HomeMy WebLinkAbout20190633.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
January 24, 2019
Dear Sir or Madam:
On January 31, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for
Outrigger DJ Operating LLC - Makena Gas Plant. A copy of this public notice and the public comment
packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Clara Gonzales
Regards,
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
C-Ct PLC ), LI-IC JT),
Pt,v(ERICHI Smictc)
Oaroco/19
Ptyt3k,c, RzV 2c,�
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2019-0633
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Outrigger DJ Operating LLC - Makena Gas Plant - Weld County
Notice Period Begins: January 31, 2019
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: Outrigger DJ Operating LLC
Facility: Makena Gas Plant
Natural Gas Processing Plant
NESE of Section 25, Township 8N, Range 62W
Weld County
The proposed project or activity is as follows: The operator is requesting permit coverage for one (1) 60
MMscf/day MDEA natural gas sweeting unit, one (1) plant flare, one (1) 10.9 MMBtu/hr amine regenerator
reboiler, fugitive emissions and two (2) 400 barrel fixed roof crude oil storage vessels at a new synthetic
minor natural gas processing facility located in the ozone non -attainment area.
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 18WE0503 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Comments may be submitted using the following options:
• Use the web form at https://www.colorado.Rov/pacific/cdphe/air-permit-public-notices. This page
also includes guidance for public participation
• Send an email to cdphe.commentsapcd@state.co.us
• Send comments to our mailing address:
Harrison Slaughter
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
Colorado Air Permitting Project
006
004
PRELIMINARY ANALYSIS - PROJECT SUMMARY
Project Details
Review Engineer: Harrison slaughter
Package #: 376422
Received Date: 5/9/2018
Review Start Date: ';9/11/2018
Section 01- Facility Information
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
Physical
Address/Location:
County:
Type of Facility: ' Natural Gas Processing Plant
What industry segment? Oil & Natural Gas Production & Processing
Is this facility located in a NAAQS non -attainment area? Ye
If yes, for what pollutant? ❑ Carbon Monoxide (CO)
Outrigger 0) Operating LLC
123
9FC0
Ma kena Gas Plant
NESE quadrant of Section 25, Township 8N, Range 62W
Weld County
Section 02 - Emissions Units In Permit Application
El
Particulate Matter (PM)
El
Quadrant
Section
Township
Range
NESE
25,
RN
62
Ozone (NOx & VOC)
AIRS Point #
Emissions Source Type
Equipment Name
Emissions
Control?
Permit #
Issuance #
Self Cert
Required?
Action
Engineering
Remarks
002
Amine Sweetening Unit
Process Flare
Amine Sweetening
Unit
FS -1761`:'.
Yes
No
18WE0503
18WE0503
1
'Yes
Yes
Permit Initial
Issuance
Permit Initia€.
Issuance
NG Heater
H-781
No
18WE0504.XP
APEN Required?
/ Permit
Exempt
NG Heater
Amine Reboiler
No
18WE0503
Permit Initial_
Issuance..
NG Heater
No
18WE0505.XP
Yea
APEN Required
/ Permit
Exempt
ugitive Component Leaks
Fugitives
18WE0503
1
Permit Initial
Issuance':
Permit Initial✓
Issuance
009
Crude Oil Tank
Slop Tanks
Yes
18WE0503
1
Yes
Section 03 - Description of Project
Outrigger DJ Operating LLC (Outrigger) submitted an application requesting permit coverage -for a new 60 million standard cubic feet per day cryogenic natural gas processing
facility located in the ozone non -attainment area. The operator is requesting permit coverage for the following equipment at the facility:
1.One (1) 60 MMscf/day MDEA natural gas sweetening unit.
2. One (1) plant flare used to combust residue during compression downtime.
3. One (1) 10.9 MMBtu/hr amine reboiler.
Fugitive emissions
5. Two (2) 400 barrel crude oil storage vessels
It should be further noted thatthe application also includes one (1) 10 MMBtu/hr hot oil heater and one (1) 5.542 MMBtu/hr mole sieve regenerator gas heater: These
sources are APEN required and categorically permit exempt based on Regulation 3, Part B, Section II.D.1:e.This section of the regulation exempts the following equipment
from obtaining a permit: "Each individual piece of fuel burning equipment, other than smokehouse generators, that uses gaseous fuel, and that has a des ign rate less than or
equal to ten million British thermal units per hour."
' Addi€ionally, this application includes APENs for two (2) residue compression engines and one (1) inlet compression engine. These engines are obtaining GPOZ
coverage (package #376438 & 388617) and are thus not addressed in this preliminary analysis.
This permit will require public comment because new synthetic minor limits are being established to avoid other requirements. Additionally, to
emissions of NOx and VOC are greater than 25 tpy, and the projected controlled CO emissions are greater than 50 tpy:
Section 04 - Public Comment Requirements
Is Public Comment Required?
If yes, why? RaquestingSyntheticMinorPerhnit
projected controlled a
Section 05 - Ambient Air Impact Analysis Requirement
Colorado Air Permitting Project
Was a quantitative modeling analysis required?
If yes, for what pollutants?
If yes, attach a copy of Technical Services Unit modeling results summary.
Section 06 - Facility -Wide Stationary Source Classification
Is this stationary source a true minor?
Is this stationary source a synthetic minor?
If yes, indicate programs and which pollutants:
Prevention of Significant Deterioration (PSD)
Title V Operating Permits (OP)
Non=Attainment New Source Review (NANSR)
Is this stationary source a major source?
If yes, explain what programs and which pollutants hers 5O2
Prevention of Significant Deterioration (P5D)
Title V Operating Permits (OP)
Non -Attainment New Source Review (NANSR)
5O2 NOx CO VOC PM2.5 PM10 TSP HAPs
J
J
CO VOC PM2.5 PM10 TSP HAPs
❑ ❑
Amine Unit Emissions Inventory
salon 01-AanINadeHe Mamelon
INwtyuu lo:
Seaton 02 rea , DesceNlm➢�ade na �heTy c
Malw
Serial Number:
Oetlan Comas
fleelecuisa FM, Mfanaaan
Number of Pumps
Purnp Ty,
0eap:/Nor P¢FcvMmn Pas
Amine Equipment FlashTank
Peboler stmangGae
Amine Lint EgWpnnt➢.4.Pmn
and raboler homer
One (1) Mmmrvdahenobmina{M0En1 neturalt6eweetenhg unit lmeYa:oleWn vmceee5wten4ttC. Move: T00, 500 Rumba: ta0)ran a
dasIgn Lathy oleo Mwa per day. This anisgons unitlaemlpped whhylMak.;P0apwab.MnaN:NP53655001elerttlmnriven amimvumplal
eha0Npnaom0y of 14.6.1 Nens per minute. T. a.m. wk is oguippa with a a. vont. naentana-eM reboil.' burner.
ere roan. to en•irKws, lea modemand then to the Thermal Oxidizer. Emlalem from the neon [amore mu•aairs.
EmaaeoCo t.Devlce0er p . tot., dn.-looprynemm
005Ernhtiaa.-eCoa.Oohswyntarun la0000al
Pegoetm PotmklM[throughput= __ _ _ a, l
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smmavE.Naaaa-Co :mntfoo 0...(atforAl.wtulaamrtml
Rill Vent Control
Condemeranission reduction claim.
Ncle e
uN vertc Henke, Value:
opera..VA Vent Wase6aa Vent Pato
Mesh kmntml
Primary control clavicle Primary con.t.evIce smwrycwt. ewQ remit.gash Yankees Heating Value
05* MMadvevear
,000 cf per year
➢u gp w�ea
StIll Vent Pnm.tpwnwk 21.900.0 0145‘1/yr
stmvent ndanlronra: 0.0 Mk4scf/yr
ant Prmw*03300 49,30 MMael/yr
SMl vans seronaar5 050: [wow MMsnhr
sour Gas Fromm.
Raft, Tank Prtrna,Control: 21.000.0 maMNr
Namnnk Eewndw Controt Vizata�MSMNr
�0 M
Flash Tank Pr., rant. 0.0 MAIscflyr
Nash rank .condan, Cannot cum MMan/yr
Mot Fuel 11se Rate:
Hot Fuel Hearing Value
MalstGas Healing Value
1087.47
Stuiscf
5.ymw Emlmons Factors O M0odao..
TIu. usm PmM.. raernzto 2-
iyh pw
34a -W Ikry nas/s3(zmlTho
Input Parameters
mietea Input Temperature
Lean Mane Pressure
Lean Mane Ten.rature
Requested lean PnlIne 5 an re ulaae Rate
Poah Tank Pressure
!MEP weight %(teen cannel
Pipear1. weight%(Lean Arninej
Inlet NaWNflN%
XP Inet000w05011
STILL VENT
am c
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ea uhNi
Controlled
tied ubmrl
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um
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=.c(sour 4L5030.5ml
(mm iced sneml
IM
ss Mser/ve,
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ml Xen
Prl ea
control scenario
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0
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0
0
sox Emission cantle*
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Amine Unit Emissions Inventory
Sectim 05- Inventory
Old opratorFmumta mxmn
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Crlter,3 Pollutants
91.110
VCC
502
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immmmr)
0.02
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le v .,l
0.02
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0.02
0.02
026
0.02
026
022
125.75
9.13
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277
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3.02.6-06
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xylme
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n-Nerane
220 IMP
UncentOled
139
6.16
035
129
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oomnvn (tons/v.,1
0.57
0.30
Mounted Permit..
wrnea'l mn�u0
0.67
020
6.02
0.06
260,765. 556691.5455
onammaee con..
27616.18
1696.23
699.69
3927
12229
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129
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293660
78.637
0.1073
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6.376.5
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0.1098
2.20
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0,1
2.20
219.60
Process= Combustion or TO ASsIstGas-and Kat Fuel
CAL.. Pollutan6
VOC
Paten., ,to Emit
Im�,mm�
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023
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629
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-
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xeQumtee Pemnaume
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x..9sssuepart0000
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kwuy gpm upda th450reitect Pn use, m lmm,44002rzal 0,r, pami aml t.dymwoum5M1e Inhere the 4100,efle. 3ezua7Mn race 205S' 3040/stmutatkn would needmbe uodeed
rm a...en2 do son rem 04143 v epin377150nnwre'aase3conamanr Please update meuata
pct rY.e 1 tuna weg o eta5itWe tf x82 teozerEnH rPy n FameagoalsNlri w�er,houMete has been 'maces requester, Iltecoemlore,es.d.ey. narumner
Section os- inventoro, rmbw aM EMsma Paton
.14 SPotnt
SCC Code
Pollutent Rmiadana Factor na unite
5010 0078 CO.0/030335
b/MM027
00C 113 9.854b/MM02r
CO 0.865 0.0%b/MM.'
Bann. 1.70 95.2%b/MM02r
Toluene OS. S5.1%b/038227
Ethylbenzene 921.‘ m/MM305
Mylene 0_119 95.1%b/08307
n-lierone 0.0.3693.3% b/M8%I
ae4TMa 95.4% b/MM¢
025 0.101 95.0%b/038027
401 _3771 o0o% le/03824
PNI10 0.1027 0.00%
b/00307
5M25 01025 OM% 40.4,e1.5
200 :06.6147 0.00% aMMacr
vac 51.1355,779 b/kI/Vocf
CO SO3S66 5/00x5
MArlsof
/MM.
Ebmleeoene b/MMan
.Olen 5010303x5
mllexene 0.73.09 05.o.77/0303,[5
aeiMc 531E.b/0303x7
KS 1.10,02 /11,x0
Methanol 633,06 ANAsef
wa 6.40,01 7750% b/0303x5
Amine Sweetening Unit Regulatory Analysis Worksheet
Colorado Re ulation 3 Parts A and B - APEN and Permit Requirements
Source is in the Non -Attainment Area
ATTAINMENT
1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2, Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY Regulation 3, Part B, Section 11.3.3 ?
You have indicated that source is in the Non -Attainment Area
NON -ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section
2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 Thy or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2 ?
Source requires a permit
NSPS Analysis
1. Isthe sweetening unit located at an onshore natural gas processing plant that processes natural gas produced from either onshore or offshore wells?
'Source is subject to NSPS- Continue to determine applicable sections
40 CFR, Part 60, Subpart LLL, Standards of Performance for SO2 Emissions from Onshore Natural Gas Processing
1. Did construction or modification (see definitions 40 CFR 60.2) of the sweetening unit commence after January 20,1984 and on or before August 23, 2011 (60.640(d))?
2. Does facility have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H25) in the acid gas (expressed as sulfur) (60.640(b))?
3. 'You ltuve Indicated that this facility is not subject to fdopS
Subpart A, General Provisions
§60.642 - Standards for sulfur dioxide
§60.646 - Monitoring of emissions and operations
§60.647 - Recordkeeping and reporting requirements
40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution
1. Did construction, modification or reconstruction (see definitions 40 CFR 60.2) of the sweetening unit commence after August 23, 2011 and on or before September 18, 2015?
2. Does facility have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) (60.5365(g)(3))?
'You have indicated ih
Is not svli(t :t to NSPS 0(li)(
Subpart A, General Provisions per §60.5425 Table 3
§60.5405 -Standards for sulfur dioxide
§60.5407- Monitoring of emissions and,operations
§ 60.5423 - Notification, Recordkeeping and reporting requirements
40 CFR, Part 60. Subpart 0000a, Standards of Performance for Crude Oil and Natural Gas Facilities
1. Did construction, modification or reconstruction (see definitions 40 CFR 60.2) of the sweetening unit commence after September 18, 2015?
2. Does facility have a design capacity less than 2 long tons per day (LT/D) of hydrogen sulfide (H21) in the acid gas (expressed as sulfur) (60.5365a(g)(3))?
' lit I. is'xmbject to NSPS OOOO0- Recordkeeping and Report€ng tiegrrifentant f tr 60.54'30(c)
Subpart A, General Provisions per 460.5425a Table 3
460.5405a - Standards for sulfur dioxide Do Not Apply
560.5407a - Monitoring of emissions and operations Do Not Apply
460.5'4236(c) - Recordkeeping and reporting requirements
Coloraation 3 Parts 8, Section III.D.2.a - RACT
Source is subject to RACT
Source Requires an APEN. Go to the next question
Source Requires a permit
Source Requires an APEN. Go to the next question
Source Requires a permit
'Yes 'You have indicated the facility type on the Project Summary Sheet
1 • The unit Is not subject - Go to Subpart 0000
N'• The unit is not subject - Go to Subpart 00(iba
Yg , The unit is subject - Go to question 2 -
Disclaimer
This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control
Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and
circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event
of any conflict between the language of this document and the language of the Clean Air Act„ Its implementing regulations, and Air Quality Control
Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is
intended to describe APCD interpretations and recommendations. Mandatory terminology such as must" and "required" are intended to describe controlling
requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in
and of itself.
Plant Flare Emissions Inventory
Section 01 -Administrative Information
'Facility AIRs ID:
123
County
9100
002
Point
Section 02 -Equipment Description Details
Detailed Emissions Unit Description:
e_(Make: B0O6,EEGU-24)
Thsso rce serves as the trl devic tor resdiueg durIng residue c= mpress01 do
Emission Control Device Description:
Requested Overall VOC& HAP Control Efficiency %. 95
Limited Process Parameter
Gas meter
Section 03 - Processing Rate Information for Emissions Estimates
ti"sR`; MMscf per year
1 Requested Permit Limit Throughput ='i;
7248$: MMscf per year
Requested Monthly Throughput = 12.64 MMscf per month
Potential to Emit (PTE) Throughput =
Purge Gas Flow Rate =
Pilot Light Flow Rate=
Purge & Pilot Light Throughput =
Process Control (Recycling) -
Equipped with a VRU:
Is VRU process equipment:
149 MMscfper year
acy//hhr
5.694 MMscl per year
scf/bbi
Description
IThis flare is used to control residue gas durIngres due ga., compression 4 hint no m ssicns for this source were calculated cased cc vudue gas compos tlon and beat co
RESIDUE strea m). The ProMaxsmulation is based on a representativesales gas sample obtained from acopupstrearr.,acilty (He verger 3-26--34-8-601 on 09/13/2012:..:
Weight %
Helium
CO2
N2
Hydrogen
Oxygen
Hydrogen Sulfide
methane
ethane
propane
isobutane
n -butane
isopentane
n -pentane
cydopentane
n -Hexane
cyclohexane
Other hexanes
heptanes
methyicyclohexane
224-TMP
Benzene
Toluene
Ethylbenoene
Xylenes
Methanol
COO Heavies
:45
193
1.358120E-03
0.02
3.788760E-05
75.85
9.86
704820E-01
7.413060E-03
7.413060E-03
L327500E-02
2.473890E-04
883780E-04
165520E-05
172170E-06
4.619360E-07
0.000000E-000
2.503880E-08
637360E-08
--:9.589730E•11
6.872120E-07
1.731600E-08
5.260490E-11
.036352E-30
01750E-08
3.301888E-05
Total
VOC Wt %
100.00
0.8916529
b/Ib-mol Displacement Equation
Ex=4•MW'Xx/C
Pollutant
Separator Venting
Uncontrolled
Controlled
MIIMMELIMISMIMIEMI
MINEWEIMENIMMIMMIre
Emission Factor 5ouace
Pollutant
INICEMMIM
Primary Control Device
Uncontrolled
(Ib/MMBtu)
(Waste Heat
Combusted)
Uncontrolled
lb/MMscf
0.0075
0.0075
0.0005
0.0680
0.3100
(Gas Throughput)
Emission Factor Source
0.640
MIMTIIZMINM
7 of 18
K:\PA\2018\18 W E0503.CP1.xlsm
Plant Flare Emissions Inventory
Section 05- Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Umlts
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
PM2.5
SOx
NOx
M VOC
CO
0.63
0.00
0.00
0.63
0.63
106.32
0.63
0.00
0.00
0.63
0.63
106.32
0.05
0.00
0.00
0.05
0.05
8.39
5.71
0.00
0.00
5.712
5.71
970.30
32.92
0.00
0.00
. 32.92
1.65
279.57 -
' 26,04'
0.00
0.00
26.04
26.04
4423.43
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(Ibs/year)
Actual Emissions
,Uncontrolled Controlled
(Ibs/year) (Ibs/year)
Requested Permit Limits
Uncontrolled Controlled
fibs/year) fibs/Veer)
Benzene
Toluene
Ethylbenzene
Xytene
n -Hexane
224 TMP
Methanol
Hydrogen Sulfide
- 0.0507
0.0000
0.0000
0.0507
0.0025
0.0013
0.0000
0.0000
1.28E-03
6.39E-05
0.0000
0.0000
0,0000
3.89E-06
1.94E-07
0.0000
0.0000
0.0000
7.65E-06
3.83E-07
0.0866
0.0000
0.0000
8.66E-02
4.33E-03
0.0000
0.0000
0.0000
7.08E-06
3.54E-07
0.0008
0.0000
0.0000
8.14E-04
4.07E-05
2.7978
0.0000
0.0000
2.7978 -
0.1399
Section 06 - Regulatory Summery Analysis
„-,
Regulation 1
Section 11..,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% opadty. 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 IIA,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 fora period or periods aggregating more than six
minutes in any sixty consecutive minutes.
