HomeMy WebLinkAbout20174107.tiffCOLORADO
Department of Public
Health b Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
11500 St
PO Box 758
Greeley, CO 80632
November 28, 2017
Dear Sir or Madam:
RECEIVED
NOV 3 0 2017
WELD COUNTY
COMMISSIONERS
On November 30, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for
Discovery DJ Services LLC - Discovery West Brighton 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. Hickentooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
�CJ�QIiG ��/ie(,�) C.c.,PLCWI rP)• LCST)
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2017-4107
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Discovery DJ Services LLC - Discovery West Brighton Compressor Station - Weld County
Notice Period Begins: November 30, 2017
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: Discovery DJ Services LLC
Facility: Discovery West Brighton Compressor Station
Natural gas compressor station
Section 28, T1 N, R67W
Weld County
The proposed project or activity is as follows: New natural gas compressor station with a capacity of 40
MMscf /day.
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 17WE1165 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Any such comment must be submitted in writing to the following addressee:
Betsy Gillard
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
cdphe.commentsapcd@state.co.us
Colorado Air Permitting Project
PRELIMINARY- ANALYSIS - PROJECT SUMMARY
Project' Details -
Review Engineer:
Package it
Rece`Diverr Date:
Review Start Date:
Section 01- Facility Information
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name: -
Physical Address/Location:
Type of Facility:
What industry segment?
Is this facility located in a NAAQS-non-attainment area?
If yes, for what pollutant? Crarbon.Monoxide (co)
Section 02 - Emissions Units In Permit Application
Weld
Star[S.Ir, -
Section 28, Township 1N, Range 67W, in Weld County, Colorado
attatt.....�:
Quadrant
Section
Township
Range
articulate Matter (PM) zone (tOe & VOC)
AIRs Point #
Emissions Source Type
Equipment
Name
Emissions
Control?
Permit #
Issuance #
- Self Cert
Required?
Action Engineering Remarks
0.
n
Yes
I'.
1
E;
y
D
Yes
Prgc P
=6�
Yp
IS
7hitidl
5
1
`p
At
17WE1165
60G -A4,
E1165
Yes
17WE1165
Aid
Section 03 - Descriptiom of Project
333 3j 3il 3ji
Iressor station wifh•40 M
Fdrt:L€Ifiton Gas Plant and; s€
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why?
Section 05 - Ambient Air Impact Analysis Requirements
Wasa quantitative modeling analysis required?
If yes, for what pollutants?
If yes, attach a copy of Technical Services Unit modeling results summary.
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor?
Is this stationary source a synthetic minor?
If yes, indicate programs and which pollutants:
Prevention -of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
Is this stationary source a major source?
SO2 NOx
CO VOC PM2.5 PM10 TSP HAPs
0 0 0 0 0 ❑
❑ 0000 ❑ ❑ o
❑ o
001 Compressor Maintenance Blowdowns
Equipment Qescription
This source vents natural gas from:
Emissions from this source are:
4 compressors
vented to the atmosphere
Natural gas venting from 4 compressors during maintenance blowdown events (Point 001). Emissions from
this source are vented to the atmosphere.
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
Point 001: Maintence Slowdowns
Throughput (Q)
0.4032 MMscf/yr
46.0 scf/hr
MW
24.3 lb/Ib-mcl
mass fraction
Ib/hr
lb/yr
tpy
CO2
0.031
0.1
812
0.41
methane
0.447
1.3
11566
5.78
total VOCs
0.336
1.0
8678
4.34
n -Hexane
0,013
0.0
336
0.1680
224-TMP
0.000
0.0
0
0.0000
Benzene
0.001
0-0
23
0.0116
Toluene
0.002
0.0
41
0.0207
Ethylbenzene
0.000
0.0
10
0.0052
Xylenes
0.001
0.0
21
0.0103
VOC mass fraction:
Total VOC Emissions (tpy)
0.3357
4.3
Notes
MW, andmass fractions from an average of 5 inlet gas analyses.
Emissions are based on 8760 hours of operation per year.
-Point 001: Throughput volume -is based on 24 events/compressor/year and 4 compressors.
Estimated gas volume released is 4.2 Mscf/event/unit. This volume is derived from piping and instrumentation diagramsof the compressors.
Emissions Summary
Point 001: Maintenance Blowdowns
Calculated
Uncontrolled
Total
Operator
Uncontrolled
Total
Emission
factor
(lb/event)
Operator
Emission Factor
(lb/event)
Reportable?
VOC
4.34
4.34
tpy
90.40
90.41
Benzene
23
24
lb/yr
124
0.25
No
Toluene
41 -
40
lb/yr
0.43
0.42
No
Ethytbenzene
10
10
lb/yr
411
0.10
No
Xylenes
21
22
lb/yr
122
0.23
No
n -hexane
336
336
lb/yr
3.50
3.50
Yes
224-TMP
0
0.3
tb/yr
100
0.003
No
Note: Permit reflects operator -calculated values.
Regulatory Applicability
AQCC Regulation 1
This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a
smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the
atmosphere of any air pollutant which is in excess of 30% opacity.'
AQCC Regulation 2
Section I.A applies to all emission sources. "No person, wherever located, shall ®use 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 diluied with seven (7) or more
volumes of odor free air.'!:-
AQCC Regulation 3
Is public comment
required?
Public Comment Required
17WE1165.cP1.xls-n
Glycol Dehydrator Emissions Inventory
Section 01 -Administrative Information
(Facility AIRS ID:
Coup
_
Plant 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 Bumer
Stripping Gas
Dehydrator Equipment Description
MMscf/day
gallons/minute
and flash tank
One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TRD, Model: TBD, Serial Number: TOD) with a design
capacity of 20 MMscf per day. This emissions unit is equipped with 2 (Make: TOD, Model: TBD). electric driven glycol pumps
with a total design capacity of 4.2 gallons per minute. This dehydration unit is equipped with a still vent and flash tank.
Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash
Emission Control Device Description: tank ace routed directly to the Enclosed Flare.
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions- Dehydrator Still Vent and Flash Tank (if presets(
Requested Pernit Limit Throughput = ;';,/ 5fl0 y: MMscf per year
Potential to Emit (PTE) Throughput= 7,300 MMscf per year
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 WasteGas Vent Rate:
Flash tank Control
Primary controldevioe:
Primary control device operation:
Senondarycontml device:
Secondary control device operation:
Flash Tank Gas Heating Value
Flash Tank Waste Gas Vent Rate:
Section 04- Emissions Factors & Methodologies
Dehydrator
Input Paramete
Inlet Gas Pressure
Inlet Gas Temperature
Requested Glycol Recirculate Rate
STILL VENT
Pollutant
VOC
Benzene
Toluene
Ethylbenzene
Xylenes
n•Hexane
224-TMP s19i1:Op0i
hr/yr
ItillffillilliTteititr4SiVA8 Control Efficiency %
hr/yr
cth
Control Efficiency%
Control Scenario
Primary
Secondary
Uncontrolled (Ih/hr)
Controlled pb/hr)
DORIS.
0.1213
0.1370
0.0340
0.0660
0.0138
0.0000
Controlled (lb/hr)
0
AMMER
0
0
0
0
FLASH TANK
Pollutant
V0C
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
224TMP
Control Scenario
Primary
Secondary
Uncontrolled (lh/hr)
Controlled (lb/hr)
0.6017
0.0032
0.0025
0.0004
0.0005
0.0096
0.0000
Controlled (lb/hr)
0
0
ESSitOORESIII
0:0493;
0.0074 I
0
0
0
Wet Gas Processed:
Still Vent Primary Control: 7,300.0 MMscf/yr
Still Ventlecondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Still Vent Primary Control: 15.0 MMscf/yr
Still Vent Secondary Control: 0.0 MMscf/yr
Wet Gas Processed:
Flash Tank Primary Control: 7,300.0 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
Waste Gas Combusted:
Flash Tank Primary Control: 3.1 MMscf/yr
Flash Tank Secondary Control: 0.0 MMscf/yr
affillincw
Glycol Dehydrator Emissions Inventory
Emission Factors
Pollutant
Glycol Dehydrator
Uncontrolled
(Ib/MMscf)
(Wet Gas
Throughput)
VOC 31.04
Benzene 2.9878
Toluene 3.3463
Ethylbenzene 0.825
Xylene 1.5964
n -Hexane 0.5611
224 TMP 0.0002
Controlled
(Ib/MMscf) Emission Factor Source
(Wet Gas Throughput)
0.149388
0.167316
0.041256
0.079818
0.028056
0.000012
Stlll'Vent Primary Control Device
Uncontrolled
Uncontrolled
(Ib/MMscf) Emission Factor Source
(Waste Gas
Combusted(
Pollutant (Ib/MMBtu(
(Waste Heat
Combusted)
NOx
1
207.0000
NOx ,:,;,17;0680;
Flash Tank Primary Control Device
Uncontrolled
Pollutant (Ih/MMBtu)
(Waste Heat
Combusted)
PM10
PM2.5
Uncontrolled
(Ib/MMscf)
(Waste Gas
Corn busted)
0.0000
0.0000
CO
Section 05 - Emissions Inventory
Did operator request a buffer?
Requested. Buffer )%))
413.2500
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) (tans/year)
PM10
0.0
0.0
0.0
0.0
0.0
PM2.5
0.0
0.0
0.0
0.0
0.0
Nox
1.1
1.1
1.1
1.1
1.1
CO
4.1
4.1
4.1
4.1
4.1
VOC
113.3
113.3
5.7
113.3
5.7
Potential to Emit
Actual Emissions
Requested Permit Limits
Hazardous Air Pollutants
Uncontrolled
• Uncontrolled Controlled
Uncontrolled Controlled
- Ohs/year)
(Ibs/year) (Ibs/year)
)Ibs/year) (lbs/year)
Benzene
21811
21811
1091
21811
1091
Toluene R
24428
24428
'1221
24428
1221
Ethylbenzene
6023
6023
301
6023
301
Xylene
11653
11653
583
11653
583
n -Helene
4096
4096
205
4096
- 205
224 TMP
2
2
0
2
0
Section 06-'Reeulatory Summary Analysis
Regulation 3, Parts A, B
Regulation 7, Section XV11.3,D
Regulation 7, Section XVII.B.2.e
Regulation 7, Section XII.H
Regulation 8, Part E, MACT Subpart HI -I (Area)
Regulation 8, Part E, MACE Subpart HH (Major)
Regulation 8, Part E, MAR Subpart HHH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Dehydrator is subject to Regulation 7, Section XVII, B, 5.3
The control device for this dehydrator is not subject to Regulation 7, Section XVII.8,2
Dehydrator is subject to Regulation 7, Section XII.H
The dehy unit meets the benzene exemption
You have indicated that this facility is not subject to Major Source requirements of N
You have Indicated that this facility is notaubject to MACT HHH.
Section 07 - Initial and Periodic Sampling and Testing Requirements
Was the extended wet gas sample used in the GlyCaalcmodel/Process model site -specific and collected within a year -
of application submittal?
If no, the permit will contain an "Initial Compliance" testing requirementto demonstrate compliance with emission Ilmi
Does the company request a control device efficiency greater than 95% far a flare or combustion device? _ Fc
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point H
002 & 003
Process H
01
SCC Code
Pollutant
PM10
PM2.5
NOx
VOC
CO
Benzene
Toluene
Ethylbenzene
Sylene
n -Hexane
224 TMP
Uncontrolled
Emissions Factor
holy/01
t)DIV/01
0.296
31.0
1.128
2.988
3.346
0.825
1.596
0.561
0.000
Control %
0.0%
0.0%
0.0%
9500.0%
0.0%
9500.0%
9500.0%
9500.0%
9500.0%
9500,0%
9500.0%
Dehydrator Regulatory Analysis Worksheet
Colorado Regulation 3 Parts A and B - APEN and Permit Requirements
You have indicated that 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 it TPY or CO emissions greater than it TPY (Regulation 3, Part B, Section Il.D.3)?
IYou have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual sour. greater than S TPY (Regulation 3, Part A, Section ll.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 5 TPY (Regulation 3, Part 3, Section 11.5.2)?
Yes
Source requires a permit
Colorado Regulation 7, Section XII.H
1. Is this glycol natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Reg 7, Section )31.6,1 and 2)?
2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation', natural gas compressor station, natural gas drip station ar gas -processing plant (Reg 7 Section
3; Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy (Reg 7, Section XII.H.3.b)?
4. Are actualuncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section Xll.H.3.a)?
Yes
Dehydrator Is subject to Regulation 7, Section XII.H
Section XICH — Emission Reductions from glycol natural gas dehydrators
MACE Analysis
1. Is the dehydrator located at an oil and natural gas production facility that meets ether of the following criteria,
a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(0)(2)); OR
A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end
b. user' (63.760(a)(3))?
2. Is the dehydrator located at a facility that is a major source for HAPs?
} Go to MACF HH Area Source Requirement section to determine MACF HH applicability
40 CFR, Part 63, Subpart MACF HH, Oil and Gas Production Facilities
Area Source Requirements
1. Is the dehydrator a triethylene glycol (TEG) dehydration unit (63.760(6)(2))?
Exemptions.
2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.764(e)(1)(i)?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.764(e)(1)(ii)?
3. Is the unit located inside of a UA plus offset and UC boundary area?
Yes
Source Re
Source Re
Continue
Continue
Go to the
Dehydrate
Continue •
MENA Go to MA'
Yes
'The dehy unit meets the benzene exemption
Subpart A, General provisions per 463.764 (a) Table 2
§63.765 - Emissions Control Standards Do Not Apply
§63.773 - Monitoring Standards Do Not Apply
§63,774: Recordkeeping
463.775 - Reporting Standards Do Not Apply
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 hydrocarbon liquid throughput less than 249.7
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)?
26. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.761)3
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 MACF HH.
Subpart A, General provisions per §63.764 (a) Table 2
§63.765 - Emissions Control Standards
463.773 - Monitoring
§63.774-Recordkeeping
§63.775 - Reporting
40 CFR, Part 63. Subpart MACI HHH, Natural Gas Transmission and Storage Facilities
1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source (63.1270(f))?
Small or Large Dehy Determination
2a. Is the actual annual averageflowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day (63.1270(b)(2))?
2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.1270(6)(2))?
Small Dehy( Requirements
3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011(63.1270(6)(2) and (3) )?
4. For this small dehy, is a control device required to meet the BTIX emission limit (standard?) given by the applicable equation?
You have indicated that this facility is not subject to MACr HHH.
Subpart A, General provisions per 463.1274 (a) Table 2
663.1275 - Emissions Control Standards
363.1281 -Control Equipment Standards
§63.1283 - Inspection and Monitoring
§63.1284 - Recordkeeping
§63.1285 - Reporting
Continue
go to the
The dehy
The dehy
Colorado Regulation 7, Section XVII.D
1. Is the dehydrator subject to an emissions control requirement under MACTHH or HHH (Regulation 7, Section XVII.B.5)?
2. Is this dehydrator Ibcated at a transmission/storage facility?
3. Is this dehydrator located at an oil and gas exploration and production operation, natural gas compressor station or gas processing plant (Reg 7, Section XVII.D.3)?
4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)?
If constructed prior to May 1, 2015, are uncontrolled actual emissionsfrom a single glycol natural gas dehydrator equal to or greater than 6tons per year VOC or 2 tpy VOC if the
4a. ' dehydrator is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)? •
5. If constructed an or after May 1, 2015, are uncontrolled actual emissionsfrom a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC (Regulation 7, Section XVII.D.4.a)?
Dehydrator is subject to Regulation 7, Section XVII, B, D.3
Section XVII.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.D.3 - Emissions Reduction Provisions
Alternative Emissions Control (Optional Section),
6. Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion devicee(i.e., not the primary control device) that is not enclosed?
