HomeMy WebLinkAbout20191840.tiffPubv c aeAs.le
512o/+°'
COLORADO
Department of Public
Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150 0 St
PO Box 758
Greeley, CO 80632
May 8, 2019
Dear Sir or Madam:
RECEIVED
MAY 1 3 281D
WELD COUNTY
COMMISSIONERS
On May 9, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for REP
Processing, LLC - Severance 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
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
CC; PL(TP)
PW(31 tRIcNic,,)
5/131 t°►
2019-1840
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: REP Processing, LLC - Severance Compressor Station - Weld County
Notice Period Begins: May 9, 2019
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: REP Processing, LLC
Facility: Severance Compressor Station
Compressor Station
NW SEC 8 T7N R66W
Weld County
The proposed project or activity is as follows: Dehydrator, Condensate tank, blowdowns, pigging, and
fugitive equipment leaks at a compressor station.
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 18WE1051 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.Rov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Timothy Sharp
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
COLORADO
1 I Iw
Colorado Air Permitting Project
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer: Timothy_ Sharp..
Package #: 388102
Received Date: 9/25/2018
Review Start Date: 12/5/2018
Section 01- Facility Information
Company Name: REP Processing, LLC,-
County AIRS ID: 123
Plant AIRS ID: 9FFB
Facility Name: Reverence Compressor Station
Physical
Address/Location:
County:
Type of Facility: Natural Gas Compressor Station
What industry segment? ail & Natural Gas Production &Processing
Is this facility located in a NAAQS non -attainment area? Yes
If yes, for what pollutant? ❑° Carbon Monoxide (CO)
NW quadrant of Section 8, Township 7N, Range 66W
Weld County
Section 02 - Emissions Units In Permit Application
Quadrant
Section
Township
Range
NW
Particulate Matter (PM) ❑ Ozone (NOx & VOC)
8
AIRs Point#
Emissions Source Type
Equipment Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
001
Dehydrator
SK-4100TEG
Yes
18WE1051
1
yes
Permit initial
Issuance
002
FugitiveComponentLeaks
FUG -1
No
13W61051
2
yes ':
Permit Initial
Issuance
003.
Separator Venting
V-7000
Yes
18WE1051
1
yes
Permit Initial
Issuance
004
Separator Venting ._
V-8100
Yes
18WE1051
1
yes
Permit Initial
Issuance
"condensate
surge vessel»
sent to pipeline
005
MaintenanceBjowdowns
BD -1
No
18WE1051
1
yes
Permit Initial
Issuance
006
Maintenance&lewdowns
PG -1
No
18WE1051
1
yes '-
Permit Initial
Issuance
Section 03 - Description of Project
-facility flare is enclosed.
-blowdown and pigging capture efficiencies need to be established.
-produced water atm tank is APEN exempt
fugitive leak (table 2-4) is conservative.
Section 04 - Public Corranent Requirements
Is Public Comment Required? "- Yes
If yes, why? Greater than 25 tons per year in Non -Attainment Area
Section 05 - Ambient Air Impact Analysis Requirement
Was a quantitative modeling analysis required? Yes
If yes, for what pollutants? PM 25
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)
No -
' - Yes
S02 NOx CO VOC PM2.5 PM10 TSP HAPs
❑ O O O ❑ O
Colorado Air Permitting Project
Non -Attainment New Source Review (NANSR) ❑ ❑
Is this stationary source a major source?
If yes, explain what programs and which pollutants hen5O2 NOx CO VOC PM2.5 PM10 TSP HAPs
Prevention of Significant Deterioration (PSD) ❑ O ❑ O O ❑
Title V Operating Permits (OP) ❑ ❑ O ❑ O O ❑ O
Non -Attainment New Source Review (NANSR) O O
Glycol Dehydrator Emissions Inventory
001 Dehydrator
(Facility AIRs ID:
County
BFPO
Plant
001
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 Sumer
Stripping Gas
Dehydrator Equipment Description
Emission Control Device Description:
TAD
760
TAD
100
tbd
MMscf/day
gallons/minute
flash tank,
and reboiler burner
Stripping gas is injected into the reboiler.
One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TOD, Model: TOD, Serial Number. TOD) with a design capacity of 100 MMscf per day. This emissions
unit is equipped with the (Make: tbd, Model: tbd) electric driven glycol pump with a design capacity of 25 gallons per minute. This dehydration unit o equipped with a
still vent, flash tank, end reboiler bumer. Stripping gas is injected into the reboiler.
Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank art routed directly to the dosed -soap
system.
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emlwlons- Dehydrator Still Vent and Flash Tank (if present)
(Requested Permit Limit Throughput=
Potential to Emit (PTE) Throughput= 36,500 MMscf per year
MMscf per year Requested Monthly Throughput= 3100 MMscf per month
Secondary Emissions -Combustion Device(s) for Air Pollution Control
Still Vent Control
Condenser:
Condenser emission reduction claimed:
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Still Vent Gas Heating Value:
Still Vent Waste Gas Vent Rate:
Flash tank Control
Primary control device:
Primary control device operation:
Secondary control device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
Requested Condenser Outlet Temperature:
$250 hr/yr
Section 04- Emissions Factors & Methodologies
Dehydrator
Requested TO Temp Degrees F
Control Efficiency %
hr/yr
544 Btu/scf
403 scfh
2197
'y100% Control Efficiency a
hr/yr
. ::= s,,y Control Efficiencya
hr/Vr
1211 Btu/scf
EH03 Seth
Input Parameters
inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol l&circulate Rate
psig
deg F
gpm
STILL VENT
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled (lb/hr)
VOC
.:496.8905 .-
4.844525
0
Benzene
:`;':&$940':` -'iii,.
0.44474
0
Toluene
r10,4771
0.523855
0
Ethylbenurre
;:;99632.
0.04816
0
Xyienes
5.6163
0.280815
0
n -Hexane
.... 55648
0,27824
0
224-TMP
- 0.0069
0.000345
0
FLASH TANK
Control Scenario
Primary
Secondary
Pollutant
Uncontrolled (lb/hr)
Controlled (lb/hr)
Controlled (lb/hr)
VOC
s ^31,691$
0
37.6918
Benzene
.095a
0
0.0936
Toluene
0
0.0747
Ethyibenzene
: 0.0042
0
0.0042
Xylenes
0,0173
0
0.0173
n -Hexane
-' L372.
0
1.372
224-TMP
0.0010
0
0.0016
Dry Gas Throughput:
Still Vent Primary Control: 36,500.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 85.1 MMscfi/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Dry Gas Throughput:
Flash Tank Primary Control: 36,500.0 MMscf/yr
Flash Tank Secondary Control 0.0 MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 0.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
3,100.0
7.2
Glycol Dehydrator Emissions Inventory
Emission Factor
Section 05 -Emissions Inventory
Did operator request a buffer?
Requested Buffer)%):
Pollutant
Pollutant
PM10
PM2.5
Pollutant
500
NOx
Glycol Dehydrator
Uncontrolled
(Ib/MMsef) (Ib/MMsct)
(Dry Gas
Throughput) (Dry Gas Throughput)
Controlled
4.7984
0.0000
88.8720
77.4220
Still Vent Secondary Control Device
Uncontrolled Uncontrolled
(Ib/MM Des)
(Waste Heat
Combusted)
Emission Factor Source
(Ib/MMscf) Emission Factor Source
(Waste Gas
Combusted)
0.0000
0.0000
0.0000
0.0000
0.0000
Hash Tank Primary Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu)
(Waste Heat
Combusted)
(lb/MM
(Waste Gas
Combusted)
0.0000
0.0000
0,0000
0,0000
Emission Factor Source
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM1O
PM2.5
SO9
Not
CO
VOC
0.2
0.2
0.2
0.2
0.2
35
0.0
0.0
0.0
0.0
0.0
0
0.0
0.0
0.0
0.0
0.0
0
3.8
3.8
3.8
3.8
3.8
643
7.6
7.6
7.6
7.6
7.6
1283
589.5
569.5
2(2
589.5
21.2
3604
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
78740
78740
3836
78740
3896
92434
92434
4589
92434
4589
8474
8474
422
6474
422
49300
49350
2460
49350
2460
60766
60766
2437
60766
2437
74
]4
3
74
3
Section 06- Rres(atgry Summary Anohnls
Regulation 3, Parts A, B
Regulation 7, Section XVILB,1
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, Part E, MAR Subpart HH (Area)
Regulation 8, part E, MACE subpart HH (Ma)or)
Regulation 8, Part E, MACI Subpart HHH
(See regulatory applicability worksheet for detailed analysts)
Source requires a permit
Dehydrator is subject to Regulation 7, Section XVII, 8, 0.3
The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e
Dehydrator is subject to Regulation 7, Section XII.H
Dehy is subject to alto source MAR OH, per the requirements in 63.764(dl17)
You have indicated that this facility A not subject to Major Source requirements of MAR HU.
You have indicatedthat this facility is not subject to MACI HHH.
Glycol Dehydrator Emissions Inventory
Section 07- Intial and Periodic Sampling end Testing Requirements
Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a
year of application snbmittal7
If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission Iimi
Does the company request a control device efficiency greater than 95%for a flare or combustion device?
If yes, the permit will contain end initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on Inlet and outlet concentration sampling
lithe company has requested a control device efficiency greater than 95%, Is athermal oxidizer or regenerative thermal oxidizer being used to achieve d?
If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer
is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F?
Oyes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer.
No
Section 08 -Technical Analysis Notes
Section 09- Inventory5CC Coding and Emissions Factors
AIRS Point #
001
Process # SCC Code
01
Uncontrolled
Pollutant Emissions Factor Control % Units
PM10 0.011 0.0 b/MMscf
PM2.5 0.000 0.0 b/MMscf
S0x 0.000 0.0 b/MMscf
NOx 0.207 0.0 b/MMscf
VOC 32.3 96.4 b/MMscf
CO 0.414 0.0 b/MMscf
Benzene 2.157 95.1 b/MMscf
Toluene 2.532 95.0 b/MMscf
Ethylbenzene 0.232 95.0 b/MMscf
Xylene 1.352 95.0 b/MMscf
n-Nexane 1.665 96.0 b/MMscf
224 TMP 0.002 95.9 b/MMscf
Dehydrator Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
'Source is in the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Sec
'You have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Pal
'Source requires a permit
Colorado Regulation 7, Section XII.H
1. Is this glycol natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Reg 7, Sec
2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation', natural gas compressor station, natural gas drip
3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater tt
4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section XII.H.3.a)?
'Dehydrator is subject to Regulation 7, Section XII.H
Section XII.H — Emission Reductions from glycol natural gas dehydrators
MACT Analysis
1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria:
a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage
b. source category or is delivered to a final end user2 (63.760(a)(3))?
2. Is the dehydrator located at a facility that is a major source for HAPs?
IGo to MACT HH Area Source Requirement section to determine MACT HH applicability
40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities
Area Source Requirements
1. Is the dehydrator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))?
Exemptions
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.764(e)(1)(i)?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.7
3. Is the unit located inside of a UA plus offset and UC boundary area?
IDehy 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
Major Source Requirements
1. Does the facility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility -wide actual annual average
Small or Large Dehy Determination
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.761)?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.7
Small Dehy Requirements
3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B) and (C )?
4. For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation?
(You have indicated that this facility is not subject to Major Source requirements of MACT HH.
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards
§63.773 - Monitoring
§63.774 - Recordkeeping
§63.775 - Reporting
40 CFR, Part 63, Subpart MACT HHH, Natural Gas Transmission and Storage Facilities
1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source (6.
Small or Large Dehy Determination
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day (63.1270(b)(2))?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.1
Small Dehy Requirements
3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(2) and (3) )?
4. For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicable equation?
'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 - Recordkeeping
§63.1285 - Reporting
Colorado Regulation 7, Section XVII.D
1. Is the dehydrator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)?
2. Is this dehydrator located at a transmission/storage facility?
3. Is this dehydrator located at an oil and gas exploration and production operation, natural gas compressor station or gas processing plant (RE
4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)?
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,
4a. Section XVII.D.4.b)?
5. If constructed on or after May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC (F
'Dehydrator is subject to Regulation 7, Section XVII, B, D.3
Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.D.3 - Emissions Reduction Provisions
Alternative Emissions Control (Optional Section)
6. Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not en
IThe 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
regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains
may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or
substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any
conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air
Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory
language such as "recommend,""may," "should," and "can," is intended to describe APCD interpretations and recommendations.
Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the
Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements
Colorado Department of Public Health Environment
Air Pollution Control Division
Operation (hrs/yr) 8760
SCC Code: 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains)
Fugitive Component Counts & Emissions
Service
Component
Type
Count
TOC EF
lb/hr-
source
TOC EF
kg/hr-
source
Control
(%)
VOC
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
Uncontrolled
()py)
Controlled
(tpy)
Uncontrolled
(Ib/yr)
Controlled
(Ib/yr)
Uncontrolled
(Ib/yr)
Controlled
(Ib/yr)
Uncontrolled
(Ib/yr)
Controlled
(Ib/yr)
Uncontrolled
(lb/yr)
Controlled
(Ib/yr)
Uncontrolled
(Ib/yr)
Controlled
(lb/yr)
Gas
Valves
640
9.92E-03
4.50E-03
0.0%
7.26
7.3
22.2
22.2
22.2
22.2
2.2
2.2
11.1
11.1
622.9
622.9
Pump Seals
10
5.29E -D3
2.40E-03
0.0%
0.06
0.1
0.2
0.2
0.2
0.2
0.0
0.0
0.1
0.1
5.2
5.2
Others
50
1.94E-02
8.80E-03
0.0%
1.11
1.1
3.4
3.4
3.4
3.4
0.3
0.3
1.7
1.7
95.2
95.2
Connectors
710
4.41E-04
2.00E-04
0.0%
0.36
0.4
1.1
1.1
1.1
1.1
0.1
0.1
0.5
0.5
30.7
30.7
Flanges
360
8.60E-04
3.90E-04
0.0%
0.35
0.4
1.1
1.1
1.1
1.1
0.1
0.1
0.5
0.5
30.4
30.4
Open-ended lines
80
4.41E-03
2.00E-03
0.0%
0.40
0.4
1.2
1.2
1.2
1.2
0.1
0.1
0.6
0.6
34.6
34.6
Light Oil
Valves
110
5.51E-03
2.50E-03
0.0%
2.66
2.7
28.7
28.7
100.9
100.9
28.7
28.7
134.9
134.9
713.8
713.8
Pump Seals
50
2.87E-02
1.30E-02
0.0%
6.28
6.3
67.8
67.8
238.5
238.5
67.8
67.8
318.8
318.8
1687.1
1687.1
Others
50
1.65E-02
7.50E-03
0.0%
3.62
3.6
39.1
39.1
137.6
137.6
39.1
39.1
184.0
184.0
973.3
973.3
Connectors
210
4.63E-04
2.10E-04
0.0%
0.43
0.4
4.6
4.6
16.2
16.2
. 4.6
4.6
21.6
21.6
114.5
114.5
Flanges
20
2.43E-04
1.10E-04
0.0%
0.02
0.0
0.2
0.2
0.8
0.8
0.2
0.2
1.1
1.1
5.7
5.7
Open-ended lines
20
3.09E-03
1.40E-03
0.0%
0.27
0.3
2.9
2.9
10.3
10.3
2.9
2.9
13.7
13.7
72.7
72.7
Heavy 0i1
Valves
0
1.85E-05
6.40E-06
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Pump Seals
r�
- - _i
:..,
`r ._.-�ry
'.`...
