HomeMy WebLinkAbout20200679.tiffCOLORADO
Department of Public
Health Et Environment
Weld County - Clerk to the Board
1150O St
PO Box 758
Greeley, CO 80632
February 4, 2020
Dear Sir or Madam:
RECEIVED
FEB 18 7020
WELD COUNTY
COMMISSIONERS
On February 5, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for
DCP Operating Company, LP - Lucerne I Natural Gas Processing Plant. 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.
pu b l : c Rev ,ec1
03/04/a0
Colorado Dept. of Public Health Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Public Notice Coordinator
4300 Cherry Creek Drive S., Denver, Co 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
Jared Polls, Governor I Jill Hunsaker Ryan, MPH, Executive Director
CC: PI.C1P), NL(Lx), pv.gsM/ctt/cH/cW),
O6(3M)
oz/7/a
2020-0679
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: DCP Operating Company, LP - Lucerne I Natural Gas Processing Plant - Weld County
Notice Period Begins: February 5, 2020
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: DCP Operating Company, LP
Facility: Lucerne I Natural Gas Processing Plant
Natural gas processing plant
31495 Weld County Road 43, Lucerne, CO
Weld County
The proposed project or activity is as follows: DCP is requesting to permit an existing plant flare to account
for routine maintenance and purge gas emissions.
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 19WE0732 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:
Carissa Money
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
Department of Public
Health 5 Environment!
COLORADO
Air Pollution Control Division
Depart', rent of Pubtkc Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Permit number:
Date issued:
Issued to:
CONSTRUCTION PERMIT
19WE0732 Issuance: 1
DCP Operating Company, LP
Facility Name:
Plant AIRS ID:
Physical Location:
County:
Description:
Lucerne 1 Natural Gas Processing Plant
123/0107
31495 Weld County Road 43, Lucerne, CO
Weld County
Natural Gas Processing Plant
Equipment or activity subject to this permit:
Equipment
ID
AIRS
Point
Equipment Description '
Emissions Control
Description
F-2
060
Routine maintenance activities, purging of
gas and malfunctions. Activities are
controlled by an elevated open process
flare. Purge gas prevents low flashback
problems to the flare and keeps the flame
stable. The purge gas and pilot gas used is
residue gas. The purge gas helps the flare
maintain a minimum required positive flow
through the system. The pilot gas keeps
the burner flame lit. Flare is also used as
back-up control device.
Open flare (John
Zink, Model FTIP
Indair KMI I -12-H2,,
Serial No. 9047896)
with 95% destruction
efficiency.
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 this
specific general terms and conditions included in this document and the following specific terms and
conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of
the latter of commencement of operation or issuance of this permit, 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.
Page 1 of 15
COLORADO
Air Pollution Control Division
Department at PuH c Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit must be
demonstrated to the Division. It is the owner or operator's responsibility to self -certify
compliance with the conditions. Failure to demonstrate compliance within 180 days may result
in revocation of the permit. A self certification form and guidance on how to self -certify
compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-
permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.)
3. This permit must expire if the owner or operator of the source for which this permit was issued:
(i) does not commence construction/modification or operation of this source within 18 months
after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit; (ii) discontinues construction for a period of eighteen months or
more; (iii) does not complete construction within a reasonable time of the estimated
completion date. The Division may grant extensions of the deadline. (Regulation Number 3,
Part, B, Section III .F.4.)
4. Within one hundred and eighty days (180) after issuance of this permit, the operator must
install a low flow (thermal mass flow meter) meter(s) to monitor and record volumetric flow
rate of gas routed to the flare covered by this permit. The low flow (thermal mass flow meter)
meter must be capable of accurately measuring and recording the minimum purge gas flow
rate. Until the low flow (thermal mass flow meter) meter(s) is installed, the operator must
monitor and record the gas flow using the existing high flow (ultrasonic flow meter), meter. For
any periods when the flare is operational but the actual metered volume is below the detection
level of the high flow (ultrasonic flow meter) meter or the high flow (ultrasonic flow meter)
meter is displaying zero, the operator must assume a gas flow rate of 2,375 scfh. The operator
must assume a gas flow rate of 2,375 scfh for all times when the flare is operational but the
high flow (ultrasonic flow meter) meter is not functioning or collecting data.
5. The operator must complete all initial compliance testing and sampling as required in this
permit and submit the results to. the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
6. The operator must retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
7. Emissions of air pollutants must not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
)
Annual Limits:
Equipment
ID
AIRS
Point
Process
Tons per Year
Emission
Type
NOx
S02
VOC
CO
PM2.5
F-2
060
01
1.3
--
20.1
5.9
Point
02
0.1
--
--
0.1
--
Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits.
Page 2 of 15
COLORADO
Air Pollution Control Division
Department of Publsc Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
For Point 060, the following process designations apply:
• (01) Combustion of purge gas and gas routed to flare due to routine maintenance activities;
• (02) Combustion of pilot light gas.
Facility -wide emissions of each individual hazardous air pollutant must not exceed 8.0 tons per
year.
Facility -wide emissions of total hazardous air pollutants must not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants must apply to all permitted
emission units at this facility.
Compliance with the annual limits, for both criteria and hazardous air pollutants, must be
determined on a rolling twelve (12) month total. By the end of each month a new twelve month
total is calculated based on the previous twelve months' data. The permit holder must calculate
actual emissions each month and keep a compliance record on site or at a local field office with
site responsibility for Division review.
8. For Process 01, the owner or operator shall calculate uncontrolled V0C and HAP emissions on a
monthly basis using the most recent measured gas composition and most recent monthly
measured flow volume of gas routed to the flare. The measured gas composition shall be
representative of all gases routed to the flare, including routine maintenance gases when
applicable. A control efficiency of 95% for VOC and HAPs, based on operating the flare in
compliance with requirements specified in this permit, shall be applied to the uncontrolled
VOC and HAP emissions. Compliance for Process 01 shall be based on the sum of VOC and HAP
emissions from all inlets to the flare.
9. For Process 02, 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.
10. The emission points in the table below must be operated and maintained with the emissions
control equipment as listed in order to reduce emissions to less than or equal to the limits
established in th's permit. (Regulation Number 3, Part B, Section III.E.)
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
F-2
060
Open Flare
VOC and HAP
PROCESS LIMITATIONS AND RECORDS
11. This source must be limited to the following maximum processing rates as listed below. Monthly
records of the actual processing rates must be maintained by the owner or operator and made
available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.)
Process Limits
Equipment
ID
AIRS
Point
Process
Process Parameter
Annual Limit
Page 3 of 15
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
F-2
060*
01
Combustion of purge gas
and gas routed to flare
during routine maintenance
and blowdown activities
26.06 MMscf/yr
02
Combustion of pilot fuel
1.31 MMscf/yr
*Note: The open flare covered under point 060 will handle gas (inlet, propane and residue) routed to the flare during
standard operational process/normal operation of equipment (i.e. purge gas, maintenance activities, and blowdown
activities). In addition, gas will be routed to this flare during any events that qualify as a malfunction per Colorado
Common Provisions Regulation Section II.E and II.J. The process limit does not include gas routed to the flare during
malfunction events or startup and shutdown events per the Colorado Common Provisions Regulation Section II.E and
II.J.
For Point 060, the following process designations apply:
• (01) Combustion of purge gas and gas routed to flare due to routine maintenance activities;
• (02) Combustion of pilot light gas.
Compliance with the annual process limits must be determined on a `rolling twelve (12)'month
total. By the end of each month a new twelve-month total is calculated based on the previous
twelve months' data. The permit holder must calculate throughput each month and keep a
compliance record on site or at a local field office with site responsibility, for Division review.
12. For Process 01, upon installation of the low flow (thermal mass flow meter) meter(s), the owner
or operator shall continuously (i.e., at least once every 15 minutes) monitor and record the
volumetric flow rate of gas routed to the flare, including, but not limited to, process gas, gas
from routine maintenance and purge gas, using high flow (ultrasonic flow meter) and low flow
(thermal mass flow meter) meters. The flow meters must be capable of accurately measuring
and recording the maximum and minimum potential flow rates routed to the flare. The operator
shall assume a gas flow rate of 2,375 scfh for all times when ' the flare is operational but the
flow' meter is not functioning or collecting data. The owner or operator shall use monthly
throughput records to demonstrate compliance with the process limits contained in this permit
for Process 01 and to calculate emissions as described in this permit.
13. The owner or operator shalt install, calibrate, operate and maintain each ultrasonic (high flow
meter) flow meter according to the manufacturer's procedures and specifications and the
following requirements:
a. Locate the flow sensor in a position that provides a representative measurement of the
total gas flow rate and install per manufacturer's recommendation.
b. Use a flow sensor meeting an accuracy requirement of ±20 percent of the flow rate at
velocities ranging from 0.1 to 1 feet per second and an accuracy of ±5 percent of the
flow rate for velocities greater than 1 feet per second.
c. Use a flow meter system that is maintainable online, is able to continuously correct for
temperature and pressure and is able to record flow in standard conditions (Standard
conditions means a temperature of 293 K (68 °F) and a pressure of 101.3 kilopascals
(29.92 in Hg)) over one -minute averages.
d. At least quarterly, perform a visual inspection of the meter for physical and operational
integrity. At least quarterly, conduct diagnostic tests consistent with the manufacturer's
Page 4 of 15
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
procedures and specifications for the meter. Replace the flow sensors based on the
results of visual inspections and diagnostic tests as needed.
e. The flow meter shall be calibrated during the next planned plant shutdown, not to
exceed five years from permit issuance. The flow meter shall be calibrated in
accordance with the manufacturer's procedures and specifications.
f. Calibrate the flow meter in accordance with the manufacturer's procedures and
specifications at least every five years or more frequently if specified by the
manufacturer.
14. The owner or operator shall install, calibrate, operate and maintain each thermal mass (low
flow meter) flow meter according to the manufacturer's procedures and specifications and the
following requirements:
a.
Locate the flow sensor in a position that provides a representative measurement of the
total gas flow rate and install per manufacturer's recommendation.
b. Usea flow sensor meeting an accuracy requirement of ±20 percent of the: flow rate at
velocities ranging from 0.1 to 1 feet per second and a.n accuracy of ±5 percent of the
flow rate for velocities greater than 1 `,feet per second.
Use a flow meter system that is maintainable online, is able to continuously correct for
temperature and pressure and is able to record flow in standard conditions (Standard
conditions means a temperature of 293 K (68 °F) and a pressure of 101.3 kilopascals
(29.92 in Hg)) over one -minute averages.
At least quarterly, perform a visual inspection of the meter for physical and operational
integrity. At least quarterly, conduct diagnostic tests consistent with the manufacturer's
procedures and specifications for the meter. Replace the flow sensors based on the
results of visual inspections and diagnostic tests as needed.
nitially calibrate the flow. meter within 180 days of permit issuance in accordance with
the manufacturer's procedures and specifications.
f. Calibrate the flow meter in accordance with the manufacturer's procedures and
specifications at least biennially (every two years) or more frequently if specified by the
manufacturer.
STATE AND FEDERAL REGULATORY REQUIREMENTS
15. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001)
must be marked on the subject equipment for ease of identification. (Regulation Number 3,
Part B, Section III.E.) (State only enforceable)
16. No owner or operator of a smokeless flare or other flare for the combustion of waste gases must
allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%
opacity for a period or periods aggregating more than six minutes in any sixty consecutive
minutes. (Regulation Number 1, Section II.A.5.)
17. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
Page 5 of 15
COLORADO
Air Pollution Control Division
Department of Publtc Health Er Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
18. The flare shall be air -assisted and designed and operated in accordance with the New Source
Performance Standards requirements of Subpart A Section §60.18, General Control Device and
Work Practice Requirements, including, but not limited to, the following:
• §60.18(b) Flares. Paragraphs (c) through (f) apply to flares.
• §60.18(c)(1) Flares shall be designed for and operated with no visible emissions as
determined by the methods specified in paragraph (f), except for periods not to exceed_
a total of 5 minutes during any 2 consecutive hours.
• §60.18(c)(2) Flares shall be operated with a flame present at all times, as determined
by the methods specified in paragraph (f).
• $60. 18(c)(3) An owner/operator has the choice of adhering to either the heat content
specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity
specifications in paragraph (c)(4) of this section, or adhering to the requirements in
paragraph (c)(3)(l) of this section.
