HomeMy WebLinkAbout20171309.tiffCOLORADO
Department of Public
Health Er Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150O St
PO Box 758
Greeley, CO 80632
May 2, 2017
Dear Sir or Madam:
RECEIVED
MAY 0 8 2017
WELD COUNTY
COMMISSIONERS
On May 4, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for
Extraction Oil It Gas, Inc. - Winder Production Facility. 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 commeht 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 Ft 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.co(orado.gov/cdphe
John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
Pub1iC Rev
S/(5/I 7
cc•PLOY)(1- ITP), Hl.CPS),
RARER/CH/JP/1/0c)
5(G/!7
2017-1309
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Extraction Oil Et Gas, Inc. - Winder Production Facility - Weld County
Notice Period Begins: May 4, 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: Extraction Oil Et Gas, Inc.
Facility: Winder Production Facility
Well production facility
NENE of Section 9 of T6N R67W
Weld County
The proposed project or activity is as follows: This project involves expansion of an existing EEtP well
production facility to add twenty (20) more wells and associated production equipment (i.e., condensate
storage tanks, truck loadout, VRT and separator venting.) The facility is split into two co -located sets
(Winder North and Winder South) which do not share any equipment, but are both contained on this same
facility -wide permit. Project also includes one GP02 and two GP08 general permit registrations.
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 17WE0290 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:
Andy Gruel
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
cdphe.commentsapcd@state.co.us
1
COLORADO
Colorado Air Permitting Project
Project Details
Review Engineer:
Package #:
Received Date:
Review Start Date:
Section 01 - Facility Information
Andy Gruel
359843
3/21/2017
4/3/2017
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
Physical Address/Location:
Type of Facility:
What industry segment?
Extraction Oil & Gas, Inc =_
Weld
Quadrant
Section
Township
Range
NENE
9
6N
Winder Production Facility
NENE quadrant of Section 9, Township 6N, Range 67W, in Weld County, Colorado
Exploration & Production Well Pad
Oil & Natural Gas Production & Process'r
Is this facility located in a NAAQS non -attainment area? Yes
If yes, for what pollutant? ID Carbon Monoxide (CO) ❑ Particulate Matter (PM)
Section 02 - Emissions Units In Permit Application
D Ozone (NOx & VOC)
AIRS Point #
Emissions Source Type
Equipment
Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
001
Condensate Tank
yes"
17WE029C
1
Yes
hermit Initial
Issuance
002
Hydrocarbon liquid Loading
17WE029C
1
Yes
003
Produced Water Tank
winder Nortnwater
Yes
GP0$
N/A
No
pkg 357342
007
Produced Water Tank
wrndersouth Water
Tank,
s
GP0$ _
N/A
No
pkg 357342
4 008
Separator
17WE029C
1
Yes
009
Separator Venting
17 W E029C
1
Yes "
Permit Initial
010
Condensate Tank
27WE029C
1
Yes
011
Hydrocarbon Liquid Loading
17WE029C
1
Yes
i"stance
012
Separator Venting
17WE029C
1
Yes
013
Separator Venting
17 W E029C
1
Yes
014
Natural Gas RICE
GfN-oar
Yes ` GP02
N/A
[do
pkg 360050
Section 03 - Description of Project
Synthetic minor E&P site in non -attainment area. Facility previously operated since 2015 with four wells. <This application accommodates the addition of
twenty (20) more wells to this facility in 2017.
Facility is split into two co -located sets (Winder North and Winder South) which do not share any equipment, but are contained on this same facility -wide
permit Points 001, 002, 008, 009 are Winder North, and points 010, 011, 012, 013 are Winder South. Points 003 and 007 are new GP08 registrations for
produced water storage at Winder North and Winder South respectively. Point 014 is a new GP02 registration for a generator. Points 004, 005 and 006 (all
GP02 engines) were cancelled in October2016.
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why?
Yes
Requesting Synthetic Mino
Section 05 - Ambient Air Impact Analysis Requirements
Was a quantitative modeling analysis required? Na
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
No
Yes
NOx CO
❑ ❑
❑ ❑
VOC
2
U
PM2.5
O
PM10 TSP HAPs
❑ ❑ o
Condensate Storage Tank(s) Emissions Inventory
Section 01- Administrative Information
Facility AIRs ID:
I23 9CAA
County Plant
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Twelve (12) 400 -bbl fined-roofatnsosplteric canderrsate slarage vessels. "North`
Emission Control Device Enclosed combustor
Description:
Requested Overall VOC & HAP Control
Efficiency %:
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Condensate Throughput =
Requested Permit Limit Throughput =
Potential to Emit (PTE) Condensate
Throughput =
Secondary Emissions - Combustion Device(s)
Heat content of waste gas =
Volume of waste gas emitted per BBL of liquid
produced = 2470', scf/bbl
Actual heat content of waste gas routed to combustion device =
Request heat content of waste gas routed to combustion device =
1,516,788!. Barrels (hbl) per year
1,820,145 Barrels (bbl) per year
145.. Barrels (bbl) per year
254239 Btu/scf
Actual Condensate Throughput While Emissions Controls Operating = 1,516,788": Barrels (bbl) per year
from ProMax
from ProMax
9,524 MMBTU per year
11,428 MMBTU per year'
Potential to Emit (PTE) heat content of waste gas routed to combustion device = 11,428 MMBTU per year
Section 04- Emissions factors & Methodologies
Will this storage tank emit flash emissions?
Pollutant
Pollutant
Uncontrolled
Controlled
(lb/bbl)
(lb/bbl)
(Condensate
Throughput)
0;234?...........
0.00034
0.000068
(Condensate
Throughput)
Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu)
(waste heat
combusted)
(Ib/bbl)
0.310':''.
(Condensate
Throughput)
0.0000
0.0000
0.0004
0.0019
Emission Factor Source
Emission Factor Source
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(ions/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
VOC
PM10
PM2.5
NOx
CO
213.6
178.0
8.9
213.63
10.68
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.4
0.32
0.32
0.39
0.39
1.8
1.48
1.48
1.77
1.77
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(Ibs/yearl (lbs/year(
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
0.3075
0.2563
0.0128
0.3075
0.0154
615.0270
30.7513
0.2281
0.1901
0.0095
0.2281
0.0114
456.1283
22.8064
0.0158
0.0132
0.0007
0.0158
0.0008
31.5795
1.5790
0.0614
0.0512
0.0026
0.0614
0.0031
122.8598
6.1430
2.4742
2.0618
0.1031
2.4742
0.1237
4948.4271
247.4214
0.2817
0.2347
0.0117
0.2817
0.0141
563.3349
28.1667
2 of 17
K:\PA\2017\17W E0290.CP1.xlsm
Condensate Storage Tank(s) Emissions Inventory
Section 06- Regulatory Summ
Regulation 3, Parts A, B
APEN and Permit required
Regulation 7, Section XII.C, D, E, F
Storage tank is subject to Regulation 7, Section XII.C-F, as provided
Regulation 7, Section XII.G, C
Storage Tank is not subject to Regulation 7, Section XII.0
Regulation 7, Section XVII.B, C.1, C.3
Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3, a
Regulation 7, Section XVII.C.2
Storage tank is subject to Regulation 7, Section XVII.C.2, as provide
Regulation 6, Part A, NSPS Subpart Kb
Storage Tank is not subject to NSPS Kb
Regulation 6, Part A, NSPS Subpart 0000
Storage Tank is not subject to NSPS 0000
Regulation 8, Part E, MACT Subpart HH
Storage Tank is not subject to MACT HH
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Sampling and Testing Reauirements
Does the company use the state default emissions factors to estimate emissions? ,.
If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the
facility being permitted? This sample should be considered representative which generally means site -specific and
collected within one year of the application received date. However, if the facility has not been modified (e.g., no
new wells brought on-line), then it may be appropriate to use an older site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section OS - Technical Analysis Notes
Applicant used ProMax to model flash, working and breathing emissions, using a model condensatethroughput-of 3955 bbl/d and based on a site-specific(Winder 9-41 existing well) pressurized liquid
sample. ProMax modeled mass flow from flash/working/breathing in terms of Ib/b; this mass flow was divided by the modeled throughput to arrive at VOC and HAP. emission factors listed above, which
match the APEN. However;: this sample was collected over 12 months prior to the application received date, and is from an existing well. The permit will require an "initial compliancetesting
requirementto develop a SSEF from one of the new wells, based on guidelines in PS Memo 05-01.
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point # Process # SCC Code
001 01
Uncontrolled
Emissions
Pollutant Factor Control % Units
NOx 0.0102 0 lb/1,000 gallons condensate throughput
VOC 5.5890 95 lb/1,000 gallons condensate throughput
CO 0.0463 0 lb/1,000 gallons condensate throughput
Benzene 0.0080 95 lb/1,000 gallons condensate throughput
Toluene 0.0060 95 lb/1,000 gallons condensate throughput
Ethylbenzene 0.0004 95 lb/1,000 gallons condensate throughput
Xylene 0.0016 95 lb/1,000 gallons condensate throughput
n -Hexane 0.0647 95 lb/1,000 gallons condensate throughput
224 TMP 0.0074 95 lb/1,000 gallons condensate throughput
3 of 17 K:\PA\2017\17WE0290.CP1.xlsm
002 Hydrocarbon Loadout to Tanker Trucks when Liquids Pipeline is Unavailable
123-9CAA-002 17WE0290 CP1 Revised APEN rec'd 4/6/17 Winder NORTH
Emission Factors
Applicant requested to use state default emission factors for VOC, benzene, and n -hexane.
VOC
Benzene
n -Hexane
0.236 lb/bbl
0.000416 lb/bbl
0.00361 lb/bbl
Annual requested Throughput
Annual requested VOC emissions
Annual requested Benzene emissions
Annual requested n -hexane emissions
Control:
Efficiency:
Dedicated Flare
95.00%
151150 BBL/yr
6348300 gal/yr
35671 lb/yr
17.84 tpy VOC uncontrolled
62.88 lb/yr uncontrolled
545.65 lb/yr uncontrolled
Pollutant
Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
NOx
0.000685
0.003121
lb/bbl
0.05 tpy
AP -42
CO
lb/bbl
0.24 tpy
AP -42 4
VOC
2.3600E-01
lb/bbl
17.84 tpy
0.89 tpy
CDPHE
Default
Benzene
4.1600E-04
lb/bbl
63 lb/yr
3 lb/yr
n -Hexane
3.6100E-03
lb/bbl
546 lb/yr
27 lb/yr
123-9CAA-002 17WE0290
Regulatory Review
Regulation 1 - Particulate, Smoke; Carbon, Monoxide and Sulfur Dioxide
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the
emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive
opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions
measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this
regulation.
Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or
other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is
in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes.
Regulation 2 — Odor
Section I.A - 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.
Regulation 3 - APEN and Permitting Requirements
Is this site considered an exploration and production location (e.g. well pad)?
If yes, review the following two exemptions for applicability:
Does the operator unload less than 10,000 gallons (238 BBLs) per day of crude oil on an annual average basis?
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1
Does this operator unload less than 6,750 bbls per year of condensate via splash fill or
16,308 bbls per year of condensate via submerged fill procedure?
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1
Yes
No
No
Part A-APEN Requirements
Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a
non -attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant
(pollutants are not summed) for which the area is non -attainment.
(Applicant is required to file an APEN since emissions exceed 1 ton per year VOC)
Part B — Construction Permit Exemptions
Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY
threshold (Reg. 3, Part B, Section II.D.2.a).
Part B, III.D.2 - RACT requirements for new or modified minor sources
This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or
attainment/maintenance areas. This source is located in the 8 -hour ozone nonattainment area, but not the 1 -hour ozone area.
The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8 -
hour ozone NA area designation). Since the tank battery from which loadout is occurring came into service after the date
above (Reported as 07/02/14 on condensate tank APEN), this source is considered "new or modified." Operator is using
submerged fill (0.6 saturation factor) and a dedicated flare, therefore, RACT requirements are satisfied.
Regulation 7 —Volatile Organic Compounds
No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility
that has a daily average throughput of more than 76,000 liters of gasoline (20,000 gallons), which is loaded directly into
transport vehicles.
This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C.
Regulation 8 - Hazardous Air Pollutants
MACT EEEE:
Not subject because facility is classified as a synthetic minor source of HAPs
It should also be noted that the loadout operation is located at a production field facility and thus would be exempt per 40CFR
63.2334(c)(1).
Truck loadout only occurs when liquids pipeline is not available. Liquids pipeline was connected in April 2017 and is
operational going forward. This loadout throughput accounts for roughly 5% downtime of the liquids pipeline.
The applicant states that the loadout point is controlled by a dedicated flare, which only controls vapors from the
loadout and water tanks. This control is granted 95% control efficiency.
The NOx and CO emissions associated with the loadout operation were determined using emission factors from AP -42
Chapter 13.5. The emission factors are 0.068 and 0.31 for NOx and CO respectively. Using these emission factors along
with ProMax modeled vapor energy content throughput of 1.6591 MMBtu/hr (BASED ON MODEL THROUGHPUT OF
1443575 BBL/YR.) Calculating a lb/bbl NOx and CO emission factor as follows:
NOx: 1.6591 MMBtu/hr * 8760 hr * (0.068 lb/MMBtu) / 1443575 bbl/yr = 0.000684615 lb/bbl
CO: 1.6591 MMBtu/hr * 8760 hr * (0.31 lb/MMBtu) / 1443575 bbl/yr = 0.003121 lb/bbl
These emission factors were multiplied by the requested permit throughput to arrive at the emission limits listed above.
SCC CODING
Pollutant
Uncontrolled Emissions Factor
(lb/1,000 gallons)
Control Efficiency
NOx
CO
VOC
Benzene
n -hexane
0.0163
0.0743
5.6190
0.0099
0.0860
lb/1,000 gallons
lb/1,000 gallons
lb/1,000 gallons
lb/1,000 gallons
lb/1,000 gallons
40600132: Crude Oil: Submerged Loading (Normal Service) Use if S = 0.6
123-9CAA-002 17W E0290
0
0
95%
95%
95%
Venting from Winder North Vapor Recovery Tower wh
008 controlled by EC[) with 95% control efficiency.
