3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(I)(B) and (C )?
4. For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation?
'You have Indicated that this facility is not subject to Major Source requirements of MACT NH.
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards
§63.773 - Monitoring
§63.774 - Recordkeeping
§63.775 - Reporting
40 CFR, Part 63, Subpart MACT HHH, Natural Gas Transmission and Storage Facilities
1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source (63.1270(f))?
Small or Large Dehv Determination
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day (63.1270)b))2)(?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere -less than 1,984.2 lb/yr (63.1270)b)(2))?
Small Dehv Requirements
3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(2) and (3) )?
4. For this small dehy, Is a control device required to meet the BTEX emission limit (standard?) given by the applicable equation?
Yes
You have Indicated that this facility is not subject to MACT HHH.
Subpart A, General provisions per §63.1274 (a) Table 2
§63.1275 - Emissions Control Standards
§63.1281 -Control Equipment Standards
§63.1283 - Inspection and Monitoring
§63.1284 - Record keeping
§63.1285 - Reporting
Colorado Regulation 7, Section XVII.D
1. Is the dehydrator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)?
2. Is this dehydrator located at a transmission/storage facility?
3. Is this dehydrator located at an oil and gas exploration and production operation, natural gas compressor station or gas processing plant (Reg 7, Section XVII.D.3)?
4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)?
If constructed prior to May 1, 2015, are uncontrolled actual emissionsfrom a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 tpy VOC if the
4a. dehydrator Is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)?
5. If constructed on or after May 1, 2015, are uncontrolled actual emissionsfrom a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC (Regulation 7, Section XVII.D.4.a)?
(Dehydrator is subject to Regulation 7, Section XVII, B, D.3
Section XVII.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.D.3 - Emissions Reduction Provisions
Alternative Emissions Control (Optional Section)
6. Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that Is not enclosed?
No
No
The control device for this dehydrator is not subject to Regulation 7, Section XVII,S,2.e
Section XVII.B.2.e —Alternative emissions control equipment
Disclaimer
I his document assists operators withdetermining applicability of certain requirements of the clean Air Act, its implementing regulations, and Air duality Gontrol
Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts
and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the
event of any conflict between the language of this document and the language of the Clean Air Act, its implementing regulations, and Air Quality Control
Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," may," "should," and "can,"
is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must"and "required" are intended to describe controlling
requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in
and of itself.
RECEIVED
Condensate Storage Tank(s) APEN
Form APCD-205
MAY 7 zoos
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is
filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require
payment for a new filing fee.
This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your
emission source does not fall into this category, there may be a more specific APEN available for your source (e.g.
crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General
APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all
available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD)
website at: www.colorado.Rov/pacific/cdphe/air-permits.
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:
lgWE04a2
AP
Stationary
Bargees
AIRS ID Number: 123 / 0277 / 063
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Namei: DCP Operating Company, LP
Site Name: Enterprise Compressor Station
Site Location: SWSW Section 30, T3N, R63W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 2500
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 4922
Contact Person: Roshini Shankaran
Phone Number: 303-605-2039
E -Mail Address2: rshankaran@dcpmidstream.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
3966
Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 3/2019
WjCOLORADO
A
1 Oe}vl b En l'u.
K�altfibEnalronmMl
Permit Number:
AIRS ID Number: 123 /0277/063
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
O NEW permit OR newly -reported emission source
❑ Request coverage under traditional construction permit
O Request coverage under a General Permit
❑ GP01 O GP08
If General Permit coverage is requested, the General Permit registration fee of $312.50 must be
submitted along with the APEN filing fee.
-OR-
❑/ MODIFICATION to existing permit (check each box below that applies)
O Change in equipment O Change company name3
O Change permit limit O Transfer of ownership4 O Other (describe below)
OR -
▪ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info & Notes: Increase throughput, no change in emission factors
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: stabilized condensate tanks
Company equipment Identification No. (optional): P013
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day /
O Exploration & Production (E&P) site
days/week
52
weeks/year
0 Midstream or Downstream (non E&P) site
Will this equipment be operated in any NAAQS nonattainment area?
O
Yes
■
No
Are Flash Emissions anticipated from these storage tanks?
■
Yes
19
No
Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day?