)III{
I
.:� ....
h
1
Mt Wail
Others
0
7.05E-05
3.20E-05
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Connectors
0
1.65E-05
7.50E-06
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.D
0.0
0.0
0.0
Flanges
0
8.60E-07
3.90E-07
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Open-ended lines
0
3.09E-04
1.40E -d4
0.0%
0.00
0.0
0.0
0,0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Water/Oil
Valves
0
2.16E-04
9,80E-05
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Pump Seals
0
5.29E-05
2.40E-05
0.D%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Others
0
3.09E-02
1.40E-02
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Connectors
0
2.43E-04
1.10E-04
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Flanges
0
6.39E-06
2.90E-06
0.0%
0.00
0.0
0,0
0.0
0.0
0.0
0.0
Op
0.0
0.0
0.0
0,0
Open-ended lines
0
5.51E-04
2.502-04
0.0%
0.00
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
The default list of TOC emissions factors are based on Table 2-4 "Average Emissions Factors" of the EPA Protocal for Fugitive
Equipment Leaks. If the company qualifies to use Table 2-8 "Less than 10,000 ppmv" emissions factors based on provisions of
Regulation 7, Section XVII.F, you must update and manually enter the Table 2-8 emissions factors into column "E" below.
TOTALS (Ib/yr)
0.
0.34
0.34
2.19
2.19
With safety factor: 1 I
TOTALS TL(tpy) 0.09 0.09 0.27 0.27 0.07 061. *1' SIr� }.i I 119 .
TOTALS (Ib/yr) f, g;t; g;1; �g
Emission Factor Source: EPA -453/R-95-017, Table 2-4
Stream VOC Fraction (wt) Stream HAP Components (wt fraction
Gas
0.2611
1.0000
1.0000
1.0000
Light Oil
Heavy Oil
Water/Oil
Regulatory Considerations
Reg. 3
Is this source located in an ozone non -attainment area or attainment maintenance area? yes
If yes, is this source subject to leak detection and repair (LDAR) requirements per Regulation 7, Section XVILF or XILG or 40 CFR, Part 60, Subparts KKK or OOOO? yes
If you repond "yes" to the first question and "no" to the second, this source is subject to Regulation 3, Part B, Section III.D.2, Reasonably Available Control Technology (RACT) requirements and must implement a
leak detection and repair program. The engineer should work with the supervisor to craft an LDAR requirement that mirrors the provisions of Regulation 7, Section X\/II.F.
Reg. 6
Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? no
Did this source commences construction, reconstruction, or modification after January 20, 1984, and on or before August 23, 2011? ' no
If you answer "yes" to both questions above, this source is subject to the provisions of 40 CFR, Part 60, Subpart KKK "Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing
Plants" contained in Regulation 6, Part A.
Did this source commences construction, reconstruction, or modification after August 23, 2011? yes
If you answer "yes" to question #1 and #3 this source is subject to the provisions of 40 CFR, Part 60, Subpart OOOO "Standards of Performance for Crude Oil and Natural Gas Production, Transmission and
Distribution". Specifically, review subpart 60.5400 for fugitive component leaks and 60.5380 and 60.5385 if the operator reports compressors.
Reg. 7
Is this source located in an ozone non -attainment area or attainment maintenance area? yes
Is this source at an onshore "natural gas processing plant" as defined in 40 CFR, Part 60.631? no
If you answer "yes" to both questions above, this source is subject to the provisions of Regulation 7, Section XII.G regardless of the date of construction
Reg. 8
Is this source at a "natural gas processing plant" as defined in 40 CFR, Part 63.761? no
Is this facility considered a "major source" of HAP as specifically defined in 40 CFR, Part 63.761 for sites that are not produution field facilities? no
If you repond "yes" to both questions above, further review if the provisions of 40 CFR, Part 63.769 "Equipment Leak Standards" apply? no
HAP
Gas
Light Oil
Heavy Oil
Water/Oil
Benzene
0.0004
0.005
0.00
0.00
Toluene
0.0004
0.019
0.00
0.00
Ethylbenzene
4E-05
0.005
0.00
0.00
Xylene
0.0002
0.025
0.00
0.00
n -Hexane
0.0112
0.134
0.00
0.00
Printed 5/7/2019
Page 9 of 23
Separator Venting Emissions Inventory
003 Separator Venting
'Facility AIRs ID:
11
County
'N,IFFAggkitr
Plant
00
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit Description:
Emission Control Device Description:
Requested Overall VOC & HAP Control Efficiency %:
Limited Process Parameter k „�
Gas meter
Section 03- Processing Rate Information for Emissions Estimates
Actual Throughput =
6 MMscf per year
)i MMscf per year
Requested Permit Limit Throughput =
Requested Monthly Throughput = MMscf per month
Potential to Emit (PTE) Throughput =
Process Control (Recycling)
Equipped with a VRU:
Is VRU process equipment:
1 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
Separator Gas Heating Value:
Volume of waste gas emitted per BBL of
liquids throughput:
Section 04- Emissions Factors & Methodologies
-'-1372 Btu/scf
scf/bbl
MW
23.98
Weight %
Helium
-.:0.00
CO2
3.95
N2
- 0.47
methane
44.61
ethane
20.61
propane
26.57
isobutane
x;23
n -butane
isopentane
1756
n -pentane
6Z
cyclopentane
n -Hexane
8
cyclohexane
0:10
Other hexanes
30:00
heptanes
methylcyclohexane
9.11
224-TMP
Benzene
0.05
Toluene
..0.05
Ethylbenzene
: .0.05
Xylenes
0.0
C8+ Heavies
0.16
Total
VOC Wt %
Emission Factors
99.77
30.13
b/Ib-mol
Separator Venting
Uncontrolled
Pollutant (lb/MMscf)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Pollutant
PM10
PM2.5
SOx
NOx
Controlled
(lb/MMscf)
(Gas Throughput) (Gas Throughput)
19063.7836 953.1892
31.6359 1.5818
31.6359 1.5818
0.0000 0.0000
6.3272 0.3164
809.8786 40.4939
0.0000 0.0000
Primary Control Device
Uncontrolled Uncontrolled
(lb/MMBtu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Gas Throughput)
Displacement Equation
Ex=Q*MW*Xx/C
Emission Factor Source
0.0075
0.0075
10.223
189.336
10 of 23 K:\PA\2018\ 18WE1051.CP1.001-006.xlsm
Separator Venting Emissions Inventory
CO I .0:2755 I 377.986
11 of 23 K:\PA\2018\ 18WE1051.CP1.001-006.xlsm
Separator Venting Emissions Inventory
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions.
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
PM2.5
SOx
NOx
VOC
CO
0.00
0.00
0.00
0.00
0.00
0
0.00
0.00
0,00
0.00
0.00
0
0.00
0.00
0.00
0.00
0.00
0
0,05
0.05
0.05
0.05
0.05
9
5.36
5.36
0.27
5.36
0.27
45
0.11
0.11
0.11.
0.11
0.11
18
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (Its/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
18
18
1
18
1
18
18
1
18
1
0
0
0
0
0
4
4
0
4
0
455
455
23
455
23
0
0
0
0
0
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Section XVII.B, G
Regulation 7, Section XVII.B.2.e
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Sampling and Testing Requirements
Using Gas Throughput to Monitor Compliance
Source requires a permit
Source is subject to Regulation 7, Section XVII.B.2, G
The Control device for this separator is not subject to Regulation 7, Section XVII.B.2.e
Does the company use site specific emission factors based on a gas sample to estimate emissions?
This sample should represent the gas outlet of the equipment covered under this AIRs ID, and should have been 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 maybe appropriate to use an older site -specific sample.
If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis
to demonstrate that the emission factors are less than or equal to the emissions factors established with this application.
Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year?
If yes, the permit will contain:
*An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the
emission factors are less than or equal to the emissions factors established with this application.
-A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the
emission factors are less than or equal to the emissions factors established with this application on an annual basis.
Will the operator have a meter installed and operational upon startup of this point? No
If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to
exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03.
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
You have indicated above that the monitored process parameter is natural gas vented. The following questions do not require an answer.
12 of 23 K:\PA\2018\18WE1051.CP1.001-006.xlsm
Separator Venting Emissions Inventory
Section 08 - Technical Analysis Notes
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point #
Process # SCC Code
003 01 3-10-001-60 Flares
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 10.22 0 Ib/MMSCF
PM2.5 10.22 0 Ih/MMSCF
SOx 0.00 0 Ib/MMSCF
NOx 189.34 0 Ib/MMSCF
VOC 19063.78 95 lb/MMSCF
CO 377.99 0 Ib/MMSCF
Benzene 31.64 95 lb/MMSCF
Toluene 31.64 95 Ib/MMSCF
Ethylbenzene 0.00 95 lb/MMSCF
Xylene 6.33 95 lb/MMSCF
n -Hexane 809.88 95 Ib/MMSCF
224 TMP 0.00 95 lb/MMSCF
13 of 23 K:\PA\2018\ 18WE1051.CP1.001-006.xlsm
Separator Venting Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APES and Permit Requirements
Source Is In the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 IVY (Regulation 3, Part A, Section II.D.1.e)?
2. Aretotal facility uncontrolled VOC emissions greater than 5 TPY,NOX. greater than 1OTPY or CO emissions greater than 10 TPY (Regulation3, Part B, Section 11.0.3)?
Noteneugh Information
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from the individual source greater than)TPY (Regulation 3, Part A, Section ll.Dl.e)?
2. Are total facility uncontrolled VOC emissions from the greeter than 2 TPY,NOX greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.1.2)?
!Source requires a permit
Colorado Regulation 7. Section XVII
1. Was the well newly constructed, hydraulically fractured, or rerompleted on or after August 1, 2014?
'Source is subject to Regulation 7,Seotlon XVII.o.2, G
Section XVII.B.2—General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.G - Emissions Control
Alternative Emissions Control (Optional Section)
a. Is tuns separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed?
'Thecontrol device for this separator is not subjectto Regulation 7, Section XVILB.2e
Section XVII.B.2.e —Alternative emissions control equipment
Disclaimer
This document assists operators with determining applicability of certain requirements ofthe Clean Air Act its implementing regulations, and Air Quality Control Commission regulations. This document is
note rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act, its
implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," may,"
"should,"and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must"and "required" are intended to describe controlling requirements under the
'terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself.
1Source Req
1r Ii Source Rey
Source is su
The control
Separator Venting Emissions Inventory
004 Separator Venting
Facility AIRs ID:
County
9FF f9
Plant
004,.x` Mme;
Point
Section 02- Equipment Description Details
Detailed Emissions Unit Description:
Emission Control Device Description:
Requested Overall VOC & HAP Control Efficiency %:
Limited Process Parameter
Gas meter
Section 03- Processing Rate Information for Emissions Estimates
Primary Emissions - Separator
Actual Throughput
0.3.: MMscf per year
Requested Permit Limit Throughput 0.3i MMscf per year
Requested Monthly Throughput= MMscf per month
Potential to Emit (PTE) Throughput =
Process Control (Recycling)
Equipped with a VRU
Is VRU process equipment:
0 MMscf per year
Secondary Emissions - Combustion Device(s) for Air Pollution Control
Separator Gas Heating Value:
Volume of waste gas emitted per BBL of
liquids throughput:
Section 04- Emissions Factors & Methodologies
Description
b/Ib-mol Displacement Equation
Ex=O*MW*Xx/C
Weight %
Helium
0.00
CO2
+-' 4T30
N2
;1:0(29
methane
41,355
ADAM.
ethane.
x2292
propane
_v �g90.
isobutane
'. 1339
n -butane
isopentane.
r=t}2
n -pentane
;,1.72
cyclopentane
L''}0.11
n -Hexane
=' g2.18
cyclohexane
:;1,'0.09
Other hexanes
- •`10:00
heptanes
-k 023
methylcyclohexane
,'... 0.08
224-TMP
Jai@nn"tk<:trF0
Benzene
Toluene
'p^1004
Ethylbenzene
t.1:0 00
Xylenes
MIES 001
C8+ Heavies
- 000
Total
VOC Wt %
Emission Factors
Pollutant
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Pollutant
Btu/scf
cf/bbl
99.89
31.83
Separator Venting
Uncontrolled
(lb/MMscf) (lb/MMscf)
Controlled
(Gas Throughput)
(Gas Throughpu
20769.2850 1038.4642
32.6253 1.6313
26.1003 1.3050
0.0000 0.0000
6.5251 0.3263
769.9578 38.4979
0.0000 0.0000
Primary Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu) lb/MMscf Emission Factor Source
(Waste Heat
Combusted) (Gas Throughput)
Emission Factor Source
PM10 .0,007
PM2.5
SOx
NOx
10.521
10.521
194.856
15 of 23
K:\PA\2018\18 W E1051.CP1.001-006.xlsm
Separator Venting Emissions Inventory
CO 9.006
16 of 23 K:\PA\2018\ 18WE1051.CP1.0011006.xksm
Separator Venting Emissions Inventory
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
PM2.5
SOx
NOx
VOC
CO
0.00
D.00
0.00
0.00
0.00
0
0.00
0.00
0.00
0.00
0.00
0
0.00
0.00
0.00
0.00
0.00
0
0.03
0.03
0.03
0.03
0.03
5
3.22
3.22
0.16
3.22
0.16
27
0.06
0.06
0.06
0.06
0.06
10
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(Ibs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
10
10
1
10
1
8
8
0
8
0
0
0
0
0
0
2
2
0
2
0
239
239
12
239
12
0
0
0
0
0
Section 06 - Regulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Section XVII.B, G
Regulation 7, Section XVII.B.2.e
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Sampling and Testing Requirements
Using Gas Throughput to Monitor Compliance
Source requires a permit
Source is subject to Regulation 7, Section XVII.B.2, G
The control device for this separator is not subject to Regulation 7, Section XVII.B.2.e
Does the company use site specific emission factors based on a gas sample to estimate emissions?
This sample should representthe gas outlet of the equipment covered under this AIRs ID, and should have been collected within one year of the application received date. However,
if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample.
If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample trom the equipment being permitted and conduct an emission factor analysis
to demonstrate that the emission factors are less than or equal to the emissions factors established with this application.
Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year?
If yes, the permit will contain:
-An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the
emission factors are less than or equal to the emissions factors established with this application.
-A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the
emission factors are less than or equal to the emissions factors established with this application on an annual basis.
Will the operator have a meter installed and operational upon startup of this point? No
If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to
exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03.