) §60.18(c)(3)(i)(A) Flares shall be used that have a diameter of 3 inches or greater,
are nonassisted, have a hydrogen content of 8.0 percent (by volume), or greater,
and are designed for and operated with an exit velocity less than 37.2 m/sec (122
ft/sec) and less than. the velocity, Vmax, as determined by the following equation:
Vmaic= (XHz-K1) ,K2
Where:
Vmax = Maximum permitted velocity, m/sec.
Kt' = Constant, 6.0 volume -percent hydrogen.
K2 = Constant, 3.9(m/sec)/volume-percent hydrogen.
XH2 = The volume -percent of hydrogen, on a wet basis, as calculated by
using the American Society for Testing and Materials (ASTM) Method
D1946-77. (Incorporated by reference as specified in §60.17).
(2) §60.18(c)(3)(i)(B) The actual exit velocity of a flare shall be determined by the
method specified in paragraph (f)(4) of this section.
(3) §60.18(c)(3)(ii) Flares shall be used only with the net heating value of the gas being
combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam -assisted
or air -assisted; or with the net heating value of the gas being combusted being 7.45
MJ/scm (200 Btu/scf) or greater if the flare is nonassisted. The net heating value
of the gas being combusted shall be determined by the methods specified in
paragraph (f)(3) of this section.
• §60.18(c)(5) Air -assisted flares shall be designed and operated with an exit velocity less
than the velocity, Vmax, as determined by the method specified in paragraph (f)(6).
• §60.18(c)(6) Flares used to comply with this section shall be steam -assisted, air -
assisted, or nonassisted.
• §60.18(d) Owners or operators of flares used to comply with the provisions of this
subpart shall monitor these control devices to ensure that they are operated and
Page 6 of 15
COLORADO
Air Pollution Control. Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
maintained in conformance with their designs. Applicable subparts will provide
provisions stating how owners or operators of flares shall monitor these control devices.
• §60.18(e) Flares used to comply with provisions of this subpart shall be operated at all
times when emissions may be vented to them.
• §60.18(f)(1) Method 22 of appendix A to this part shall be used to determine the
compliance of flares with the visible emission provisions of this subpart. The observation
period is 2 hours and shall be used according to Method 22.
• §60.18(f)(2) The presence of a flare pilot flame shall be monitored using a thermocouple
or any other equivalent device to detect the presence of a flame.
• §60.18(f)(3) The net heating value of the gas being combusted in a flare shall be
calculated using the following equation:
Where:
= Net heating value of the sample, MJ/scm; where the net enthalpy per mote of
offgas is based on combustion at 25 °C and 760 mm Hg, but the standard temperature
for determining the volume corresponding to one mole is 20 °C;
K Constant, 7 1 g•1e ft)
1. x: 10 A Ipp i' sent l :Ca1l.
t i re t h
e standard temperature for etale} is 2
sem
C = Concentration of sample component i in ppm on a wet basis, as measured for
organics by Reference Method 18 and measured for hydrogen and carbon monoxide
by ASTM D1946-77 or 90 (Reapproved 1994) (Incorporated by reference as specified
in §60.17); and
Hi = Net heat of combustion of sample component i, kcal/g mole at 25 °C and 760
mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or
D4809-95 (incorporated by reference as specified in §60.17) if published values are
not available or cannot be calculated.
• §60.18(f)(4) The actual exit velocity of a flare shall be determined by dividing the
volumetric flowrate (in units of standard temperature and pressure), as determined by
Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross
sectional area of the flare tip.
• §60.18(f)(5) The maximum permitted velocity, Vmax, for flares complying with
paragraph (c)(4)(iii) shall be determined by the following equation.
Log10 (Vmax)=(HT+28.8)/31.7
Vmax = Maximum permitted velocity, M/sec
28. 8=Constant
31.7=Constant
Page 7 of 15
COLORADO
Air Poilution Control Division
Department of Public Health & environment
Dedicated to protecting and improving the health and environment of the people of Colorado
HT = The net heating value as determined in paragraph (f)(3).
• $60.18(f)(6) The maximum permitted velocity, Vmax, for air -assisted flares shall be
determined by the following equation.
Vmax = 8.706+0.7084 (HT)
Vmax = Maximum permitted velocity, m/sec
8.706=Constant
0.7084=Constant
HT = The net heating value as determined in paragraph (f)(3).
19. This source is located in an ozone non -attainment or attainment -maintenance area and subject
to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3,
Part B, III.D.2.b. The following requirements were determined to be RACT for this source.
Facility
Equipment
ID
AIRS'.
Point'
Pollutant
F-2
060
VOC
Installing and operating the flare according to
40 CFR 60.18
OPERATING 8 MAINTENANCE REQUIREMENTS
20. Upon startup of these points, the owner or operator must follow the most recent operating and
maintenance (O&tM) plan and''. record keeping format;, approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to
'the O&M plan are subject to Division approval prior to. implementation. (Regulation Number 3,
Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
21. For Process 01, the owner or operator shall complete an initial extended gas analysis of the gas
routed to the plant flare within one hundred and eighty days (180) of the issuance of this
permit. The sample shall be representative of all gases routed to the flare, including routine
maintenance gases when applicable. The sample shall be analyzed for heat content and stream
composition including VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-
trimethylpentane, H2S, and methanol content using EPA approved methods. 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.
Periodic Testing Requirements
22. For Process 01, the owner or operator shall complete an extended gas analysis of the gas routed
to the plant flare on a weekly basis. The sample shall be representative of all gases routed to
the flare, including routine maintenance gases when applicable. Each sample shall be analyzed
Page 8 of 15
COLORADO
Air Pollution Control. Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
for heat content and stream composition including VOC, Benzene, Toluene, Ethylbenzene,
Xylene, n -Hexane, 2,2,4-trimethylpentane, H2S, and methanol content using EPA approved
methods. The weekly heat content and stream composition results shall be averaged on a
monthly basis to calculate emission as specified in this permit.
ADDITIONAL REQUIREMENTS
23. The owner or operator shall maintain the following records for a period of 5 years:
a. Operating hours for the flare.
b. Volume of gas routed to flare.
c. Gas sampling.
d. Flow meter accuracy.
e. Records of flow meter visual inspection and any adjustments made.
f. Initial and recatibration results for the flow meter and any adjustments made.
All records required by this permit shall be retained for not less than 5 years following
the date of such measurements, maintenance, and reports.
24. A revised Air Pollutant Emission Notice (APEN) must be filed: (Regulation Number 3, Part A,
II.C.)
Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 10O 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,t per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on
the last APEN submitted; or
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or
activity; or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
Page 9 of 15
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
25. This source is subject to the provisions of Regulation Number 3, Part C, Operating Permits (Title
V of the 1990 Federal Clean Air Act Amendments). The provisions 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.
26. Federal regulatory program requirements (i.e. PSD, NANSR) must apply to this source at any
such time that this source becomes major solely by virtue of a relaxation in any permit
condition. Any relaxation that increases the potential to emit above the applicable Federal
program threshold will require a full review of the source as though construction had not yet
commenced on the source. The source must not exceed the Federal program threshold until a
permit is granted. (Regulation Number 3, Parts C and D).
GENERAL TERMS AND CONDITIONS
27. 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.
28. 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.
29. 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.
30. 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.
31. Each and every condition of this permit is a material part hereof and is not severable. Any
challenge to or appeal of a condition hereof must constitute a rejection of the entire permit
and upon such occurrence, this permit must be deemed denied ab initio. This permit may be
revoked at any time prior to self -certification and final authorization by the Air Pollution
Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and
regulations of the Air Quality Control Commission (AQCC), including failure to meet any express
term or condition of the permit. If the Division denies a permit, conditions imposed upon a
permit are contested by the owner or operator, or the Division revokes a permit, the owner or
operator of a source may request a hearing before the AQCC for review of the Division's action.
Page 10 of 15
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
32. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution
Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and
administration. If a source or activity is to be discontinued, the owner must notify the Division
in writing requesting a cancellation of the permit. Upon notification, annual fee billing will
terminate.
33. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention
and Control Act or the regulations of the AQCC may result in administrative, civil or criminal
enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil
penalties), -122.1 (criminal penalties), C.R.S.
By:
Carissa Money
Permit Engineer
Permit Histo
Issuance
Date
Description
Issuance 1
This Issuance
Issued to DCP Operating Company, LP for
existing plant flare at Lucerne 1
Page 11 of 15
COLORADO
Air Pollution Control Division
bepamnent of Public Health & Ernrironment
Dedicated to protecting and improving the health and environment of the people of Colorado
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder must pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit.
(Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator must notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written
notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions
Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the
process limits as indicated in this permit. This information is listed to inform the operator of the
Division's analysis of the specific compounds emitted if the sources operates at the permitted
limitations.
Equipment
ID
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(lb/yr)
F-2
060
Benzene
71432
675
34
Toluene
108883
765
38
Ethylbenzene
100414
31
2
Xylenes
1330207
218
11
n -Hexane
110543
3,806
193
Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per
year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice.
5) The emission levels contained in this permit are based on the following emission factors:
Point 060
Emissions associated with the open flare result from the combustion of maintenance gas (inlet
and residue), purge gas (residue), and pilot light gas. Total actual emissions are based on the
sum of the emissions calculated for the combustion of maintenance gas and purge gas (process
01) and the combustion of pilot light gas (process 02). This open flare will handle gas (inlet and
residue) routed to the flare during standard operational process/normal operation of equipment
(i.e. maintenance and blowdown activities). The process limit does not include gas routed to
the flare during malfunction events or startup and shutdown events per the Colorado Common
Provisions Regulation Section II.E and II.J.
Page 12 of 15
HAP
COLORADO
Air Pollution Control. Division
Department of Pubtrc Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Process 01 Combustion of purge gas and gas routed to flare due to routine maintenance and
blowdown activities
Combustion emissions are calculated using the following emission factors, the most recent monthly
flare gas heat content, and volume of total gas combusted.
CAS
Pollutant
Uncontrolled
Emission Factors
lb/MMBtu
Uncontrolled EF
Source
NOx
0.068
AP -42, Table 13.5-1
CO
0.31
AP -42, Table 13.5-2
Actual VOC and HAP emissions shall be calculated based on most recent gas sampling of gases
routed to flare and most recent monthly gas flow volume. Controlled emissions are based on 95%
control for VOC and HAP. Actual VOC and HAP emissions are calculated using the following
equations:
Equation for Actual VOC Emissions Calculations:
lb l
onthl
scf
= VOC concentration (wt %) =100 x Purge/Process Gas (month)
lb x Gas Molecular Weight ' (lbmol) ,. 379 (lSc!i) x (1 — 95% control)
*VOC concentration and Gas Molecular Weight are based on actual monthly -average sampled values of the
gas streams routed to flare.
*Purge/Process Gas is the actual measured monthly flow volume of the gas routed to flare.
Equation for Actual HAP Emissions Calculations:
(Ib
month)
scf
= HAP concentration (wt %) _ 100 x Purge/Process Gas (month)
x Gas Molecular Weight (Ibmol) : 379 scf x (1 — 95% control)
lb \
(lb
*HAP concentration and Gas Molecular Weight are based on actual monthly -average sampled values of the
gas streams routed to flare.
*Purge/Process Gas is the actual measured monthly flow volume of the gas routed to flare.
Process 02 Combustion of pilot light fuel
The flare pilot light flow rate shall be assumed to have a constant flow rate of 75 scf/hr and a total
of two pilot lights in the flare for a total pilot flow rate of 150 scf/hr. Monthly pilot gas throughput
Page 13 of 15
COLORADO
Air Pollution Control Division
Department of Public Health £r Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
shall be determined by multiplying this total hourly pilot gas throughput by the flare monthly hours
of operation.
CAS
Pollutant
Emission Factors -
Uncontrolled
lb/MMscf
Source
NOx
102.94
AP -42, Table 1.4-1
CO
86.471
AP -42, Table 1.4-1
VOC
5.6618
AP -42, Table 1.4-2
PM2.5/PM10
7.8235
AP -42, Table 1.4-2
110543
n -Hexane
1.8529
AP -42, Table 1.4-3
Permitted emissions are based on a heat content of 1,050 btu/scf.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN must be submitted no later than 30 days before the five-year term expires. Please refer to
the most recent annual fee invoice to determine the APEN expiration date for each emissions point
associated with this permit. For any questions regarding a specific expiration date call the Division
at (303)-692-3150.
7) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Major Source of NOx, VOC, and CO
PSI
Major Source of CO'
NANSR
Major Source of NOx and VOC
8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the following website: http://www.ecfr.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart UUUU
NSPS
Part 60, Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
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
Page 14 of 15
MACT
COLORADO
Mr Pollution Control Division
Department of Public Health Fr Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
Page 15 of 15
•
Colorado Air Permitting Project
PRELIMINARY ANALYSIS-PROJECT SUMMARY
Project Details
Review Engineer: Carissa Money
Package#: 402003
Received Date: 7/8/2019
Review Start Date: 9117/2019
Section 01-Facility Information
Company Name: DCP Operating Company,LP
County AIRS ID: 123
Plant AIRS ID: 0107
Facility Name: Lucerne 1 Natural Gas Processing Plant
Physical Address/Location: 31495 Weld County Road 43
Type of Facility: Natural Gas Processing Plant
What industry segment? Exploration&Production
Is this facility located in a NAAQS non-attainment area? Yes
If yes,for what pollutant? Carbon Monoxide(CO) ❑Particulate Matter(PM) QOzone(NOx&VOC)
Section 02-Emissions Units In Permit Application
Emissions Self Cert
AIRs Point# Emissions Source Type Permit# Issuance# Action Engineering Remarks
Control? Required?
Permit Initial
060 Process Flare Yes 19WE0732 1 Yes Issuance
Section 03-Description of Project
DCP is requesting to permit the existing plant flare(F-2)for Lucerne 1 Plant This flare is existing and previously categorized as an insignificant activity.With this
application,DCP is accounting for routine maintenance and blowdown emissions as well as purge gas and pilot gas.
DCP evaluated this permit request for PSD applicability by assuming the flare is the entire project and the entire requested increase.DCP states that since the
requested emissions increase for F-2 are below 40 tpy,it is not subject to PSD.However,DCP has been operating this flare and routing purge gas and maintenance
gas since the flare was originally installed.DCP has not made any substantial modifications to the units routed to the flare or to the flare itself since it was built.Thus,
while the flare is only now being permitted,it must be evaluated for PSD applicability also based on when it was installed.
The flare was originally installed in 2006 based on the APEN.I evaluated the permitted emissions for all of Plant 1 in 2006,2008 and 2010.See the tabs in this
spreadsheet for documentation of total plant emissionsfor Plant 1 in each scenario.In 2006,total Plant 1 emissions including the flare would have been less than
250 tpy for each pollutant and thus DCP did not avoid PSD permitting by not including the flare with the original permitting application.DCP made several
modifications from 2005 through 2010 to add three engines,two heaters,and an amine unit controlled with a thermal oxidizer.Further,the area was redesignated
to nonattaintment in Nov 2007,it appears facility wide emissions would have exceeded 250 tpy in Nov 2007(just prior to the non-attainment redesignation)when
points 032 and 033 were added.However,Point 031 was never installed so it's not clear if total permitted emissions,when also accounting for the flare,did exceed
250 tpy.The project to add the heater and amine unit controlled by a thermal oxidizer in`2010 did not exceed 40 tpy.Further,the currently permitted emissions for
Plant 1,including the Plant 1 flare,are below 250 tpy for each pollutant.
In my historical review for PSD,I am assuming the flare emissions are constant and as presented in this application.I'm unable so determine if the addition of the
amine unit or other plant modifications would have modified routine emissions to the flare.
Section 04-Public Comment Requirments
Proie
mitting
Coiora
Is Public Comment Required? ley° is
If yes,why? t ��e�c lF� • etE ;€ x ,,. Gi ;.
Section 05-Ambient Air Impact Analysis Requirements
Was a quantitative modeling analysis regwred?2
ri
If yes,for what pollutants � � ae
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? i o
Is this stationary source a synthetic minor? 1 No
If yes explain what programs and which• pollutants here
I
i qua �a �� a �''
'� tip ?' /7 "'� ' aru ;
Is this stationary source a major source?
If yes,explain wha₹programs and which pollutants here:
i. Prevention of Significant Deter.oration(PSC� CCt ��
• T (e`J operatingPern'ts(OP) _d CI �'
No
Yttainrnent Nev Source Review(N�NSR; NOx,V• GC i;; ,./_,,,,,, :f �'
a
a� T
•
i
,
Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment
Air Pollution Control Division
Section 01- Administrative Information
Facility AIRs ID:
123 0107 960
County Plant Poin
Section 02 - Equipment Description Details
Maintenance activities and purging of gas. Activities are controlled by an elevated open process flare. Purge gas prevents low
flashback problems to the flare and keeps the flame stable. The purge gas and pilot gas used is residue gas and helps the flare
maintain a minimum required positive flow through the system. Also includes combustion from pilots. The flare is also a back up
control device.
Control Efficiency 95%
Section 03 - Processing Rate Information for Emissions Estimates
Flare Pilot Rating 0.1575 MMBtu/hr based on manufacturers spec of 75 scfh per pilot and assuming 2 pilots
Fuel Gas Heat Value 1050 Btu/scf 0.1575 MMBtu/hr 1.314 MMscf/yr 13717 MMBtu/yr 0.112 MMscf/morth
Flare Purge Gas Rate 600 scf/hr 0.659 MMBtu/hr 5.26 MMscf/yr 5771.088 MMBtu/yr 0.446 MMscr/month
Purge Gas Heat Value 1098 Btu/scf
Residue Gas Slowdown to Fl 712.3287671 scf/hr 0.78214 MMBtu/hr 6.24 MMscf/yr east 52 MMBtu/yr 0.530 MMsc1/month
Residue Gas Heat Value 1098 Btu/scf
In le Gas Slowdown to Flare 1068.493151 scf/hr 1.43285 MMBtu/hr 9.36 MMscf/yr 12551.76 MMBtu/yr 0.795 MMscr/monh
Inlet Gas Heat Value 1341 Btu/scf
Refrig System Slowdown to 593.6073059 scf/hr 1.49352 MMBtu/hr 5.20 MMscf/yr 130812 MMBtu/yr 0.442 MMscr/m«nh
Refrig Gas Heat Value 2516 Btu/scf
Maintenance 20.80 MMscf/yr 1.77 MMscf/month
Hours of operation
8760 hr/yr
Total 2974.4292 scf/hr without pit 4.52480228 MMBtu/hr 27.37000000 MMscf/yr MMscr/month
26.06 Mmacf/yr without peat
Section 04 - Emissions Factors & Methodologies
Emission Calculation Method
EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3)
Ex= Q' MW*Xx/C
Ex = emissions of pollutant x
Q = Volumetric flow rate/volume of gas processed
MW = Molecular weight of gas = SG of gas' MW of air
Xx = mass fraction of x in gas
C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm
PURGE GAS
Maximum Vent Rate I 600 scf/hr
ReguestedThroughput (Q) 5.3 MMscf/yr
600.0 scf/hr I 0.014 MMsd/d I 0.45 MMscf/mo
% Vented I 100%
MW 18.300 lb/lb-mcl
Component
mole%
MW
IbxAbmol
mass fraction
E
Ib/hr
lb/yr
tpy
Helium
0
4.0026
0.000
0.000
Helium
0.0
0
0.00
CO2
1.3323
44.01
0.586
0.032
CO2
0.9
8131
4.07
N2
0.587
28.013
0.164
0.009
N2
0.3
2280
1.14
methane
85.9465
16.041
13.787
0.753
methane
21.8
191195
95.80
ethane
10.9474
30.063
3.291
0.180
ethane
5.2
45841
22.82
propane
1.1818
44.092
0.5211
0.028
propane
0.8
7226
3.61
isobutane
0.0272
58.118
0.0158
0.001
isobutane
0.0
219
0.11
n -butane
0.0384
58.118
0.0223
0.001
n -butane
0.0
309
0.15
isopentane
0.0014
72.114
0.0010
0.000
isopentane
0.0
14
0.01
n -pentane
0.0008
72.114
0.0006
0.000
n -pentane
0.0
8
0.00
cyclopentane
70.13
0.0000
0.000
cyclopentane
0.0
0
0.00
n -Hexane
86.18
0.0000 •
0.000
n -Hexane
0.0
0
0.00
cyclohexane
84.16
0.0000
0.000
cyclohexane
0.0
0
0.00
Other hexanes
86.18
0.0000
0.000
Other hexanes
0.0
0
0.00
heptanes
100.21
0.0000
0.000
heptanes
0.0
0
0.00
methylcyclohexane
98.19
0.0000
0.000
methylcyclohexane
0.0
0
0.00
224-TMP
114.23
0.0000
0.000
224-TMP
0,0
0
0.00
Benzene
78.12
0.0000
0.000
Benzene
0.0
0
0.00
Toluene
92.15
0.0000
0.000
Toluene
0.0
0
0.00
Ethylbenzene
108.17
0.0000
0.000
Ethylbenzene
0.0
0
0.00
Xylenes
106.17
0.0000
0.000
Xylenes
0.0
0
0.00
C8+ Heavies
315.000
0.0000
0.000
C8+ Heavies
0.0
0
0.00
100.0628 VOC mass fraction: 0.0306 Total
Notes
VOC Emissions (Uncontrolled)
3.89
Mole %, MW, and mass fractions are based on data from Meter #308409 for Lucerne 2. DCP also provided a 2017 extended gas analysis showing HAPs at "NIL".
Emissions are based on 8760 hours of operation per year.
MW of C8+ is assumed to be 315
RESIDUE GAS SLOWDOWN
Maximum Vent Rate I
712.3287671 scf/hr
RequestedThroughput (Q)
6 MMscf/yr
712.3 scf/hr I 0.017 MMscf/d ( 0.53 MMscf/mo
% Vented I
100%
MW
18.3001b/Ib-mol
Component
mole %
MW
Ibxdbmol
mass fraction
E
lb/hr
lb/yr
tpy
Helium
0
4.0026
0.000
0.000
Helium
0.0
0
0.00
CO2
1.3323
44.01
0.586
0.032
CO2
1.1
9654
4.83
N2
0.587
28.013
0.164
0.009
N2
0.3
2707
1.35
methane
85.9465
16.041
- 13.787
0.753
methane
25.9
226989
113.49
ethane
10.9474
30.063
3.291
0.180
ethane
6.2
54186
27.09
propane
1.1818
44.092
0.5211
0.028
propane
1.0
8579
4.29
isobutane
0.0272
58.118
0.0158
0.001
isobutane
0.0
260
0.13
2325 MMsd/month
33.0
Produced Natural Gas Venting/Flaring Preliminary Analysis
Colorado Department of Public Health and Environment
Air Pollution Control Division
n -butane
0.0384
58.118
0.0223
0.001
n -butane
0.0
367
0.18
isopentane
0.0014
72.114
0.0010
0.000
isopentane
0.0
17
0.01
n -pentane
0.0008
72.114
0.0006
0.000
n -pentane
0.0
9
0.00
cyGopentane
70.13
0.0000
0.000
cyGopentane
0.0
0
0.00
n -Hexane
86.18
0.0000
0.000
n -Hexane
0.0
0
0.00
cyclohexane
84.16
0.0000
0.000
cyclohexane
0.0
0
0.00
Other hexanes
86.18
0.0000
0.000
Omer hexanes
0.0
0
0.00
heptanes
100.21.
0.0000
0.000
heptanes
0.0
0
0.00
methylcyclohexane
98.19
0.0000
0.000
methylcyclohexane
0.0
0
0.00
224TMP
114.23
0.0000
0.000
224-TMP
0.0
0
0.00
Benzene
78.12
0.0000
0.000
Benzene
0.0
0
0.00
Toluene
92.15
0.0000
0.000
Toluene
0.0
0
0.00
Ethylbenzene
106.17
0.0000
0.000
Ethylbenzene
0.0
0
0.00
Xylenes
106.17
0.0000
0.000
Xylenes
0.0
0
0.00
C8+ Heavies
315.000
0.0000
0.000
C8+ Heavies
0.0
0
0.00
100.0628
Notes
Mole %, MW, and mass fractions are based on data from Meter #308409 for Lucerne 2. DCP also provided a 2017 extended gas analysis showing HAPs at "NIL".