123-9CAA-008 17WE0290 CP1 APEN rec'd 3/21/17
Equipment Description
This source vents natural gas from:
Emissions from this source are:
vapor recovery tower
routed to a flare
Natural gas venting from vapor recovery tower. Emissions from this source are routed to a flare.
Calculations
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/Ib-mol) at 60F and 1 atm
Throughput (Q)
MW
3.67
MMscf/yr
Ib/Ib-mol
418.9497717
0.010054795
scf/hr
46.84
MMscf/d
mole % MW Ibx/Ibmol mass fraction
lb/hr
lb/ r
t.
Helium 0.00000
0.00
0.00
0.00
C02 0.00600326
0.31
2720.02
1.36
N2 0.00114259
0.06
517.70
0.26
methane 0.0125392
0.65
5681.40
2.84
ethane 0.136795
7.08
61980.61
30.99
propane 0.370638
19.17
167932.81
83.97
isobutane 0.075967
3.93
34419.84
17.21
n -butane 0.240774
12.45
109092.58
54.55
isopentane 0.047079
2.44
21330.99
10.67
n -pentane 0.050158
2.59
22725.97
11.36
cyclopentane 0.000000
0.00
0.00
0.00
n -Hexane 0.013148
0.68
5957.42
2.98
cyclohexane 0.014794
0.77
6702.99
3.35
Other hexanes 0.005392
0.28
2443.15
1.22
heptanes 0.012163
0.63
5510.90
2.76
methylcyclohexane 0.000000
0.00
0.00
0.00
224-TMP 0.001644
0.09
744.81
0.37
Benzene 0.002438
0.13
1104.69
0.55
Toluene 0.001983
0.10
898.43
O.45
Ethylbenzene 0.000144
0.01
65.47
0.03
Xylenes 0.000540
0.03
244.85
0.12
C8+ Heavies 0.006658
VOC mass fraction: 0.8435
0.34
Total VOC
3016.67
(Uncontrolled)
1.51
191.10
Notes
Mass fraction of vapors are modeled by ProMax and based on a pressurized liquids analysis from the facility collected 2/25/16.
The permit will require site -specific gas sampling to develop a site -specific emission factor based on actual gas.
Emissions are based on 8760 hours of operation per year.
Flaring Information
Equipment Description
Flare to combust vapor recovery tower gas when sales line is not available.
Manufacturer
TBD
Model
TBD
Serial Number
TBD
Gas Heating Value
2639.77
Btu/scf
Throughput
9687.9559
MMBtu/yr
Overall Control
95.00%
Combustion emission factor source:
AP -42: Chapter 13.5
0.07 I lb NOX/MMBtu
0.31 IlbCO/MMBtu
17WE0290.CP1.xlsm
Venting from Winder North Vapor Recovery Tower when unable to compress to sales line. Vapors
008 controlled by',EGO' with 95% control efficiency.
123-9CAA-008 17WE0290 CP1 APEN recd 3/21/17
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
104139
lb/MMscf
5206.97 lb/MMscf
191.10 tpy
9.55 tpy
Gas Analysis
Nox
0.07
Ib/MMBTU
0.07 Ib/MMBTU
0.33 tpy
0.33 tpy
AP -42
CO
0.31
Ib/MMBTU
0.31 lb/MMBTU
1.50 tpy
1.50 tpy
AP -42
Benzene
301.01
lb/MMscf
15.05 lb/MMscf
1104.69 lb/yr
55.23 lb/yr
Gas Analysis
Toluene
244.803
lb/MMscf
12.2401 lb/MMscf
898.43 lb/yr
44.92 lb/yr
Gas Analysis
Ethylbenzene
17.838
lb/MMscf
0.8919 lb/MMscf
65.47 lb/yr
3.27 lb/yr
Gas Analysis
Xylenes
66.716
lb/MMscf
3.3358 lb/MMscf
244.85 lb/yr
12.24 lb/yr
Gas Analysis
n -Hexane
1623.28
lb/MMscf
81.1638 lb/MMscf
5957.42 lb/yr
297.87 lb/yr
Gas Analysis
2,2,4-TMP
202.945
lb/MMscf
10.1473 lb/MMscf
744.81 lb/yr
37.24 lb/yr
Gas Analysis
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 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
Yes See additional notes section below for further discussion.
This separator is subject to Reg 7, Section XVII.G. and control requirements of l 'eg 7, Section XVII.B.2
Additional Notes:
Several new wells are anticipated to come on-line at this facility in 2017. The separators at thsi facility are subject to R7.XVII.B.2.
The applicant provided details on the O&M plan that describe flow meters to monitor and record volumetric flowrates.
SCC CODING
SCC Code:
31000205
Emission Factors for Permit:
Uncontrolled (lb/MMscf vented)
179.50
NOx
CO
VOC
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane 1623.28
2,2,4-TMP
Controlled (Ib/MMscf vented) Control Eff.
179.50 0%
818.33 818.33 0%
104139.39
5206.97 95%
301.01 15.05 95%
244.80 12.24 95%
17.84 0.89 95%
66.72 3.34 95%
81.16 95%
202.95 10.15 95%
17WE0290.CP1.xlsm
venting from Winder NorihHigh/Low Pressure Separators when u
009 are controlled by ECD with 95%control of ciency.
123-9CAA-009 17WE0290 CP1 APEN rec'd 3/21/17
Equipment Description
This source vents natural gas from:
Emissions from this source are:
vapor recovery tower
routed to a flare
Natural gas venting from vapor recovery tower. Emissions from this source are routed to a flare.
Calculations
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 (Q)
MW
3.67
37.394
MMscf/yr
Ib/Ib-mol
418.9497717
0.010054795
scf/hr
MMscf/d
mole % 16� Ibx/Ibmol
mass fraction
lb/hr
lb r
Helium
0.00000
0.00
0.00
0.00
CO2
0.01746980
0.72
6319.15
3.16
N2
0.01830380
0.76
6620.82
3.31
methane
0.0842677
3.48
30481.18
15.24
ethane
0/243955
10.07
88243.02
44.12
•ro•ane
0.332641
13.74
120322.39
60.16
isobutane
0.051909
2.14
18776.55
9.39
n -butane
0.155382
6.42
56204.54
28.10
iso.entane
0.028366
1.17
10260.51
5.13
n-•entane
0.030190
1.25
10920.17
5.46
c clo•entane
0.008984
0.37
3249.53
1.62
n -Hexane
0.008147
0.34
2946.85
1.47
c clohexane
0.003273
0.14
1183.96
0.59
Other hexanes
0.000000
0.00
0.00
0.00
he•tanes
0.008020
0.33
2901.11
1.45
meth lc clohexane
0.000000
0.00
0.00
0.00
224-TMP
0.001071
0.04
387.22
0.19
Benzene
0.001481
0.06
535.57
0.27
Toluene
0.001280
0.05
463.17
0.23
Eth (benzene
0.000100
0.00
0.02
X lenes
0.000377
0.02
136.23
0.07
C8+ Heavies
0.004784
0.20
1730.53
0.87
VOC mass fraction:
0.6360 Total VOC (Uncontrolled)( 115.03
Notes
Mass fraction of vapors are modeled by ProMax and based on a pressurized liquids analysis from the facility collected 2/25/16.
The permit will require site -specific gas sampling to develop a site -specific emission factor based on actual gas.
Emissions are based on 8760 hours of operation per year.
Flaring Information
Equipment Descripton
Flare to combust separator as when sales line is not available.
Manufacturer
TBD
Model
TBD
Serial Number
TBD
Gas Heating Value
2077.75
Btu/scf
Throughput
7625.3425
MMBtu/yr
Overall Control
95.00%
Combustion emission factor source:
0.07 alb NOX/MMBtu
AP -42: Chapter 13.5
0.31 IIb CO/MMBtu
17WE0290.CP1.xIsm
Venting from Winder North High/Low Pressure Separators when unable to compress to sales line. Vapors
009 are controlled by ECO with 95% control efficiency.
123-9CAA-009 17WE0290 CP1 APEN rec'd 3/21/17
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
V0C
62685
lb/MMscf
3134.26 lb/MMscf
115.03 tpy
5.75 tpy
Gas Analysis
N0x
0.07
lb/MMBTU
0.07 lb/MMBTU
0.26 tpy
0.26 tpy
AP -42
CO
0.31
lb/MMBTU
0.31 Ib/MMBTU
1.18 tpy
1.18 tpy
AP -42
Benzene
145.93
lb/MMscf
7.30 lb/MMscf
535.57 lb/yr
26.78 lb/yr
Gas Analysis
Toluene
126.205
lb/MMscf
6.3103 lb/MMscf
463.17 lb/yr
23.16 lb/yr
Gas Analysis
Ethylbenzene
9.872
lb/MMscf
0.4936 lb/MMscf
36.23 lb/yr
1.81 lb/yr
Gas Analysis
Xylenes
37.120
lb/MMscf
1.8560 Ib/MMscf
136.23 lb/yr
6.81 lb/yr
Gas Analysis
n -Hexane
802.96
lb/MMscf
40.1478 Ib/MMscf
2946.85 lb/yr
147.34 lb/yr
Gas Analysis
2,2,4-TMP
105.509
lb/MMscf
5.2755 lb/MMscf
387.22 lb/yr
19.36 lb/yr
Gas Analysis
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 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
Yes See additional notes section below for further discussion.
This separator is subject to Reg 7, Section XVII.G. Aid control requirements of Reg 7, Section XVII.B.2
Additional Notes:
Several new wells are anticipated to come on-line at this facility in 2017. The separators at thsi facility are subject to R7.XVI1.B.2.
The applicant provided details on the O&M plan that describe flow meters to monitor and record volumetric flowrates.
SCC CODING
SCC Code:
31000205
Emission Factors for Permit:
Uncontrolled (Ib/MMscf vented)
NOx 141.29
CO 644.10
VOC 62685.16
Benzene 145.93
Toluene 126.21
Ethylbenzene 9.87
Xylenes _..._......_..._..._.. 37.12
n -Hexane 802.96
2,2,4-TMP 105.51
Controlled (lb/MMscf vented) Control Eff.
141.29 0%
644.10 0%
3134.26 95%
7.30 95%
6.31 95%
0.49 95%
1.86_......_..........._..._..._......_..._..._.__..._....._95%
40.15 95%
5.28 95%
17WE0290.CP1.xlsm
Condensate Storage Tank(s) Emissions Inventory
Section 01- Administrative Information
Facility AIRs ID:
123 '.. 9[AA
County Plant
0'
Point
Section 02- Equipment Description Details
Detailed Emissions Unit
Description:
Twelve (12) 400 -bbl fixed -roof atmospheric condensate storage vessels. "Sau t,
Emission Control Device Enclosed combustor
Description:
Requested Overall VOC & HAP Control
Efficiency %.
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Condensate Throughput =
Requested Permit Umit Throughput =
Potential to Emit (PTE) Condensate
Throughput =
Secondary Emissions - Combustion Device(s)
Heat content of waste gas=
Volume of waste gas emitted per BBL of liquids
produced = 2.0058 scf/bbl
Actual heat content of waste gas routed to combustion device =
Request heat content of waste gas routed to combustion device =
.1,890,315'.. Barrels (bbl) per year
2,268,378 Barrels (bbl) per year
2,268, Barrels (bbl) per year
2.7 Btu/scf
Actual Condensate Throughput While Emissions Controls Operating = 1,890,313 Barrels (bbl) per year
from ProMax
from ProMax
9,679 MMBTU per year
11,615 MMBTU per year
Potential to Emit (PTE) heat content of waste gas routed to combustion device = 11,615 MMBTU per year
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Pollutant
Uncontrolled
Controlled
(Ib/bbl)
(Ib/bbl)
(Condensate
Throughput)
...._...0:1917.....'
0.00029
MIIIMIZEME
Pollutant
0♦00001
0.000057........
O.0022___..
0.00025
(Condensate
Throughput)
0.0096
0.000014
0.000011
0.000001
0.000003
0.000112
0.00001.3
Control Device
Uncontrolled Uncontrolled
(Ib/MMBtu)
(waste heat
combusted)
(lb/bbl)
(Condensate
Throughput)
...:;'0.068.......
0.0000
0.0000
0.0003
0.0016
Emission Factor Source
Emission Factor Source
section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
VOC
PM10
PM2.5
NOx
CO
217.5
181.2
9.1
217.5
10.87
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.4
0.33
0.33
0.39
0.39
1.8
1.50
1.50
1.80
1.80
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
0.3268
0.2723
0.0136
0.3268
0.0163
654
33
0.2422
0.2019
0.0101
0.2422
0.0121
484
24
0.0167
0.0139
0.0007
0.0167
0.0008
33
2
0.0646
0.0539
0.0027
0.0646
0.0032
129
6
2.5306
2.1088
0.1054
2.5306
0.1265
5061
253
0.2885
0.2404
0.0120
0.2885
0.0144
577
29
10 of 17
K:\PA\2017\17W E0290.CP1.xlsm
Condensate Storage Tank(s) Emissions Inventory
Section 06- Regulatory Summary Analysis
Regulation 3, Parts A, B
APEN and Permit required
Regulation 7, Section XII.C, D, E, F
Storage tank is subject to Regulation 7, Section XII.C-F, as provided
Regulation 7, Section XII.G, C
Storage Tank is not subject to Regulation 7, Section XII.G
Regulation 7, Section XVII.B, C.1, C.3
Storage tank is subject to Regulation 7, Section XVII, 6, C.1 & C.3, a
Regulation 7, Section XVII.C.2
Storage tank is subject to Regulation 7, Section XVII.C.2, as provide
Regulation 6, Part A, NSPS Subpart Kb
Storage Tank is not subject to NSPS Kb
Regulation 6, Part A, NSPS Subpart OOOO
Storage Tank is not subject to NSPS OOOO
Regulation 8, Part E, MACT Subpart HH
Storage Tank is not subject to MAR HH
(See regulatory applicability worksheet for detailed analysis)
Section 07 - Initial and Periodic Sampling and Testing Requirements
Does the company use the state default emissions factors to estimate emissions? FIp„ r
If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year?