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
You have indicated above thet the monitored process parameter is natural gas vented. The following questions do not require an answer
AIN
17 of 23 K:\PA\2018\ 18WE1051.CP1.001-006.xlsm
Separator Venting Emissions Inventory
Section 08 - Technical Analysis Notes
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point #
004
Process # SCC Code
01 3-10-001-60 Flares
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 10.52 0 lb/MMSCF
PM2.5 10.52 0 Ib/MMSCF
5Ox 0.00 0 lb/MMSCF
NOx 194.86 0 lb/MMSCF
VOC 20769.28 95 lb/MMSCF
CO 389.01 0 lb/MMSCF
Benzene 32.63 95 lb/MMSCF
Toluene 26.10 95 lb/MMSCF
Ethylbenzene 0.00 95 lb/MMSCF
Xylene 6.53 95 lb/MMSCF
n -Hexane 769.96 95 lb/MMSCF
224 TMP 0.00 95 lb/MMSCF
18 of 23 K:\PA\2018\18WE1051.CP1.001-006.xlsm
Separator Venting Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APEN and Permit Reouirements
mo"' ce Is In the Non-Attalnment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any critena pollutants from this Individual source greater than 2 SPY(Regulation 3, Part A, Section ll.D,1.a)?
2. Are total facility uncontrolled VOC emissions greater than 5 TPY, 000 greater than to TPY or CO emissions greater than 10TPY (Regulation 3, Part B, Section 11.0.31?
loot enough information
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1 TPY (Regulation 3, Part A, Section ll.D.1.a)?
2. Are total facility uncontrolled VOC emissions from the greater than 2TPY, NOx greater than 5TPY or CO emissions greater than 10TPY (Regulation3, Part B, Section 11.0.2)7
'Source requires a permit
Colorado Regulation 7, Section XVII
1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
(Source is subject to Regulation 7, Section XVII.B.2, G
Section XVII.B.2— General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.G- Emissions Control
Alternative Emissions Control (Optional Sectionj
a. Is this separator controlled by a back-up or alternate combustion device (i.e., not the prlmaryeantrol device) that is not enclosed?
'The control device for this separator Is not subject to Regulation 7, Section XVIl.B.2.e
Section XVII.B.2.e—Alternative emissions control equipment
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is
not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law,
regulation, or any other legally binding requirement and is not legally enforceable. 'Oho event of any conflict between the language of this document and the language of the C/ean Air Act„ its
implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," 'May,"
'should,"and 'can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and 'required"are intended to describe controlling requirements under the
terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself
ource Req
ource Req
rtirA e, iThe control
Section 01- Adminstrative Information
Facility AIRs ID:
123 :9FF6 005
County Plant Point
Section 02- Equipment Description Details
Detailed Emissions Unit Compressor blowdown events
Description:
Emission Control Device Emissions from this Source are not controlled.
Description:
Requested Overall VOC & HAP Control Efficiency %: 0
Section 03 - Processing Rate Information for Emissions Estimates
Compressor Slowdown Volume= - 2.71E-03 MMscf
Requested Compressor Slowdown Events= 100 events/year
Actual Compressor Slowdown Events= 0 events/year
Actual Gas Throughput = 0 MMscf per year
Requested Permit Limit Throughput = 2.71E-01 MMscf per year
Potential to Emit (PTE) Throughput = 2.71E-01 MMscf per year
Actual Gas Throughput While Emissions Controls Operating =
Section 04 - Emissions Factors & Methodologies
Emission Calculation Method
EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3)
ExoQ*MW *Xx/C
Ex = emissions of pollutant x
Q= Volumetric flow rate/volume of gas processed
MW = Molecular weight of gas = SG of gas* MW of air
Xx = mass fraction of x in gas
C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm
Throughput (0)
MW
2.71E-01
MMscf/yr
Ib/Ib-mol
3.10E+01
scf/yr
MMscf/d
22.6
0.000743562
mole 4
MW
Ibx/Ibmol
mass fraction
lb/hr
lb/yr
tpy
Helium
0.00•,.'
4.0026
0.000
0.000
0.00
0.00
0.00
CO2
1.92
-
44.01
0.845
0.037
0.07
605.09
0.30
N2
0.71
28.013
0.199
0.009
0.02
142.43
0.07
methane
71.95
".
16.041
11.541
0.511
0.94
8264.81
4.13
ethane
13.91
=.
30.063
4.182
0.185
0.34
2994.54
1.50
propane
°'-
7.38
;`i
44.092
3.254
0.144
0.27
2330.17
1.17
isobutane
0.75
58.118
0.436
0.019
0.04
312.14
0.16
n -butane
2.05
58.118
1.191
0.053
0.10
853.17
0.43
isopentane
0.36".
72.114
0.260
0.011
0.02
185.91
0.09
n -pentane
''
0.44
('
72.114
0.317
0.014
0.03
227.22
0.11
cyclopentane
0.03
70.13
0.021
0.001
0.00
15.07
0.01
n -Hexane
'.
0.26
86.18
0.224
0.010
0.02
160.45
0.08
cyclohexane
0.02
84.16
0.017
0.001
0.00
12.05
0.01
Other hexanes
.:..'
..'.
0,00
'.-
,:"-86,18
0.000
0.000
0.00
0.00
0.00
heptanes
'. `:
0.04
:.
100.21
0.040
0.002
0.00
28.70
0.01
methylcyclohexane
0.01
98.19
0.010
0.000
0.00
7.03
0.00
224-TMP
0.00
114.23
0.000
0.000
0.00
0.00
0.00
Benzene
0.01
._
'78.12
0.008
0.000
0.00
5.59
0.00
Toluene
_C
'0.01
'.
'.92.15
0.009
0.000
0.00
6.60
0.00
Ethylbenzene
..-.-
0.00
106.17
0.000
0.000
0.00
0.00
0.00
Xylenes
0.00
106.17
0.000
0.000
0,00
0.00
0.00
C8+ Heavies
• 0.01
114
0.011
0.001
0.00
8.16
0.00
VOC mass fractic 0.2566
MW 22.566
Total VOC (Uncontrolled)
2.08
Notes
Mole %, MW, and mass fractions are based on a representative gas sample .
Emissions are based on 100 compressor blowdown events per year.
The MW of C8+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable.
Section 05 - Emissions Inventory
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
41.52
lb/event
41.52 lb/event
2.08 tpy
2.08 tpy
Gas Analysis
Benzene
0.056
lb/event
0.056 lb/event
5.6 lb/yr
5.6 lb/yr
Mass Balance
Toluene
0.066
lb/event
0.066 lb/event
6.60 lb/yr
6.60 lb/yr
Mass Balance
Ethylbenzene
0.000
lb/event
0.000 lb/event
0.00 lb/yr
0.00 lb/yr
Mass Balance
Xylenes
0.000
lb/event
0.000 lb/event
0.00 lb/yr
0.00 lb/yr
Mass Balance
n -Hexane
1.605
lb/event
1.605 lb/event
160.45 lb/yr
160.45 lb/yr
Mass Balance
2,2,4-TMP
0.000
lb/event
0.000 lb/event
0.00 lb/yr
0.00 lb/yr
Mass Balance
Section 06 - Regulatory Summary Analysis
AQCC Regulation 1
18W E1051.CP1.001-006.xlsm
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in
excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions
measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation.
AQCC Regulation 2
Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable
odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has
been diluted with seven (7) or more volumes of odor free air."
Section 07 - Technical Analysis Notes
18W E1051.CP1.001-006.xlsm
Requested Compressor Blowdown Events=
Actual Compressor Blowdown Events=
Actual Gas Throughput =
Requested Permit Limit Throughput =
Potential to Emit (PTE) Throughput =
Section 01- Adminstrative Information
Facility AIRs ID:
123 9FFB 006..
County Plant Point
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Natural gas venting from pigging. Emissions from thissource are vented to the atmosphere.
unS(.5:e s!'�. .. nki.}..aa6�fe
Emission Control Device 'Emissions
Description:
Requested Overall VOC & HAP Control Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Compressor Blowdown Volume= 1.37E 03t MMscf
728 events/year
0 events/year
0 MMscf per year
1.15E+0D MMscf per year
1.15E+00 MMscf per year
E D' MMscf *for pig launching and pig receiving
8 everts/year
Actual Gas Throughput While Emissions Controls Operating =
Section 04- Emissions Factors & Methodologies
Emission Calculation Method
EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3)
Ex=Q*MW*Xx/C
Ex = emissions of pollutant x
Q = Volumetric flow rate/volume of gas processed
MW = Molecular weight of gas = SG of gas * MW of air
Xx = mass fraction of x in gas
C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm
Throughput (0.1
MW
1.15E+00
MMscf/yr
Ib/Ib-mol
1.31E+02
scf/yr
MMscf/d
22.6
0.003154334
mole%
MW
Ibx/Ibmol
mass fraction
lb/hr
lb/yr
tpy
Helium
'�.-,i"qc""'I 0.00
4.0026
0,000
0.000
0,00
0.00
0.00
CO2
1.90
]44.01
0.837
0.037
0.29
2541.53
1.27
N2
0.71
28.013
0.198
0.009
0.07
602.50
0.30
methane
:. 71.41
.: 16.041
11.455
0.506
3.97
34799.27
17.40
ethane
�_'`r� 13.82
30.063
4.154
0.183
1.44
12617.58
6.31
propane
7.35
44.092
3.240
0.143
1.12
9843.50
4.92
isobutane
0.75
58118
0.436
0.019
0.15
1325.90
0.66
n -butane
2.06
58.118
1.199
0.053
0.42
3642.26
1.82
isopentane
0.38
72.114
0.270
0.012
0.09
821.51
0.41
n -pentane
0.46
72.114
0.334
0.015
0.12
1014.29
0.51
cyclopentane
'. 0.03
70.13
0.022
0.001
0.01
66.04
0.03
n -Hexane
0.31
186.18
0.270
0.013
0.10
894.20
0.45
cyclohexane
0.03
84.16
0.021
0.001
0.01
63.92
0.03
Other hexanes
0.00
86.18
0.000
0.000
0.00
0.00
0.00
heptanes
0.08
100.21
0.075
0.003
0.03
228.31
0.11
methylcyclohexane
0.03
.98.19
0.026
0.001
0.01
77.55
0.04
224-TMP
0.00
- 114.23
0.000
0.000
0.00
0.00
0.00
Benzene
'- 0.01
78.12
0.011
0.001
0.01
61.91
0.03
Toluene
< 0.01
92.15
0.012
0.002
0.01
110.05
0.06
Ethylbenzene
0.00
106.17
0.001
0.000
0.00
27.51
0.01
Xylenes
0.01
106.17
0.006
0.001
0.01
55.03
0.03
C8+ Heavies
0.07
_ 114
0.075
0.003
0.03
228.57
0.11
VOC mass fractic
MW 22.643
Notes
0.2684 Total VOC (Uncontrolled)) 9.23
Mole %, MW, and mass fractions are based on a representative gas sample
Emissions are based on (14 x 52) pigging events per year.
The MW of 18+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable.
Section 05 - Emissions Inventory
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
25.36
lb/event
25.36 lb/event
18.46 tpy
18.46 tpy
Gas Analysis
Benzene
0.085
lb/event
0.085 lb/event
123.8 lb/yr
123.8 lb/yr
Mass Balance
Toluene
0,151
lb/event
0.151 lb/event
220.11 lb/yr
220.11 lb/yr
Mass Balance
Ethyl benzene
0.038
lb/event .
0.038 lb/event
55.03 lb/yr
55.03 lb/yr
Mass Balance
Xylenes
0.076
lb/event
0.076 lb/event
110.05 lb/yr
110.05 lb/yr
Mass Balance
n -Hexane
1.228
lb/event
1.228 lb/event
1788.39 lb/yr
1788.39 lb/yr
Mass Balance
2,2,4-TMP
0.000
lb/event
0.000 lb/event
0.00 lb/yr
0.00 lb/yr
Mass Balance
Section 06 - Regulatory Summary Analysis
AQCC Regulation 1
18 W E1051.CP1.001-006.xlsm
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in
excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions
measurement. is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation.
AQCC Regulation 2
Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable
odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has
been diluted with seven (7) or more volumes of odor free air."
Section 07 - Technical Analysis Notes
applicant has specified (14x52) events for each pig laucher, and pig receiver.
18 W E1051.CP 1.001-006. xlsm
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Permit number:
Date issued:
Issued to:
CONSTRUCTION PERMIT
18WE1051
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General
Description:
Issuance: 1
REP Processing, LLC
Severence Compressor Station
123/9FFB
NW SEC 8 T7N R66W
Weld County
Natural Gas Compressor Station
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Paint
Equipment Description
Emissions Control
Description
SK -4100
TEG
001
One (1) Triethylene glycol (TEG), natural gas
dehydration unit (make, model, serial
number: TBD) with a design capacity of 100
MMscf per day. This emissions unit is
equipped with one (1) electric driven glycol
pump with a design capacity of 25 gallons
per minute. This unit is equipped with a
flash tank, reboiler and still vent. Stripping
gas is injected into the still vent.
Emissions from the
still vent are routed
to an air-cooled
condenser and then
to the enclosed
combustion device.
Emissions from the
flash tank are routed
recycled to the plant
inlet.
FUG -1
002
Fugitive equipment leaks from a natural gas
compressor station
V-7000
003
Low pressure separator
Enclosed Flare
V-8100
004
Low pressure separator
Enclosed Flare
BD -1
005
Natural gas venting from compressor
blowdown events
No Control
Page 1 of 23
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
PG -1
006
Natural gas venting from pigging events
No Control
This permit is granted subject to all rules and regulations of the Colorado Air Quality Control
Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the
specific general terms and conditions included in this document and the following specific terms and
conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of
the latter of commencement of operation or issuance of this permit, by submitting a Notice of
Startup form to the Division for the equipment covered by this permit. The Notice of Startup
form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to
notify the Division of startup of the permitted source is a violation of Air Quality Control
Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the
revocation of the permit.
2. Within one hundred and eighty days (180) of the latter of commencement of operation or
issuance of this permit, compliance with the conditions contained in this permit shall be
demonstrated to the Division. It is the owner or operator's responsibility to self -certify
compliance with the conditions. Failure to demonstrate compliance within 180 days may result
in revocation of the permit. A self certification form and guidance on how to self -certify
compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-
permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.)
3. This permit shall expire if the owner or operator of the source for which this permit was issued:
(i) does not commence construction/modification or operation of this source within 18 months
after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit; (ii) discontinues construction for a period of eighteen months or
more; (iii) does not complete construction within a reasonable time of the estimated
completion date. The Division may grant extensions of the deadline. (Regulation Number 3,
Part B, Section III.F.4.)
F.4. )
4. The operator shall install a flow meter to monitor and record volumetric flow rate of natural
gas vented from separator(s) points covered by this permit. Until the flow meter is installed,
the operator shall monitor and record liquid produced through the separator(s) and estimate
the gas flow rate.