■
Yes
El
No
If "yes", identify the stock tank gas -to -oil ratio:
m3/liter
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
•
■
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
•
•
Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 3/2019
COLORADO
2 I dr
xxnttb a [nnromnmI
Permit Number:
AIRS ID Number: 123 /0277/063
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Storage Tank(s) Information
Actual Annual Amount
(bbl /year)
Requested Annual Permit Limits
(bbl/year)
Condensate Throughput:
54,165
202,848
2018
IFreirm what year is the Gaunt amid t3
Average API gravity of sales oil: 65.4 degrees
❑ Internal floating roof
Tank design: ❑✓ Fixed roof
RVP of sales oil: 10
❑ External floating roof
Storage
Tank ID
# of Liquid Manifold Storage
Vessels in Storage Tank
Total Volume of
Storage Tank
(bbl)
Installation Date of Most
Recent Storage Vessel in
Storage Tank (month/year)
Date of First
Production
(month/year)
P013
8
2,400
1993
1993
Wells Serviced by this Storage Tank or Tank Battery° (MP Sites On
y)
API Number
Name of Well
Newly Reported Well
■
-
■
■
_
■
■
5 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 The EFrP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.191 / -104A877
Operator Stack
ID No.
Discharge Height Above
Ground Level (feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
P013
15
Indicate the direction of the stack outlet: (check one)
❑� Upward ❑ Downward
❑ Horizontal
❑ Other (describe):
❑ Upward with obstructing raincap
Indicate the stack opening and size: (check one)
❑✓ Circular Interior stack diameter (inches):
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 3/2019 3 I
COLORADO
ucp.ucun:ot Rubin
HSaunkcnn,Gnf,tflt
Permit Number:
AIRS ID Number: 123 /0277/063
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Control Device Information
0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Vapor
O Recovery
Unit (VRU):
Pollutants Controlled:
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented): %
❑ Combustion
Device:
Pollutants Controlled: VOC, HAPs
Rating: NA MMBtu/hr
Type: Enclosed Combustor Make/Model: LEE D
Requested Control Efficiency: 95
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: NA
Waste Gas Heat Content:
Constant Pilot Light: ✓❑ Yes 0 No Pilot Burner Rating:
NA
NA
Btu/scf
MMBtu/hr
❑ Closed Loop System
Description of the closed loop system:
O Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
%
Section 7 - Gas/Liquids Separation Technology Information (E&tP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig
Describe the separation process between the well and the storage tanks:
Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 3/2019
4 I
iCOIORADO
Permit Number:
AIRS ID Number: 123 /0277/063
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
Overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested Control
Efficiency
(% reduction in emissions)
VOC
Enclosed Combustor
95%
NOx
CO
HAPs
Enclosed Combustor
95%
Other:
From vw iast year i_s tilte frallloa'4tsg r ti rued Gaud o.um& emissions
2018
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor7
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissionss
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
VOC
0.332
1b/bbl
Tanks 4.0.9d
8.99
0.45
33.67
1.68
NOx
CO
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor7
Actual Annual Emissions,.
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions8
(pounds/year)
Benzene
71432
4.00E-03
Ib/bbl
Eng. Est.
217
11
Toluene
108883
1.50E-02
lb/bbl
Eng. Est.
812
41
Ethylbenzene
100414
1.00E-03
lb/bbl
Eng. Est.
54
3
Xylene
1330207
1.10E-02
lb/bbl
Eng. Est.
596
30
n -Hexane
110543
3.20E-02
lb/bbl
Eng. Est.
1,733
87
2,2,4-
Trimethylpentane
540841
5 Requested values wilt become permit limitations. Requested limit(s) should consider future growth.
7 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site
specific emissions factors according to the guidance in PS Memo 14-03.
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 3/2019 5 I
COLORADO
ihf rtmane n[th:Mk
vemthsn,nrmnx ETV/1;5=W'
Permit Number:
AIRS ID Number: 123 /0277/063
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that
this source is and will be operated in full compliance with each condition of the applicable General Permit.
Signature of Legally Authorized Person (not a vendor or consultant)
Marie Cameron
yin
Dat
Senior Environmental Engineer
Name (print) Title
Check the appropriate box to request a copy of the:
O Draft permit prior to issuance
❑r Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 and the General Permit
registration fee of $312.50, if applicable, to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.$ov/cdphe/apcd
Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 3/2019
Ayl:2:777. 7.