'The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e
Section XVII.B.2.e—Alternative emissions.control equipment
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act its implementing regulations, and Air Quality Control
Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and
circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event
of any conflict between the language of this document and the language of the Clean Air Act its implementing regulations, and Air Quality Control
Commission regulations,. the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may,""should,"and "can," is
intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling
requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in
and of itself.
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Source is:
004 Process Flare for the control of TEG dehydrators (Points 003 and 004) and slop tanks.
Equipment Description
This source vents natural gas from:
Emissions from this source are:
TEG dehydrators and slop tanks
routed to a flare
Natural gas venting from TEG dehydrators and slop tanks. Emissions from this source are routed to a flare.
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
Process flare
Pilot bumers (2)
Purge fuel
5833
22
4
scf/hr
scf/hr
scf/hr
1500 Btu/scf
1130 Btu/scf
1130 Btu/scf
Total
5881
scf/hr
Weighted fuel heating value
51.52
4.38
MMscf/yr
Flaring Information
Equipment Description
Flare to combust oas from TEG dehydrators and slop tanks.
Manufacturer
TBD
Model
TBD
Serial Number
TBD
Gas Heating Value
1497
Btu/scf
Throughput
77120.7624
MMBtu/yr
Overall Control
95:00%
Combustion emission factor source: AP -42: Chapter 13.5
0.138
lb NOX/MMBtu
0.276
10.6
14971 Btu/scf
lb CO/MMBtu
5.3
Emissions Summary
tpy NOX
tpy CO
5.3
tpy NOX
Uncontrolled/PTE
10.6
tpy CO
0.0
tpy VOC
Regulatory Applicability
AQCC Regulation 1
This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a
smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the
atmosphere of any air pollutant which is in excess of 30% opacity.'
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."
AQCC Regulation 3
Is public comment
required?
Public Comment Required,
AQCC Regulation 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
• yes
This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVII.B.2
17WE1165.CP1.xlsm
Points 005. 006, 007: Caterpillar 3606 A4 RICE
General description of equipment
purpose:
This emission unit is used for natural gas compression.
Date the engine was ordered:
1/1/2017
Date engine construction commenced:
1/1/2017
Date engine relocated into Colorado:
1/1/1900
Date of any reconstruction/modification:
1/1/1900
Will this equipment be operated in any nonattainment area?
Yes
Section 04: Engine Information
Engine Info
Engine date of mfg
1/1/20171
Engine Displacement
0 Licyl
Manufacturer:
Caterpillar
Model Number:
3606 A4
Serial Number:
TBD
Engine Function
Compression
berating
Mfg's Max. Rated Horsepower @ sea level: 11875
C Derate Based on Altitude:
C Derate by a factor of:
C Use Site -Specific Rating
t'i° No Derafirat
3 % for every
500 feet over
3000 feet of altitude
0.5
1000
hp
Horsepower used for calcuations:
1875
BSCF @ 100% Load (btu/hp-hr):
7500
Site - Rated BSCF @ 100% load (btu/hp-hr):
7500
Other
Parameters
Engine Type
4SLB
Aspiration
turbo -charged
Electrical Generator Max Site Rating (kw)
0
Annual hours for PTE
8760
Annual hours for permit
8760
Section 06: Fuel Consumption Information
Fuel Use Rate @ 100% Load
12444.69027 scf/hr
ACTUAL Annual Fuel Consumption
109.015 MMscf/yr
MAX POTENTIAL Annual Fuel
Consumption
109.015 MMscf/yr
REQUESTED Annual Fuel
Consumption
109.015 MMscf/yr
Fuel Heating Value
1130 btu/scf
Section 07: Emission Control Information
Primary Control Device Description
This engine shall be equipped with an oxidation catalyst and air -fuel ratio control
Uncontrolled Emission Factors - Criteria & HCHO
Pollutant
Value - lb/MMBtu
Value - g/bhp-hr
Source/Comments
NOx
0.500
Manufacturer
CO
2.720
Manufacturer
VOC
1.500
Manufacturer
Formaldehyde
0.200
Manufacturer
Control Eff ciencv/Controlled Emission Factors - Criteria & HCHO
Pollutant
Value - lb/MMBtu
Value - g/bhp-hr
Control (%)
Source/Comments
NOx
0.500
0.0%
CO
0.150
94.5%
VOC
0.300
80.0%
Formaldehyde
0.020
90.0%
Summary of Preliminary Analysis - NG RICE
Points 005, 006, 007
Emission Point Description
One (1) Caterpillar, Model 3606 A4, Serial Number TBD, natural gas -fired, turbo -charged, 4SLB reciprocating internal
combustion engine, site rated at 1875 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio
control This emission unit is used for natural gas compression.
Natural Gas Consumption
Requested (mmscf/yr)
109.02
Requested (mmscf'm)
9.08
Fuel Heat Value (btu/scf)
1130
BSCF (Btu/hp-hr)
7500
Emission Factor Sources
Uncontrolled
Controlled
NOx
NSPS JJJJ
Manufacturer
VOC
Manufacturer
Catalyst Data Sheet
CO
Manufacturer
Catalyst Data Sheet
Formaldehyde
Manufacturer
Catalyst Data Sheet
SOX
AP -42
No Control
TSP
AP -42
No Control
PM10
AP -42
No Control
PM2.5
AP -42
No Control
Other HAPs
AP -42
AP -42
Flours of Operation
PTE Calculated at (hpy)
Permit limits calculated at (hpy)
8760'
8760
Point Summary of Criteria Emissions (tpy)
Uncontrolled
Requested
Controlled
Requested
PTE
Proposed Control
Efficiency
NOx
9.1
9.1
9.1
0.0%
VOC
27.2
5.4
27.2
80.0%
CO
49.2
2.7
49.2
94.5%
"Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de
minimus thresholds. PTE includes all HAPs calculated, even those below de minimus.
Point Summary of Hazardous Air Pollutants (lb/yr
HAP Name
Uncontrolled
Requested
Controlled
Requested
PTE
Proposed Control
Efficiency
Formaldehyde
7242
724
—
90.0%
Acetaldehyde
1030
1030
-
0.0%
Acrolein
633
633
—
0.0%
Methanol
308
308
--
0.0% -
*Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED
UNCONTROLLED is greater than de minimus
Permitting Requirements
Ambient Air Impacts
Source is not required to model based on Division Guidelines
Public Comment
Public Comment Required
MACT 7777
Reg 7 XVII.E Standards
(g/hp-hr)
NOx: 1.0 CO: 2.0 VOC: 0.7
Reg 7 XVI.B (Ozone NAA
requirements) applies?
Yes
MACT 7777 (area source)
Is this engine subject to MACT 7777 area
Yes
source requirements?
NSPS JJJJ
Is this engine subject to NSPS JJJJ?
Yes
Note: JJJJ requriements are not currently included as permit conditions because the reg has not been
adopted into Reg 6.
Comments/Notes
Point 008: Cateraillar G3516 J RICE
I 52 weeks/yr
General description of equipment
purpose:
This emission unit is used for natural gas compression.
Date the engine was ordered:
1/1/2017
Date engine construction commenced:
1/1/2017
Date engine relocated into Colorado:
1/1/1900
Date of any reconstruction/modification:
1/1/1900
Will this equipment be operated in any nonattainment area?
Yes
Section 04: Enoine Information
Engine Info
Engine date of mfg
1/1/20171
Engine Displacement
0 L/cyl
Manufacturer:
Caterpillar
Model Number:
G3516 J
Serial Number:
TBD
Engine Function
Compression
berating
Mfg's Max. Rated Horsepower @ sea level: 11380
( Derate Based on Altitude:
C Derate by a factor of
C UseSite-SpecificRating:
f- Noaeration
3 % for every
500 feet over
3000 feet of altitude
0.5
1000
hp
Horsepower- used for calcuations:
1380
BSCF @ 100% Load (btu/hp-hr):
8256
Site - Rated BSCF @ 100% load (btu/hp-hr):
8256
Other
Parameters
Engine Type
4SLB
Aspiration
turbo -charged
Electrical Generator Max Site Rating (m)
0
Annual hours for PTE
8760
Annual hours for permit
8760
Section 06: Fuel Consumption Information
Fuel Use Rate @ 100% Load
10082.54867 scf/hr
ACTUAL Annual Fuel
Consumption
88.32312637 MMscf/yr
MAX POTENTIAL. Annual Fuel
Consumption
88.323 MMscf/yr
REQUESTED Annual Fuel
Consumption
88.323 MMscf/yr
Fuel Heating Value
1130 btu/scf
Section 07: Emission Control Information
Primary Control Device Description
This engine shall be equipped with an oxidation catalyst and air -fuel ratio control
Uncontrolled Emission Factors - Criteria & HCHO
Pollutant '
Value - Ib/MMBtu
Value - g/bhp-hr
Source/Comments
NOx
0.500
JJJJ
CO
• 2.430
Manufacturer
VOC
0.910
Manufacturer
Formaldehyde
0.430
Manufacturer
Control Efficiency/Controlled Emission Factors - Criteria & HCHO
Pollutant
Value - Ib/MMBtu
Value - g/bhp-hr
Control (%)
Source/Comments
NOx
0.500
0.0%
CO
0.200
91.8%
VOC
0.360
60.4%
Formaldehyde
0.035
91.9%
Summary of Preliminary Analysis - NG RICE
Point 010
Emission Point Description
One (1) Caterpillar, Model G3516J, Serial Number TBD, natural gas -fired, turbo -charged, 4SLB reciprocating internal
combustion engine, site rated at 1380 horsepower. This engine shall be equipped with an oxidation cacalyst and an air -fuel
ratio control. The emission unit is used for natural gas compression.
Natural Gas Consumption
Requested (mmscf/yr)
88.32
Requested (mmscf/m)
7.50
Fuel Heat Value (btu/scf)
1130
BSCF (Btu/hp-hr)
8256
Emission Factor Sources
Hours of Operation
PTE Calculated at (hpy)
Permit limits calculated at (hpy)
8760
8760
Uncontrolled
Controlled
NOx
NSPS JJJJ
Manufacturer
VOC
Manufacturer
Catalyst Data Sheet
CO
Manufacturer
Catalyst Data Sheet
Formaldehyde
Manufacturer
Catalyst Data Sheet
Point Summary of Criteria Emissions (tpy)
Uncontrolled
Requested
Controlled
Requested
PTE
Proposed Control
Efficiency
NOx
6.7
6.7
6.7
0.0%
VOC
12.1
4.8
19.2
60.4%
CO
32.4
2.7
41.2
91.8%
*Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de
minimus thresholds. PTE includes all HAPs calculated, even those below de minimus.
Point Summary of Hazardous Air Pollutants ( b/yr)
HAP Name
Uncontrolled
Requested
Controlled
Requested
PTE
Proposed Control
Efficiency
Formaldehyde
11460
928
11460
91.9%
Acetaldehyde
834
834
834
0.0%
Acrolein
513
513
513
0.0%
*Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED
UNCONTROLLED is greater than de minimus
Permitting Requirements
Ambient Air Impacts
Source is not required to model based on Division Guidelines
Public Comment
Public Comment Required
MACT 777Z
Reg 7 XVII.E Standards
(g/hp-hr)
NOx: 1.0 CO: 2.0 VOC: 0.7
Reg 7 XVI.B (Ozone NAA
requirements) applies?
Yes
MACT ZZZZ (area source)
Is this engine subject to MACT LZLZ area
source requirements?
Yes
NSPS JJJJ
Is this engine subject to NSPS JJJJ?
Yes
Note: JJJJ requriements are not currently included as permit conditions because the reg has not
been adopted into Reg 6.
Comments/Notes
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
FACILITY EMISSION SUMMARY
Company Name
County AIRS ID
Plant AIRS ID
Facility Name
Discovery DJ Services LLC
123
9F71
Discovery West Brighton Compressor Station
History File Edit Date
Ozone Status
10/16/2017
Non -Attainment
Author
Betsy Gillard
EMISSIONS - Uncontrolled (tons per year
EMISSIONS With Contro s (tons per year
POINT
AIRS ID
PERMIT
Description
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug VOC
CO
Total
HAPs
PM10
PM2.5
H2S
SO2
NOx
VOC
Fug VOC
CO
Total
HAPs
REMARKS
Previous FACILITY TOTAL
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
New Facility - No Previous Total
Previous Permitted Facility total
0.0
0.0
0.0
0.0
0.0
0.0
'0.0
0.0
0.0
Do
0.0
0.0
D0
0.0
0.0
0.0
0.0
0.0
001
17111/01165
Compressor Maintenance Slowdowns
4.3
0.2
4.3
0.2
002
17WE1165
TEG Glycol Dehy '
113.3
34.0
5.7
1.7
003
17WE1165
TEG Glycol Dehy
113.3
34.0
5.7
1.7
004
17WE1165
Process. Flare
5.3
10.6
0.0
5.3
10.6
0.0
005
17WE1165
Caterpillar A3606 Compressor 1875 hp
9.1
27.2
49.2
4.7
9.1
5.4
2.7
1.4
006
17WE1165
Caterpillar A3606 Compressor 1875 hp
9.1
27.2
49.2
4.7
9.1
5.4
2.7
1.4
007
17WE1165
Caterpillar A3606 Compressor 1875 hp
-
9.1
27.2
49.2
4.7
9.1
5.4
2.7
1.4
008
17WE1165
Caterpillar G3516J Compressor 1380 hp
6.7
12.1
-
32.4
6.6
6.7
4.8
2.7
1.3
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
FACILITY TOTAL
0.0
0.0
0.0
0.0
39.3
324.6
0.0
190.6
88.9
0.0
0.0
0.0
0.0
39.3
36.7
0.0
21.4
9.3
VOC: Syn Minor(NANSR and OP)
CO: Bye Minor(OP)
HAPS: Syn Minor B, T, X, HCHO & Total
HH: Syn Minor +affected Area
ZZZZ: Syn Minor
Permitted Facility Total
0.0
0.0
0.0
0.0
#REPI
324.E
#RGTt
#REP/
50.2
0.0
0.0
0.0
0.0
#REFI
36.7
#RfiFl
#RG51
6.1
Excludes units exempt from permits/APENs
(A) Change In Permitted Emissions
0.0
0.0
0.0
0.0
#REFI
36.7
#REFI
#REFI
Pubcom required
Total VOC Facility Emissions (point and fugitive)
(A) Change in Total Permitted VOC emissions (point and fugitive)
36.7
Facility is eligible for GP02 because < 90 tpy
Project emissions less than 25150 tpy
#REF!
Note 1
Points 001 and 005 initially filed by operator for addition to Permit 17WE0783, but cancelled before the permit was Issued as both fell below APEN thresholds.