If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01.
Does the company use a site specific emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the
facility being permitted? This sample should be considered representative which generally means site -specific and
collected within one year of the application received date. However, if the facility has not been modified (e.g., no
new wells brought on-line), then it may be appropriate to use an older site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section OS - Technical Analysis Notes
Applicant used ProMax to model flash, working and breathing emissions, using a model condensate throughput of 6214.2 bbl/d and basedon a site-specdi (Winder 9-41 existing well) pressurized liquid
sample. Winder 9-41 welt is at the facibtybut servesthe'"North" tankbattery, but since it's the same facility it is acceptable as a preliminary data source. However, this sample wascollected over 12
months priortothe application received date, and is from an existing well. The permit will require art "Initial compliance" testing requirement to develop. a SSEF fromone of the new wells, based on
guidelines in PS Memo 05-01. ProMax modeled mass flow -from flash/working/breathing in terms of lb/h; this mass flow was divided by the modeled throughput to arrive at VOC and HAP emission
factors listed above,which match the APEN.
Section 09 - Inventory 5CC Coding and Emissions Factors
AIRS Point it
Process tt 5CC Code
010 01 d-64-06
Uncontrolled
Emissions
Pollutant Factor Control % Units
NOx 0.0083 0 lb/1,000 gallons condensate throughput
VOC 4.5651 95 lb/1,000 gallons condensate throughput
CO 0.0378 0 lb/1,000 gallons condensate throughput
Benzene 0.0069 95 lb/1,000 gallons condensate throughput
Toluene 0.0051 95 lb/1,000 gallons condensate throughput
Ethylbenzene 0.0004 95 lb/1,000 gallons condensate throughput
Xylene 0.0014 95 lb/1,000 gallons condensate throughput
n -Hexane 0.0531 95 lb/1,000 gallons condensate throughput
224 TMP 0.0061 95 lb/1,000 gallons condensate throughput
11 of 17 K:\PA\2017\ 17WE0290.CP1.xlsm
011 Hydrocarbon Loadout to Tanker Trucks when Liquids Pipeline is Unavailable
123-9CAA-011 17WE0290 CP1 Revised APEN rec'd 4/6/17 Winder SOUTH
Emission Factors
Applicant requested to use state default emission factors for VOC, benzene, and n -hexane.
VOC
Benzene
n -Hexane
0.236 lb/bbl
0.000416 lb/bbl
0.00361 lb/bbl
Annual requested Throughput
Annual requested VOC emissions
Annual requested Benzene emissions
Annual requested n -hexane emissions
Control:
Efficiency:
Dedicated Flare
Emissions Summary Table
95.00%
113419 BBL/yr
4763598 gal/yr
26767 lb/yr
13.4 tpy VOC uncontrolled
47.2 lb/yr uncontrolled
409.4 lb/yr uncontrolled
Pollutant
Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
NOx
0.000689
0.003143
lb/bbl
0.04 tpy
AP -42
CO k
lb/bbl
0.18 tpy
AP -42
VOC
2.3600E-01
lb/bbl
13.38 tpy
0.67 tpy
CDPHE
default
Benzene
4.1600E-04
lb/bbl
47 lb/yr
2 lb/yr
n -Hexane
3.6100E-03
lb/bbl
409 lb/yr
20 lb/yr
123-9CAA-011 17WE0290
Regulatory Review
Regulation 1 -Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause
the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24
consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible
emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B
of this regulation.
Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or
other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is
in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes.
Regulation 2 —Odor
Section I.A - 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.
Regulation 3 - APEN and Permitting Requirements
Is this site considered an exploration and production location (e.g. well pad)?
If yes, review the following two exemptions for applicability:
Does the operator unload less than 10,000 gallons (238 BBLs) per day of crude oil on an annual average basis?
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.I
Does this operator unload less than 6,750 bbls per year of condensate via splash fill or
16,308 bbls per year of condensate via submerged fill procedure? No
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.I •
Yes
No
Part A-APEN Requirements
Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a
non -attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant
(pollutants are not summed) for which the area is non -attainment.
(Applicant is required to file an APEN since emissions exceed 1 ton per year VOC)
Part B — Construction Permit Exemptions
Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY
threshold (Reg. 3, Part B, Section II.D.2.a).
Part B, III.D.2 - RACT requirements for new or modified minor sources
This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or
attainment/maintenance areas. This source is located in the 8 -hour ozone nonattainment area, but not the 1 -hour ozone area.
The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8 -
hour ozone NA area designation). Since the tank battery from which loadout is occurring came into service after the date
above (Reported as 07/02/14 on condensate tank APEN), this source is considered "new or modified." Operator is using
submerged fill (0.6 saturation factor) and a dedicated flare, therefore, RACT requirements are satisfied.
Regulation 7 — Volatile Organic Compounds
No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility
that has a daily average throughput of more than 76,000 liters of gasoline (20,000 gallons), which is loaded directly into
transport vehicles.
This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C.
Regulation8 — Hazardous Air Pollutants
MACT EEEE:
Not subject because facility is classified as a synthetic minor source of HAPs
It should also be noted that the loadout operation is located at a production field facility and thus would be exempt per 40CFR
63.2334(c)(1).
Truck loadout only occurs when liquids pipeline is not available. Liquids pipeline was connected in April 2017 and is
operational going forward. This loadout throughput accounts for roughly 5% downtime of the liquids pipeline.
The applicant states that the loadout point is controlled by a dedicated flare, which only controls vapors from the
loadout and water tanks. This control is granted 95% control efficiency.
The NOx and CO emissions associated with the loadout operation were determined using emission factors from AP -42
Chapter 13.5. The emission factors are 0.068 and 0.31 for NOx and CO respectively. Using these emission factors along
with ProMax modeled vapor energy content throughput of 2.616 MMBtu/hr (BASED ON MODEL THROUGHPUT OF
2260445 BBL/YR.) Calculating a lb/bbl NOx and CO emission factor as follows:
NOx: 2.616 MMBtu/hr * 8760 hr * (0.068 lb/MMBtu) / 2260445 bbl/yr = 0.000689377 lb/bbl
CO: 2.616 MMBtu/hr * 8760 hr * (0.31 lb/MMBtu) / 2260445 bbl/yr = 0.00314275 lb/bbl
These emission factors were multiplied by the requested permit throughput to arrive at the emission limits listed above.
SCC CODING
Uncontrolled Emissions Factor
Pollutant (lb/1,000 gallons)
NOx
CO
VOC
Benzene
n -hexane
Control Efficiency
0.0164
0.0748
5.6190
0.0099
0.0860
lb/1,000 gallons
lb/1,000 gallons
lb/1,000 gallons
lb/1,000 gallons
lb/1,000 gallons
40600132: Crude Oil: Submerged Loading (Normal Service) Use if S = 0.6
123-9CAA-011 17W E0290
0
0
95%
95%
95%
Venting; from Winder South Vapor Recovery Tower wh
012 controlled by ECO with 95% control efficiency.
123-9CAA-012 17WE0290 CP1 APEN rec'd 3/21/17
Equipment Description
This source vents natural gas from:
Emissions from this source are:
vapor recovery tower
routed to a flare
unable to compress to sales line. Vapor
Natural gas venting from vapor recovery tower. Emissions from this source are routed to a flare.
Calculations
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 (Q)
MW
4.25
46.84
MMscf/yr
lb/Ib-mol
485.1598174
0.011643836
scf/hr
MMscf/d
mole % MW Ibx/Ibmol mass fraction
lb/hr
lb/ r
t•
Helium 0.00000
0.00
0.00
0.00
CO2 0.00600326
0.36
3149.89
1.57
N2 0.00114259
0.07
599.51
0.30
methane
0.0125392
0.75
6579.28
3.29
ethane
0.136795
8.19
71775.91
35.89
propane
0.370638
22.20
194472.61
97.24
isobutane
0.075967
4.55
39859.49
19.93
n -butane
0.240774
14.42
126333.37
63.17
isopentane
0.047079
2.82
24702.10
12.35
n -pentane
0.050158
3.00
26317.54
13.16
cyclopentane
0.000000
0.00
0.00
0.00
n -Hexane
0.013148
0.79
6898.92
3.45
cyclohexane
0.014794
0.89
7762.31
3.88
Other hexanes
0.005392
0.32
2829.27
1.41
heptanes
0.012163
0.73
6381.84
3.19
methylcyclohexane
0.000000
0.00
0.00
0.00
224-TMP
0.001644
0.10
862.52
0.43
Benzene
0.002438
0.15
1279.27
0.64
Toluene
0.001983
0.12
1040.41
0.52
Ethylbenzene
0.000144
0.01
75.81
0.04
Xylenes
0.000540
0.03
283.54
0.14
C8+ Heavies
0.006658
0.8435
0.40
Total VOC
3493.42
(Uncontrolled)
1.75
221.30
VOC mass fraction:
Notes
Mass fraction of vapors are modeled by ProMax and based on a pressurized liquids analysis from the facility collected 2/25/16.
The permit will require site -specific gas sampling to develop a site -specific emission factor based on actual gas.
Emissions are based on 8760 hours of operation per year.
Flaring Information
Equipment Description
Flare to combust vapor recovery tower gas when sales line is not available.
Manufacturer
TBD
Model
TBD
Serial Number
TBD
Gas Heating Value
2639.77
Btu/scf
Throughput
11219.0225
MMBtu/yr
Overall Control
95.00%
Combustion emission factor source:
0.07 jib NOX/MMBtu
AP -42: Chapter 13.5
0.31 Ilb CO/MMBtu
17WE0290.CP1.xlsm
Venting from Winder South Vapor Recovery Tower when unable to compress to sales line. Vapors are
012 controlled by ECO with 95% control efficiency.
123-9CAA-012 17WE0290 CP1 APEN rec'd 3/21/17
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
V0C
104139
lb/MMscf
5206.97 Ib/MMscf
221.30 tpy
11.06 tpy
Gas Analysis
Nox
0.07
Ib/MMBTU
0.07 lb/MMBTU
0.38 tpy
0.38 tpy
AP -42
CO
0.31
Ib/MMBTU
0.31 Ib/MMBTU
1.74 tpy
1.74 tpy
AP -42
Benzene
301.01
lb/MMscf
15.05 lb/MMscf
1279.27 lb/yr
63.96 lb/yr
Gas Analysis
Toluene
244.803
lb/MMscf
12.2401 lb/MMscf
1040.41 lb/yr
52.02 lb/yr
Gas Analysis
Ethylbenzene
17.838
lb/MMscf
0.8919 lb/MMscf
75.81 lb/yr
3.79 lb/yr
Gas Analysis
Xylenes
66.716
lb/MMscf
3.3358 lb/MMscf
283.54 lb/yr
14.18 lb/yr
Gas Analysis
n -Hexane
1623.28
lb/MMscf
81.1638 lb/MMscf
6898.92 lb/yr
344.95 lb/yr
Gas Analysis
2,2,4-TMP
202.945
lb/MMscf
10.1473 lb/MMscf
862.52 lb/yr
43.13 lb/yr
Gas Analysis
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 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
Yes See additional notes section below for further discussion.
This separator is subject to Reg 7, Section XVII.G. and contro' requirements of Reg 7, Section XVII.B.2
Additional Notes:
Several new wells are anticipated to come on-line at this facility in 2017. The separators at thsi facility are subject to R7.XVII.B.2.
The applicant provided details on the O&M plan that describe flow meters to monitor and record volumetricflowrates.
SCC CODING
SCC Code:
31000205
Emission Factors for Permit:
Uncontrolled (lb/MMscf vented) Controlled (lb/MMscf vented) Control Eff.
179.50 179.50 0%
NOx
CO
VOC
Benzene
Toluene
Ethylbenzene
Xylenes 66.72
n -Hexane 1623.28
2,2,4-TMP 202.95
818.33 818.33 0%
104139.39 5206.97 95%
301.01 15.05 95%
244.80 12.24 95%
17.84 0.89 95%
3.34 95%
81.16 95%
10.15 95%
17WE0290.CP1.xlsm
01
Venting from Winder South High/Low Pressure Sel
are controlled by ECD with 95% control efficiency.
123-9CAA-013 17WE0290 CP1 APEN recd 3/21/17
Equipment Description
This source vents natural gas from:
Emissions from this source are:
vapor recovery tower
routed to a flare
when unable to compress to s+
Natural gas venting from vapor recovery tower. Emissions from this source are routed to a flare.
Calculations
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 (O)
MW
4.25
37.394
MMscf/yr
lb/lb-mol
485.1598174
0.011643836
scf/hr
MMscf/d
mole % MW Ibx/Ibmol
mass fraction
lb/hr
lb/ r
t.
Helium
0.00000
0.00
0.00
0.00
CO2
0.01746980
0.84
7317.82
3.66
N2
0.01830380
0.88
7667.16
3.83
methane
0.0842677
4.03
35298.37
17.65
ethane
0.243955
11.67
102188.79
51.09
propane
0.332641
15.91
139337.91
69.67
isobutane
0.051909
2.48
21743.96
10.87
n -butane
0.155382
7.43
65087.00
32.54
isopentane
0.028366
1.36
11882.06
5.94
n -pentane
0.030190
1.44
12645.98
6.32
cyclopentane
0.008984
0.43
3763.08
1.88
n -Hexane
0.008147
0.39
3412.56
1.71
cyclohexane
0.003273
0.16
1371.07
0.69
Other hexanes
0.000000
0.00
0.00
0.00
heptanes
0.008020
0.38
3359.60
1.68
methylcyclohexane
0.000000
0.00
0.00
0.00
224-TMP
0.001071
0.05
448.42
0.22
Benzene
0.001481
0.07
620.21
0.31
Toluene
0.001280
0.06
536.37
0.27
Ethylbenzene
0.000100
0.00
41.95
0.02
Xylenes
0.000377
0.02
157.76
0.08
C8+ Heavies
0.004784
0.23
2004.02
1.00
VOC mass fraction:
0.6360
Total VOC (Uncontrolled)
133.21
Notes
Mass fraction of vapors are modeled by ProMax and based on a pressurized liquids analysis from the facility collected 2/25/16.