NeatIDb ETVI�OnM&4
RECEIVED
MAY 1 7 2019
APC
Stionery
Hydrocarbon Liquid Loading APEN
Form APCD-208
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is
filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require
payment for a new filing fee.
This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category,
there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit,
condensate storage'tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN
options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution
Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
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: 1A w E 0 +q 2.
AIRS ID Number: 123 / 0277 / 066
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name1: DCP Operating Company, LP
Site Name: Enterprise Compressor Station
Site Location: SWSW Section 30, T3N, R63W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 2500
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 4922
Contact Person: Roshini Shankaran
Phone Number: 303-605-2039
E -Mail Address2: rshankaran@dcpmidstream.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019
399627
1I
COLORADO
x•allhsF.11V11MtlW1,
Permit Number:
AIRS ID Number: 123 / 0277 / 066
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action'
❑ NEW permit OR newly -reported emission source
O Request coverage under construction permit
❑ Request coverage under General Permit GP07
If General Permit coverage is requested, the General Permit registration fee of $312.50 must be
submitted along with the APEN filing fee.
-OR-
❑✓ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment O Change company name3
✓❑ Change permit limit ❑ Transfer of ownership4 O 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: Increase throughput, no change in emission factor
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: Loadout of stabilized condensate to trucks
Company equipment Identification No. (optional): P016
For existing sources, operation began on:
1993
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
Yes
No
p
I
Is this equipment located at a stationary source that is considered a Major Source of (HAP)BI
emissions?
Yes
No
•
Does this source load gasoline into transport vehicles?
Yes
No
■
A
Is this source located at an oil and gas exploration and production site?
Yes
No
•
p
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual
average?
Yes
No
•
■
Does this source splash fill less than 6750 bbl of condensate per year?
Yes
No
■
■
Does this source submerge fill less than 16308 bbl of condensate per year?
Yes
No
■
■
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019
ICOLORADO
2 I I-...hbEZP"1*Y.*
Permit Number:
AIRS ID Number: 123 / 0277 / 066
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
Product Loaded: ❑✓ Condensate O Crude Oil O Other:
If this APEN is being filed for vapors displaced from cargo carrier, complete the following:
Requested Volume Loaded5:
202,848
bbl/year
This product is loaded from tanks at this facility into:
(e.g. "rail tank cars" or "tank trucks")
Actual Volume Loaded:
tank trucks
54,165
bbl/year
If site specific emission factor is used to calculate emissions, complete the following:
Saturation Factor:
0.6
Average temperature of
bulk liquid loading:
58.16
, F
True Vapor Pressure:
4.65
Psia ® 60 °F
Molecular weight of
displaced vapors:
66.00
lb/lb-mot
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume Loaded5:
bbl/year
Actual Volume Loaded:
bbl/year
Product Density:
lb/ft3
Load Line Volume:
ft3/truckload
Vapor Recovery Line Volume:
ft3/truckload
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 3 I
COLORADO
Dean °IPuti t
HNMbEnU1MXn1RY.1
Permit Number:
AIRS ID Number: 123 / 02771066
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.191 / -104.4877
Operator.-
Stack ID No.
Discharge Height Above
Ground'Level
(feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ftlsec)
P016
Indicate the direction of the stack outlet: (check one)
o Upward
❑ Horizontal
O Downward
O Other (describe):
Indicate the stack opening and size: (check one)
o Circular Interior stack diameter (inches):
o Other (describe):
O Upward with obstructing raincap
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.
O Loading occurs using a vapor balance system:
Requested Control Efficiency:
▪ Device:
Combustion
Used for control of: VOC, HAPs
Rating: NA
Type:
Enclosed Combustor
MMBtu/hr
Make/Model: LEED
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: NA °F Waste Gas Heat Content: NA Btu/scf
Constant Pilot Light: 0 Yes O No Pilot Burner Rating: NA MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 4
COLORADO
flcp_rtm.° :ro4ns i°
tCCat�]i5 Ei��li+6l�hitrtl
Permit Number:
AIRS ID Number: 123 / 0277 / 066
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
erall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SO.