Regulation 2
Section LA - 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
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 re 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 fadlity are greater then the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.2.a)
Regulation 7
Section XVII.B.2: Based on the Information provided by the operator, this source is not intended to control emissslans from any equipment subject to Regulation
7 Section XVII. As a result, the flare is not subject to this portion of the Regulation.
(See regulatory applicability worksheet for detailed analysis)
Section 07- Initial and Periodic Sampling and Testing Requirements
Using Gas Throughput to Monitor Compliance
Does the company use site specific emission factors based on a HE sample to estimate emissions?.'s'9
This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if
the facility has not been modified (e.g., no new wells brought on-line), then it may he appropriate to use an alder site -specific sample.
Ono, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis
to demonstrate that the emission factors are less than or equal to the emissions factors established with this application.
Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? „y
If yes, the permit will contain:
-An"Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the
emission factors are less than or equal to the emissions factors established with this application.
-A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the
emission factors are less than or equal to the emissions factors established with this application on an annual basis.
Will the operator have a meter installed and operational upon startup of this point? Yes
. If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to
exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03.
Does the company request a control device effidency 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
80118
K:\PA\2018\18 WE0503.CP1xlsm
Plant Flare Emissions Inventory
Section 08 - Technical Analysis Notes
1. According to she operator thls flare Is Intended to be used to combust residue gat Curlrg ten dtte compression downtm : The flare will ago be used to combtp
only ,erns Using foreseeable events associatedwith residue compresOon downtime eased on this lnformatioie it was da erminedthc_ es du.. gas composti.n fron
emissions ss ated with tnecombustIon of residue gas
] The operator pressed she thoured throughout for thesource was determines oased on two days or res ie compression downtime,
3. The OeeM.plan provided inthe .pplcatiott indicates a flow meter at the it os'o he pen flare e resthe sofa. e degas sea tdectly to the flare,'
the volume of gas {both residue and purge) routed to the fare in order to den•on. are n mpuanca wtth ene perms cots..
�l1
4 he em_unlo tedwdh this source Were determned using th.read m the Pmorazsmulation The P sfa'ao simulation Is sed one reo_entative gas mp'e.ht was ob.a d from an ups₹rearnfaci ity,a more
h .one ye.orp r o apol :anon submittal. Since the sample s representative rather than sitespecr'c, Nth penult will include initiagtesting that requirs -fie operator 70 obtain a qte specific sampe of re':._ gas toco"hren the emission
conservative. In the . event the. ore co nsery -msdon factor will oe required to mco.-Incpermit for resent the newly developed emission factors.
., tie:.... u- gem MN analys are accurate or sample results ,vim s. the operator Y V
5 As discussed in the regulatory summary analy s section) this flare not subsublect to Regulation 7, Section XVII because Nis notintended to control emiseons from any equipment than is subfoct to the portion of the Regulation. However,,,
.he operator stall provides the alternative emiss on control equipment request form This o m provides some additional data Is regatiegtles flareincluding: I l The Rare has a manufactuierguaranteed des'auct on efficiency of98%
omen flare is intended ID operate with no visible emisoons clueing normal operation. (ill) Tne flare isadequately designed and sued Coach e re the control efficiency rated and handle foreseeable fluctuations m emissions o. VOC and
hyd ocortmns du ng'loran ai operas on (v):The flare will re designed such that eon observer can, by means of visual observatnn from the outside of the flare determine uihea , r it is ope a.:ng properly. lvi The Mare will oe equipped with
-- -
auto -igniter.
Plant during upsets or em
simulation In t the appl Kato
Power
sapproprfa
6 4ccord,rigt he operator -:the pilot fuel the. to s _ant at 150 setthr: 00 esult the opere0vi I Crank the
ourgeandsaee gas nordertoodefi n ra' compliance with the permitted prose linftof _545MMscf/yea,.
7. The operator pr de_ draft p -m no APEN t eve to pubic men[ The opera
with thp'APEN dl ea d
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point a
002
Process# SCC Code
3-10-001-60 Flares
epermit NMI -,sa contain a condition ndcatnga.8o dieter will to mea
ors of opera[ on p order to determines ie total n ibs.geu volume TI
al volume mil be induded with�'El
ev =_w=dthedcr:.,n mos and_xa__sed they had no coom_nts regarding the plant fix
he permit and that they agreedi
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 8.10 0 lb/MMSCF
PM2.5 8.10 0 lb/MMSCF
50x 0.64 0 lb/MMSCF
NOx 73.95 0 lb/MMSCF
VOC 426.13 95 lb/MMSCF
CO 337.12 0 Ib/MMSCF
Benzene 3.28E-04 95 lb/MMSCF
Toluene - 8.28E-06 95 lb/MMSCF
Ethylbenzene 2.52E-08 95 lb/MMSCF
Xylene 4.95E-08 95 lb/MMSCF
n -Hexane 5.60E-04 95 lb/MMSCF
224 TMP 4.58E-08 95 lb/MMSCF
Methanol 5.27E-06 95 Ib/MMSCF
Hydrogen Sulfide 1.81E-02 95 lb/MMSCF
9 of 18
K:\PA\2018\18W E0503.CP1xlsm
Natural Gas Heater Emissions Inventory
004 NG Heater
Facility AIRS ID:
County
Plant Point
Section 02 - Equipment Description Details
Heater Information
Fuel Type
Number of Heaters
Purpose
Make:
Model:
Serial Number.
Design Heat Input Rate:
Equipped with Low-NOx burners:
Equipped with Add -On Control Equipment:
Natural Gas
.One (1)
MMBtu/hr
One (1) natural gas heater(s) (Make: TBD, Model: TBD, Serial Number: TBD) each with a design heat input rate of 10.9
MMBtu/hr. Each unit is an amine regeneration heater.
Detailed Emissions Unit Description:
Emission Control Device Description:
Requested Overall VOC & HAP Control Efficiency
Section 03 - Processing Rate Information for Emissions Estimates
Design Heat Input Rate =
Heat content of waste gas=
Actual Hours of Operation =
Requested Hours of Operation =
Requested heat input rate =
Actual Fuel Consumption =
No add-on control equipment
10.9 MMBtu/hr
;::-1087: Btu/scf
&�fifti hrs/year
476tt: hrs/year
95,484.00 MMBTU per year
87.80 MMscf/year
Requested Fuel Consumption =
87.80 MMscf/year Requested Monthly Throughput = 7.46 MMscf per month
Potential to Emit (PTO) Fuel Consumption =
Section 04- Emissions Factors & Methodologies
87.80 MMscf/year
Emission Factors
Pollutant
PM10
PM2.5
SOx
NOx
CO
VOC
Formaldehyde
Benzene
Toluene
n -Hexane
Uncontrolled
Ib/MMBtu
(Fuel Heat
Combusted)
0.00745098:.:;:'.
8:00745098
0.0 085 88 2 35 :
0',098039216'."x:
0:005392157".:'.
.•I:,058.82E00iiiiill
0,001764708:,
Uncontrolled
Ib/MMscf
(Fuel
Consumption)
106.6147059
0079961029
0.002238909
0.0036249
.919064706
Emission Factor Source
Section 05 - Emissions Inventor/
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Requested Monthly Limits
Controlled
(lbs/month)
PM10
PM2.5
SOx
NOx
CO
VOC
0.36
0.36
0.36
0.36
0.36
60.42
0.36
0.36
0.36
0.36
0.36
60.42
0.03
0.03
0.03
0.03
0.03
4.77
4.68
4.68
4.68
4.68
4.68
795.06
3.93
3.93
3.93
3.93
3.93
667.85
0.25
0.26
0.26
0.26
0.26
43.73
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(lbs/year)
Actual Emissions
Uncontrolled Controlled
(lbs/year) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(lbs/year) (lbs/year)
Formaldehyde
7.02
7.02
7.0Z
7.02
7.02
Benzene
0.20
0.20
0.20
0.20
0.20
Toluene
D.32
0.32
0.32
0.32
0.32
n -Hexane
168.50
168.50
168.50
168.50
168.50
Regulation 3, Parts A, B
Source requires a permit
Regulation 1, Section VI
Based on the requested emissions and emission factor, compliance is presumed.
Regulation 1, Section III & Regulation 6, Part B, Section II
Based on the design heat input rate, the source is subject to Regulation' Section I II.A.1.b. and Regulation 6, Part B, Section II.C2. and 3. Based on the
requested emission factor, compliance is presumed.
Regulation 6, Part A, Subpart lb, 302 Standards
Source is not subject to NSPS Db.
Regulation 6, Part A, Subpart lb, NOx Standards
Source is not subject to NSPS Db.
Regulation 6, Part A, Subpart Dc
Source is subject to NSPS Dc,
Regulation 7, Section XVI.0
Source is not subject to Regulation 7, Section %VIA.
Regulation 8, Part E, MACT Subpart DDDDD
Source is not subject to MACT DDDDD.
10 of18
K:\PP.\2018\18 W E0503.CPLxlsm
Natural Gas Heater Emissions Inventory
(See regulatory applicability worksheet for detailed analysis)
Section 07- Initial and Periodic Sampling and Testing Requirements
Is the project close to the 40 tpy modeling./ NANSR threshold for NOx?
If yes, stack -testing should be required for NOx, as well as for CO.
Is the operator limiting their heat input rate below the design rate?
If yes, stack -testing should he required far NOx, as well as for CO.
Is the project close to the 5 tpy modeling threshold for PM 2.5?
If yes, stack -testing should be required for PM 2.5
Does the company use AP -42 emission factors (or more conservative factors)?
If no and testing hasn't already been required due to proximity to modeling thresholds, testing should he required for any polfutantsfor which alternative emission factors
have been used. If testing is being done for only NOx or only CO, the other should be included as well.
Section 08 Technical Analysis Notes
The s ctorsfrom AP -42 Chareer 1A are b d rage l as higher heating al 1;020 Bt / cf Ei .e the th r.. f 1 terpTbase at78 t vaige f 1,087:47Btu/ cf, the
given emission factorswere convertedtnthe sue spec Ts h..atmg values Itiplyin the given facto rsby the ralo of the s pecfied nesting aIue to the eohrg�
y mu g g average heaC(vafireF e'ezzmpie,tfie CO emission factor
was converted using the fdlloW ng equation. CO em is factor (84 lb/MMsof)' (1,087.47 Btu/scI)f(1,020 Btu/scf).= 89.5A lb/MMscf. This same. co vcra on t' conducted iOrRhe tend coin emission factors in Section 04
above.
2. The operas i expressed the amine redo ler is not equipped with low Nov burners. Asa result, RACT for this sou-.ce is the use 0f natural gas as fuel and good. -combustion pract ces::
3 Even though this source i., located inthe ozone non. att mans area, itwas determined Iow.NOx burnerswould not be required, In additonoo natural gas as fuel and good combustion practices, to satisfy RACY. This
decision was made because CO AOCC Regulation 7 Section;(VI.0 only requires heaters that have (400 emissions greater than 5. tp;and are located at existing majorsources of NOx in the ozone non attainment area to follow
combust on process adjustment prob.. (See Seriion %VI.O 5.) and maintain the equipment per "manufactures speoficationsth available, or good engineering and rnamtenance praci ces. This portion ofihe Regulation
does not require the use of low NOx bum ens by heaters that have higher NOx emissions and that arelocated at existing majorsources of NOx. The heater permitted here has Nov emissions less than 5tpy and it is located at
w synthetic e of NOx. Since low NOx burner- are not required for higher emitting sources of larger facilities inche non atta inment area,.It stands to reason that tow NOx burners mould not be required for -the
heater .permitted attft sfad Itty To reiterate, Ise of natural gas as fueland good combustion practices satisfy the RACT ra)wrements forthe amine regeneratmn render.
der
Section 09 - Inventory SCC Coding and Emissions Factors
AIRS Point #
004
Process # SCC Code
Pollutant
01 I3-10-00404: Industrial Process; Oil & Gas Production; Process Heaters; Natural Gas )MMscf) PM10
PM2.5
SOx
NOx
CO
VOC
Formaldehyde
Benzene
Toluene
n -Hexane
Uncontrolled
Emissions
Factor Control % Units
8.10 0 Ib/MMsef Burned
8.10 0 lb/MMscf Burned
0.64 0 lb/MMscf Burned
106.61 0 lb/MMscf Burned
89.56 0 lb/MMscf Burned
5.86 0 Ih/MMscf Burned
8.00E-02 0 lb/MMscf Burned
2.24E-03 0 lb/MMscf Burned
3.62E-03 0 Ih/MMsef Burned
1.9 0 lb/MMscf Burned
10 of 18
K:\PA\2018\18 W E0503.CP1.xlsm
Natural Gas Heater Regulatory Analysis Worksheet
Dosed on tire heater purpose Relocate In the Inventory, this Anil qualifies as fuel burning equipsneut per Colorado Regulations 1 & 6, a steam generating unit pen NSPS Eh & tic and
a Industrial: cornn.erciel nr Institutional boiler copra.. heater pee MACT DOOM
This unit fires natural got en defined by NSPS DD&Deand/ar is designed to barn gas 1 fuels as defined by MAC --WOOD
Colorado Regulation 3 Parts A and B-APFN and Permit Requirements
ISnuena in in the NoreAttalnntnni Area
ATTAINMENT
1. Are uncontrolled actual emissions of any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Does the heater have a design heat input rate less than or equal to 5 MMBtu/hr? (Regulation 3, Part A, Section II.D.1.k.)
3. Does the heater have a design heat input rate less than or equal to 10 MMBtu/hr? (Regulation3, Part B, Section ll.D.1.e.)
4. Are total facllit uncontrolled VOC emissions :reater than 5 TPY,NOx: realer than 10 TPY or CO emissions.: rester than 10TPY Re:ulation 3 Part B, Section 11.0
toot eough information
NON -ATTAINMENT
1. Are uncontrolled emissions of any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section 11.0.1.0)?
2. Does the heater have a design heat input rate less than or equal to 5 MMBtu/hr? (Regulation 3, Part A, Section II.D.l.k.(
3. Does the heater have a design heat input rate less than or equal to 10 MMBtu/hr? (Regulation 3, Part 6, Section II.O.l.e.)
4. Are total facility uncontrolled AOC emissions greater than 2TPV, NOx greater than 5TPY or CO emieaiensgreater than en TPY (Regulation 3, Part B. Section 11.0.2)?
ISouree requires a permit
Colorado Regulation 1. Section VI
1. Are sulfur dioxide emissions from the heater greater than 2 tons tier day? (Regulation 1, Section Vi.B.5.a.)
IRasod on the requested omissions and ernissinn farenr, compliance A presumed.
Section 11.5.5 - Emission Limits
Section 01.5.6 and 7 - Recordkeeping, Reporting, Data Retention
Colorado Regulation 1, Section III and Colorado Regulation 6, Part B. Section II. Standards of Performance for New Fuel -Burning Equipment
1. What is the design heat input rate of the heater? (Regulation 1, Section W.A. and Regulation 6, Part B, Section R.C.)
2 Does the source discharge particulate matter in excess of 0.5 lb/Mmbtu heat input? (Regulation 1, Section III.A.I.a. and Regulation 6, Part B, Section II.C.1.(
3. Does the source discharge particulate matter in excess of the following equation: PE=0.5(FI)1'tsl?(Regulation 1, Section ill.A.1.b. and Regulation 6, Part B, Section ll.C.2.)
4. Does the source dluharge particulate matter in excess of 0.1 Ib/Mmbtu heat input? (Regulation 1, Section IIIAl.c.)
Based on the design heat Input rate, the source is subject to Regulation 1 Section l[LA1,b. and Regulation 0, Pent B, Section il.C2, and 3. limed on the requested edtissian factor,
compilarua is pcasunred.
Colorado Regulation 7. Section MILD.
1. Dld the natural gas fired heater exist at a major source of NO0 as as otlune 3,2016? (Regulation 7 Section XVI.D.1.)
2. Does the natural.. s fired heater have uncontrolled actual emissions of NOxe•ual to or: water than 5t. ? Regulation )5 o XV1.D.6.a
Source is oat subject to Regulation Suction XVIA.
Section XVI.D.6.b. —Combustion Process'Adjustment
Section WI.D.7.—Recordkeeping
NSPS Analysis
1. Does the natural gas fired heater have a maximum design heat input capacity of 29 megawatts (MW) (100 MMBtu/hr) or less, but greater than or equal to 2.9 MW (IOMMetu/hr)? (660.40c(a))
2. Does the natural gas fired heater have a maximum design heat input capacity greater than 29 megawatts (MW) (100 MMBtu/hr(? (660.406(a))
'Evaluate questions in RIPS Dc section haircut.
Yes
No
6o to toe nee: question.
to the next question.
Source Requires an ?WEAL Ru to the rout question
Co to the next question.. e
tin to the nee: question.
Source Requires a Permit
Based un the requested emissions and emission fautar, complienm is presumed.
Go to question 3.
Rased on the requested emission factor, compliance. is pmsumad.
based on the requested emission factor, aempiiance is urea rued.
Based on the requested emission factor, Compliance is presumed.
Sterne ie not sublets to Regulation 7, Section WAX,
Gu to NSPS De applicability section
Source is noteobir:ct to NSPS nb.
40 CFR, Part 60, Subpart De. Standards of Performance for Smell Industrial -Commercial -Institutional Steam Generating Units
1. Dld construction,modification, or reconstruction of the steam generating unit commence after lune9, 1909?(§60:40c(a)( Sore is sub}
Source Is subject to NIPS tic -
Subpart A, General Provisions
660.48c -Reporting and Recordkeeping Requirements
P.S
90 CR. Part 60. Subpart Db, Standards of Performance for industrial -Commercial -Institutional Steam Generating Units
1. Did construction, modification, or reconstruction of the steam generating unit commence after June 19,1984? (§60.40b(a))
502 Standards
2. Does the natural gas fired heater have a potential 502 emission rate of 140 ng/1(0.32 Ib/MMBtu) heat Input or less? 1460.42b(k)121)
3. Did the affected facility c construction, reconstruction or modification after Februar 28, 2005? §60.42bk 1
'roam is notpsuhlnttto MPS Db.
