HomeMy WebLinkAbout20173348.tiffCOLORADO
Department of Public
Health Er Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150O St
PO Box 758
Greeley, CO 80632
September 19, 2017
Dear Sir or Madam:
RECEIVED
SEP 2 5 2017
WELD COUNTY
COMMISSIONERS
On September 21, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for
DCP Operating Company, LP - Northstar Compressor Station. A copy of this public notice and the
public comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health a Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Clara Gonzales
Regards,
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
oblic
¢,view
1O/9/(7
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
CCtPLCmM/ TP), HL('3 T),
(k))C ERICH/s(Y1/C1,)
919511-/
2017-3348
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: DCP Operating Company, LP - Northstar Compressor Station - Weld County
Notice Period Begins: September 21, 2017
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: Northstar Compressor Station
Compressor Station
NE SEC 2 T6N R65W
Weld County
The proposed project or activity is as follows: Applicant proposes a new compressor station in the non -
attainment area. Compressor station included two compression turbines, a glycol natural gas dehydrator,
and hydrocarbon loadout activity.
The Division has determined that this permitting action is subject to public comment per Colorado
Regulation No. 3, Part B, Section III.C due to the following reason(s):
• permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section
III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area)
• the source is requesting a federally enforceable limit on the potential to emit in order to avoid other
requirements
The Division has made a preliminary determination of approval of the application.
A copy of the application, the Division's analysis, and a draft of Construction Permit 17WE0640 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. Any such comment must be submitted in writing to the following addressee:
Christopher Kester
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
cdphe.commentsapcd@state.co.us
1 I AV =a._ __ O
ontrol Division
Department of Public Health b Environment
Permit number:
Date issued:
Issued to:
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General
Description:
STRUCTION PERMIT
Issuance: 1
DCP Operating Company, LP
Northstar Compressor Station
123/9F41
NE SEC 2 T6N R65W
Weld County
Natural Gas Compressor Station
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control Description
TURB-1
001
One (1) Solar Taurus 70, Serial Number
(TBD), natural gas -fired, natural gas
compression turbine rated at 72.2
MMBtu/hr, and site rated at 8,534
horsepower at 11,575 RPM.
None
TURB-2
002
One (1) Solar Taurus 70, Serial Number
(TBD), natural gas -fired, natural gas
compression turbine rated at 72.2
MMBtu/hr, and site rated at 8,534
horsepower at 11,575 RPM.
None
D-1
003
One (1) Triethylene glycol (TEG)
natural gas dehydration unit (Make:
TBD, Model: TBD, Serial Number: TBD)
with a design capacity of 130 MMscf per
day. This emissions unit is equipped
with 2 (Make: TBD, Model: TBD)
electric driven glycol pump with a
design capacity of 40 gallons per
minute. This dehydration unit is
equipped with a still vent, flash tank,
and reboiler burner.
Emissions from the still vent are
routed to an air-cooled
condenser, and then to the
Enclosed Combustor. Emissions
from the flash tank are routed
back to the inlet via the vapor
recovery unit (VRU). As a
secondary control device and
during VRU downtime, flash
tank emissions are routed to the
Enclosed Combustor.
L-1
004
Pressurized condensate tank truck
loadout
None
COLORADO
Air Pollution Control Division
Page 1 of 21
y be replaced with another Solar Taurus 70 turbine in
por tuL ine replacement provision or with another Solar Taurus 70 in
accordance wi t e permanen rep acement provision of the Alternate Operating Scenario (AOS),
included in this permit as Attachment A.
Point 003: The glycol pump may be replaced with another pump of the same design capacity in
accordance with the provisions of the Alternate Operating Scenario (AOS) included in this permit
as Attachment
This permit is granted su•-ct to all rules and regulations of the Colorado Air Quality Control Commission
and the Colorado Air Poll on Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general
terms and conditions in = and 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. The Notice of Startup form may be downloaded online at
https://www.colorado.gov/pacific/cdphe/other-air-permitting-notices. Failure to notify the
Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC)
Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance
of this permit. Compliance with the conditions contained in this permit shall be demonstrated to
the Division. It is the owner or operator's responsibility to self -certify compliance with the
conditions. Failure to demonstrate compliance within 180 days may result in revocation of the
permit. (Reference: Regulation No. 3, Part B, III.G.2).
3. This permit shall expire if the owner or operator of the source for which this permit was issued:
(i) does not commence construction/modification or operation of this source within 18 months
after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit; (ii) discontinues construction for a period of eighteen months or
more; (iii) does not complete construction within a reasonable time of the estimated completion
date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b.
(Reference: Regulation No. 3, Part B, III.F.4.)
4. The operator shall complete all initial compliance testing and sampling as required in this permit
and submit the results to the Division as part of the self -certification process. (Reference:
Regulation No. 3, Part B, Section III.E.)
5. The following information shall be provided to the Division within fifteen (15) days of the latter
of commencement of operation or issuance of this permit.
• Points 001 £t 002: Serial number
• Point 003: The dehydrator manufacturer name, model number and serial number
• Point 003: The glycol circulation pump manufacturer name and model number
This information shall be included with the Notice of Startup submitted for the equipment.
(Reference: Regulation No. 3, Part B, III.E.)
6. The operator shall retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
COLORADO
Air Pollution Control Division
Page 2 of 21
EMISSI
ND
7. ant exceed the following limitations (as calculated in the
Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4)
Monthly Limits:
Facilit,,
Equipme `` I
TURB-2
AIRS
Point
Pounds per Month
PM2.5
NO,
V0C
CO
Emission Type
001
357
2,940
3,266
Point
002
357
2,940
3,266
D-1
003
476
7,890
2,158
L-1
004
374
Note: Monthly limits are based on a 31 -day month.
The owner or operator shall calculate monthly emissions based on the calendar month.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds
per month.
Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per
month.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
Annual Limits:
Facility
Equipment ID
AIRS
Point
Tons per Year
Emission Type
pM2.5
NO),
V0C
CO
TURB-1
001
2.1
17.3
---
19.3
Point
TURB-2
002
2.1
17.3
---
19.3
Point
D-1
003
---
2.8
46.4
12.7
Point
L-1
004
---
---
2.2
---
Point
See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per
year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
During the first twelve (12) months of operation, compliance with both the monthly and annual
emission limitations is required. After the first twelve (12) months of operation, compliance
with only the annual limitation is required.
Compliance with the annual limits, for criteria and hazardous air pollutants, shall be determined
on a rolling twelve (12) month total. By the end of each month a new twelve month total is
calculated based on the previous twelve months' data. The permit holder shall calculate actual
emissions each month and keep a compliance record on site or at a local field office with site
responsibility for Division review.
COLORADO
Air Pollution Control Division
Page 3 of 21
8. ,:,'omt i 3 ` •lion ° the i sion limits in this permit shall be demonstrated by running
or higher on a monthly basis using the most recent extended
wet gas ana ysis anrecor:e• operational values, including: gas throughput, lean glycol
recirculation rate, enclosed combustion device (ECD) downtime, vapor recovery unit (VRU)
downtime, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet
pressure. Recorded operational values, except for gas throughput, shall be averaged on a
monthly basis into the model and be provided to the Division upon request.
9. The owner or op ator shall operate and maintain the emission points in the table below as a
closed loop syst r! and shall recycle 100% of emissions as described in the table below.
(Regulation NumeA9r 3, Part B, Section III.E.)
Facility
Equipment ID
AIRS
Point
Emissions Recycling Description
Pollutants
Recovered
D-1
003
Flash Tank: Recycled to Plant Inlet with a VRU
(except during VRU downtime - up to 5% downtime
annually)
VOC and
HAP
10. The owner or operator shall operate and maintain the emission points in the table below with
the emissions control equipment as listed in order to reduce emissions to less than or equal to
the limits established in this permit. The owner or operator shall operate this dehydration unit
so as to prevent any emissions directly to the atmosphere except as authorized below.
(Regulation Number 3, Part B, Section III. E. )
Facility
Equipment ID
AIRS
Point
Control Device
Pollutants
Controlled
D-1
003
Still Vent: Enclosed Combustor (except during
enclosed combustor downtime - up to 3% downtime
annually)
VOC and
HAP
Flash Tank: Enclosed Combustor (during VRU
downtime - up to 5% downtime annually)
VOC and
HAP
COLORADO
Air Pollution Control Division
Page 4 of 21
ours � a it [lowing maximum processing rates as listed below. Monthly
records of the actual processing rate shall be maintained by the owner or operator and made
available to the Division for inspection upon request. (Reference: Regulation 3, Part B,
Process/Consumption Limits
Facility'
Equipment
ID
IRS
-'pint
Process Parameter
Annual Limit
Monthly Limit
TURB-1
001
Consumption of natural gas
as a fuel
619 MMscf
53 MMscf
TURB-2
002
Consumption of natural gas
as a fuel
619 MMscf
53 MMscf
D-1
003
Natural Gas Processed
47,450 MMscf
4,030 MMscf
Natural gas processed while
still vent emissions routed to
atmosphere
1,424 MMscf
---
Natural gas processed while
flash tank emissions routed
to enclosed combustor
2,373 MMscf
---
L-1
004
Pressurized loadout events
4,286 loadouts
365 loadouts
The owner or operator shall calculate monthly process rates based on the calendar month.
During the first twelve (12) months of operation, compliance with both the monthly and annual
throughput limitations is required. After the first twelve (12) months of operation, compliance
with only the annual limitation is required.
Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month
total. By the end of each month a new twelve-month total is calculated based on the previous
twelve months' data. The permit holder shall calculate throughput each month and keep a
compliance record on site or at a local field office with site responsibility, for Division review.
12. Point 003: This unit shall be limited to the maximum lean glycol circulation rate of 40 gallons
per minute. The lean glycol recirculation rate shall be recorded weekly in a log maintained on
site and made available to the Division for inspection upon request. Glycol recirculation rate
shall be monitored by one of the following methods: assuming maximum design pump rate, using
glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This
maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation
rate (Lops) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4)
13. Point 003: On a monthly basis, the owner or operator shall monitor and record operational values
including: ECD downtime, VRU downtime, flash tank temperature and pressure, wet gas inlet
temperature and pressure. These records shall be maintained for a period of five years.
STATE AND FEDERAL REGULATORY REQUIREMENTS
14. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject
equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only
enforceable)
15. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the
source. During periods of startup, process modification, or adjustment of control equipment
visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive
COLORADO
Air Pollution Control Division
Page 5 of 21
ject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall
e: Regulation No. 1, Section II.A.1. a 4.)
16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable)
17. Points 001 Et 002: This source is subject to the Particulate Matter and Sulfur Dioxide Emission
Regulations of Regulation 1 including, but not limited to, the following(Regulation 1, Section
III.A.1)::
a. No ovine:__ ?r operator shall cause or permit to be emitted into the atmosphere from any
fuel -bur g equipment, particulate matter in the flue gases which exceeds the following
(Regulati 1, Section III.A.1)::
(i)
For fuel burning equipment with designed heat inputs greater than 1x106 BTU
per hour, but less than or equal to 500x106 BTU per hour, the following equation
will be used to determine the allowable particulate emission limitation.