Note 2
NOx and CO emissions for Points 003 & 004 are reflected in the process flare emission summary (Point 006)
Page 12 of 13
Printed 11/22/2017
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION DIVISION
FACILITY EMISSION SUMMARY - HAPs
Company Name
County AIRS ID
Plant AIRS ID
Facility Name
Discovery DJ Services LLC
123
9F71
Discovery West Brighton Compressor Station
Emissions - uncontrolled (Ibs per year
POINT PERMIT
Description
Formaldehyde
Acetaldehyde
Acrolein
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
McOH
224 TMP
H2S
TOTAL (tpy)
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
17WE1165
Compressor Maintenance Blowdowns
23
41
10
21
336
0.2
002
17WE1165
TEG Glycol Dehy
21811
24428
6023
11653
4096
2
34.0
003
17WE1165
TEG Glycol Dehy
21811
24428
6023
11653
4096
2
34.0
004
17WE1165
Process Flare
0.0
005
17WE1165
Caterpillar A3606 Compressor 1875 hp
7242
1030
633
54
137
308
4.7
006
17WE1165
Caterpillar A3606 Compressor 1875 hp
7242
1030
633
54
137
308
4.7
007
17WE1165
Caterpillar A3606 Compressor 1875 hp
7242
1030
633
54
137
308
4.7
008
17WE1165
Caterpillar G3516J Compressor 1380 hp
11460
834
513
40
101
227
6.6
0.0
0.0
0.0
0.0
TOTAL (tpy)
16.6
2.0
1.2
21.9
24.4
6.0
11.7
4.5
0.6
0.0
0.0
0.0
88.9
*Total Reportable = all HAPs where uncontrolled emissions > de minimus values
Red Text: uncontrolled emissions < de minimus
Emissions with controls (Ibs per year
POINT PERMIT
Description -
Formaldehyde
Acetaldehyde
Acrolein
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
McOH
224TMP
H2S
TOTAL (tpy)
Previous FACILITY TOTAL
0
0
0
0
0
0
0
0
0
0
0
0
0.0
001
17WE1165
Compressor Maintenance Blowdowns
23
41
14
21
336
0.2
002
17WE1165
TEG Glycol Dehy
1091
1221
301
583
205
0
1.7
003
17WE1165
TEG Glycol Dehy
1091
1221
301
583
205
0
1.7
004
17WE1165
Process Flare
0.0
005
17WE1165
Caterpillar A3606 Compressor 1875 hp
724
1030
633
54
137
308
1.4
006
17WE1165
Caterpillar A3606 Compressor 1875 hp
724
1030
633
54
137
308
1.4
007
17WE1165
Caterpillar A36D6 Compressor 1875 hp
724
1030
633
54
137
308
1.4
008
17WE1165
Caterpillar G3516J Compressor 1380 hp
933
834
513
40
101
227
1.3
0.0
0.0
0.0
0.0
TOTAL (tpy)
1.6
2.0
1.2 -
1.2
1.2
0.3
0.6
0.6
0.6
0.0
0.0
0.0
9.3
13
17WE1165.CP1.xlsm
11/22/2017
Permit number:
Date issued:
Issued to:
A D C?
n Contra
Itc Heal
CONSTRUCTION PERMIT
17WE1165
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General
Description:
Issuance: I
Discovery DJ Services LLC
Discovery West Brighton Compressor Station
123/9F71
SEC 28 T1 N R67W
Weld County
Natural Gas Compressor Station
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
CB
001
Compressor maintenance blowdowns.
None
D-3101
002
One (1) Triethylene glycol (TEG) natural gas
dehydration unit (make, model, serial number: TBD)
with a design capacity of 20 MMscf per day. This
emissions unit is equipped with two (2) glycol pumps
(make, model: TBD) with a total design capacity of 4.2
gallons per minute. This unit is equipped with a flash
tank and still vent.
Enclosed Flare
D-3111
003
One (1) Triethylene glycol (TEG) natural gas
dehydration unit (make, model, serial number: TBD)
with a design capacity of 20 MMscf per day. This
emissions unit is equipped with two (2) glycol pumps
(make, model: TBD) with a total design capacity of 4.2
gallons per minute. This unit is equipped with a flash
tank and still vent.
Enclosed Flare
F 4101
004
Process flare controlling emissions from TEG
dehydrators (Points 002 if 003) and slop tanks.
None
C 210
005
One (1) Caterpillar 3606 A4, serial number TBD, natural
gas -fired, turbo -charged, 45LB reciprocating internal
combustion engine, site rated at 1875 horsepower. This
emission unit is used for natural gas compression.
Oxidation catalyst
and air/fuel ratio
control
COLORADO
Air Pollution Control Division
Page 1 of 23
C-
C -212
007
ar 3606 A4 iW umber TB
-charged,ocating i
e, site horsep'
ed fo
One aterpi ar serial number natural
gas -fired, turbo -charged, 4SLB reciprocating internal
combustion engine, site rated at 1875 horsepower. This
emission unit is used for natural gas compression.
One (1) Caterpillar G3516 J, serial number TBD, natural
gas -fired, turbo -charged, 4SLB reciprocating internal
combustion engine, site rated at 1380 horsepower. This
emission unit is used for natural gas compression.
Oxidati catalyst
and air el ratio
control
Oxidation catalyst
and air/fuel ratio
control
C-213
008
Oxidation catalyst
and air/fuel ratio
control
Points 005, 006, 007: These engines may be replaced with another engine in accordance with the
temporary engine replacement provision or another Caterpillar 3603 A4 engine in accordance with the
permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as
Attachment A.
Point 008: This engine may be replaced with another engine in accordance with the temporary engine
replacement provision or another Caterpillar G3516 J engine in accordance with the permanent
replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment
A.
This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission
and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this specific general
terms and conditions included in this document and the following specific terms and conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the
latter of commencement of operation or issuance of this permit, by submitting a Notice of
Startup form to the Division for the equipment covered by this permit. The Notice of Startup
form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting-
notices. Failure to notify the Division of startup of the permitted source is a violation of Air
Quality Control Commission (AQCC) Regulation 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/pacific/cdphe/air-permit-self-
certification. (Regulation Number 3, Part B, Section III.G.2.)
3. This permit shall expire if the owner or operator of the source for which this permit was issued:
(i) does not commence construction/modification or operation of this source within 18 months
after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit; (ii) discontinues construction for a period of eighteen months or
more; (iii) does not complete construction within a reasonable time of the estimated completion
date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section
III.F.4.)
4. The operator shall complete all initial compliance testing and sampling as required in this permit
and submit the results to the Division as part of the self -certification process. (Regulation
Number 3, Part B, Section III.E.)
,COLORADO
11lir Pollution Control Division
C^vYr?rirtvrt
Page -2 of 23
5. nts 002 R �_' � : Th � nformatio provided ision withi _._ teen (15)
ent of op . suance o is p emit.
rial number
• The glycol circu ation pump manu acturer name and mo•e number
This information shall be included with the Notice of Startup submitted for the equipment.
(Reference: Regulation Number 3, Part B, III.E.)
6. Points 005-008: 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.
• manufacture date
• construction date
• order date
• date of relocation into Colorado
• manufacturer
• model number
• serial number
This information shall be included with the Notice of Startup submitted for the equipment.
(Reference: Regulation No. 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 atone 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 I I.A.4. )
9. Monthly Limits:
Facility
Equipment ID
AIRS
Point
Tons per Month
Emission
Type
PM2.5
NO.
VOC
CO
D-3101
002
--
--
0.5
--
Point
D-3111
003
--
--
0.5
--
Point
C-210
005
--
0.8
0.5
0.3
Point
C-211
006
--
0.8
0.5
0.3
Point
C-212
007
--
0.8
0.5
0.3
Point
C-213
008
-
0.6
0.4
0.3
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.
COLORADO
Air Pollution Control Division
`ryr,,Cr-r.: a er fii� � H ee �.v Envhnrrne+
Page 3 of 23
air pollut. Il apply to •ermitted
Facility
Equipment ID
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NO),
V0C
CO
CB
001
--
--
4.4
--
Point
D-3101
002
--
--
5.7
--
Point
D-3111
003
--
--
5.7
--
Point
F-4101
004
--
5.4
--
10.7
Point
C-210
005
--
9.1
5.4
2.7
Point
C-211
006
--
9.1
5.4
2.7
Point
C-212
007
--
9.1
5.4
2.7
Point
C-213
008
-
6.7
4.8
2.7
Point
Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate
limits.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per
year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
Points 002, 003, 005-008: During the first twelve (12) months of operation, compliance with
both the monthly and annual emission limitations is required. After the first twelve (12) months
of operation, compliance with only the annual limitation is required.
Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be
determined on a rolling twelve (12) month total. By the end of each month, a new twelve month
total is calculated based on the previous twelve months' data. The permit holder shall calculate
actual emissions each month and keep a compliance record on site or at a local field office with
site responsibility for Division review.
10. Points 002 ft 003: Compliance with the emission limits in this permit shall be demonstrated by
running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent
extended wet gas analysis and recorded operational values, including: gas throughput, lean glycol
recirculation rate, condenser temperature, 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.
11. The emission points in the table below shall be operated and maintained with the emissions
control equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit. (Regulation Number 3, Part B, Section III.E.)
COLORADO
Air Pollution Control Division
"t fiAati� 1e_;;:n E^virOnntent
Page 4 of 23
Facility ..
E ui men�E_;'
q p
A
P�
Device
utants
C rolled
D-3101
002
Still Vent: Enclosed Flare
HAPs
Flash Tank: Enclosed Flare
VOC and HAPs
D-3111
003
Still Vent: Enclosed Flare
VOC and HAPs
Flash Tank: Enclosed Flare
VOC and HAPs
C-210
005
Oxidation catalyst and air/fuel ratio controller
NOx, VOC, CO,
Formaldehyde
C-211
006
Oxidation catalyst and air/fuel ratio controller
NOx, VOC, CO,
Formaldehyde
C-212
007
Oxidation catalyst and air/fuel ratio controller
NOx, VOC, CO,
Formaldehyde
C-213
008
Oxidation catalyst and air/fuel ratio controller
NOx, VOC, CO,
Formaldehyde
PROCESS LIMITATIONS AND RECORDS
12. 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)
CB
001
Natural gas vented
0.40 MMscf
N/A
D-3101
002
Natural gas throughput
7300 MMscf
620 MMscf
D-3111
003
Natural gas throughput
7300 MMscf
620 MMscf
F-4101
004
Natural gas combusted
51.5 MMscf
4.38 MMscf
C-210
005
Consumption of natural
gas as a fuel
109.0 MMscf
9.26 MMscf
C-211
006
Consumption of natural
gas as a fuel
109.0 MMscf
9.26 MMscf
C-212
007
Consumption of natural
gas as a fuel
109.0 MMscf
9.26 MMscf
C-213
008
Consumption of natural
gas as a fuel
80.2 MMscf
6.82 MMscf
Points 002 £t 003: The owner or operator shall monitor monthly process rates based on the
calendar month. The volume of gas processed shall be measured by gas meter or by assuming the
maximum design rate of the dehydrator unit of 20.0 MMscf/d.
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.
COLORADO
I Air Pollution Control Division
Jepr✓ti1tnt U. Pubic: He, th n f•;^.'i,6r 312 :t
Page 5 of 23
hput limit
, a new tw
't holder
cal fi
determin
total is
to thro
�.ite res
lung twely 2) month
d based on previous
put each month :! d keep a
sibility, for Divis r review.
13. Points 002 Et 003: This unit shall be limited to the maximum lean glycol circulation rate of 4.2
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)
14. Points 002 ft 003: On a monthly basis,the owner or operator shall monitor and record
operational values including: flash tank temperature and pressure, and wet gas inlet temperature
and pressure. These records shall be maintained for a period of five years.
15. Points 005-008: Fuel consumption shall be measured by one of the following methods: individual
engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of
operation; or manufacturer -provided fuel consumption rate.
STATE AND FEDERAL REGULATORY REQUIREMENTS
16. Points 002-008: 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. Point 001: The owner or operator shall record the following information during each compressor
blowdown. Records shall be maintained by the applicant and made available to the Division for
inspection upon request. (Reference: Regulation No. 3 Part B, II.A.4)
• Date and time of blowdown.
• Estimated volume of each blowdown.
In order to demonstrate compliance with the emission limitations of this permit, emissions due
to blowdown activities shall be calculated on a monthly basis. The emissions calculations shall
be based on the information collected above and the emission factors listed in the Notes section
of this permit. VOC and HAP emissions collected from each event shall be summed to obtain
monthly emissions from vented blowdown activities. Monthly emissions shall be used in a rolling
twelve-month total to monitor compliance with the annual limitations. Each month a new twelve-
month total shall be calculated using the previous twelve months' data.
19. Points 002 Et 003: This source is subject to Regulation Number 7, Section XII.H. The operator
shall comply with all applicable requirements of Section XII and, specifically, shall:
• Comply with the recordkeeping, monitoring, reporting and emission control
requirements for glycol natural gas dehydrators; and
• 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. Points. 002 a 003: The glycol dehydration unit covered by this permit is subject to the emission
control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents
and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an
duction o• natural • If i ressor stat , or gas -
trot requir - suant to •c 1 XVII.D.4., ll reduce
hydrocar •ns by a ' -ast 95% a rolling twelve +nth basis
21. Points 002 & 003: The glycol dehydration unit at this facility is subject to National Emissions
Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production
Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this
regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E,
Subpart A and HH-)
MACT HH Applicable
Requirements
Area Source
Benzene emissions exemption
563.764 - General
Standards
§63.764 (e)(1) - The owner or operator is exempt from the requirements of
paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii)
of this section are met, except that the records of the determination of
these criteria must be maintained as required in §63.774(d)(1).
§63.764 (e)(1)(ii) - The actual average emissions of benzene from the glycol
dehydration unit process vent to the atmosphere are less than 0.90
megagram per year, as determined by the procedures specified in
§63.772(b)(2) of this subpart.
$63.772 - Test
Methods, Compliance
Procedures and
Compliance
Demonstration
§63.772(b) - Determination of glycol dehydration unit flowrate or benzene
emissions. The procedures of this paragraph shall be used by an owner or
operator to determine glycol dehydration unit natural gas flowrate or
benzene emissions to meet the criteria for an exemption from control
requirements under §63.764(e)(1).
§63.772(b)(2) - The determination of actual average benzene emissions
from a glycol dehydration unit shall be made using the procedures of either
paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined
either uncontrolled, or with federally enforceable controls in place.
$63.772(b)(2)(i) - The owner or operator shall determine actual average
benzene emissions using the model GRI-GLYCalc TM, Version 3.0 or higher,
and the procedures presented in the associated GRI-GLYCaIc TA°Technical
Reference Manual. Inputs to the model shall be representative of actual
operating conditions of the glycol dehydration unit and may be determined
using the procedures documented in the Gas Research Institute (GRI) report
entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator
Emissions" (GRI-95/0368.1); or
§63.772(b)(2)(ii) - The owner or operator shall determine an average mass
rate of benzene emissions in kilograms per hour through direct measurement
using the methods in $63.772(a)(1)(i) or (ii), or an alternative method
according to §63.7(f). Annual emissions in kilograms per year shall be
determined by multiplying the mass rate by the number of hours the unit is
operated per year. This result shall be converted to megagrams per year.
563.774 -
Recordkeeping
Requirements
§63.774 (d)(1) - An owner or operator of a glycol dehydration unit that
meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall
maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii)
of this section, as appropriate, for that glycol dehydration unit.
§63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of
benzene emissions per year) as determined in accordance with
$63.772(b)(2).
(COLORADO
I Air Pollution Control Division
ti*prrotm ,: a Ot Punt:= Het: h 1, F=-rvir-rrtent
Page 7 of 23
22. s omb; low e covered •ermit is ; 1 • Regulatio ' umber 7,
ons (Stat rceable) a re or other mbustion
of vola e orgam ;;.mpoun « ;° o comply with Se • n XVII, it
le e sions dun normal aerations, as d ed under
on Numbe , ? .16, • "': : =" igned ." . a "" :`:" = ` er can, by visual
observation from the outside of the enclosed flare or combustion device, or by other convenient
means approved by the Division, determine whether it is operating properly. This flare must be
equipped with an operational auto -igniter according to the following schedule:
• All combustion devices installed on or after May 1, 2014, must be equipped with an
operational auto -igniter upon installation of the combustion device;
• All combustion devices installed before May 1, 2014, must be equipped with an
operational auto -igniter by or before May 1, 2016, or after the next combustion device
planned shutdown, whichever comes first.
23. Points 005-008: This equipment is subject to the control requirements for stationary and
portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.2. For
lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required.
24. Points 005-008: These sources are subject to 40 CFR, Part 60, Subpart 0000a- Standards of
Performance for Crude Oil and Natural Gas Facilities for which Construction Modification or
Reconstruction Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting
- effective August 02, 2016). This rule has not yet been incorporated into Colorado Air Quality
Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA
website at: https://www.gpo.gov/fdsys/pkg/FR-2016-06-03/pdf/2016-11971.pdf.