5. The operator shall complete all initial compliance testing and sampling as required in this
permit and submit the results to the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
6. Point(s) 001: The following information shall be provided to the Division within fifteen (15) days
of the latter of commencement of operation or issuance of this permit.
• The dehydrator manufacturer name, model number and serial number
• The glycol circulation pump manufacturer name and model number
Page 2 of 23
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
This information shall be included with the Notice of Startup submitted for the equipment.
(Reference: Regulation Number 3, Part B, III.E.)
7. The operator shall retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
8. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
)
Monthly Limits:
Facility
Equipment
ID
AIRS
Point
Pounds per Month
Emission
Type
PM2.5
NO.
VOC
CO
SK -4100
TEG"
001
---
683
3,605
1,387
Point
FUG -1
002
---
---
3,940
---
Fugitives
V-7000
003
---
---
46
---
Point
V-8100
004
---
---
28
---
Point
BD -1
005
---
---
346
---
Point
PG -1
006
---
---
3,110
---
Point
Note: Monthly limits are based on a 31 -day month.
The owner or operator shall calculate monthly emissions based on the calendar month.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds
per month.
Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per
month.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
Annual Limits:
Facility
Equipment
ID
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NO.
VOC
CO
SK -4100
TEG
001
---
4.1
21.3
8.2
Point
FUG -1
002
---
---
23.2
---
V-7000
003
---
---
0.3
---
Point
Page 3 of 23
COLORADO
Air Pollution Control Division
Department of Pubitc Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
V-8100
004
---
---
0.2
---
Point
BD -1
005
---
---
2.1
---
Point
PG -1
006
---
---
18.3
---
Point
Note: See "Notes to Permit Holder" for information on emission factors and methods used to
calculate limits.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per
year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
During the first twelve (12) months of operation, compliance with both the monthly and annual
emission limitations is required. After the first twelve (12) months of operation, compliance
with only the annual limitation is required.
Compliance with the annual limits, for criteria and hazardous air pollutants, shall be
determined on a rolling twelve (12) month total. By the end of each month a new twelve month
total is calculated based on the previous twelve months' data. The permit holder shall calculate
actual emissions each month and keep a compliance record on site or at a local field office with
site responsibility for Division review.
9. Point(s) 001: Compliance withthe emission limits in this permit shall be demonstrated by
running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent
extended wet gas analysis and recorded operational values, including: dry gas throughput, lean
glycol recirculation rate, flash tank temperature and pressure, wet gas inlet temperature, and
wet gas inlet pressure: Recorded operational values, except for gas throughput, shall be
averaged on a monthly basis for input into the model and be provided to the Division upon
request.
10. Point(s) 001: On a monthly basis, the owner or operator shall monitor and record operational
values including: flash tank temperature and pressure, wet gas inlet temperature and pressure.
These records shall be maintained for a period of five years.
11. The owner or operator shall operate and maintain the emission points in the table below with
the emissions control equipment as listed in order to reduce emissions to less than or equal to
the limits established in this permit. The owner or operator shall operate this dehydration unit
so as to prevent any emissions directly to the atmosphere. (Regulation Number 3, Part B,
Section III. E.)
Facility
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
SK -4100
TEG
001
Still Vent: Enclosed Flare
V0C and
HAP
Page 4 of 23
COLORADO
Air Pollution Control Division
Department of Public Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
V-7000
003
Enclosed Flare
VOC and
HAP
V-8100
004
Enclosed Flare
VOC and
HAP
12. The owner or operator shall operate and maintain the emission points in the table below as a
closed loop system and shall recycle 100% of emissions as described in the table below.
(Regulation Number 3, Part B, Section III.E.)
Facility
Equipment
ID
AIRS
Point
Emissions Recycling Description
Pollutants
Recovered
SK -4100
TEG
001
Flash Tank: Recycled to Plant Inlet
VOC and
HAP
PROCESS LIMITATIONS AND RECORDS
13. This source shall be limited to the following maximum processing rates as listed below. Monthly
records of the actual processing rates shall be maintained by the owner or operator and made
available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4. )
Process Limits
Facility
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
Monthly Limit
(31 days)
SK -4100
TEG
001
Dry Gas Throughput
36,500
MMscf/yr
3100
MMscf/month
V-7000
003
Natural Gas Venting
0.6 MMscf/yr
0.1 MMscf/month
V -810O
004
Natural Gas Venting
0.4 MMscf/yr
0.1 MMscf/month
BD -1
005
Compressor
Blowdown Events
100 events
---
PG -1
006
Pig Launching
728 events
---
Pig Receiving
728 events
---
The owner or operator shall monitor monthly process rates based on the calendar month. The
volume of dry gas throughput shall be measured by gas meter at the outlet of the dehydrator.
During the first twelve (12) months of operation, compliance with both the monthly and annual
throughput limitations is required. After the first twelve (12) months of operation, compliance
with only the annual limitation is required.
Compliance with the annual 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.
Page 5 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
14. Point(s) 001: This unit shall be limited to the maximum lean glycol circulation rate of 25 gallons
per minute. The lean glycol recirculation rate shall be recorded 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 (Loft) provisions under MACT HH. (Reference: Regulation Number 3, Part B,
II.A.4)
15. Point(s) 003, 004: The owner or operator shall continuously monitor and record the volumetric
flow rate of natural gas vented from the separator(s) using the flow meter. The owner or
operator shall use monthly throughput records to demonstrate compliance with the process
limits contained in this permit and to calculate emissions as described in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
16. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001)
shall be marked on the subject equipment for ease of identification. (Regulation Number 3,
Part B, Section III. E. ) (State only enforceable)
17. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
18. This source is subject to Regulation No. 7, Section XII.C General Provisions (State only
enforceable). All condensate collection, storage, processing and handling operations,
regardless of size, shall be designed, operated and maintained so as to minimize leakage of
volatile organic compounds to the atmosphere to the maximum extent practicable. The
operator shall comply with all applicable requirements of Section XII.
19. Point(s) 001: This source is subject to Regulation Number 7, Section XII.H. The operator shall
comply with all applicable requirements of Section XII and, specifically, shall:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for glycol natural gas dehydrators; and
• Ensure uncontrolled actual emissions of volatile organic compounds from the still vent
and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash
tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month
basis through the use of a condenser or air pollution control equipment. (Regulation
Number 7, Section XII.H.1.)
20. Point(s) 001: The combustion device covered by this permit is subject to Regulation Number
7, Section XVII.B.2 General Provisions (State only enforceable). If a flare or other combustion
device is used to control emissions of volatile organic compounds to comply with Section XVII,
it shall be enclosed; have no visible emissions during normal operations, as defined under
Regulation Number 7, XVII.A.17; and be designed so that an observer can, by means of visual
observation from the outside of the enclosed flare or combustion device, or by other convenient
means approved by the Division, determine whether it is operating 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;
Page 6 of 23
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• 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.
21. Point(s) 001: 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.
22. Point(s) 001: The glycol dehydration unit at this facility is subject to National Emissions
Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas
Production Facilities, Subpart HH. This facility shall be subject to applicable area source
provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation
Number 8, Part E, Subpart A and HH)
Page 7 of 23
COLORADO
Air Pollution Control Division
Department of Public Health t Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
MACT HH Applicable
Requirements
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) of this section.
Page 8 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
MACT HH Applicable
Requirements
Area Source
Outside UA/UC boundary
§63.764 (d)(2) -Each owner or operator of an area source not
located in a UA plus offset and UC boundary (as defined in
§63.761) shall comply with the provisions specified in paragraphs
(d)(2(i) through (iii) of this section.
§63.764 (d)(2)(i) - Determine the optimum glycol circulation rate
using the following equation:
Lo„=1.15* 3.0 gal TEG*(F*
1b1-12OO 24hr/day
Where:
LOPT = Optimal circulation rate, gal/hr.
F = Gas flowrate (MMSCF/D)
I = Inlet water content (lb/MMSCF)
O= 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
563.764 - General
the actual glycol circulation rate does not exceed the optimum
Standards
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 §63.774(f) and submit the Initial Notification in
accordance with the requirements in §63.775(c)(7). If operating
conditions change and a modification to the optimum glycol
circulation rate is required, the owner or operator shall prepare a
new determination in accordance with paragraph (d)(2)(i) or (ii)
of this section and submit the information specified under
§63.775(c)(7)(ii) through (v).
Page 9 of 23
COLORADO
Air Pollution Control Division
Department of Public Health Et Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
MACT HH Applicable
Requirements
Area Source
Outside UA/UC boundary
§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.
§b3.774 -
§63.774 (b)(1)(ii) - The most recent 12 months of records shall be
Recordkeeping
retained on site or shall be accessible from a central location by
Requirements
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.
Page 10 of 23
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
§63.775 - Reporting
Requirements
§63.775 (c) - Except as provided in paragraph (c)(8), each owner
or operator of an area source subject to this subpart shall submit
the information listed in paragraph (c)(1) of this section. If the
source is located within a UA plus offset and UC boundary, the
owner or operator shall also submit the information listed in
paragraphs (c)(2) through (6) of this section. If the source is not
located within any UA plus offset and UC boundaries, the owner
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 (c)(7)(iii) - If applicable, documentation of the alternate
glycol circulation rate calculated using GRI-GLYCalcTM, Version
3.0 or higher and documentation stating why the TEG dehydration
unit must operate using the alternate glycol circulation rate.
§63.775 (c)(7)(iv) - The name of the manufacturer and the model
number of the glycol circulation pump(s) in operation.
§63.775 (c)(7)(v) - Statement by a responsible official, with that
official's name, title, and signature, certifying that the facility
Page 11 of 23
COLORADO
Air Pollution Control Division
Department of Public Health 5 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
MACT HH Applicable
Requirements
Area Source
Outside UA/UC boundary
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.
23. Point(s) 002: The reciprocating compressors grouped with thefugitive emissions addressed by
AIRS ID 002 are subject to the New Source Performance Standards requirements of Regulation
No. 6, Part A, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas
Production, Transmission and Distribution including, but not limited to, the following:
• §60.5385(a) - Owner or operator must replace the reciprocating compressor rod packing
according to either paragraph §60.5385(a)(1) or (2).
(i) §60.5385(a)(1) - Before the compressor has operated for 26,000 hours. The number
of hours of operation must be continuously monitored beginning upon initial startup
of your reciprocating compressor affected facility, or October 15, 2012, or the date
of the most recent reciprocating compressor rod packing replacement, whichever
is later.
(ii) §60.5385(a)(2) - Prior to 36 months from the date of the most recent rod packing
replacement, or 36 months from the date of startup for a new reciprocating
compressor for which the rod packing has not yet been replaced.
• §60.5410 - Owner or operator must demonstrate initial compliance with the standards
as detailed in §60.5410(c).
• §60.5415 - Owner or operator must demonstrate continuous compliance with the
standards as detailed in §60.5415(c).
Page 12 of 23
COLORADO
Air Pollution Control Division
(department of Public Health b fnvibonment
Dedicated to protecting and improving the health and environment of the people of Colorado
• §60.5420 - Owner or operator must comply with the notification, reporting, and
recordkeeping requirements as specified in §60.5420(a), §60.5420(b)(1),
§60.5420(b)(4), and §60.5420(c)(3).
24. Point(s) 002: Minor sources in designated nonattainment or attainment/maintenance areas
that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply
Reasonably Available Control Technology for the pollutants for which the area is nonattainment
or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). LDAR
Requirements as required by the following condition shall satisfy the requirement to apply
Reasonably Available Control Technology (RACT).
25. Point(s) 002: Fugitive component leaks at this natural gas compressor station are subject to
the Leak Detection and Repair (LDAR) program requirements, including but not limited to:
monitoring, repair, re -monitoring, recordkeeping and reporting contained in Regulation 7,
Section XVII.F. In addition, the operator shall comply with the General Provisions contained in
Regulation 7, Section XVII.B.1.
26. Point(s) 003, 004: The combustion device covered by this permit is subject to Regulation
Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other
combustion device is used to control emissions of volatile organic compounds to comply with
Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined
under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of
visual observation from the outside of the enclosed flare or combustion device, or by other
convenient means approved by. the Division, determine whether it is operating properly. This
flare must be equippedwith 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.
OPERATING a MAINTENANCE REQUIREMENTS
27. Point(s) 001, 003, 004: Upon startup of these points, the owner or operator shall follow the
most recent operating and maintenance (O&M) plan and record keeping format approved by
the Division, in order to demonstrate compliance on an ongoing basis with the requirements of
this permit. Revisions to the O&M plan are subject to Division approval prior to implementation.
(Regulation Number 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
28. Point(s) 001: The owner or operator shall demonstrate compliance with opacity standards,
using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or
absence of visible emissions. "Visible Emissions" means observations of smoke for any period
Page 13 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
or periods of duration greater than or equal to one minute in any fifteen minute period during
normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.17)
29. Point(s) 001: 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.)
30. Point(s) 002: Within one hundred and eighty days (180) of the latter of commencement of
operation or issuance of this permit, the owner or operator shall complete the initial extended
gas analysis of gas samples that are representative of volatile organic compound (VOC) and
hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas
analysis shall be used in the compliance demonstration as required in the Emission Limits and
Records section of this permit. The operator shall submit the results of the gas analysis and
emission calculations to the Division as part of the self -certification process to ensure
compliance with emissions limits.
31. Point(s) 002: Within one hundred and eighty days (180) of the latter of commencement of
operation or issuance of this permit, the operator shall complete a hard count of components
at the source and establish the number of components that are operated in "heavy liquid
service", "light liquid service",''"water/oil service" and "gas service". The operator shall submit
the results to the Division as part of the self -certification process to ensure compliance with
emissions limits.
32. Point(s) 003, 004, 005, 006: The owner/operator shall complete an initial site specific
extended , gas analysis ("Analysis") within one hundred and eighty days (180) after
commencement of operation or issuance of this permit, whichever comes later, of the natural
gas vented from this emissions unit in order to verify the VOC, benzene, toluene, xylenes, and
n -hexane content (weight fraction) of this emission stream. Results of the Analysis shall be used
to calculate site -specific emission factors for the pollutants referenced in this permit (in units
of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis shall be
submitted to the Division as part of the self -certification and must demonstrate the emissions
factors established through the Analysis are less than or equal to, the emissions factors
submitted with the permit application and established herein in the "Notes to Permit Holder"
for this emissions point. If any site specific emissions factor developed through this Analysis is
greater than the emissions factors submitted with the permit application and established in the
"Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a
timeframe as agreed to by the Division, a request for permit modification to address this/these
inaccuracy(ies).
33. Point(s) 003, 004: The owner or operator shall demonstrate compliance with opacity
standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the
presence or absence of visible emissions. "Visible Emissions" means observations of smoke for
any period or periods of duration greater than or equal to one minute in any fifteen minute
period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.17)
Page 14 of 23
COLORADO
Air Pollution Control Division
Department of Public Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Periodic Testing Requirements
34. Point(s) 001: The owner or operator shall demonstrate compliance with opacity standards,
using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, on a weekly basis to determine
the presence or absence of visible emissions. "Visible Emissions" means observations of smoke
for any period or periods of duration greater than or equal to one minute in any fifteen minute
period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.17)
35. Point(s) 001: 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.
36. Point(s) 002: On an annual basis, the owner or operator shall complete an extended gas analysis
of gas samples that are representative of volatile organic compounds (VOC) and hazardous air
pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall
be usedin the compliance demonstration as required in the Emission Limits and Records section
of this permit.