PE=0.5(FI )_0.26
Where:
PE = Particulate Emission in Pounds per million BTU heat input.
Fl = Fuel Input in Million BTU per hour.
(ii) If two (2) or more fuel burning units connect to any opening, the maximum
allowable emission rate shall be calculated on a lb/ hour basis as calculated from
a weighted average of the individual allowable limits for each unit ducting to the
common stack.
b. Emissions of sulfur dioxide shall not emit sulfur dioxide in excess of the following
combustion turbine limitations. (Heat input rates shall be the manufacturer's
guaranteed maximum heat input rates).
New sources (Regulation 1, Section VI.B.4.c):
(i) Combustion Turbines with a heat input of less than 250 Million BTU per hour:
0.8 pounds of sulfur dioxide per million BTU of heat input.
18. Points 001 Et 002: This source is subject to the New Source Performance Standards requirements
of Regulation 6, Part B including, but not limited to, the following (Regulation 6, Part B, Section
II)
a. Standard for Particulate Matter - On and after the date on which the required
performance test is completed, no owner or operator subject to the provisions of this
regulation may discharge, or cause the discharge into the atmosphere of any particulate
matter which is:
(i )
For fuel burning equipment generating greater than one million but less than 250
million Btu per hour heat input, the following equation will be used to determine
the allowable particulate emission limitation:
PE=0.5(FI)-0.26
Where:
PE is the allowable particulate emission in pounds per million Btu heat input.
Fl is the fuel input in million Btu per hour.
If two or more units connect to any opening, the maximum allowable emission
rate shall be the sum of the individual emission rates.
(ii) Greater than 20 percent opacity.
b. Standard for Sulfur Dioxide - On and after the date on which the required performance
test is competed, no owner or operator subject to the provisions of this regulation may
discharge, or cause the discharge into the atmosphere sulfur dioxide in excess of:
(i) Sources with a heat input of less than 250 million Btu per hour: 0.8 lbs.
S02/ million Btu.
COLORADO
Air Pollution Control Division
Page 6 of 21
19. •oint +0 +02•mb f•=` turbines are subject to the New Source Performance
of •ul on No. 6, Part A, Subpart KKKK, Standards of Performance for
emu:,
ationary ombus ion Tur.Ines inc uding, but not limited to, the following:
• 40 CFR, Part 60, Subpart A - General Provisions
• §60.4320 - Nitrogen Oxide Emissions Limits
o ) - NOx emissions shall not exceed 25 ppm at 15% O2 or 1.2 lb/MW-hr;
• §60.4330 - S fur Dioxide Emissions Limits
o §60. 30 (a)(1) - SO2 emissions shall not exceed 0.9 lb/MW-hr gross output; or
o §6 + (a)(2) - Operator shall not burn any fuel that contains total potential sulfur
emissions in excess of 0.060 lb SO2/MMBtu heat input.
• §60.4333 - General Requirements
o §60.4333 (a) - Operator must operate and maintain your stationary combustion
turbine, air pollution control equipment, and monitoring equipment in a manner
consistent with good air pollution control practices for minimizing emissions at all
times including during startup, shutdown and malfunction.
• §60.4340 - NO, Monitoring
o §60.4340 (a) - Operator shall perform annual performance tests in accordance with
§60.4400 to demonstrate continuous compliance with NOX emissions limits. If the
NOX emission result from the performance test is less than or equal to 75 percent of
the NOX emission limit for the turbine, you may reduce the frequency of subsequent
performance tests to once every 2 years (no more than 26 calendar months following
the previous performance test). If the results of any subsequent performance test
exceed 75 percent of the NOX emission limit for the turbine, you must resume annual
performance tests.
• §60.4365 (or §S60.4360 and 60.4370) - 5O2 Monitoring
o The operator shall comply with §60.4365 or with both §§60.4360 and 60.4370 to
demonstrate compliance with SO2 emissions limits.
• §60.4375 - Reporting
o §60.4375 (b) - For each affected unit that performs annual performance tests in
accordance with §60.4340(a), you must submit a written report of the results of each
performance test before the close of business on the 60th day following the
completion of the performance test.
• §S60.4400 and 60.4415 - Performance Tests
o Annual tests must be conducted in accordance with §60.4400(a) and (b).
o Unless operator chooses to comply with §60.4365 for exemption of monitoring the
total sulfur content of the fuel, then initial and subsequent performance tests for
sulfur shall be conducted according to §60.4415.
20. Point 003: During VRU downtime, operator shall reduce uncontrolled VOC emissions from the
flash tank by at least 95 percent through the use of an enclosed combustor.
21. Point 003: This source is subject to Regulation Number 7, Section XII.H. The operator shall
comply with all applicable requirements of Section XII and, specifically, shall:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for glycol natural gas dehydrators; and
COLORADO
Air Pollution Control Division
Page 7 of 21
any
present, s all •e
through the use of a
7, Section XII.H.1.)
missions of volatile organic compounds from the still vent
densate-glycol (GCG) separator (flash separator or flash tank),
re•uced by at least 90 percent on a rolling twelve-month basis
condenser or air pollution control equipment. (Regulation Number
22. Point 003: The combustion device covered by this permit is subject to Regulation Number 7,
Section XVII - I Provisions (State only enforceable). If a flare or other combustion device
is used to contro-missions of volatile organic compounds to comply with Section XVII, it shall
be enclosed; ha no visible emissions during normal operations, as defined under Regulation
Number 7, XVII. • 6; and be designed so that an observer can, by means of visual observation
from the outsithe enclosed flare or combustion device, or by other convenient means
approved by the Division, determine whether it is operating properly. This flare must be equipped
with an operational auto -igniter according to the following schedule:
• All combustion devices installed on or after May 1, 2014, must be equipped with an
operational auto -igniter upon installation of the combustion device;
• All combustion devices installed before May 1, 2014, must be equipped with an
operational auto -igniter by or before May 1, 2016, or after the next combustion device
planned shutdown, whichever comes first.
23. Point 003: The glycol dehydration unit covered by this permit is subject to the emission control
requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and
vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil
and gas exploration and production operation, natural gas compressor station, or gas -processing
plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled
actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use
of a condenser or air pollution control equipment.
24. Point 003: The glycol dehydration unit at this facility is subject to National Emissions Standards
for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities,
Subpart HH. This facility shall be subject to applicable area source provisions of this regulation,
as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and
HH)
COLORADO
Air Pollution Control Division
Page 8 of 21
T HH .pli.le
m
Area Source
Outside UA/UC boundary
§63.760 - Applicability and
designation of affected
source
§63.760 (f) - The owner or operator of an affected major source shall achieve compliance
with the provisions of this subpart by the dates specified in paragraphs (f)(1) and (f)(2) of
this section. The owner or operator of an affected area source shall achieve compliance
with the provisions of this subpart by the dates specified in paragraphs (f)(3) through (f)(6)
his section.
§63.764 - General Standards
§ .764 (d)(2) -Each owner or operator of an area source not located in a UA plus offset
and UC boundary (as defined in §63.761) shall comply with the provisions specified in
paragraphs (d)(2(i) through (iii) of this section.
63.764 (d)(2)(i) - Determine the optimum glycol circulation rate using the following
equation:
LOP,=L15*3.0gal TEG*(F*(I-O)�
1bH2O 24hr/day)
Where:
LOPT = Optimal circulation rate, gal/hr.
F = Gas flowrate (MMSCF/D)
I = Inlet water content (lb/MMSCF)
0 = Outlet water content (lb/MMSCF)
3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/lbH2O)
1.15 = Adjustment factor included for a margin of safety.
§63.764 (d)(2)(ii) - Operate the TEG dehydration unit such that the actual glycol
circulation rate does not exceed the optimum glycol circulation rate determined in
accordance with paragraph (d)(2)(i) of this section. If the TEG dehydration unit is unable
to meet the sales gas specification for moisture content using the glycol circulation rate
determined in accordance with paragraph (d)(2)(i), the owner or operator must calculate
an alternate circulation rate using GRI-GLYCalcTM, Version 3.0 or higher. The owner or
operator must document why the TEG dehydration unit must be operated using the
alternate circulation rate and submit this documentation with the initial notification in
accordance with §63.775(c)(7).
§63.764 (d)(2)(iii) - Maintain a record of the determination specified in paragraph
(d)(2)(ii) in accordance with the requirements in 563.774(f) and submit the Initial
Notification in accordance with the requirements in §63.775(c)(7). If operating conditions
change and a modification to the optimum glycol circulation rate is required, the owner or
operator shall prepare a new determination in accordance with paragraph (d)(2)(i) or (ii)
of this section and submit the information specified under §63.775(c)(7)(ii) through (v).
§63.774 - Recordkeeping
Requirements
§63.774 (b) - Except as specified in paragraphs (c), (d), and (f) of this section, each owner
or operator of a facility subject to this subpart shall maintain the records specified in
paragraphs (b)(1) through (11) of this section §63.774 (b)(1)
§63.774 (b)(1) - The owner or operator of an affected source subject to the provisions of
this subpart shall maintain files of all information (including all reports and notifications)
required by this subpart. The files shall be retained for at least 5 years following the date
of each occurrence, measurement, maintenance, corrective action, report or period.
§63.774 (b)(1)(i) - All applicable records shall be maintained in such a manner that they
can be readily accessed.
§63.774 (b)(1)(ii) - The most recent 12 months of records shall be retained on site or shall
be accessible from a central location by computer or other means that provides access
within 2 hours after a request.
§63.774 (b)(1)(iii) - The remaining 4 years of records may be retained offsite.
§63.774 (b)(1)(iv) - Records may be maintained in hard copy or computer -readable form
including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape,
or microfiche.
§63.774 (f) - The owner or operator of an area source not located within a UA plus offset
and UC boundary must keep a record of the calculation used to determine the optimum
glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as
applicable.
COLORADO
Mr Pollution Control Division
Page 9 of 21
T HH %pli ble
Area Source
x.ate r rn Tns
Outside UA/UC boundary
§63.775 (c) - Except as provided in paragraph (c)(8), each owner or operator of an area
source subject to this subpart shall submit the information listed in paragraph (c)(1) of this
section. If the source is located within a UA plus offset and UC boundary, the owner or
operator shall also submit the information listed in paragraphs (c)(2) through (6) of this
:< ..
- tion. If the source is not located within any UA plus offset and UC boundaries, the
oner or operator shall also submit the information listed within paragraph (c)(7).
§63.775 (c)(1) - The initial notifications required under §63.9(b)(2) not later than January
3, 2008. In addition to submitting your initial notification to the addressees specified
under §63.9(a), you must also submit a copy of the initial notification to EPA's Office of Air
quality Planning and Standards. Send your notification via e-mail to CCG-ONG®EPA.GOV or
via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs
Division/Coatings and Chemicals Group (E143-01), Attn: Oil and Gas Project Leader,
Research Triangle Park, NC 27711.
§63.775 (c)(7) - The information listed in paragraphs (c)(1)(i) through (v) of this section.
This information shall be submitted with the initial notification.