25. Points 005-008: Visible emissions shall not exceed twenty percent (20%) opacity during normal
operation of the source. During periods of startup, process modification, or adjustment of
control equipment visible emissions shall not exceed 30% opacity for more than six minutes in
any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections
XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section
II.A.1. It 4.)
26. Points 005-008: This equipment is subject to the control requirements for natural gas -fired
reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only
enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion
engine that is either constructed or relocated to the state of Colorado from another state after
the date listed in the table below shall operate and maintain each engine according to the
manufacturer's written instructions or procedures to the extent practicable and consistent with
technological limitations and good engineering and maintenance practices over the entire life of
the engine so that it achieves the emission standards required in the table below:
nt 004: T
tion XVII.
ice is use
ll b
Maximum' Engine
HP
Construction or
Relocation Date
Emission Standard in g/hp-hr
NOx
CO
VOC
<100HP
Any
N/A
N/A
N/A
≥100HP and
<500HP
January 1, 2008
January 1, 2011
2.0
1.0
4.0
2.0
1.0
0.7
≥500HP
July 1, 2007
July 1, 2010
2.0
1.0
4.0
2.0
1.0
0.7
account for deration.
27. Points 005-008: This source is subject to the requirements of:
COLORADO
Air Pollution Control Division
;panment "r% Pubk Heten
Page 8 of 23
rt E , SuFFFF: Nmissions Sards for
tants for S ciprocat n = nal Combu n Engines
rt 63, S n`•art ZZ .nd
egula , PQ A f l.A, a tandards f
pollutants for Source Categories: General Provisions, 40 CFR Part 63
including, but not limited to, the following:
• Emission and Operating Limitations
o 63.6600(b) - If you own or operate a new or reconstructed 4SLB stationary RICE with
a site rating of more than 500 brake HP located at major source of HAP emissions
you must comply with the following emission limitations (Table 2a, Subpart ZZZZ to
Part 63):
• reduce CO emissions by 93 percent or more; or
• limit concentration of formaldehyde in the stationary RICE exhaust to 14
ppmvd or less at 15 percent 02.
o 63.6600(b) - If you own or operate a new or reconstructed 4SLB stationary RICE with
a site rating of more than 500 brake HP located at major source of HAP emissions
you must comply with the following operating limitations (Table 2b, Subpart ZZZZ to
Part 63):
• maintain your catalyst so that the pressure drop across the catalyst does not
change by more than 2 inches of water at 100 percent load plus or minus 10
percent from the pressure drop across the catalyst that was measured during
the initial performance test; and
• maintain the temperature of your stationary RICE exhaust so that the
catalyst inlet temperature is greater than or equal to 450 °F and less than
or equal to 1350 ° F.
• General Compliance Requirements
o §63.6605(a) - You must be in compliance with the emission limitations and operating
limitations in this subpart that apply to you at all times, except during periods of
startup, shutdown, and malfunction.
o §63.6605(b) - If you must comply with emission limitations and operating limitations,
you must operate and maintain your stationary RICE, including air pollution control
and monitoring equipment, in a manner consistent with good air pollution control
practices for minimizing emissions at all times, including during startup, shutdown,
and malfunction.
• Testing and Initial Compliance Requirements
o §63.6610(a) - You must conduct the initial performance test or other initial
compliance demonstrations in Table 4 to Subpart ZZZZ of Part 63 that apply to you
within 180 days after the compliance date that is specified for your stationary RICE
in §63.6595 and according to the provisions in $63.7(a)(2).
o §63.6615 - If you must comply with the emission limitations and operating
limitations, you must conduct subsequent performance tests semiannually (as per
Table 3 of Subpart ZZZZ to Part 63). After you have demonstrated compliance for
two consecutive tests, you may reduce the frequency of subsequent performance
tests to annually. If the results of any subsequent annual performance test indicate
the stationary RICE is not in compliance with the CO or formaldehyde emission
limitation, or you deviate from any of your operating limitations, you must resume
semiannual performance tests.
COLORADO
Air Pollution Control Division
Page 9 of 23
ect to in
erate, and
et and
hs 6
63.
Table 5 ofsubpart,
O and eiths•xygen or
rol device acco g to the
25(4) of Subpart £ fr Z to Part
o §63.6625(b) - If you are required to install a continuous parameter monitoring
system (CPMS) as specified in Table 5 of this subpart, you must install, operate, and
maintain each CPMS according to the requirements in §63.8.
o §63.6630(a) - You must demonstrate initial compliance with each emission and
operating limitation that applies to you according to Table 5 of Subpart ZZZZ to Part
63.
o §63.6630(b) - During the initial performance test, you must establish each operating
limitation in Tables 1 b and 2b of Subpart ZZZZ to Part 63 that applies to you.
o §63.6630(c) - You must submit the Notification of Compliance Status containing the
results of the initial compliance demonstration according to the requirements in
§63.6645.
• Continuous Compliance Requirements
o §63.6635(b) - Except for monitor malfunctions, associated repairs, and required
quality assurance or control activities (including, as applicable, calibration checks
and required zero and span adjustments), you must monitor continuously at all times
that the stationary RICE is operating.
o §63.6635(c) - You may not use data recorded during monitoring malfunctions,
associated repairs, and required quality assurance or control activities in data
averages and calculations used to report emission or operating levels. You must,
however, use all the valid data collected during all other periods.
o §63.6640(a) - You must demonstrate continuous compliance with each emission
limitation and operating limitation in Tables la and lb and Tables 2a and 2b of
subpart ZZZZ of Part 63 that apply to you according to methods specified in Table 6
of Subpart ZZZZ of Part 63.
o §63.6640(b) - You must report each instance in which you did not meet each
emission limitation or operating limitation in Tables 1a and 1b and Tables 2a and 2b
of Subpart ZZZZ of Part 63 that apply to you. These instances are deviations from
the emission and operating limitations in this subpart. These deviations must be
reported according to the requirements in §63.6650. If you change your catalyst, you
must reestablish the values of the operating parameters measured during the initial
performance test. When you reestablish the values of your operating parameters,
you must also conduct a performance test to demonstrate that you are meeting the
required emission limitation applicable to your stationary RICE.
o §63.6640(d) - Consistent with §§63.6(e) and 63.7(e)(1), deviations from the emission
or operating limitations that occur during a period of startup, shutdown, or
malfunction are not violations if you demonstrate to the Administrator's satisfaction
that you were operating in accordance with §63.6(e)(1). For new, reconstructed, and
rebuilt stationary RICE, deviations from the emission or operating limitations that
occur during the first 200 hours of operation from engine startup (engine burn -in
period) are not violations.
o §63.6640(e) - You must also report each instance in which you did not meet the
requirements in Table 8 of Subpart ZZZZ to Part 63 that apply to you.
• Notifications, Reports and Records
COLORADO
Air Pollution Control Division
Page 10 of 23
645
rake
icati
and
tionary RI e . i site rating ore than
HAP ems .ns'u must sub all of the
, 63.8(-;, f)(4) an )(6), 63.9(b)thr• (e), and
the date cified
o 563.6645(g) - If you are required to conduct a performance test, you must submit a
Notification of Intent to conduct a performance test at least 60 days before the
performance test is scheduled to begin as required in §63.7(b)(1).
o 563.6645(h) - If you are required to conduct a performance test or other initial
compliance demonstration as specified in Tables 4 and 5 of Subpart ZZZZ to Part 63,
you must submit a Notification of Compliance Status according to §63.9(h)(2)(ii).
• §63.6645(h)(1) - For each initial compliance demonstration required in
Table 5 of Subpart ZZZZ to Part 63 that does not include a performance test,
you must submit the Notification of Compliance Status before the close of
business on the 30th day following the completion of the initial compliance
demonstration.
• §63.6645(h)(2) - For each initial compliance demonstration required in
Table 5 of Subpart ZZZZ to Part 63 that includes a performance test
conducted according to the requirements in Table 3 to this subpart, you must
submit the Notification of Compliance Status, including the performance test
results, before the close of business on the 60th day following the completion
of the performance test according to §63.10(d)(2).
o 563.6650(a) - You must submit each report in Table 7 of Subpart ZZZZ to Part 63
that applies to you.
o 563.6655(a) - If you must comply with the emission and operating limitations, you
must keep the records described in §63.6655(a)(1) through (a)(3), §63.6655 (b)(1)
through (b)(3) and §63.6655 (c).
o 563.6655(d) - You must keep the records required in Table 6 of Subpart ZZZZ of Part
63 to show continuous compliance with each emission or operating limitation that
applies to you.
o §63.6660(a) Your records must be in a form suitable and readily available for
expeditious review according to §63.10(b)(1).
o §63.6660(b) - As specified in §63.10(b)(1), you must keep each record for 5 years
following the date of each occurrence, measurement, maintenance, corrective
action, report, or record.
o 563.6660(c) - You must keep each record readily accessible in hard copy or
electronic form on -site for at least 2 years after the date of each occurrence,
measurement, maintenance, corrective action, report, or record, according to
§63.10(b)(1). You can keep the records off -site for the remaining 3 years.
• Other Requirements and Information
o §63.6665 - Table 8 to this subpart shows which parts of the General Provisions in
§§63.1 through 63.15 apply to you.
OPERATING £t MAINTENANCE REQUIREMENTS
28. Points 002-O08: 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 Oi:tM plan are subject to Division approval prior to implementation. (Regulation
Number 3, Part B, Section III.G.7.)
COLORADO
Air Pollution Control Division
rtment kZ ate&. w a Cnimnrnert
Page 11 of 23
29. y !�2 Et 0 The r or ;aerator sh om.l � the initial exten wet gas
a a sis within one `un:re " and eig y ays(180) o `" e` at er o commencemen o '`•p ' -ration
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. Points 005-008; A source initial compliance test shall be conducted on to measure the emission
rate(s) for the pollutants listed below in order to demonstrate compliance with the emission
limits in this permit. The test protocol must be in accordance with the requirements of the Air
Pollution Control Division Compliance Test Manual and shall be submitted to the Division for
review and approval at least thirty (30) days prior to testing. No compliance test shall be
conducted without prior approval from the Division. Any compliance test conducted to show
compliance with a monthly or annual emission limitation shall have the results projected up to
the monthly or annual averaging time by multiplying the test results by the allowable number of
operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3)
Oxides of Nitrogen using EPA approved methods
Carbon Monoxide using EPA approved methods
Formaldehyde
31. Point 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.16)
Periodic Testing Requirements
32. Points 002 Et. 003: The owner or operator shall complete an extended wet gas analysis prior to
the inlet of the dehydration unit on an annual basis. Results of the wet gas analysis shall be used
to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be
provided to the Division upon request.
33. Points 005-008: This engine is subject to the periodic testing requirements of 40 C.F.R Part 63,
Subpart ZZZZ.
34. Points 005- 008: This engine is subject to the periodic testing requirements as specified in the
operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan
are subject to Division approval. Replacements of this unit completed as Alternative Operating
Scenarios may be subject to additional testing requirements as specified in Attachment A.
ADDITIONAL REQUIREMENTS
35. 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 NO), per year, a change in
COLORADO
Air Pollution Control Division
Heak
Page 12 of 23
ces e
tor50;°s•er
ast APEN s .` =; or
ear or mo in • percent, chever is
PEN; or.
re, a cage in actual emi ns of five
is less ss`ove the level re • : -d on the
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or activity;
or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
GENERAL TERMS AND CONDITIONS
36. 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.
37. 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 alt 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.
38. 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.
39. 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.
40. 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.
41. 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
COLORADO
Mr Pollution Control Division
Page 13 of 23
rce or acti nued, the st notify
ancellatio the •on notific l fee bill
42 lation of term £ ape or of provision! .f the
Act orlatiCC t
enforcement actions under Sections 25-7-115 (enforcement),
penalties), -122.1 (criminal penalties), C.R.S.
By:
Betsy Gillard
Permit Engineer
Permit History
on in writin mss -questing
erminate.
rado Air Pollutio revention
• istrative, Y iminal
-121 (injunctions), -122 (civil
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Discovery DJ Services LLC.
COLORADO
Pollution Control Division
Page 14 of 23
Notes t permit iss
1) The rmit holde Ar equi to ees for th time fo s pe it. An invo for these
fee =ll be iss -fter t .ermi ssued e perms lder sh .ay the invoice w n 30 days
e invevocation ermit.
(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)
CB
001
n -Hexane
110543
336
N/A
D-3101
002
Benzene
71432
21,811
1091
Toluene
108883
24,428
1221
Ethylbenzene
100414
6023
301
Xylenes
1330207
11,653
583
n -Hexane
110543
4096
205
D-3111
003
Benzene
71432
21,811
1091
Toluene
108883
24,428
1221
Ethylbenzene
100414
6023
301
Xylenes
1330207
• 11,653
583
n -Hexane
110543
4096
205
C-210
005
Formaldehyde
50000
7242
724
Acetaldehyde
75070
1030
N/A
Acrolein
107028
633
N/A
Methanol
67561
308
N/A
C-211
006
Formaldehyde
50000
7242
724
Acetaldehyde
75070
1030
N/A
Acrolein
107028
633
N/A
COLORADO
Air Pollution Corttro1 Division
€ epartment a Pcbti„ a c4'sn6 Envimnrne
Page 15 of 23
C-212
007
of
rma yde
lde
107028
633
N/A
0000
5070
N
7
Acrolein
Methanol
67561
308
N/A
C-213
008
Formaldehyde
50000
11,460
933
Acetaldehyde
75070
834
N/A
Acrolein
107028
513
N/A
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:
CAS #
Pollutant
Weight Fraction
of Gas (%)
Uncontrolled
Emission Factors
(lb/event)
Source
V0C
33.57
90.41
Mass balance
110543
n -Hexane
1.30
3.50
Points 002 It 003:
The emission levels contained in this permit are based on information provided in the application
and the GRI GlyCalc 4.0 model. Controlled emissions are based on a flare control efficiency of 95%.
Total actual flash tank and still vent combustion emissions are based on the sum of the emissions for
the still vent primary control and flash tank primary control. Total combustion emissions for Points 002
a 003 are reflected in the emission calculations for Point 004: Process Flare.
Point 004:
Pollutant
Uncontrolled Emission
Factors
(lb/MMSCF)
Source
N0x
206.59
TCEQ
CO
413.17
TCEQ
Note: The emissions factors for this point are based on a weighted fuel heating value of 1497 Btu/scf.
Points 005, 006, £t 007:
CAS
Pollutant
Units
Emission Factors
- Uncontrolled
Emission Factors
- Controlled
Emission
Factor Source
N0x
g/bhp-hr
0.50
0.50
Vendor
CO
g/bhp-hr
2.72
0.15
V0C
g/bhp-hr
1.50
0.30
50000
Formaldehyde
g/bhp-hr
0.20
0.02
75070
Acetaldehyde
lb/MMBtu
0.0836
0.0836
AP -42
107028
Acrolein
lb/MMBtu
0.0514
0.0514
67561
Methanol
lb/MMBtu
0.0250
0.0250
Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7500 Btu/hp-hr, a
site -rated horsepower value of 1875, and a fuel heat value of 1130 Btu/scf.
COLORADO
Air Pollution Control Division
'„ep r-1,3011.61' t°ut t t: Fxe :;*t s E^, Ko;.:k rip
Page 16 of 23
lutant. -
ssion F rs
contra
Em : on Factors
� rolled
` ssion
Fa• Source
NOx
g/bhp-hr
0.50
0.50
Vendor
CO
g/bhp-hr
2.43
0.20
VOC
g/bhp-hr
0.91
0.36
50000
Formaldehyde
g/bhp-hr
0.43
0.035
75070
Acetaldehyde
lb/MMBtu
0.0836
0.0836
AP -42
107028
Acrolein
lb/MMBtu
0.0514
0.0514
67561
Methanol
lb/MMBtu
0.0250
0.025O
Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7500 Btu/hp-hr, a
site -rated horsepower value of 1380, and a fuel heat value of 1130 Btu/scf.