ADDITIONAL REQUIREMENTS
37. 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 (NOr) in ozone
nonattainment areas emitting less than 100 tons of VOC or NOX per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on the
last APEN submitted; or
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or activity;
or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
Page 15 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
GENERAL TERMS AND CONDITIONS
38. 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.
39. If this permit specifically states that final authorization has been granted, then the remainder
of this condition is not applicable. Otherwise, the issuance of this construction permit does not
provide "final" authority for this activity or operation of this source. Final authorization of the
permit must be secured from the APCD in writing in accordance with the provisions of 25-7-
114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization
cannot be granted until the operation or activity commences and has been verified by the APCD
as conforming in all respects with the conditions of the permit. Once self -certification of all
points has been reviewed and approved by the Division, it will provide written documentation
of such final authorization. Details for obtaining final authorization to operate are located
in the Requirements to Self -Certify for Final Authorization section of this permit
40. 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.
41. 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.
42. 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.
43. 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.
44. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention
and Control Act or the regulations of the AQCC may result in administrative, civil or criminal
Page 16 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil
penalties), -122.1 (criminal penalties), C.R.S.
By:
Timothy Sharp
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to REP Processing, LLC.
Page 17 of 23
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder shall pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit.
(Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written
notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions
Regulation. See: 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
(lb/yr)
Controlled
Emissions
(lb/yr).
SK -4100
TEG
001
Benzene
71432
77,918
3,896
Toluene
108883
91,779
4,589
Ethylbenzene
100414
8,438
422
Xylenes
1330207
49,199
2,460
n -Hexane
110543
48,748
2,437
2,2,4-
Trimethylpentane
540841
60
3
FUG -1
002
Benzene
71432
179
179
Toluene
108883
551
551
Ethylbenzene
100414
149
149
Xylenes
1330207
706
706
n -Hexane
110543
4,491
4,491
2,2,4-
Trimethylpentane
540841
21
21
V-7000
003
Benzene
71432
18
1
Page 18 of 23
COLORADO
Air Pollution Control Division
Department of Public Health 6 Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
n -Hexane
110543
455
32
V-8100
004
Benzene
71432
9
1
n -Hexane
110543
236
16
BD -1
005
Benzene
71432
6
6
n -Hexane
110543
159
159
PG -1
006
Benzene
71432
65
65
Toluene
108883
74
74
n -Hexane
110543
1,637
1,637
Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates
above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on
the most recent Air Pollution Emission Notice.
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
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 flare control efficiency of 95%.
Total actual still vent combustion emissions are based onthe emissions for the still vent primary
control. Total combustion emissions are based on the following emission factors:
Still Vent Primary Control:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf Waste
Gas Combusted
Source
NOx
0.1380(lb/MMbtu)
TNRCC
CO
0.2775 (lb/MMbtu)
TNRCC
V0C
23.25
GlyCalc
71432
Benzene
2.13
GlyCalc
108883
Toluene
2.51
GlyCalc
100414
Ethylbenzene
0.23
GlyCalc
1330207
Xylenes
1.35
GlyCalc
110543
n -Hexane
1.34
GlyCalc
Note: The combustion emission factors are based on a heating value of 1211 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.
Point 002:
Page 19 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Component
Gas Service
Heavy Oil
Light Oil
Water/Oil
Service
Connectors
710
0
210
0
Flanges
360
0
20
0
Open-ended Lines
80
0
20
0
Pump Seals
10
0
50
0
Valves
640
0
110
0
Other*
50
0
50
0
VOC Content (wt.
fraction)
26.11%
100%
100%
100%
Benzene Content (wt.
fraction)
.04%
0.0%
0.5%
0.0%
Toluene Content (wt.
fraction)
0.04%
0.0%
1.9%
0.0%
Ethylbenzene (wt.
fraction)
-0.00%
0.0%
0.5%
0.0%
Xytenes Content (wt.
fraction)
0.02%
0.0% "
2.5%
0.0%
n -hexane Content
(wt. fraction)
1.12%
0.0%
13.4%
0.0%.
*Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms,
drains, dump arms, hatches, instrument meters, polish rods and vents
TOC Emission Factors (kg/hr-component):
Component
Gas Service
Heavy Oil
Light Oil
Oil
Service '
Connectors
2.0E-04
7.5E-06
2.1E-04
1.1E-04
Flanges
3.9E-04
3.9E-07
1.1E-04
2.9E-06
Open-ended Lines
2.0E-03
1.4E-04
1.4E-03
2.5E-04
Pump Seals
2.4E-03
NA
1.3E-02
2.4E-05
Valves
4.5E-03
8.4E-06
2.5E-03
9.8E-05
Other
8.8E-03
3.2E-05
7.5E-03
1.4E-02
Source: EPA -453/R95-017
Compliance with emissions limits in this permit will be demonstrated by using the TOC emission
factors listed in the table above with representative component counts, multiplied by the VOC
content from the most recent gas analysis.
As requested, light oil component counts shall include those in water/oil service.
Page 20 of 23
COLORADO
Air Pollution Control Division
Department of Public Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Point 003:
CAS #
Pollutant
Uncontrolled
Emission
Factors
(lb/MMSCF)
Controlled
Emission
Factors
(lb/MMSCF)
Source
NOx
0.1380 lb/MMbtu
TNRCC
CO
0.2755 lb/MMbtu
TNRCC
VOC
19,049.65
952.48
Source (Promax)
71432
Benzene
32.29
1.61
Source (Promax)
110543
n -Hexane
809.80
40.49
Source (Promax)
Note: The controlled emissions factors for this point are based on the flare control efficiency of
95%.
Point 004:
CAS #
Pollutant
Uncontrolled
Emission
Factors
(lb/MMSCF)
Controlled
Emission
Factors
(lb/MMSCF)
Source
NOx
0.1380 lb/MMbtu
TNRCC
CO
0.2755 lb/MMbtu
TNRCC
VOC
20,668.82
1,033.44 f
Source (Promax)
71432
Benzene
30.83
1.54
Source (Promax)
110543
n -Hexane
766.96
38.35
Source (Promax)
Note: The controlled emissions factors for this point are based on the flare control efficiency of
95%.
Point 005:
CAS #
Pollutant
Uncontrolled
Emission
Factors
(lb/event)
Source
VOC
42.52
Source (Promax)
71432
Benzene
0.056
Source (Promax)
110543
n -Hexane
1.605
Source (Promax)
Point 006:
CAS #
Pollutant
Uncontrolled
Emission
Factors
(lb/event)
Source
VOC
25.36
Source (Promax)
71432
Benzene
0.085
Source (Promax)
108883
Toluene
0.151
Source (Promax)
Page 21 of 23
COLORADO
Air Pollution Control Division
Department of Public Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
CAS #
Pollutant
Uncontrolled
Emission
Factors
(lb/event)
Source
110543
n -Hexane
1.228
Source (Promax)
Note: emission factor has been averaged to account for different event volumes between pig
launching and pig receiving.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to
the most recent annual fee invoice to determine the APEN expiration date for each emissions point
associated with this permit. For any questions regarding a specific expiration date call the Division
at (303)-692-3150.
7) This permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration unit
and associated control device per the Colorado Oil and Gas Conservation Commission rule
805b(2)(B) when applicable.
8) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of: NOx CO, VOC, HAPs
PSD or NANSR
Synthetic Minor Source of: NOx, "CO, VOC
MALT HH
Major Source Requirements: Not Applicable
Area Source Requirements: Applicable
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
Page 22 of 23
COLORADO
Air Pollution Control Division
Department of Public Health u Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart KKKK
NSPS
Part 60, Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source
Categories
MACT
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
Page 23 of 23
flcfL) Izv A/ ! - ScApiccded - 7,15
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, incl
updates. An application with missing information may be determined incomplete and may be returned orre
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 (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/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:
'S NEO CJ I AIRS ID Number: I2.3 MIFFMIFFEJ 001
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': REP Processing, LLC
Site Name: Severance Compressor Station
Site Location: NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address:
(Include Zip Code) 1611 N. Broadway Ave.
Oklahoma City, OK 73101
Site Location
County: Weld
NAICS or SIC Code: 211130
Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: (.king@rimrockenergy.com
' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
388095
1 fr
Hat�thbER.iraRntnt
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
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
O Change fuel or equipment O Change company name3 O Add point to existing permit
O Change permit limit O Transfer of ownership4 O Other (describe below)
OR
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑✓ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For tompany'naine change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: TEG Dehydration Unit
Company equipment Identification No. (optional): SK -4100 TEG Regeneration Skid
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is: April 2019
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Will this equipment be operated in any NAAQS
nonattainment area?
hours/day days/week
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 7/2018
❑✓
Yes
Yes
❑✓
weeks/year
No
No
.COLORADO
2 I ATT,
Puklie
H aIITb Elsmnmml
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer:
TBD
Dehydrator Serial Number:
TBD
Model Number:
Reboiler Rating:
TBD
1.5
MMBTU/hr
Glycol Used: O Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) ❑✓ TriEthylene Glycol (TEG)
Glycol Pump Drive: 0 Electric O Gas If Gas, injection pump ratio: / Acfm/gpm
Pump Make and Model: TBD
# of pumps:
Glycol Recirculation rate (gal/min): Max: 25
Lean Glycol Water Content:
0.5
Wt.%
Requested: 25
TBD
Dehydrator Gas Throughput:
Design Capacity: 100 MMSCF/day
Requested5: 100 MMSCF/year Actual: NA MMSCF/year
Inlet Gas: Pressure: 1177 psig Temperature: 120 °F
Water Content: Wet Gas: lb/MMSCF ❑✓ Saturated Dry gas: 7.0 lb/MMSCF
Flash Tank: Pressure: 150 psig Temperature: 140 °F O NA
Cold Separator: Pressure: psig Temperature: °F ❑✓ NA
Stripping Gas: (check one)
O None O Flash Gas 0 Dry Gas ❑ Nitrogen
Flow Rate: 18.8
scfm
Additional Required Information:
❑✓ Attach a Process Flow Diagram
O Attach GRI-GLYCalc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results)
❑✓ Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
coLoRADo
3I 1.
H�rttR bE}Vnnmenl
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)
UTM 516584.92 E, 4493368.49 N
ff
F-9500
10
1,500 4,684 (all sources to flare)
26.6 (all sources to flare)
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
✓❑ Circular
❑ Square/rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches): 23.4"
Interior stack width (inches): Interior stack depth (inches):
Section 6 - Control Device Information
0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑✓ Condenser:
Used for control of: Still Vent VOC & HAPs
Type: TBD
Make/Model:
Maximum Temp: 120 °F Average Temp:
Requested Control Efficiency: NA
TBD
°F
O VRU:
Used for control of:
Size:
Requested Control Efficiency:
VRU Downtime or Bypassed:
Make/Model:
%
%
✓❑ Combustion
Device:
Used for control of: Still Vent VOC & HAPs
Rating: MMBtu/hr
Type: Enclosed Flare Make/Model: TBD
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98 %
Minimum Temperature: °F Waste Gas Heat Content: 2197(dehyvent) Btu/scf
Constant Pilot Light: ❑✓ Yes 0 No Pilot Burner Rating: 0.07 MMBtu/hr
Closed
❑✓ Loop
System:
Used for control of: Flash Gas
Description: Recirculate flash gas back to compressor suction
System Downtime: 0
O Other:
Used for control of:
Description:
Requested Control Efficiency: %
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
COLORADO
4IATV
_ ;�
H°a{th6Envle°M1menl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOx
NO,
CO
VOC
Route still vent to condenser, then to enclosed combustor (Flash gas to be recirculated)
95%
HAPs
Route still vent to condenser, then to enclosed combustor (Flash gas to be recirculated)
95%
Other:
From what year is the following reported actual annual emissions data?
NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions('
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
7.5e-3
Ib/MMBtu
AP -42 (flare)
NA
NA
0
0.03
SOx
NA
NA
NA
0
0.00
NOx
0.138
Ib/MMBtu
TCEQ (flare)
NA
NA
0
3.66
CO
0.28
Ib/MMBtu
TCEQ (flare)
NA
NA
0
7.43
VOC
Process Simulation
GLYCaIc
NA
NA
589.47
19.96
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions('
(pounds/year)
Benzene
71432
Process Simulation
GLYCaIc
Toluene
108883
Process Simulation
GLYCaIc
Ethylbenzene
100414
Process Simulation
GLYCaIc
Xylene
1330207
Process Simulation
GLYCaIc
n -Hexane
110543
Process Simulation
GLYCaIc
2,2,4-
Trimethylpentane
540841
Process Simulation
GLYCaIc
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
COLORADO
5
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.
qb alt
Signature of Legally Autbi6rized Person (not a vendor or consultant) Date
Kevin Bailey
Chief Operating Officer
Name (print) Title
Check the appropriate box to request a copy of the:
O Draft permit prior to issuance
❑✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
AICOLO ai ADO
6 ��nO
HeailhbEnYliausenl
1-Fcb,,t)
Glycol Dehydration Unit APEN G i ►�
Form APCD-202 3(
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 ror result in
longer application processing times. You may be charged an additional APEN fee if the APEN i
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
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liqui
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.eov/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: 18WE1051 AIRS ID Number: 123 / 9FFB /OO
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name':
Site Name:
Site Location:
REP Processing, LLC
Severance Compressor Station
Site Location
NW 1/4, S8, T7N, R66W County: Weld
County Rd 27, Ault, CO 80610
Mailing Address:
(Include zip Code) 1611 N. Broadway Ave.
Oklahoma City, OK 73101
NAICS or SIC Code: 211130
Contact Person:
Phone Number:
E -Mail Address2:
Lance King
405-317-9587
l.king@rimrockenergy.com
I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear
on ail documents issued by the APCD. Any changes will require additional paperwork. •
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 1 I
COLORADO
C 7..nrr.o[ al Pat:.<
Permit Number: 1$W E 1051
AIRS ID Number:
123/0FF9/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source
- OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment 0 Change company name3 0 Add point to existing permit
O Change permit limit 0 Transfer of ownership4 0 Other (describe below)
OR -
▪ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑✓ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-1O6) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: TEG Dehydration Unit
Company equipment Identification No. (optional):
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is: ApnI-1a
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: t
Normal Hours of Source hours/day days/week weeks/year
Operation:
SK -4100 (TEG Regeneration Skid)
Will this equipment be operated in any NAAQS 0 Yes ❑ No
nonattainment area?
Is this unit located at a stationary source that is considered ❑ Yes ❑✓ No
a Major Source of (HAP) Emissions?