§63.775 (c)(7)(i) - Documentation of the source's location relative to the nearest UA plus
offset and UC boundaries. This information shall include the latitude and longitude of the
affected source; whether the source is located in an urban cluster with 10,000 people or
more; the distance in miles to the nearest urbanized area boundary if the source is not
located in an urban cluster with 10,000 people or more; and the names of the nearest
urban cluster with 10,000 people or more and nearest urbanized area.
§63.775 (c)(7)(ii) - Calculation of the optimum glycol circulation rate determined in
accordance with §63.764(d)(2)(i).
§63.775 - Reporting
§63.775 c 7 m If applicable, documentation of the alternate glycol circulation rate
( ) pp g y
Requirements
calculated using GRI-GLYCalcTM, Version 3.0 or higher and documentation stating why the
using
TEG dehydration unit must operate using the alternate glycol circulation rate.
§63.775 (c)(7)(iv) - The name of the manufacturer and the model number of the glycol
circulation pump(s) in operation.
§63.775 (c)(7)(v) - Statement by a responsible official, with that official's name, title, and
signature, certifying that the facility will always operate the glycol dehydration unit using
the optimum circulation rate determined in accordance with §63.764(d)(2)(i) or
§63.764(d)(2)(ii), as applicable.
§63.775 (f) - Notification of process change. Whenever a process change is made, or a
change in any of the information submitted in the Notification of Compliance Status
Report, the owner or operator shall submit a report within 180 days after the process
change is made or as a part of the next Periodic Report as required under paragraph (e) of
this section, whichever is sooner. The report shall include:
§63.775 (f)(1) - A brief description of the process change;
§63.775 (f)(2) - A description of any modification to standard procedures or quality
assurance procedures
§63.775 (f)(3) - Revisions to any of the information reported in the original Notification of
Compliance Status Report under paragraph (d) of this section; and
§63.775 (f)(4) - Information required by the Notification of Compliance Status Report
under paragraph (d) of this section for changes involving the addition of processes or
equipment.
25. Point 004: This source is located in an ozone non -attainment or attainment -maintenance area
and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation
Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by loading from
a pressurized tank to a pressurized tank truck. (Reference: Regulation 3, Part B, TILE)
COLORADO
Air Pollution Control Division
Page 10 of 21
26. ading operations, regardless of size, shall be designed,
ned . a o minimize leakage of volatile organic compounds to the
a mosphere o t e maximum ex en practicable.
OPERATING a MAINTENANCE REQUIREMENTS
27. Point 003: Uson startup of this point, the owner or operator shall follow the most recent
operating an, .-,ance (OEM) plan and record keeping format approved by the Division, in
order to demons ate compliance on an ongoing basis with the requirements of this permit.
Revisions to your . M plan are subject to Division approval prior to implementation. (Reference:
Regulation No. 3, part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
28. Points 001 Et 002: These turbines are subject to the initial testing requirements of 40 C.F.R.
Part 60, Subpart KKKK as referenced in this permit.
29. Point 003: The owner or operator shall complete the initial extended wet gas analysis within
one hundred and eighty days (180) of the latter of commencement of operation or issuance of
this permit. The owner or operator shall use this analysis to calculate actual emissions, as
prescribed in the Emission Limitation and Records section of this permit, to verify initial
compliance with the emission limits. The owner or operator shall submit the analysis and the
emission calculation results to the Division as part of the self -certification process. (Reference:
Regulation Number 3, Part B, Section III.E.)
Periodic Testing Requirements
30. Points 001 ft 002: This turbine is subject to the periodic testing requirements of 40 C.F.R. Part
60, Subpart KKKK as referenced in this permit.
31. Points 001 a 002: The operator shall conduct, at a minimum, annual portable analyzer
monitoring of the turbine exhaust outlet emissions of nitrogen oxides (NOx) and carbon monoxide
(CO) to monitor compliance with the emissions limits. Results of all tests conducted shall be
kept on site and made available to the Division upon request.
32. Point 003: The owner or operator shall complete an extended wet gas analysis prior to the inlet
of the dehydration unit on an annual basis. Results of the wet gas analysis shall be used to
calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be
provided to the Division upon request.
ADDITIONAL REQUIREMENTS
33. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.)
• Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five
(5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone
nonattainment areas emitting less than 100 tons of VOC or NOx per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
COLORADO
Air Pollution Control Division
Page 11 of 21
s per year or more, a change in actual emissions of five
or more, whichever is less, above the level reported on the
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level = on the last APEN submitted to the Division.
• Wheneve here is a change in the owner or operator of any facility, process, or activity;
or
• Whene -w control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
GENERAL TERMS AND CONDITIONS
34. 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.
35. 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 M.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.
36. 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.
37. 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.
38. Each and every condition of this permit is a material part hereof and is not severable. Any
challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and
upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked
at any time prior to self -certification and final authorization by the Air Pollution Control Division
(APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air
Quality Control Commission (AQCC), including failure to meet any express term or condition of
the permit. If the Division denies a permit, conditions imposed upon a permit are contested by
the owner or operator, or the Division revokes a permit, the owner or operator of a source may
request a hearing before the AQCC for review of the Division's action.
39. 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.
'COLORADO
Air Pollution Control Division
Page 12 of 21
40. o of the provisions of the Colorado Air Pollution Prevention
of the AQCC may result in administrative, civil or criminal
en orcemen ac ions under ec ions 25-7-115 (enforcement), -121 (injunctions), -122 (civil
penalties), -122.1 (criminal penalties), C.R.S.
By:
Christop Po r Kester
Permit E a ineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to DCP Operating Company, LP
COLORADO
Air Pollution Control Division
Page 13 of 21
Notes Per H • + t th +f th p: mit issuance:
1) T . - t h for the processing time for this permit. An invoice for these
fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days
of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit.
(Regulation Number 3, Part A, Section VI.B.)
2) The production
based on the co
upon request of the
control regulation or
and complete appli
terial processing limits and emission limits contained in this permit are
io rates requested in the permit application. These limits may be revised
ner or operator providing there is no exceedance of any specific emission
y ambient air quality standard. A revised air pollution emission notice (APEN)
form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of
any malfunction condition which causes a violation of any emission limit or limits stated in this permit
as soon as possible, but no later than noon of the next working day, followed by written notice to
the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation.
See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process
limits as indicated in this permit. This information is listed to inform the operator of the Division's
analysis of the specific compounds emitted if the source(s) operate at the permitted limitations.
Facility
Equipment ID
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(Ib/yr)
Controlled
Emissions
(lb/yr)
TURB-1
001
Formaldehyde
50000
449
449
TURB-2
002
Formaldehyde
50000
449
449
D-1
003
Benzene
71432
175,890
13,677
Toluene
108883
162,435
12,679
Ethylbenzene
100414
4,570
358
Xylenes
1330207
45,428
' 3,559
n -Hexane
110543
36,213
2,164
2,2,4-
Trimethylpentane
540841
224
14
L-1
004
n -Hexane
110543
289
289
Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 0.125 tons
per year (tpy) are reportable and may result in annual emission fees based on the most recent Air Pollution
Emission Notice.
COLORADO
Air Pollution Control Division
Page 14 of 21
mit are based on the following emission factors:
CAS
Pollutant
Emission Factors
(lb/MMBtu)
- Uncontrolled
Source
PM2.5
0.0066
AP -42
0.055
Manufacturer
0.061
Manufacturer plus safety factor
0.002
AP -42
50000
Forma.=ehyde
0.00071
AP -42
Emission factors awe based on a Brake -Specific Fuel Consumption Factor (Higher Heating Value)
of 8461 Btu/hp-hr, a site -rated horsepower value of 8534 HP and a fuel heat value of 1023
Btu/scf.
Point 003:
The emission levels contained in this permit are based on information provided in the application
and the GRI GlyCalc 4.0 model. Controlled emissions are based on a combustor control efficiency of
95%.
Total actual flash tank and still vent combustion emissions are based on the sum of the emissions for
the still vent primary control, flash tank secondary control, pilot gas combustion, and assist gas
combustion. Total combustion emissions are based on the following emission factors:
Still Vent Primary Control:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMBtu Waste
Gas Combusted
Source
NOx
0.068
AP -42 Chapter 13.5 Industrial
Flares
CO
0.31
Note: The combustion emission factors are based on a heating value of 300 Btu/scf. Actual emissions are
calculated by multiplying the emission factors in the table above by the waste gas flow from the regenerator
overheads stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this
control device.
Flash Tank Secondary Control:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf Waste
Gas Combusted
Source
NOx
0.068
AP -42 Chapter 13.5 Industrial
Flares
CO
0.31
Note: The combustion emission factors are based on a heating value of 1468 Btu/scf. Actual emissions are
calculated by multiplying the emission factors in the table above by the waste gas flow from the flash tank off -gas
stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this control device.
COLORADO
Air Pollution Control Division
Page 15 of 21
The emission levels contained in this permit are based on the following emission factors:
CAS
Pollutant
Emission Factors
(lb/loadout)
- Uncontrolled
Source
1.0242
Engineering Calculation
110543
n -H ane
0.0675
Emission factors re based on liquid and vapor line volumes of 0.0218 ft^3/loadout venting
directly to the phere.
6) At the time of permit issuance, DCP has indicated that there is the following equipment and
activities located at the facility that is exempt from APEN reporting:
Equipment / Activity Description
1,000 gal Methanol Tank
200 gal Lube Oil Tank
1,000 gal Glycol Tank
80 bbl drain tank
2 - 60,000 gal pressurized condensate storage tanks
Turbine la Blowdown
Turbine 1b Blowdown
Turbine 2a Blowdown
Turbine 2b Blowdown
Turb-1 and Turb-2 Purges
Dehydrator Reboiler (H-1)
Pigging
Fugitive Component Leak Emissions
7) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to
the most recent annual fee invoice to determine the APEN expiration date for each emissions point
associated with this permit. For any questions regarding a specific expiration date call the Division
at (303)-692-3150.
8) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of:
VOC and HAP
NANSR
Synthetic Minor Source of:
VOC
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
COLORADO
Air Pollution Control Division
Page 16 of 21
NSPS
St d s oferf an for New Stationary Sources
60.1 -End
Subpart A - Subpart KKKK
NSPS
Part 60, Appendixes Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories
MACT
MACT
MACT
63.-6 9
Subpart A - Subpart Z
Subpart AA - Subpart DDD
63.12 .1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ- Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
ATTACHMENT A:
ALTERNATIVE OPERATING SCENARIOS
TURBINES WITHOUT CONTINUOUS EMISSIONS MONITORING
August 16, 2011
1. Routine Turbine Component Replacements
The following physical or operational changes to the turbines in this permit are not considered a modification
for purposes of NSPS GG, major stationary source NSR/PSD, or Regulation No. 3,
Part B. Note that the component replacement provisions apply ONLY to those turbines subject to NSPS GG.
Neither pre-GG turbines nor post GG turbines (i.e. KKKK turbines) can use those provisions.
1) Replacement of stator blades, turbine nozzles, turbine buckets, fuel nozzles, combustion chambers, seals,
and shaft packings, provided that they are of the same design as the original.
2) Changes in the type or grade of fuel used, if the original gas turbine installation, fuel nozzles, etc. were
designed for its use.
3) An increase in the hours of operation (unless limited by a permit condition)
4) Variations in operating loads within the engine design specification.