The permit will require site -specific gas sampling to develop a site -specific emission factor based on actual gas.
Emissions are based on 8760 hours of operation per year.
Flaring Information
Equipment Description
Flare to combust separator gas when sales line is not available.
Manufacturer
TBD
Model
TBD
Serial Number
TBD
Gas Heating Value
2077.75
Btu/scf
Throughput
8830.4375
MMBtu/yr
Overall Control
95.00%
Combustion emission factor source:
AP -42: Chapter 13.5
0.07 Ilb NOX/MMBtu
0.31 1IbCO/MMBtu
17WE0290.CP1.xlsm
Venting from Winder South High/Low Pressure Separators when unable to compress to Sales line. Vapors
013 are controlled by ECD with 95% control efficiency.
123-9CAA-013 17WE0290 CP1 APEN rec'd 3/21/17
Emissions Summary Table
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
62685
lb/MMscf
3134.26 lb/MMscf
133.21 tpy
6.66 tpy
Gas Analysis
NOx
0.07
Ib/MMBTU
0.07 Ib/MMBTU
0.30 tpy
0.30 tpy
AP -42
CO
0.31
Ib/MMBTU
0.31 lb/MMBTU
1.37 tpy
1.37 tpy
AP -42
Benzene
145.93
Ib/MMscf
7.30 lb/MMscf
620.21 lb/yr
31.01 lb/yr
Gas Analysis
Toluene
126.205
Ib/MMscf
6.3103 Ib/MMscf
536.37 lb/yr
26.82 lb/yr
Gas Analysis
Ethylbenzene
9.872
lb/MMscf
0.4936 lb/MMscf
41.95 lb/yr
2.10 lb/yr
Gas Analysis
Xylenes
37.120
lb/MMscf
1.8560 lb/MMscf
157.76 lb/yr
7.89 lb/yr
Gas Analysis
n -Hexane
802.96
lb/MMscf
40.1478 lb/MMscf
3412.56 lb/yr
170.63 lb/yr
Gas Analysis
2,2,4-TMP
105.509
lb/MMscf
5.2755 lb/MMscf
448.42 lb/yr
22.42 lb/yr
Gas Analysis
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 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
Yes See additional notes section below for further discussion.
This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, Section XVII.B.2
Additional Notes:
Several new wells are anticipated to come on-line at this facility in 2017. The separators at thsi facility are subject to R7.XVII.B.2.
The applicant provided details on the O&M plan that describe flow meters to monitor and record volumetric flowrates.
SCC CODING
SCC Code:
31000205
Emission Factors for Permit:
Uncontrolled (lb/MMscf vented)
NOx 141.29
CO
VOC
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
2,2,4-TMP
644.10
62685.16
145.93
126.21
9.87
37.12 1.86 95%
802.96 40.15 95%
105.51 5.28
Controlled (lb/MMscf vented) Control Eff.
141.29 0%
644.10 0%
3134.26 95%
.__7.30..................._..._..._......_..._................_.._95%
6.31 95%
0.49 95%
95%
17WE0290.CP1.xlsm
Non -Attainment
—J
O
ea
O
0
W
m
tL
0
0
2
E
U
O
a
U
a
a)
Q
a
2
lL
m
41
43
a
2.
b
2
O
U
-C
N
Z
O
N
N
Ui
W
m
d
01
b
C
O
a
m
0 O
L.,
C
2
O
N
N
LU
W
REMARKS
Previous total taken from Dec 2015 tab
March 2017: indiv. permit; formerly GP01
March 2017: indiv. Permit; formerly GP07
March 2017: new GP08, formerly GP05
c c
•.
L 1 02 - canceller! Oct 2Sf 6 -- removed
March 2017: new GP08
March 2017, indiv permit
March 2017. indiv permit
March 2017. indiv permit
March 2017: indiv permit
Mindiv r
Marcharch 20172017, pe
indiv permmitit
March 2017: new GP02 registration
VOC: Syn Minor (NANSR and OP)
NOx: Minor (NANSR and OP)
CO: Minor (PSD and OP)
HAPS: Syn Minor n -hexane & Total
HH: Minor
7777: Syn Minor
Excludes units exempt from pemlits/APENs
Pubcom required based on new synthetic minor
constriction permit, and new construction permit emissions
increase greater than 25 tpy VOC
Facilityis eligible for GP02 because < 90 tpy
Project emissions less than 25150 tpy
O. 9
0.
i° 4=
o v
O
o
0..
0 O
NNo
0
0 0
CV ooO
0 0
.-
0 0
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ui La
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OO
n
O
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r7
0 o
Total VOC Facility Emissions (point and fugitive)
(A) Change in Total Permitted VOC er111ssions (point and fugitive)
ev O
w
a o
O o
O
O O
0 0
ro
OC
o p
0 0
a
o
O O
0 0
a
O O
O 0
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a
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N N
0 0
o
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a.
a O
O O
N
O
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N N
0 0
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0 d
N N
ri vi
ci0<
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44Ci6wi
N en
N
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N N
V
0
n
CO
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m
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'
m
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o
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o
c
O
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rn
m 4
r
N
co c
M
Q
M
O
Oi N
N cm]
N'
N"
N
N^
N
CV
N
O
H
N
N
x
zz
r r
N O
o
0 o
Q
o 0
o ...
o ‘.1
r
N
N
N
N
0
m
O O
O O
O
O
O
m
oc
O o
o0
o
O
O
d
N
0.
a
O O
O O
O
O
OC
O
N
O
oo
i
a
p
o O
O
N
O
N
O
N
O
c
e
a
8
'Previous FACILITY TOTAL
Previous Permitted Facility total
Condensate Tanks (12) NORTH
Loadout NORTH
Produced Water Tanks (2) NORTH
254 `Jotter:
Produced Water Tanks (2) SOUTH
'VRT Venting NORTH
Produced Gas Venting NORTH
Condensate Tanks (12) SOUTH
Loadout SOUTH
VRT Venting SOUTH
Produced Gas Venting SOUTH
Doosan O146L, sn: EEZOG200241
Permitted Facility Total
(A) Change in Permitted Emissions
O
m
N
33aa
o
m
N
17WE0290
17WE0290
17 W E0290
17WE0290
a o
O
a N
o
33
GP02
FACILITY TOTAL
PERMIT
o,OO
el
0O
,a.
0 0
I....
0 0
0 0
0 0
N
N C,1
0 0
,
O
O
2
t- °
z N
i Q
F
z
z
0
m
z
Za
o
E O
Rm9E
aa�'cz
E S t ql
Uu. UC
d
0)
0
(0
.0
d
O
0 0
(0
O
CO
C
WC
Q
O
r
O
0
e M
C) 0
7
e
at0
e e
M N
N 0
N N
O (0
0 e
N O
CO
n
N
0
0
0
N
I
O
0
o
a
FIr
O
N
r
M N
CO
0
a-
x
0
o
2
o
N
No
N
o
x
O
a O
e
?
00
(N
o
O N
CO 0
V
N M
m 0
0 CO
e 0
M
at
M
N
0
0
N
X
0
CO
t.0
e
N
D 0J
M N
a
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N
0
0
y
o
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O
M
c00
M M
e
e
O
O
N
O
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a
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e
a
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e
M
N
C
0
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CO
O
M
O
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O
O O
N
O e
N f0
N co
4'
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0 e
N
O
C
0
0
a
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CO
o
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a
0
ti
e
E
CD0
N
G
'POINT 1PERMIT I Description
!Previous FACILITY TOTAL
r �
Condensate Tanks (12) NORTH
Loadout NORTH
Produced Water Tanks (2) NORTH
GM Vortec 5. 7L
N
Produced Water Tanks (2) SOUTH
VRT Venting NORTH
Produced Gas Venting NORTH
Condensate Tanks (12) SOUTH
Loadout SOUTH
VRT Venting SOUTH
Produced Gas Venting SOUTH
Doosan D146L, sn: EEZOG200241
17WE0290
17WE0290
CO 0
�
0
y
U ci
o
CO
0 .-
17WE0290
17WE0290
17WE0290
17WE0290
0
0
WN
<- 0
TOTAL1(tpy)
O O
O V
6. C..
00000
0 CO
0 0.-
00000
N.-
e
as
0
to
.0
N
O
0
0
ci
C
O
.(0
C
W
i.
hO
O
0
N O
O o
N
O
N N
0 0
a- N
0 0
0 CO
0 0
a- e
0 0
e
0
0
0
N
04 I
O
0
O
E
r
Fl
O
N 0
CO
N N
e
N
r
0
=
O
0
2
o
r
o
m
N
S
C
erg
N N
M
cn coon,'
M N
u`�ioen.
N
N M
o
d
x
o
CO
,_
N 0
at
,_
CO
O
O
-
W
O
N
e
N N
a
CV
O
O
0
O
F
O
N
N
t0
at
M e
N N
N
0
t`
N
e
0
0
m
O
N M
0
O UOfl
N NMO
N le0
N 40
O
zu
'7.2,
O
+0
O
0
O
a
o
it:o
43,
E
047
CO
0
c
POINT I PERMIT I Description
!Previous FACILITY TOTAL
Condensate Tanks (12) NORTH
Loadout NORTH
Produced Water Tanks (2) NORTH
GM Vor?ec 5. 75
n
Produced Water Tanks (2) SOUTH
VRT Venting NORTH
Produced Gas Venting NORTH
Condensate Tanks (12) SOUTH
ILoadout SOUTH
VRT Venting SOUTH
IProduced Gas Venting SOUTH
Doosan D146L, sn: EEZOG200241
17WE0290
17WE0290
GP08
,cancelled
,
}0-3
0
0
m W
17WE0290
17WE0290
17WE0290
17WE0290
0CD
0
W N
311
TOTAytpy)
N
O O
000
M 40
047
CO
< .�
N CO
O o
000000010
01 0
0
a- N
M: at
1239CAAxIsx
Permit number:
Date issued:
Issued to:
DO
on = » trol Division
Department of Public Health b Environment
CONSTRUCTION PERMIT
17WE0290
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General Description:
Issuance: 1
Extraction Oil Et Gas, Inc
Winder Production Facility
123/9CAA
NENE Section 9 T6N R67W
Weld County
Well Production Facility
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
Winder North
Condensate
Tank Battery
001
Twelve (12) 400 barrel fixed roof storage
vessels used to store condensate.
Enclosed Flare
Winder North
Truck Loadout
002
Truck loadout of condensate, when liquids
pipeline is not available.
Dedicated Enclosed
Flare
Winder North
VRT Gas
008
Vapor recovery tower controlled by enclosed
flare when sales gas line is not available.
Enclosed Flare
Winder North
Produced Gas
009
HLP Separators controlled by enclosed flare
when sales gas line is not available.
Enclosed Flare
Winder South
Condensate
Tank Battery
010
Twelve (12) 400 barrel fixed roof storage
vessels used to store condensate.
Enclosed Flare
Winder South
Truck Loadout
011
Truck loadout of condensate, when liquids
pipeline is not available.
Dedicated Enclosed
Flare
Winder South
VRT Gas
012
Vapor recovery tower controlled by enclosed
flare when sales gas line is not available.
Enclosed Flare
Winder South
Produced Gas
013
HLP Separators controlled by enclosed flare
when sales gas line is not available.
Enclosed Flare
COLORADO
Air Pollution Control Division
F.rtme?rt of f*i.;Aic 11. 1th n €^*•:;r ,si-::.gin[
Page 1 of 16
This is r wed; sub`s t all rukbs and regulations of the Colorado Air Quality Control
Co ion a e ". ad "° lutio'"�T'-vention and Control Act (C.R.S. 25-7-101 et seq), to the
specific general terms and conditions included in this document and the following specific terms and
conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of
the latter of commencement of operation or issuance of this permit, by submitting a Notice of
Startup form to the Division for the equipment covered by this permit. The Notice of Startup
form may be downloaded online at www.colorado.gov/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.)
5. The operator shall retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
)
Annual Limits:
Facility '.
Equipment ID
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NO,
VOC
CO
Winder North
Condensate
Tank Battery
001
---
---
10.7
1.8
Point
Winder North
Truck Loadout
002
---
---
0.9
---
Point
COLORADO
{ Air Pollution Control Division
.:: tics.h
Page 2 of 16
Facility
Equipment ID
AIRS
Point
Tons per Year
Emission
PM2.5
NO,
V0C
CO
Type
Winder North
VRT Gas
008
---
---
9.6
1.5
Point
Winder North
Produced Gas
009
---
---
5.8
1.2
Point
Winder South
Condensate
Tank Battery
010
---
---
10.9
1.8
Point
Winder South
Truck Loadout
011
---
---
0.7
---
Point
Winder South
VRT Gas
012
---
---
11.1
1.8
Point
Winder South
Produced Gas
013
---
---
6.7
1.4
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.
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.
7. 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.)
Facility Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
Winder North Condensate Tank
Battery
001
Enclosed Flare
V0C and HAP
Winder North Truck Loadout
002
Dedicated Enclosed Flare
V0C and HAP
Winder North VRT Gas
008
Enclosed Flare when sales gas line is
not available
V0C and HAP
Winder North Produced Gas
009
Enclosed Flare when sales gas line is
not available
V0C and HAP
COLORADO
Air Pollution Control Division
•:` of Flo?;; kt<�ai!'.hy ^.^„r;r,�r::tnc
Page 3 of 16
Facility Equipment ID
AIRS
Point
Control Device
Pollutants
Controlled
Winder South Condensate Tank
Battery
010
Enclosed Flare
VOC and HAP
Winder South Truck Loadout
011
Dedicated Enclosed Flare
VOC and HAP
Winder South VRT Gas
012
Enclosed Flare when sales gas line is
not available
VOC and HAP
Winder South Produced Gas
013
Enclosed Flare when sales gas line is
not available
VOC and HAP
PROCESS LIMITATIONS AND RECORDS
8. 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
Winder North Condensate Tank
Battery
001
Condensate throughput
1,820,145 barrels
Winder North Truck Loadout
002
Hydrocarbon liquids loaded to
truck
151,150 barrels
Winder North VRT Gas
008
Natural gas venting
3.67 MMscf
Winder North Produced Gas
009
Natural gas venting
3.67 MMscf
Winder South Condensate Tank
Battery
010
Condensate throughput
2,268,378 barrels
Winder South Truck Loadout
011
Hydrocarbon liquids loaded to
truck
113,419 barrels
Winder South VRT Gas
012
Natural gas venting
4.25 MMscf
Winder South Produced Gas
013
Natural gas venting
4.25 MMscf
The owner or operator shall monitor monthly process rates based on the calendar month.