Non Standards
4. Does the natural gas fired heater have a heat input capacity of73 MW (250 MM6tu/hr) or less? (460.44b1k))
5. Does the heater meetall of the following cd[ena?I§60.44b(k)i
5a. Combust, alone or in combination, only natural gas, distillate oil, or residual oil with a nitrogen content of 0.3 weight percent or less(§60,44b11)lllli
5b. Have a combined annual capacity factor of 10 percent or less for natural gas, distillate oil, and residual ail with a nitrogen contentof 0.30 weight percent or less l§60.44b01(2)); and
Are subject to a federally enforceable requirement limiting operation of the affected facility to the firing of natural gas, distillate oil, and/or residual oil with a nitrogen content of 0.30
weight percent or less and limiting operation of the affected facility to a combined annual capacity factor of 10 percent or less for natural gas, distillate of, and residual oil with a nitrogen
50. content of 0.30 weight percent or less. (460.44601(311
6. Did the affected facility commence construction, reconstruction or modification after July 09, 1997? )460A4b11))
Is the natural gas fired heater subject to and in compliance with a federally enforceable requirement that limits operation of the facility to an annual capacity factor of 10 percent (0.10) or less for
7. Coal, oil, and natural gas (or any combination of the three)? (460.44b(I)(3.)1
Does the natural gas fired heater have low heat release rate and combust natural gas or distillate oil In excess of 30 percent of the heat Input on a 30 -day roiling average from the Combustion of all
e. fuels? (460.44O1(2))
'Source is not subject to ts5P3 Ob.
§60.42b(k)(1) -Standard for sulfur dioxide (502)
460.44b1a) or (k) or (I); (h) and (I) or 0) -Standard for nitrogen oxides (NOx)
§60.45b - Compliance and performance test methods and procedures for sulfur dioxide
§60.46b -Compliance and performance test methods and procedures for particulate matter and nitrogen oxides
460.47b - Emission monitoring for sulfur dioxide
§60.46b -Emission monitoring for particulate matter and nitrogen oxides
460.46b- Reporting and recordkeeping requirements
MACE Analysis
40 CR. Part 63. Subpart MAR 09000. N0SHAP for Maier sources; industrial. Commercial. and Institutional Boilers and Process Heaters
1. Is the heater located at a facility that's a major source for HAPs? (463.7485)
2. Dld construction (463.7490(h)) or reconstruction (063.7490(c)) of heater commence after June 4, 2010?
3. Is the heat Input capacity less than or equal to 5 MMBtu/hr? (503.75001e1)
4. Is the heat input capacity greater than 5 MMBtu/hr but less than or equal to 10 MM8tu/hr? (§63.7500(e))
'Source Is oat subject to MALT 00000.
463.7500 (e) and Table 3 - Work practice standards
463.7505 (a) - General requirements
463.7510 (g) • Irlidal requirements for existing sources OR 16,9116 (al far new spumes
463.7515 Id) -Subsequent tests, fuel analyses or tune-ups
463.7530 (e) and (f) - Demonstrating Initial compliance
463.7540 (6)(10) and (6)1131 - Demonstrating continuous compliance
§63.7545 (a), (b -for existing or c - for new), (e), (e)11), e(6), e(7), eta) - NotiCcatlons
§63.7550 (a), )b), (a), (c)(1), h(3) - Reporting
463.7555 (a), (a)(1) and (2) and 63.7560 (a), (b) and (c)-Recordkeeping
Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control
Commission regulations. This document Is not a NIB or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts
and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the
event of any conflict between the language of this document and the language of the Clean Air Act„ As implementing regulations, and Air Quality Control
Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend,""may,"'should," and "can,"is
intended to describe APCD Interpretations and recommendations. Mandatory terminology such as °must" and 'required" are Intended to describe controlling
requirements under the terms of the Clean Air Act and Air Qualify Control Commission regulations, but this document does not establish legally binding requirements in
end of itself
leo to que.tion OS.
0006 aoas qn.
The unit in nut subject to MACT.
Au to next question.
The source must conduct o tuneup arvnunliy.
Fugitive Emissions Inventory
Section131 101005Ne Information
'Facility AIRS ID:
/43
Plant
Section 02 -Equipment Description Des.
Detailed Emissions Unit
oemription:
Emission Control Device
Description:
EeMon 03-Pra raaflat or Em ns Est
This section Is not appinmbk to fu
Section.' - Emissions Fallon & Methodologies
Regulation 7 Information
Operating Hour.
Emission Factor Source
Control Bide.), Source t <„ t3dhai-.
Calculations
Service
Component Type
I Count Emieib$Factor lKglnr-
Table 24 Table 2.8
control (%)
P's''''''' Mass
Fraction
Uneorm0um
Emissi000 ltpy(
Controlled
Emissions (VA
connectors
:247 ' 200E-04
100545
0.0%
VOC
0 366260228 i
8.664022616
8.664022616
Flange
243 ;'< 3.90E-04
5.70E-06
0.0%
Benzene
0.001449301
0035205397
0.035705397
Open -Ended Lute
Y00 200E-03
150E-05
0.016
Toluene
0.007111413
0.026997652
0.026997652
Gas
Pump Seals
U, 240E-03
3.50E-01-
0.0%
Ethylbelrzene
0.000'5333
0003846038
0.003646038
Valves
Other
4.50E-03
3,, 8.80E-03
250E-05
1.20E-04
0.0%
0.0% -
Xyknes
5.3exane
0.000405137
0.008133442
0009841305
0.198422032
0.009641305
0.198422032
Reid Valves
apt 8.80E03
120E-04
0.0%
2,2,4 -TOP
.501044E-00
000012171
0,00012171
_
—
—
—
—
Methanol
0
0
0
Connectors
32 750E-06
7.50E-06
0.0%
VOC
1
0.01179286
0.01179286
Flange
32 `� 3.90E-07
3.90E-07
0.0%
Benzene
0.0.617375
0.000148795
0.000148796
Open -Ended Lira.
140E-01
7.20E-06
0.0%
Toluene
a 0.907244
0000352569
0.000352659
Heavy 00Pump
Sean
83x 0.00E+00
000E+00
0.0%
Eth510010ee
0.003516766
030011223
0.00011223
Valve
32: 8A0E-06
8.40E-06
00%
Xylene
0.025590846 .:
0.000301709
0.000301789
Other
0 £ 3.20E-05
3.20E-05
00%
n-Hexene
0.06557117
0.000773272
0,000773272
Relief Valves
V5^j/j" —
—
—
2,2,4.TMP
0. 000110623
1.30466E-06
1.30456E-06
—
.{- —
—
—
Methanol
9000674894..,.
7.65893E-06
7.95993E-06
Connectors
133 -,: 210E-06
9.70E-0fi
0.0%
VOC
i
10.04876698
10.04876698
Flange
133;; 1.10E-04
240E-06
0.0%
Benzene
012611575
0.12678906
0.12678906
Open -Ended tines
(4 ;i 1.40E-03
140E-05
0.0%
Toluene
0 02.07844:
0.300536651
0.300536951
Light Oil
Pump Beals
32" 130E-02
5.10E-04
0.0%
Elhylberaene
0 00016765
0095631765
0.095631756
Valve
324' 250E'03
190E-05
0.0%
Xylene
002.350846
0.257156443
0.267158443
Other
'0 7.50543
110E-09
00%
nkleane
0.06557117-
0.568809412
0.658309412
Refs. Vales
0' „', 7.50E-03
110E-04
0.0%
2,2,4-TMP
0 003110623
0001111625
0,001111625
—
—
—
—
Methanol
:2.000674894
000676195
0.00570185
Connectors
307^ 110E-04
LOOS -05
0.0%
VOC "
-; 1
0.073301704
0.078301704
Flanges
30 : 290E-0fi
290E-05
0.0%
Benzene ,
0.012517375 .:
0000987%2
0.000987962
Open -Ended Line
4 : 250E-04
3 5072
00%
Toluene ,
0.03390(6344
0.002341935
0.002341835
Water/Oil
Pump Seals
1 4 3.40E-05
240E-05
0.0%
E1hylb ee
4,0(0+0746V
0.000746175
0.000745179
Valves
37 - 9.80E-05
9.70E4M
0.016
Xyane
0.026590848
0.002003807
0.002003607
Other
0 140E-02
5.90E-05
00%
n-Hmane
006557147
0005134334
0.005134334
Reid Valves
—
—
—
02.4 -TOP
0 00 623
855197146
8.56197E-05
—
—
—
—
Methanol ...
0.000674894..+;
5.23463E-06
6,28463146
06-EmissionsImer2ery
op20tar request r? a buffer?
Req
uested Meer (%):
Pollutant
Uncontrolled Embsions
Controlled Emissions
Soiree
VOC
23.49
tp0
2309
toe
Standard EFs- EPAA5NR-95-017 Table 24
Berme
407.83
lb/yr
407.53
lb/yr
Standard EFs-EPA-45-ME95-017 Table2-4
Toluene
825.671Nyr
62507
lb/yr
Standard EFs- EPAA63R-95017 Table 2.4
Ethylbsreem
250.84
lb/yr
250.64
lb/yr
Standard EFs-EPAA53R25017 Table 2-4
Xylene
673..
lb/yr
673.261507
Standard EFs-EPA-053/6-95017 Table2-4
n+immne
2168.101b/Or
2158.1016+0
Standard EFs- EPAA531R-95017 Tahie2.4
2,2,4-TMP
3.11
INyr
3.11
lb/yr
Standard EFs-EPA-453635017 Table 2-4
Methanol
1711
lb/yr
17.111Myr
Standard EFs-EPAA53R435.017 Table 29.
Renew Regulation 3. Part B. Sec5n 111.02 to datetmine a RACT Is required?
'my 40 CFR. Part 60, Subpart KKK to determine if app able to this source?
Review 40 CFR, Pad 60. Subpart 0000 to determine if 60.5380 and/or 60.53858 applicable?
Review Section %VIIF to detemine is 11109 is amicable?
Regulation 1
Section 11.0.1 - Except as provided In paragraphs 2 through 6 below, no owner or operator of a source shall allow
or reuse the erasion into the atmosphere of any our pollutant which Is In excess of 20% meaty. This standard Is
based on 24 consecutive opacity readings taken at 15seco d intervals for sir minutes. The appoved reference
t 1 method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60. Appends (July. 196201n
all subsac5ons of 5ec8on 11. A and B of this regulation.
Section I.A- No person, whoever boated. shall cause or allow the emission of odorous air 0odamkna354nm
any single sauce such as to mutt in detectable ales which are measured in excess of the Wowing 9mi6: For
Re9ulationl
areas used predominantly for ® r residential o commercial purposes is violation d olors are defected after the
ad0mus air has been d5lded with seven (7) or more volume ofodor teas air.
Part A-APEN Requirements
Criteria Pahbr3O0 For criteria pollute t, Air Pollutant Emission Notices are required fog each individual
emissizn point in a nonaltainmeet area with uncontrolled actual emissions of one ton per year or more of any
ind0dual cr0ea pollutant (pollutants are oat mermaid) for which the ems is non -#diner+.
App6ont Is required to file an OPEN sine emissions exceed 1 ton per year VOC
Part B-00541umon Permit Exemptions
Appliont is required to obtain a permit since uncontrolled VOC emissions from this facility are greater
bran the 20 TPY threshold 'Reg. 3, Part B, Section IL0.2a)
Is this source located in an ozone non -attainment arm or Maimen maintenance area?
If ye,Is Ms CFR subject to leak Subparts KR, 00 or 0000a?
3.56E+01
3.56E+01
1.45E-01
1.11E-01
1.58E-02
4.05E-02
8.17E-01
5.01E-04
0.00E+00
1.00E+02
1.26E+00
299E+00
9.52E-01
2.%1+00
6.55E+00
1.11E-02
6.75E-02
TPY
0.2036114017 0.20914
0,412786422 04127864
0.125419002 0.125419
0.336629181 0.3366292
1.079048612 1.0790488
0.00134127 0.0015541
0.00353317 000&5533
Fugitive Emissions Inventory -.
Part B, BI.0.2 -RACT requirements for new or modified minor sources
This sedbn of Regulation 3 require RACT lot new or modified minor sources located in nanattamment
aativnmentlmaintenance area. This source a located in the e4tour ozone nonattaimment area
The date of intact for determining whetter the source is new or modified is therefore November 20,
2007 (the date of the ethaur ozone NA area deynation). Since the fugitives ll be in service after the
doe above, this source is considered"new a modified."
This facility is subject. NOES 0000a. Fd.w.g the leak detection and repair program per NOES
0000a satislfies.e RACT ragsiremna of Regulation 3. The permit will contain a condition reflecting
this determined..
Regulation 6
'
Is this source at an onshore -natural gas processing plant- as defined In 40 CFR, Pad E0.®1? 333
Did this source commences cons.ction,moor...ion. or modification after January 20, 1884, and on or beide
Aughst23.2011?
This source a not subject. MPS 100( bemuse the equipment covered by this fugitive sours Will
commence construction after August 23, 2011.
Cutts Sou onsaucton, recor&nwtlen, a modification alter August 23, 2011 and on ..before Source 2015?
Sepambar tB, 2015?
Source is not sub- NSPS OWG bemuse the
fed. equipment by this source MI
commence construction alter September 18, 2016.
"y iy
Regulation 7
Isihts sauceloca.d in an ozone non -attainment area 0r attainment maintenance area?
Is.. sourceele onshore-natural9a proce.Mg pant- as defined In 40 CFR Part 60.631? 3 �
Fa1Oty a classified as a natural gas promsing plant Therefore, this source Is subject b Regulation T
Section XII.G.
Is0a facility classified as a well pieductn facililyornetumlga compressor smlan?
SSce this facifity is not classified as a well production fatality or natural gas compre aer oration, it is not
sabjectto Regulation? Section XVII.F.
sunu
ed] 33y^
?3.,3Yj 33
YW
Regulatinn8
...saute at a'natural gas processing pant' as defined -in 40 CFR, Pan 63,761?
Istblenaty considered a'malor source of HAP -es specifically darn In 40 CFR. Part 63.761 fa sites Matgll9.1
net poetdien field facilities? 3
If you upend -yes' to both questions above, bather review tithe provisions et 40 CFR, Part 63.7661 -Equipment
Leak Standards' apply?
Source is not subject. MACT eH berauscthe facility is classified as a synthetic minor source of HAPs
(A>
of N'o
PEPS 0000a
ad.a saute commence consin:clioe recrns.tdion, o modification after September 18, 20107
Is .a source at a well sea, compreesa clation or onshore -natural gas processing p1ahC a tlefined.4o CFR j
part 60.543.?
This fatality tee. the definition of onshore -natural gas processing plant" as defined by 40 CFR, Part
52.8430a. Therese .5 fuq.ve omissions at this fecilty are subiect to NSPS 0000a
- 3
Yb 11
- A;
Section 07 -Technical Analysis Notes
,tutu....,,
Additional Notes - �-
1 city.[00 dartmor.ent counts used to Icrate erne one are an estimamor Me tioroporientxMatsieff beat Mefa. y suh;me perms volt contain
an trahal hngcondition n the operator to condi,ual hard count oft , componentS atthefecil.y once M is conmructed endr sopea
2. Srmce the ernissfons associated rr dusinga tie (hares ern1 mil rem. ethat
a Me specinc extend. yas(vaP _ e obtained dvmon,trate co-rp nimns canto dn. (epr_=sen
fight hn r(o services) will not be redm part of the initial comiplmnee Mat bed 6theneratorsamummg l2.22‘20,6jhphbnied, hem,. and
waternoil serwce vvfaichls the ma051 t should be furltr. Thattest.determine niholight liquid, heavy, and
waternml noun no Included th054,,,e e facile, classifi5,111ed as synthetic for OAPs and ire controlled HAIM are notdose to.im:nape source thresholds
this source. is subiect to h5P5.000We/rove), ths 14,5001ttie t adopted. into Colorado Peguat en 6. result, the condition
NIPSOCOCia will be addressed inthE end holder on ommo It shmichbe fur ther noted that followtng Um leak detector and tepee proem
(O. sahsfies the PACT cenuirmnemd for th, source E
SPS
. The VOC arm li aht "na mama meal to estrmete emodons from the gasservice,ereo ed from a repreeenmtem inlet gas analysis taken from:tne sales gess stream at
Me Cam, Oil no Gas rlembergo 2-26348-60 well pad on 02613/2015..The masa nem mnswere corrected To arbondbxa, permnen, era., hydrogensufide,.
heimrn. hydrogen and amend, Tins was eone invader to assummthe entire sernnle t2 composed of rv,l°carbons TM operator expresser:1th,wlculaa done s
sauna factors rattle PAN-atm. Equipment Lea E - the
Erma,. Esnaie.; total antrumss [ meenote under tablet-Oj.Th ,areslt, is
in a awe ofVOCur earnie caha Otheuse VOC and Sseem,drec es-Asx at,
Mme moms ehI I rla. up determinell we gnu Seedsas form
Itsbohl M1 the total hydrocarbon content (all.rnpments exclhding rmrban dioxide, water, hydronmsulfide, hel m.hydregennd oxygen} in the
amp, sample wes determined Mee er4.2446,6 Using thie atummlong Yi CA MeuOC (all components excluding methane, ethane, ca trog e:Sydrogcn
edifice,oxygen) weight ,thc e,. VOCweg. `a wasdetermined asd wt%Ico� ell) 33`6113/3 3 e
hydrogen come,. corrected
35.02'0022841The-calculationmma..1 alsoconducted,6%,,for the HAP weigh,valuesFor remnm,, 7 NAPwegI, es 7the ,and/mina10 tobeing cmrec40are as follow
Ih�nz_=6p:o13�3a ",rn)mmel;�t nas6x,(iq.Etty.enze,e aoTas37s-s,(w)xvtena bo3uzzasa a(y(n-Hexane onorsoY,anal 32.ze?me�omonzz7o3v,
S. ,e weightlues usedtoestimate emissions from[heingh. I quid heavy oll orMwatm aervice avere ootamed from Me slop tarsi Rom, stream predicted by sire
c'ry.Vde Prorseaxsimulationnedd n the apI It Ixeo Stream 17)The ass frxtions55were cermet, emoveca Mon Model, 0ger va,s, nydrogem mike,
helmro.nydropen and Patera,. Mho was done in coder Lea Neentrezme .coalposed flydrdcaftions- loperator,00, is did calculation calculation
results
in a memmamars euvec,rs h el, Pr MoodVC,,d EqupmmTtet f et Est mates ftotcallya amenmgan. the
r2Cand eOia ported date bvnder licted ytheh Rion. Hs result?
v..deredeem,occeMand HASsee1515igh, eve Aneamhe plefthion ahyulatio5useto determine
vh nzeneddrectlyprq'dctedby?he Asaedsu to
Mese vere saol u,.tor purposes. ample 5 calculation u d odeterrn ne,h benzene we ghC%rsasrollows
It shoo, be fr't noted -0.r thvial hydrocarbon (all mamponents1 d , arbom dioxide, nitrogen. weter, hldroge0 eolfid, helium, hydrogen and oxygen) lathe
0 3 atmrnple am, tietatnnneat La be 45310)e93y,. Using thismalHe. Moog h tie berme, weght96of0S70500" the torreetedberimoe weight dismay de,mti,dd1
fdlow,; benzene wtl'lwrrected0-0502690/4538202193"100=1.261]374f. Ts calculation condun.ed for the remaining HAP sareld Te witted For =, .II HAP
ugh,, values morns. simulaSon perm to neorgeorremml esry ,erne. Toluene -I rthymenzenet. 0.13186 tee hill :%el tutu 1161.2,e, lama o Hese,'. d9It69ya,
1122 s' /00602010 Band red hiethanor 0306220,
he sample mddho estimate the fugitive c,Msionsideraerfeted well the amt repres, tttva0
-recto des Vega_
f gtmesoome in the p retie and agreed with
Mt es
MRS Point
006
'ma etg s analIM.: cef gry. may also rim, fro
dine for [his -.e the operato edewed both dome
Process6 5[t- Code
01
Ifrrenntroiled
Pollutant Emissions factor
Section 08. haven.. SCC Cadin5aed Emissions Factors
Control Source
Varies by Varies by
V0C component type component type Standard EFs. EPAA53/11-95-017 Table 2-0
Varies by Varies by
Benzene component type component type Standard EFs.EPA-403/n-95.017 Table 2-4
Varies by Varies by
Toluene mnponent type component type Standard EFs- EPA -453/8.95.017 Table 2-0
Vades by Varies by
Ethylbenzene component type component type Standard EFs -EPA.453/11-95-017 Table 2-4
Varies by Varies by
Oyler, omponent type componen[tyoe Standard Eta -EPA -453/0.-95-017 Table 2.4
Varies by Varies by
a -Hexane component type compeenttype Standard EFs-EPA-053/0.-95-017 Table 2-0
Varies by Varies by
224 TMP component type component type Standard bPs- EPA-0S3/RAS-017 Table 2-0
Crude Oil Storage Tank(s) Emissions inventory
• 009 Crude Oil Tank
'Facility AIRS ID:
123
Plant
Point
Section 02- Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control Efficiency %: ^;
Section 03- Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Throughpus - ' Cr, Barrels (bbl) per year
)Requested Permit Limit Throughput =
Tsvo""{2j
omPressOt%....