Emissions are based on 8760 hours of operation per year.
MW of C8+ is assumed to be 315
VOC mass fraction:
.0306 Total VOC Emissions (UnconVo
INLET GAS BLOWDOWN
Maximum Vent Rate I
1068.493151 scf/hr
RequestedThroughput (Q)
9.4 MMscf/yr
1068.5 scf/hr I 0.026 MMscf/d I 0.79 MMscf/mo
% Vented
100%
MW
23.200 lbdb-mol
Component
mole %
MW
Ibx/Ibmol
mass fraction
E
Ib/hr
6/yr
tpy
Helium
0
4.0026
0.000
0.000
Helium
0.0
0
0.00
C02
2.28
44.01
1.003
0.043
C02
2.8
24781
12.39
N2
0.28
28.013
0.078
0.003
N2
0.2
1937
0.97
methane
71.7284
16.041
11.508
0.496
methane
32.4
284158
142.08
ethane
13.6633
30.063
4.108
0.177
ethane
11.6
101444
50.72
propane
6.6784
44.092
2.9446
0.127
propane
8.3
72723
36.36
isobutane
0.9366
58.118
0.5443
0.023
isobutane
1.5
13443
6.72
n -butane
2.304
58.118
1.3390
0.058
n -butane
3.8
33070
16.53
isopentane
0.5649
72.114
0.4074
0.018
isopentane
1.1
10061
5.03
n -pentane
0.6668
72.114
0.4809
0.021
n -pentane
1.4
11875
5.94
cyGopentane
0.0381
70.13
0.0267
0.001
cyGopentane
0.1
660
0.33
n -Hexane
0.1787
86.18
0.1540
0.007
n -Hexane
0.4
3803
1.90
cyclohexane
0.0529
84.16
0.0445
0.002
cyclohexane
0.1
1100
' 0.55
Other hexanes
0.2896
86.18
0.2496
0.011
Omer hexanes
0.7
6164
3.08
heptanes
0.1461
100.21
0.1464
0.006
heptanes
0.4
3618
1.81
methylcyclohexane
0.0459
98.19
0.0451
0.002
methylcyclohexane
0.1
1113
0.56
224-TMP
0.0002
114.23
0.0002
0.000
224-TMP
0.0
6
0.00
Benzene
0.035
78.12
0.0273
0.001
Benzene
0.1
875
0.34
Toluene
0.0336
92.15
0.0310
0.001
Toluene
0.1
765
0.38
Ethylbenzene
0.0012
106.17
0.0013
0.000
Ethylbenzene
0.0
31
0.02
Xylenes
-
0.0083
106.17
0.0088
0.000
Xylenes
0.0
218
0.11
C8+ Heavies
0.0676
315.000
0.2129
0.009
C8+ Heavies
0.6
5259
2.63
Notes
99.9996 VOC mass fraction: 0.2872 C Emissions (Uncontrolled) PLUS 10% Safety Factor
90.5
Mole %, MW, and mass fractions are based on 11/20/2018 analysis of Lucerne 1 Plant inlet
Emissions are based on 8780 hours of operation per year.
MW of C8+ is assumed to be 315
REFRIGERANT GAS SLOWDOWN
Maximum Vent Rate I 593.6073059 scf/hr
RequestedThroughput (0) 5.2 MMscf/yr
593.6 scf/hr I 0.014 MMscf/d I 0.44 MMscf/mo
% Vented I 100%
MW 43.900 Ib/Ib-mol
Component
mole %
MW
lbx/Ibmol
mass fraction
E
lb/hr
lb/yr
tpy
Helium
0
4.0026
0.000
0.000
Helium
0.0
0
0.00
C02
0
44.01
0.000
0.000
C02
0.0
0
0.00
N2
0
28.013
0.000
0000
N2
0.0
0
0.00
methane
0
16.041
0.000
0.000
methane
0.0
0
0.00
ethane
0.5073
30.063
0.153
0.003
ethane
0.2
2092
1.05
propane
99.4447
44.092
43.8472
0.999
propane
68.7
601597
300.80
isobutane
58.118
0.0000
0.000
isobutane
0.0
0
0.00
n -butane
0.048
58.118
0.0279
0.001
n -butane
0.0
383
0.19
isopentane
72.114
0.0000
0.000
isopentane
0.0
0
0.00
n -pentane
72.114
0.0000
0.000
n -pentane
0.0
0
0.00
cycopemane
70.13
0.0000
0.000
cycopentane
0.0
0
0.00
n -Hexane
86.18
0.0000
0.000
n -Hexane
0.0
0
0.00
cyclohexane
84.16
0.0000
0.000
cyclohexane
0.0
0
0.00
Other hexanes
86.18
0.0000
0.000
Other hexanes
0.0
0
0.00
heptanes
100.21
0.0000
0.000
heptanes
0.0
0
0.00
methylcyclohexane
98.19
0.0000
0.000
methylcyclohexane
0.0
0
0.00
224-TMP
114.23
0.0000
0.000
224-TMP
0.0
0
0.00
Benzene
78.12
0.0000
0.000
Benzene
0.0
0
0.00
Toluene
92.15
0.0000
0.000
Toluene
0.0.
0
0.00
Ethylbenzene
106.17
0.0000
0.000
Ethylbenzene
0.0
0
0.00
Xylenes
106.17
0.0000
0.000
Xylenes
0.0
0
0.00
C8+ Heavies
315.000
0.0000
0.000
C8+ Heavies
0.0
0
0.00
100 OC PLUS ETHANE mass fraction: 1.0029 Total VOC + Ethane Emissions (Uncontrolled)
Notes
302.0
Mole %, MW, and mass fractions are based on 7110/17 Liquids analysis at Lucerne II. Application did not include the analytical report
Emissions are based on 8760 hours of operation per year.
MW of C8+ is assumed to be 315
Sub -Total of Uncontrolled VOC and HAP Emissions
VOC
tpy
401.1
Ib/yr
Ib/MMscf
A check for H2S emissions
H2S
H25 in Process Gas 6 ppm
30784 tcid Gas Molar Volume to Molar Mass 379
90.6
SOURCE CONSERVATIVELY ASST
398.09
Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment
. Air Pollution Control Division
Benzene 0.3376 675 25.9155 SO2 64.05
Toluene 0.3823 765 29.3470 H2S 34.08
Ethylbenzene 0.0157 31 1.2076
_ Xylene _ 0.1088 218 8.3524 H25 in Process Gas 15 lb/yr
n-Hexane 1.9 3803 145.9688 SO2 combustion emissions 28 lb/yr
0
PILOT LIGHT COMBUSTION EMISSIONS
Uncontrolled Emission Factors Total Emissions
Pollutant Emission Factor Source
Ib/MMscf lb/MMBtu lb/yr tpy
VOC - 5,50 0.0054-' '' .4'2 sapter24..2'.`_....At.z•, ".,40. " .iii/o#f:, •`7.4-. .. 0:004 • 1 5.6618
Benzene _.0.0021' . 0.0000 314 pt r."+ -' '' , 1` j '' 0.0028 0.000 0.0022
Toluene 0.0034 ' 6 0000 t's yWA41 V /, ' 0,0046, . 0-000.
Ethylbenzene ... �4 a 44 / / ', .-09 0.000I
.- ,R -e
Xylene ��� -_yam e :.'00 '-' • 0.000-;-
n-Hexane 1800 00018 AE-42ChNp190143- 1;1C.,/r'F i/. '24 0.001 • 1.8529
224-Trimethylpentane - :,-:' ,„m.4I'/ '4// '� "�, l� , :.,,0,12 .,0.000;.. EF for permit
PM10 .; 7,6 .09075 f#p:Zt fiap89y"1!d-2% e --- „ ..;. ,,,: ;. .."10.3 ..'•: " 0.0:::. 7.8235
PM2.5 7.6. 110075 40-42,Ch8p€e7142'< --x IE1' _ ,,.,20 3:;,` _ 0.0 7.8235
SO2 . 0:6:'" . 6.0006:: , ,r 3 , :,,�'' 4.o 0.8 0.0 lb/31 day 0.6176
NOx ;,..100.000000,;,, ,' 0,0980 �4* "rid'lr �/rh",, --1353 0,1 - 11 102.94
CO :04.000000 0.0824 ,,,,,,„, _ '''''.1, ,,„i ttft 11336 0.1 10 86.471
COMBUSTION EMISSIONS FOR PURGE GAS
Uncontrolled Emission Factors Uncontrolled Emissions Controlled Emissions
Pollutant lh/MMscf Ib/MMBtu Emission Factor Source lb/yr tpy lb/yr tpy lb/31 day
VOC 1479.7' _ - " 3, , 4. fttat 7777. ..3.889 389 9.2 ' 33
Benzene _ • 0.0 x4 *'9, AV - 9 0.000 0 ' 0,0 -
Toluene . 0.0. 'ffey, r 9 ' . 0.000 0 0.0
Ethylbenzene 0.0 '' ` r.,x ;? r 0 0.000 0 • - • 0.0.
.. A'j, 1' _,..0000 -Xylene �0.0 z _ �� :.�-'.�,.� :. 0 �-:,0 .• -:.OA.;
n-Hexane - 8/0 - '. ..„ ?3:` 0% : 0000, - :0 - 0:0-
224-Trimethylpentane 0.0 -
PM10 .. . ..•_ . r ,Ofi{ A „i fr "'l .. 0
rM d ,41-/4 4 -
502 .. - �i/r . •. 0 .. 0-.::.:.•_. 0
NOx • 74,664. . -.-- 0.0680• ,GIs-„Z;;C(Eapto>a17 .4* , .,, .,,- „ 0 • 392' ' 0.20' - 392 " 0212':: ' 33
CO 340.38:; 0.3100. y ,,,, „„. .„ _ H•,,.. _ M 1789 0.89 1789. :, - 0.89- • , 152 .
COMBUSTION EMISSIONS FOR BLOWDOWN/MAINTENANCE ACTIVITIES
Uncontrolled Emission Factors Uncontrolled Emissions Controlled Emissions
Pollutant Ib/MMscf lb/MMBtu Emission Factor Source lb/yr tpy lb/yr tpy lb/31 day
VOC 881896 .: _ . %r/�,r /i + U0 g!' - - 794344 .397.2" . 39717 19.9 3373
Benzene .. 323. 4", •, 4im��? ., 675 - 0.3 34. 0.0'
Toluene •.36.8 - 444'' 3 f B . 765
Ethylbenzene 1.5 '`,' 4'V .1. :„ .1, O--W .r/'/(..z ,at-- 0.0 • :2z. ,,,,,5.93,,,.5'
Xyiene -:DOS 1-.T- e ., ,, tF: .44a4.. 218' - ' 0.1 .11 .0.0`:
n-Hexane i- . 182.9= '�4 `�* . '3803 . 1.9 ' '190 0.1 :.224-Trimethylpentane
.224-Trimethylpentane '0.3', ��E ''„/ 6 0.003 . . 0- 0.0. 0
PM10 ,. .. 40
���'-'4(:;',,,
. 't. ''. ,0,:. 0.,,. 0
PM2.5 - -- ₹V 9 / - '- 5!:•,' 0 .
SO2 • . 1'S` IT oi' *4I .. • .. 0.:: 0:: -:-. 0
NOx .106.206 0.0686 Kir o1m/ .2209 "1.10- 2209' " 11 '. 188
CO - , 484.17 • 0.3100 R'F-4'2 Ssefir= -.02,<£,.., Art 11; (C., i.• -.,,10071 .. . -5-04- 10071, '50, 855
SUB-TOTAL-COMBUSTION EMISSIONS FOR PURGE AND BLOWDOWN/MAINTENANCE ACTIVITIES
Uncontrolled Emission Factors Uncontrolled Emissions Controlled Emissions
Pollutant Emission Factor Source
Ih/MMscf lb/MMBtu lb/yr tpy lb/yr tpy lb/31 day
VOC ..... ,., ^tf' - - .,..