Compliance with the annual throughput limits shall be determined on a rolling twelve (12)
month total. By the end of each month a new twelve-month total is calculated based on the
previous twelve months' data. The permit holder shall calculate throughput each month and
keep a compliance record on site or at a local field office with site responsibility, for Division
review.
9. Points 008, 009, 012, and 013: The owner or operator shall continuously monitor and record
the volumetric flow rate of natural gas vented from these points using a flow meter. The
(COLORADO
Air Pollution Control Division
Page 4 of 16
month throughput records to demonstrate compliance with the
ai"'"='"°i is pe and to calculate emissions as described in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
10. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
11. Points 001, 008, 009, 010, 012, 013: 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)
12. Points 001 and 010: This source is subject to Regulation Number 7, Section XII. 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 condensate storage tanks; and
• Ensure that the combustion device controlling emissions from this storage tank be
enclosed, have no visible emissions, and be designed so that an observer can, by means
of visual observation from the outside of the enclosed combustion device, or by other
means approved by the Division, determine whether it is operating properly.
(Regulation Number 7, Section XII.C.) (State only enforceable)
13. Points 001, 008, 009, 010, 012, 013: The combustion device covered by this permit is
subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable).
If a flare or other combustion device is used to control emissions of volatile organic compounds
to comply with Section XVII, it shall be enclosed; have no visible emissions during normal
operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an
observer can, by means of visual observation from the outside of the enclosed flare or
combustion device, or by other convenient means approved by the Division, determine whether
it is operating properly. This flare must be 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.
14. Points 001 and 010: The storage tank covered by this permit is subject to the emission control
requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and
operate air pollution control equipment that achieves an average hydrocarbon control
efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency
of at least 98% for hydrocarbons except where the combustion device has been authorized by
permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation
Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two
years, made available to the Division upon request. This control requirement must be met
within 90 days of the date that the storage tank commences operation.
15. Points 001 and 010: The storage tanks covered by this permit are subject to the venting and
Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7,
Section XVII.C.2.
16. Points 002 and 011: 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.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section
II.A.1. Et 4.)
COLORADO
Air Pollution Control Division
Page 5 of 16
17. is 0 s•n 01 s sourc is located in an ozone non -attainment or attainment-
aint=P` c= • ' bjec •` the Reasonably Available Control Technology (RACT)
requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall
be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E.)
18. Points 002 and 011: The owner or operator shall follow loading procedures that minimize the
leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part
B, III.D.2):
• Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or
other liquid or vapor loss during loading and unloading.
• All compartment hatches at the facility (including thief hatches) shall be closed and
latched at all times when loading operations are not active, except for periods of
maintenance, gauging, or safety of personnel and equipment.
• The owner or operator shall inspect onsite loading equipment during loading
operations to monitor compliance with above conditions. The inspections shall occur
at least monthly. Each inspection shall be documented in a log available to the
Division on request.
19. Points 002 and 011: All hydrocarbon liquid loading operations, regardless of size, shall be
designed, operated and maintained so as to minimize leakage of volatile organic compounds to
the atmosphere to the maximum extent practicable.
20. Points 008, 009, 012, 013: The separators covered by this permit are subject to Regulation
Number 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator,
produced during normal operation from any newly constructed, hydraulically fractured, or
recompleted oil and gas well, must either be routed to a gas gathering line or controlled from
the date of first production by air pollution control equipment that achieves an average
hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design
destruction efficiency of at least 98% for hydrocarbons.
OPERATING a MAINTENANCE REQUIREMENTS
21. Points 001, 002, 008, 009, 010, 011, 012, 013: 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 OEtM plan are subject to Division
approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.)
22. Points 002 and 011: The owner or operator of a loadout at which emissions are controlled by
dedicated enclosed flare shall:
a. Install and operate the vapor collection equipment to collect vapors during all loading
of tank compartments of outbound transport trucks.
b. Include devices to prevent the release of vapor from vapor collection hoses not in use.
c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred
unless the vapor collection equipment is in use.
d. Operate all recovery and disposal equipment at a back pressure less than the pressure
relief valve setting of transport vehicles.
e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch
covers shall be weighted an properly seated.
f. Inspect pressure relief devices (PRDs) annually for proper operation and replace as
necessary. PRDs shall be set to release at a pressure that will ensure flashing, working
and breathing losses are routed to the control device under normal operating
conditions.
COLORADO
1 Air Pollution Control Division
Peke- ne : of fixity tI. i.t :i E r -t r: nz
Page 6 of 16
pectio of thief hatch seals and PRDs with an indication of status,
de on W' :roble ound, and their resolution.
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
23. Points 001, 002, 008, 009, 010, 01, 012, 013: 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
XII.C, XVII.B.2. and XVII.A.16)
24. Point 001: The owner or operator shall complete site specific sampling including a
compositional analysis of the pre -flash pressurized condensate routed to these storage tanks.
Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of
testing shall be used to determine a site -specific emissions factor for VOC and all reportable
NCRPs using ProMax process simulator. Results of site -specific sampling, analysis, and ProMax
modeling shall be submitted to the Division as part of the self -certification and used to
demonstrate compliance with the emissions factors chosen for this emissions point.
25. Point 008: The owner/operator shall complete an initial site specific extended gas analysis
("Analysis") within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the natural gas vented from this emissions
unit in order to verify the VOC and n -hexane content (weight fraction) of this emission stream.
Results of the Analysis shall be used to calculate site -specific emission factors for the
pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved
methods. Results of the Analysis shall be submitted to the Division as part of the self -
certification and must demonstrate the emissions factors established through the Analysis are
less than or equal to, the emissions factors submitted with the permit application and
established herein in the "Notes to Permit Holder" for this emissions point. If any site specific
emissions factor developed through this Analysis is greater than the emissions factors
submitted with the permit application and established in the "Notes to Permit Holder" the
operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the
Division, a request for permit modification to address this/these inaccuracy(ies).
26. Point 009: The owner/operator shall complete an initial site specific extended gas analysis
("Analysis") within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the natural gas vented from this emissions
unit in order to verify the VOC and n -hexane content (weight fraction) of this emission stream.
Results of the Analysis shall be used to calculate site -specific emission factors for the
pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved
methods. Results of the Analysis shall be submitted to the Division as part of the self -
certification and must demonstrate the emissions factors established through the Analysis are
less than or equal to, the emissions factors submitted with the permit application and
established herein in the "Notes to Permit Holder" for this emissions point. If any site specific
emissions factor developed through this Analysis is greater than the emissions factors
submitted with the permit application and established in the "Notes to Permit Holder" the
operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the
Division, a request for permit modification to address this/these inaccuracy(ies).
27. Point 010: The owner or operator shall complete site specific sampling including a
compositional analysis of the pre -flash pressurized condensate routed to these storage tanks.
Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of
testing shall be used to determine a site -specific emissions factor for VOC and all reportable
NCRPs using ProMax process simulator. Results of site -specific sampling, analysis, and ProMax
COLORADO
Air Pollution Control Division
xep ,nrr„ of ice .: ii+ter Y 1rCn-rce:nf
Page 7 of 16
d to t°H- Division as part of the self -certification and used to
emo ':t- •lia the =' sions factors chosen for this emissions point.
28. Point 012: The owner/operator shall complete an initial site specific extended gas analysis
("Analysis") within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the natural gas vented from this emissions
unit in order to verify the VOC and n -hexane content (weight fraction) of this emission stream.
Results of the Analysis shall be used to calculate site -specific emission factors for the
pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved
methods. Results of the Analysis shall be submitted to the Division as part of the self -
certification and must demonstrate the emissions factors established through the Analysis are
less than or equal to, the emissions factors submitted with the permit application and
established herein in the "Notes to Permit Holder" for this emissions point. If any site specific
emissions factor developed through this Analysis is greater than the emissions factors
submitted with the permit application and established in the "Notes to Permit Holder" the
operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the
Division, a request for permit modification to address this/these inaccuracy(ies).
29. Point 013: The owner/operator shall complete an initial site specific extended gas analysis
("Analysis") within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the natural gas vented from this emissions
unit in order to verify the VOC and n -hexane content (weight fraction) of this emission stream.
Results of the Analysis shall be used to calculate site -specific emission factors for the
pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved
methods. Results of the Analysis shall be submitted to the Division as part of the self -
certification and must demonstrate the emissions factors established through the Analysis are
less than or equal to, the emissions factors submitted with the permit application and
established herein in the "Notes to Permit Holder" for this emissions point. If any site specific
emissions factor developed through this Analysis is greater than the emissions factors
submitted with the permit application and established in the "Notes to Permit Holder" the
operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the
Division, a request for permit modification to address this/these inaccuracy(ies).
Periodic Testing Requirements
30. This source is not required to conduct periodic testing, unless otherwise directed by the
Division or other state or federal requirement.
ADDITIONAL REQUIREMENTS
31. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A,
II.C.)
• Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five
(5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone
nonattainment areas emitting less than 100 tons of VOC or NO), per year, a change in
annual actual emissions of one (1) ton per year or more or five percent, whichever is
greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on the
last APEN submitted; or
COLORADO
Air Pollution Control Division
teepatcn re of Riatet Health o
Page 8 of 16
r on ."repo: e 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.
32. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any
such time that this source becomes major solely by virtue of a relaxation in any permit
condition. Any relaxation that increases the potential to emit above the applicable Federal
program threshold will require a full review of the source as though construction had not yet
commenced on the source. The source shall not exceed the Federal program threshold until a
permit is granted. (Regulation Number 3, Parts C and D).
GENERAL TERMS AND CONDITIONS
33. 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.
34. If this permit specifically states that final authorization has been granted, then the remainder
of this condition is not applicable. Otherwise, the issuance of this construction permit does not
provide "final" authority for this activity or operation of this source. Final authorization of the
permit must be secured from the APCD in writing in accordance with the provisions of 25-7-
114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization
cannot be granted until the operation or activity commences and has been verified by the APCD
as conforming in all respects with the conditions of the permit. Once self -certification of all
points has been reviewed and approved by the Division, it will provide written documentation
of such final authorization. Details for obtaining final authorization to operate are located in
the Requirements to Self -Certify for Final Authorization section of this permit.
35. 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.
36. 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.
37. 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.
COLORADO
Air Pollution Control Division
of F;Gd",c. hie+zi:F 3 EnvIr nrrten,
Page 9 of 16
38. o ►5 11,.7(2 ), R.S. rauires that all sources required to file an Air Pollution
(A` Est p• n annual fee to cover the costs of inspections and
administration. If a source or activity is to be discontinued, the owner must notify the Division
in writing requesting a cancellation of the permit. Upon notification, annual fee billing will
terminate.
39. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention
and Control Act or the regulations of the AQCC may result in administrative, civil or criminal
enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil
penalties), -122.1 (criminal penalties), C.R.S.
By:
Andy Gruel, P.E.
Permit Engineer
Permit Histo
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Extraction Oil Ft Gas, Inc.
COLORADO
Air Pollution Control Division
Page 10 of 16
No
th this it issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder shall pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit.
(Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written
notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions
Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process
limits as indicated in this permit. This information is listed to inform the operator of the Division's
analysis of the specific compounds emitted if the source(s) operate at the permitted limitations.
Facility
Equipment ID
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(Ib/yr)
Winder North
Condensate
Tank Battery
001
Benzene
71432
615
31
Toluene
108883
456
23
Ethylbenzene
100414
32
2
Xylenes
1330207
123
6
n -Hexane
110543
4949
248
2,2,4-
Trimethylpentane
540841
564
28
Winder North
Truck
Loadout
002
Benzene
71432
63
3
n -Hexane
110543
546
27
Winder North
VRT Gas
008
Benzene
71432
1105
56
Toluene
108883
899
45
Ethylbenzene
100414
66
4
Xylenes
1330207
245
13
n -Hexane
110543
5958
298
2,2,4-
Trimethylpentane
540841
745
38
COLORADO
Aix Pollution Control Division
of rr ::: r,r>z r F ;•:
Page 11 of 16
Facility
Equipment ID
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(Ib/yr)
Winder North
Produced Gas
009
Benzene
71432
536
27
Toluene
108883
464
24
Ethylbenzene
100414
37
2
Xylenes
1330207
137
7
n -Hexane
110543
2947
148
2,2,4-
Trimethylpentane
540841
388
20
Winder South
Condensate
Tank Battery
010
Benzene
71432
654
33
Toluene
108883
484
24
Ethylbenzene
100414
33
2
Xylenes
1330207
129
6
n -Hexane
110543
5061
253
2,2,4-
Trimethylpentane
540841
577
29
Winder South
Truck
Loadout
011
Benzene
71432
47
2
n -Hexane
110543
410
20
Winder South
VRT Gas
012
Benzene
71432
1280
64
Toluene
108883
1041
52
Ethylbenzene
100414
76
4
Xylenes
1330207
284
14
n -Hexane
110543
6899
345
2,2,4-
Trimethylpentane
540841
863
43
Winder South
Produced Gas
013
Benzene
71432
621
31
Toluene
108883
537
27
Ethylbenzene
100414
42
2
Xylenes
1330207
158
8
n -Hexane
110543
3413
171
2,2,4-
Trimethylpentane
540841
449
23
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.