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN 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 engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary
Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting -
effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control
Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at:
htto://www.epa.govittn/atw/area/fr18ja08.pdf
8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous
Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal
Register posting - effective March 18, 2008). The January 18, 2008 amendments to include
requirements for area sources and engines < 500 hp located at major sources have not yet been
incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete
subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr181a08.pdf
Additional information regarding area source standards can be found on the EPA website at:
htto://www.epa.gov/ttn/atw/area/arearules.html
9) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous
Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register
posting - effective October 19, 2010). The August 20, 2010 amendments to include requirements for
existing engines located at area sources and existing engines < 500 hp located at major sources have
not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy
of the complete subpart is available on the EPA website at:
http://www.epa.Rov/ttn/atw/rice/fr20au10.pdf Additional information regarding area source
standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html
10) 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.
COLORADO
Air Air Pollution Control Division
^uepart,ent or PutAi_ Kenhi E.,-,,rrunrieRt
Page 17 of 23
Synthetic Minor Source of:
VOC, CO, Benzene, Toluene, Xylenes, Formaldehyde, total HAPs
Operating Permit
NANSR
Synthetic Minor Source of:
VOC
MACT NH
Area Source Requirements: Applicable
MACT ZZZZ
Area Source Requirements: Applicable
NSPS 0000a
Area Source Requirements: Applicable
12) 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/
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 X)00O(X
'COLORADO
Air Pollution Control Division
. ^a?r• ^stc»Pubdte6e th&Environment
Page 18of 23
The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of
natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the
requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating
Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major
Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been
found to meet all applicable substantive and procedural requirements. This permit incorporates and
shall be considered a Construction Permit for any engine replacement performed in accordance with
this AOS, and the permittee shall be allowed to perform such engine replacement without applying for
a revision to this permit or obtaining a new Construction Permit.
A.1 Engine Replacement
The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown
or periodic routine maintenance and repair of an existing onsite engine that requires the use of either
a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90
operating days or less in any 12 month period. "Permanent" is defined as in the same service for more
than 90 operating days in any 12 month period. The 90 days is the total number of days that the
engine is in operation. If the engine operates only part of a day, that day shall count as a single day
towards the 90 -day total. The compliance demonstrations and any periodic monitoring required by this
AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit.
All replacement engines are subject to alt federally applicable and state -only requirements set forth in
this permit (including monitoring and record keeping).
The results of all tests and the associated calculations required by this AOS shall be submitted to the
Division within 30 calendar days of the test or within 60 days of the test if such testing is required to
demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for
five (5) years and made available to the Division upon request.
The permittee shall maintain a log on -site and contemporaneously record the start and stop date of
any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and
serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer,
model number, horsepower, and serial number of the replacement engine. In addition to the log, the
permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make
them available to the Division upon request.
A.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the
emission limits set forth in this permit with an engine that is of the same manufacturer, model, and
horsepower or a different manufacturer, model, or horsepower as the existing engine without
modifying this permit, so long as the emissions from the temporary replacement engine comply with
the emission limitations for the existing permitted engine as determined in section A.2. Measurement
of emissions from the temporary replacement engine shall be made as set forth in section A.2.
A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is
of the same manufacturer, model and horsepower without modifying this permit so long as the
emissions from the permanent replacement engine comply with 1) the permitted annual emission
limitations for the existing engine, 2) any permitted short-term emission limitations for the existing
permitted engine, and 3) the applicable emission limitations as set forth in the Applicability Report
submitted to the Division with the Air Pollutant Emissios Notice (APEN) for the replacement engine (see
[COLORADO
Air Pollution Control Division
ap✓ti:et rr Pulili�
Page 19 of 23
htt.://
Measur
emissio
example ity report f ats).
gine an ; imp nce with th pplicable
An Ai �` : ` missions EN) i '"'r s the rer, model
number and horsepower of the permanent replacement engine shall be filed with the Division for the
permanent replacement engine within 14 calendar days of commencing operation of the replacement
engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining
that the permittee is exercising an alternative operating scenario and is installing a permanent
replacement engine, and a copy of the relevant Applicability Reports for the replacement engine.
Example Applicability Reports can be found at https://www.colorado.gov/pacific/cdphe/alternate-
operating-scenario-aos-reporting-forms. This submittal shall be accompanied by a certification from a
person legally authorized to act on behalf of the source indicating that "based on the information and
belief formed after reasonable inquiry, the statements and information included in the submittal are
true, accurate and complete".
This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt
engine or an engine that is not subject to emission limits.
The permittee shall agree to pay fees based on the normal permit processing rate for review of
information submitted to the Division in regard to any permanent engine replacement.
A.2 Portable Analyzer Testing
Note: In some cases there may be conflicting and/or duplicative testing requirements due to
overlapping Applicable Requirements. In those instances, please contact the Division Field Services
Unit to discuss streamlining the testing requirements.
Note that the testing required by this Condition may be used to satisfy the periodic testing
requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly
portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an
additional portable analyzer test is not required for another three months).
The permittee may conduct a reference method test, in lieu of the portable analyzer test required by
this Condition, if approved in advance by the Division.
The permittee shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust
from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of
commencing operation of the replacement engine.
All portable analyzer testing required by this permit shall be conducted using the Division's Portable
Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's website at:
http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf
Results of the portable analyzer tests shall be used to monitor the compliance status of this unit.
For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of
the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the
month or year (whichever applies) in order to monitor compliance. If a source is not limited in its
hours of operation the test results will be multiplied by the maximum number of hours in the month or
year (8760), whichever applies.
For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr)
or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the
COLORADO
Air Pollution Control Division
r;`e .t Of Public Het4th.'v ? "mrronrnvr.f
Page 20 of 23
replace results of shall be c -fir r to the app riate
units as .cribed in abov e � ,�� red Portablonitorin o o ;; l document
If the • E ble .� r result l dicat with bot ' e NOX CO emission lim_ ions, in
the a • - - : credible evil the . � �, e sour .' e " ' _ the engin
compliance with both the NOX and CO emission limitations for the relevant time period.
Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary,
if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission
limitations, the engine will be considered to be out of compliance from the date of the portable
analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission
limitations or until the engine is taken offline.
A.3 Applicable Regulations for Permanent Engine Replacements
A.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B S II.D.2
All permanent replacement engines that are located in an area that is classified as
attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT)
for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both
VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the
pollutant for which the area is in attainment/maintenance or nonattainment, except as follows:
In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of
emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds
40 tons/yr.
For purposes of this AOS, the following shall be considered RACT for natural-gas fired reciprocating
internal combustion engines:
VOC: The emission limitations in NSPS JJJJ
CO: The emission limitations in NSPS JJJJ
NOX: The emission limitations in NSPS JJJJ
SO2: Use of natural gas as fuel
PM10: Use of natural gas as fuel
As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains
20.0 grains or less of total sulfur per 100 standard cubic feet.
A.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E
(State -Only conditions).
Control Requirements: Section XVI
Any permanent replacement engine located within the boundaries of an ozone nonattainment area is
subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified
below:
Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non-
selective catalyst and air fuel controller to reduce emission.
Lean burn engines with a manufacturer's design rate greater than 500 hp shalt use an oxidation
catalyst to reduce emissions.
COLORADO
Air Pollution Control Division
emtm-tor Puf., Neu#th.& E:rironmee,t
Page 21 of 23
The abo
and mai
ll be appr
er specific
sized for ' e and shall r operated
The sou s shat t copie' the r- -nt A•, icability arts re•,' -d under Conditi• sr' .1.2.
Emission Standards: Section XVII.E - State -only requirements
Any permanent engine that is either constructed or relocated to the state of Colorado from another
state, after the date listed in the table below shall operate and maintain each engine according to the
manufacturer's written instructions or procedures to the extent practicable and consistent with
technological limitations and good engineering and maintenance practices over the entire life of the
engine so that it achieves the emission standards required in the table below:
Max Engine
HP
Construction
or Relocation
Date
Emission Standards in G/hp-hr
NOx
CO
VOC
100<Hp<500
January 1,
2008
2.0
4.0
1.0
January 1,
2011
1.0
2.0
0.7
500<Hp
July 1, 2007
2.0
4.0
1.0
July 1, 2010
1.0
2.0
0.7
The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2
A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 60, Subpart JJJJ
A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines
greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal
to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and
1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject 40
CFR 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements
for the permanent engine replacement shalt be included in the Applicability Reports required under
Condition A.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that
the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under
Condition A.2, if approved in advance by the Division, provided that such test is conducted within the
time frame specified in Condition A.2.
Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from
outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to
the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado
becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ
requirements).
However, as of November 1, 2008 the Division has not yet adopted NSPS JJJJ. Until such time as it
does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts
NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the
provisions of Regulation No. 6, Part 8, § 1.B (which is referenced in Part A), any engine relocated from
outside of the State of Colorado into the State of Colorado is considered to be a new source, subject
to the requirements of NSPS JJJJ.
A.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ
COLORADO
Air Pollution Control Division
t Publit Freeth & Er m nr ter;t
Page 22 of 23
A perm nt re.. ent en ' 9 local tan a source t comm ed construction
reco ' `a ter June 1" , i"• �s de : �" � .2, wil -- - = -ments of 4 •`=""'� 63,
Subpart ZZZZ by meeting the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of the
applicable monitoring, recordkeeping, and reporting requirements for the permanent engine
replacement shall be included in the Applicability Reports required under Condition A.1.2. Any testing
required by the MACT is in addition to that required by this AOS. Note that the initial test required by
the MACT can serve as the testing required by this AOS under Condition A.2, if approved in advance by
the Division, provided that such test is conducted within the time frame specified in Condition A.2.
A.4.3.2 Major source for HAPs
A permanent replacement engine that is located at major source is subject to the requirements in 40
CFR Part 63 Subpart ZZZZ as follows:
Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of
more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ.
New or reconstructed (construction or reconstruction commenced after 12/19/02) 2 stroke and
4 stroke lean burn engines with a site rating of more than 500 hp are subject to the
requirements in 40 CFR Part 63 Subpart ZZZZ.
New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean
burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and
were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63
Subpart ZZZZ.
New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean
burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the
requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart
JJJJ.
New or reconstructed (construction or reconstruction commenced after 6/12/06) 4 stroke lean
burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63,
Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ.
An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the
permanent engine replacement shall be included in the Applicability Reports required under
Condition A.1.2. Any testing required by the MACT is in addition to that required by this AOS.
Note that the initial test required by the MACT can serve as the testing required by this AOS
under Condition A.2, if approved in advance by the Division, provided that such test is
conducted within the time frame specified in Condition A.2.
A.3.5 Additional Sources
The replacement of an existing engine with a new engine is viewed by the Division as the installation of
a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially
an advanced construction permit review. The AOS cannot be used for additional new emission points
for any site; an engine that is being installed as an entirely new emission point and not as part of an
AOS-approved replacement of an existing onsite engine has to go through the appropriate
Construction/Operating permitting process prior to installation.
1COLORADO
Air Pollution Control Division
Page 23 of 23
..m
Natural 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 Natural Gas Venting only. Natural 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. In addition, the General APEN
(Form APCD-200) is available if the specialty APEN options wilt 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.00v/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.
ciF71
Permit Number: A4tE-QZBi_ ji INE 11(.25 AIRS ID Number: 123 /QE- / 001
RECEIVED
NOV 1 0 2017
APCD m
Stationary
Sources
APCD h ,:; tdrrndy nssi≤;,rrr.I : peanm :: ;.Erna AIRS 1Df
Company equipment Identification: CB
li'rnvid r, r.tl!l;r I:.yuipnirr!t ID u, rrllrnttly ho'./ tali; equgnrnrnt n. !, thlrnced ,:Ji!.iii,, ymn' ult;.lni .lti;ml
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery West Brighton Compressor Station
Site Location: Section 28, T1 N, R67W
Mailing Address:
(include zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
E -Mail Address': manya@discoverymidstream,com
Site Location
County: Weld
NAICS or SIC Code: 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
t Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will
appear on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
rut in APCD-:205 Idcstt, ,il Cllr; Vrruin; APF11 Rev 0;1201%
371340
AI7COtORAGO
1I
,1
Permit Number: AIRS ID Number:
IL •.'.'i bionk 11wli"•., Af'I:,O li r. alii•ncly c; ip!nc: l ,I l i)nnil r. ;utti IRS 1111
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 name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Please note blank APENs will not be accepted)
ADDITIONAL PERMIT ACTIONS -
[=I Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
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:
Compressor Blowdown (total for 4 compressors)
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
/ /
01 / 01 / 2018
❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation:
24 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
lot in;i'Cl).Uh Ilam i;l(i i Vc:nl.in!;AI'LII icv()';i/017
7
days/week 52
Yes
❑ Yes
weeks/year
❑ No
O No
AT COLORADO
2 I
Permit Number: AIRS ID Number: / /
�Lcti.rdc f,l:;l,l. uut:. APCU irr; a!r ;:; ly ,r...i in cl :I ;>,ti mil ;: al,Ll
Section 4 - Process Equipment Information
❑ Gas/Liquid Separator
❑ Well Head Casing
❑ 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: 24 per compressor Volume per event: 0.0042 per unit MMscf/event
❑ Other
Description:
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural
Gas Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes
Natural Gas Venting
Process Parameters4:
Liquid Throughput
Process Parameters4:
❑ No
Maximum Vent
Rate:
SCF/hr
Vent Gas
Heating Value:
BTU/SCF
Requested:
0.4032
MMSCF/year
Actual:
MMSCF/year
-OR-
Requested:
Bbl/yr
Actual:
Bbl/yr
Requested values will become permit limitations. Requested limit(s) should consider future process growth
Process Properties:
Molecular Weight:
VOC (mole %)
VOC (Weight %)
33.57
Benzene (mole %)
Benzene (Weight %)
0.09
Toluene (mole %)
Toluene (Weight %)
0.16
Ethylbenzene (mote %)
Ethylbenzene (Weight %)
0.04
Xylene (mole %)
Xylene (Weight %)
0.08
n -Hexane (mole %)
n -Hexane (Weight %)
1.30
2,2,4-Trimethylpentane
(mole %)
2,2,4-Trimethylpentane
(Weight %)
0.001
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 Et n -Hexane, temperature, and
pressure)
I lil 111 AI'l I - 20'3 Pl,.Illlf:}! l ;i5 Venting, All I'i Icl-\, 0.S.' J0I
T cOtOR
Permit Number:
AIRS ID Number:
II �.•uvi• lil,inb unlr^,•. ;iI'L.0 Iris dlic•r, ns.r,n,_rl .r I�, c nil ;inrl I;Iii ; IUJ
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
Latitude 40.021283779/Longitude -104,893770229
Operator
Stack ID No,
Discharge Height
Above Ground Level
(Feet)
Temp.
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
❑ Upward
❑ Horizontal
Indicate the stack opening and size: (check one)
El Circular
❑ Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
Section 6 - Control Device Information
❑ 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:
Constant Pilot Light: El Yes ❑ No Pilot burner Rating
Waste Gas Heat Content
Btu /scf
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
o/ 0
COLORADO
I.ir in irtl'CU 1u!i I.I,i ursrl (At', Vent illy, Af'I:I-I ilciv lei/201 7
Permit Number:
AIRS ID Number:
/ /
ILc.avc l,lcrd, unlc".. w'c:Li Ito; ali va;.ly a,,:i.'ii cl a poi wit. a P,II'.; !Dl
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑ Yes ✓❑ No
if yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SOX
NOX
VOC
CO
HAPs
Other:
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor
Units
Emission
Factor
Source
(AP -42,
Mfg. etc)
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
(Tons/year)
Controlled6
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SOX
NOx
VOC
90.41
lb/event
Engineering Est.