NO),
CO
VOC
Enclosed Combustor
95%
HAPs
Enclosed Combustor
95%
Other:
o Using State Emission Factors (Required for GP07) VOC Benzene n -Hexane
❑ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL
❑ Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL
Freon what year its the allegaiing
emissions.
2018
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
tons/ eartons/
(tons/year) )
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
ear
! Y )
Controlled
Emissions
tons/ year
(tons/year)
)
PM
SOx
NO.
CO
VOC
0.186
lb/bbl
AP -42
5.03
0.25
18.83
0.94
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service(CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions°
(pounds/year)
Benzene
71432
5.16E-04
lb/bbl
Eng. Est.
28
1
Toluene
108883
6.34E-04
lb/bbl
Eng. Est.
34
2
Ethylbenzene
100414
1.78E-05
lb/bbl
Eng. Est.
1
0
Xylene
1330207
9.62E-05
lb/bbl
Eng. Est.
5
0
n -Hexane
110543
3.62E-03
lb/bbl
Eng. Est.
196
10
2,2,4-
Trimethylpentane
540841
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019
5I
COLORADO
ngur,�,poi tIU+
H:annsenmrnnmrmi
Permit Number:
AIRS ID Number: 123 / 0277 / 066
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source
is and will be operated in full compliance with each condition of General Permit GP07.
Signature of Legally Authorized Person (not a vendor or consultant)
Marie Cameron
s/i&/tai
Date
Senior Environmental Engineer
Name (print) Title
Check the appropriate box to request a copy of the:
E✓ Draft permit prior to issuance
❑✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 and the General Permit
registration fee of $312.50, if applicable, to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019
61
IcoioRAuo
i! NOWISE=
Glycol Dehydration Unit APEN
Form APCD-202
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
RECEIVED
MAY 1 7 2019
APCD
Stationary
Sources
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 at: www.colorado.gov/cdohe/aocd.
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:
101weo*12
AIRS ID Number: 123 / 0277 / 611
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': DCP Operating Company, LP
Site Name: Enterprise Compressor Station
Site Location: SWSW Section 30, T3N, R63W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 2500
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 4922
Contact Person: Roshini Shankaran
Phone Number: 303-605-2039
E -Mail Address2: rshankaran@dcpmidstream.com
' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
399625
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019 1 I
COLORADO
w+m.atnw—amu
Permit Number:
AIRS ID Number: 123/.277/
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 2 - Requested Action
O 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 0 Transfer of ownership4 0 Other (describe below)
OR
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
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: TEG Dehydration unit for water removal
Company equipment Identification No. (optional): D-3
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
TBD
Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Will this equipment be operated in any NAAQS
nonattainment area?
Is this unit located at a stationary source that is considered
a Major Source of (HAP) Emissions?
hours/day days/week
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019
0
O
Yes
Yes
weeks/year
No
No
COLORADO
Oepaueavrel h1m
2 � H�atiTSEnYitMYUN
Permit Number: AIRS ID Number:
123/0277/
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer: TBD
Dehydrator Serial Number:
TBD
Model Number: TBD
Reboiler Rating: 1.5 MMBTU/hr
Glycol Used: O Ethylene Glycol (EG) O DiEthylene Glycol (DEG) ❑✓ TriEthylene Glycol (TEG)
Glycol Pump Drive: ❑✓ Electric O Gas If Gas, injection pump ratio:
Pump Make and Model: FMC Triplex
Glycol Recirculation rate (gal/min):
Lean Glycol Water Content:
Max: 25.0
1.0 Wt.%
Requested: 25.0
Acfm/gpm
# of pumps: 2
(1P+1 B)
Dehydrator Gas Throughput:
Design Capacity: 145 MMSCF/day
Requested5: 52,925 MMSCF/year Actual: -- MMSCF/year
Inlet Gas: Pressure: 1 ,100 psig Temperature: 115 °F
Water Content: Wet Gas: lb/MMSCF ❑� Saturated Dry gas: 5.0 lb/MMSCF
Flash Tank: Pressure: 50 psig Temperature: 140 °F ❑ NA
Cold Separator: Pressure: psig Temperature: °F 0 NA
Stripping Gas: (check one)
0 None O Flash Gas ❑ Dry Gas O Nitrogen
Flow Rate:
scfm
Additional Required Information:
❑✓ Attach a Process Flow Diagram
❑✓ Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results)
✓❑ Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019
COLORADO
ii Exg..�
3 I d wu�
Kaalgtb Ehen0 fa
Permit Number:
AIRS ID Number: 123 /o2n f
[Leave blank unless APCD has already assigned a permit fi and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.191 / -104.4877
Operator
Stack ID No.