)laod roof sio
ia119uldmanHoU.-1'ligeuesseisareusedt stobA'
Enclosed Combustion Or
Actual Crude Oil Throughput While Emissions Controls Operating =
Requested Monthly Throughput =
1994 Barrels )bbl) per month I
"-23.480': Barrels (bbl) per year
Potential to Emit (PTE) Throughput =
23,480, Barrels (bbl) per year
Secondary Emissions- Combustion Device(s)
Heat content of waste gas= j3 x 2334 Btu/scf
Volume of waste gas emitted per BBL of liquids
produced=
Actual heat content of waste gas routed to combustion device =
Requested heat content of waste gas routed to combustion device =
0 MMBTU per year
1,833 MMBTU per year
Potential to Emit (PTE) heat content of waste gas routed to combustion device= 1,833 MMBTU per year
Pilot Fuel Use fate ..,,v,,,_`„l,.30}scf/hr
Section 04 - Emissions Factors & Methodologies
ProMax Throughput
,::1,19566.96862 bbl/year
EPA Tanks Throughput
'-, 11740 bb/year/vessel
ProMax
EPA Tanks
Pollutant
Emission Rate (lb/hr)
Weight%
Emission Rate
(Ib/year/vessel)
VOC
i ,:::;,6.38873056
H :.'7-:
....T,'.:;.54,P,2091.;53,..::::'. :.. ;.
Benten
'-U'034573701=
0.402437295°;.
8,417095735
Toluene
' ''4022834399,--
. 0.273%44826?_
5.706631382
Ethvlbee
.':..0002'226619.'_,' .
i'11.026605777;0
0.5564678
Xylen
':e'd 0054174a'&:,P/t
0(230647326 0
1.353397566
n -Hexes
'" 0192 95 P(?P
12:2981403130'
48.06733986
2,2,4-TMP
':.::0m0106551'PP'
0:3:0012231720
0.02802878
Hydrogen Sulfide
:.c 330313E a 6: ":
:'0.00034469"
0.008255062
Methanol
1 '?=, 0.000774774. ;;
D.009257745,
0.19362851
Will this storage tank emit flash emissions?
Section 05 - Emissions Inventory
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Actual Emissions
Uncontrolled Controlled
(tans/year) (tans/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tors/year)
Requested Monthly Limits
Controlled
(ICs/month)
VOC
PM30
PM25
NOx
CO
35.7
0.0
0.0
35.670
1784
303
0.0
0.0
0.0
0.009
0.009
1
0.0
0.0
0.0
0.009
0.009
1
0.1
0.0
0.0
0.078
0.078
13
0.3
0.0
0.0
0.358
0.358
61
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(ICs/year)
Actual Emissions
Uncontrolled Controlled
Rbs/vear) (lbs/year)
Requested Permit Limits
Uncontrolled Controlled
(Ihs/year) (lho/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
Hydrogen Sulfide
Methanol
370.87
0
0
370.87
18.54
25144
0
0
25144
1257
24.52
0
0
24.52
123
59.65
0
0
59.65
2.98
2117.92
0
0
2117.92
105.90
L17
0
0
1.17
0.06
0.36
0
0
0.36
0.02
8.53
0
0
8.53
0.43
Section 06- Regulatortnummary Analysis
Regulation 3, Parts A,B
Regulation 7, Section XVII.0. Cl, C3
Regulation 7, Section XVII.C.2
Regulation 6, Part A, NSPS Subpart Kb
Regulation 6, Part A, NSPS Subpart 0000
MPS 0000a
Regulation 8, Part E, MAR Subpart HH
(See regulatory applicability worksheet for detailed analysis)
Source requires a permit
Storage tank's subjectto Regulation 7, Section XVII, B, C.1 & C.3
Stange tank is subject to Regulation 7, Section XVII.C.2
Storage Tank is not subject to NSPS Kb
Storage Tank is not subject to NSPS 0000
Storage Tank is not subject to NSPS 40008
Storage Tank is not subject to MACE HH
16 of 18
K:\PA\2018\18WE0503.CP15lsm
Crude Oil Storage Tank(s) Emissions Inventory
Section 07 - Initial and Periodic Sampling and Testiae Reou(remaot
Does the company use the state default emissions factors to estimate emissions?
Ifyes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 20 tans VOC peryear?
If yes, thepermit will contain an Initial Compliance"testing requirement to develop a she spedfic emissions factor based on guidelines in PS Merin 14-03
Does thecompany use a site spedfic emissions factor to estimate emissions?
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample of crude oil drawn at the facility being
permitted?
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines In PS Menu 14-03.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and Initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on Inlet and outlet concentration sampling
N/A- operator developed site specific emission factors.
Section O6 Technical Analysis Notes .......................
1. Em'sson liom this.utoe atedeterminedusiifgboth aProMacsimui tiorrandan EPA T ksd,09d-simulation_ TltePr Mazsmulationls based on a re presentativegassempfeobiainedfmmaztupotreanoiactity morethan one
year prior to appication-submittalThe ProMaxsta Wption iv0Wiaedtadetornrinetheflasft emissionsassotlatedtv4h this source.The EPA Tanks simulanm uses crude ail RVP Sforthe fluid basisdndsalwer.25 the location. The
a
.PA Tanks sun ulat ort is usedtodetermine the waikingand breethitigemissfonsasseciatedwith this source.
2 Since the PioMaxsrmmation used -to estimatefiash emssionsisbased de arepresentaavesample Matures taker, more thane sear prier -Lathe application the opemtarwolberequred to obtain ante specific pressurized liqud
ample from :this facilhy_once it begins aperaton in coder tocamculate emissions. and movie factarsrang site specdicinformatien. Additionally, the opeatr vein be required to obtain a stabilized liquid sample frbm 111 notrage
vessels. This stabilizediiigtddsample wilt be.used. confirm API gravity and RVP of the sample. TheoPfgavny wRicanfremthesource indeed scores liquidzhat isdassifiedas crude off (F.e.APl Gsavdy040). Tine RVP will beused to
onion the RVP 5 basis. used in the EPA Tanks 439d simulation n.e3 urate or conservative -estimate (Or determining working and breathing emissions from this source.
3 In ordertntalculeteHAPemisswn factors associated withiheirarkng and -breathing emissions from the storage vessels, theoperator multiplied the VOC emission factor calculacedhy the EPATanks simulatwnby the HAP
weight %vtt oes intheflashgas streamealcuiatedhy the ProMazsimulabon (See Stream 57in the Mebane Plant -Extended Analyse rim illation). The weigiit%values from thes'mastion are available for reference In jet-non04of
the analysis above, An example cal talons as follows: Bemene W&BEP(Ibjbbl)-(0,178154171bV0C/hkl)"(0.452437%benzene/1001=0.00071695816/bbl. Thssamemethadelogy was usedto calcuial the other HAP -emission
evesselwasle a hhfearn. factors "n.Yfiestoreg g z . .
4- In order to calculate combustion eiposions,iheoperaterusedthe flash gasteat comeorfrom the Psasaxslmulatton (2,334.13Btu/ref) and calculated -the gas-ta-og(GOR) ratio from detain the ProMax model The GOR
presented ie Section 03 above s calculatedasfei1ows: (0A0179253057951897MMscf/day)"(365day/yeariE(I,000,0 0scf/Mined)/(19556.96862 bid/year). 33,4376601 stf/bhl.::. ...
s It should be notedthacthe heat content and -GDR usedtotaluula1 the -combustion emission assoaate withthissource do notaccount for thro+otentml haat =content or waste gas volume associatedwth theworkngand
(Bathing emissions. Thas duetathefact ehat€2A Tanks was teed to estimate working and breathing emissions,andthh software does not provide the voiumeofthe working andbreathing gas m the beat content of the waste
gas. While these parameters were notaccounted'for illthe abula00m, the following dI.stwsionwtl provide detailsas towhythe combusbonofworking and breathinggas would insigmficantlyinapadtheoverall combustion
mnissions To supped thisdleusson, threeoptlow for calculating theworkingand breathing wastegasvolumeand associated emissions will be presented
The( lrst oppen is to assume thatthe working acrd breathing gas has the exec(same G0R.as the Flashga5 la thislnstaruethetotaI NOx and CO emissions assotlatedwkirthe combustion afwastegas wouldbe doubled Total N0x
and CO emissiomwouidthusbe0.12tpy: ando,slnpyrmpoontoy iyely, Thsresu@a still well belcwthe APFN re portingthresholds for these pollutants and does not changethe regulator(applioabiityfor this somoe,Th-n optionh
likely conservative hocausethe volumeef gas emitted. a result of working bfeathlogemaslons i Cypital)y less than that rim dwh nilash occurs. -'
Thesecoedoptlon would he to applythestate defeat( GORand heat content₹etheworking and breathing gas These values are 235cf/bbl and 3,5356t0/s01 Usingthese values along With arequestedthroughput Of 23,480
bbl/yeartheworkingand breathing gas. heat content routedtnthe cnmbustiondevice would be aFculated as follows: (13,840 bN(year)'123rd/hbll't3,535 btu/sill/)1,000,000$tif/t4M9tn)=1938.31 MM8tu/year.Withihis value
and the AP -42 NOx andto emission factors (0.066and 0.31ib/RfMBtu respectively), the NOE and CD ernisslorrs associated with the combustion m working and breathing gas are 0J37_tpy and 0.3 tpy.Addingthese results to the
O end COteoo associated both and working
iof ngflash dgas attilts lmeI npRllss₹ane o₹0,13fpyandtll38tp✓-Het rag am the results are well bebtidOPEN repgr4ngth hai(gr7hR methodology KmSo�sonseNairya because
the deFatrltGo Rvalueaceountrior both flash andwarkugaM breathing erne.
The third option:3 to use the data from- the EPA Tanks simulation in eon)uomicn with thefollowing equation:Volumefsd/year[-100 001rotied VOC(tonlyear))12000@/tonl/(MolecularinteightElb/lb.moDj.(379scf/lb-moli.The
molecular weight used (mite equation in this insssnee is 50 lb/lb-mole based'onthe operator'sselertionof crude o)fas the basis for thPAT 060 imulatioor,dd010mooa lly,the Uncontrolled VOCemissmnsassocietedwteh only the
working and breathing tosses is calculated as follows:10178₹54173010/0111223;480bbljjean)/i200011/tan)a2.00353 opy Using thisinfotmatnn, the volitmes calculated as folbw3_ (2.09153 ton/year)')200PIb/ton)/)50lb/lb -
mnll`(379 stf/Ib-mop=31,707.594,8 so/year. Using this volumeintd 1 netianveithfhestaae default heat contentfor crude oTI3535 010/srf),. the heat content rautedto theflareassociateda ththeworkingand breathing
emissions s: calculated. -follows( (31,707.59480ri/year)'(3,5358tu/sil)/(1,000,0006tu/MMfitu)= 112.086MM&u/year. WOO t his value and the AP -42 NOx and COemiss Ion (adios 10.060 an0D.311b/MMBtu respectively), the
500 and CD. emissions 050001 tedwitnthe combustion of workng and breathing gas are 03Kt4tpyand0.02tpy_Adding these tee alts to the NOx and CD emisdons associated with they combustion of flash gas results intotal
emissions 010.060 toy and tpy Here again -the -results we well below APEN Yeportingthlesholds.This methotlology Is like ly the most representative sincit uses paramttess from mhe tmulafi50 used to estimate wer0ing and
breathing emissions. It is oho the lowest result ofthe threeopflens.
Based on the ab discussion, the contrbuton of gas assodatedwith working a nd breathing emissions is likely -mall enough that it would not significantly ch a ride the NOx and CO: emissions associated with combustion. it is clear
Mese emirs Iris will not causethe NOk and CO emissions to exceedAPENreportingthresholds.A.4 aresult, the Operator will notbe required to muse the moulded calculations to accountfor bus ton ofworking and breathing
gas
6 The combustonemasiom in the Mule 01 Secto505 include the emissions associatedwith the -combustion of pilot light pa. for exa m pie NO0 emissfo0s associatedwln the combustionof prim light gas arecabala tedas follows:
(006a lb/MMBtuI'(4751MMBtit/year)`(sitan/20001bs)=0..02 toy: The other pilot light combustioncossibbstion erniss101,5 are calculafedin .the same manner.
7 The operator.vas provided with a draft perm Sand APEN mane to ew prior to public comment.The operator reviewed the d 00,0Tbattl expressed they had no coin men 6.regardi ihecrudeoil [znks in the draft permit
and that they agreed both. the APEN redlines.
Section 09 - Inventory SCC Coding and EmW Ions Factors
AIRS Paint #
009
Process #
01
FCC Code
Uncontrolled
Emissions
Pollutant Factor
PM10 0.02 0
PM2.5 0.02 0
900 0.16 0-
VOC 72.3 95
CO 0.73 0
Benzene 0.36 95
Toluene 0.25 95
Ethylbenzene 0.02 95
Xylene 0.06 95
mHexane 215 95
224 TMP 0.00 95
H2S 0.00 95
Methanol 0.01 95
Control% Units
b/1,000 gallons crude oil throughput
6/1,000 gallons crude oil throughput
b/1,090 gallons crude oil throughput
b/1,000 gallons crude op throughput
b/1,000 gallons crude oil throughput
b/1,000 gallons crude oil throughput
b/1,000 gallons crude at throughput
b/1,000 gallons crude all throughput
b/1,000 gallons crude all throughput
b/1,000 gallons crude oil throughput
b/1,000 gallons code oil throughput
b/1,000 gallons crude oil throughput
b/1,000 gallons crude oil throughput
17 of 18 - KI\PA\2018\18WE0503.CP1dIsm
CrlIde Oil Storage Tank Regulatory Rnalyels Worksheet
Cder•mw[ulalbn5 P.n3Aanew-APFN •MPeimnnauirmanu
�wm..k :he.3.n
ATTAINMENT
1. Aro uncontrolled actual nalvasi sourogredert•n hSTP, inaguIntion 3 ...Won II.o.3.e13
Me construction El. prior ,0 4/14/1014 em4/14/141ae P5Mamo 14-33 for eaalrbn•hula•s@ .,.nalaher•pplwhinevll
answer ton ayea,the etude ell throughput leathan.10.0C0 &Ions per year,
3. Are u emgreater tban realer 1Wn10 WV or Coe.sionspeat..10Tre 1piervlallons,wn e,5ealonn.o.31P
1. Are uncontrolled e0.1.lrom any aed.pollutant. Iro.ddfldua 3oura greater. Nn lflv INeaulnlon3,Pan0.5enbnll.0.,,a17
1. 1...constructIon prior to 4/14/1gand 34vatmadik 0.aternD4/341. Ps enema14-031or•aalmnaaulaance on ranch., appw4-0WV
annum. La IQ Is yel,lathe crude ml m raa3hpal.n than 4opm ollana par vearx
3. Arat ten tonshm the voter than3rPY,Nmgreaerman 57e.h.00 mbaosmnert.1o7P3 IRegmMn 3 Pot e.admn /1.0,313
�n.eni.al ,I .n
W1.3Manml•auv3
2. Is. cncleoll glory. Wt. Muted at an all ea W ..WM and produalen eart.n , well pa union rallh, Wu. gm am pre•or %mice...x,ru tar rowN s pW,
3. W owl. ell stomp WY. Died mei stomp Ma?
Are uncontrolled actual emIssloniol this nerage Tank mow. or peeler.. 6 tons per yam VOC7
I00
Settlon XVII.II-GentralProutslong for AV Pollution aWonmtt,-Pmluwns Control and MonaoFfile anon entaM Prevention of FmWMn.