4,34
4.34
CO
Benzene
0.25
lb/event
Engineering Est.
0.0118
0.0118
Toluene
0.42
lb/event
Engineering Est.
0,0201
0.0201
Ethy(benzene
0.10
lb/event
Engineering Esl.
0.0048
0.0048
Xylenes
0.23
lb/event
Engineering Esi.
0.011
0.011
n -Hexane
3.50
lb/event
Engineering Est.
0.1682
0.1682
2,2,4-0.0028
Trimethylpylpentane
lb/event
Engineering Esl.
0.0001
0.0001
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
I +nin al'l_f) %Q' Il il.ural t a: Vc nlnr ',I°i i! Roy i!-i/tII7 5
Z4r.."C0L0FtAD0
Permit Number: AIRS ID Number:
LL1 tV:1 Ii(dit& unlcs, APCD hiri dii`ntly r:'.i;i C l li mnil ; ani.l r\IRS, II]f
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( egally Authorized Person (not a vendor or consultant) Date
Cory G. Jordan
EVP Operations
Name (please 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)
Send this form along with $152.90 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
Telephone: (303) 692-3150
uinI Al't_D-/0!) flatur,il GT; Rev 031201./
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https: //www,colorado.gov/cdphe/apcd
COLORADO
6 I
I� REC EIVEI
NOV 1 0 20171
APCD
Glycol Dehydration Unit APEN - Form APCD-202 S{aliollarti /
JOurce
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this
category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is
available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can
be found on the Air Pollution Control Division (APCD) website at: www.colorado.00v/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.
1 iEaysr o F71 062_Permit Number: i-1 WC 41 [0 5 AIRS ID Number: 123 / .9.14E / '683
I.L avr• i,l:uik unlcess, APCD has ;+licady rar,rhrrl :h permit dntd AIR IDl
Company equipment Identification: D-3101
[Provide I-ac.hlity Cqugi,nent ID to tdertlify how llth equipment is r fetonCcd vdilltin with ou,txuzaihonf
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Sit Name: Discovery West Brighton Compressor Station
Site Location: Section 28, T1 N, R67W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
E -Mail Address': Manya@discoverymidstream.com
Site Location
County: Weld
NAICS or SIC Code: 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
'Please use the full, legal company name registered with the Colorado Secretary of State: This is the company name that will
appear on all documents issued by the APCD, Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided,
Form APCD-202 - Glycol Dehydration Unit APEIl - Revision 02/2011
371341
COLORADO
Permit Number: AIRS ID Number:
(Leave blank unless APCD I v; aire;uly :c,,ignc d a pormil // and AIRS ID1
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 name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of Ownership' ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Please note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-1O4) must be submitted.
Section 3 - General Information
General description of equipment and purpose:
natural gas.
TEG dehydrator for the removal of water from
Facility equipment Identification:
D-3101
For existing sources, operation began on: / /
For new or'reconstructed sources, the projected
start-up date is:
01 /01 /2018
Q Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day
Wilt this equipment be operated in any NAAQS nonattainment
area
Is this unit located at a stationary source that is considered a
Majcr Source of (HAP) Emissions
Form APCD-202 Glycol Dehydration Unit APLPI Revision 02/2017
days/week
Yes
Yes
weeks/year
No
No
Avw COLORADO
2 I
Permit Number: AIRS ID Number:
[Leave blank unless \PCD has already assigned a Ixrrnnil.:! and AIRS ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer:
Dehydrator Serial
Number:
Glycol Used:
TBD
TBD
Ethylene Glycol
(EG)
Model Number: TBD
Reboiler Rating: 0.6
❑ DiEthylene Glycol
(DEG)
Glycol Pump Drive: El Electric ❑ Gas If Gas, injection pump ratio:
Pump Make and Model: TBD
Glycol Recirculation rate (gal/min): Max:
Lean Glycol Water Content:
0.15
4.2
Wt.%
❑✓
MMBTU/hr
hr
TriEthylene Glycol
(TEG)
Requested: 4.2
Acfm/gpm
# of pumps: 2
Dehydrator Gas Throughput:
Design Capacity: 20 MMSCF/day
Requested: 7,300 MMSCF/year Actual: MMSCF/year
Inlet Gas: Pressure: 1100
Water Content: Wet Gas:
Flash Tank: Pressure: 65
Cold Separator: Pressure:
Stripping Gas: (check one)
❑✓ None
Flow Rate:
ri • ▪ Flash Gas
psig Temperature:
lb/MMSCF ❑✓ Saturated
psig Temperature:
psig Temperature:
❑ Dry Gas ❑ Nitrogen
scfm
120
Dry gas:
145
°F
7
lb/MMSCF
"F ❑ NA
°F El NA
Additional Required Information:
• Attach a Process Flow Diagram
CI Attach GRI-GLYCalc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results)
• Attach the extended gas analysis (including BTEX a n -Hexane, temperature, and pressure)
Pori APCD-202 Glycol Dehydration Unit APEII Revision 02/20'17
COLORADO
3 I
Permit Number:
AIRS ID Number:
/ /
[Leave blank nil; unless APCD has already assigned tj Ix r:uit and I\ IRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
Latitude 40.021229347/Longitude -104.894246862
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
❑� Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-202 Glycol Dehydration Unit ADEN - Revision 02/2017
�V COLORADO
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already a,:igned a pciniit /t and AIRS IDj
Section 6 - Control Device Information
Used for control of: Regenerator
• Condenser:
Type: BTEX
Make/Model: TBD
Maximum Temp 400 Average Temp 125
Requested Control Efficiency 0 %
❑ VRU:
Used for control of:
Size: Make /Model:
Requested Control Efficiency %
VRU Downtime or Bypassed
❑ Combustion
Device:
Used for control of:
Rating:
Type:
Regenerator Vent & Flash Gas
6.27
Process Flare
MMBtu/hr
Make/Model: TBD
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency 95 %
Minimum Temperature: Waste Gas Heat Content 1500 Btu/scf
Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating 0.0456 MMBtu/hr
Closed
❑ Loop
System:
Used for control of:
Description:
System Downtime
0
❑ Other:
Used for control of:.
Description:
Control Efficiency
Requested
0/0
Aviv/ COLORADO
Purrs ARC I)-207. Glycol DohydrnIion Unit. ARCH • RovRiion 0?/701;
Permit Number:
AIRS ID Number:
/ /
[Leave ht:nk unless APCD has already assigned a permit. and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(96 reduction in emissions)
PM
SOX
NOX
CO
VOC
BTEX Condenser and Flare
95%
HAPs
BTEX Condenser and Flare
95%
Other:
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor
Units
Emission
Factor
Source
(AP -42,
Mfg. etc)
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)4
Uncontrolled
(Tons/year)
Controiled5
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SOX
NOX
CO
VOC
31.04
lb/MMSCF
GRI-GLYCaIc
113.31
5.7
Benzene
2.99
Ib/MMSCF
GRI-GLYCaIc
10.91
0.55
Toluene
3.35
lb/MMSCF
GRI-GLYCaIc
12.21
0.61
Ethylbenzene
0.83
lb/MMSCF
GRI-GLYCaIc
3.01
0.15
Xytenes
1.60
Ib/MMSCF
GRI-GLYCaIc
5.83
0.29
n -Hexane
0.56
lb/MMSCF
GRI-GLYCaIc
2.05
0.10
2,2,4-
Trimethylpentane
Other:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Farm APCD-202 Glycol Dehydration Unit APEN - Revision 02./2017
6 I
ANWFT, COLORADO
./
Permit Number: AIRS ID Number:
[Leave blank ink unless APCD lids already .r,&i ;nail n pc•nnu ! ,and AIRS IDI
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct,
Signature a vendor or consultant)
F H V - /7
Date
Cory G. Jordan EVP Operations
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)
Send this form along with $152.90 to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-81
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and
Environment
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
(orrn APCD-2O2 Glycol Dehynat Lk, i Unit i\PEH - Revision 02/2017
Aw COLORADO
71
of gaily Aut orized Person (not
Glycol Dehydration Unit APEN - Form APCD-202
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this
category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is
available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can
be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
I',l CE`rti L,
AP CD
,i ,ioaary
-Jtt
I1WEIl�5 RAE l34
OS
Permit Number: +-�.,� AIRS ID Number: 123 / 4F1E / -4304-
[Leave blank tinit.•ss APCD has already assigned as permit t/ and AIRS ID]
Company equipment Identification: D-31 11
[Provide F;r.iln.y Erµiipmnne ID to identify port this equipment is intz•renccd within your ortoniidtlord
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery West Brighton Compressor Station
Site Location
Site Location:
Section 28, Ti N, R67W County: Weld
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
E -Mail Address': Manya@discoverymidstream.com
NAICS or SIC Code: 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
Please 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.
- Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided,
COLORADO
Form APCD-202 • Glycol Dehydration Unit APEN - Revision 02/2017
371342
Permit Number: AIRS ID Number: / /
lLeavc blank unless APCD ha; already assigned <i I nail. i! and AIRS 'Di
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 name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership' 0 Other (describe below)
- OR
APEN submittal for update only (Please 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 £t Notes:
a For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted,
Section 3 - General Information
General description of equipment and purpose:
natural gas.
TEG dehydrator for the removal of water from
Facility equipment Identification:
D-3111
For existing sources, operation began on: / /
For new or reconstructed sources, the projected
start-up date is:
01 /01 /2018
Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day
Will this equipment be operated in any NAAQS nonattainment
area
Is this unit located at a stationary source that is considered a
Major Source of (HAP) Emissions
Him APC 0-202 Glycol Uehydlration Unit, /Pt, N Revkinn 02/2017
days/week
Yes
Yes
weeks/year
No
No
COLORADO
2i
.fi
Permit Number: AIRS ID Number;
[Leave blank unless APCD fins already assigned a lu:nnit r; and,. AIRS ID]
Section 4 - Dehydration Unit Equipment Information
Manufacturer:
Dehydrator Serial
Number:
TBD
TBD
Ethylene Glycol
Glycol Used: ❑ (EG)
CI
Model Number:
TBD
Reboiler Rating: 0.6
DiEthylene Glycol
(DEG)
Glycol Pump Drive: p Electric El Gas If Gas, injection pump ratio:
Pump Make and Model: TBD
Glycol Recirculation rate (gal/min):
Lean Glycol Water Content:
Max: 4.2
0.15
Wt.%
MMBTU/hr
TriEthylene Glycol
(TEG)
Requested: 4.2
Acfm/gpm
It of pumps: 2
Dehydrator Gas Throughput:
Design Capacity:
20
MMSCF/day
Requested: 7,300 MMSCF/year Actual:
MMSCF/year
Inlet Gas:
Water Content:
Flash Tank: Pressure: 65
Cold Separator: Pressure:
Pressure: 1100
Wet Gas:
psig
lb/MMSCF
psig
psig
Stripping Gas: (check one)
0 None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen
Flow Rate:
scfm
Temperature:
0 Saturated Dry gas:
Temperature:
120
Temperature:
145
°F
7
lb/MMSCF
°F ❑ NA
°F 0 NA
Additional Required Information:
Q Attach a Process Flow Diagram
Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results)
❑✓ Attach the extended gas analysis (including BTEX & n -Hexane, temperature, and pressure)
Form APCD-2.02 Glycol Dehydration Unit APLN Revision 02/2017
3 I 7 COLORADO
A
Permit Number:
AIRS ID Number:
(Leave blank unle.s /\PCI) I iliearly as;.igi]ed ;; permit_ Ii find AIRS IDI
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
Latitude 40.021132307/Longitude -104.894373090
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
(.F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
✓❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
✓❑ Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
nnn APCI)-20) Glyc::ul l)eltydiaLion Ufa APL's! Revision 02/2017
\C37?�TJ coLoRAoo
�fi-G�a�.VJ
4I
Permit Number: AIRS ID Number: 1 /
ILeava blank unless APCD leas already T; iuia d a IRA nuir J and AIRS IDI
Section 6 - Control Device Information
Used for control of: Regenerator
r❑ Condenser:
Type: BTEX
Make/Model: TBD
Maximum Temp 400 Average Temp 125
Requested Control Efficiency 0 %
❑ VRU:
Used for control of:
Size: Make/Model:
Requested Control Efficiency %
VRU Downtime or Bypassed
❑ Combustion
r
Device:
Used for control of: Regenerator Vent & Flash Gas
Rating: 6.27
MMBtu/hr
Type: Process Flare Make/Model: TBD
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency 95 %
Minimum Temperature: Waste Gas Heat Content 1500 Btu/scf
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.0456 MMBtu/hr
Closed
❑ Loop
System:
Used for control of:
Description:
System Downtime
0/0
❑ Other:
Used for control of:
Description:
Control Efficiency
Requested
0
Folrn APCD-202 Glycol Deliychralicni Unit RPEN - Revision (P/2017
5I Eco LonAoo
.
Permit Number:
AIRS ID Number: / /
(Leave blank unless APCI:) hes already assigned a permit ,Sr and AIRS IUi
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? E Yes ❑ No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SO,
NOx
CO
VOC
BTEX Condenser and Flare
95%
HAPs
BTEX Condenser and Flare
95%
Other:
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor
Units
Emission
Factor
Source
(AP -42,
Mfg. etc)
Actual Annual Emissions
Requested Annual Permit
gEmission Limit(s)4
Uncontrolled
(Tons/year)
Controlled5
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SO,
NOx
CO
VOC
31.04
lb/MMSCF
GRI-GLYCaIc
113.31
5.7
Benzene
2.99
Ib/MMSCF
GRI-GLYCaIc
10.91
0.55
Toluene
3,35
Ib/MMSCF
GRI-GLYCaIc
12.21
0.61
Ethylbenzene
0,83
lb/MMSCF
GRI-GLYCaIc
3.01
0.15
Xylenes
1.60
Ib/MMSCF
GRI-GLYCaIc
5.83
0.29
n -Hexane
0.56
lb/MMSCF
GRI-GLYCaIc
2.05 -
0.10
2,2,4-
Trimethylpentane
Other:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
:T
form APCD-202 Glycol Dehydration Unit APEI•I Revision 02/2017
6 1 COLORADO
Do..
Permit Number: AIRS ID Number: I I
�Lc�Ivr- hlanl; LII'I€eas APCD has nlr0u1V ,IVA;n+:'c1 6.liurmil /1 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,
//-/0 - r`7
Signature of egally Autl, rized Person (not a vendor or consultant) Date
Cory G. Jordan EVP Operations
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)
Send this form along with $152.90 to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and
Environment
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-202 G[vcul Dehydration Unit APEN • Revision 0717017
Av COLORADO
7I •
General APEN - Form APCD-200
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
#ipV 0 22011
APCD
Stationary
Sow_
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of
specialty APENs is available on the Air Pollution Control Division (APCD) website at:
www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
1-114'164 7433 I-1WEl1(o5
AIRS ID Number: 123
qF7 / OOy-
/ 9F1E / -09g-
[Leave blank unless APCD has already assigned a permit 1; and AIRS ID]
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery West Brighton Compressor Station
Site Location: Section 28, Ti N, R67W
Mailing Address:
(Include Zip Code) 7859 Walnut hill Lane, Suite 335
Dallas, TX 75230
Portable Source N/A
Home Base:
Site Location
County:
Weld
NAICS or SIC Code: 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address2: manya@discoverymidstream.com
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear
on alt documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
x COLOR 7.D0
Form APCD-200 - General APEN - Revision 1/2017 1
371343
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit N and AIRS ID]
Section 2- Requested Action
❑r NEW permit OR newly -reported emission source (check one below)
O STATIONARY source ❑ PORTABLE source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
❑ APEN submittal for permit exempt/grandfathered source
Additional Info @ Notes: Process Flare
3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose:
for TEG Dehydrator and Slop Tanks
Process Flare to control VOC and HAPs
Manufacturer: TBD Model No.: TBD Serial No.: TBD
Company equipment Identification No. (optional): F_4101
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
01/01/2018
Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day
Seasonal use percentage: Dec -Feb: Mar -May:
Form APCD-200 - General APEN - Revision 1/2017
days/week weeks/year
Jun -Aug: Sep -Nov:
MX COLORADO'r
2 I
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 4 - Processing/Manufacturing Information £t Material Use
El Check box if this information is not applicable to source or process
From what year is the actual annual amount?