5) Any physical change constituting routine maintenance, repair, or replacement.
Turbines undergoing any of the above changes are subject to all federally applicable and state only requirements
set forth in this permit (including monitoring and record keeping). If replacement of any of the components
listed in (1) or (5) above results in a change in serial number for the turbine, a letter explaining the action as
well as a revised APEN and appropriate filing fee shall be submitted to the Division within 30 days of the
replacement.
Note that the repair or replacement of components must be of genuinely the same design. Except in accordance
with the Alternate Operating Scenario set forth below, the Division does not consider that this allows for the
entire replacement (or reconstruction) of an existing turbine with an identical new one or one similar in design
or function. Rather, the Division considers the repair or replacements to encompass the repair or replacement
of components at a turbine with the same (or functionally similar) components.
2. Alternative Operating Scenarios
COLORADO
Air Pollution Control Division
Page 17 of 21
n io (AOS) for the temporary and permanent replacement of
bine'. mp ` ents has been reviewed in accordance with the requirements of
n No. ar , io , v"ational Flexibility- Alternative Operating Scenarios, Regulation No.
3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and
Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural
requirements. This permit incorporates and shall be considered a Construction Permit for any turbine or turbine
component replacement performed in accordance with this AOS, and the owner or operator shall be allowed to
perform such turbine component replacement without applying for a revision to this permit or
obtaining a new Co "str io Permit.
2.1 Turbine Replaceme
The following As corporated into this permit in order to deal with a turbine breakdown or periodic
routine maintenance and repair of an existing onsite turbine that requires the use of a temporary
replacement turbine. "Temporary" is defined as in the same service for 90 operating days or less in any 12
month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12
month period. The 90 days is the total number of days that the turbine is in operation. If the turbine
operates only part of a day, that day shall count as a single day towards the 90 -day total. The compliance
demonstrations and any periodic monitoring required by this AOS are in addition to any compliance
demonstrations or periodic monitoring required by this permit.
Any permanent turbine replacement under this AOS shall result in the replacement turbine being considered
a new affected facility for purposes of NSPS and shall be subject to all applicable requirements of that
Subpart including, but not limited to, any required Performance Testing.
All replacement turbines are subject to all federally applicable and state -only requirements set forth in
this permit (including monitoring and record keeping).
The results of all tests and the associated calculations required by this AOS shall be submitted to the Division
within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate
compliance with the NSPS requirements. Results of all tests shall be kept on site for five (5) years and
made available to the Division upon request.
The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date
of any turbine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial
number of the turbine (s) that are replaced during the term of this permit, and the manufacturer, model
number, horsepower, and serial number of the replacement turbine.
2.1.1 The owner or operator may temporarily replace an existing turbine that is covered by this permit
with a turbine that is the exact same make and model as the existing turbine without modifying this
permit, so long as the temporary replacement turbine complies with the emission limitations for the
existing permitted turbine and other requirements applicable to the original turbine. Measurement
of emissions from the temporary replacement turbine shall be made as set forth in section 2.2.
2.1.2 The owner or operator may permanently replace the existing turbine that is covered by this permit
with a turbine that is the exact same make and model as the existing turbine without modifying this
permit so long as the permanent replacement turbine complies with the emission limitations and
other requirements applicable to the original turbine as well as any new applicable requirements for
the replacement turbine. Measurement of emissions from the temporary replacement turbine shall
be made as set forth in section 2.2.
2.1.3 An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial
number and horsepower of the permanent replacement turbine shall be filed with the Division for
the permanent replacement turbine within 14 calendar days of commencing operation of the
replacement turbine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover
letter explaining that the owner or operator is exercising an alternative operating scenario and is
installing a permanent replacement turbine. This AOS cannot be used for permanent turbine
replacement of a grandfathered or permit exempt turbine or a turbine that is not subject to emission
limits. The owner or operator shall agree to pay fees based on the normal permit processing rate
for review of information submitted to the Division in regard to any permanent turbine replacement.
COLORADO
Mr Pollution Control Division
Page 18 of 21
Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping
Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss
streamlining the testing requirements.
Note that the tes
specified by the p= mi
testing, this test condu
test is not required for
d by this Condition may be used to satisfy the periodic testing requirements
or e relevant time period (i.e. if the permit requires quarterly portable analyzer
d under the AOS will serve as the quarterly test and an additional portable analyzer
other three months).
The owner or operato conduct a reference method test, in lieu of the portable analyzer test required by
this Condition, if approved in advance by the Division.
The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust
from the replacement turbine using a portable flue gas analyzer within seven (7) calendar days of commencing
operation of the replacement turbine.
All portable analyzer testing required by this permit shall be conducted using the most current version of the
Division's Portable Analyzer Monitoring Protocol as found on the Division's website. Results of the portable
analyzer tests shall be used to monitor the compliance status of this unit.
For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the
tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year
(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test
results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies.
For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or
concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the replacement turbine
will be subject to, the results of the test shall be converted to the appropriate units as described in the above -
mentioned Portable Analyzer Monitoring Protocol document.
If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the
absence of credible evidence to the contrary, the source may certify that the turbine is in compliance with both
the NOX and CO emission limitations for the relevant time period.
Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the
portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the
turbine will be considered to be out of compliance from the date of the portable analyzer test until a portable
analyzer test indicates compliance with both the NOX and CO emission limitations or until the turbine is taken
offline.
2.3 Applicable Regulations for Permanent Turbine Replacements
2.3.1 NSPS for Stationary Gas Turbines: 40 CFR 60, Subpart GG
§60.330 Applicability and designation of affected facility.
(a) The provisions of this subpart are applicable to the following affected facilities: All stationary gas
turbines with a heat input at peak load equal to or greater than 10.7 gigajoules (10 million Btu) per hour,
based on the lower heating value of the fuel fired.
(b) Any facility under paragraph (a) of this section which commences construction, modification, or
reconstruction after October 3, 1977, is subject to the requirements of this part except as provided in
paragraphs (e) and (j) of §60.332.
A Subpart GG applicability determination as well as an analysis of applicable Subpart GG monitoring,
recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in
any request for a permanent turbine replacement
COLORADO
Air Pollution Control Division
Page 19 of 21
gation No. 6. Part B, Section I.B. that Relocation of a source from
the State of Colorado is considered to be a new source, subject to
req i.e., the date that the source is first relocated to Colorado becomes
equivalent to the commence construction date for purposes of determining the applicability of NSPS GG
requirements).
2.3.2 NSPS for Stationary Combustion Turbines: 40 CFR 60, Subpart KKKK
§60.4305 Do t su o+art apply to my stationary combustion turbine?
(a) If you are th- .wner or operator of a stationary combustion turbine with a heat input at peak load
equal to or grea than 10.7 gigajoules (10 MMBtu) per hour, based on the higher heating value of the
fuel, which co,A- ced construction, modification, or reconstruction after February 18, 2005, your
turbine is subject to this subpart. Only heat input to the combustion turbine should be included when
determining whether or not this subpart is applicable to your turbine. Any additional heat input to
associated heat recovery steam generators (HRSG) or duct burners should not be included when
determining your peak heat input. However, this subpart does apply to emissions from any associated
HRSG and duct burners.
(b) Stationary combustion turbines regulated under this subpart are exempt from the requirements of
subpart GG of this part. Heat recovery steam generators and duct burners regulated under this subpart
are exempted from the requirements of subparts Da, Db, and Dc of this part.
A Subpart KKKK applicability determination as well as an analysis of applicable Subpart KKKK monitoring,
recordkeeping, and reporting requirements for the permanent turbine replacement shall be included in
any request for a permanent turbine replacement
Note that under the provisions of Regulation No. 6. Part B, Section I.B. that Relocation of a source from
outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to
the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes
equivalent to the commence construction date for purposes of determining the applicability of NSPS KKKK
requirements).
2.4 Additional Sources
The replacement of an existing turbine with a new turbine is viewed by the Division as the installation of a new
emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced
construction permit review. The AOS cannot be used for additional new emission points for any site; a turbine
that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an
existing onsite turbine has to go through the appropriate Construction/Operating permitting process prior to
installation
ATTACHMENT B:
ALTERNATIVE OPERATING SCENARIO
GLYCOL PUMP
1. The dehydrator's gas -driven glycol pump may be replaced with another gas -driven glycol pump in
accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this
permit or obtaining a new construction permit. A replacement pump shall be the same capacity as authorized in this
permit.
COLORADO
Air Pollution Control Division
Page 20 of 21
2. The owner or operator shall maintain a log on -site or at a local field office to contemporaneously record
the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of
the replacement pump.
3. All pump replacements installed and operated per the alternate operating scenarios authorized by this
permit must comply with all terms and conditions of this construction permit.
COLORADO
Air Pollution Control Division
Page 21 of 21
Colorado Air Permitting Project
Project Details
Review Engineer:
Package 4:
Received Date:
Review Start Date:
Section 01- Facility Information
Christopher Kester
364278
6/8/2017
7/19/2017
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
Physical Address/Location:
Type of Facility:
What industry segment?
Is this facility located in a NAAQS non -attainment area? Ye
If yes, for what pollutant? carbon Monoxide (CO)
DCP Operating Company, LP
123
9F41,
Northstar Compressor Station
NE quadrant of Section 2, Township 6N, Range 65W, in Weld County, Colorado
Natural Gas Compressor Station
Oil & Natural. Gas Production & Processing,
Weld
Section 02 - Emissions Units In Permit Application
[Particulate Matter (PM)
Quadrant
Section
Township
Range
6N
Luzon (NOx & VOC)
AIRs Point #
Emissions Source Type
Equipment
Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
001
Turbine
TURB-1
No
17WE0640
1
Yes
Permit, Initial
Issuance
002
Turbine
TURB-2
No:
17WE0640
1
yes
Permit Initial
Issuance
003
TEGDehydrator
D 1
Yes
17WE0640
1
Yes" " -
Permit initial
=Issuan€e ,....:
004
Hydrocarbon Liquid Loading
L-1
No,;
17WE0640
1
Yes"
Permit irtial"':' Pressurized
issuance=.. -.,''Loading
005
Produced Water _ Tank
PW
No - ' _
17WE0641.XP
1
Nn " `
APEN Required<1% Crude by
/Permit volume
Exempt exemption
Section 03 - Description of Project
Applicant proposes a new synthetic minor compressor station in the non -attainment area.
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why?
Yes
Requesting Synthetic Minor Perini
Section 05 - Ambient Air Impact Analysis Requirements
Was a quantitative modeling analysis required?
If yes, for what pollutants?
Colorado Air Permitting Project
If yes, attach a copy of Technical Services Unit modeling results summary.
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor?
Is this stationary source a synthetic minor?
If yes, indicate programs and which pollutants:
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
No,
SO2 NOx CO VOC PM2.5 PM10 TSP HAPs
❑ ❑ ❑ ❑ ❑ ❑
❑ ❑ ❑ o O ❑ O o
❑ O
Is this stationary source a major source? No
If yes, explain what programs and which pollutants here: S02 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration (PSD) O O ❑ O O ❑
Title V Operating Permits (OP) O O O O O ❑ O O
Non -Attainment New Source Review (NANSR) ❑ O
0O1 - Turb 1 One (1) Solar Taurus 70, Serial Number (TBD), natural gas -fired, natural gas compression turbine, site
rated at 8,534 horsepower at 11,575 RPM.