5. Nun the erode %crap tank contaln onlestabIllue liquids? ilnertlielo.s.,addl.nal prou.n. apply.
5.alonmho3 Capture and manitormaar3toaga nnMattea 4,/11.,1 Palwtlan Control fqumment
40 4311 NAN Selma SliknOardi of Performance lOrvalatIle ['manic TauM m6n
1. la Individual Mornay...I ...city Mater Ilmn or equal mn lm 111-433 B0Lali
3. Dom la 75
a. goes the veal. encapadryleumm or equal to1.359.074,/1 1-10,000 nyuma laaroleum. or condensate gum, pmeuud,or acted 0x4/10 amdvtransfer' 'seem) In 60.31163
rote.' aeonedin 50.1111.3
6. too .lens. 13..4,aanlonaa empnona:
amhnae to operate In emu ofmskr 4335 Oland wlrnoutemp.i.iom. atmotpnaml6o.t3W.all3n3:ar
b. 1Tedul4n c.d.% yule,. Omar equal m'1 -n50 egg an s. Wud 4/a 160.11m1611tm
o 75 m'hMilk, Mews than 151 mIremmeaap+.a uaore +liqua�wl.. mmmom true rpor prsar: W3tlunssmPdw.,loel6lP
Ittw 33514010NMx0u
Subpart ',General Provisions
w0.153b.p.Ing.nev mo.n.pmgn.wlr.menta
660.1161.-MeniteM3 al opur.n.
40 Cr, Pan6o,subp.rt 0a00.5..rdrul Padoinance for c,umoe.ntl xaturel0upmtluatlory trans... end Walton
1. Is this [Me oil storage veael located at a facility le.he ...ore all and natural gm production t gas
ld 1... d enwu u 406 R 60.21 betweentAugsttv.anatural
1011. septunw[
& 30133 m W loft and Coo n[e vemmt m the la uarvt
3. Are potential VOL ernitsione ',ern Inc IndiNcluals1orsge lereates than or ...aim... payeart
00.4.ucle all non. a vesseln torn veua per 60,54403
1,4
:W-• Soma lie.ulres an ARM. Gotama nextn.etan
4-P to n.nq.eatwn
ContInue•Voti have Indio. the on the Nolen Surnmag
Source Ls sub.. to parla of 5.121. 7.5ections 10/11.88.C. Gole the pung.
e Is s.bjea to all proaana a Replan. 1,sect Ian Rlll.5naeaiom 3 e
tor[. Tane.nm subject MPS g6.The'lamp noel uperya 1.4ow the appiwble threshold.
per f60,5425nbk3
vas lerv0c
460.54xt
-Teats.re Procedures
100.5345WNonlluum13,300in. and amrdMepin,R.quIrernama
41614. Cover anti nosed v ent System Monitoring Req uOamentr
xwln .bnrnw!r,xxw..aiivn:.im0w<a4e w61sa to Nan WOO metaem0l4m.hoe6 ton3w0t.300con0Wap3R3ml'sere..tionmte,xrh,,140.msmsu3len to Nan 0000wtms36s14140
.an patenwly«.mWrnrdrop bemw3tnmwr...g
IOCIR Pan uofeert m anetld.a n3,3o.4lm.101113mm 3e,m4srl�.mRammtmaioncpmmenaea Anerseprember1y 3015
2. Mel thlt [NA. all rlorap Vessel met the definition per 60.503Da
5..me a ubj4. ea to emntmnl.ei .�x,n t1. re .m.IeO.tton6tons
.1.1. 40CFn Pad 609A art marmergPan 61546 an
m•ISto .n7na6nae.:blxirnesFs:4roga
40 CP., wrta ,,suban MAR RN. 0114/14OM Pmaue.n Fm
3 rW wM[an.d..
te •. Plwmnhn #l403443up4r.deaarmld w gran 33004'ln.76001 ORml
emvo.mrrHAW n. u,al.4s Prd la the point.t whldi naval anent.. OM natural anu.n3mWlan and stomp a man eaneorvor la daweremo.3m.lend user' 03.7Wo1141139. Does the UnIt meet the delhilzIon orstorge vessel.' In 63.761,
1. b the touted st .60.1
j4-_, ;
5.ast 4Pe l pramonrf63.75,..ble1
44764. FmWwaluntrolstandfaa
563373. Mona..
563.774.140. eepin[
46373 •P.0.4
MCI !WM
IIACT Wax. niquIrotl MINIM., >claim not apply ANO th. Unit Is In Om nonwsInmmit ono.
sot. bail
DMmlmn
This aorumanfe3aiclaCpretm3 wih eermfay.ppfub0lyd0awnraurem a. athe Clan.Act IMhnplerreatiro,.4004au, .i0 kr OwfyCapdCavu'aelnr0ae0au. Thta doctoral.
nda ndea oM the ea*,a ll cot; may no apply meper40Wmellauarhe4ed upon 04 110b0Nhua anc acumamrcv, mw accumenfMm ndpheroevaubafnulelnenylew
wlbn a nanydhrbpolybindirpregWrmvl erd. no, hgayeffaceable. In Ma aml denye3OnMbelcmun Me language&this accintmnl end 'halenpupeaniecleen Abaci. Ii.
1 amen rau.eov�MpbD ye lComm3dan rpulatioru rorguipedthe all.. orrepulati0n 4001 antra. TM use dvpew. Inaguaeauch as,noommad"mey:
prertvu sal 3t M.Mry kern..kern..sh
cendue..
m/arm ua,.giaaronu0Mran
7rm.dua ba naandes tdvau4ycowactmm.aimngwm,oa. euflni3�dcu 114334aorwunl4.0141Mitp35tararm.3a in enat
1..0.145037736007 psi
40+1
px�
euntlnue-You brie Inaiota the norm stewry on the Roles summary ahem.
Go to the neaq quenlon
rwa Coml.. -You ham Indicated Mawor.esuaery en the haled Summary..
starge T.o6l.not aubjea MAR xx. There are n4- MRR w. rea6ement. for tan. at arw auras
Permit number:
Date issued:
Issued to:
of Division
h & Environment
CONSTRUCTION PERMIT
1 8WE0503
Facility Name:
Plant AIRS ID:
Physical Location:
County:
General
Description:
Issuance: 1
Outrigger DJ Operating LLC
Makena Gas Plant
123/9FC0
NESE SEC 25 T8N R62W
Weld County
Natural Gas Processing Plant
Equipment or activity subject to this permit:
Facility
Equipment ID
AIRS
Point
Equipment Description
Emissions Control
Description
Amine
Sweetening
Unit
001
One (1) Methyldiethanolamine (MDEA) natural
gas sweetening unit (Make: Dickson Process
Systems, LLC, Model: TBD, SN: TBD) for acid
gas removal with a design capacity of 60
MMscf per day. This emission unit is equipped
with two (2) (Make: PumpWorks, Model:
HP538-5500) electric driven amine
recirculation pumps with a limited capacity of
146.1 gallons per minute of lean amine. Only
one (1) amine recirculation pump will be
operated at any given time. The second amine
recirculation pump serves as a back-up only.
This amine unit is equipped with a natural
gas/amine contactor, condenser, flash tank,
still vent and amine regeneration reboiler
covered under point 123/9FC0/004.
Emissions from the
flash tank are used as
fuel for the amine
reboiler or sent to the
plant fuel system. The
acid gas stream from
the still vent is routed
to a condenser and
then to a thermal
oxidizer.
Emergency
Plant Flare
(FS -1761)
002
One (1) open flare (Make: BCCK, Model: EEF-
U-24) used to control residue gas during
residue compressor downtime.
None
Amine
Reboiler
004
One (1) (Make: TBD, Model: TBD, SN: TBD)
natural gas fired amine regeneration heater
None
COLORADO
Air Pollution Control Division
Page 1 of 19
"With a e n heats • t rate f 10.9
MMBt
$
et# '
. ,e em 'o mponen 'V ks from a
natural gas processing plant.
None
Slop Tanks
009
Two (2) 400 barrel fixed roof storage vessels
connected via liquid manifold. These vessels
are used to store crude oil, water and slop oil
from compressors.
Enclosed Combustion
Device
This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission
and the Colorado Air Pollution Prevention and Control Act (C. R.S. 25-7-101 et seq), to the specific general
terms and conditions included in this document and the following specific terms and conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1 YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the
latter of commencement of operation or issuance of this permit, by submitting a Notice of
Startup form to the Division for the equipment covered by this permit. The Notice of Startup
form may be downloaded online at www.colorado.gov/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. Point 001 Et 004: The following information shall be provided to the Division within fifteen (15)
days of the latter of commencement of operation or issuance of this permit.
• Manufacturer
• Model Number
• Serial Number
This information shall be included with the Notice of Startup submitted for the equipment.
(Regulation Number 3, Part B, III.E.)
COLORADO
Air Pollution Control Division
Page 2 of 19
6.
EMIS
l auth ization letter issued by the Division, after
elmost cl rent construction permit. This construction
ority for t operation of this source.
7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part
B, Section II.A.4.)
)
Monthly Limits:
Facility
Equipment
ID
AIRS
Point
Process
Pounds per Month
Emission
Type
PM2.5
PM10
SO,H25
NO,VOC
CO
Amine
Sweetening
Unit
001
01
---
---
714
34
51
476
51
Point
02
---
---
17
---
510
136
425
Emergency
Plant Flare
(FS -1761)
002
01
---
---
---
---
986
280
4,434
Point
Amine
Reboi ler
004
01
---
---
---
- -
795
-
680
Point
Fugitives
006
01
---
---
---
---
---
3,992
---
Fugitive
Slop Tanks
009
02
---
---
- -
---
-
306
---
Point
N
1. Monthly limits are based on a 31 -day month.
2. Process 01 and 02 for the amine unit covered under point 001 are as follow:
a. Process 01: Still vent waste gas routed to the thermal oxidizer.
b. Process 02: Combustion of assist gas and pilot fuel by the thermal oxidizer.
The owner or operator shall calculate monthly emissions based on the calendar month.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds
per month.
Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per
month.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
Annual Limits:
Facility
Equipment
ID
AIRS
Point
Process
Tons per Year
Emission
Type
PM2.5
PM10
SO,H2S
NO,VOC
CO
Amine
Sweetening
Unit
001
01
---
---
4.2
0.2
0.3
2.8
0.3
Point
02
---
---
0.1
---
3.0
0.8
2.5
Emergency
Plant Flare
(FS -1761)
002
01
---
---
---
---
5.8
1.7
26.1
Point
Amine
Reboiler
004
01
---
---
---
4.7
---
4.0
Point
COLORADO
Air Pollution Control Division
Page 3 of 19
Fu we
�-
' 006
01
i
--
`` --
---
---
---
23.5
---
Fugitive
Slop an
X009
1
---
-
---
---
---
1.8
---
Point
1. See "Notes to Permit Holder" for information on emission factors and methods used to calculate
limits.
2. Process 01 and 02 for the amine unit covered under point 001 are as follow:
a. Process 01: Still vent waste gas routed to the thermal oxidizer.
b. Process 02: Combustion of assist gas and pilot fuel by the thermal oxidizer.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per
year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
During the first twelve (12) months of operation, compliance with both the monthly and annual
emission limitations is required. After the first twelve (12) months of operation, compliance with
only the annual limitation is required.
Compliance with the annual limits, for criteria and hazardous air pollutants, shall be determined
on a rolling twelve (12) month total. By the end of each month a new twelve month total is
calculated based on the previous twelve months' data. The permit holder shall calculate actual
emissions each month and keep a compliance record on site or at a local field office with site
responsibility for Division review.
8. Point 001: Compliance with the emission limits in this permit shall be determined by using the
monthly measured still vent waste gas sample composition and monthly measured waste gas flow
volumes. The owner or operator shall calculate uncontrolled VOC, HAP, and H2S emissions on a
monthly basis using the most recent measured waste gas sample composition and monthly
measured waste gas flow volume. A control efficiency of 95%, based on operating the control
device in accordance with the O&M Plan, shall be applied to the uncontrolled VOC, HAP and H2S
emissions.
9. Point 001: 100% of emissions that result from the flash tank associated with the amine unit shall
be recycled and used as fuel for the amine reboiler (AIRS Point 123/9CF0/004) or sent to the
plant fuel system.
10. Point 006: The owner or operator shall calculate actual emissions from this emissions point based
on representative component counts for the facility with the most recent inlet gas analysis, as
required in the Compliance Testing and Sampling section of this permit. The owner or operator
shall maintain records of the results of component counts and sampling events used to calculate
actual emissions and the dates that these counts and events were completed. These records shall
be provided to the Division upon request.
11. The owner or operator shall operate and maintain the emission points in the table below with
the emissions control equipment as listed in order to reduce emissions to less than or equal to
the limits established in this permit. (Regulation Number 3, Part B, Section III.E.)
Facility
Equipment ID
AIRS
Point
Control Device
Pollutants
Controlled
Amine
Sweetening
Unit
001
Still Vent: Thermal Oxidizer (TO)
VOC Et HAP
COLORADO
Air Pollution Control Division
Page 4 of 19
009
PRO
RDS
Enclosed Combustion Device
V0C a HAP
12. This source shall be limited to the following maximum processing rates as listed below. Monthly
records of the actual processing rates shall be maintained by the owner or operator and made
available to the Division for inspection upon request. (Regulation Number 3, Part B, Section
II.A.4.)
Process Limits
Facility
Equipment ID
AIRS
Point
Process
Process Parameter
Annual Limit
Monthly Limit
(31 days)
Amine
Sweetening
Unit
001
_
Natural Gas
Throughput
21,900 MMSCF
1,860 MMSCF
01
Still vent waste gas
routed to the
thermal oxidizer
498.4 MMSCF
42.32 MMSCF
02
Combustion of assist
gas and pilot gas by
the thermal oxidizer
55.63 MMSCF
4.72 MMSCF
Emergency
Plant Flare
(FS -1761)
002
01
Combustion of
residue gas during
residue compression
downtime, purge gas
and pilot fuel
154.5 MMSCF
13.12 MMSCF
Amine
Reboiler
004
01
Consumption of
natural gas as a fuel
87.8 MMSCF
7.46 MMSCF
Slop Tanks
009
01
Crude Oil
Throughput
23,480 barrels
1,994 barrels
The owner or operator shall monitor monthly process rates based on the calendar month.
During the first twelve (12) months of operation, compliance with both the monthly and annual
throughput limitations is required. After the first twelve (12) months of operation, compliance
with only the annual limitation is required.
Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month
total. By the end of each month a new twelve-month total is calculated based on the previous
twelve months' data. The permit holder shall calculate throughput each month and keep a
compliance record on site or at a local field office with site responsibility, for Division review.
13. Point 001: The owner or operator shall continuously monitor and record the following amine unit
emission streams using continuous operational flow meters:
• Total amine unit still vent waste gas volume routed to the thermal oxidizer,
• Total assist gas volume routed to the thermal oxidizer.
The owner or operator shall use monthly throughput records to demonstrate compliance with the
process limits contained in the permit and to calculate emissions as described in this permit.
14. Point 001: The owner or operator shall continuously monitor and record the volumetric flow rate
of natural gas processed by the amine unit contactor using an operational continuous flow meter
at the inlet to the amine contactor. The owner or operator shall use monthly throughput records
to demonstrate compliance with the process limits contained in this permit and to calculate
emissions as described in this permit.
COLORADO
Air Pollution Control Division
Page 5 of 19
15.
urn lean amine recirculation pump rate of
tion rate shall be recorded weekly in a log
on for inspection upon request. (Regulation
16. Point 002: The owner or operator shall continuously monitor and record the following emission
streams associated with the open flare using continuous operational flow meters at the inlet to
the open flare:
• Total residue gas volume routed to the open flare,
• Total purge gas volume routed to the open flare.
The owner or operator shall use monthly throughput records to demonstrate compliance with the
process limits contained in the permit and to calculate emissions as described in this permit.
17. Point 004: The owner or operator shall continuously monitor and record the volumetric flow rate
of natural gas combusted as fuel by the amine regeneration heater using an operational
continuous flow meter at the inlet to the amine regeneration heater. The owner or operator shall
use monthly throughput records to demonstrate compliance with the process limits contained in
this permit and to calculate emissions as described in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
18. 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)
19. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable)
20. Points 001, 004, 006 Et 009: This source is located in an ozone non -attainment or attainment -
maintenance area and subject to the Reasonably Available Control Technology (RACT)
requirements of Regulation Number 3, Part B, Section III.D.2.B. The following requirements were
determined to be RACT for this source:
Facility
Equipment ID
AIRS Point
RACT
Pollutants
Amine
Sweetening Unit
001
Flash Tank: Recycled and used as amine
reboiler fuel or in the plant fuel system.
VOC
Still Vent: Thermal Oxidizer
Amine Reboiler
004
Natural gas as fuel and good combustion
practices
VOC, NOx
Fugitives
006
LDAR as provided at 40 CFR Part 60 Subpart
0000a
VOC
Slop Tanks
009
Enclosed Combustion Device
VOC
21. Point 001, 004 Et 006: 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. (Regulation Number 1, Section II.A.1. Et 4.)
22. Point 002: 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 Number 1, Section II.A.5.)
COLORADO
Air Pollution Control Division
Page 6 of 19
23.
Point
egula
lumbe
ource " s ;tbject e Par . ulate Matter and Sulfur Dioxide Emission
igulatio der 1 c %ding, t not limited to, the following (Regulation
II.A.
er pe ator satLcaute, or perrnto be emitted into the atmosphere from any
fuel -burning equipment, particulate matter in the flue gases which exceeds the following
(Regulation Number 1, Section III.A.1.):
(i)
For fuel burning equipment with designed heat inputs greater than 1x106 BTU
per hour, but less than or equal to 500x106 BTU per hour, the following equation
will be used to determine the allowable particulate emission limitation.
PE=0.5(FI)-0.26
Where:
PE = Particulate Emission in Pounds per million BTU heat input.
Fl = Fuel Input in Million BTU per hour.
b. Emissions of sulfur dioxide shall not emit sulfur dioxide in excess of the following
limitations. (Heat input rates shall be the manufacturer's guaranteed maximum heat
input rates).
(i)
Limit emissions to not more than two (2) tons per day of sulfur dioxide
(Regulation Number 1, Section VI.B.5.a.)
24. Point 004: This source is subject to the New Source Performance Standards requirements of
Regulation Number 6, Part B including, but not limited to, the following (Regulation Number 6,
Part B, Section II.C.):
a. Standard for Particulate Matter - On and after the date on which the required
performance test is completed, no owner or operator subject to the provisions of this
regulation may discharge, or cause the discharge into the atmosphere of any particulate
matter which is:
(i)
For fuel burning equipment generating greater than one million but less than 250
million Btu per hour heat input, the following equation will be used to determine
the allowable particulate emission limitation:
PE=0.5(FI )-0.26
Where:
PE is the allowable particulate emission in pounds per million Btu heat input.
Fl is the fuel input in million Btu per hour.
If two or more units connect to any opening, the maximum allowable emission
rate shall be the sum of the individual emission rates.