COLORADO
Air Pollution Control Division
Page 12 of 16
si l is .nta ed this pe it are based on the following emission factors:
Point 001:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl "`
Controlled
Emission Factors
lb/bbl
Source
NOx
---
0.0004
AP -42 Ch. 13.5
CO
---
0.0019
AP -42 Ch. 13.5
VOC
0.2347
0.0117
ProMax model
based on a site -
specific
pressurized liquid
sample collected
over 12 months
prior to
application date
71432
Benzene
0.00034
0.000017
108883
Toluene
0.00025
0.000013
100414
Ethylbenzene
0.00002
, 0.000001
1330207
Xylene
0.000068
0.000003
110543
n -Hexane
0.002719
0.000136
540841
2'2'4
Trimethylpentane
0.00031
0.000015
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO
emission factors are based on a heat content of waste gas of 2542.39 Btu/scf, and a waste gas volume of 2.47
scf/bbl (both modeled by ProMax.)
Point 002:
CAS #
Pollutant
lb/bbl
Uncontrolled
Emission
Factors
Controlled
Emission
Factors
lb/bbl
Source
VOC
0.236
0.0118
State default for
condensate
71432
Benzene
0.000416
0.0000208
110543
n -Hexane
0.00361
0.0001805
VOC, benzene and n -hexane emission factors are state default accepted emission factors from PS
Memo 14-02.
Controlled emission factors are based on a dedicated flare control efficiency of 95%. NOx and CO
emissions are below APEN reporting thresholds when using ProMax modeled vapor energy content
of 1.6591 MMBtu/hr and AP -42 Ch 13.5 emission factors.
Point 008:
CAS #
Pollutant '
Uncontrolled
Emission Factors
lb/MMscf
Controlled
Emission Factors
lb/MMscf
Source
NOx
---
179.50
AP -42 Ch. 13.5
CO
---
818.33
AP -42 Ch. 13.5
VOC
104139.39
5206.97
ProMax model
based on a site -
specific
pressurized liquid
71432
Benzene
301.01
15.05
108883
Toluene
244.80
12.24
100414
Ethylbenzene
17.84
0.89
1330207
Xylene
66.72
3.34
sample collected
over 12 months
prior to
application date
110543
n -Hexane
1623.28
81.16
540841
2,2,4-
Trimethylpentane
202.95
10.15
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO
emission factors are based on a heat content of waste gas of 2639.77 Btu/scf.
COLORADO
Air Pollution Control Division
Pu'^Ac h ieak:.h. Fr E ..,=rst*rznc
Page 13 of 16
Point 009:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf
Controlled
Emission Factors
Ib/MMscf
Source
N0x
---
141.29
AP -42 Ch. 13.5
CO
---
644.10
AP -42 Ch. 13.5
V0C
62685.16
3134.26
ProMax model
based on a site -
specific
pressurized liquid
71432
Benzene
145.93
7.30
108883
Toluene
126.21
6.31
100414
Ethylbenzene
9.87
0.49
1330207
Xylene
37.12
1.86
sample collected
over 12 months
prior to
application date
110543
n -Hexane
802.96
40.15
540841
2,2,4-
Trimethylpentane
105.51
5.28
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO
emission factors are based on a heat content of waste gas of 2077.75 Btu/scf.
Point 010:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
N0x
---0.0003
AP 42 .
CO
0.0016
AP 42 ChCh.. 13.5135
V0C
0.1917
0.0096
omodel
basPreMud on a site
specific
pressurized liquid
sample collected
over 12 months
prior to
application date
71432
Benzene
0.00029
0.000014
108883
Toluene
0.00021
0.000011
100414
Ethytbenzene
0.00001
0.000001
1330207
Xylene
0.000057
0.000003
110543
n -Hexane
0.0022
0.000112
540841
2,2,4
Trimethylpentane
0.00025
0.000013
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO
emission factors are based on a heat content of waste gas of 2552.7 Btu/scf, and a waste gas volume of 2.006
scf/bbl (both modeled by ProMax.)
Point 011:
CAS #
Pollutant
Uncontrolled
Emission
Factors
lb/bbl
Controlled
Emission
Factors
lb/bbl
Source
V0C
0.236
0.0118
State default for
condensate
71432
Benzene
0.000416
0.0000208
110543
n -Hexane
0.00361
0.0001805
VOC, benzene and n -hexane emission factors are state default accepted emission factors from PS Memo 14-02.
Controlled emission factors are based on a dedicated flare control efficiency of 95%. NOx and CO emissions are below
APEN reporting thresholds when using ProMax modeled vapor energy content of 2.616 MMBtu/hr and AP -42 Ch
13.5 emission factors.
COLORADO
Air Pollution Control Division
,p_ me t of Putt,:ik x'h 7 - r,rr.;mnc
Page 14 of 16
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf
Controlled
Emission Factors
lb/MMscf
Source
N0x
---
179.50
AP -42 Ch. 13.5
CO
---
818.33
AP -42 Ch. 13.5
V0C
104139.39
5206.97
ProMax model
based on a site -
specific
pressurized liquid
71432
Benzene
301.01
15.05
108883
Toluene
244.80
12.24
100414
Ethylbenzene
17.84
0.89
1330207
Xylene
66.72
3.34
sample collected
over 12 months
prior to
application date
110543
n -Hexane
1623.28
81.16
540841
2,2,4-
Trimethylpentane
202.95
10.15
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO
emission factors are based on a heat content of waste gas of 2639.77 Btu/scf.
Point 013:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf
Controlled
Emission Factors
lb/MMscf
Source
N0x
---
141.29
AP -42 Ch. 13.5
CO s
---
644.10
AP -42 Ch. 13.5
V0C
62685.16
3134.26
ProMax model
based on a site -
specific
pressurized liquid
71432
Benzene
145.93
7.30
108883
Toluene
126.21
6.31
100414
Ethylbenzene
9.87
0.49
1330207
Xylene
37.12
1.86
sample collected
over 12 months
prior to
date
110543
n -Hexane
802.96
40.15
540841
2,2,4- 105.51 5.28
Trimethylpentane application
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO
emission factors are based on a heat content of waste gas of 2077.75 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 permit fulfills the requirement to hold a valid permit reflecting the storage tank and
associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A)
when applicable.
COLORADO
Air Pollution Control Division
f.k.piaTIrlf,t. Of PUth {ear r 5 ,onrr.:;ns
Page 15 of 16
8
Applicable
Requirement
Operating Permit
Synthetic Minor Source of: VOC, HAPs (total, and n -Hexane)
NANSR
Synthetic Minor Source of: VOC
MACT HH
Area Source Requirements: Not Applicable
9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
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
r
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
COLOR ADO
Air Pollution Control Division
Page 16 of 16
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Permit Number:
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization.]
Facility Equipment ID: Winder North Condensate Tank Battery
uested Action (Check applicable request boxes)
Section 02 — Re
Section 01 — Administrative Information
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External Floating Roof:
Internal Floating Roof:
Fixed Roof:
Date Of First Production
(Month/Year)
a)
N
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Installation Date of most recent
storage vessel in storage tank
(Month/Year)
0)
0
N
Total Volume of
Storage Tank
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4800
# of Liquid Manifold
Storage Vessels in
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Form APCD-205-CondensateTank APEN-Ver.12-22-2014.doc
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FORM APCD-205
AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Stora
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Permit Number:
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Section 06 -Stack (Source
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Direction of stack outlet (check one):
Exhaust Opening Shape & Size (check one):
Section 07 — Control Device Information
E&P Sites On
Information
aration Technolo
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Section 08 — Gas/Li
HLP Separation, Vapor Recovery Tower
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Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above.
Requested Permitted Emissions
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FORM APCD-205
Hydrocarbon Liquid Loading APEN - Form APCD-208
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category,
there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if
the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on
the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
i "1-tArG d 2-610 AIRS ID Number: 123 / 9CAA / 002
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Company equipment Identification: Winder North Truck Loadout
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name':
Site Name:
Extraction Oil & Gas, Inc.
Winder Production Facility
Site Location: NENE Sec 9 T6N R67W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 5300
Denver, CO
E -Mail Address'-: jarlisle@extractionog.com
Site Location
County: Weld
/
CEIVED
x242017
^ APCD
NAICS or SIC Code: 211111
Permit Contact: Josh Carlisle
Phone Number: 720-481-2372
Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on
all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided.
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017
®V COLORADO
Hml1� En.��unm.�
Permit Number:
Winder North Liquid Loading APEN
AIRS ID Number: 123 i9CAA/ 002
[Leave blank unless APCD has already assigned a permit ft and AIRS ID]
Section 2- Requested Action
NEW permit OR newly -reported emission source
Request coverage under construction permit ❑ Request coverage under General Permit GP07
If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted
along with the APEN Filing fee.
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name
❑ Change permit limit ❑ Transfer of ownership3
- 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)
,C EIVED
APR 242017
ry,
❑ Other (describe below) 1 7
Additional Info Et Notes: Changing GP07 to Individual Permit. Collocated with Winder South Loadout point source.
No shared equipment, requesting same construction permit for both point sources.
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: Loadout of condensate into tanker trucks for transport off -site. Assumed that
5% of production is loaded on trucks. All other production goes to oil pipeline. Loading throughput calculated on rolling basis.
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
09/ 30 /2015
/ /
Will this equipment be operated in any NAAQS nonattainment area?
Is this equipment located at a stationary source that is considered a Major Source of (HAP)
emissions?
Does this source load gasoline into transport vehicles?
Is this source located at an oil and gas exploration and production site?
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual
average?
Does this source splash fill less than 6750 BBL of condensate per year?
Does this source submerge fill less than 16308 BBL of condensate per year?
• Yes ❑ No
❑ Yes O No
❑ Yes 0 No
❑ Yes ❑ No
❑ Yes 0 No
❑ Yes (] No
❑ Yes 2 No
COLORADO
Form APCD-208 -Hydrocarbon Liquid Loading APEN Rev 02/2017 2 I AVmE�;
Winder North Liquid Loading APEN
Permit Number:
AIRS ID Number: 123 /9CAA/ 002
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
Product Loaded: El Condensate ❑ Crude Oil ❑ Other:
If this APEN is being filed for vappr(displaced from cargo carrier, omplete the followin
Requested Volume
Loaded4:
125,958
Bbl/yr
Actual Volume
Loaded:
151,150
Bbl/yr
a Requested values will become permit limitations. Requested limit(s) should consider future process growth
This product is loaded from tanks at this facility into:
(eg, "rail tank cars" or "tank trucks")
Tank trucks
If site specific emission factor is used to calculate emissions, complete the following:
Saturation Factor:
N/A
Average temperature
of bulk liquid loading:
N/A
°F
True Vapor
Pressure
N/A
Psia 60 °F
Molecular weight of
displaced vapors
N/A
Lb/lb-mol
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume
Loaded5:
N/A
Bbl/yr
Actual Volume
Loaded:
N/A
Bbl/yr
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Product Density:
Load Line Volume:
N/A
N/A
Lb/ft3
ft3/truckload Vapor Recovery Line Volume
N/A
ft3/truckload
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 1 A®
COLORADO
Department of Pahhc
HwItM1 E Envoonment
Permit Number:
Winder North Liquid Loading APEN
AIRS ID Number: 123 /9CAW 002
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Geographical Information
Geographical Coordinates
40.50800, -104.892373
F.#s
Operator ,
Stec ID �Io
Discharge Height
e round -Le
Above Ge
xr u
_
emp
A�"
}�
Flo v� Ra
eloci
N/A
Unknown
Unknown
Unknown
Unknown
Indicate the direction of the stack outlet: (check one)
• Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
O Circular Interior stack diameter (inches):
❑ Other (describe):
❑ Upward with obstructing raincap
Unknown
Section 6 - Control Device Information
❑ Loading occurs using a vapor balance system:
Requested Control Efficiency
%
❑ Combustion
✓ Device:
Pollutants Controlled: VOC, HAP's
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency
Minimum Temperature:
MMBtu/hr
Make/Model:
95
98 %
Waste Gas Heat Content
Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating
Btu/scf
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0/0
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
4I
COLORADO
•xw.nm , t m wwt
Health h f..„.anent
Permit Number:
Winder North Liquid Loading APEN
AIRS ID Number: 123 / 9CAP✓ 002
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? E Yes ❑ No
If yes, describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
PM
SOX
NO,,
CO
VOC
ECD
95%
HAPs
ECD
95%
Other:
❑ Using State Emission Factors (Required for GP07) VOC
E Condensate
❑ Crude
0.236 Lbs/BBL
0.104 Lbs/BBL
Benzene n -Hexane
0.00041 Lbs/BBL 0.0036 Lbs/BBL
0.00018 Lbs/BBL 0.0016 Lbs/BULL
From what year is the following reported actual annual emissions data? 2017
Use the following table to report the criteria pollutant emissions from source:
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor ;
Units
Emission
Factor
Sourcerwm
?
ualAnnua
��T'
usio
zx
e este rrn
Em�s�o
i
C li
�mi 5
Uncontrolled
Controlled 5
Uncontrolled
Controlled
PM
SOX
NO,,
VOC
.236
lb/bbl
PS Memo 14-02
14.86
0.74
17.84
0.89
CO
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
.0036
lb/bbl
PS Memo 14-02
0.23
0.01
0.27
0.01
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.
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
COLORADO
5 I A�
HUItN 6 Fihronmvn�
Permit Number:
Winder North Liquid Loading APEN
AIRS ID Number: 123 /9CAA' 002
[Leave blank unless APCD has already assigned a permit x and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature of ega ll y Acithorized Person (not a vendor or consultant)
Josh Carlisle
Date
EHSR Manager
Name (print) Title
Check the appropriate box to request a copy of the:
Draft permit prior to issuance
Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $152.90 and the General
Permit registration fee of $250 as applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-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
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
https: //www.colorado.gov/cdphe/apcd
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
®® coroaaoo
6 1 ay r.�a�.e�
Gas/Liquid Separator APEN - Form APCD-211
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Gas/Liquid Separators only. If your emission unit does not fall into this category, there
may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
r'7 wEO2_9O
AIRS ID Number: 123 / 9CAA/ 065
[Leave blank unless APCD has already assigned a permit ti and AIRS ID]
Company equipment Identification: Winder North VRT Gas
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name': Extraction Oil & Gas, Inc.