Form APCD-202 - Gtycol Dehydration Unit APEN - Revision 7/2018
VES COLORADO
Permit Number:
18WE1051 AIRS ID Number: 123 /9FFBI
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Dehydration Unit Equipment information
Manufacturer; TBD
Dehydrator Serial Number:
TBD
Glycol Used: O Ethylene Glycol (EG)
Glycol Pump Drive: ❑✓ Electric ❑ Gas
Pump Make and Model: TBD
Model Number: TBD
Reboiler Rating: 1.5
MMBTU/hr
❑ DiEthylene Glycol (DEG) ❑✓ TriEthylene Glycol (TEG)
If Gas, injection pump ratio:
Glycol Recirculation rate (gal/min): Max: 25
Lean Glycol Water Content:
0.5 Wt.%
Requested: 25
# of pumps:
Acfm/gpm
TBD
Dehydrator Gas Throughput:
Design Capacity: 100
MMSCF/day
Requesteds: 100 MMSCF/year
Actual: NA MMSCF/year
Inlet Gas: Pressure: 1 177 psig
Water Content: Wet Gas: lb/MMSCF
Flash Tank: Pressure: 1 50 psig
Cold Separator: Pressure: psig
Stripping Gas: (check one)
❑ None O Flash Gas ❑✓ Dry Gas O Nitrogen
Flow Rate: 18.8
scfm
Temperature:
Q Saturated
Temperature:
Temperature:
120
'F
Dry gas: 7.0 lb/MMSCF
140 o F
°F
El
NA
NA
Additional Required Information:
❑✓ Attach a Process Flow Diagram
▪ AttachGRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results)
❑✓ Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 3 Av
COLORADO
n.�:rtaen: of PcGuc
❑✓ Upward
❑ Horizontal
Permit Number: 1 8WE1051 AIRS ID Number: 123 /9FFB/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
N 4493368.39 E 516584.30
Operator
Stack ID No.
Discharge Height
Above Ground Level
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
(feet)
F-9500
10
1 ,500
4,684 (all sources to flare)
26.6 (all sources to flare)
Indicate the direction of the stack outlet: (check one)
❑ Downward
o Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular
❑ Square/rectangle
❑ Other (describe):
0 Upward with obstructing raincap
Interior stack diameter (inches): 23.4"
Interior stack width (inches): Interior stack depth (inches):
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Condenser:
Used for control of: - StitrVenf VOu & HAPs
Type: 1:8 2 Make/Model:
Maztmum °F Average Temp: °F
1( ' 1°I r" Requested Control Efficiency: NA
O VRU:
Used for control of:
Size:
Make/Model:
Requested Control Efficiency:
VRU Downtime or Bypassed:
❑ Combustion
Device:
Used for control of: Still Vent VOC & HAPs
Rating: MMBtu/hr
Type: Enclosed Flare Make/Model: TBD
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98 % to
4 ¢. kid, tip)
Minimum Temperature: °F Waste Gas Heat Content: °;l Btu/scf
Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: 0.07
MMBtu/hr
Closed
❑✓ Loop
System:
Used for control of: Flash Gas
Description: Recirculate flash gas back to compressor suction
System Downtime: 0 %
O Other:
Used for control of:
Description:
Requested Control Efficiency:
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 4 I
AY
COLORADO
Permit Number: 18W E 1051
AIRS ID Number: 123 / 9FFB /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction ):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOX
NO.
CO
VOC
(
Route still vent combustor (Flash gas to be recirculated)
95%
HAPS
Route still vent a _c_gocr.,11fflinclosed combustor (Flash gas to be recirculated)
95%
Other:
From what year is the following reported actual annual emissions data?
NA
N Q — N D �c Cp 1 PM re s L -{- -Pwv, (;fir" o t 1 i �S lc k�t� 2. ilrc s s cp-s
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
Uncontrolled
Basis
pM
7.5e-3
Ib/MMBtu
AP -42 (flare)
NA
NA
0
0.03
SOx
NA
NA
NA
0
0.00
NO.
0.138
Ib/MMBtu
TCEQ (flare)
NA
NA
0
1,0L3r66--
CO
0.28
Ib/MMBtu
TCEQ (flare)
NA
NA •
0
IC, Ile ZACT"
VOC
Proce emulation
l5/MNSCE
GLYCaIc
NA
NA
,-689: Y
--1O ' "
23 - ac
Sir
,2 l 22
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
(CAS)
( )
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
MM�
Source
(AP -42,
. etc.)
Mfg., ..
Uncontrolled
Emissions
(pounds/year)
(P y )
Controlled
Emissions6
(pounds/year)
Benzene
71432
Pro -Simulation
2, I3
GLYCaIc
Toluene
108883
Pr a rSimulation
, ,51
GLYCaIc
Ethylbenzene
100414
Pro imulation
0, 23
GLYCaIc
Xylene
1330207
RD:Zssimulation
i, 35
GLYCaIc
n -Hexane
.110543
Er4 Simulation
►, 34
GLYCaIc
2,2,4-
Trimethylpentane
540841
! 's -simulation
I .ti ye -3
GLYCaIc
Other:
4-
l�PiAW
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
COLORADO
5 I A. }rn:ne21Puelc
Permit Number: 18WE1051
AIRS ID Number: 123 I9FFe f
[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.
124/4
Signature of Legally Authorized Person (not a vendor or consultant) Date
Kevin Bailey
Chief Operating Officer
Name (print) Title
Check the appropriate box to request a copy of the:
Draft permit prior to issuance
Q Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018
i-'0
COLORADO
6
Ave Adend w.t WW2 -015
Fugitive Component Leak Emissions APEN 4r'≥
Form APCD-203 4°s`
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, i ing APEN
updates. An application with missing information may be determined incomplete and may be ret r - It in
longer application processing times. You may be charged an additional APEN fee if the APEN is
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for fugitive component leak emissions only. If your emission source does not fall into t
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/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: - 1%vvE} 051 AIRS ID Number: '23 /o1FF73/0042,
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name1:
Site Name:
REP Processing, LLC
Severance Compressor Station
Site Location: NW 1/4, S8, T7N, R66W
Mailing Address:
(Include Zip Code)
County Rd 27, Ault, CO 80610
1611 N. Broadway Ave.
Oklahoma City, OK 73101
Site Location Weld
County:
NAICS or SIC Code: 211130
Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: I.king@rimrockenergy.com
I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
388096
Ay coRAoo
HeII�M1 6 EnWroM1m<nt
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit ft and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source (check one below)
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
O Change process or equipment O Change company name3 O Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 O Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info £t Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
Company equipment Identification No. (optional): FUG -1
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is: April 2019
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal HouNf Source
Operation:
Facility Type:
❑ Well Production Facility5
❑✓ Natural Gas Compressor Stations
❑ Natural Gas Processing Plants
❑ Other (describe):
hours/day
days/week weeks/year
5 When selecting thatr)titystype, refer to definitions in Colorado Regulation No. 7, Section XVII.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
COLORADO
2 1 AY uep�rt O m AD
Neagh 6 EnNronn¢n�
Permit Number: AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 4 - Regulatory Information
What is the date that the equipment commenced construction?
Will this equipment be operated in any NAAQS nonattainment area?
Will this equipment be located at a stationary source that is considered a
Major Source of Hazardous Air Pollutant (HAP) emissions?
Are there wet seal centrifugal compressors or reciprocating compressors
located at this facility?
Is this equipment subject to 40 CFR Part 60, Subpart KKK?
Is this equipment subject to 40 CFR Part 60, Subpart OOOO?
Is this equipment subject to 40 CFR Part 60, Subpart OOOOa?
Is this equipment subject to 40 CFR Part 63, Subpart HH?
Is this equipment subject to Colorado Regulation No. 7, Section XII.G?
Is this equipment subject to Colorado Regulation No. 7, Section XVII.F?
Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3?
TBD; expected 4Q 2018
✓❑ Yes
❑ Yes
❑✓ Yes
❑ Yes
✓❑ Yes
✓❑ Yes
❑✓ Yes
❑ Yes
ID Yes
❑✓ Yes
❑ No
❑✓ No
❑ No
❑✓ No
❑ No
❑ No
❑ No
✓❑ No
❑ No
❑ No
Section 5 - Stream Constituents
❑✓ The required representative gas and liquid extended analysis (including BTEX) to support the data below has
been attached to this APEN form.
Use the following table to report the VOC and HAP weight % content of each applicable stream.
Stream
VOC
(wt %)
Benzene
(wt %)
Toluene
(wt %)
Ethylbenzene
(wt %)
Xylene
(wt %)
n -Hexane
(wt %)
2,2,4
Trimethylpentane
(wt %)
Gas
26.11
0.04
0.04
0.004
0.02
1.12
0.00
Heavy Oil
(or Heavy Liquid)
NA
NA
NA
NA
NA
NA
NA
Light Oil
(or Light Liquid)
100
0.54
1.90
0.54
2.54
13.44
0.07
Water/Oil
Section 6 - Geographical Information
Geographical Coordinates
(Latitude/Longitude or UTM)
UTM N 4493424.09, E 516573.65 - approx. center of facility
Attach a topographic site map showing location
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
3 1 ��COLORADO
� Haa�iN6EnWronmen�
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Leak Detection and Repair (LDAR) and Control Information
Check the appropriate boxes to identify the LDAR program conducted at this site:
❑ LDAR per 40 CFR Part 60, Subpart KKK
❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump
0 Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump
✓❑ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa
❑ Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81%
connectors
❑✓ LDAR per Colorado Regulation No. 7, Section XVII.F
0 Other6:
0 No LDAR Program
6 Attach other supplemental plan to APEN form if needed.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018 4 I A'
COLORADO
Enviro
T<IFO
HeTlIT 6 nment
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emission Factor Information
Select which emission factors were used to estimate emissions below. If none apply, use the table below to
identify the emission factors used to estimate emissions. Include the units related to the emission factor.
El Table 2-4 was used to estimate emissions7.
❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions7.
Use the following table to report the component count used to calculate emissions. The component counts listed
in the following table are representative of:
✓❑ Estimated Component Count
❑ Actual Component Count conducted on the following date:
Service
Equipment Type
Open -Ended
Connectors Flanges Pump Seals Valves Other
Lines
9
Gas
Counts
710
360
80
10
640
50
Emission Factor
0.00044
0.00086
0.00441
0.00529
0.00992
0.01940
Units
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
Heavy Oil (or Heavy Liquid)
Counts
0
0
0
0
0
0
Emission Factor
Units
Light Oil (or Light Liquid)
Counts
210
20
20
50
110
50
Emission Factor
0.00046
0.00024
0.00031
0.02866
0.0055
0.0194
Units
lb/hr/component
lb/hr/component
lb/hr/component
Ib/hr/component
lb/hr/component
lb/hr/component
Water/Oil
Counts
0
0
0
0
0
0
Emission Factor
(assume all
liquid compo
nents are in
HC, light
liquid service
-)
Units
' Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R-
95-017).
8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual
Calendar Year Emissions" below.
9 The "Other" equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump
seals, or valves.
Form APCD-2O3 - Fugitive Component Leak Emissions APEN - Revision 7/2018
[��I COLORADO
5 l �/JL!l Hamwem
ilM 6 EnW10RMlnl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
From what year is the following reported actual annual emissions data?
NA
Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source:
(Use the data reported in Section 8 to calculate these emissions.)
Chemical Name
CAS
Number
•
Actual Annual Emissions
Annual Requested AL� Permit Emission
11
Uncontrolled
(tons/year)
Controlled10
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year)
VOC
NA
NA
17.84
17.84
Does the emissions source have any actual emissions of non -criteria pollutants
(e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
0✓ Yes ❑ No
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
Chemical Name
CAS
Number
Actual Annual Emissions
Requested limit s nual Permit Emission
( )11
Uncontrolled
(lbs/year)
Controlled10
{lbs/year)
Uncontrolled `
(lbs/year)
Controlled
(lbs/year)
Benzene
71432
NA
NA
129.62
129.62
Toluene
108883
NA
NA
385.52
385.52
Ethylbenzene
100414
NA
NA
103.29
103.29
Xylene
1330207
NA
NA
488.84
488.84
n -Hexane
110543
NA
NA
3,252.99
3,252.99
2'2'4 y p
Trimeth l entane
540841
NA
NA
20.52
20.52
Other:
10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count
variability, and gas composition variability.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
!COLORADO
6 I xeWnsfuvl,aon n�
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit tt and AIRS ID]
Section 10 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
Signature of Legally Au rized Person (not a vendor or consultant) Date
Kevin Bailey Chief Operating Officer
Name (print) Title
Check the appropriate box to request a copy of the:
❑ Draft permit prior to issuance
El Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
7i AV
COLORADO
Departreacti eaPutilc
Health& Enalronmtml
Fugitive Component Leak Emissions AP
Form APCD-203
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 •i 'EN
updates. An application with missing information may be determined incomplete and may be r
longer application processing times. You may be charged an additional APEN fee if the APEN is
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for fugitive component leak emissions only. If your emission source does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.Rov/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:
(14 toil
AIRS ID Number: I �3 /91'FA / c O
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Site Location:
Mailing Address:
REP Processing, LLC
Severance Compressor Station
NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
(Include Zip Code) 1611 N. Broadway Ave.
Oklahoma City, OK 73101
Site Location WeIA
ld
County:
NAICS or SIC Code: 211130
Contact Person:
Phone Number:
E -Mail Address2:
Lance King
405-317-9587
(.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
COLORADO
1I�" :H�
e.YN 6Fiat,"t
iun.r.1
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)
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change process or equipment ❑ Change company name3 ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 O Other (describe below)
- OR
▪ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
Company equipment Identification No. (optional): FUG -1
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is: April 2010 2Q2019
✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Facility Type:
❑ Well Production Facility5
✓❑ Natural Gas Compressor Stations
❑ Natural Gas Processing Plants
o Other (describe):
hours/day
days/week weeks/year
5 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018 2
;COLORADO
vemefu of A:tUc
)lf
-. Health 6 Enuffafunael
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Regulatory Information 2Q2019
What is the date that the equipment commenced construction? TBD; expected /1Q 2018
Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No
Will this equipment be located at a stationary source that is considered a ❑ Yes 0 No
Major Source of Hazardous Air Pollutant (HAP) emissions?
Are there wet seal centrifugal compressors or reciprocating compressors 0 Yes ❑ No
located at this facility?
Is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑ Yes 0 No
Is this equipment subject to 40 CFR Part 60, Subpart 0000? 0 Yes ❑ No
Is this equipment subject to 40 CFR Part 60, Subpart 0000a? 0 Yes ❑ No
Is this equipment subject to 40 CFR Part 63, Subpart HH? 0 Yes ❑ No
Is this equipment subject to Colorado Regulation No. 7, Section XII.G? ❑ Yes 0 No
Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? 0 Yes 0 No
Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? 0 Yes O No
Section 5 - Stream Constituents
0 The required representative gas and liquid extended analysis (including BTEX) to support the data below has
been attached to this APEN form.
Use the following table to report the VOC and HAP weight % content of each applicable stream.