(ii) Greater than 20 percent opacity.
25. Point 004: This source is subject to the New Source Performance Standards requirements of
Regulation Number 6, Part A, Subpart Dc, Standards of Performance for Small Industrial -
Commercial -Institutional Steam Generating Units including, but not limited to the following:
• §60.48c Reporting and recordkeeping requirements:
o §60.48c(a) - The owner or operator of each affected facility shall submit
notification of the date of construction or reconstruction and actual startup, as
provided by §60.7 of this part. This notification shall include:
■ §60.48c(a)(1) - The design heat input capacity of the affected facility
and identification of fuels to be combusted in the affected facility.
o §60.48c(g)(1) - Except as provided under paragraphs (g)(2) and (g)(3) of this
section, the owner or operator of each affected facility shall record and maintain
records of the amount of each fuel combusted during each operating day.
COLORADO
Air Pollution Control Division
Page 7 of 19
.48c(g)2) ,As an alternative to meeting the requirements of paragraph (g)(1)
of this section, the owner or operator of an affected facility that combusts only
natural gas may elect to record and maintain records of the amount of each fuel
combusted during each calendar month.
.1n22 =OM NEVAMI.4 =MMOM
o §60.48c(i) - All records required under this section shall be maintained by the
owner or operator of the affected facility for a period of two years following the
date of such record.
26. Point 006: This source is subject to Regulation Number 7, Section XII.G.1. (State only
enforceable). For fugitive volatile organic compound emissions from leaking equipment, the leak
detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart OOOO (July 1, 2017)
applies, regardless of the date of construction of the affected facility, unless subject to the LDAR
program provided at 40 CFR Part 60, Subpart 0000a (July 1, 2017).
27. Point 009: The combustion device covered by this permit is subject to Regulation Number 7,
Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion
device is used to control emissions of volatile organic compounds to comply with Section XVII, it
shall be enclosed; have no visible emissions during normal operations, as defined under
Regulation Number 7, XVII.A.17; and be designed so that an observer can, by means of visual
observation from the outside of the enclosed flare or combustion device, or by other convenient
means approved by the Division, determine whether it is operating properly. This flare must be
equipped with an operational auto -igniter according to the following schedule:
• All combustion devices installed on or after May 1, 2014, must be equipped with an
operational auto -igniter upon installation of the combustion device;
• 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.
28. Point 009: 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.
29. Point 009: 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.
OPERATING Et MAINTENANCE REQUIREMENTS
30. Points 001-002 Et 009: Upon startup of these points, the owner or operator shall follow the most
recent operating and maintenance (O&M) plan and record keeping format approved by the
Division, in order to demonstrate compliance on an ongoing basis with the requirements of this
permit. Revisions to the O&M plan are subject to Division approval prior to implementation.
(Regulation Number 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
31. Point 001: The owner or operator shall complete an initial site specific extended gas analysis of
the amine unit still vent waste gas stream within one hundred and eighty days (180) after
commencement of operation or issuance of this permit, whichever comes later. The sample shall
be analyzed for total VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-
Trimethylpentane and H2S content. The sample shall be collected prior to the inlet of the thermal
COLORADO
Air Pollution Control Division
Page 8 of 19
orri
i o bein co ined ny oth
VOC, H,• H2S e::issrpns as s
Witted th ` ivisi as part of
assic�i limit -
stream. Results of the sampled data will be
cified in this permit. Results of the sampled
e self -certification process to demonstrate
32. Point 001: 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 residue gas combusted as assist gas and
pilot fuel by the thermal oxidizer in order to verify the VOC, benzene, toluene, ethylbenzene,
xylenes, n -hexane, 2,2,4-trimethylpentane, methanol and hydrogen sulfide content (weight
fraction) of this emission stream. Results of the Analysis shall be used to calculate site -specific
emission factors for the pollutants referenced in this permit (in units of lb/MMSCF gas vented)
using Division approved methods. Results of the Analysis shall be submitted to the Division as
part of the self -certification and must demonstrate the emissions factors established through the
Analysis are less than or equal to, the emissions factors submitted with the permit application
and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific
emissions factor developed through this Analysis is greater than the emissions factors submitted
with the permit application and established in the "Notes to Permit Holder" the operator shall
submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request
for permit modification to address this/these inaccuracy(ies).
33. Point 002: 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 residue gas routed to and controlled by
the open flare in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane,
2,2,4-trimethylpentane, methanol and hydrogen sulfide 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).
34. Point 004: A source initial compliance test shall be conducted on this heater to measure the
emission rate(s) for the pollutants listed below in order to demonstrate compliance with the
emissions limits contained in this permit. The test protocol must be in accordance with the
requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted
to the Division for review and approval at least thirty (30) days prior to testing. No compliance
test shall be conducted without prior approval from the Division. Any compliance test conducted
to show compliance with a monthly or annual emission limitation shall have the results projected
up to the monthly or annual averaging time by multiplying the test results by the allowable
number of operating hours for that averaging time (Regulation Number 3, Part B., Section III.G.3)
Oxides of Nitrogen using EPA approved methods.
Carbon Monoxide using EPA approved methods.
35. Point 006: Within one hundred and eighty days (180) of the latter of commencement of operation
or issuance of this permit, the owner or operator shall complete the initial extended gas analysis
of gas samples that are representative of volatile organic compound (VOC) and hazardous air
pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be
used in the compliance demonstration as required in the Emission Limits and Records section of
this permit. The operator shall submit the results of the gas analysis and emission calculations
to the Division as part of the self -certification process to ensure compliance with emissions limits.
COLORADO
Air Pollution Control Division
Page 9 of 19
2
36. oint 0Ei 1 c ne hunre:• nd ei ays (18 of the latter of commencement of operation
r issuate ermit erat . s ill com to a hard count of components at the source
nd estiblisl he mbe �f co one that are orated in "heavy liquid service", "light liquid
er g", derica, se r ice" a " a service" the operator shall submit the results to the
ivision as parof tiie se -certification process o ensure compliance with emissions limits.
37. Point 009: The owner or operator shall complete site specific sampling including a compositional
analysis of the pre -flash pressurized crude oil routed to these storage tanks and for emission
factor development, a sales oil analysis to determine RVP and API gravity. Testing shall be in
accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to
determine site -specific emissions factors for VOC and Hazardous Air Pollutants using Division
approved methods. Results of site -specific sampling and analysis 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.
Periodic Testing Requirements
38. Point 001: At a minimum frequency of once per calendar month, the owner or operator shall
sample and complete an extended gas analysis of amine unit still vent waste gas. This sample
shall be analyzed for total VOC, Benzene, Toluene, Ethylbenzene, Xylene, n -Hexane, 2,2,4-
trimethylpentane and H2S content. The sample shall be collected prior to the inlet of the thermal
oxidizer and prior to being combined with any other stream. The sampled data will be used to
calculate VOC and H2S emissions specified in this permit. If an amine unit is not operated during
a calendar month, monthly sampling is not required.
39. Point 006: On an annual basis, the owner or operator shall complete an extended gas analysis of
gas samples that are representative of volatile organic compounds (VOC) and hazardous air
pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be
used in the compliance demonstration as required in the Emission Limits and Records section of
this permit.
ADDITIONAL REQUIREMENTS
40. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A,
Section 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
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or activity;
or
COLORADO
Air Pollution Control Division
Page 10 of 19
d, or whenever a different type of control
rol equipment; or
fied; or
No later than 30 days before the existing APEN expires.
41. The requirements of Colorado Regulation Number 3, Part D shall apply at such time that any
stationary source or modification becomes a major stationary source or major modification solely
by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980,
on the capacity of the source or modification to otherwise emit a pollutant such as a restriction
on hours of operation (Regulation Number 3, Part D, Section V.A.7.B).
42. Point 006: MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil
and Natural Gas Production Facilities major stationary source requirements shall apply to this
stationary source at any such time that this stationary source becomes major solely by virtue of
a relaxation in any permit limitation and shall be subject to all appropriate applicable
requirements of Subpart HH. (Reference: Regulation Number 8, Part E)
43. Point 004: MACT Subpart DDDDD - National Emission Standards for Hazardous Air Pollutants for
Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters
requirements shall apply to this source at any such time that this source becomes a major source
of hazardous air pollutants (HAP) solely by virtue of a relaxation in any permit limitation and
shall be subject to all appropriate applicable requirements of that Subpart on the date as stated
in the rule as published in the Federal Register. (Reference: Regulation Number 8, Part E)
GENERAL TERMS AND CONDITIONS
44. 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.
45. 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.
46. 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.
47. 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.
48. 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
COLORADO
Air Pollution Control Division
Page 11 of 19
CC), i ing fai
s a pmi condi
vlsiorr� evokes a p
C f�eview of t41
e to meet any express term or condition of
ns imposed upon a permit are contested by
mit, the owner or operator of a source may
Division's action.
49. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission
Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a
source or activity is to be discontinued, the owner must notify the Division in writing requesting
a cancellation of the permit. Upon notification, annual fee billing will terminate.
50. 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:
Harrison Slaughter
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Outrigger DJ Operating LLC
Permit for one (1) 60 MMscf/day MDEA natural gas
sweetening unit, one (1) plant flare, one (1) 10.9
MMBtu/hr amine regeneration heater, fugitives,
and two (2) 400 barrel fixed roof storage vessels at
a new natural gas processing facility located in the
ozone non -attainment area.
COLORADO
Air Pollution Control Division
Page 12 of 19
Notes
1) Th.ermit Fold is required d p fees or tfe proce $ling time for this permit. An invoice for these
will he issu after, the f ermi issu The perr It holder shall pay the invoice within 30 days
-,ei 1of inv ilur pathe invoitwill 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-reps
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)
Amine
Sweetening
Unit
001
Benzene
71432
27,814
1,347
Toluene
108883
12,313
599
Ethylbenzene
100414
704
35
Xylenes
1330207
2,490
123
n -Hexane
110543
789
7
2,2,4-
Trimethylpentane
540841
0.1
4.0x10-4
Hydrogen Sulfide
7783064
4,400
220
Emergency
Plant Flare
(FS -1761)
002
Hydrogen Sulfide
7783064
3
1
Amine
Reboiler
004
Formaldehyde
50000
7
7
Benzene
71432
0.2
0.2
Toluene
108883
0.3
0.3
n -Hexane
110543
169
169
Fugitives
006
Benzene
71432
408
408
Toluene
108883
826
826
Ethylbenzene
100414
251
251
Xylenes
1330207
674
674
n -Hexane
110543
2,158
2,158
COLORADO
Air Pollution Control Division
Page 13 of 19
a 4
_
,2,4-
Tit ylpen n
54 1
4
4
M anon,
675--61
MI
18
18
Slop Tanks
009
Beri +ndu
7i 2
371
19
Toluene
108883
252
13
Ethylbenzene
100414
25
2
Xylenes
1330207
60
3
n -Hexane
110543
2,118
106
2,2,4-
Trimethylpentane
540841
2
0.1
Hydrogen Sulfide
7783064
1
0.1
Methanol
67561
9
1
Note: All non-criter'a reportable pollutants in the table above with uncontrolled emission rates above 250 pounds
per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution
Emission Notice.
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
Process 01:
Emissions from the amine unit result from venting of acid gas (still vent overhead). Additionally,
emissions result from the combustion of thermal oxidizer (TO) assist gas and pilot fuel. Actual VOC,
HAP and H2S emissions from the venting of still vent acid gas shall be calculated based on the most
recent monthly still vent waste gas sampling and the most recent monthly measured still vent waste
gas flow volume. The following equation shall be used to in conjunction with the sample and flow
volume data to calculate actual emissions:
Weight %x Sample MW, lb lb — mole 1.0x106 scf Metered Still Vent Volume, MMscf
Emission Rater = 100 x x x
lb — mole x 379 scf 1 MMscf Month
Controlled emissions are as follows:
Point Source
Control Efficiency
Still vent controlled by thermal oxidizer
95%
Flash tank recycled and used as fuel for amine
unit reboiler or in plant fuel system
100%
SO2 emissions resulting from the combustion of H25 emissions in the still vent waste gas stream are
based on a mass balance. The mass balance utilizes molecular weights of 64.066 lb SO2/lb-mol and
34.08088 lb H2S/lb-mol. The calculation assumes 100% of H25 in the still vent waste gas stream is
COLORADO
Air Pollution Control Division
IT
Page 14 of 19
co erted
cal late a
er. The following equation shall be used to
Tent Emissr n Rate, lb 64.066 lb SO2 lb — mol
s
month x lb — mol x 34.08088 lb H2S
Emissions associated with the combustion of still vent waste gas by the thermal oxidizer are
calculated using the following emission factors:
CAS #
Pollutant
Uncontrolled
Emission Factors
(lb/MMSCF)
Controlled
Emission Factors
(lb/MMSCF)
Source
NOx
1.032
1.032
AP -42 Chapter 1.4
Table 1.4-1
CO
8.67x10-'
8.67x10-'
AP -42 Chapter 1.4
Table 1.4-1
Note: Emission factors in the table above are based on a still vent waste gas heat content of 10.522 Btu/scf.
Actual emissions are calculated by multiplying the emission factors in the table above by the total metered amine
unit stilt vent waste gas routed to the thermal oxidizer.
Process 02:
Combustion of assist gas and pilot fuel:
CAS #
Pollutant
Uncontrolled
Emission Factors
(lb/MMSCF)
Controlled
Emission Factors
(lb/MMSCF)
Source
NOx
106.61
106.61
AP -42 Chapter 1.4
Table 1.4-1
CO
89.56
89.56
AP -42 Chapter 1.4
Table 1.4-1
SOx
6.4x1a1
6.4x101
AP -42 Chapter 1.4
Table 1.4-2
VOC
511.36
25.57
Mass Balance
7783064
Hydrogen Sulfide
2.17x10-2
1.09x10-3
Mass Balance
Note: NOx and CO emission factors in the table above are based on a residue gas heat content of 1087.47 Btu/scf.
Actual emissions are calculated by multiplying the emission factors in the table above by the supplemental fuel
volume for the thermal oxidizer (as measured by flow meter) plus the fuel volume to the thermal oxidizer pilot
(constant at 50 scf/hr). The VOC and HAP emission factors in the table above were calculated based on the residue
gas composition in the ProMax simulation in conjunction with the EPA Emission Inventory Improvement Program
Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3). The ProMax simulation is based on a
representative gas analysis obtained from an upstream facility on 09/13/2012. The controlled VOC and HAP
emission factors are based on the thermal oxidizer control efficiency of 95%.
Point 002:
Emissions associated with the open flare result from the combustion of residue gas during residue
compressor downtime, purge gas and pilot light gas. Total actual emissions are based on the sum of
emissions calculated for the combustion of residue gas, purge gas and pilot light gas (150 scf/hr).
CAS #
Pollutant
Uncontrolled
Emission Factors
(lb/MMSCF)
Controlled
Emission Factors
(lb/MMSCF)
Source
NOx
73.95
73.95
AP -42 Chapter 13.5
CO
337.13
337.13
AP -42 Chapter 13.5
VOC
426.13
21.31
Mass Balance
Note: The uncontrolled VOC emission factor was calculated based on the residue gas composition in the ProMax
simulation provided with the application. The ProMax simulation is based on a representative sales gas analyses
obtained from an upstream facility (Hemberger 3-26-34-8-60) on 09/13/2012. The controlled VOC emission
factor is based on the open flare control efficiency of 95%. The NOx and CO emission factors from AP -42 Chapter
COLORADO
Air Pollution Control Division
Page 15 of 19
13 (0 068 lbMM
of 87.47 Olds
th otal ga
fuel se. T
Point 004:
y) were c nverted to units of lb/MMscf using a heat content
by mu plying the emission factors in the table above by
sured by fl meter (residue and purge gas) plus the pilot gas
g a constant ate of 150 scf/hr.
s
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/MMscf
Source
NOx
106.61
AP -42 Chapter 1.4
Table 1.4-1
CO
89.56
Note: The emissions factors for this point are based on a rated heat input of 10.9 MMBtu/hr, a higher heating
value of 1,087.47 Btu/scf and 8,760 hours of operation per year.
Point 006:
Component
Gas Service
Heavy Oil
Light Oil
Water/Oil
Service
Connectors
247
32
133
30
Flanges
247
32
133
30
Open-ended Lines
103
5
14
4
Pump Seals
0
0
32
4
Valves
475
32
225
37
Other*
3
0
0
0
VOC Content (wt. %)
35.63
100
100
100
Benzene Content (wt. %)
1.45x10-'
1.26
1.26
1.26
Toluene Content (wt. %)
1.11x10'
2.99
2.99
2.99
Ethylbenzene (wt. %)
1.58x10-2
9.52x10'
9.52x10'
9.52x10'
Xylenes Content (wt. %)
4.05x10 2
2.56
2.56
2.56
n -Hexane Content (wt.
%)
8.17x10 1
6.56
6.56
6.56
2,2,4-Trimethylpentane
Content (wt. %)
5.01x104
1.11x102
1.11x102
1.11x1O2
Methanol (wt. %)
---
6.75x10 2
6.75x10-2
6.75x1O2
`Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms,
drains, dump arms, hatches, instrument meters, polish rods and vents
TOC Emission Factors (kg/hr-component):
Component
Gas Service
Heavy Oil
Light Oil
Water/Oil
Service
Connectors
2.0E-04
7.5E-06
2.1E-04
1.1E-04
Flanges
3.9E-04
3.9E-07
1.1E-04
2.9E-06
Open-ended Lines
2.0E-03
1.4E-04
1.4E-03
2.5E-04
Pump Seals
2.4E-03
NA
1.3E-02
2.4E-05
Valves
4.5E-03
8.4E-06
2.5E-03
9.8E-05
Other
8.8E-03
3.2E-05
7.5E-03
1.4E-02
COLORADO
Air Pollution Control Division
Page 16 of 19
Soli :ce: EPA
No that t
in e tat* ab
era'cons
permit arq;•derived by multiplying the equipment counts
r of f'y 5 toy ccommoda e other minor changes to the facility and to
e ` e o atl'de emiss.
Compliance with emissions limits in this permit will be demonstrated by using the TOC emission
factors listed in the table above with representative component counts, multiplied by the VOC
content from the most recent extended gas analysis.