Discharge Height
Above Ground Level
(feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
ECD-1
25.0
Indicate the direction of the stack outlet: (check one)
0 Upward
O Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
0 Circular
❑ Square/rectangle
❑ Other (describe):
ECDesai,
"91V iltS Val
O Upward with obstructing raincap
Interior stack diameter (inches): 36.0
Interior stack width (inches):
Interior stack depth (inches):
&whoa a for sal Tent
Ito awn- , llneire hltaring
crcm't ou to V
lr'
tall
has ai 1.tB ii auroral
ICD ad r�i tujnrnj
Mimic liar morintionamar
eu
repahis
Section 6 - Control Device Information
O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
O Condenser:
Used for control of:
Type:
Maximum Temp:
Make/Model:
°F Average Temp:
Requested Control Efficiency:
°F
0 VRU:
Used for control of: Flash Tank vent stream
Size: NA Make/Model: TBD
Requested Control Efficiency: 100 %
VRU Downtime or Bypassed: 5 %
❑ Combustion
Device:
Used for control of: Still Vent stream
Rating: NA MMBtu/hr
Type: Enclosed Combustor Make/Model: LEED / L30-0018-00
Requested Control Efficiency: 95
Manufacturer Guaranteed Control Efficiency: 98
%
Minimum Temperature: NA °F Waste Gas Heat Content: 1,500 Btu/scf
Constant Pilot Light: 0 Yes El No Pilot Burner Rating: 0.11 MMBtu/hr
Closed
O Loop
System:
Used for control of:
Description:
System Downtime:
0/0
O Other:
Used for control of: Flash Tank during 5% annual VRU downtime
Description: Enclosed Combustor
Requested Control Efficiency: 95 %
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019
algrIcotoRADo
4 l Haan gtZlent
Permit Number:
AIRS ID Number:
123/0277/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction ):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOX
NOx
CO
VOC
Vapor Recovery Unit / Enclosed Combustor
100% / 95%
HAPs
Vapor Recovery Unit / Enclosed Combustor
100% / 95%
Other:
From what yew is the fa llll mg oe urted ortuat errorernissims
NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
SOX
NOx
0.068
Ib/MMBtu
AP -42
—
—
.•1 L
-1.52' 4c1
CO
0.31
lb/MMBtu
AP -42
-
-
16.711):47,
€.74432.
VOC
22.96
lb/MMscf
GLYCaIc
--
--
22.00
607.61
*HAP Emissions represent P
r
to
?11
tall to Emit ff•,
r this prop
(04y.
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
2.52
Ib/MMscf
GLYCaIc
133,283
7,773
Toluene
108883
3.77
Ib/MMscf
GLYCaIc
199,612
11,751
Ethylbenzene
100414
0.12
Ib/MMscf
GLYCaIc
6,227
369
Xylene
1330207
0.87
lb/MMscf
GLYCaIc
45,786
2,725
n -Hexane
110543
0.47
Ib/MMscf
GLYCaIc
21,812
=85.1' q21,
2,2,4-540841
Trimethylpentane
0.0003
lb/MMscf
GLYCaIc
74
17 C $
1
Other:
67561 (Methanol)
0.003
Ib/MMscf
Eng. Est.
159
5
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 /annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
51
iccioRaoro
e�p ,tma,,otwnm
x..attn»snm,t* 't1 i
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019
Permit Number:
AIRS ID Number: 123/°277/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
5/t1Q/t t
Signature of Legally Authorized Person (not a vendor or consultant) Date
Marie Cameron
Senior Environmental Engineer
Name (print) Title
Check the appropriate box to request a copy of the:
�✓ Draft permit prior to issuance
✓0 Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 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
Or visit the APCD website at:
httos://www.colorado.gov/cdohe/apcd
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 3/2019
6I
COLORADO
xeauh & EnbtronmMl
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