Site Name: Winder Production Facility
Site Location: NENE Sec 9 T6N R67W
Mailing Address:
(Include Zip code) 370 17th Street, Suite 5300
Denver, CO
E -Mail Address2: jarlisle@extractionog.com
Site Location
County: Weld
NAICS or SIC Code: 211111
Permit Contact: Josh Carlisle
Phone Number: 720-481-2372
'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.
359835
Form APCD-211 - Gas/Liquid Separator APEN - Rev 02/2017 1
A®
Department of
COLORADO
Winder North VRT
Permit Number: AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
O NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership3 ❑ 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 a Notes: Collocated with Winder South VRT Gas point source.
No shared equipment, please issue same permit number for each point source.
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:
will be combusted with ECD.
If unable to compress into sales line, gas from VRT
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
06 / 10 / 2017 Estimated, Refer to NOS
✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation:
N/A hours/day N/A days/week
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
N/A
weeks/year
O Yes ❑ No
❑ Yes ❑✓ No
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
:8®COLORADO COLxwnn� m
Health b Enannnmen,
Winder North VRT
Permit Number: AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
If you are requesting uncontrolled VOC emissions greater than 100 tpy you must use Natural Gas Venting as a process
parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy?
Natural Gas Venting
Process Parameters4:
Liquid Throughput
Process Parameters4:
El Yes
❑ No
Maximum Vent
Rate:
9970
SCF/hr
Vent Gas
Heating Value:
2639.77
BTU/SCF
Requested:
3.67
MMSCF/year
Actual:
3.06
MMSCF/year
-OR-
Requested:
N/A
Bbl/yr
Actual:
N/A
Bbl/yr
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Process Properties:
Molecular Weight:
46.84 I b/I b m o l
voc
(mole %)
74.2
VOC
(Weight %)
84.3
Benzene
(mole %)
0.146
Benzene
(Weight %)
0.244
Toluene
(mole %)
0.101
Toluene
(Weight %)
0.198
Ethylbenzene
(mole %)
0.006
Ethylbenzene
(Weight %)
0.014
Xylene
(mole %)
0.024
Xylene
(Weight %)
0.054
n -Hexane
(mole %)
0.715
n -Hexane
(Weight %)
1.315
2,2,4-
Trimethylpentane(Weight
0.067
2,2,4-Trimethylpentane
%)
0.164
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)
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
3 eDepartment
e b;w nm:t,
Winder North VRT
Permit Number:
AIRS ID Number: 123 / 9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.50800, -104.892373
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
rF)
Flow Rate
(ACFM)
Velocity
(ft/sec)
N/A
Unknown
Unknown
Unknown
Unknown
Indicate the direction of the stack outlet: (check one)
E Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
✓❑ Circular Interior stack diameter (inches):
❑ Other (describe):
❑ Upward with obstructing raincap
Section 6 - Control Device Information
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency %
VRU Downtime or Bypassed
%
❑ Combustion
Device:
Pollutants Controlled: VOC, HAP's
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency
Minimum Temperature:
MMBtu/hr
Make/Model:
95
98
%
Waste Gas Heat Content
Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating
Btu/scf
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
4 I R
Winder North VRT
Permit Number:
AIRS ID Number: 123 /9CAAi
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ✓❑ Yes ❑ No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SOX
NO„
VOC
ECD
95%
CO
HAPs
ECD
95%
Other:
From what year is the following reported actual annual emissions data? 201 7
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
5
Emission Limits)
Uncontrolled
(Tons/year)
Controlled°
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SOX
NO,
VOC
104.11
lb/MSCF
Promax
159.3
8.0
191.1
9.6
CO
0.31
lb/MMBTU
AP -42
1.25
1.25
1.50
1.50
Benzene
0.301
lb/MSCF
Promax
0.46
0.02
0.55
0.03
Toluene
0.245
Ib/MSCF
Promax
0.37
0.02
0.45
0.02
Ethylbenzene
Xylenes
n -Hexane
1.623
lb/MSCF
Promax
2.48
0.12
2.98
0.15
2'2'4
Trimethylpentane
0.203
Ib/MSCF
Promax
0.31
0.02
0.37
0.02
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.
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
5 AVCOLORADO
H pinburt cl Pua�c
Winder North VRT
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a Dennit 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.
Sig?fure of Le i y Authorized Person (not a vendor or consultant)
Josh Carlisle
Date
EHSR Manager
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
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
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
61
®® COLOnR A D 0
Gas/Liquid Separator APEN - Form APCD-211
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Gas/Liquid Separators only. If your emission unit does not fall into this category, there
may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
riviEgZ90
AIRS ID Number: 123 / 9CAA/ OOq
[Leave blank unless APCD has already assigned a permit ft and AIRS ID]
Company equipment Identification: Winder North Produced Gas
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name':
Site Name:
Site Location:
Extraction Oil & Gas, Inc.
Winder Production Facility
Site Location
NENE Sec 9 T6N R67W County: Weld
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 5300
Denver, CO
E -Mail Address2: jcarlisle@extractionog.com
NAICS or SIC Code: 211111
Permit Contact: Josh Carlisle
Phone Number: 720-481-2372
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.
359836
Form APCD-211 - Gas/Liquid Separator APEN - Rev 02/2017 1 I
AY
COLORADO
Winder North Produced Gas
Permit Number: AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
• NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment El Change company name ❑ Add point to existing permit
El Change permit limit El Transfer of ownership3 ❑ Other (describe below)
OR
El 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 Et Notes: Collocated with Winder South Produced Gas point source,
No shared equipment. Please issue same permit number for both point sources.
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:
separators will be combusted with ECD.
If unable to compress into sales line, produced gas from HLP
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
/ /
06 / 10 / 2017 Estimated, Refer to NOS
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation:
N/A hours/day N/A days/week
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
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
E Yes
❑ Yes
N/A
weeks/year
❑ No
❑✓ No
A COLORADO
x °iniu,.f-,,..:N
Winder North Produced Gas
Permit Number: AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
If you are requesting uncontrolled VOC emissions greater than 100 tpy 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:
37594
SCF/hr
Vent Gas
Heating Value:
2077.75
BTU/SCF
Requested:
3.67
MMSCF/year
Actual:
3.06
MMSCF/year
-OR-
Requested:
N/A
Bbl/yr
Actual:
N/A
Bbl/yr
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Process Properties:
Molecular Weight:
37.394
VOC
(mole %)
46.09
VOC
(Weight %)
63.6
Benzene
(mole %)
.071
Benzene
(Weight %)
.148
Toluene
(mote %)
.052
Toluene
(Weight %)
. 12 Q
0
Ethylbenzene
(mote %)
.004
Ethylbenzene
(Weight %)
.010
Xylene
(mole %)
.001
Xylene
(Weight %)
.037
n -Hexane
(mole %)
.354'
n -Hexane
(Weight %)
.815
2,2,4-
Trimethylpentane
.035(Weight
2,2,4-Trimethylpentane
%)
. 107
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)
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
3 AlfCOLORADO
xe m
Winder North Produced Gas
Permit Number:
AIRS ID Number: 123 / 9CAA/
[Leave blank unless APCD has already assigned a permit ft and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.50800, -104.892373
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
CF)
Flow Rate
(ACFM)
Velocity
(ft/sec)
N/A
Unknown
Unknown
Unknown
Unknown
Indicate the direction of the stack outlet: (check one)
0 Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular Interior stack diameter (inches):
❑ Other (describe):
❑ Upward with obstructing raincap
Section 6 - Control Device Information
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency %
VRU Downtime or Bypassed
%
❑ Combustion
Device:
Pollutants Controlled: VOC, HAP's
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency
Minimum Temperature:
MMBtu/hr
Make/Model:
95
98
Waste Gas Heat Content
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating
Btu/scf
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
4 I AV =1.,'="`„,
a
Winder North Produced Gas
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? Yes ❑ No
rol equipment AND state the overall control efficiency (% reduction):
r
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SOx
NOx
VOC
ECD
95%
CO
HAPs
ECD
95%
Other:
From what year is the following reported actual annual emissions data? 201 7
Use the following table to report the criteria pollutant emissions from source:
Pollutant
Uncontrolled
Emission
Factor
Emission
Factor
Units
Emission
Factor
Source
(AP -42,
Mfg. etc)
Actual Annual Emissions
Requested Annual Permit
s
Emission Limrt(s),.
Uncontrolled
(Tons/year)
Controlled°
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
sOx
NOx
VOC
62.67
Ib/MSCF
Promax
95.9
4.8
115.0
5.8
CO
.31
Ib/MMBTU
AP -42
0.99
0.99
1.18
1.18
Benzene
0.146
Ib/MSCF
Promax
0.22
0.01
0.27
0.01
Toluene
0.126
Ib/MSCF
Promax
0.19
0.01
0.23
0.01
Ethylbenzene
Xylenes
n -Hexane
0.803
lb/MSCF
Promax
1.23
0.06
1.47
0.07
2,2,4-0.105
Trimethylpentane ylp
Ib/MSCF
Promax
0.16
0.01
0.19
0.01
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
AAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
5 A®COLORADO
xwnm�e ci r o�c
Winder North Produced Gas
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit z 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.
/LJ
Si ature ftt�gally Auth rized Person (not a vendor or consultant)
Josh Carlisle
/y /?
Date
EHSR Manager
Name (please print)
Title
Check the appropriate box to request a copy of the:
E Draft permit prior to issuance
1 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
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
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
®® COLOR&DO
6 I
AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Stora
U
0)
N
Emission Source AIRS ID:
[Leave blank unless APCD has already assigned a permit # & AIRS ID]
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization.]
a
a)
76
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R
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a)
R
rn
1 c
C
0
0
.0
3l)
0
)
d)
•0
Permit Number:
Facility Equipment ID:
uested Action (Check applicable request boxes)
Section 02 — Re
Section 01— Administrative Information
O
r�
0
0
0.1
O
0
.0
O.1
0
.0
C)
u
.0
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O.
d
wJ
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CD
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0
z
0
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v
aT
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T-
N
o 0
VU
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zup
Extraction Oil & Gas, Inc
Company Name:
C
0
0
U
Change company name
O
O
Transfer of ownership
❑ ❑
Change process or equipment
Change permit limit
❑ ❑
a)
Elevation: 4,870
N
O
N
O
CO
0
0
U
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FORM APCD-205
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E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml
1,0
Company Name:
Extraction Oil and Gas, Inc.
Source Name:
Winder South Condensate Tank Battery
Emissions Source AIRS ID2:
123 / 9CAA /
Wells Services by this Storage Tank or Tank Battery (E&P Sites Only)
API Number
Name of Well
Newly Reported Well
05 -123 - 43402
Winder South 1
/1
05 - 123 - 43404
Winder South 2
/1
05 - 123 - 43408
Winder South 3
/1
05 - 123 - 43400
Winder South 4
/1
05 -123 - 43407
Winder South 5
�I
05 -123 - 43403
Winder South 6
//
05 -123 - 43401
Winder South 7
/1
05 -123 - 43405
Winder South 8
/1
05 -123 - 43406
Winder South 9
/1
05 -123 - 43419
Winder South 10
.1
05 -123 - 43548
Winder South 11
/1
05 -123 - 43549
Winder South 12
/1
- -
❑
- -
❑
- -
❑
- -
❑
- -
❑
- -
❑
- -
❑
- -
❑
Footnotes:
1 Attach this addendum to associated APEN form when needed to report additional wells.
2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter
N/A
Form APCD-212
2017_0221 Winder South AP FormAPCD-212-EP-StorageTank-APEN-Addendum
Hydrocarbon Liquid Loading APEN - Form APCD-208
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category,
there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if
the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on
the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
AIRS ID Number: 123 /9CAA / 011
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Company equipment Identification: Winder South Truck Loadout
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name': Extraction Oil & Gas, Inc.
Site Name: Winder Production Facility
Site Location: NENE Sec 9 T6N R67W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 5300
Denver, CO
E -Mail Address2: jarlisle@extractionog.com
/PF, 24 4:
Site Location
County: Weld
NAICS or SIC Code: 211111
Permit Contact: Josh Carlisle
Phone Number: 720-481-2372
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.
9
Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017
COLORADO
1 I AY Heal•1. gym rrSv:,,
Winder South Liquid Loading APEN
Permit Number:
AIRS ID Number: 123 /9CAA/ 011
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
O NEW permit OR newly -reported emission source
2 Request coverage under construction permit
❑ Request coverage under General Permit GP07
If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted
along with the APEN Filing fee.
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name
permit Changelimit ❑ g ❑ Transfer of ownership3 ❑ Other (describe below)
- OR
• APEN submittal for update only (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: Collocated with Winder North Truck Loadout point source.
No equipment shared, Requesting same construction permit for both.
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:
Loadout of condensate into tanker trucks for transport off -site. Assumed that
5% of production is loaded on trucks. All other production goes to oil pipeline. Loading throughput calculated on rolling basis.
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
/ /
05/ 10 /2017
Will this equipment be operated in any NAAQS nonattainment area? E Yes ❑ No
Is this equipment located at a stationary source that is considered a Major Source of (HAP)
emissions?
Does this source load gasoline into transport vehicles?
Is this source located at an oil and gas exploration and production site?
If yes:
Does this source load less than 10,000 gallons of crude oil per day on an annual
average?
Does this source splash fill less than 6750 BBL of condensate per year?
Does this source submerge fill less than 16308 BBL of condensate per year?