Stream
VOC
(wt %)
Benzene
(wt %)
Toluene
(wt %)
Ethylbenzene
(wt %)
Xylene
(wt %)
n -Hexane
(wt %)
2,2,4
Trimethylpentane
(wt %)
Gas
26.11
0.04
0.04
0.004
0.02
1.12
0.00
Heavy Oil
(or Heavy Liquid)
NA
NA
NA
NA
NA
NA
NA
Light Oil
(or Light Liquid)
100
0.54
1.90
0.54
2.54
13.44
0.07
Water/Oil
Section 6 - Geographical Information
Geographical Coordinates
(Latitude/Longitude or UTM)
UTM N 4493424.09, E 516573.65 - approx. center of facility
Attach a topographic site map showing location
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
COLORADO
31 • ?
H.� 6EntlVGnmetl
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Leak Detection and Repair (LDAR) and Control Information
Check the appropriate boxes to identify the LDAR program conducted at this site:
LDAR per 40 CFR Part 60, Subpart KKK
O Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid
pump
O Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump
0✓ LDAR per 40 CFR Part 60, Subpart 0000/0000a
Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81%
connectors
❑✓ LDAR per Colorado Regulation No. 7, Section XVII.F
O Other6:
O No LDAR Program
6 Attach other supplemental plan to APEN form if needed.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018 4
COLORADO
N�ot9s6 EnWeGnment
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Emission Factor Information
Select which emission factors were used to estimate emissions below. If none apply, use the table below to
identify the emission factors used to estimate emissions. Include the units related to the emission factor.
❑✓ Table 2-4 was used to estimate emissions7.
❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions7.
Use the following table to report the component count used to calculate emissions. The component counts listed
in the following table are representative of:
❑✓ Estimated Component Count
❑ Actual Component Count conducted on the following date:
Service
Equipment Type
Connectors
Flanges
Open -Ended
Lines
Pump Seals
Valves
Other 9
Gas
Count8
710
360
80
10
640
50
Emission Factor
0.00044
0.00086
0.00441
0.00529
0.00992
0.01940
Units
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
Heavy Oil (or Heavy Liquid)
Count8
0
0
0
0
0
0
Emission Factor
Units
Light Oil (or Light Liquid)
Count8
210
20
20
50
110
50
Emission Factor
0.00046
0.00024
0.00031
0.02866
0.0055
0.0194
Units
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
lb/hr/component
Water/Oil
Count8
0
0
0
0
0
0
Emission Factor
(assume all
liquid compo
nents are in
HC, light
liquid service
)
Units
7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R-
95-017).
8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual
Calendar Year Emissions" below.
9 The "Other" equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump
seals, or valves.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
!COLOR.ADO
5 I �.` MT's -Meant ofP,w.
"WN 6Envlifinmrnl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
From what year is the following reported actual annual emissions data?
NA
Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source:
(Use the data reported in Section 8 to calculate these emissions.)
Chemical Name
CAS
Number
Actual Annual Emissions
Requested Annual Permit Emission
Limit(s)11
Uncontrolled
(tons/year)
Controlled10
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year)
voC
NA
NA
17.84
17 84
23.19
23.19
Does the emissions source have any actual emissions of non -criteria pollutantsEl Yes O No
(e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
Chemical Name
CAS
Number
Actual Annual Emissions
Requested Annual
Limit(s)11Permit Emission
Uncontrolled
(Ibs/year)
Controlled10
(lbs/year)
Uncontrolled
(lbs/year)
Controlled
(lbs/year)
Benzene
71432
NA
NA 178.97
129.02
129.02
Toluene
108883
NA
NA 550.58
385.52
385.52
Ethylbenzene
100414
NA
NA 149.20
103.29
103.20
Xylene
1330207
NA
NA 706.34
188.81
488.84
n -Hexane
110543
NA
NA 4,490.53
3,252.00
3,252.03 4,
2,2,4
Trimethylpentane
540841
NA
NA 2C.52
20.52
20.2
Other:
10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count
variability, and gas composition variability.
COLORADO
178.97
550.58
149.20
706.34
490.53
20.52
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018 6
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 10 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
4i7-7;va- R�l q�i8
Signature of Legally Au rized Person (not a vendor or consultant) Date
Kevin Bailey Chief Operating Officer
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 $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
COLORADO
7 I b I oepvwm ethpllc
NuMbGWeemoll
Gas Venting APEN - Form APCD-211
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 gas venting only. Gas venting includes emissions from gas/liquid se arato h
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does no fall i
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbo
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the •
Air Pollution Control Division (APCD) website at: www.colorado.gov/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: 1$ vve 061 AIRS ID Number: 123 OFFS P /003
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': REP Processing, LLC
Site Name: Severance Compressor Station
Site Location: NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address: 1611 N. Broadway Ave.
(Include Zip Code)
Oklahoma City, OK 73101
Site Location
County: Weld
NAICS or SIC Code: 211130
Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: (.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
388097
1iAY
COLORADO
Heath
NdFoyle
HeatlT 6EnWronmeN
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
- OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment 0 Change company name3 ❑ Add point to existing permit
0 Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Ft Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Vessel V-7000 will be a 3 -phase separator used
to separate gas, hydrocarbon liquid, and water at a natural gas compressor station.
Company equipment Identification No. (optional): V-7000
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
April 2019
nCheck this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Will this equipment be operated in any NAAQS
nonattainment area?
hours/day
Is this equipment located at a stationary source that is
considered a Major Source of (HAP) Emissions?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
Form APCD-211 - Gas Venting APEN - Revision 7/2018
days/week weeks/year
Yes
Yes
Yes
❑ No
0 No
❑ No
COLORADO
2 ' AVImm�fr rnn.e
H��i=I1tb ETW.aninrnl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
❑✓ Gas/Liquid Separator
O Well Head Casing
❑ Pneumatic Pump
Make: Model:
Compressor Rod Packing
Make: Model:
❑ Blowdown Events
# of Events/year:
❑ Other
Description:
Serial #: Capacity: gal/min
# of Pistons: Leak Rate: Scf/hr/pist
Volume per event: MMscf/event
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy?
Gas Venting
Process Parameterss:
Liquid Throughput
Process Parameterss:
Vented Gas
Properties:
O Yes ❑✓ No
Vent Gas
Heating Value:
1,372
BTU/SCF
Requested:
0.562
MMSCF/year
Actual:
NA
MMSCF/year
-OR-
Requested:
bbl/year
Actual:
bbl/year
Molecular Weight:
23.98
VOC (Weight %)
30.15
Benzene (Weight %)
0.05
Toluene (Weight %)
0.05
Ethylbenzene (Weight
0.00
Xytene (Weight %)
0.01
n -Hexane (Weight %)
1.28
2,2,4-Trimethylpentane
(Weight %)
0.00
Additional Required Information:
❑✓ Attach a representative gas analysis (including BTEX & n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX & n -Hexane, temperature, and
pressure)
s Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
3I AY
COLORADO
Ikpe.,msneet Palk
Heath Envttnnment
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
❑ Horizontal
Geographical Coordinates
(Latitude/Longitude or UTM)
UTM 516584.92 E, 4493368.49 N
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular
O Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
23.4"
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed:
Combustion
Device:
Pollutants Controlled: VOC, HAPs
Rating:
Type: enclosed flare Make/Model: TBD
MMBtu/hr
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: Waste Gas Heat Content:
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating:
(V-7000only) 1,372
0.07
Btu/scf
MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
4 I • Iwwnavv
IOrysrtman dPnNlc
Haaitnb E�Nmnmenl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOx
NO,
CO
VOC
Enclosed combustor (Main Flare)
95%
HAPs
Enclosed combustor (Main Flare)
95%
Other:
From what year is the following reported actual annual emissions data? NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
7.5e-3
lb/MMBtu
AP -42
NA
NA
0
0.00
SOx
NA
NA
0
0.00
NOx
0.138
Ib/MMBtu
TCEQ
NA
NA
0
0.05
CO
0.28
Ib/MMBtu
TCEQ
NA
NA
0
0.11
VOC
Process Simulation
ProMax
NA
NA
5.35
0.27
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
CAS Service
( )
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
Process Simulation
ProMax
Toluene
108883
Process Simulation
ProMax
Ethylbenzene
100414
Process Simulation
ProMax
Xylene
1330207
Process Simulation
ProMax
n -Hexane
110543
Process Simulation
ProMax
2,2,4-540841
Trimethylpentane 1p
Process Simulation
ProMax
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
51
COLORADO
.
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.
Signature of Legally Aurized Person (not a vendor or consultant)
q/I ff M
Date
Kevin Bailey Chief Operating Officer
Name (please print) Title
Check the appropriate box to request a copy of the:
O Draft permit prior to issuance
❑✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.Rov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018
6 I AiCO�RADO
HeWlt�6 EnWo.unvnl
CAIVz,t)
So
Gas Venting APEN - Form APCD-211
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, inclu
updates. An application with missing information may be determined incomplete and may be returned o
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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.sov/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: I$ NE 051
AIRS ID Number: I22 /qp / 0 M„
[Leave blank unless APCD has already assigned a permit # and AIRS ID] �"!
Section 1 - Administrative Information
Company Name': REP Processing, LLC
Site Name: Severance Compressor Station
Site Location: NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address: 1611 N. Broadway Ave.
(Include Zip Code)
Oklahoma City, OK 73101
Site Location
County: Weld
NAICS or SIC Code: 211130
Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: I.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
388098
��COLORADO
xeamsen+nronmwu
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
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
D Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
❑ Change permit limit 0 Transfer of ownership' O Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑✓ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info & Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Vessel V-8100 will be a liquid condensate surge vessel
used to collect condensate product immediately prior to sending condensate into sales pipeline.
Company equipment Identification No. (optional): V-8 1 00
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
April 2019
X❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Will this equipment be operated in any NAAQS
nonattainment area?
hours/day
Is this equipment located at a stationary source that is
considered a Major Source of (HAP) Emissions?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
Form APCD-211 - Gas Venting APEN - Revision 7/2018
days/week weeks/year
❑✓ Yes
O Yes
❑ Yes
❑ No
❑✓ No
❑✓ No
COLORADO
2 I AV
➢cpawmne oe weu�
r+.imsFAVmmt
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
❑✓ Gas/Liquid Separator
El Well Head Casing
O Pneumatic Pump
Make: Model:
❑ Compressor Rod Packing
Make: Model:
❑ Blowdown Events
# of Events/year:
❑ Other
Description:
Serial #: Capacity: gal/min
# of Pistons: Leak Rate: Scf/hr/pist
Volume per event: MMscf/event
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑✓ No
Vent Gas
Heating Value:
1 412
BTU/SCF
Requested:
O.31
MMSCF/year
Actual:
NA
MMSCF/year
-OR-
Requested:
bbl/year
Actual:
bbl/year
Molecular Weight:
24.73
VOC (Weight %)
31.85
Benzene (Weight %)
0.05
Toluene (Weight %)
0.04
Ethylbenzene (Weight
on
0.00
Xytene (Weight %)
0.01
n -Hexane (Weight %)
1.18
2,2,4-Trimethylpentane
(Weight %)
00
Additional Required Information:
❑✓ Attach a representative gas analysis (including BTEX £t n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX It n -Hexane, temperature, and
pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
AY COLORADO
3 per
HBab�6Envlronment
Form APCD-211 - Gas Venting APEN - Revision 7/2018
❑✓ Upward
❑ Horizontal
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
UTM 516584.92 E, 4493368.49 N
Y L
'"
y5u�.
R �
D
) r ) I
o i -� i 3
-'
R¢�'e''a`
�"1
}
f f F f , )
iY�
b'k^
wy� A
2 ,.
.
�i' L - Fn
ggSSff
,+s4
F-9500
10
1,500
4,684 (all sources to flare)
26.6 (all sources to flare)
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular
❑ Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
23.4"
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
O VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed:
❑✓ Combustion
Device:
Pollutants Controlled: VOC, HAPs
Rating: MMBtu/hr
Type: enclosed flare Make/Model: TBD
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature:
Waste Gas Heat Content: (VAI00 ONLY) 1,412 Btu/scf
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating: 0.07' MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
1L Vt. V NAI
4 I AV '�b;w
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SO,
NO,
CO
VOC
Enclosed combustor (Main Flare)
95%
HAPs
Enclosed combustor (Main Flare)
95%
Other:
From what year is the following reported actual annual emissions data? NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
7.5E-3
Ib/MMBtu
AP -42 (flare)
NA
NA
0
0.00
SOx
NA
NA
0
0.00
NO,
0.138
Ib/MMBtu
TCEQ (flare)
NA
NA
0
0.03
CO
0.28
Ib/MMBtu
TCEQ (flare)
NA
NA
0
0.06
VOC
Process Simulation
ProMax
NA
NA
3.17
0.16
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
Process Simulation
ProMax
Toluene
108883
Process Simulation
ProMax
Ethylbenzene
100414
Process Simulation
ProMax
Xylene
1330207
Process Simulation
ProMax
n -Hexane
110543
Process Simulation
ProMax
2,2,4-
Trimethylpentane
540841
Process Simulation
ProMax
Other:
5 Requested values will become permit [imitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
5I
NlirCOLORADO
Ce ate-^- :v r.r,.
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.
Kw --
Signature of Legally Aut ized Person (not a vendor or consultant) Date
Kevin Bailey Chief Operating Officer
Name (please print) Title
Check the appropriate box to request a copy of the:
O Draft permit prior to issuance
p✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018 6 I AV
Dcpartmant
COLORADO
lc
Healthh6Ej Uun aef rt
j pt i P>de,Lf - (2,
,ccr✓�ENED
SEP 2 5 2019
AP�Ib
StaciagA.rE
Sourer,'•
Gas Venting APEN - Form APCD
Air Pollutant Emission Notice (APEN) and‘VO
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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.Rov/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: i g IN E I 0 5 I AIRS ID Number: 123 /q FP / 605
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': REP Processing, LLC
Site Name: Severance Compressor Station
Site Location: NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address: 1611 N. Broadway Ave.
(Include Zip Code)
Site Location
County: Weld
NAICS or SIC Code: 211130
Oklahoma City, OK 73101 Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: I.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
V8VS9
COLORADO
1 I ��I.^°^°o,
Heath 6 kTW�onment
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
O NEW permit OR newly -reported emission source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
O Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info ft Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Routine, planned compressor blowdowns - majority of gas to
be directed to compressors' suction line; remaining gas volume (below suction pressure) will be vented.