Engine Information
berating
Mfg's Max. Rated Horsepower @ sea level:
8534
Horsepower used for calcuations:
8534
BSCF @ 100% Load (btu/hp-hr):
8461
Site - Rated BSCF @ 100% load (btu/hp-hr):
8461
Max hrs/yr of Operation' 8760
Calculations
Fuel Use Rate @ 100% Load
70582.8 scf/hr
MAX POTENTIAL Annual Fuel
Consumption
618.305 MMscf/yr
REQUESTED Annual Fuel
Consumption
618.305 MMscf/yr
Fuel Heating Value
1023 btu/scf
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
PM
0.00660
lb/MMBTU
0.007
Ib/MMBTU
2.1
tpy
2.1
tpy
SOx
0.00340
lb/MMBTU
0.003
Ib/MMBTU
1.1
tpy
1.1
tpy
NOx
0.21000
g/hp-hr
0.210
g/hp-hr
17.3
tpy
17.3
tpy
CO
0.23400
g/hp-hr
0.234
g/hp-hr
19.24
tpy
19.2
tpy
VOC
0.00210
lb/MMBTU
0.002
Ib/MMBTU
0.7
tpy
0.7
tpy
Formaldehyde
0.00071
Ib/MMBTU
0.001
Ib/MMBTU
449
lb/yr
449
lb/yr
Acetaldehyde
0.00004
lb/MMBTU
0.000
Ib/MMBTU
25
lb/yr
25
lb/yr
Acrolein
0.00001
lb/MMBTU
0.000
Ib/MMBTU
4
lb/yr
4
lb/yr
Benzene
0.00001
Ib/MMBTU
0.000
lb/MMBTU
8
lb/yr
8
lb/yr
NOx
CO
0.054603475
0.060843872
Ib/MMBTU
Ib/MMBTU
17WE0640.CP1.xlsm
Source
AP -42
AP -42
Manufacturer
Manufacturer with a safety factor
AP -42
AP -42
AP -42
AP -42
AP -42
17WE0640.CP1.xlsm
002 - Turb 2
One (1) Solar Taurus 70, Serial Number (TBD), natural gas -fired, natural gas compression turbine, site
rated at 8,534 horsepower at 11,575 RPM.
Engine Information
berating Mfg's Max. Rated Horsepower @ sea level:
8534
Horsepower used for calcuations:
8534
BSCF @ 100% Load (btu/hp-hr):
8461
Site - Rated BSCF @ 100% load (btu/hp-hr):
8461
Max hrs/yr of Operation I 8760
Calculations
Fuel Use Rate @ 100% Load
70582.8 scf/hr
MAX POTENTIAL Annual Fuel
Consumption
618.305 MMscf/yr
REQUESTED Annual Fuel
Consumption
618.305 MMscf/yr
Fuel Heating Value
1023 btu/scf
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
PM
0.00660
Ib/MMBTU
0.007
Ib/MMBTU
2.1
tpy
2.1
tpy
SOx
0.00340
Ib/MMBTU
0.003
lb/MMBTU
1.1
tpy
1.1
tpy
NOx
0.21000
g/hp-hr
0.210
g/hp-hr
17.3
tpy
17.3
tpy
CO
0.23500
g/hp-hr
0.235
g/hp-hr
19.3
tpy
19.3
tpy
VOC
0.00210
lb/MMBTU
0.002
lb/MMBTU
0.7
tpy
0.7
tpy
Formaldehyde
0.00071
lb/MMBTU
0.001
lb/MMBTU
449
lb/yr
449
lb/yr
Acetaldehyde
0.00004
Ib/MMBTU
0.000
Ib/MMBTU
25
lb/yr
25
lb/yr
Acrolein
0.00001
Ib/MMBTU
0.000
Ib/MMBTU
4
lb/yr
4
lb/yr
Benzene
0.00001
lb/MMBTU
0.000
lb/MMBTU
8
lb/yr
8
lb/yr
17WE0640.CP1.xlsm
Source
AP -42
AP -42
Manufacturer
Manufacturer with a safety factor
AP -42
AP -42
AP -42
AP -42
AP -42
17WE0640.CP1.xlsm
Glycol Dehydrator Emissions Inventory
Section 01 -Administrative Information
(Facility AIRs ID:
123
County
9F41
Plant
003...
Point
Section 02 - Equipment Description Details
Dehydrator Information
Dehydrator Type:
Make:
Model:
Serial Number:
Design Capacity:
Recirculation Pump Information
Number of Pumps
Pump Type
Make:
Model:
Design/Max Recirculation Rate:
Dehydrator Equipment
Flash Tank
Reboiler Burner
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
MMscf/day
gallons/minute
flash tank,
and reboiler burner
One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design
capacity of 130 MMscf per day. This emissions unit is equipped with 2 (Make: TBD, Model: TBD) electric driven glycol pump
with a design capacity of 40 gallons per minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler
burner.
Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash
tank are routed directly to the closed -loop system. Asa secondary control device, flash tank emissions are muted to the
Enclosed Flare .
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Dehydrator Still Vent and Flash Tank (if present)
Requested Permit Limit Throughput = 47,45O. MMscf per year
Potential to Emit (PTE( Throughput = 47,450 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
Still Vent Control
Condenser:
Condenser emission reduction claimed:
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Still Vent Gas Heating Value:
Still Vent Waste Gas Vent Rate:
Flash tank Control
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
8497.2 hr/yr
262.0 hr/yr
298. Btu/scf
9:325403scf r
438: hr/yr
1468. Btu/scf
2.92E+03. scfh
9
Control Efficiency %
(3% downtime)
Control Efficiency %
100% Control Efficiency %
(5% downtime)
95% Control Efficiency %
(5% uptime)
Wet Gas Processed:
Still Vent Primary Control: 46,026.5 MMscf/yr
Still Vent Secondary Control: 1,423.5 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 79.2 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Wet Gas Processed:
Flash Tank Primary Control: 45,077.5 MMscf/yr
Flash Tank Secondary Control: 2,372.5 MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 0.0 MMscf/yr
Flash Tank Secondary Control: 1.3 MMscf/yr
Glycol Dehydrator Emissions Inventory
Section 04 - Emissions Factors & Methodologies
Dehydrator
Thesourceused GRI Gtyealo 4.0 to estimate emissic
analysiscutlected on 11/4/2016
Input Parameters
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
STILL VENT
Control Scenano
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (Ib/br)
Controlled (lb/hr)
VOC
120.2186......
6.01093
120.2186
Benzene
18:0755
0.903775
18.0755
Toluene
.:16.719......
0.83795
16.759
Ethylbenzene
04720
0.02364
0.4728
Xylenes
4.7044
0.23522
4.7044
n -Hexane
.2.8316
0.14158
2.8316
224-TMP
00178
0.00089
0.0178
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (Ib/hr)
Controlled (lb/hr)
Controlled (Ib/hr)
VOC
.....81,385
0
4.06925
Benzene
0:1779
0
0.008895
Toluene
0.0981
0
0.004905
Ethylbenzene
0.0010
0
7.5E-05
Xylenes
-::0:01,
0
0.0005
n -Hexane
0.9265.,..
0
0.046325
224-TMP
::9.0084
0
0.00027
Emission Factors
Pollutant
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Glycol Dehydrator
Uncontrolled
(Ib/MMscf) (Ib/MMscf)
(Wet Gas
Throughput) (Wet Gas Throughput)
Controlled
40.94 1.96
3.706844308 0.288241597
.423288 0.267214048
0.096319385 0.00753792
0.957385846 0.07500045
0.763183385 0.0456104
0.004711385 0.00028610
Still Vent Primary Control Decks
Uncontrolled Uncontrolled
Emission Factor Source
Pollutant (Ib/MMBtu( (Ib/MMscf) Emission Factor Source
(Waste Heat
Combusted(
0.0075
PM2.5 0:0075.
NO 0.0680
CO 0.3100.
Pollutant
(Waste Gas
Combusted)
2.2204
2.2204
20.2640
92.3800
Still Vent Secondary Control Decke
Uncontrolled Uncontrolled
(Ib/MMBtu)
(Waste Heat
Combusted)
(Ib/MMscf(
(Waste Gas
Combusted(
Flash Tank Primary Control Device
Uncontrolled Uncontrolled
Section OS - Emissions Inventory
Did operator request a buffer?
Requested Buffer (%):
Emission Factor Source
Pollutant (Ib/MMBtu( (Ib/MMscf( Emission Factor Source
(Waste Heat
Combusted)
PM10 :.00000
(Waste Gas
Combusted)
Flash Tank Secondary Control Dev
Uncontrolled Uncontrolled
Pollutant (lb/MMBtu( (lb/MMscf(
(Waste Heat (Waste Gas
Combusted) Combusted(
PM10 >.... ::0:0075
PM2.5
NO
CO
0(00:
0.0680
0.3100::.
0.9380
10.9380
99.8240
455.0800
Emission Factor Source
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
PM10
PM2.5
Nox
CO
VOC
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
2.8
2.8
2.8
2.8
2.8
12.7
12.7
r 12.7
12.7
12.7
971.3
971.3
46.4
971.3
46.4
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/Year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(lb/yr) (lb/yr)
Glycol Dehydrator Emissions Inventory
Benzene
87.94
97.94
6.84
87.94
6.84
175890
13677
Toluene
11.22
81.22
6.34
81.22
6.34
162435
12679
Ethylbenzene
2.29
2.29
0.18
2.29
0.18
4570
358
Xylene
22.71
22.71
1.78
22.71
1.78
45428
3559
n -Hexane
18.11
18.11
1.08
18.11
1.08
36213
2164
224 TMP
0.11
0.11
0.01
0.11
0.01
224
14
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Section XVII.8,D
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, Part E, MACT Subpart FIB (Area)
Regulation 8, Part E, MACI' Subpart Fill (Major)
Regulation 8, Part E, MACT Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Dehydrator is subject to Regulation 7, Section XVII, B, D.3
The control device for this dehydrator is not subject to Regulation 7, Section 8011.8.2
Dehydrator is subject to Regulation 7, Section 011.6
Dehy is subject to area source MACT HO, per the requirements in 63.264)452)
You have indicated that this facility is not subject to Major Source requirements of N
You have indicated that this facility is not subject to MACT HHH.
Section 07 - Initial and Periodic Sampling and Testing Requirements
Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a
year of application submittal?
If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limits
Does the company request a control device efficiency greater than 95% fora flare or combustion device? y,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
Please nate that 48840:MMBtu/yrwas added to the combustion emissions from the pilot light:...