❑ Yes 0 No
❑ Yes 0 No
Yes ❑ No
❑ Yes 0 No
❑ Yes 0 No
❑ Yes 0 No
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 I A®
COLORADO
Department nbc
Hu. 6 Env:tonm.ni
Winder South Liquid Loading APEN
Permit Number:
AIRS ID Number: 123 /9CAA/ 011
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
Product Loaded: 0 Condensate ❑ Crude Oil ❑ Other:
If this APEN is being filed for v •ors displaced from car• carrier, complete the following: PSG `'(2 1/4(1I 7
Requested Volume
Loaded4:
94,516
Bbl/yr
Actual Volume
Loaded:
113,419
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
This product is loaded from tanks at this facility into:
(eg, "rail tank cars" or "tank trucks")
Tank trucks
Bbl/yr
If site specific emission factor is used to calculate emissions, complete the following:
Saturation Factor:
N/A
Average temperature
of bulk liquid loading:
N/A
°F
True Vapor
Pressure
N/A
Psia 60 °F
Molecular weight of
displaced vapors
N/A
Lb/lb-mol
If this APEN is being filed for vapors displaced from pressurized loading lines, complete the
following:
Requested Volume
Loaded5:
N/A
Bbl/yr
Actual Volume
Loaded:
N/A
Bbl/yr
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Product Density:
Load Line Volume:
N/A
N/A
Lb/ft3
ft3/truckload Vapor Recovery Line Volume
N/A
ft3/truckload
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
®®COLORADO
==
Permit Number:
Winder South Liquid Loading APEN
AIRS ID Number: 123 / 9CAA011
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Geographical Information
Geographical Coordinates
40.50800, -104.892373
s
e a
t'oh
t ��=Discharge
O
Neigh •
er, r
Above Ground Le
:.�.Aj4
* em
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�
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5�'�5"�+''�+'�S"
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N/A
Unknown
Unknown
Unknown
Unknown
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
0 Upward
❑ Horizontal
Indicate the stack opening and size: (check one)
El Circular Interior stack diameter (inches):
❑ Other (describe):
El Upward with obstructing raincap
Section 6 - Control Device Information
❑ Loading occurs using a vapor balance system:
Requested Control Efficiency
Combustion
✓ Device:
Pollutants Controlled: VOC, HAP's
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency
Minimum Temperature:
MMBtu/hr
Make /Model:
95
98
Waste Gas Heat Content
Constant Pilot Light: El Yes ❑ No Pilot burner Rating
Btu/scf
MMBtu/hr
El Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0/0
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
4 I®® COLORADO
Permit Number:
Winder South Liquid Loading APEN
AIRS ID Number: 123/9CAP✓C1 1
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
PM
PM
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, describe the control equipment AND state the overall control efficiency (% reduction):
Control Equipment Description
Overall Requested, Control
Efficiency
SOX
NO„
CO
VOC
ECD
95%
HAPs
ECD
95%
Other:
E Using State Emission Factors (Required for GP07) VOC
E Condensate 0.236 Lbs/BBL
❑ Crude 0.104 Lbs/BBL
Benzene n -Hexane
0.00041 Lbs/BBL 0.0036 Lbs/BBL
0.00018 Lbs/BBL 0.0016 tbs/BBL
From what year is the following reported actual annual emissions data? 2017
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.)
Uncontrolled
Emission
Factor:
lb/bbl
PS Memo 14-02
Emission;'
Factor
Source
Uncontrolled Controlled
11.15
0.56
13.38
0.67
ncontrolled
Controlled'
SO),
NO),
VOC
.236
CO
Benzene
Toluene
Ethylbenzene
Xylenes
n -Hexane
0.0036
lb/bbl
PS Memo 14-02
0.17
0.01
0.20
0.01
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.
COLORADO
Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
Permit Number:
Winder South Liquid Loading APEN
AIRS ID Number: 123 /9CAA' 011
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will
be operated in full compliance with each condition of the applicable General Permit.
Signature of Legally Authorized Person (not a vendor or consultant) Date
Josh Carlisle
EHSR Manager
Name (print) Title
Check the appropriate box to request a copy of the:
ID 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 registration fee of $250 as applicable to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
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-2O8 -Hydrocarbon Liquid Loading APEN - Rev 02/2017
®Y COLORADO
Gas/Liquid Separator APEN - Form APCD-211
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Gas/Liquid Separators only. If your emission unit does not fall into this category, there
may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: /7K16:02-9 I3 AIRS ID Number: 123 / 9CAA/ 01-2_
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Company equipment Identification: Winder South VRT Gas
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Name': Extraction Oil & Gas, Inc.
Site Name: Winder Production Facility
Site Location: NENE Sec 9 T6N R67W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 5300
Denver, CO
E -Mail Address2: jcarlisle@extractionog.com
Site Location
County: Weld
NAICS or SIC Code: 211111
Permit Contact: Josh Carlisle
Phone Number: 720-481-2372
'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-211 - Gas/Liquid Separator APEN - Rev 02/2017
359840
i iAY
COLORADO
aputtnant d!Mc
Hrbt b EnvunMu.0
Winder South VRT
Permit Number: AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
El NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name El Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership3 ❑ 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 It Notes: Collocated with Winder North VRT Gas point source.
No shared equipment, please issue same permit number.
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:
will be combusted with ECD.
If unable to compress into sales line, gas from VRT
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
05 / 10 / 2017 Estimated, Refer to NOS
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation:
N/A hours/day N/A days/week
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
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
El Yes
❑ Yes
N/A
weeks/year
❑ No
E No
:eVCOLORADO
NbEna �nm�
Winder South VRT
Permit Number: AIRS ID Number: 123 i9CAAi
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment Information
If you are requesting uncontrolled VOC emissions greater than 100 tpy you must use Natural Gas Venting as a process
parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? E Yes
Natural Gas Venting
Process Parameters4:
Liquid Throughput
Process Parameters4:
❑ No
Maximum Vent
Rate:
15 660
SCF/hr
Vent Gas
Heating Value:
2 640
BTU/SCF
Requested:
4.25
MMSCF/year
Actual:
3.54
MMSCF/year
-OR-
Requested:
N/A
Bbl/yr
Actual:
NhA
Bbl/yr
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Process Properties:
Molecular Weight:
46.84
VOC
(mole %)
74.2
VOC
(Weight %)
il
84.3
Benzene
(mole %)
0.146
Benzene
(Weight %)
0.244
Toluene
(mole %)
O. 101
Toluene
(Weight %)
0198
U.
Ethylbenzene
(mole %)
0.006
Ethylbenzene
(Weight %)
0.014
xylene
(mole %)
0.024
Xylene
(Weight %)
0.054
n -Hexane
(mole %)
0.715
n -Hexane
(Weight %)
1.315
2,2,4-
Trimethylpentane(Weight
0.067
2,2,4-Trimethylpentane
%)
U. 64
0 1
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)
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
3 eV
Winder South VRT
Permit Number:
AIRS ID Number: 123 / 9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.50800, -104.892373
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
CF)
Flow Rate
(ACFM)
Velocity -
(ft/sec)
N/A
Unknown
Unknown
Unknown
Unknown
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
0 Circular Interior stack diameter (inches):
❑ Other (describe):
❑ 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: VOC, HAP's
Rating:
Type:
Requested Control Efficiency:
MMBtu/hr
Make/Model:
95
Manufacturer Guaranteed Control Efficiency 98
Minimum Temperature:
%
Waste Gas Heat Content Btu/scf
Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0/0
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
4 I eV o.pnm.,n o�wy,c
N.al�� b Envin�nm.0
Winder South VRT
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ✓❑ Yes ❑ No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Requested Control
Efficiency
(% reduction in emissions)
PM
SOx
NOx
VOC
ECD
95%
CO
HAPs
ECD
95%
Other:
From what year is the following reported actual annual emissions data? 201 7
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
s
Emission Limit(s)
Uncontrolled
(Tons/year)
Controlled6
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SOX
NOx
VOC
104.15
Ib/MSCF
Promax
184.5
9.2
221.4
11.1
CO
0.31
Ib/MMBtu
AP -42
1.45
1.45
1.74
1.74
Benzene
0.301
Ib/MSCF
Promax
0.53
0.03
0.64
0.03
Toluene
0.245
Ib/MSCF
Promax
0.43
0.02
0.52
0.03
Ethylbenzene
Xylenes
.067
Ib/MSCF
Promax
0.12
0.01
0.14
0.01
n -Hexane
1.623
Ib/MSCF
Promax
2.87
0.14
3.45
0.17
2'2'4
Trimethylpentane
0.203
Ib/MSCF
Promax
0.36
0.02
0.43
0.02
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.
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
®® COLORADO
5 =e=
Winder South VRT
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave plank uness APCD has already assigned a permit d 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.
7
Suture of egally'Authorized Person (not a vendor or consultant)
Josh Carlisle
3- /3-/7
Date
EHSR Manager
Name (please print)
Title
Check the appropriate box to request a copy of the:
0 Draft permit prior to issuance
0 Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
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
Form APCD-211 Gas/Liquid Separator APEN - Rev 02/2017
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
6[
AY
COLOR ADO
Gas/Liquid Separator APEN - Form APCD-211
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for Gas/Liquid Separators only. If your emission unit does not fall into this category, there
may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number:
1'7INE0129
AIRS ID Number: 123 / 9CAA/ 013
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Company equipment Identification: Winder South Produced Gas Combustion
[Provide Facility Equipment ID to identify how this equipment is referenced within your organization]
Section 1 - Administrative Information
Company Namel:
Site Name:
Extraction Oil & Gas, Inc.
Winder Production Facility
Site Location: NENE Sec 9 T6N R67W
Mailing Address:
(Include Zip Code) 370 17th Street, Suite 5300
Denver, CO
E -Mail Address2: jarlisle@extractionog.com
Site Location
County: Weld
NAICS or SIC Code: 211111
Permit Contact: Josh Carlisle
Phone Number: 720-481-2372
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
359841
Form APCD-211 - Gas/Liquid Separator APEN - Rev 02/2017
ft 21 "97 J I COLORADO
1 Ie� „°ini°°t:Ltt
Winder South Produced Gas
Permit Number: AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
El NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
El Change permit limit ❑ Transfer of ownership3 El 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: Collocated with Winder North Produced Gas point source,
No shared equipment, please issue same permit number.
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:
will be combusted with ECDs.
If unable to compress into sales line, Produced gas from separators
For existing sources, operation began on:
For new or reconstructed sources, the projected
start-up date is:
/ /
05/10 /2017
Estimated, Refer to NOS
0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation:
N/A hours/day N/A days/week
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
N/A
weeks/year
2 Yes ❑ No
El Yes El No
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
e a�•�� w�`.,i�inn a u. u��.��
Winder South Produced Gas
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Process Equipment information
If you are requesting uncontrolled VOC emissions greater than 100 tpy you must use Natural Gas Venting as a process
parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? 0 Yes
Natural Gas Venting
Process Parameters4:
Liquid Throughput
Process Parameters4:
❑ No
Maximum Vent
Rate:
59,068
SCF/hr
Vent Gas
Heating Value:
2 077
,
BTU/SCF
Requested:
4.25
MMSCF/year
Actual:
3.54
MMSCF/year
-OR-
Requested:
N/A
Bbl/yr
Actual:
N/A
Bbl/yr
4 Requested values will become permit limitations. Requested limit(s) should consider future process growth
Process Properties:
Molecular Weight:
37.394
VOC
(mole %)
46.09
C
(Weigho )
63.6
Benzene
(mole %)
.071
Benzene
(Weight %)
.148
Toluene
(mole %)
.052
Toluene
(Weight %)
. 1 28
Ethylbenzene
(mole %)
.004
Ethylbenzene
(Weight %)
.010
Xylene
(mole %)
.0011
Xylene
(Weight %)
.037
n -Hexane
(mole %)
.354
n -Hexane
(Weight %)
-815
2,2,4-
Trimethylpentane
.035
2,2,4-Trimethylpentane
(Weight %)
. 1 07
Additional Required Information:
Attach a representative gas analysis (including BTEX a n -Hexane, temperature, and pressure)
Attach a representative pressurized extended liquids analysis (including BTEX It n -Hexane, temperature, and
pressure)
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
3 Al
H.unn b L.wnnm.a�
Winder South Produced Gas
Permit Number:
AIRS ID Number: 123 / 9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.50800, -104.892373
Operator
Stack ID No.
Discharge Height
Above Ground Levet
(Feet)
Temp.
CF)
Flow Rate
(ACFM)
Velocity
(ft/sec)
N/A
Unknown
Unknown
Unknown
Unknown
Indicate the direction of the stack outlet: (check one)
✓❑ Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
E Circular Interior stack diameter (inches):
❑ Other (describe):
❑ 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: VOC, HAP's
Rating:
Type:
Requested Control Efficiency:
Manufacturer Guaranteed Control Efficiency
Minimum Temperature:
MMBtu/hr
Make/Model:
95
98
%
%
Waste Gas Heat Content
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating
Btu/scf
MMBtu/hr
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency
Requested
0
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
COLORADO
4 I AY �«
Nuli� F Frvomnm.ni
Winder South Produced Gas
Permit Number:
AIRS ID Number: 123 /9CAA/
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? 0 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
NO,,
VOC
ECD
95%
CO
HAPs
ECD
95%
Other:
From what year is the following reported actual annual emissions data? 201 7
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
5
Emission Limit(s)
Uncontrolled
(Tons/year)
Controlled'
(Tons/year)
Uncontrolled
(Tons/year)
Controlled
(Tons/year)
PM
SOX
NO,,
VOC
62.67
Ib/MSCF
Promax
111.0
5.6
133.2
6.7
CO
0.31
Ib/MMBTU
AP -42
1.14
1.14
1.37
1.37
Benzene
0.146
Ib/MSCF
Promax
0.26
0.01
0.31
0.02
Toluene
0.126
Ib/MSCF
Promax
0.22
0.01
0.27
0.01
Ethylbenzene
Xylenes
n -Hexane
0.803
lb/MSCF
Promax
1.42
0.07
1.71
0.09
2,2,4-
Trimethylpentane
0.105
Ib/MSCF
Promax
0.19
0.01
0.22
0.01
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
5 ACOLORADO
- �� � N
Winder South Produced Gas
Permit Number:
AIRS ID Number: 123 / 9CAA/
[Leave blank unless APCD has aireativ assigned a permit t ana AIRS !DI
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete, true
and correct.
Si ature of egally Authorized Person (not a vendor or consultant)
Josh Carlisle
Date
EHSR Manager
Name (please print)
Title
Check the appropriate box to request a copy of the:
0 Draft permit prior to issuance
0 Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
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
Form APCD-211 -Gas/Liquid Separator APEN - Rev 02/2017
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
I AV COLORADO
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