"' ..o,.,,:,,., ,.,,�,,,�`.,� ,rurc <'' 802121 .1" 4q S." 40106 ?O.S 3406
Benzene .. .. _: _ _ .: ..,. -+ ,H. -.,„:., .._ -,.� ...," w:675 ,„0 • :.3d. .-0
Toluene - . .. ''v" -..r r/f� i d fi�.,e2 :::765:'. .>0: 38 .0
Ethylbenzene .,..... ..a...;._ i'.e.. z >.,...,.. /' • 31 . . 0 _• ' 2 . 0 .
Xylene ' ' �/ x ' ' .'218,.. 0 • ''11 .,0'
n-Hexane :.. ..&d .'�/ _t'4 '' `s' 3803.•:. 2 - :190' :0'..
224-Trimethylpentane .. ^- `"' "° `O - 6 0 . . -0: -0.'. o
PM10 _ `' 4 - :,M�,/'�,f 0 0 . 0 0 - 0
PM2.5 - ' . axis Q. • - 0 '0 Q"
SO2 ,a /j4444449/4, : h v yf- ',r •:i; 0. '. 0 0 0 - 0
NOx .. VV' - -2602.. • '1 2602 13 221
CO r- _.;.. - U _ ; _ ',11860 6 11860 5.9 1007
Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment
Air Pollution Control Division
Section 05-Emissions Inventory
Potential to Emit Actual Emissions Requested Permit Limits
Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled
(tons/year) (tons/year) (tons/year) (tons/year) (tons/year)
PM10 0,0 0.0 , 0,01
PM2.5 0.0 0.0 0.01
SO2 0.0 0.00
Nox 1.4 1,37 1,4 1.4
CO 6-0 5,99 6.0 6.0 -
_ VOC 401.1 401.1 20.1 401.1 20.1
Potential to Emit Actual Emissions Requested Permit Limits Requested Permit Limes
HazardousAirPollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Controlled DCP's values
(tons/year( (tons/year) (tons/year) (tons/year) (tons/year) (Ib/yri (Ib/yr)
Benzene 3.4£-01 0.34 0.02 675 34 675 34
Toluene 3,8E-01 0,38 0.02 765 38 764 38
Ethylbenzene 1.6E-02 0.02 0.00 31 2 31 2
Xylene 1.1E-01 0.11 0,01 218 11 218 11 -
n-Hexane 1.9E+00 1.90 0,10. 3806 193 3798 192
224 TMP 0:08+00 0.00 0.00
2.75 5495
Section 06-Regulates Summary Analysis
Regulation 3,Parts A,B Unit is required to have an APEN and a permit
Regulation 7,Section XVII.B
Regulation 7,Section XVII.B.2.e
Section 07-Initial and Periodic Sampling and Testing Requirements
Was a site-specific gas sample collected within a year of application submittal used
to estimate emissions?
If no,the permit will contain an"Initial Compliance"testing requirement to demonstrate compliance with emission limits
Does the company request a control device efficiency greater than 95%for a flare or combustion device? y-
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 08-Technical Analysis Notes
In this application,DCP is requesting to permit the existing plant flare for Lucerne Plant 1 DCP previously considered this flare to bean insignificant activity:With
this.modification,DCP is accounting for purge gas and routine maintenance gas routed to the plant flare.DCP is also accounting for the pilot light.
Unlike the plant 2 flare(AIRS ID 059),this flare only has one header.DCP provided flare specification sheets documenting a pilot-flow rate:of 75 scfh and 2 pilots.This specification also showed a minimum purge rate of 80 scfh and DCP then added a 25%buffer to the total purge rate which equals100 scfh.When I visited the
plant on 9/19/2019,the rotameters-showed 60 scfhfor the east flare header and 120 sdh for west flare gas header which would total 180 scfh.Since the actual purge rate at the
site was higher than the value proposed in the application,I.requested DCP to increase:the flow rate DCP clarified that the existing flow meter cannot read:less than 2,375 scf/hr
so I proposed using the minimum detection flow of the meter as the basis f orthe purge.rate.DCP proposed increasingthe requested purge rate from 100 scf/hr to 600 scf/hr.
DCP also requested to`increasethe requested flow for blowdown.In the original application,DCP requested residue gas blowdown flow of 029 MMscf/yr,inlet gas Slowdown
flow of 3.53 and refrigerant system`blowdown flow of 031 MMscf/yr.With the revised:flows,DCF`is requesting 6.24 MMscf/yrforresidue gm Slowdown,.9:36 MMscf/vr for inlet
gas blowdown and 5.20 Mmscf/yr for refrigerant system Slowdown.DCP will also be required to installa low flow meterthat can read the flows at lower levels.With these
revised rates,the total flow would be slightly above t he detection level of the high flow meter but since:the flows are intermittent,DCP must install a low flow mete r to
determine compliance.
DCP is also assuming the gas composition of residue gas far the purge gas.DCP used the same gas composition as used for Plant lflare(AIRS ID 059)which,is
based on a gas analysis from meter readings.This analysis did not include'IAPs.DCP also used site-specific pm amine inlet gas analysis collected 5/10/2018 to
estimate inlet gas composition and a site-specific refrigerant liquids analysis collected 7/10/2017 to estimate refrigerant gas composition.These stream
compositions were also used to estimate emissions from Plant 2 flare(AIRS ID 059) The permit will include a condition to sample the gas routed to the flare
For ongoing compliance,DCP will be required to sample the gas composition and meter the volume routed to the flare:
Section 09-Inventory 5CC Coding and Emissions Factors
Uncontrolled
Emissions
AIRS Point it Process# 5CC Code Pollutant Factor Control% Units
060 31 V,, PM10 0.376 0.0% Ib/MMscf PM2.5 0.376 0.0% lb/MMscf
NOx 99.992 0.0% lb/MMscf
VOC 29306.8 95.0% lb/MMscf
CO 437.467 _ 0.0% lb/MMscf
Benzene 24.6714 95,0% lb/MMscf
Toluene 27.9382 95.0% lb/MMscf
Ethylbenzent 1.1496 95.0% lb/MMscf
Xylene 7.9514 95.0% lb/MMscf
a-Hexane 139,0499 95.0% lb/MMscf
224 TMP 0.0000 #DIV/01 lb/MMscf
12510107
POINT I PERMT
P7Pvlous FACIIJTY TOTAL
Previous Pe7mltmd Pacllltvlolal
DCP Midstream. LP
Lucerne Gas Process,. Plant
SW1N,eectIon 29. 78N. 665W
Weld county
Description
Edlled 1/2012020
PTE -WITH ENFORCEABLE CONTROLS
PTE -UNCONTROLLED
TSP PM10 HON 602 Ws V. PM29 Fug V. CO Reps... Total TSP P1410 025 502 Sax VOC P142.5 Fup VOC CO Repodob Taal REMARKS
Ie HAPe HAPs Is HAPs HAPs
1 A. 130 .6' 47.1 238.3 149.7 130 846 201.0 17.0 IRA_ A 13.0
127 127 1.0 470 2942 1458 12.7 34.8 297.6 158 18.5
1788 1200 771,8 774.7 B- •r . ' 6 soreadsheete
/1010427 it"1.724.7/03;r1;?:?N%-
002
00
00 03'5 /1//,/1,34+ ','..03
004
000
21343
0411113,1
03:200430
ttrev
4:1:6:92
78'2'/''214
70547
032YG073
>I'AtiOFSH0 F.333%51113502 0
02137141-/24232/1102/0
00//223114 1.1'4401011D:1:'IP
Aja ,13.11/1F2P7 30 5163CF;1
/0/4'1110022
/2,1///3011," 1.3521/1// 350097'
10 6230 2,3740 TAM
00004 2.:03. TANG
Edelman, l eaks
1232 HP Waukesha 17042 ICE
/1,1004141.EssIsp 01007:
1232 H- Waukesha L7042 ICE
12 2 HP Waukesha L7042 ICE
1232 HP Waukesha 07042 ICE
704,101/44 11/20.'2/'0.172' 5"t if.17.71
124 '2420 1Ii23341/0/0 31'5708:
W0002310 3353.33' 3/0 38301
00
00
00
00
013
014
015
05 7':1303
96//5906
06W5605
01.4000;:
OBWE005
96W 905
98WE005
01231400
sprF?,?
03;07:0409
017
018
019
020
022
024
025
029
030
031
033
03.5
040
044
045
046
047
048
049
043
04WE1301
04WE1302
04,01.1301
05WE0958
05WEO959XP
901'02Iti I00
1232 HP Waukesha L7042ICE
1232 HP Waukesha 17042 ICE
at, 331q,3 sh ./,vv.
Vent/s,I0,essipts21,11,,sp., 22,:s ,;- 0 01.1,,
1232 HP W....ha L7042 CE
REGENERATION GAS HEATER
0, a 33305rn 2201-/3 3t," 23.3
07WE0979 WAUKESHA 15794 G51 $N' C-17418/1
St3,,VO4 r et, (:,,.,1,732
00:521001 I CM 0//111;//// ^:4 0, 3 00 T .2/ . 02!9 v.+n an.,7.,3...v
00ih00'4(:l/ C, 3/.312 .3560 7.445 n,$./ 1/,,./.,
08 08 00 23.8 11.5 0.8
08 08 0.0 238 11.0 58
08 09
08 00 1 0,0 238 112 58
05 2 8 119 08
00 08 00 238 119 0.0
0B 08
00 238 119 04
06 08 00 238 119
02 02
40 I n
00 09
25
13.6
0,7 0.7
23.8 0,3 0.4 08 0.5
00
232 0.3 0,4 0.6. 08
38 0.3 0.4 08' O0
23.8 0.3 0.4 08 0A
30 00 fir. fn.>1,r{.12':01"3
00
1.11.12,10, P10
00 PIS 0c1;.../'em. 4201
Not Thu: "1'0
00 000,0.7. 7000
2131, 1/01
0 0 7S 1,4,412.1 7003
0.0 5r) }r+p
17 00 Pic GLv11//./ -107
47.3 2.5 2.5 No change
0 0 155 0 119 0.8 1302 1.0 1.3 No charms
art 00nc00evf: /1010
0.0 155 8 119 0 8 1302 1.0 13 No charms
00 1558 119 08
00 1558 119 08 1392 1.0 1.3 No charms
1392 1.0 13 Nochanae
238 02 0.4 00 08 0.0 1558 119
23.0 02 0.4 08 08 00 1550 119
00
00
08 230 03 0.4 05 08 0.0 155.8 119
no 785 143 1.0
25.7 133 09
21 00 0.0 02 07
285 /;I
257 0.0
00
071/00910 C7/ 11,0,nnpl,y 17043 ('2/ N.an:;a/,.9s /•n; 3 ps^.Y.l, 22174/.1.11,33 Hn
2240 m/: et, 070.2 LS 1232 HP
00/•01.081311. ..1/0 57'12 r• '3111.,'.,10/o/ .nn 0/ n r,;
08WF0921
12WE2024
12WE2024
12WE2024
12WF7024
12WE2024
12047414
12WE2024
1249.2.2
12//.2024
NA
NA
NA
12WF7n74
12WE2024
12WE2024
13WE2024
196.0732
Too Amine reoenaGlm halters model 6 5Ne' TB0
Nat Is Des turbine reed a185.99Mmblu011
Natural axe 40bine sled a, 85.99 Mmbidhr
Idol all healer design .,sally 453 6 MMBI:MI1
230 MMSCFD Amine ....Ina unit and RTO
230 MMSCFO TEA 430001. or
R0,
4-1000 BBL condensate dome hold
Truckload.,
Punitive mulomenl bake
Poinl created In PTS by mdlake-not a Ylace dmuirmenl
Point created In PTS by mlelake - not a Dime of a.m..