AIRS Point it
003
Section 09 - Inventory SCC Coding and Emissions Factors
Pollutant
PM10
PM2.5
NOx
VOC
CO
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Uncontrolled
Emissions Factor
0010/01
0DIV/01
0.117
40.9
0.534
3.707
3.423
0.096
0.957
0.763
0.005
Control %
0.0%
0.036
0.0%
9521.8%
0.0%
9222.4%
9219.4%
9217.4%
9216.6%
9402.4%
9391.9%
Glycol Dehydrator Emissions Inventory
Glycol Dehydrator Emissions Inventory
Glycol Dehydrator Emissions Inventory
Units
lb/MMscf
Ib/MMscf
Ib/MMscf
Ib/MMscf
lb/MMscf
lb/MMscf
Ib/MMscf
lb/MMscf
Ib/MMscf
lb/MMscf
Ib/MMscf
Dehydrator
Colorado Regul
ATTAINMENT
1. Are uncont
2. Are total fa
NON-ATTAINM
1. Are uncont
2. Are total fa
Colorado Regul
1. Is this glycc
2. Is this glycc
3. Is the sum t
4. Are actual t
Section XII.
MACT AnaIN
1. Is the dehyi
a.
b.
2. Is the dehyi
40 CFR, Part 63
Area Sourc
1. Is the dehyl
Exemption:
2a.
2b.
3. Is the unit I
Major Sour
1. Does the fa
Small or La
2a.
2b.
Small Dehy
3.
4.
40 CFR, Part 63
1 Is the facilit
Small or La
2a.
2b.
Small Dehy
3.
4.
Colorado Regul
1. Is the dehyi
2. Is this dehy
3. Is this deh'
4. Was this gl�
4a.
5. If construct
Section XVI
Section XVI
Alternative
6.
Regulatory Analysis Worksheet
ation 3 Parts A and B - APEN and Permit Requirements
You have indicated that source is in the Non -Attainment Area
rolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Pa
cility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TF
You have indicated that source is in the Non -Attainment Area
ENT
rolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, 5
cility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater th,
Source requires a permit
ation 7, Section XII.H
natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/r
natural gas dehydrator located at an oil and gas exploration and production operation', natural gas compressor
of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary
uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Re
IDehydrator is subject to Regulation 7, Section XII.H
H — Emission Reductions from glycol natural gas dehydrators
rsis
drator located at an oil and natural gas production facility that meets either of the following criteria:
A facility that processes, upgrades or stores hydrocarbon liquids" (63.760(a)(2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural
gas transmission and storage source category or is delivered to a final end user2 (63.760(a)(3))?
drator located at a facility that is a major source for HAPs?
Go to MACT HH Area Source Requirement section to determine MACT HH applicability
, Subpart MACT HH, Oil and Gas Production Facilities
e Requirements
drator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))?
s
Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per c
Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere
ocated inside of a UA plus offset and UC boundary area?
Dehy is subject to area source MACT HH, per the requirements in 63.764(d)(2)
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards Do Not Apply
§63.773 - Monitoring Standards Do Not Apply
§63.774 - Recordkeeping
§63.775 - Reporting
•ce Requirements
icility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility-
rge Dehy Determination
Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per d
Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere
Requirements
Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B)
For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation
'You have indicated that this facility is not subject to Major Source requirements of MACT HH.
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards
§63.773 - Monitoring
§63.774 - Record keeping
§63.775 - Reporting
, Subpart MACT HHH, Natural Gas Transmission and Storage Facilities
:y wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the
rge Dehy Determination
Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per c
Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere
Requirements
Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(2) and
For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicabl
You have indicated that this facility is not subject to MACT HHH.
Subpart A, General provisions per §63.1274 (a) Table 2
§63.1275 - Emissions Control Standards
§63.1281 -Control Equipment Standards
§63.1283 - Inspection and Monitoring
§63.1284 - Record keeping
§63.1285 - Reporting
ation 7, Section XVII.D
drator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)?
drator located at a transmission/storage facility?
ydrator located at an oil and gas exploration and production operation , natural gas compressor station c
/col natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)?
equal to or greater than 6 tons per year VOC or 2 tpy VOC if the dehydrator is located within 1,320 feet of a
building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)?
ed on or after May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to
'Dehydrator is subject to Regulation 7, Section XVII, B, D.3
II.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
II.D.3 - Emissions Reduction Provisions
Emissions Control (Optional Section)
Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary
The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e
Section XVII.B.2.e - Alternative emissions control equipment
Disclaimer
Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not
a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the
individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any
conflict between the language of this document and the language of the Clean Air Act„ its
implementing regulations, and Air Quality Control Commission regulations, the language of the statute
or regulation will control. The use of non -mandatory language such as "recommend," "may," "should,"
and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology
Source Requires an APEN. Go to the next question
Source Requires a permit
Yes
Yes
Continue - You have indicated the attainment status on the Project Summary Sheet.
Continue - You have indicated the facility type on the Project Summary Sheet.
Go to the next question
Dehydrator is subject to Regulation 7, Section XII.H
Continue - Source is subject to MACT HH requirements. You have indicated the source category on t
Go to MACT HH Area source applicability section
Continue - You have indicated the dehydrator type on the dehydrator inventory sheet.
go to the next question
go to the next question
The dehy is subject to the Lopt requirements in 63.764(d)(2)
Continue - You have previously indicated this in the MACT section
Continue - You have previously indicated this in the beginning of the MACT section
Continue - You have previously indicated this in the Reg 7, Section XII determination
Go to question 5
Source is subject
he Project Summary Sheet.
004
Pressurized Condensate Tank Truck Loadout
Liquid Hose Diameter
0.16667
feet
Vapor Hose Diameter
0.16667
feet
Liquid Hose Length*
1
feet
Vapor Hose Length*
1
feet
Liquid Hose Volume
0.0218
cubic feet
Vapor Hose Volume
0.0218
cubic feet
Truck and Tank Pressure
97
psig
109.2
psia
Loadout Capacity
7000
gallons/load
Condensate Production
2500000
gallons/month
357.14286
loadouts/month
4286
loadouts/year
*Length as
pressurized
714285.71 bbl/yr
All liquid lines contain liquid products at individual specific gravity.
'All vapor return lines contain products that behave as Ideal Gases at 60 deg F and stor
P*V=n*R*T
Where:
P = pressure in hose at time of disconnect = storage tank pressure (psia)
V = Volume of hoses (cubic feet)
n = number of Ibmoles of product in hoses
R = Universal Gas Constant = 10.73 ft^3 * psi / Ibmole / deg R
T = avg Ioadout temp = 60 deg F = 519.67 deg R
Vapor Density
n
0.00042725
Ibmol
n/V
0.01958372
Ibmol/ft^3
MW
32.4
Ib/Ibmol
Vapor Density
0.63451264
Ib/ft^3
Vapor VOC Emissions
59.32679364
lb/yr
0.029663397
tpy
Total VOC Emissions
1.92
tpy
Emission Factor
0.897
Ib/Ioadout
n -hexane mass fraction
0.0752'
D
Liq
Total n -hexane Emissions
289.2
lb/yr
Emission Factor
0.0675
Ib/loadout
:ounts for length of isolation valve on
I hose
age tank pressure
Liquid Density
SG
0.65
ensity of Water
8.33
lb/gal
Liquid Density
5.4145
lb/gal
40.50
Ib/ft^3
luid VOC Emissions
3786.784167
lb/yr
1.89
tpy
Produced Water Storage Tank(s) Emissions Inventory
Section 01- Administrative Information
Facility AIRs ID:
123 9f41 00S
County Plant Point
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control
Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Produced Water Throughput =
Requested Permit Limit Throughput =
Potential to Emit (PTE) Produced Water
Throughput=
21,900 Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating =
1,900`. Barrels (bbl) per year
1,900 Barrels (bbl) per year
Secondary Emissions - Combustion Device(s)
Heat content of waste gas = Btu/scf
Volume of waste gas emitted per BBL of liquids
produced = S'. scf/bbl
Actual heat content of waste gas routed to combustion device =
Request heat content of waste gas routed to combustion device =
0 MMBTU per year
0 MMBTU per year
Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year
Section 04 - Emissions Factors & Methodologies
2 4%7f-',7�,i/
Will this storage tank emit flash emissions?
Pollutant
Pollutant
Produced Water Tank
Uncontrolled
Controlled
(lb/bbl)
(lb/bbl)
(Produced Water
Throughput)
0.007
0.022
(Produced
Water
-Throughput)
0.007
Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu)
(lb/bbl)
(waste heat
combusted)
(Produced
Water
Throughput)
Emission Factor Source
Emission Factor Source
Section 05 - Emissions Inventory
Criteria Pollutants
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Potential to Emit
Uncontrolled
(tons/year)
0.2409
Section 06- Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Section XVII.B, C.1, C.3
Regulation 7, Section XVII.C.2
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
=EMI
0.0767
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
0.0767
0.2409 IIKEEMMEMEI
Source requires APEN, is permit exempt
Storage Tank is not subject to Regulation 7, Section XVII
Storage Tank is not subject to Regulation 7, Section XVII.C.2
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
153.3000
481.8000
153.3000
481.8000
29 of 33
K:\PA\2017\17W E0640.CP1.xlsm
Produced Water Storage Tank(s) Emissions Inventory
Regulation 6, Part A, NSPS Subpart OOOO 'Storage Tank is not subject to NSPS OOOO
(See regulatory applicability worksheet for detailed analysis)
30 of 33 K:\PA\2017\17WE0640.CP1.xlsns
Produced Water Storage Tank(s) Emissions Inventory
Section 07 - Initial and Periodic Sampling and Testing Requirements
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn
at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered
representative which generally means site -specific and collected within one year of the application received date.
However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to
use n older site -specific sample.
Ifno, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section 08- Technical Analysis Notes
Source is claiming the <1% crude oil by volume permit exemption. A permit exempt letter
AIRS Point It
005
Section 09 - Inventory SCC Coding and Emissions Factors
Process 0 SCC Code
01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 0.00 0 lb/1,000 gallons liquid throughput
PM2.5 0.00 0 lb/1,000 gallons liquid throughput
NOx 0.00 0 lb/1,000 gallons liquid throughput
VOC 6.2 0 lb/1,000 gallons liquid throughput
CO 0.00 0 lb/1,000 gallons liquid throughput
Benzene 0.17 0 Ib/1,000 gallons liquid throughput
Toluene 0.00 0 lb/1,000 gallons liquid throughput
Ethylbenzene 0.00 0 lb/1,000 gallons liquid throughput
Xylene 0.00 0 lb/1,000 gallons liquid throughput
n -Hexane 0.52 0 lb/1,000 gallons liquid throughput
224 TMP 0.00 0 lb/1,000 gallons liquid throughput
31 of 33 K:\PA\2017\ 17WE0640.CP1.xlsm
Produced Water Storage Tank Regulatory Analysis Worksheet
a
z
2
v
N
m
a
d
d
w
0
Cl
O
CD
c
d
d
10
T
c
d
d
C
0
d
C
C
c
D
C
E
3
A
r
D
u
d
m
p
d
tn
E
a
E
a
m
H
0
c
m
a
a
6
O
in the Non -Attainment A
s
a
00
0
NON -ATTAINMENT
0
V
r4
00.1
0r
Colorado Re
a
m
m
O
a
m
T2
171
`°
m0
v
E
0
m
S
c
n3.