Point 009:
CAS #
Pollutant
Uncontrolled
Emission Factors
lb/bbl
Controlled
Emission Factors
lb/bbl
Source
VOC
3.04
1.52x10-1
ProMax Et EPA
Tanks 4.09d
71432
Benzene
1.58x10-2
7.9x10-4
108883
Toluene
1.07x10-2
5.35x10-4
110543
n -Hexane
9.02x1O2
4.51x10-3
Note: The controlled emissions factors for this point are based on the enclosed combustion device control
efficiency of 95%. The site specific V0C and HAP emission factors in the table above were developed
using ProMax for flash emissions and EPA Tanks 4.09d for working and breathing emissions. The
ProMax simulation is based on a representative sales gas sample obtained from an upstream facility
(Hemberger 3-26-34-8-60) on September 13, 2012. The EPA Tanks simulation uses crude oil RVP 5
for the fluid basis and Denver as the location.
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) Point 001: This source is subject to 40 CFR, Part 60, Subpart 0000a —Standards of Performance
for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction
Commenced After September 18, 2015 (See June 3, 2016 Federal Register posting - effective August
02, 2016). This rule has not yet been incorporated into Colorado Air Quality Control Commission's
Regulation No. 6. A copy of the complete subpart is available on the EPA website at:
https://www.gpo.gov/fdsys/pkg/FR-2016-06-03/pdf/2016-11971.pdf This unit is subject to
requirements including, but not limited to the following:
• §60.5365a - Applicability and Designation of Affected Facilities
o §60.5365a(g)(3) - Facilities that have a design capacity less than 2 long tons per
day (LT/D) of hydrogen sulfide (H2S) in the acid gas (expressed as sulfur) are
required to comply with recordkeeping and reporting requirements specified in
§60.5423a(c) but are not required to comply with §560.5405a through 60.5407a and
§§60.5410a(g) and 60.5415a(g).
• §60.5423a - Record keeping and reporting Requirements
o §60.5423a(c) - To certify that a facility is exempt from the control requirements of
these standards, for each facility with a design capacity less that 2 LT/D of H2 S in
the acid gas (expressed as sulfur) you must keep, for the life of the facility, an
analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2 S
expressed as sulfur.
8) Point 006: This source is subject to 40 CFR, Part 60, Subpart 0000a —Standards of Performance
for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction
COLORA00
Air Pollution Control Division
Page 17 of 19
Co `"mence
02 016).
Reg ; lation ANo.
htts //www g
ember015 ( ne 3, 216 Federal Register posting - effective August
as not t„J en in p ated it Colorado Air Quality Control Commission's
cop of i he ccplete sub4.rt is available on the EPA website at:
ov,sykg/Ff2016 °6-03/pdf/e16-11971.pdf
9) 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.
10) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of: VOC, NOx, CO, benzene and total HAPs
NANSR
Synthetic Minor Source of: VOC and NOx
PSD
Synthetic Minor Source of: CO
MACT HH
Major Source Requirements: Not Applicable
Area Source Requirements: Not Applicable
MACT DDDDD
Not applicable
NSPS Dc
Applicable to point 004
NSPS Db
Not applicable
NSPS Kb
Not applicable
NSPS KKK
Not applicable
NSPS LLL
Not applicable
NSPS OOOO
Not applicable
NSPS OOOOa
Applicable
11) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
COLORADO
Air Pollution Control Division
Page 18 of 19
art 60 , 'ta ate of Perf rri ahce for�Ne i Stationary Sources
u.5:,t.
tSPS
60 -Endue
Subpart A - Subrt KKKK
PA160, j56n ixes a
Ap ix A - dix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories
MACT
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ- Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
COLORADO
Air Pollution Control Division
Page 19 of 19
Amine Sweetening Unit - Form APCD-206
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 amine sweetening units only. If your emission unit does not fall into this category,
there may be a more specific APEN available for your source (e.g. glycol dehydration unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: 18WE0503
AIRS ID Number: 123 / 9FC0 / 001
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name': Outrigger DJ Operating LLC
Site Name: Makena Gas Plant
Site Location: NESE Sec 25 T8N R62W
Mailing Address:
(Include Zip Code) 1200 17th Street, Suite 900
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 237120
Contact Person:
Phone Number:
E -Mail Address2:
Andrew Perdue
720-361-2580
aperdue@outriggerenergy.com
1 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 the APCD via e-mail to the address provided.
Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 1 A¢
,COLORADO
hr, W r^.Nn: cl RN.Ic
I+v£nvlwnmertl
Permit Number: 18WE0503
AIRS ID Number: 123 / 9FC0 / 001
[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 O Change company name3 ❑ Add point to existing permit
❑ Change permit limit 0 Transfer of ownership4 0 Other (describe below)
OR
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: H2S and CO2 removal
Company equipment Identification No. (optional):
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
TBD
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
hours/day
Will this equipment be operated in any NAAQS
nonattainment area?
Does this facility have a design capacity less than 2 long
tons/day of H2S in the acid gas?
days/week
Yes
Yes
weeks/year
Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 2 I
No
No
COLORADO
'`-c fl nn, cif Put.,
Permit Number: 18WE0503
AIRS ID Number: 123 / 9FC0 / 001
(Lease blank unless APCD Las already assigned a permit ' and AIRS ID
Section 4 - Amine Unit Equipment Information
Manufacturer: Dickson Process Systems, LLC Model No.: TB D
Absorber Column Stages: 20
Amine Type: O MEA
stages
O DEA O TEA
Pump Make and Model: pumpWorks HP538-5500
Serial Number: TBD
❑✓ MDEA O DGA
# of pumps: 2
Sour Gas Throughput:
Design Capacity: 60 MMSCF/day
Requested5: it cCO MMSCF/year Actual: __ MMSCF/year
Sour Gas:
Pressure: 911 . psig
Temperature: 100 • °F
Lean Amine
Stream:
Pressure: .28 psia
Flowrate: iyQ, \ gal/min
Mole loading H2S: 0.0001%
Temperature:
Wt. % amine:
Mole Loading
CO2:
2-56 110°F
5
0.054%
NGL Input:
Pressure:
Flowrate:
psia
Gal/min
Temperature:
°F
Flash Tank: Pressure: 100 . psia Temperature: 1 1 1. (p °F
• No Flash Tank
l."9,44,cS ar Sivvkc7lri-/ -iOk (Mot
Additional Required Information: l HbS
p Attach a Process Flow Diagram
IS Attach the simulation model inputs Et emissions report
p Attach composition reports for the rich amine feed, sour gas feed, NGL feed, a outlet stream (emissions)
p Attach the extended gas analysis (including BTEX Et n -Hexane, H2S, CO2, temperature, and pressure)
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018
®� COLORADO
Permit Number: 18W E0503
AIRS ID Number: 123 / 9FC0 / 001
[Leave blank-;niess APCD has already assigned a permit C and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.62922, -104.26171
Operator
Stack ID No.
Discharge Height
Above Ground Level
(feet)
Temp.
('F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TO
35
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
O Horizontal
o Downward
o Other (describe):
0 Upward with obstructing raincap
Indicate the stack opening and size: (check one)
✓❑ Circular Interior stack diameter (inches): 60
o Square/rectangle Interior stack width (inches): Interior stack depth (inches):
o Other (describe):
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
O VRU:
Used for control of:
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed: %
❑ Combustion
Device:
Used for control of: Amine Vent
Rating: 7.504 MMBtu/hr
Type: Thermal Oxidizer Make/Model: MRW Technologies
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: 1,400 °F Waste Gas Heat Content: 11 Btu/scf
Constant Pilot Light: ❑✓ Yes 0 No Pilot Burner Rating: 0.05 MMBtu/hr
Supplemental Fuel Flow: 55.188 MMscf/year
Btu/scf
Supplemental Fuel Heat Content: 1,087
Closed
Loop
System:
Used for control of: Flash gas
Description: Flash gas is used as fuel for reboiler or sent to plant's fuel system
System Downtime: 0 %
O Other:
Used for control of:
Description:
Requested Control Efficiency:
Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018
4 AyCOLORADO
„..rnat,k�.
Permit Number: 18WE0503 AIRS ID Number: 123 / 9FC0 / 001
( e blank unless A.PCD has already assigned a permit = and AIDS ID]
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction ):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOX
H2S
Gill iCKt: Thermal Oxidizeer / F1a510,.OL.: ctitj SycterA
95% f coIp1
NO.
CO
VOC
X111 VcKt: Thermal Oxidizer/ lrlgy,`'1-; AL: Vvtk 9s
h \.. 95%` 1OO%
HAPs
l\ V(, , Thermal Oxidizer r .�='(,,,k "-4.0.-, �.J i �(Stuv 95% 1 Itoo?.Other: c+;T'
j
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Source
Uncontrolled
Controlled
Uncontrolled
Controlled
Uncontrolled
Basis
Units
(AP -42,
Mfg., etc.)
Emissions
tons/ ear
(tons/year) )
Emissions6
(tons/year)
Emissions
tons/ ear
(tons/year) )
Emissions
tons/ ear
(tons/year)
)
PM
7.6
Ib/MMscf
AP -42
--
--
0.24
0.24
SOx
0.1)11• / 0. to
17l( kJ
?'0 /A? -4L
--
--
4.13/0,01
4.130.41-
H 25
0•iAl /1•\ 4x1° 1
ibl .. .c.4(
Ibl��^Sc(
i'�ow� x/
cp5A 'c.s
--
--
2.20
0.11
NO.
100
Ib/MMscf
AP -42
—
--
3.22
3.22
CO
84
lb/MMscf
AP -42
-
--
2.71
2.71
VOC
tims1 Al.3to
;031`"'"` 41
Ibl�m��
Pr.:::;nl __
�-SP'i'vi\�S
--
ris.-4 I1.l.tt
� o.'}
�- / l
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service(CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
y
al /31165t
ttiw+^^S-(9.ow'o.x/
Bbl x{
(o$A.tyyy
L r3\"S.{e (?r ,1
,
1,346.11 (PTE)
Toluene
108883
S•etxlo`A45AO
;errW. k
Gas zA vs:t
'2-,3‘2.3�(Pm)
598.81 (PTE)
Ethylbenzene
100414
3,11 x I- 011 $
IelmMsc�/
ib ,'�,",���`�L
���^^aN
�' p,,,,,,t7ys
i-p3, gt (- )
34.27 (PTE)
Xylene
1330207
I.Wgn6'l�`i5w6g
tt�m+.njt}
t��,,,,M5c /
ja.ovhox/
c,,$gy�,,l,�;s
1.);-1/4S1 v, (?TE)
122.3`+ (PTE)
n -Hexane
110543
LI y
3.tpx�o Ib};xID
lbl►wN 4(
I�,M«sy��
'l wt (
rash \
L *'& (pcE)
t 9. (?1-C)
2,2,4-
Trimethylpentane
540841
Other:
I
\'AC VCS
J CittW\0.x i �v�s�
bRequested values will become permit limitations. Requested limit(s) should consider future process growth.kjc�� �l �O I
Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave 1
blank.
Aw COLORADO
Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018
Permit Number: 18WE0503
AIRS ID Number: 123 / 9FC0 / 001
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
,o/ti/r$
Signature of Legally Authorized Person (not a vendor or consultant) Date
Andrew Perdue
Senior Project 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 $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018
6I �1COLORADO
'h;,r.:o
Gas Venting APEN - Form APCD-211
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head
casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.cotorado.00v/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: 18WE0503
AIRS ID Number:
123 / 9FC0 /002
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Outrigger DJ Operating LLC
Makena Gas Plant
Site Location: NESE Sec 25 T8N R62W
Mailing Address: 1200 17th Street, Suite 900
(Include Zip Code)
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 237120
Contact Person:
Phone Number:
E -Mail Address2:
Andrew Perdue
720-361-2580
aperdue@outriggerenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
it
Form APCD-211 - Gas Venting APEN - Revision 7/2018
c
;COLORADO
Lea,arttcc: Na. He
alth Ent,
Permit Number: 18WE0503 AIRS ID Number:
123 /9FC0/002
[Leave blank unless APCD has already assigned a permit ' and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below)
OR-
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose:
compression downtime
Flaring during unplanned residue
Company equipment Identification No. (optional):
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
TBD
❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
TBD hours/day TBD days/week TBD weeks/year
Will this equipment be operated in any NAAQS
nonattainment area?
Is this equipment located at a stationary source that is
considered a Major Source of (HAP) Emissions?
Is this equipment subject to Colorado Regulation No. 7,
Section XVII.G?
Form APCD-211 - Gas Venting APEN - Revision 7/2018
• Yes
❑ Yes
❑ Yes
❑ No
0 No
Q No
COLORADO
2 1L
n�
Permit Number: 18WE0503
AIRS ID Number:
123 /9FC0/002
[Leave blank unless A?CD has already assigned a permit _ and AIRS ID]
Section 4 - Process Equipment Information
❑ Gas/Liquid Separator
❑ Well Head Casing
❑ Pneumatic Pump
Make: Model:
Compressor Rod Packing
Make: Model:
Serial #: Capacity: gal/min
# of Pistons: Leak Rate: Scf/hr/pist
❑ Blowdown Events
# of Events/year: Volume per event: MMscf/event
❑✓ Other
Description: Flaring during unplanned residue compression downtime
If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas
Venting as a process parameter.
Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes
Gas Venting
Process Parameters5:
Liquid Throughput
Process Parameters5:
Vented Gas
Properties:
❑✓ No
Vent Gas
Heating Value:
1087
,
BTU/SCF
Requested:
•k ,-1.c-
MMSCF/year
Actual:
__
MMSCF/year
kr*-- to C&tat i ass. +-1 DS 01 0°1 Ick
-OR-
Requested:
bbl/year
Actual:
bbl/year
Molecular Weight:
18.14
VOC (Weight %)
0.89%
Benzene (Weight %)
6.9E- °/,
Toluene (Weight %)
1 .7E- 53%,
Ethylbenzene (Weight %)
5.3E- \ \ Yo
Xylene (Weight %)
1.0E- (Q°jo
n -Hexane (Weight %)
1.2E- lo%
2,2,4-Trimethylpentane (Weight %)
9.6E- II%
fk
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 ft n -Hexane, temperature, and
pressure)
E
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
COLORADO
3 �- En,"«fit
Permit Number: 18WE0503
AIRS ID Number:
123 / 9FC0 / 002
[Leave blank unless APCD has already assigned a permit ' and AIRS ID]
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.62922, -104.26171
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet)
Temp.
('F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
FS -1761
65
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
❑✓ Upward
❑ Horizontal
9 Downward
9 Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular
9 Other (describe):
Interior stack diameter (inches):
❑ Upward with obstructing raincap
24
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
❑ VRU:
Pollutants Controlled:
Size:
Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed:
❑ Combustion
Device:
Pollutants Controlled:
Rating:
Type:
VOC, HAPs
18.47 MMBtu/hr
Open Flare Make/Model: BCCK/EEF-U-24
Requested Control Efficiency: 95 %
Manufacturer Guaranteed Control Efficiency: 98
Minimum Temperature: TBD
Waste Gas Heat Content:
1,087
Btu/scf
Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating: 0.64 MMBtu/hr
Other:
Pollutants Controlled:
Description:
Requested Control Efficiency:
Form APCD-211 - Gas Venting APEN - Revision 7/2018
WI COLORADO
Permit Number: 18WE0503
AIRS ID Number: 123 / 9FC0 / 002
[Leave blank unless APCD has already assi_ned a permit # and AIRS ID
Section 7 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested
Control Efficiency
(% reduction in emissions)
PM
SOX
NOx
CO
VOC
Open Flare
95%
HAPs
Open Flare
95%
Other:
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions6
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
PM
SOx
NOx
0.068
Ib/MMBtu
AP -42
--
--
5769 5,'1-%
S•l1
Co
0.31
Ib/MMBtu
AP -42
--
--
25.95Zjo.otU 25,96 7.C
VOC
426.13
Ib/MMscf
ProMax
--
--
32.80 3Z.411, 4-64 i.lo°
9
Jrilxkccx . a io0-S . HO5 p%v91°
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
Uncontrolled
Emissions
(pounds/year)
Controlled
Emissions6
(pounds/year)
Benzene
71432
Toluene
108883
Ethylbenzene
100414
Xylene
1330207
n -Hexane
110543
2,2,4-
Trimethylpentane
540841
Other:
5 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-211 - Gas Venting APEN - Revision 7/2018
®V COLORADO
Permit Number: 18W E0503
AIRS ID Number:
123 /9FC0/002
[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.
/0/O/5
Signature of Legally Authorized Person (not a vendor or consultant) Date
Andrew Perdue
Senior Project Manager
Name (please print) Title
Check the appropriate box to request a copy of the:
❑✓ Draft permit prior to issuance
Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https: / /www.colorado.Rov/cdphe/apcd
Form APCD-211 - Gas Venting APEN - Revision 7/2018
ATiCO LORADO
6
Boiler APEN - Form APCD-220
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 boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit
does not fall into one of these categories, there may be a more specific APEN for your source (e.g. print shop,
mining operations, engines, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN
options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution
Control Division (APCD) website at: www.colorado.gov/cdphe/apcd.
Do not complete this form for the following source categories:
- Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by
natural gas or liquid petroleum gas (LPG).
Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating
buildings for personal comfort that are fueled solely by natural gas or liquid petroleum gas (LPG).
More information can be found in the APEN exempt/permit exempt
checklist: https://www.colorado.00v/pacific/cdphe/apen-or-air-permit-exemptions.
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:
18WE0503
AIRS ID 123 / 9FC0 / 004
Number:
[Leave blank unless APCD has already assigned a permit k and AIRS ID]
Section 1 - Administrative Information
company Name': Outrigger DJ Operating LLC
Site Name: Makena Gas Plant
Site Location: NESE Sec 25 T8N R62W
Mailing Address:
(Include Zip Code) 1200 17th Street, Suite 900
Denver, CO 80202
Site Location
county: Weld
NAICS or SIC code: 237120
contact Person: Andrew Perdue
Phone Number: 720-361-2580
E -Mail Address2: aperdue@outriggerenergy.com
1 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. A -5 2°
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. -C
Form APCD-220 - Boiler APEN - Revision 7/2018
,1'18610
COLORADO
Permit Number: 1 8WE05503 AIRS ID Number: 123 / 9FC0 / 004
[Leave blank unless A?CD has already assigned a permit. 4 and AIRS ID]
Section 2 - Requested Action
0 NEW permit OR newly -reported emission source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change fuel or equipment O Change company name3 O Add point to existing permit
❑ Change permit limit ❑ Transfer of ownership4 O Other (describe below)
- OR
APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
❑ APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose: Amine Reboiler
Manufacturer: TBD Model No.: TBD Serial No.: TBD
Company equipment Identification No.