Point created in PT5 by mistake not s Noce ormummenl
Prn.nnd>nd:/0350/nn Il raw rmndnneaA
One 400 bbl modgced pates storage lank
One 309 bbl ...and storage tank
Plant 2 Aare
Plant 1 Flare
051
052
053
.54
055
956
957
050
059
05 '05
19 19
19 I9
05 05
00 00 10 324_ 27 106 0.0-
123 08
26 04 05
1.0 115
10 115 0,7 19
0.1 58 09 OA
19
01 1.7
02 2
01
00
60 0.0
43 45 45
5.1 00 0.1 05 0.5
18.3 02 02 19 10 10 115 07 19
10.1. 0.2 03 19 19
13.2 0,3 02 0.8 0.9
83 58 5.8 0.0 0,0 178 324 2.7 7241 OR 83 1152 115.5 No change
04 0.3 03
0.0 SP PIS 0m3.32:M. 200
J 0 00 011: Cnm',M,/Of 21,0
SS PT'S f.:ann300. 30.?5
*; fam•a/ro/ 2001
08 1302 10 1.3 No change
05 192. 1.0 13 Nochanae
00 00 075 cs2rs9,P
0 0 0.0 002 2,34.,22si5/,11'/3,,/12
00 00 (.7'a Cm0a.5n115/n'1s.//1m/u./OO19MC
08 1392 1.0 13 No change
25 02, 21 00 0A NO change (APEN4.665.1oermhseemoll
7'14 /11/.5!4/' 1/139
1.0 10 00 1852 285 10 12, 13 No change
0.5 09
1852 257 09
123 00 5897
26 0.4 05
Insipnincanl sources .M4. 2 expand. •
0.0 00
D.0 OA
0.1 0.1
0.0 0.2
02
19 12.9 00
IA 20.1 0.0
0.1 0.7 22
214
15 115 07 10
0.1 65 00 05
1159 12 1.4 Nochanae
'v0
00 01pre isH,n:r
0'0 Pe0/2/:33,5::s.I/?-/ .•....2 /04 bat.tt-./,5,:.10/n
0.0
.0.f 30 1 .13,11033,3
.,., Pfin..1...r...1733.:;.s.n.dris.,d.04.::.rrr
43 4509 450.8 J4o chance
51 0.0 0.1 No chnnas
153 0.2 03 No clams
153 0.2 02 Nochanae
133 0.3 02 Nochanoe
0.5 0.4 0,4
06 08 0.8
07 0.7
00
0.0
01
0.0
02
0.0 0.0 05
0.2 0.2
8.7 0,0 0.0 0,0 0.0
60 0.1 0.1 0.0 0.0
0.8 02 02 0.1
Insign/r I sources for ;Ming Prairie Nord
8.7
05
Oi 9512
02 553
01 739
131 3
0.1
Dg 30
02
15 257.1 05
1,4 401.1 01,
0.4 165.2 160.2 No change
f.00.bi1;+,:;a'2I: 3':;:1104;
05 8.0 8.5 .Hochanes
06 115 115 No chen00
44 4,4 Nochanae
00 Polntmulled In PTSbv mistake -not a placed mule
00 071 Point viedad In PTS bvmbleke-nde eland PAW
00 0.0 Ponlmealed In PT5 by mblake-nde alma of wadi
0.1 0.2 No change
00 0.3 0.4 Nochanae
02 0.2 No change
5.7 0.7 0.0 No clangs
0.0 2.6 2.7 I1er.'porn, /witlh/d flow ,/,/had,:d been
oresictratv ue tined
0.7 22 0.1 0.6 0.2 0.2 Based on WOW c4de Iola subn8lled 11/1511018
87
Based on facility aide farm submitted 11/1571018
Total Facility ITPY1
Total Permitted Feel Kv ITPT1
Change In admitted em salonsllPY1
P.bcleMASgns0Or wemel?PY1
13.0 10,0 1.0 47 1 263 2 184 0 13.0 54.6 3.6.2 17.1 190 13.0 13.0 175 47.1 1 602 ' 3.100 2 130 175.5 1.303.; 773.6 7774
1 07 I
127 12.7 1.0 470 2600 173.1 27 342 303.6 1711 157
0.0 DA 0.0 0.0 262 27.2 0.0 0.0 60 O1 0.1
00 05 72'1 1 58 82 130 2'2 _8_
123(0107
DCP Midstream, LP
Lucerne Gas Processing Plant
SW1/4, section 28, T6N, R65W
Weld County
PTE - with Enforceable Controls
POINT
PERMIT
Description
Formaldehyde
Acetaldehyde
Benzene
Acrolein
1.3-Buladiene
Toluene
Ethylbeneone
Xylenes
n -Hexane
224 TMP
McOH
DEA
001
84W0'06'0-2
WAUKESHA L-7042051 110011P
002
Not used
0
003
85W0'043
WAUKESHA F-352101) 450HP
004
84tH::384-1
WAUKESHA L-7042051 11000P
00005 -
Not used
0
006
0 :WE0489
WAUKESHA L: 70420 S1 9100HP
007
Not used
0
008
03W00489
NG GLYDEHY 10.5E6SCFD
008
86040216
WAUKESHA SHA L-7042GS1 I100HP
010
86W0562
WAUKESHA F-352101) 45014
011
96140905
THREE 300 BEL CONDENSATE TANKS
0/2
96WE135-2
210 BEL COND. TANK
013
96WE135-3
300B01. CONE). TANK
014
96WE905
Equipment Leaks
1478
015
96WE905
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
8
126
016
96010305
Waukesha Engine 1P002)
017
96WE905
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
8
126
018
96WE905
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
8
126
019
96WE905
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
8
126
020
9&W0905
WAUKESHA. MODEL; F-3521, SN: 365350
021
9614/0805
GLYCOL DEHYDRATION SYSTEM
022
03W00489
WAUKESHA 03521051. 549: 3333031
023
0391/E0490
Glycol Dehydration Unit
024
04WE1301
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
a
126
025
04WE1302
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
8
126
0211
04M/01303
Fugitive eguilirnent leaks
027
Depressuna/nq of the gas processing plant in preparation to shutdown
028
Venting of pressurized condensate tank when VR11 is down
029
05WE0958
1232 HP Waukesha L7042 ICE
405
115
65
115
23
1
8
126
030
05WE0959.XP
REGENERATION GAS HEATER
4
91
031
95OPWE(00
Caterpillar G3306TA. 220 HP. SN: TED
032
07WE0021
WAUKESHA L7042GSI RICE, SN: C-17495/1
497
141
80
133
33
28
1
10
0
0
155
033
07WE0979
WAUKESHA L5794 GSI, SN: C-1741911
455
129
73
122
26
1
9
141
034
080100912. CN
Caterpillar 03608 TALE Natural gas COMpe,SS/Or engine 2370 HP
035
O8WE09 f3. CE
Caterpillar 03608 TALE Natural gas compression engine 2370 HP
036
08141'0514. CE
Caterpillar 03608 TALE Natural gas compression engine 2370 HP
037
08WE0515. Chi
Waukesha L7042 GS/ Natural Sas compression engine 1232 HP
038
08WE0916.CN
Waukesha L7042 GS( Natural gas compression engine 1232 HP
0301
013WE3817.13N
Waukesha 1.704211;11 Natural gas orhlt;ression engine 1232 HP
040
06WE0918. CN
Solar Saturn 50 (SoLoNOo) power generation SN: TED
041
08000918. CN
Solar Saturn 50 (SoLoNOx) power generation SN: TED
042
O8WE0920
Amine unit w/ Thermal oxidizer, model 8 SN: TBD
443
349
23
177
15
8008
043
08WE0921
Two Amine regeneration heaters, model & SNs: TBD
10
243
044
12WE2024
Natural pas turbine rated at 65.99 Mmbtu/hr
410
23
7
4
75
18
37
045
12WE2024
Natural gas turbine rated at 65.99 Mmbtu/hr
410
23
7
4
75
18
37
046
12WE2024
Hot oil heater design capacity of 53.6 MMBtu/hr
24
1
1
567
047
12WE2024
230 MMSCFD Amine sweetening unit and RTO
7507
3564
130
270
114
048
12WE2024
230 MMSCFD TEG dehydrator
327
166
6
31
51
049
12010X124
Regenerative thermal oxidizer
050
12WE2024
4-1000 BBL condensate storage tanks
75
209
15
158
405.
051
12WE2024
Truck loadout
101
279
21
211
541
052
12WE2024
Fugitive equipment leaks
65
43
3
11
1314
053
NA
Point created in PTS be mistake - not a piece of equipment
054
NA
Point created in PT S by mistake - not a piece of equipment
055
NA
Point ::rea.ad in 6 (91 by n)istake - not a loam. of e'eplpnrent
056
12WE2024
Pressurized unloading of raw condensate
30
30
2
9
250
9
057
12WE2024
One 400 bbl produced water storage tank
11
33
058
12WE2024
One 300 bbl methanol storage tank
461
059
12WE2024
Plant 2 flare
12
4
1
73
060
19WE0732
Plant 1 Flare
34
38
2
11
193
ire Kiriikicant sources for Plant' expansion "
63
23
24
12
357
insfwa ,t sources for existing Prairie Plant
167
85
1
15
842
165
TOTAL (tpy)
TOTAL
REPORTABL
F /MO
0.u"
0.0
00
0.0
0.0
0.0
0.u"
0.0
0.0
np
no
0.0
O. i3
0.7
0.4
00
0.4
0.4
0.4
0.0
0.0
08
00
0,4
0.4
0.11
0u"
0r,
0.4
0.0
0.0
0.5
0.5
00
0 f,
00
0.0
0.0
0.0
O00
0.0
4.5
0.1
0,3
0.3
0.3
5.8
0.3
00
0.4
0.6
0.7
0.0
0.0
0.0
0.2
0.0
0.2
0.0
0.1
0.2
0.6
0
)
0
0
0
0
0.0
0.7
0.3
0.0
0.3
0.3
0.3
0.0
0.0
0.0
0.0
0.3
0.3
0.0
0.0
0.0
0.3
0.0
0.0
0.5
0.4
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
4.5
0.0
0.2
0.2
0.3
5.8
0.3
0.0
0.4
0.6
0.7
0.0
0.0
0.0
0.1
0.0
0.2
0.0
0.1
0.2
0.4
'
'TOTAL (TPI)
'Total Reportable = all HAPs where uncontrolled emissions > de minimus values
Red Text: uncontrolled emissions < de minimus
' 2.3' 0.6' 4.7 0.5' 0.0' 2.6' 0.1 J 0.5' 3.3' 0.1' 4.8' 0.0' 96' 176'
PTE - Uncontrolled
POINT
PERMIT
Description
Formaldehyde
Acetaldehyde
Benzene
Acrolein
13-BlF iene
Toluene
Ethylbenoon
Xylenes
n -Hexane
224 TMP
McOH
DEA
TOTAL (tpy)
TOTAL
REPORTABL
F nod
001
£4WE060-2
WAUKESHA L-7042051110HP
0.8
0.0
002
Not used.
0
0.0
0.0
003
85WE043
WAUKESHA F-3521;30 450HP
0.0
0.0
004
84WE384-1
WAUKESHA 70420S1 7'IOOHP
0.0
0.0
005
Not used
0
0 0
0 0
006
0:3WE0489
WAUKESHA t.-7042OS1 11001.1P
0.0
70
007
Not used
0
0.0
0.0
008
03W50489
NO GLY DEWY 10.515600P0
0.0
0.0
009
9661x5-216
WAUKESri'IA L7042GS11f00HP
0.0
0.0
010
8661+5562
WAUKESHA F-3521GU 450HF'
0.00
0.0
011
90W55905
THREE 300 BBL CONDENSATE TANKS
0.0
n 0
012
96 WE135-2
210 BBL COND. TANK
0.0
0.0
013
96WE135-3
300 BBL COND. TANK
0.0
0.0
014
96WE905
Equipment Leaks
5071
2.5
2.5
015
96WE905
1232 HP Waukesha L7042 ICE
1688
230
130
217
46
2
16
252
1.3
1.0
0188
96W5905
Waukesha Engine (P002)
0.0
0.0
017
96WE905
1232 HP Waukesha L7042 ICE
1688
230
130
217
46
2
16
252
1.3
1.0
018
96WE905
1232 HP Waukesha L7042 ICE
1688
230
130
217
46
2
16
252
1.3 .