O
O0
a
3
O
0
C
U
O
0
0
a
mx
x
an 6 tons per year VOC?
ipment and Prevention of Emissions
N O 4 Vl
:c
S
0
d with Air Pollution Control Equipment
Section XVII.C.2 - Ca
m
S s ',;2;
Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
0
O
O
O
r
40 C
Are pi
Doi
of
O
m
0
O
O
O
0
L
d
0
c
E
a
a
m
0
>
T
n
C
«
b
0
m
C
0
S
O
vJ
O
O
0
O
a
Z
y c 0
E d w
w
O a
d ▪ d
d
m m a
O. F .0 n
d O ^
d Y > d C
C C « O
E (o
n C Nm — 6
w c a c 0
a 2- y 0 a o
O O` 2 aiO: O
• a V I
a N E
° O a '°
c0
O o n v d U
o >
0 20 - d O I
m . >
E ZUO
U w H V N E
m u q
N trl ‘.0
▪ y
✓ a 01
m a a
ad
0 0 0 0 0 2
0
w . C
tat
a 0 0 o d
Lo
3 o 0 z > N W�
C
E
u
3
0
N
E
C
c
Z
473
R
O
N
0
01
a
m ▪ `d
•� E
v
N_
O
g
k}
\k{f
( 0
2-20Ee
\(}{/
Eo
u2A7I
a■!\k\
{88-
o E§ 8
+(a))2
k//§
/)giV,b2,]
o ?5
\\���\
e-a®�•
{)\)\-2
ifJ8,))
\((\\(
C) o o
\\\9
■ :&-2f
2a« §;
/\)\
k{»])\
:##t2t
/0
0..
aE8-
-�u=o
($)\O0257
{
\8..0
&0\+f®
_2.
2 *00
O 0\0\0
$]§\t
)/\\\{
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. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged on additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of
specialty APENs is available 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: 11 yiyG Q' ti2 `I v AIRS ID Number: 1 73 &IF4 ( / 0 () f
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name':
Site Name:
DCP Operating Company, LP
Northstar Compressor Station
Site Location: NE1/4 Sec 2, T6N, R65W
Mailing Address:
(include zip code) 370 17th Street, Suite 2500
Portable Source
Home Base:
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 1311
Permit Contact: Roshini Shankaran
Phone Number: 303-605-2039
E -Mail Address2: RShankaran@DCPMidstream.com
1
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
Form APCD-2OO - General APEN - Revision 10/2016 1
364272
AV
COLORADO
ro� Health Er Em t
Permit Number: AIRS ID Number:
[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 name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below)
- OR
• APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
El APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
3 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:
Natural Gas Compression Turbine
Manufacturer: Solar
Model No.: Taurus 70
Company equipment Identification No. (optional): TURB-1
For existing sources, operation began on:
Serial No.: TBD
For new or reconstructed sources, the projected start-up date is:
TBD
O 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
Seasonal use percentage: Dec -Feb: Mar -May:
days/week weeks/year
June -Aug: Sept -Nov:
Form APCD-200 - General APEN - Revision 10/2016 2
®V COLORADO
H*ITh ntom
x«un a cmolmm,
Permit Number:
AIRS ID Number:
r❑ Upward
E Horizontal
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Processing/Manufacturing Information ft Material Use
❑✓ 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 Limit4
(Specify Units)
Material
Consumption:
Finished
Product(s):
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.518685 / -104.625131
❑ 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
t)
Temp
-
(
Flow Rate
(ACFM)
Velocity
(ft/seca
TURB-1
45.0
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
❑✓ Circular Interior stack diameter (inches): 48.0
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-200 - General APEN - Revision 10/2016
3 A77 COLORADO
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit fr and AIRS ID]
Section 6 - Combustion Equipment Et 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 Limit4
(Specify Units)
72.2 -
618.3 MMscf/yr ,
From what year is the actual annual fuel use data?
Indicate the type of fuel useds:
❑ 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:
El Other (describe): Pipeline Natural Gas Heating value (give units): 1,023 Btu/scf
a Requested values will become permit limitations. Requested limit(s) should consider future process growth.
s 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 0 No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Control Efficiency
(% reduction in emissions)
TSP (PM)
PM10
PM2.5
SOX
NOx
CO
VOC
Other:
!;4
Form APCD-200 - General APEN - Revision 10/2016
®V COLORADO
Hwltb b Envinnmmi
,
Permit Number:
Section 7 (continued)
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
From what year is the following reported actual annual emissions data?
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.)
Pollutant
Uncontrolled
Emission
Factor
(specify Units)
Emission
Factor
Source
(AP -42, Mfg.
etc)
Actual Annual Emissions
_
Requested Annual Permit
4
Emission Limits)
Uncontrolled
(Tons/year)
Controlled6
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
TSP (PM)
6.6E-03 Ib/MMBtu-""
AP -42
2.1 '
2.1
PM,0
6.6E-031b/MMBtu-
AP -42
2.1 '
2.1
PM2.s
6.6E-03 Ib/MMBtu--•
AP -42
2.1 '
2.1
SO,,
3.4E-03 lb/MMBtu✓
AP -42
1.1 -
1.1
NO,,
5.5E-02Ib/MMBtu-
Mfg.
17.3 '
17.3
CO
6.1E-02 Ib/MMBtu
' Mfg.
19.2 -
19.2
VOC
2.1E-03 lb/MMBtu
— AP -42
0.7 '
0.7
Other:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emission 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) emissions equal to or greater than 250 ❑✓ Yes ❑ No
lbs/year?
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
CAS
Number
Overall
Efficiency
Uncontrolled
Emission
Chemical Name Control Source
Factor
(specify units)(lbs/year)
Emission Factor
'
(AP -42, Mfg. etc)
Uncontrolled
Actual
Emissions
Controlled
Actual
Emissions6
(Ws/year)
50-00-0
Formaldehyde
0.0%
7.1E-04 '
AP -42
449.1 -
449.1
6 Annual emission fees win be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-200 - General APEN - Revision 10/2016
Avis, * COLORADO
x«nns[,wtmrm.m
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct.
Signature of Legally Authorized Person (not a vendor or consultant) Date
Roshini Shankaran Environmental Engineer
Name (print) Title
Check the appropriate box to request a copy of the:
❑✓ Draft permit prior to issuance
❑✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $152.90, to: For more information or assistance call:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD-2OO - General APEN - Revision 10/2016
zir COLORADO
6 I 6 u��
xuim mnnm.m
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. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of
specialty APENs is available 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:
11650U46
AIRS ID Number: I 23 /q 1 / d a 2
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': DCP Operating Company, LP
Site Name: Northstar Compressor Station
Site Location: NE1/4 Sec 2, T6N, R65W
Mailing Address:
(Include Zip code) 370 17th Street, Suite 2500
Portable Source
Home Base:
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 1311
Permit Contact: Roshini Shankaran
Phone Number: 303-605-2039
E -Mail Address: RShankaran@DCPMidstream.com
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
Form APCD-200 - General APEN - Revision 10/2016
364273
COLORADO
1 I A. vtM XUIN bLrov,m,
Permit Number: AIRS ID Number:
[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 name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
- OR
• APEN submittal for update only (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 ft Notes:
3 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:
Natural Gas Compression Turbine
Manufacturer: Solar
Model No.: Taurus 70
Company equipment Identification No. (optional): TURB-2
For existing sources, operation began on:
Serial No.: TBD
For new or reconstructed sources, the projected start-up date is:
TBD
0 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
Seasonal use percentage: Dec -Feb: Mar -May:
Form APCD-200 - General APEN - Revision 10/2016
days/week weeks/year
June -Aug: Sept -Nov:
pp COLORADO
2 I m� xuun a a
umnnm.m
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Processing/Manufacturing Information £t Material Use
❑✓ 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 Limit 4'
(Specify Units)
Material
Consumption:
Finished
Product(s):
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.518685 / -104.625131
❑ 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 f
Discharge Height
Above Ground Level -
(Feet)-`
Temp
( F): ;
Flow Ma te
A
( CFM)
Veloci
(ft/sec)
TURB-2
45.0
Indicate the direction of the stack outlet: (check one)
❑r Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
❑ Circular Interior stack diameter (inches): 48.0
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-2OO - General APEN - Revision 10/2016
w COLORADO
x.+�m u umronmm�
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit k 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 Limit4
(Specify Units)
72.2
618.3 MMscf/yr
From what year is the actual annual fuel use data?
Indicate the type of fuel used5:
❑ 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): Pipeline Natural Gas Heating value (give units): 1,023 Btu/scf
a Requested values will become permit limitations. Requested limit(s) should consider future process growth.
5 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 ❑� No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Control Efficiency
(% reduction in emissions)
TSP (PM)
PM10
PM2.5
SOX
NOX
CO
VOC
Other:
Form APCD-200 - General APEN - Revision 10/2016
®r COLORADO
==ac,
Permit Number:
AIRS ID Number: /
Section 7 (continued)
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
From what year is the following reported actual annual emissions data?
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.)
Pollutant
Uncontrolled
Emission---44.-,1-?:54,1.-;':.,,,,e...:-,A=....,,,Emission
Factor
(specify Units)
Emission
Factor
Source_h._
(Ap-42, Mfg.
etc)
Actual Annual Emissions
Requested Annual Permit
4
Limitls)- '.
Uncontrolled
(Tons/year)
Controlled6
(Tons/year) `
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
TSP (PM)
6.6E-031b/MMBtu
AP -42
2.1
2.1
PM10
6.6E-03 lb/MMBtu
AP -42
2.1
2.1
PM2.5
6.6E-03 lb/MMBtu
AP -42
2.1
2.1
SO),
3.4E-03 lb/MMBtu
AP -42
1.1
1.1
NO„
5.5E-021b/MMBtu
Mfg.
17.3
17.3
CO
6.1E-02 Ib/MMBtu
Mfg.
19.2
19.2
VOC
2.1E-03Ib/MMBtu
AP -42
0.7
0.7
Other:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emission 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) emissions equal to or greater than 250 ✓❑ Yes ❑ No
lbs/year?
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
CAS
Number
Chemical Name
Overall
Control
Efficiency
Uncontrolled
Emission
Factor
(specify units)
Emission Factor
-
Ap Source
(-42, Mfg. etc)
Uncontrolled
Actual
Emissions
-
(lbs/year)
Controlled
Actual
Emissions
(lbs/year)
50-00-0
Formaldehyde
0.0%
7.1E-04
AP -42
449.1
449.1
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-200 - General APEN - Revision 10/2016
COLORADO
51 •
x.aun a �nronm«u
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct.