Company equipment Identification No. (optional): BD -1
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
April 2019
❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
see next page hours/day
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?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
R ,
F r'
Form APCD-211 - Gas Venting APEN - Revision 7/2018
days/week weeks/year
Yes
Yes
Yes
❑ No
❑✓ No
❑✓ No
IFIV,COLORADO
CI
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
❑ Gas/Liquid Separator
El Well Head Casing
O Pneumatic Pump
Make: Model:
Compressor Rod Packing
Make:
❑� Blowdown Events
# of Events/year:
❑ Other
Description:
Serial it:
Capacity: gal/min
Model: # of Pistons: Leak Rate: Scf/hr/pist
100
Volume per event: 0.0105
MMscf/event
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑✓ No
Vent Gas
Heating Value:
1 305
BTU/SCF
Requested:
1 .05
MMSCF/year
Actual:
NA
MMSCF/year
-OR-
Requested:
bbl/year
Actual:
bbl/year
Molecular Weight:
22.60
VOC (Weight %)
25.69
Benzene (Weight %)
0.04
Toluene (Weight %)
0.03
Ethylbenzene (Weight
°LIXylene
0.00
(Weight %)
0.01
n -Hexane (Weight %)
0.98
2,2,4-Trimethylpentane
(Weight %)
0'00
Additional Required Information:
❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX a n -Hexane, temperature, and
pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
COLORADO
Haat4.6Envlronmrni
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
Geographical Coordinates
(Latitude/Longitude or UTM)
NA
O Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
0 Other (describe):
Interior stack diameter (inches):
O Upward with obstructing raincap
Section 6 - Control Device Information
❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed:
❑ Combustion
Device:
Pollutants Controlled:
Rating: MMBtu/hr
hr
Type: Make/Model:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency: %
Minimum Temperature: Waste Gas Heat Content: Btu/scf
Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
L V IV ItAVV
4�.alwla�
ff atmftnasa.neiloomall
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SO,
NO,
CO
VOC
HAPs
Other:
From what year is the following reported actual annual emissions data?
NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
SOX
NO,
CO
VOC
Process Simulation
ProMax
NA
NA
8.05
8.05
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
Process Simulation
ProMax
Toluene
108883
Process Simulation
ProMax
Ethylbenzene
100414
Process Simulation
ProMax
Xylene
1330207
Process Simulation
ProMax
n -Hexane
110543
Process Simulation
ProMax
2,2,4-
Trimethylpentane
540841
Process Simulation
ProMax
Other:
5 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
COLORADO
Form APCD-211 - Gas Venting APEN - Revision 7/2018
51
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.
11/10)
Signature of Legally AutXhorized Person (not a vendor or consultant) Date
Kevin Bailey Chief Operating Officer
Name (please 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 $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
Colorado Department of Public Health and Environment https://www.colorado.Rov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018
6I Aillf
COLORADO
Nmtth6Envlron
nryart&Entrut+Y
mml
Gas Venting APEN - Form APCD-211
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, clod
updates. An application with missing information may be determined incomplete and may be ret ned
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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/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: O We IDS I AIRS ID Number: y2,3 / l PTFI' O ≤
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': REP Processing, LLC
Site Name: Severance Compressor Station
Site Location: NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address: 1611 N. Broadway Ave.
(Include Zip Code)
Oklahoma City, OK 73101
Site Location
County: Weld
NAICS or SIC Code: 211130
Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: (.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
® ICOLORACO
1 Ma�w�
Hea�rotlh b En�lrunmrnr
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
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 O Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Routine, planned compressor blowdowns - majority of gas to
be directed to compressors' suction line; remaining gas volume (below suction pressure) will be vented.
Company equipment Identification No. (optional): BD -1
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
April 2019
❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
see next page hours/day
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?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
Form APCD-211 - Gas Venting APEN - Revision 7/2018
days/week weeks/year
❑✓ Yes
❑ Yes
❑ Yes
❑ No
❑✓ No
❑✓ No
j COLORADO
2 I AV lt3 n P Ic
LLii V HnaUnbgAvvomm�nl
Permit Number:
AIRS ID Number: / /
{Leave blank unless APCD has already assigned a permit # and AIRS ID)
Section 4 - Process Equipment Information
❑ Gas/Liquid Separator
❑ Well Head Casing
❑ . Pneumatic Pump
Make: Model:
❑ ; Compressor Rod Packing
Make:
❑✓ Blowdown Events
# of Events/year:
❑ Other
Description:
Serial #:
Capacity: gal/min
Model: # of Pistons: Leak Rate: Scf/hr/pist
100
Volume per event: 0.01 05
MMscf/event
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑✓ No
Qa �% /
Vent Gas
Heating Value:
1 ,305
BTU/SCF
Requested:
MMSCF/year
Actual:
NA
MMSCF/year
-OR-
Requested:
bbl/year
Actual:
bbl/year
Molecular Weight:
22.60
VOC (Weight %)
25.69
Benzene (Weight %)
0.04
Toluene (Weight %)
0.03
Ethylbenzene (Weight
or,Xylene
0.00
(Weight %)
0.01
n -Hexane (Weight %)
0.98
2,2,4-Trimethylpentane
(Weight %)
0.00
Additional Required Information:
❑✓ Attach a representative gas analysis (including BTEX & n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX a n -Hexane, temperature, and
pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
COLORADO
3 I aOW <U`,.,,:•r:.'_,
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(LatitudeILongitude or UTM)
NA
A for
0'[r�
scha ` el t
Glluc
:(FI' , r. ..?
Te
�� i= ow Rate
(ACM }�"/"
NA
NA
NA
NA
NA
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
O Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
0 Other (describe):
Interior stack diameter (inches):
O Upward with obstructing raincap
Section 6 - Control Device Information
❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency:
VRU Downtime or Bypassed:
n Combustion
Device:
Pollutants Controlled:
Rating: MMBtu/hr
Type: Make/Model:
Requested Control Efficiency: %
Manufacturer Guaranteed Control Efficiency:
Minimum Temperature: Waste Gas Heat Content: Btu/scf
Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
CULURADO
4 I AV!=;d
aoauna o„nm:m.n,
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS fDI
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
uction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOX
NO.
CO
VOC
HAPs
Other:
From what year is the following reported actual annual emissions data?
NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
SOx
NO.
/
CO
�"
....O.1. --
VOC
Process ulation
16Tsct._
ProMax
NA
NA
r""
.O
.2.0
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
nits
l�/SC�
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds year)
Controlled
Emissions 6
(pounds/year)
Benzene
71432
Pro,
2.34 -c
ProMax
Toluene
108883
Proce imul i
(,1' -5
ProMax
Ethylbenzene
100414
ProchilOan
1,02 -E -(p
ProMax
Xylene
1330207
Pro.c nul9n
4.4 -(p
ProMax
n -Hexane
110543
Pros4Dn
5,85e-11-
ProMax
2'.2,4
Trimethylpentane
540841
Proc
:� �'
Z
Z 32�_
ProMax
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
A� eotbnaoo
5 I :SEa4461 +s.
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.
Signature of Legally Au>6Korized Person (not a vendor or consultant) Date
Kevin Bailey Chief Operating Officer
Name (please 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 $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018
COLORADO
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Gas Venting APEN - Form APCD-211
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, incl
updates. An application with missing information may be determined incomplete and may be returned�
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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/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: 18' lyE 1 0 6 1 AIRS ID Number: �3 "1Ffe, / 00 Lo
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Site Location:
REP Processing, LLC
Severance Compressor Station
NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address: 1611 N. Broadway Ave.
(Include Zip Code)
Site Location
County: Weld
NAICS or SIC Code: 211130
Oklahoma City, OK 73101 Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: I.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
38810
�VICOLORADO
1 d�
H<alllt (r FMN tanlncnt
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
O NEW permit OR newly -reported emission source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment 0 Change company name3 ❑ Add point to existing permit
❑ Change permit limit 0 Transfer of ownership4 0 Other (describe below)
OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Routine pigging operations - most gas to be directed
to compressors' suction line; remaining gas volume (below suction pressure) will be vented.
Company equipment Identification No. (optional): PG -1
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
April 2019
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:
see next page hours/day
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?
Is this equipment subject to Colorado Regulation No. 7,
Sectioxi.XVI'G
T~ IL
Form APCD-211 - Gas Venting APEN - Revision 7/2018
days/week weeks/year
❑✓ Yes ❑ No
O Yes 0 No
❑ Yes 0 No
2I A
COLORADO
llepamuncut Pottle
Healthb EnutmmmerU
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
❑ Gas/Liquid Separator
D Well Head Casing
O Pneumatic Pump
Make: Model:
Serial #:
Capacity: gal/min
❑ Compressor Rod Packing
Make: _ Model: # of Pistons: Leak Rate: Scf/hr/pist
❑ Blowdown Events
# of Events/year: Volume per event: MMscf/event
❑✓ Other
Description: routine pigging operations, assume 28 events/week, 52 weeks/yr
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy?
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑ Yes ❑✓ No
Vent Gas
Heating Value:
1,307
BTU/SCF
Requested:
1.03
MMSCF/year
Actual:
NA
MMSCF/year
-OR-
Requested:
bbl/year
Actual:
bbl/year
Molecular Weight:
22.76
VOC (Weight %)
26.41
Benzene (Weight %)
0.05
Toluene (Weight %)
0.05
Ethylbenzene (Weight
on
0.01
Xylene (Weight %)
0.02
n -Hexane (Weight %)
1.18
2,2,4-Trimethylpentane
(Weight %)
0.00
Additional Required Information:
O Attach a representative gas analysis (including BTEX ft n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX 8 n -Hexane, temperature, and
pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
®®C
A OLORDO
Heath bEnNronmmt
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Indicate the direction of the stack outlet: (check one)
❑ Upward
❑ Horizontal
Geographical Coordinates
(Latitude/Longitude or UTM)
NA
O Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Other (describe):
Interior stack diameter (inches):
O Upward with obstructing raincap
Section 6 - Control Device Information
❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed:
❑ Combustion
Device:
Pollutants Controlled:
Rating: MMBtu /hr
Type: Make/Model:
Requested Control Efficiency: %
Manufacturer Guaranteed Control Efficiency: %
Minimum Temperature: Waste Gas Heat Content: Btu/scf
Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
4 I �lwwnnuv
mmetd D,men
Heay� b Ehvlmnmml
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SO,
NO,
CO
VOC
HAPs
Other:
From what year is the following reported actual annual emissions data? NA
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual AnnualEmissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
SOx
NO,
CO
VOC
Process Simulation
ProMax
NA
NA
8.18
8.18
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
, etc.)
Uncontrolled
Emissions
(pounds/year) (Pounds/ r)
Controlled
Emissions6
(pounds/year)
Benzene
71432
Process Simulation
ProMax
Toluene
108883
Process Simulation
ProMax
Ethylbenzene
100414
Process Simulation
ProMax
Xylene
1330207
Process Simulation
ProMax
n -Hexane
110543
Process Simulation
ProMax
2,2,4-
Trimethylpentane
540841
Process Simulation
ProMax
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
51
17 COLORADO
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.
/4o -r=
Signature of Legally Auth zed Person (not a vendor or consultant) Date
911q1/8
Kevin Bailey Chief Operating Officer
Name (please print) Title
Check the appropriate box to request a copy of the:
❑ Draft permit prior to issuance
0✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.Rov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018 6 I A
COLORADO
Department nrPn
NeWlh6analromntmt
Gas Venting APEN - Form APCD-211
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, inc
updates. An application with missing information may be determined incomplete and may be returned or
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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.Rov/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: 1 I (_ (OS I AIRS ID Number: ) a3 / 9FFI$/ op 6
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Site Location:
REP Processing, LLC
Severance Compressor Station
NW 1/4, S8, T7N, R66W
County Rd 27, Ault, CO 80610
Mailing Address: 1611 N. Broadway Ave.
(Include Zip Code)
Oklahoma City, OK 73101
Site Location
County: Weld
NAICS or SIC Code: 211130
Contact Person: Lance King
Phone Number: 405-317-9587
E -Mail Address2: I.king@rimrockenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
I COLORADO
1 I A-iIf°-°"d,<
sNN b Cnvttonmenl
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit It and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
❑ Change permit limit O Transfer of ownership4 ❑ Other (describe below)
OR -
• APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
11 Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info a Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Routine pigging operations - most gas to be directed
to compressors' suction line; remaining gas volume (below suction pressure) will be vented.
Company equipment Identification No. (optional): PG -1
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
April 2019
❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
see next page hours/day
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?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
Form APCD-211 - Gas Venting APEN - Revision 7/2018
days/week weeks/year
Yes
Yes
Yes
El
No
No
No
marl COLORADO
2 1 AGIBLV "�`moiwnm
NaaUbb En�Uauaml
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID)
Section 4 - Process Equipment Information
❑ Gas/Liquid Separator
❑ Well Head Casing
O Pneumatic Pump
Make: Model:
Serial #:
Capacity: gal/min
O Compressor Rod Packing
Make: Model: # of Pistons: Leak Rate: Scf/hr/pist
❑ Blowdown Events
# of Events/year: Volume per event: MMscf/event
❑✓ Other
Description: routine pigging operations, assume 28 events/week, 52 weeks/yr
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy?
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑ Yes ❑✓ No
Vent Gas
Heating Value:
1,307
BTU/SCF
Requested:
MMSCF/year
Actual:
NA
MMSCF/year
-OR-
Requested:
bbt/year
Actual:
bbl/year
Molecular Weight:
22.76
VOC (Weight %)
26.41
Benzene (Weight %)
0.05
Toluene (Weight %)
0.05
Ethylbenzene (Weight
w,
0 01
Xylene (Weight %)
0.02
n -Hexane (Weight %)
1.18
2,2,4-Trimethylpentane
(Weight %)
0.00
Additional Required Information:
❑ Attach a representative gas analysis (including BTEX ft n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and
pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
A COLORAO
3 I Ito'� D
�1
❑ Upward
❑ Horizontal
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 UT/A)
NA
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Circular
❑ Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
Section 6 - Control Device Information
❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
O VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed:
❑ Combustion
Device:
Pollutants Controlled:
Rating:
Type:
MMBtu/hr
Make/Model:
Requested Control Efficiency: %
Manufacturer Guaranteed Control Efficiency: %
Minimum Temperature:
Waste Gas Heat Content: Btu/scf
Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
Permit Number:
AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID3
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction ):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SO,
NO,
CO
VOC
HAPs
Other:
From what year is the following reported actual annual emissions data?
NA
Criteria Pollutant Emissions inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
fg
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
SOx
NO,
CO
VOC
Proces ulation
li f SC�
ProMax
NA
NA
j'
0.02
I V.eup 18, 2(0
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
U its ,,W
I tj75C1�
Source
(AP-42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
Proc
2,22E-5
ProMax
Toluene
108883
Pr1a
3.2'3E-'5
ProMax
Ethylbenzene
100414
Pfe la
3.FS5E—w
ProMax
Xylene
1330207
Proce Iru�JI n
ri- -5"
ProMax
n -Hexane
110543
Proc
711e4
ProMax
2,2,4-540841
Trimethylpentane ylp
Pro s25uanla n
t.+ ��
ProMax
Other:
5 Requested values will become permit Limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
!=orm APCD-211 - Gas Venting APEN - Revision 7/2018
n�14
5l
AyCOL�2ADD
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.
Ox -r= gla
Signature of Legally Auth ized Person (not a vendor or consultant) Date
Kevin Bailey - Chief Operating Officer
Name (please 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 $191.13 to:
Colorado Department of Public Health and
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
For more information or assistance call:
Environment Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018
AgriCOLORADO
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