1.0
019
96WE905
1232 HP Waukesha L7042 ICE
1688
230
130
217
46
2
16
252
1.3
1.0
020
96WE905
;WAUKESHA, MODEL: F-3521, SN: 365350
0.0
0.0
021
96W5905
GLYCOL DEHYDRA 77ON SYSTEM
0.0
0.0
022
03W"50489
WAUKESHA G35210S1. S!N: 383031
0.0
0.0
023
03W50490
Glycol Dehydration Unit
00
0.0
024
04WE1301
1232 HP Waukesha L7042 ICE
1688
23D
130
217
46
2
16
252
1.3
1.0
025
04WE1302
1232 HP Waukesha L7042 ICE
1688
230
130
217
46
2
16
252
1.3
1.0
026
04W51303
Fugitive ecruenf teaks
0.0
0.0
027---
Depressurizing of the pas orocessino plant in preparation lx shutdown
0.0
0.0
028 -
---
Venting of pressurized condensate lark when VRU is down
0.0
0.0
029
05WE0958
1232 HP Waukesha L7042 ICE
1688
230
130
217
46
2
16
252
1.3
1.0
030
05WE0959.XP
REGENERATION GAS HEATER
4
91
0.0
0.0
031
950PWE tOO
Caterpillar 03306'7A 220 HP, SN: '1310
00
0.0
032
07WE0021
WAUKESHA L7042GSI RICE, SN: C-17495/1
2070
282
160
266
67
56
3
20
0
0
309
1.6
1.5
033
07WE0979
WAUKESHA L5794 GSI, SN: C-17419/1
1895
258
146
243
52
2
18
283
1.4
1.2
034
080/50912. ON
Caterpillar G3508 TALE Neural gas nonwression engine 2370 HP
0.0
0.0
035
08W50913.CN
Caterpillar G3608 TALE Natural gas compression anoint, 2370 HP
0.0
0.0
038
08WE00914.CN'
Caterpillar G3808 TALE Natural gas compression engine 2370 HP
o.c
0.0
037
08K/50915. ON
Waukesha L7042 GS1 Natural oar compression engine 1232 HP
0.0
0.0
038
0£WT_0910.CN
Waukesha L7042 GO! Natural pas compression engine 1232 HP
0.0
0.0
039
08W50917. Chi
Waukesha L7042 051 Natural pas compression engine 1232 HP
0.0
0.0
040
08WE0918. ON
Solar Saturn 50 (SoLoNOo) power generation SN: TOD
0.0
0.0
041
08WE0919. CH
Solar Saturn 50 iSOLwL'Ori power generation SN: 781)
0.13
0.0
042
08WE0920
Amine unit w/ Thermal oxidizer, model & SN: TBD
44350
34936
2283
17734
1479
800792
450.8
450.8
043
08WE0921
Two Amine regeneration heaters, model & SNs: TBD
10
243
0.1
0.0
044
12WE2024
Natural gas turbine rated at 65.99 Mmbtu/hr
410
23
7
4
75
18
37
0.3
0.2
045
12WE2024
Natural gas turbine rated at 65.99 Mmbtu/hr
410
23
7
4
75
18
37
0.3
0.2
046
12WE2024
Hot oil heater design capacity of 53.6 MMBtulhr
24
1
1
567
0,3
0.3
047
12WE2024
230 MMSCFD Amine sweetening unit and RTO
139810
65700
2400
4911
18256
115.5
115.5
048
12WE2024
230 MMSCFDTEG dehydrator
187095
94794
3280
17851
29328
166.2
166.2
049
12W52024
Regenerative thermal oxidizer
0.0
0.0
050
12WE2024
4-1000 BBL condensate storage tanks
1505
4173
310
3155
8102
8.6
8.6
051
12WE2024
Truckloadout
2011
5572
415
4212
10819
11.5
11.5
052
12WE2024
Fugitive equipment leaks
400
267
20
67
8062
4.4
4.4
053
NA
Point created in PTS by mistake - not a piece of equipment
0.0
0.0
054
NA
Point created in PTS by mistake - not a piece of equipment
0.0
0.0
055
NA
Point created in PTS by mistake - note piece of equipment
0.0
0.0
056
12WE2024
Pressurized unloading of raw condensate
30
30
2
9
250
9
0.2
0.1
057
12WE2024
One 400 bbl produced water storage tank
210
660
0.4
0.3
058
12WE2024
One 300 bbl methanol storage tank
461
0.2
0.2
059
12WE2024
Plant 2 flare
246
86
4
15
1378
0.9
0.7
060
19WE0732
Plant 1 Flare
675
765
31
218
3806
2.7
2.6
Insignificant sources for Plant 2 expansion *
63
23
24
12
357
0.2
0.2
Insignificant sources for existing Prairie Plant
167
85
1
15
842
165
0.6
0.4
0.0
0.0
TOTAL (TP1�
8.3
1.1
188.9
1.0
0.0
103.5
4.4
24.2
44.7
0.1
401.8
0.0
778.0
774.3
2006 Permitted Controlled Emissions (based on 950PWE100, 14WE1301, 14WE1302, 05WE0958
POINT (PERMIT IDescriptioTSP
PM10
H2S
SO2
NOx
VOC
PM2.5
Fug VOC
CO
Previous FACILITY TOTAL
13.0
13.0
1.0
47.1
238.2
149.7
13.0
34.8
301.0
Previous Permitted Facility total
12.7
12.7
1.0
47.0
234.8
145.8
12.7
34.8
297.5
001
84 WE060-
WAUKESHA L-7042GSI 1100HP
002
Not used
f
003
85WE043
WAUKESHA F-3521 GU 450HP
004
84VVE384-
WAUKESHA L-7042GS/ 1100HP
005
Not used
I I
006
03WE0489
WAUKESHA L-70426 Sl 1100HP
007
Not used
I
008
0,3 WE0489
NG GLY DEHY 10.5E6SCFD
009
86WE216
WAUKESHA L-7042GS1 1100HP
010
86WE562
WAUKESHA F-3521 GU 450HP
011
96WE905
THREE 300 BBL CONDENSATE TANKS
012
96WF-135-
210 BBL COND. TANK
013
96WE135-.
300 BBL COND. TANK
014
96WE905
Equipment Leaks
11.2
015
96WE905
1232 HP V1
2.0
2.0
0.0
53.1
10.6
2.0
53.1
016
96WE905
Waukesha
0.8
0.8
21.7
4.4
0.8
21.7
017
96WE905
1232 HP V1
2.0
2.0
0.0
21.3
10.7
2.0
31.9
018
96WE905
1232 HP VI
2.0
2.0
0.0
21.3
10.7
2.0
31.9
019
96WE905
1232 HP VI
2.0
2.0
0.0
21.3
10.7
2.0
31.9
020
96WE905
WAUKESI
0.8
0.8
8.7
4.1
0.8
13.1
021
96WE905
GLYCOL DEHYDRATION SYSTEM
11.0
022
03WE0489
WAUKESHA G3521GS1, SIN: 393031
023
03WE049C
Glycol Dehydration Unit
024
04WE1301
1232 HP V1
0.8
0.8
0.0
23.8
11.9
0.8
23.8
025
04WE1302
1232 HP VI
0.8
0.8
0.0
23.8
11.9
0.8
23.8
026
04WE1303
Fugitive equipment leaks
027
---
Depressurizing of the gas processing plant in preparation to shutdown
028
Venting of pressurized condensate tank when VRU is down
029
05WE095e
1232 HP Waukesha L7042 ICE I
030
05WE095E
REGENERATION GAS HEATER
031
95OPWEl
Caterpillar G3306TA, 220 HP, SN: TED
032
07WE0021
WAUKESHA L7042GSI RICE, SN: C-17495/1
033
07WE0976
WAUKESHA L5794 GSI, SN: C-17419/1
034
08WE0912
Caterpillar G3608 TALE Natural gas compression engine 2370 HP
035
08WE0913
Caterpillar G3608 TALE Natural gas compression engine 2370 HP
036
08WE0914
Caterpillar G3608 TALE Natural gas compression engine 2370 HP
037
08WE09113
Waukesha L7042 GS! Natural gas compression engine 1232 HP
038
08WE0916
Waukesha L7042 GS! Natural gas compression engine 1232 HP
039
08WE0917
Waukesha L7042 GSI Natural gas compression engine 1232 HP
040
08WE0918
Solar Saturn 50 (SoLoNOx) power generation SN: TBD
041
08WE0919
Solar Saturn 50 (SoLoNOx) power generation SN: TBD
042
08WE092C
Amine unit w/ Thermal oxidizer, model & SN: TBD
043
08WE0921
Two Amine regeneration heaters, model & SNs: TBD
Permitted Facility Total
Flare
Facility Total
11.2 11.2 0.0 0.1 195.0
0.01 0.01 1.4
11.21 11.21 0.00 0.12 196.39
86.0
20.1
106.03
11.2
0.01
11.21
11.2
11.23
231.2
6.0
237.21
Based on 2007 Inspection report, Points 014-
021, 024 and 025 were on site in 2006
2008 Permitted Controlled Emissions (based on 95OPWE100, 14WE1301, 14WE1302, 05WE0958
POINT (PERMIT
Descriptio
TSP
PM10
H2S
SO2
NOx
VOC
PM2.5
Fug VOC
CO
Previous FACILITY TOTAL
13.0
13.0
1.0
47.1
238.2
149.7
13.0
34.8
301.0
Previous Permitted Facility total
12.7
12.7
1.0
47.0
234.8
145.8
12.7
34.8
297.5
001
6i4WE060-2
WAUKESHA i..-70421St 1100H,°
002
Not used
003
85WE043
WAUKESHA F.352IOU 450HP
004
84 WE364.1
WAUKESHA 07042(151!700HP
005
Notused
I
006
03WE0489
WAUKESHHA4.-70420511100HP
007
Not used
(
008
03WE0489
NO GLYDEHY 10.5ESSCFD
009
861h'E216
WAUKESHA L-70420SI 1100HP
070
86W5562
WAUKESHA F-352100 450HP
011
961h'F..905
THREE 300 BBL CONDENSATE TANKS
012
96 WE 135-2
210 7154. COND. TANK
013
96WE 935-3
300 BBL COND. TANK
014
96WE905
Equipment Leaks
10.2
015
96WE905
1232 HP VII 0.8
0.8
0.0
23.8
11.9
0.8
23.8
016
96WE905
Waukesha Engine (P002)
017
96WE905
1232 HP N
0.8
0.8
0.0
23.8
11.9
0.8
23.8
018
96WE905
1232 HP V
0.8
0.8
0.0
23.8
11.9
0.8
23.8
019
96WE905
1232 HP Vi
0.8
0.8
0.0
23.8
11.9
0.8
23.8
020
96WE905
WAUKESHA, MODEL F3521. SN: 365350
021
96WE905
GLYCOL DEHYDRATION SYS'T'EM
022
03WE0489
WAUKESLA 0352905(, S43: .3(13031
023
03WE0490
Glycol Deh;dration (:nit
024
04WE1301
1232 HP N
0.8
0.8
0.0
23.8
11.9
0.8
23.8
025
04WE1302
1232 HP N
0.8
0.8
0.0
23.8
11.9
0.8
23.8
026
04WE1303
Fugitive eq iiprnent leaks
027
_..
Depressurizing of the gas processing plant in areparatlo r to shutdown
028
---
Venting of pressurized condensate lank when VRU is down
029
05WE0958
1232 HP N
0.8
0.8
0.0
23.8
11.9
0.8
23.8
030
05WE0959.XP
REGENEF
0.2
0.2
2.5
0.2
2.1
031
95OPWE 10O
Caterpillar G3306TA A. 220 HP, SN: TED
24.22
2.12
26.98
032
07WE0021
WAUKESHA L7042GSI RICE, SN: C-17495/1
28.5
14.3
28.5
033
07WE0979
WAUKESHA L5794 GSI, SN: C-17419/1
26.7
13.3
26.7
034
08 WE01712.ON
Caterpillar G3608 TALE Natural gas compression angina 2370 HP
035
08WE09 t3.CN
Caterpillar G3608 TALE Natural gas compression engine 2370 HP
036
008WE0914.CN
Caterpillar 63608 TALE Natural gas compression engine 2370 HP
037
08W50915.CN
Waukesha L7042 0S1 Natural gas compression engine 1232 HP
038
OttWE091 t3.CN
Waukesha 1..7042 GSI Natural gas compression engine 1732 HP
039
OSWE0917 ON
Waukesha 1.7042 GS/ Naioral gas compression engine 1232 HP
040
08WE0978.CN
Solar Saturn 50 (SoLoNOx) power generation SN: TED
041
08WE0919.CN
Solar Saturn 50 (SoLoNOx) power generation SN: TED
042
08WE0920
Amine unit w/ Thermal oxidizer, model & SN: TBD
043
08WE0921
Two Amine regeneration heaters, model & SNs: TBD
Permitted Facility Total
Flare
Facility Total
Without 031
Project emissions for points 029-033
5.8
0.01
5.81
5.81
5.8
0.01
5.81
5.81
0.0
0.1
0.00 0.14
0.00 0.14
248.5
1.4
249.86
225.64
113.0
20.1
133.08
130.96
5.8
0.01
5.81
5.81
10.2
10.20
10.20
250.9
6.0
256.84
229.86
Based on 2009 Inspection report, Points 014, 015, 017-019, 024, 025, 029-033 were on site
in 2008
actual startup date of 6/26/2006
Exemption letter issued 4/2006
Based on 2011 Inspection report, Point 031 was never installed.