Signature of Legally Authorized Person (not a vendor or consultant)
Roshini Shankaran
6(1(Zor.4
Date
Environmental Engineer
Name (print) Title
Check the appropriate box to request a copy of the:
• Draft permit prior to issuance
O 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 $152.90, to: For more information or assistance call:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD-200 - General APEN - Revision 10/2016
Q COLORADO
6 I m p Dory COLORADO
H=Pultic
6 E+wfnnmm�
Glycol Dehydration Unit APEN - Form APCD-202
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. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this
category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is
available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can
be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: J7 YY r QL ,4() AIRS ID Number: 1�3 /'7F41 / QV
[Leave blank unless APCD has already assigned a permit #t and AIRS ID]
Company equipment Identification:
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name':
Site Name:
DCP Operating Company, LP
Northstar Compressor Station
Site Location: NE1/4 Sec 2, T6N, R65W
Mailing Address:
(Include Zip code) 370 17th Street, Suite 2500
Denver, CO 80202
E -Mail Address2: RShankaran@DCPMidstream.com
Site Location
County: Weld
NAICS or SIC Code: 1311
Permit Contact: Roshini Shankaran
Phone Number: 303-605-2039
1Please 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 APCD via e-mail to the address provided.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017
3642'74
1 1 mV
COLORADO
Department d Pone
Deanne EwlroNneM
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
El NEW permit OR newly -reported emission source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership3 0 Other (describe below)
OR-
❑ APEN submittal for update only (Please note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose:
TEG dehydration unit for water removal
Facility equipment Identification:
D-1 - TEG Dehydration Unit
For existing sources, operation began on: / /
For new or reconstructed sources, the projected
start-up date is:
TBD / /
0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day
Will this equipment be operated in any NAAQS nonattainment
area
Is this unit located at a stationary source that is considered a
Major Source of (HAP) Emissions
Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017
Li
days/week
Yes
Yes
0
weeks/year
No
No
COLORADO
2 I A6 d
fhpartmetu
Pa.
LK6 Lnvu nm•ru
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer:
Dehydrator Serial
Number:
Glycol Used:
TBD
TBD
Ethylene Glycol
(EG)
Model Number:
TBD
Reboiler Rating: 3.0
❑ DiEthylene Glycol
(DEG)
Glycol Pump Drive: 0 Electric' ❑ Gas If Gas, injection pump ratio:
Pump Make and Model:
TBD - 1 primary, 1 backup
Glycol Recirculation rate (gal/min):
Lean Glycol Water Content:
Max: 40.0-
1.0 - Wt.%
MMBTU/hr
❑ TriEthylene Glycol
(TEG)
# of pumps:
Requested: 40.0-
Acfm/gpm
Acfm/gpm
2
Dehydrator Gas Throughput:
Design Capacity: 130 ' MMSCF/day
Requested: 47,450 -' MMSCF/year Actual: MMSCF/year
Inlet Gas:
Pressure: 1 ,056
Water Content: Wet Gas:
Flash Tank: Pressure: 60 —
Cold Separator: Pressure:
Stripping Gas: (check one)
❑✓ None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen
Flow Rate:
scfm
psig
lb/MMSCF
psig
psig
Temperature: 110
❑✓ Saturated Dry gas: 6.7 i lb/MMSCF
Temperature: 100 - ° F ❑ NA
Temperature: °F ✓❑ NA
°F
Additional Required Information:
❑✓ Attach a Process Flow Diagram
❑✓ Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results)
❑Q Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure)
Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017
COLORADO
3 I iFF? ®V =mE.,"=.
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.518685 / -104625131
ratot
Opix
t
StacC ID No `z�{
Discharge Height+
;-t"�*44V 4
Abo a Ground Level
(Feet)
Temp
a g
F) +
Flow Rate
(ACF1)ft✓sec��
Veloaty
D-1
TBD
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
0 Upward with obstructing raincap
p Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
0 Other (describe):
Form APCD-2O2 -Glycol Dehydration Unit APEN - Revision 02/2017
COLORADO
4 I Av
w°"6pM.,
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Control Device Information
Condenser:
Used for control of:
Type: Make/Model:
•
Maximum Temp Average Temp
Requested Control Efficiency
VRU:
Used for control of: Flash Tank Vapors
Size: Make/Model:
p
Requested Control Efficiency 95.0
VRU Downtime or Bypassed 5.0
Combustion
Device: *
Used for control of: Still Vent Stream
Rating: MMBtu/hr
Type: Enclosed Combustor Make/Model: TBD
Requested Control Efficiency: 95,0 %
Btu/scf
MMBtu/hr
•
Manufacturer Guaranteed Control Efficiency 98.0 %
Minimum Temperature: Waste Gas Heat Content
Constant Pilot Light: • Yes ■ No Pilot burner Rating 0.05
Closed
Loop
System:
Used for control of:
•
Description:
System Downtime 0/0
Other:
Used for control of: Flash Tank Vapors during VRU downtime (5.0%)
Description: ECD Combustion Device
A
Control Efficiency 0'
Requested 95.0 °
* ECD combustion device used for still vent control has a 3.0% annual downtime for
maintenance and repairs. Still vent emissions will vent to atmosphere during periods of ECD
downtime.
Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017
AW COLORADO
5 Im
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SOX
NOx
CO
VOC
Vapor Recovery Unit / Enclosed Combustor
95%
HAPs
Vapor Recovery Unit / Enclosed Combustor
95%
Other:
From what year is the following reported actual annual emissions data?
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.)
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor
Units
Emission
Factor
Source
(AP -42,
Mfg. etc)
xx
�� ��
Actual. nua Emissio s .
�Requested;Annual Permit
Emission Limits a
4.,,,vvq.,,4w"� r^�
Uncontrolled
(Tons/year)
Controlled5
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SOX
NOx
0.068
Ib/MMBtu
AP -42
_2sr' Z$
,2 Z.
CO
1Y3l Q l
Ib/MMBtu
AP -42
„1-3-frZ.q-
,..1-377'l2,'
VOC
40.9
lb/MMscf
GLYCaIc
971.3'
46.4 -
Benzene
3.7
lb/MMscf
GLYCaIc
87.9 -
6.8
Toluene
3.4
lb/MMscf
GLYCaIc
81.2 —
6.3 '
Ethylbenzene
0.1
lb/MMscf
GLYCaIc
2.3 -
0.2
Xylenes
1.0
lb/MMscf
GLYCaIc
22.7 '
1.8 -
n -Hexane
0.8
lb/MMscf
GLYCaIc
18.1 '
1.1,
2,2,4-
Trimethylpentane
Other:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
5Annual emission fees wilt be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
fi
Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017
COLORADO
6 1 dn.
xnun s s,�wro�.x
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct.
6l-1Izoc�
Signature of Legally Authorized Person (not a vendor or consultant) Date
Roshini Shankaran
Environmental Engineer
Name (please print) Title
Check the appropriate box to request a copy of the:
❑r Draft permit prior to issuance
❑✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
Send this form along with $152.90 to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and
Environment
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https: //www.colorado.gov/cdphe/apcd
Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017
®17 COLORADO
HUY� 6 F.I1vOfIt
Hydrocarbon Liquid Loading APEN - Form APCD-208
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category,
there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if
the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on
the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: j "i Y vE0 (C+ AIRS ID Number: 1 �3 /D(Fq-r? / 004
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Company equipment Identification: L-1 - Pressurized liquid loading
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name:
Site Name:
DCP Operating Company, LP
Northstar Compressor Station
Site Location: NE1/4 Sec 2, T6N, R65W
Mailing Address:
(Include Zip code) 370 17th Street, Suite 2500
Denver, CO 80202
E -Mail Address2: RShankaran@DCPMidstream.com
Site Location
County: Weld
NAICS or SIC Code: 1311
Permit Contact: Roshini Shankaran
Phone Number: 303-605-2039
'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 APCD via e-mail to the address provided.
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017
364275
®V COLORADO
iWilh b EMI
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
❑✓ NEW permit OR newly -reported emission source
❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07
If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted
along with the APEN Filing fee.
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 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:
Pressurized truck loadout of condensate
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
/ /
TBD/
Will this equipment be operated in any NAAQS nonattainment area?
Is this equipment located at a stationary source that is considered a Major Source of (HAP)
emissions?
Does this source load gasoline into transport vehicles?
Is this source located at an oil and gas exploration and production site?
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual
average?
Does this source splash fill less than 6750 BBL of condensate per year?
Does this source submerge fill less than 16308 BBL of condensate per year?
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
CI Yes ❑ No
❑ Yes [] No
❑ Yes 0 No
❑ Yes 2 No
❑ Yes ❑ No
❑ Yes ❑ No
❑ Yes ❑ No
®V COLORADO
2 I Depvmrn�w wwf�
xn�n n F,rovonm.m
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
Product Loaded: ❑✓ Condensate ❑ Crude Oil ❑ Other:
If this APEN is being filed for vapors displaced from cargo carrier, complete the following:
' , Sh,""
Requested Volume
Loaded4:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Bbl/yr
Actual Volume
Loaded:
Bbl/yr
This product is loaded from tanks at this facility into:
(eg, "rail tank cars" or "tank trucks")
If site specific emission factor is used to calculate emissions, complete the following:
Saturation Factor:
Average temperature
of bulk liquid loading:
°F
True Vapor
Pressure
Psia 60 ° F
Molecular weight of
displaced vapors
Lb/lb-mol
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following: I ZKC
Requested Volume 714 286- Bbl/ r Actual Volume
Loaded : y Loaded:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Bbl/yr
Product Density:
40.5
Lb/ft3
Load Line Volume: 0.0218 .- ft3/truckload
Vapor Recovery Line Volume
0.0218 ft3/truckload
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
®V COLORADO
xnim t rnitnm.ni
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Geographical Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.518685 / -104.625131
Operator -
—. s
Stack ID NO
Discharge Height
Above Ground Level -=
(Feet)
Temp
( F) r
Flow Rate
(ACFM)
Velocity
(ft/sec)
L-1
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular Interior stack diameter (inches):
❑ Other (describe):
❑ Upward with obstructing raincap
Section 6 - Control Device Information
❑✓ Loading occurs using a vapor balance system:
Requested Control Efficiency
❑ Combustion
Device:
Pollutants Controlled:
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency
Minimum Temperature:
MMBtu/hr
Make/Model:
%
Waste Gas Heat Content
Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating
Btu/scf
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
4 I AVCOLORADO
.,0
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SOX
NO),
CO
VOC
HAPs
Other:
❑ Using State Emission Factors (Required for GP07) VOC
❑ Condensate 0.236 Lbs/BBL
❑ Crude 0.104 Lbs/BBL
Benzene n -Hexane
0.00041 Lbs/BBL 0.0036 Lbs/BBL
0.00018 Lbs/BBL 0.0016 Lbs/BBL
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor
Units
Emission
Factor
Source
(AP -42,
Mfg. etc)
Actual Annual Emissions
Requested Annual Permit
Emission Limits
Uncontrolled
(Tons/year)
Controlled'
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)'
PM
SOX
NO.
1,U 2`i
lbi 14,41...A-
VOC
15AE—.03�'
-413/d5r---
Eng. Est.
LZ.--i-�-
Z -1,-A-9-
-
CO
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
C), GC 7S"
I61)<,.da..1
Q ,1 Lic
O.14c
2,2,4-
Trimethylpentane
Other:
n Requested values will become permit limitations. Requested limit(s) should consider future process growth.
'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
A 7 COLORADO
5
Really b Favtronmv�t
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID)
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
6/1(zot-
Signature of Legally Authorized Person (not a vendor or consultant) Date
Roshini Shankaran
Environmental Engineer
Name (print) Title
Check the appropriate box to request a copy of the:
❑✓ Draft permit prior to issuance
❑✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $152.90 and the General
Permit registration fee of $250 as applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https: //www.colorado.gov/cdphe/apcd
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
6®®COLORADO
HNM1M1 bEm=1,
Hello