Description
Design Process
Rate
(Specify Units)
Actual Annual
Amount
(Specify Units)
Requested Annual
Permit Limit4
(Specify Units)
Material
Consumption:
Finished
Product(s):
4 Requested values will become permit limitations, Requested limit(s) should consider future process growth.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
Latitude 40.021035150/Longitude -104.894628826
❑ Check box if the following information is not applicable to the source because emissions will not be emitted
from a stack. If this is the case, the rest of this section may remain blank.
Operator
P
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
LI Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
LI Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
❑ Other (describe):
Form APCD-200 - General APEN - Revision 1/2017
ACOLORADO
Permit Number:
AIRS ID Number:
[Leave blank unless, APCD has already assigned a permit ,r, and AIRS ID]
Section 6 - Combustion Equipment a Fuel Consumption Information
❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated
with this emission source)
Design Input Rate
(MMBTUIhr)
Actual Annual Fuel Use
(Specify Units)
Requested Annual Permit Limit4
(Specify Units)
8.8
51.52 MMscf
From what year is the actual annual fuel use data?
Indicate the type of fuel useds:
❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTUISCF)
❑✓ Field Natural Gas Heating value: 1,500 BTU/SCF
❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon)
❑ Propane (assumed fuel heating value of 2,300 BTU/SCF)
❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content:
O Other (describe); Heating value (give units):
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction);
Pollutant
Control Equipment
Description
Overall Collection Efficiency
Overall Control Efficiency
(% reduction in emissions)
TSP (PM)
PMio
PM2.s
SOx
NOx
CO
VOC
Other:
COLORADO
Form APCD-200 - General APEN - Revision 1/2017
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit iI and AIRS ID]
Section 7 (continued)
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.
Pollutant
Uncontrolled
Emission
Factor
(Specify Units)
Emission
Factor
Source
(AP -42, Mfg.
etc)
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)4
Uncontrolled
(Tons/year)
Controlled6
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
TSP (PM)
PM10
PM2, s
SOX
NO,
0.138Ib/MMBtu
RG-109
5.32
5.32
Co
0.276 lb/MMBtu
RG-109
10.62
10,62
VOC
Other:
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Section 8 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than
250 lbs/year?
❑ Yes I] No
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
CAS
Numbers
Chemical
Name
Overall
Control
Efficiency
Uncontrolled
Emission
Source
Factor
units
(specify )
Emission Factor
(AP -42, Mfg. etc)
Uncontrolled
Actual
Emissions
(fbs/ ear
y )
Controlled
Actual
Emissions6
(lbs/year)
6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-200 - General APEII - Revision 1/2017
COLORADO
'
Permit Number: AIRS ID Number:
[Leave blank unk:ss APCD has already assigned a permit it and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true and correct.
Signature df Legally A thorized Person (not a vendor or consultant) Date
Cory G. Jordan
EVP Operations
Name (print) Title
Check the appropriate box to request a copy of the:
❑ Draft permit prior to issuance
❑� Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $152.90 to: For more information or assistance call:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD-2OO - General APEN - Revision 1/2017
coLonnoo
6 I
0
Reciprocating Internal Combustion
Engine APEN - Form APCD-201
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.
Rf,cti\LE-9:.
ppCD i
st,rionar`
This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression
ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for
your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, 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: t-PKE0783 11 W E LOG AIRS ID Number: 123
ciF7/ 065
/ 9F4E
[Leave blank unless APCD has already assigned a permit 8 and AIRS ID]
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery West Brighton Compressor Station
Site Location: Section 28, Ti N, R67W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Portable Source
Home Base: N/A
Site Location
County: Weld
NAICS or SIC Code: 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address: manya@discoverymidstream.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.
Z Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
COLORADO
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
371344
Permit Number: AIRS ID Number: I I
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 2 - Requested Action
✓❑ NEW permit OR newly -reported emission source (check one below)
❑ STATIONARY source ❑ PORTABLE source
❑� Request coverage under a Construction Permit
❑ Request coverage under General Permit GP023 (Natural Gas Only)
If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along
with the APEN Filing fee.
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment
❑ Change company name ❑ Add point to existing permit
❑ Change permit Limit ❑ Transfer of ownerships ❑ Other (describe below)
- OR
APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit-exempt/grandfathered source
❑ Notification of Alternate Operating Scenario (AOS) permanent replacements
Additional Info l* Notes:
3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary.
a For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements.
Section 3 - General Information
Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes
If yes, provide the Company Equipment Identification No.
General description of equipment and purpose:
C-210
Inlet gas compression
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
(http: / /www.colorado. gov/cdphe/attainment)
Normal Hours of Source Operation: 24 hours/day 7
Seasonal use percentage: Dec -Feb: Mar -May:
01/01/2018
0 Yes ❑ No
days/week 52
June -Aug:
weeks/year
Sept -Nov:
\ COLORADO
Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 I ..:
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit !1 and AIRS ID]
Section 4 - Engine Information
Engine
Function:
❑ Primary and/or Peaking
❑ Pump ❑ Water Pump
❑ Emergency Back-up
❑ Other:
0 Compression
What is the maximum number of hours this engine will be used for emergency
back-up power? 0
Engine Make: Caterpillar Engine Model: 3606 A4 Serial Number6:
hours/year
What is the maximum designed horsepower rating? 1875 hp What is the engine displacement? l/cyl
What is the maximum manufacturer's site -rating? 1875 hp kW
What is the engine Brake Specific Fuel Consumption at 100% Load? 7500 BTU/hp-hr
Engine Features:
Cycle Type: ❑ 2 -Stroke ✓❑ 4 -Stroke Combustion: 0 Lean Burn ❑ Rich Burn
Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged
Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes , ❑ No
If yes, what type of AFRC is in use? ✓❑ 0Z Sensor (mV) ❑NOx Sensor (ppm)
Is this engine equipped with a Low-NOx design? 0 Yes ❑ No
Engine Dates:
What is the manufactured date of this engine? 2017
What date was this engine ordered?
❑ Other:
What is the date this engine was first located to Colorado?
What is the date this engine was first placed in service/operation? 2018
What is the date this engine commenced construction?
What is the date this engine was last reconstructed or modified?
Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No
If yes, provide the make, model, and serial number of the old engine below:
Engine Make:
Engine Model: Serial Number:
6The serial number must be submitted if coverage under GP02 is requested.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
3
cotonnoo
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit if and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
Latitude 40.021383982/Longitude -104.893639901
Operator
P
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the Stack outlet: (check one)
0 Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
0 Circular
❑ Square/Rectangle
❑ Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
TBD
Interior stack diameter (inches): Interior stack depth (inches):
Section 6 - Fuel Data and Throughput Information
Fuel Use Rate @ 1OO% Load
(SCF/hour)
Actual Annual Fuel Use
(MMSCF/year)
Requested Annual Permit Limit
(MMSCF/year)
12,444.69
109.02
From what year is the actual annual amount?
Indicate the type of fuel used8:
❑ Pipeline Natural Gas
0 Field Natural Gas
❑ Propane
O Landfill Gas
❑ Other (describe):
(assumed fuel heating value of 1,020 BTU/scf)
Heating value: 1,130 BTU/scf
(assumed fuel heating value of 2,300 BTU/scf)
Heating Value:
BTU/scf
Heating Value (give units):
7 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
i iz[7Drr COLORADO
9
Permit Number:
AIRS ID Number:
/ I
[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, The APCD website has a
Natural Gas Fired Engines Calculator available to assist with emission calculations.
Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Primary Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
TSP (PM)
Kilo
PM2,5
SOx
NOx
NG/Diesel Conversion Catalyst
0
VOC
NG/Diesel Conversion Catalyst
80,0
CO
NG/Diesel Conversion Catalyst
94,5
Other: Formaldehyde NG/Diesel Conversion Catalyst
90.0
Use the following tables to report criteria and non -criteria pollutant emissions from source:
(Use the data reported in Section 6 to calculate these emissions.)
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions9
Requested Annual Permit
Emission Limit(s)7
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Tons/year)
Controlled
Emissions
(Tons/year)
Uncontrolled
Emissions
(Tons/year)
Controlled
Emissions
(Tons/year)
TSP (PM)
9.91E-03
Ib1MMBtu
AP -42
0.61
0.61
PM10
7.71E-05
lb/MMBlu -
AP -42
0.0048
0.0048
PM 2.5
7.71E-05
Ib/MMBIu
AP -42
0,0048
0.0048
SOX
5.88 5-04
ib/MMBtu
AP -42
0,04
0.04
NOx
0.5
g/bhp-hr
Mfg.
9,05
9.05
VOC
1.50
g/bhp-hr
Mfg.
27.16
5.43
CO
2.72
glbhp-hr
Mfg.
49.25
2.72
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source:
❑✓ Yes
❑ No
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions9
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Pounds/year)
Controlled Emissions
(Pounds/year)
Formaldehyde
50000
0.2
g/bhp-hr
Mfg.
7,242.2
724.2
Acetaldehyde
75070
0.00836
Ib/MMBIu
AP -42
1,029.8
1,029.8
Acrolein
107028
0.00514
Ib/MMBtu
AP -42
633.2
633.2
Benzene
71432
Other: Methanol
67561
0.0025
Ib/MMBtu
AP -42
307.97
307.97
7 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
5 V COLORADO
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit ii and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will
be operated in full compliance with each condition of general permit GP02.
//--/ -i7
Signature o/Legally Authorized Person (not a vendor or consultant) Date
Cory G. Jordan EVP Operations
Name (please 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 $152.90 and the General Permit For more information or assistance call:
registration fee of $1,500, if applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692.3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
COLORADO
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
fi
Reciprocating Internal Combustion
Engine APEN - Form APCD-201
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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression
ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for
your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, 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:
trote78-3-_. , T W E` I to 5
AIRS ID Number: 123
gF7/ OO(
9F4E / -8013-
[Leave blank unless APCD has already assigned a permit .r/ and AIRS ID)
Section 1 - Administrative Information
Company Name':
Site Name:
Site Location:
Discovery DJ Services LLC
Discovery West Brighton Compressor Station
Section 28, TIN, R67W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Portable Source
Home Base: N/A
Site Location
County: Weld
NAICS or SIC Code: 213112
Permit Contact:
Phone Number:
E -Mail Address2:
Manya Miller
(214) 414-1980
manya@discoverymidstream.com
1
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on alt documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
co�onnoo
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
371345
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit II and AIRS ID)
Section 2 - Requested Action
0 NEW permit OR newly -reported emission source (check one below)
❑ STATIONARY source ❑ PORTABLE source
❑✓ Request coverage under a Construction Permit
❑ Request coverage under General Permit GP023 (Natural Gas Only)
If General Permit coverage is requested, the General Permit registration fee of $1,500,00 must be submitted along
with the APEN Filing fee.
OR
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership" ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
APEN submittal for permit-exempt/grandfathered source
❑ Notification of Alternate Operating Scenario (AOS) permanent replacements
Additional Info & Notes:
3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. ,
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
5 This does not apply to General Permit GP02, as it does not contain a provision for A0S permanent replacements.
Section 3 - General Information
Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes
If yes, provide the Company Equipment Identification No. C-211
General description of equipment and purpose: Inlet gas compression
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
(http://www.colorado gov/cdphe/attainment)
Normal Hours of Source Operation: 24
Seasonal use percentage: Dec -Feb:
01/01/2018
❑✓ Yes ❑ No
hours/day 7 days/week 52 weeks/year
Mar -May: June -Aug: Sept -Nov:
Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017
2 IAVV COLORADO
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit // and AIRS ID]
Section 4 - Engine Information
Engine
Function:
❑ Primary and/or Peaking
❑ Pump ❑ Water Pump
❑ Emergency Back-up
❑ Other:
0 Compression
What is the maximum number of hours this engine will be used for emergency
back-up power? 0
Engine Make: Caterpillar Engine Model: 3606 A4 Serial Number':
hours/year
What is the maximum designed horsepower rating? 1875 hp What is the engine displacement?
What is the maximum manufacturer's site -rating? 1875 hp kW
What is the engine Brake Specific Fuel Consumption at 100% Load? 7500 BTU/hp-hr
l/cyl
Engine Features:
Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: 0 Lean Burn ❑ Rich Burn
Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged
Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes ❑ No
If yes, what type of AFRC is in use? 0 02 Sensor (mV) ❑NOx Sensor (ppm)
Is this engine equipped with a Low-NOx design? 0 Yes ❑ No
Engine Dates:
What is the manufactured date of this engine? 2017
What date was this engine ordered?
❑ Other:
What is the date this engine was first located to Colorado?
What is the date this engine was first placed in service/operation?
What is the date this engine commenced construction?
What is the date this engine was last reconstructed or modified?
2018
Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No
If yes, provide the make, model, and serial number of the old engine below:
Engine Make:
Engine Model: Serial Number:
6 The serial number must be submitted if coverage under GP02 is requested.
COLORADO
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 °'"
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)
Latitude 40.021283779/Longitude -104.893770229
Operator
p
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp,
('F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
indicate the direction of the Stack outlet: (check one)
El Upward
❑ Horizontal
❑ Downward
O Other (describe):
Indicate the stack opening and size: (check one)
0 Circular
❑ Square/Rectangle
❑ Other (describe):
interior stack diameter (inches):
❑ Upward with obstructing raincap
TBD
Interior stack diameter (inches): Interior stack depth (inches):
Section 6 - Fuel Data and Throughput Information
Fuel Use Rate @ 100% Load
(5CF/hour)
Actual Annual Fuel Use
(MMSCF/year)
Requested Annual Permit Limit
(MMSCF/year)
12,444.69
109.02
From what year is the actual annual amount?
Indicate the type of fuel used8:
❑ Pipeline Natural Gas
O Field Natural Gas
❑ Propane
O Landfill Gas
❑ Other (describe):
(assumed fuel heating value of 1,020 8TU/scf)
Heating value: 1,130 BTU/scf
(assumed fuel heating value of 2,300 BTU/scf)
Heating Value: BTU/scf
Heating Value (give units):
7 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth.
8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
Form APCD-201 - Reciprocating Internal Combustion Engine. APEN - Revision 1/2017
/\7 COLORADO
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit it and AIRS ID)
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a
Natural Gas Fired Engines Calculator available to assist with emission calculations.
Is any emission control equipment or practice used to reduce emissions? O Yes ❑ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Primary Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
TSP (PM)
PM10
PM2.5
SOX
NOX
nG/Diesel Conversion Catalyst
0
VOC
NG/Diesel Conversion Catalyst
80,0
CO
NG/Diesel Conversion Catalyst
94.5
Other: Formaldehyde NG/Diesel Conversion Catalyst
90,0
Use the following tables to report criteria and non -criteria pollutant emissions from source:
(Use the data reported in Section 6 to calculate these emissions.)
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions9
Requested Annual Permit
Emission Limit(s)7
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg, etc)
Uncontrolled
Emissions
(Tons/year)
Controlled
Emissions
(Tons/year)
Uncontrolled
Emissions
(Tons/year)
,Controlled
' Emissions
(Tons/year)
TSP (PM)
9.91E-03
lb/MMBIu
AP -42
0.61
0.61
PM10
7.71E-05
Ib/MMBIu
AP -42
0.0048
0.0048
PM2.5
7.71E-05
Ib/MMBlu
AP -42
0,0048
0,0048
SOX
5.88 E-04
Ib/MMBIu
AP -42
0.04
0.04
NOx
0.5
g/bhp-hr
NSPS JJJJ
9.05
9.05
VOC
1.5
g/tahp-hr
NSPS JJJJ
27.2
5.43
CO
2.72
g/bhp-hr
NSPS JJJJ
49.2
2.72
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source:
Yes El No
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions9
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Pounds/year)
Controlled Emissions
(Pounds/year)
Formaldehyde
50000
0.2
gfbhp-hr
Mfg.