07WE0021 initial permit Issued 10/4/2007, actual startup 1/23/2008, FA issued 7/21/2008
07WE0979 initial permit issued 11/5/2007, actual startup of 2/25/2008
1.0 1.0 0.0 0.0 105.8 41.6 1.0 0.0 108.1 Permit levels established prior to Nov 2007
emissions
POINT PERMIT Descriptio
Oases MI7aIJI•Wt1UU,
TSP
197.ItIAJI
PM70
16Wt1.3UI
625
05MUYS8,
502
Nos
VOC
PM25
Fug VOC
CO
Previous FACIUTY TOTAL
130
13.0
1.0
47.1
238.2
149.7
13.0
34,8
301.0
Prevk,us Pamited Pacify total
12.7
12.7
1.0
47.0
234.8
145.8
12.7
34.8
297.6
5.;417062
i'in.,).ESHA
L.7042GS! ?I00HP
U?2
t.'af Us.)
0/03
R:WE077
Y:1,' Enit4135':'.,,U
4509P
00.;
00;44733.1
147,02' SHA
1-]04264! .70'2(2
C4'5
Af,f use,:
I
WI,
all, 047'
V,=,L'hl !44)
704.^.651 Y Y(r'i!.ic
008
031177,18,
NC CLYDEHI'
10.5EESc,'D
k11412:6
U! V ES'!?4
L.7042,SE!': v%.?!"(+
110
176 41.8.`62
,4'40✓, Ni"
r-352713i142i!;;iP
!%617,7401
THREE i,'044
CCN2ENSATE TAIIKS
9E41E1.5
_`10001 COND.
TANK
,')
',,,141.:1'15.
3(1727):11. ;
ON!:!. 74.57
014
96WE905
Equipment
Leeks
10.2
015
99NE905
1232 HP Vj
0.8
0.8
0.0
23.8
11.9
0.8
23.8
016
982(8905
Waukesha
Erne (P002)
017
96017905
1232 HP V
0.8
0.8
0.0
23.8
11.9
08
23.8
018
9817/0905
1232 HP V
0.8
0.8
0.0
23.8
11.9
0.8
23.8
019
98W 8805
1232 HP lit
0.8
0.8
0.0
23.8
11.9
08
23.8
020
%44730 i
u . i!!,7 !24
MODEL 2 r-3.`12£ SN: 30,0.4,.
021
6,.L1£:ai:s
.. l,CC!.
o :UYDVA7:^NSYS,i'i4
'22
031',fO.l8E
70 '.4,SNA
43521GSi, SM': 583231
an
0.'.1.08040;
'0,o10c,+
'O,, Un,.
024
04WE130'
1232 HP VI
0.8
0.8
00
23.8
11.9
08
23.8
025
04WE130L1232
HP vi
0.8
0.8
00
23.8
11.9
a8
23.8
026
044iE12(E
04/0,00qapro,kntlesks
027
—
,Sv'q
of lh:s ga51:'r,2 SO) (4.m;.v,;:rop::ra::o, ,
02a
—
s
029
O5NE095i123211P,
0.8 0.8
0.0
23.8
11.9
0.8
23.8
030
0SNE095f
REGENCI
02 7 0.2
25
02
2.1
03,
",,E'('272,'i!c743,047n....,'
Si' S') .6<
032
07WE022'
WAUKESII��
1.0 1.0
28.5
14.3
1.0
283
033
O7WE097E
WAUKESI�
0097 0.9
26.]
13.3
09
26.7
034
04707:09,,'
!nrrarNer
63105] ALE! rnp.,, mil, 770 HP
0:1'5
4 121421'
C .1v
0%:08';'4LE ":atat3i,2as., n-,,
076
0041709!.
i' 4 tpii.l^)G3603
TALE.'OiUre! pess::owook) any'ono'.2370!+, 0
037
08417:20,2
t40,;,,,:ha
G5!A':,' ,t!(;:9:co: n,xoss.'c, 2(x.7!23::' £rI
ilk,'
1181571)::;1(7.2
,4741704^ri.Si
77118, goo ,x,ma"e::.:,.1'n ',Now 0232}!}'•
..^.;M
0810709,
Wa:sral,
,70,1' GSi Nolw'a!ua• cu!7an:::;-v1aryn'104 '?riP
0:0
0x70809 -it
Solo:S&turn
,S' (:I.CNi::rt )riwa•!anarolio„C"1' TED
040
?01,11..:1,a -E,
Sn4e. a!rsn
5,, (So:, N,.) P.,,,,'.2.,. ,t,
042
08WE092f
Amine unitv✓Thermal
oxidizer, model 83N: TBD 12.3
0.8
5.7
4.3
043
OBWE092'Txo
Amid
as]0.5]
2.6
0.4
0.5
5.1
Permitted Facility Total
Flare
Permitted Facility Total
Insig
Facility Total
Project total for amine unit
8.2
001
8.21
8.2 0.0
001
8.21
12.5
0.00 12.46
8.21 0.00 12.46
227.7 117.0
1.4 20.1
229.02 137.03
8.7
229.02 145.73
8.2
0.01
8.21
10.2 233.2
6.0
10.20 239.22
8.21 10.20
0.5 0.5 0.0 12.3 3.4 6.1 0.5 0.0 9.4
239.22
Based on 2011 Inspection report, Points 014, 015, 017019, 024,
025, 029, 030, 032, 033, 042, 043 were on site In 2010
Based on 2011 Inspection report, this unit commenced operation 11/23/2010
Based on 2011 Inspection report, this unit commenced operation 11/23/2010
v)PY
General APEN - Form APCD-200
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.
There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). 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:
101V5 0132 -
AIRS ID Number:
123 /0107/1(00
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
DCP Operating Company, LP
Site Name: Lucerne 1 Natural Gas Processing Plant
Site Location: 31495 Weld County Road 43
Lucerne, CO
Mailing
(Include Address:r de) 370 17th Street, Suite 2500
p
Portable Source
Home Base:
Denver, CO 80202
Site Location Weld
County:
NAICS or SIC Code: 1321
Contact Person: Marie Cameron
Phone Number: (303) 605-2029
E -Mail Address2: mecameron@dcpmidstream.com
I 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-200 - General APEN - Revision 3/2019
402001
ACOLORADO
Permit Number:
AIRS ID Number: 123 /0107/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source (check one below)
❑✓ STATIONARY source ❑ PORTABLE source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 O Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
❑ APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
Flare used as backup control device and
during maintenance and emergency situations
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: Lucerne 1 Plant Flare
Manufacturer: John Zink
Model No.: FTIP Indair KMI-I-12-H2
Company equipment Identification No.
(optional):
For existing sources, operation began on:
F-2
Serial No.: 9047896
2006
For new or reconstructed sources, the projected start-up date is:
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day days/week weeks/year
Seasonal use percentage: Dec -Feb: Mar -May:
Form APCD-200 - General APEN - Revision 3/2019
kin Aug: Sep -Nov:
COLORADO
2 oi,tk
Yi N4AU1i£ Fnviwnl:uw l
Permit Number:
AIRS ID Number: 123 /0107/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
coPy/
Section 4 - Processing/Manufacturing Information >:t Material Use
0 Check box if this information is not applicable to source or process
From what year is the actual annual amount?
Description
Design Process
Rate
(Specify Units)
Actual Annual
Amount
(Specify Units)
Requested Annual
Permit Limits
(Specify Units)
Finished
Product(s):
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40°27'22"N, 104°39'55"W
❑ Check box if the following information is not applicable to the source because emissions will not be emitted
from a stack. If this is the case, the rest of this section may remain blank.
Operator
Stack ID NO
Discharge Height;
Above Ground Level
� (Feet)
Temp
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec);
F-2
75
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
O Horizontal
o Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular Interior stack diameter (inches):
0 Upward with obstructing raincap
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-200 - General APEN - Revision 3/2019
COLORADO
3 o«s
Permit Number:
AIRS ID Number: 123 /0107/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Combustion Equipment £t Fuel Consumption Information
❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated
with this emission source)
Design Input Rate
(MMBTU/hr) '
Actual Annual Fuel Use
(Specify Units)
Requested Annual Permit Limits
(Specify Units)
0.16 (Pilot Only)
.5-ii?fMscf/yr (Waste/Purge Gas)
From what year is the actual annua fuel use data? N/A
Indicate the type of fuel used6:
❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF)
❑ Field Natural Gas Heating value: BTU/SCF
❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon)
❑ Propane (assumed fuel heating value of 2,300 BTU/SCF)
❑ Coal Heating value: BTU/lb Ash content: Sulfur content:
❑✓ Other (describe): Residue gas/Inlet gas/Propane Heating value (give units): 1,098/ 1,341/ 2,516
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes O No
nt AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment
Description
Overall Collection Efficiency
Overall Control Efficiency
(% reduction in emissions)
TSP (PM)
PMIo
PM2.5
SOX
NOX
CO
VOC
Flare
100%
95%
Other:
HAPs - Flare
100%
95%
Form APCD-200 - General APEN - Revision 3/2019
COLORADO
4 I /(7/� e� '�MP� �.i��tFi eth 6 F.1.ro 1
Permit Number:
AIRS ID Number: 123 /0107/
TSP (PM)
[Leave blank unless APCD has already assigned a permit /1 and AIRS ID]
From what year is the following reported actual annual emissions data?
N/A
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Uncontrolled
Emission
Factor
(Specify Units)
Emission
Factor
Source
(AP -42, Mfg.,
etc.)
Actual Annual Emissions .
Uncontrolled
(tons/year)
Controlled
(tons/year)
Uncontrolled
(tons/year)
Controlled?
(tons/year)
7.6 Ib/MMscf
AP -42
5.14E-03
5.14E-03
PMio
7.6 Ib/MMscf
AP -42
5.14E-03
5.14E-03
PM2.5
7.6 Ib/MMscf
AP -42
5.14E-03
5.14E-03
SOX
0.6 Ib/MMscf
AP -42
0.002
0.002
NO.
0.068 Ib/MMBtu
AP -42
•-030"l•�4
Co
0.310 Ib/MMBtu
AP -42
VOC
20,800 Ib/MMscf
Site -specific
�i;1.i 52
I
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Section 8 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
D✓ Yes ❑ No
in table to report the non -criteria pollutant (HAP) emissions from source:
CAS
Number
Chemical
Name
Overall
Control
EffiClency
Uncontrolled
Emission
Factor
(Specify Units)
Emission Factor
Source
(AP -42, Mfg., etc.)
Uncontrolled
Actual
Emissions
(lbs/year)
Controlled
Actual
Emissions 7
(lbs/year)
110543
n -Hexane
95%
286 Ib/MMscf
Site -specific
14-32; f,-:3
..74- l 22.
71432
Benzene
95%
51 Ib/MMscf
Site -specific
254'1,,5
43 7,-1
108883
Toluene
95%
58 lb/MMscf
Site -specific
-2BS-r -
14 Y?
7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Note: NCRP pollutants shown above are the requested PTE emissions of
NCRPs from the L1 flare F-2.
Form APCD-200 - General APEN - Revision 3/2019
COLORADO
5 I AV1 � . D,Z,
he.nn s t,,m;onmem
Permit Number:
AIRS ID Number: 123 /0107/
[Leave blank unless APCD has already assigned a permit It 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.
rla LnrmPilis7�
6/la kt
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:
✓0 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-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.Rov/cdphe/apcd
Form APCD-200 - General APEN - Revision 3/2019 6 I
COLORADO
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