7,242.2
724.2
Acetaldehyde
75070
0.00836
Ib/MMBIu
AP -42
1,029.8
1,029.8
Acrolein
107028
0.00514
lb/MMBlu
AP -42
633.2
633.2
Benzene
71432
Other: Methanol
67561 _
0.0025
lb/MMBIu
AP -42
307.97
307.97
7 Requested values will become permit limitations. Requested limits) should consider future process growth.
9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
coLosAo0
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
1,
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit 11 and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will
be operated in full compliance with each condition of general permit GP02.
(/)1/V //-10-i7
Signature of‘ Legally 9 thorized Person (not a vendor or consultant) Date
Cory G. Jordan EVP Operations
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 $152.90 and the General Permit For more information or assistance call:
registration fee of $1,500, if applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692.3175 or (303) 692.3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
COLORADO
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
Reciprocating Internal Combustion
Engine APEN - Form APCD-201
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 reciprocating internal combustion engines (RICE). If your engine is a diesel compression
ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for
your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In
addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt 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/aped.
S CEPED;\
i mg 1 o 201,
ApCD <<
St alt nary' j
�� lirCe
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:
a3-- 11 vvE l I u)
.1Fll oa-7
AIRS ID Number: 123 / .9F4E / 009 -
[Leave blank unless APCD has already assigned a permit it and AIRS ID]
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery West Brighton Compressor Station
Site Location:
Site Location
Section 28, TIN, R67W County: Weld
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Portable Source
Home Base: N/A
NAICS or SIC Code: 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address2: manya@discoverymidstream.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 nvoices will be issued by APCD via e-mail to the address provided.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 'I /2017
1 IT
COLD 11 A 0 0
tttttt
371346
Permit Number: AIRS ID Number:
[Leave blank unless APCD has already assigned a permit !t and AIRS ID]
Section 2 - Requested Action
0 NEW permit OR newly -reported emission source (check one below)
❑ STATIONARY source ❑ PORTABLE source
❑ Request coverage under a Construction Permit
❑ Request coverage under General Permit GP02' (Natural Gas Only)
If General Permit coverage is requested, the General Permit registration fee of $1,500,00 must be submitted along
with the APEN Filing fee.
OR -
• MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
-OR -
❑ APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit-exempt/grandfathered source
❑ Notification of Alternate Operating Scenario (AOS) permanent replacements
Additional Info Et Notes:
3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary,
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements.
Section 3 - General Information
Does this engine have a Company Equipment Identification No, (e.g. ENG-1, Engine 3, etc)? Yes
If yes, provide the Company Equipment Identification No.
General description of equipment and purpose:
C-212
Inlet gas compression
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
(http://www.colorado.Rov/cdphe/attainment)
Normal Hours of Source Operation: 24
Seasonal use percentage: Dec -Feb:
01/01/2018
0 Yes ❑ No
hours/day 7 days/week 52 weeks/year
Mar -May: June -Aug: Sept -Nov:
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
COLORADO
2 \V/ ai
Permit Number: MRS ID Number: / /
[Leave blank omens APCD has already assigned a permit and AIRS ID]
Section 4 - Engine Information
Engine
Function:
❑ Primary and/or Peaking
❑ Pump ❑ Water Pump
❑ Emergency Back-up
❑ Other:
0 Compression
What is the maximum number of hours this engine will be used for emergency
back-up power? 0
Engine Make: Caterpillar Engine Model: 3606 A4 Serial Number6:
hours/year
What is the maximum designed horsepower rating? 1875 hp What is the engine displacement? l/cyl
What is the maximum manufacturer's site -rating? 1875 hp kW
What is the engine Brake Specific Fuel Consumption at 100% Load? 7500 BTU/hp-hr
Engine Features:
Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: O Lean Burn ❑ Rich Burn
Ignition Source: ❑✓ Spark ❑ Compression Aspiration; ❑ Natural 0 Turbocharged
Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No
If yes, what type of AFRC is in use? 0 Oz Sensor (mV) ❑NOx Sensor (ppm) ❑ Other:
Is this engine equipped with a Low-NOx design? 0 Yes ❑ No
Engine Dates:
What is the manufactured date of this engine? 2017
What date was this engine ordered?
What is the date this engine was first located to Colorado?
What is the date this engine was first placed in service/operation? 2018
What is the date this engine commenced construction?
What is the date this engine was last reconstructed or modified?
Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No
If yes, provide the make, model, and serial number of the old engine below:
Engine Make: Engine Model: Serial Number:
6 The serial number must be submitted if coverage under GP02 is requested.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
COLORADO
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)
Latitude 40.021161437/Longitude -104,893929390
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the Stack outlet: tcheck one)
0 Upward ❑ Downward
❑ Horizontal ❑ Other (describe):
Indicate the stack opening and size: (check one)
✓❑ Circular
❑ Square/Rectangle
❑ Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
TBD
Interior stack diameter (inches): Interior stack depth (inches):
Section 6 - Fuel Data and Throughput Information
Fuel Use Rate @ 100% Load
(SCF/hour)
Actual Annual Fuel Use
(MMSCF/year)
Requested Annual Permit Limit?
(MMSCFI year)
12,444.69
109.02
From what year is the actual annual amount?
Indicate the type of fuel used':
❑ Pipeline Natural Gas
El Field Natural Gas
❑ Propane
❑ Landfill Gas
❑ Other (describe):
(assumed fuel heating value of 1,020 BTU/scf)
Heating value: 1,130 BTU/scf
(assumed fuel heating value of 2,300 BTU/scf)
Heating Value:
BTU /scf
Heating Value (give units):
7 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
e If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
COLORADO
4 j
Permit Number:
AIRS ID Number:
/ /
[Leave blank unless APCD has already assigned a permit // and AIRS IDJ
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a
Natural Gas Fired Engines Calculator available to assist with emission calculations.
Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Primary Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
TSP (PM)
PM10
PM 2,5
SOX
NOX
NG/Diesel Conversion Catalyst
0
VOC
NG/Diesel Conversion Catalyst
80,0
CO
NG/Diesel Conversion Catalyst
94,5
Other: Formaldehyde NG/Diesel Conversion Catalyst
90.0
Use the following tables to report criteria and non -criteria pollutant emissions from source:
(Use the data reported in Section 6 to calculate these emissions.)
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions9
Requested Annual Permit
Emission Limit(s)7
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Tons/year)
Controlled
Emissions
(Tons/year)
Uncontrolled
Emissions
(Tons/year)
Controlled
Emissions
(Tons/year)
TSP (PM)
9.91E-03
Ib/MMBlu
AP -42
0.61
0.61
PM10
7.71E-05
lb/MMBtu
AP -42
0.0048
0.0048
PM2.5
7.71E-05
lb/MMBtu
AP -42
0.0048
0.0048
SOX
5.88 E-04
Ib/MMBlu
AP -42
0.04
0.04
NOX
0.5
g/bhp-hr
Mfg.
9.05
9,05
VOC
1.50
g/bhp-hr
Mfg.
27.2
5.43
CO
2.72
g/bhp-hr
Mtg.
49.2
2.72
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source:
❑✓ Yes ❑ No
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions9
Uncontrolled
Basis
UnitsControlled
Source
. (AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Pounds/year)
Emissions
(Pounds/year)
Formaldehyde
50000
0.2
g/bhp-hr
Mfg.
7.242.2
724.2
Acetaldehyde
75070
0.00836
Ib/MMBIu
AP -42
1,029.8
1,029.8
Acrolein
107028
0.00514
lb/MMBIu
AP -42
633.2
633,2
Benzene
71432
Other: Methanol
67561
0.0025
Ib/MMOlu
AP -42
307.97
307.97
7 Requested values will become permit limitations, Requested limit(s) should consider future process growth.
9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Jr
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 'I /20'17
COLORADO
5I ,,:,,... ...................
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit /1 and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will
be operated in full compliance with each condition of general permit GP02.
7 /HO -17
l A thorized Person (not a vendor
consultant) o �tegal y or nsu ltant) Date
Cory G. Jordan EVP Operations
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 $152.90 and the General Permit
registration fee of $1,500, if applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https://www.coloredo.gov/cdphe/apcd
COLORADO
Fomn APCD-201 • Reciprocating Internal Combustion Engine APEN - Revision 1/2017
Reciprocating Internal Combustion
Engine APEN - Form APCD-201
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged on additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression
ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for
your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, 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: ' E0783-- 1t VVC t 110 5
Ctrlook
AIRS ID Number: 123 / -9 4E / -et0
[Leave blank unless APCD has already assigned a permit /1 and AIRS ID]
Si:iilonaty
Section 1 - Administrative Information
Company Name': Discovery DJ Services LLC
Site Name: Discovery West Brighton Compressor Station
Site Location: Section 28, T1 N, R67W
Mailing Address:
(Include Zip Code) 7859 Walnut Hill Lane, Suite 335
Dallas, TX 75230
Portable Source
Home Base: N/A
Site Location
County: Weld
NAICS or SIC Code; 213112
Permit Contact: Manya Miller
Phone Number: (214) 414-1980
E -Mail Address': manya@discoverymidstream.com
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
COLORADO
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
371347
Permit Number:
AIRS ID Number: /
[Leave blank unless APCD has already assigned a permit // and AIRS ID]
Section 2 - Requested Action
[]r NEW permit OR newly -reported emission source (check one below)
El STATIONARY source ❑ PORTABLE source
❑� Request coverage under a Construction Permit
❑ Request coverage under General Permit GP023 (Natural Gas Only)
If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along
with the APEN Filing fee.
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 El Other (describe below)
-OR -
❑ APEN submittal for update only (Blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El APEN submittal for permit-exempt/grandfathered source
El Notification of Alternate Operating Scenario (AOS) permanent replacements
Additional Info Ft Notes:
3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements.
Section 3 - General Information
Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes
If yes, provide the Company Equipment Identification No. C-213
General description of equipment and purpose: Inlet gas compression
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
Will this equipment be operated in any NAAQS nonattainment area?
(http://www.colorado.gov/cdphe/attainment)
Normal Hours of Source Operation: 24
Seasonal use percentage: Dec -Feb:
01/01/2018
❑✓ Yes ❑ No
hours/day 7 days/week 52 weeks/year
Mar -May: June -Aug: Sept -Nov:
COLORADO
Form APCD-201 - Reciprocating Internal Combustion Engine APEN! - Revision 1/2017 2 I,
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assignecl.a permit ii and AIRS ID]
Section 4 - Engine Information
Engine ❑ Primary and/or Peaking O Emergency Back-up
Function: ❑ Pump ❑ Water Pump ❑ Other:
Compression
What is the maximum number of hours this engine will be used for emergency
back-up power? N/A
Engine Make: Caterpillar
Engine Model: G3516 J Serial Number6:
hours/year
What is the maximum designed horsepower rating? 1380 hp What is the engine displacement?
What is the maximum manufacturer's site -rating? 1.380 hp kW
What is the engine Brake Specific Fuel Consumption at 100% Load? 8,256 BTU/hp-hr
l/cyl
Engine Features:
Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: 0 Lean Burn ❑ Rich Burn
Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged
Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No
If yes, what type of AFRC is in use? ❑✓ 02 Sensor (mV) ❑NOX Sensor (ppm)
Is this engine equipped with a Low-NOX design? ❑ Yes ❑ No
Engine Dates:
What is the manufactured date of this engine? 2017
What date was this engine ordered?
❑ Other:
What is the date this engine was first located to Colorado?
What is the date this engine was first placed in service/operation? 2018
What is the date this engine commenced construction?
What is the date this engine was last reconstructed or modified?
Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No
If yes, provide the make, model, and serial number of the old engine below:
Engine Make:
Engine Model: Serial Number:
6 The serial number must be submitted if coverage under GP02 is requested.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
Permit Number:
AIRS ID Number:
[Leave blank unless APCD has already assigned a permit II and AIRS ID)
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
Latitude 40.021063415/Longitude -104.894056877
Operator
P
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
(•F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the Stack outlet: (check one)
El Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
0 Circular
❑ Square/Rectangle
❑ Other (describe):
❑ Upward with obstructing raincap
Interior stack diameter (inches):
Interior stack diameter (inches): Interior stack depth (inches):
Section 6 - Fuel Data and Throughput Information
Fuel Use Rate ® 100% Load
(SCF/hour)
Actual Annual Fuel Use
(MMSCF/year)
Requested Annual Permit Limit7
(MMSCF/year)
10,082.55
80.32
From what year is the actual annual amount?
Indicate the type of fuel usede:
❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf)
Field Natural Gas Heating value: 1,130 BTU/scf
❑ Propane (assumed fuel heating value of 2,300 BTU/scf)
❑ Landfill Gas Heating Value: BTU/scf
❑ Other (describe): Heating Value (give units):
7 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field.
Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017
4lik7
COLORADO
ri
ri
Permit Number:
AIRS iD Number:
/
[Leave blank unless APCD has already assigned a permit ii and AIRS ID)
Section 7 - Emissions Inventory Information
Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a
Natural Gas Fired Engines Calculator available to assist with emission calculations.
Is any emission control equipment or practice used to reduce emissions? ID Yes ❑ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Primary Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
TSP (PM)
PM10
PM 2.5
SOX
NOX
NG/Diesel Conversion Catalyst
0
VOC
NG/Diesel Conversion Catalyst
60.4
CO
NG/Diesel Conversion Catalyst
91.8
Other: Formaldehyde NG/Diesel Conversion Catalyst
91.9
Use the following tables to report criteria and non -criteria pollutant emissions from source:
(Use the data reported in Section 6 to calculate these emissions.)
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions9
Requested
Emission
Annual Permit
Limit(s)7
Controlled
Emissions
(Tons/year)
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Tons/year)
Controlled
Emissions
(Tons/year)
Uncontrolled
Emissions
(Tons/year)
TSP (PM)
9.91E-03
Ih/MM Btu
AP -42
0,49
0.49
PM10
7.71E-05
Ib/MMBIu
AP -42
0.0039
0.0039
PM 2.5
7.71E-05
lb/MMBIu
AP -42
0.0039
0.0039
SOX
5.88 E-04
Ib/MMBIu
AP -.12
0.03
0.03
NOX
0.5
g/bhp-hr
Mfg.
6.66
666
VOC
0.91
9/bhp-hr
Mfg.
12.13
4.80
CO -
2.43
g/bhp-hr
Mtg.
32.38
2.67
Does the emissions source have any uncontrolled actual emissions of non -criteria Yes ❑ No
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source:
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions9
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg. etc)
Uncontrolled
Emissions
(Pounds/year)
Controlled Emissions
(Pounds year)
Formaldehyde
50000
0.43
g/bhp-hr
mfg.
11.460
932.7
Acetaldehyde
75070
0.00836
Ib/MMBtu
AP -42
834.37
834.37
Acrolein
107028
0.00514
lb/MMBIu
AP -02
512.998
512.998
Benzene
71432
Other:
7 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 'I /2017
COLO Rh DO
Permit Number: AIRS ID Number: / /
[Leave blank unless APCD has already assigned a permit II and AIRS 101
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will
be operated in full compliance with each condition of general permit GP02.
Avr Qu r //-/O -17
Signature blf Legally Authorized Person (not a vendor or consultant) Date
•
Cory G. Jordan EVP Operations
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 $152.90 and the General Permit For more information or assistance call:
registration fee of $1,500, if applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
Make check payable to: https://www.colorado.gov/cdphe/apcd
Colorado Department of Public Health and Environment
Telephone: (303) 692-3150
Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017
6 I77 co�oenoo
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