(optional):
For existing sources, operation began on:
For new, modified, or reconstructed sources, the projected start-up date is:
TBD
❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Seasonal use Dec -
percentage: Feb:
hours/day
Mar -
May:
days/week weeks/year
June -
Aug:
Sept -
Nov:
Are you reporting multiple identical boilers on this APEN? O Yes p No
If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers
or separate meters for each unit):
Form APCD-220 - Boiler APEN - Revsion 7/2018
/J!� COLORADO
2 1 L3�� Er.,00 n:.a
Permit Number: 1 8WE0j03
AIRS ID Number: 123 / 9FC0 / 004
[Leave btank unless aPCD has already assigned a permit = and AIRS ID]
Section 4 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.62922, -104.26171
Operator
Stack ID No.
Discharge Height
Above Ground Level
(Feet) .`
Temp.
('F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
O Upward
❑ Horizontal
❑ Downward
❑ Other (describe):
Indicate the stack opening and size: (check one)
❑ Upward with obstructing raincap
O Circular Interior stack diameter (inches): TBD
❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches):
O Other (describe):
Section 5 - Fuel Consumption Information
Design Input Rate
(MMBTU/hr)
Actual Annual Fuel Use5
(Specify Units)
Requested Ann 6al Permit
Limit
(Specify Units)
10.9
--
87.80 MMscf/yr
From what year is the actual annual fuel use data?
Fuel consumption values entered above are for: 0 Each Boiler O All Boilers O N/A
Indicate the type(s) of fuel used:
❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF)
❑✓ Field Natural Gas Heating value: 1,087 BTU/SCF
❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon)
❑ Propane (assumed fuel heating value of 2,300 BTU/SCF)
❑ Coal Heating value: BTU/lb Ash content: Sulfur Content:
❑ Other (describe): Heating value (give units):
5 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual
boiler basis, or if the values represent total fuel usage for multiple boilers.
6 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
7 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field.
Form APCD-220 - Boiler APEN - Revision 7/2018
COLORADO
3 *nTIT, n"".�,
na �,
Permit Number: 1 8W E0 '5503
AIRS ID Number: 123 19FC0 / 004
[Leave blank unless A?CD has already assigned a permit .f and AIRS ID]
Section 6 - Criteria Pollutant Emissions Information
Attach all emissions calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? O Yes O No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
Pollutant
Control Equipment Description
Overall Control
Efficiency
(% reduction in emissions)
TSP (PM)
PMio
PM2.s
SOx
NO),
CO
VOC
From what year is the following reported actual annual emissions data?
Use the following tables to report the criteria pollutant emissions from source:
(Use the data reported in Section 5 to calculate these emissions.)
Primary Fuel
Type
(natural gas, #2
diesel, etc.)
Uncontrolled
Emission
Factor
(Specify Units)
Emission
Factor
Source
(AP_42
Mfg., etc.)
Actual Annual Emissions
Requested Annual Permit
q 6
Emission Limit(s)Pollutant
Uncontrolled
(tons/year)
Controlled8
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year)
Natural
Gas
TSP (PM)
8.10 lb/MMscf •
AP -42
0.36 •
0.36 •
PM10
8.10 lb/MMscf '
AP -42
0.36 '
0.36 .
PM2s
8.10Ib/MMscf•
AP -42
0.36 .
0.36 •
SOx
0.64 lb/MMscf •
AP -42
0.03 •
0.03'
NOx
106.61 Ib/MMscf .
AP -42
4.68 •
4.68 •
CO
89.56 lb/MMscf •
AP -42
3.93.
3.93
VOC
5.86 lb/MMscf •
AP -42
0.26 ,
0.26
❑✓ Check this box if multiple fuels were NOT fired during this reporting period and skip to Section 7.
If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the
total criteria pollutant emissions table below:
Secondary
Fuel Type
diesel,
waste oil, etc.)
Pollutant
Uncontrolled
Emission
Factor
(Specify Units)
Emission
Factor
Source
(AP -42,
Mfg., etc.)
Actual Annual Emissions
Re uested Annual Permit
q
6
Emission Limit(s)6
Uncontrolled
(tons/year)
Controlled8
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year)
TSP (PM)
PM10
PM2s
SOx
NOx
CO
VOC
6 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-220 - Boiler APEN - Revision 7/2018
COLORADO
H
Permit Number:
1 8WE0503
AIRS ID Number: 123 / 9FC0 / 004
[Leave blank unless APCD has already assigned a permit = and AIRS ID]
If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria
pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the
primary and secondary fuels' emissions tables in this Section 6:
Pollutant
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)6
Uncontrolled
(tons/year)
Controlled8
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year)
TSP (PM)
PM10
PM2.5
SO),
NO),
CO
VOC
6 Requested values will become permit limitations. Requested limitjs) should consider future process growth.
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Section 7 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
❑ Yes No
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
Primary Fuel Type (natural gas, #2 diesel, etc.)
CAS Number
Chemical Name
Overall
Control
Efficiency
Uncontrolled
Emission
Factor
(specify units)
Emission Factor
Source
(AP -42, Mfg., etc.)
Uncontrolled
Actual
Emissions
(lbs/year)
y )
Controlled
Actual
Emissions8
(lbs/year)
11 Check this box if multiple fuels were NOT fired during this reporting period and skip to Section 8.
If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the
total non -criteria pollutant (HAP) emissions table below:
Secondary Fuel Type (#2 diesel, waste oil, etc.)
CAS Number
Chemical Name
Overall
Control
Efficiency
Uncontrolled
Emission
Factor
(specify units)
Emission Factor
Source
(AP -42, Mfg., etc.)
Uncontrolled
Actual
Emissions
(lbs/year)
Controlled
Actual
Emissions8
(lbs/year)
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Form APCD-220 - Boiler APEN - Revision 7/2018
COLORADO
5 1
Permit Number: 18WE05j03
AIRS ID Number: 123 / 9FC0 / 004
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
If multiple fuels were fired during this reporting period, use the following table to report the TOTAL non -criteria
pollutant (HAP) emissions from the source. Values listed below should be the sum of the reported emissions from
the primary and secondary fuels' emissions tables in this Section 7:
CAS Number
Chemical Name
Actual Annual Emissions
Uncontrolled
(tons/year)
Controlled8
(tons/year)
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
Section 8 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
W„,Z
Signature of Legally Authorized Person (not a vendor or consultant) Date
Andrew Perdue Senior Project Manager
Name (please print)
Title
Check the appropriate box if you want:
p✓ Draft permit prior to public notice
E✓ Draft of the permit prior to issuance
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https://www.colorado.gov/cdphe/apcd
Form APCD-220 - Boiler APEN - Revision 7/2018
6
pp coLonaDa
Fugitive Component Leak Emissions APEN
Form APCD-203
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, 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 fugitive component leak emissions only. If your emission source does not fall into this
category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid
loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the
specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the
Air Pollution Control Division (APCD) website at: www.colorado.00v/cdphe/apcd.
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Permit Number: 18W E0503
AIRS ID Number: 123 / 9FC0 / 006
[Leave blank unless APCD has already assigned a permit and AIRS ID]
Section 1 - Administrative Information
Company Name:
Site Name:
Outrigger DJ Operating LLC
Makena Gas Plant
Site Location: NESE Sec 25 T8N R62W
Mailing Address: 1200 17th Street, Suite 900
(Include Zip Code)
Denver, CO 80202
Site Location WeIA
ld
County:
NAICS or SIC Code: 237120
Contact Person: Andrew Perdue
Phone Number: 720-361-2580
E -Mail Address2: aperdue@outriggerenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
iros612
OCT-52018
WV COLORADO
Form APCD-2O3 - Fugitive Component Leak Emissions APEN - Revision 7/2018
Permit Number: 18WE0503 AIRS ID Number: 123 / 9FC0/ 006
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source (check one below)
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
❑ Change process or equipment ❑ Change company name3
❑ Change permit limit ❑ Transfer of ownership4 ❑
- OR
• APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info Et Notes:
Add point to existing permit
Other (describe below)
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
Company equipment Identification No. (optional):
For existing sources, operation began on:
For new or reconstructed sources, the projected start-up date is:
TBD
O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source
Operation:
Facility Type:
❑ Well Production Facility5
❑ Natural Gas Compressor Stations
❑✓ Natural Gas Processing Plants
O Other (describe):
hours/day
days/week weeks/year
s When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018 2 I �¢
COLORADO
Permit Number:
18WE0503
AIRS ID Number: 123 /9FC0 / 006
[Leave blank unless APCD has already assigned a permit it and AIRS ID
Section 4 - Regulatory Information
What is the date that the equipment commenced construction? TBD
Will this equipment be operated in any NAAQS nonattainment area? izt Yes ❑ No
Will this equipment be located at a stationary source that is considered a ❑ Yes ❑✓ No
Major Source of Hazardous Air Pollutant (HAP) emissions?
Are there wet seal centrifugal compressors or reciprocating compressors Q Yes ❑ No
located at this facility?
Is this equipment subject to 40 CFR Part 60, Subpart KKK? ❑ Yes ❑✓ No
Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑ Yes ❑✓ No
Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? ✓❑ Yes ❑ No
Is this equipment subject to 40 CFR Part 63, Subpart HH? ❑ Yes ❑✓ No
Is this equipment subject to Colorado Regulation No. 7, Section XII.G? 0 Yes ❑ No
Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? ❑ Yes ❑✓ No
Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes ❑✓ No
Section 5 - Stream Constituents
❑ The required representative gas and liquid extended analysis (including BTEX) to support the data below has
been attached to this APEN form.
Use the following table to report the VOC and HAP weight % content of each applicable stream.
Stream
VOC
%)
Benzene
(wt % )
Toluene
(wt %)
Ethylbenzene
(wt %)
Xylene
(wt %)
n -Hexane
(wt %)
2,2,4
Trimethylpentane
(wt %)ntane
(wt %)
Gas
35.63
0.14
0.11
0.02
0.04
0.82
0.001
Heavy Oil
(or HeavyLiquid)
100
1.26
2.99
0.95
2.56
6.56
0.01
(or LightLight LiqOiluid)
100
1.26
2.99
0.95
2.56
6.56
0.01
Water/Oil
100
1.26
2.99
0.95
2.56
6.56
0.01
Section 6 - Geographical Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.62922, -104.26171
Attach a topographic site map showing location
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
4-hS \\(ito�,�
3 I A-COLORADO
_. ,=`m.,
Permit Number:
18WE0503
AIRS ID Number:
123 / 9FC0 / 006
[Leave blank unless APCD has already assigned a permit = and AIRS ID]
Section 7 - Leak Detection and Repair (LDAR) and Control Information
Check the appropriate boxes to identify the LDAR program conducted at this site:
❑ LDAR per 40 CFR Part 60, Subpart KKK
❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump
❑ Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump
❑✓ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa
❑ Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81%
connectors
❑ LDAR per Colorado Regulation No. 7, Section XVII.F
❑ Other6:
❑ No LDAR Program
6 Attach other supplemental plan to APEN form if needed.
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
•COLORADO
4 I
Hwl+r in��.�+men�
Permit Number: 18WE0503 AIRS ID Number: 123 I 9FC0 / 006
[Leave blank unless APCD has already assigned a permit = and AIRS !DJ
Section 8 - Emission Factor Information
Select which emission factors were used to estimate emissions below. If none apply, use the table below to
identify the emission factors used to estimate emissions. Include the units related to the emission factor.
❑✓ Table 2-4 was used to estimate emissions7.
❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions7.
Use the following table to report the component count used to calculate emissions. The component counts listed
in the following table are representative of:
✓❑ Estimated Component Count
❑ Actual Component Count conducted on the following date:
Service
Equipment Type
Connectors
Flanges
Open -Ended
Lines
Pump Seals
Valves
Other9
Gas
Counts
247 •
247 •
103 -
0
475 -
3
Emission Factor
4.41E-4 .
8.60E-4 .
4.41E-3 .
5.29E-3 •
9.92E-3 .
1.94E-2 •
Units
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
Heavy Oil (or Heavy Liquid)
Counts
32
32
5
0
32 '
0
Emission Factor
1.65E- 5
8.60E-7 -
3.09E-4 •
0
1.85E-5 •
7.05E-5
Units
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
Light Oil (or Light Liquid)
Counts
133
133 -
14 -
32 -
225 -
0
Emission Factor
4.63E-4 •
2.43E-4
3.09E-3 '
2.87E-2 .
5.51 E-3 •
1.65E-2
Units
lb TOC/component/hr
lb TOC/component/hr
lb T0C/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/componentlhr
Water/Oil
Counts
30 '
30 '
4
4 .
37
0
Emission Factor
2.43E-4 •
6.39E-6 •
5.51E-4 •
5.29E-5 .
2.16E-4'
3.09E -2 -
Units
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
lb TOC/component/hr
7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R-
95-017).
8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual
Calendar Year Emissions" below.
9 The "Other" equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump
seals, or valves.
��Cl make. S
'A Z{otoc O\cof Eittak`-'4 r,,N,,ss;o
(I -41/4k L - Li) .
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018 5 I eg
COLORADO
Permit Number: 18WE0503 AIRS ID Number: 1 23 /9FC0 / 006
[Leave blank unless APCD has already assigned a permit = and AIRS ID]
Section 9 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source:
(Use the data reported in Section 8 to calculate these emissions.)
Chemical Name
CAS
Number
Actual Annual Emissions
Requested Annual Permit Emission
Limit(s)11
Uncontrolled
(tons/year)
Controlled10
(tons/year)
Uncontrolled
(tons/year)
Controlled
(tons/year)
voc
761346
--
--
23.52 2g,y9
23.52 Z3,`tc
Does the emissions source have any actual emissions of non -criteria pollutants
(e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year?
�✓ Yes ❑ No
If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source:
Chemical Name
CAS
Number
Actual Annual Emissions
Requested Annual Permit Emission
Limit(s)11
Uncontrolled
(Ibs/year)
Controlledt0
(lbs/year)
Uncontrolled
Ohs/year)
Controlled
(Ibs/year)
Benzene
71432
--
--
449 cb
4&9 90;
Toluene
108883
--
--
$2.7 qtS-
i $ZS,Ip
Ethylbenzene
100414
--
--
251
251
Xylene
1330207
--
--
&]g tol-3..
%A-'3,1
n -Hexane
110543
--
--
2,1G2 ZI St
2,162 7(S$
2,2,4
Trimethylpentane
540841
--
--
at
3.1
Other:
10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
11 Requested values will become permit limitations, Requested limit(s) should consider future process growth, component count
variability, and gas composition variability.
0-1)doL crr, "S .
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
6I AV
COLORADO
Lor era of T:..:
fill E,to, sf �
Permit Number:
18WE0503
AIRS ID Number: 123 /9FC0 / 006
[Leave blank unless APCD has already assigned a permit ft and AIRS ID]
Section 10 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct.
/O/L-//
Signature of Legally Authorized Person (not a vendor or consultant) Date
Andrew Perdue
Senior Project Manager
Name (print) Title
Check the appropriate box to request a copy of the:
0✓ Draft permit prior to issuance
�✓ Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $191.13 to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https: //www:colorado.gov/cdphe/apcd
Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2018
COLORADO
7 I L4rartm,rn Puelic
h a'.ih iFn��ir.::.m�i•.�
Crude Oil Storage Tank(s) APEN
Form APCD-210
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 tanks that store crude oil associated with oil and gas industry operations. If your
emission source does not fall into this category, there may be a more specific APEN available for your source (e.g.
condensate storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the
General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A
list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division
(APCD) website at: www.colorado.gov/pacific/cdphe/air-permits.
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
t8"wE d5o3 Number: 12 ARO/ 0 V
[Leave blank unless APCD has already assigned a permit C and AIRS ID]
Section 1 - Administrative Information
Company Name': Outrigger DJ Operating LLC
Site Name: Makena Gas Plant
Site Location: NESE Sec 25 T8N R62W
Mailing Address:
(Include Zip Code) 1200 17th Street, Suite 900
Denver, CO 80202
Site Location
County: Weld
NAICS or SIC Code: 237120
Contact Person:
Phone Number:
E -Mail Address2:
Andrew Perdue
720-361-2580
aperdue@outriggerenergy.com
1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear
on all documents issued by the APCD. Any changes will require additional paperwork.
2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided.
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 7/2018
0L1-52018
08615
1 ��COLORADO
e IZ :oGatu<
Permit Number:
\Stt O5 AIRS ID Number: ll-� /tFc / nook
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2 - Requested Action
❑✓ NEW permit OR newly -reported emission source
✓❑ Request coverage under traditional construction permit
O Request coverage under General Permit GP08
If General Permit coverage is requested, the General Permit registration fee of $312.50 must be
submitted along with the APEN filing fee.
-OR -
❑ MODIFICATION to existing permit (check each box below that applies)
O Change in equipment ❑ Change company name3
❑ Change permit limit ❑ Transfer of ownership4
-OR -
❑ APEN submittal for update only (Note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
El APEN submittal for permit exempt/grandfathered source
❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
Additional Info a Notes:
0 Other (describe below)
3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted.
4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted.
Section 3 - General Information
General description of equipment and purpose:
Company equipment Identification No. (optional):
For existing sources, operation began on:
Slop Tanks
For new or reconstructed sources, the projected start-up date is: TBD
Normal Hours of Source Operation: 24
Storage tank(s) located at:
hours/day 7 days/week 52
weeks/year
0 Exploration Et Production (EEEP) site 0 Midstream or Downstream (non EEtP) site
Will this equipment be operated in any NAAQS nonattainment area?
p
Yes
•
No
Are Flash Emissions anticipated from these storage tanks?
p
Yes
•
No
Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)
805 series rules? If so, submit Form APCD-105.
Yes
No
•
El
Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual
emissions ≥ 6 ton/yr (per storage tank)?
Yes
No
p
■
COLORADO
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 7/2018
2I:
Permit Number:
ISUjEbSO'-4- AIRS ID Number: `'1„,7 / ct c -"CD/
[Leave blank unless APCD has already assigned a permit b and AIRS ID]
Section 4 - Storage Tank(s) Information
Actual Annual Amount
(bbl/year)
Requested Annual Permit Limits
(bbl/year)
Crude Oil Throughput:
23,480
From what year is the actual annual amount?
Average API gravity of sales oil: <40 degrees
❑ Internal floating roof
Tank design: Fixed roof
RVP of sales oil: -5
❑ External floating roof
Storage
Tank ID
# of Liquid Manifold Storage
Vessels in Storage Tank
Total Volume of
Storage Tank
(bbl)
Installation Date of Most
Recent Storage Vessel in
Storage Tank (month/year)
Date of First
Production
(month/year)
TBD
2
800
TBD
TBD
Wells Serviced by this Storage Tank or Tank Battery6 (EEtP Sites On
y)
API Number
Name of Well
Newly Reported Well
■
■
■
■
■
5 Requested values will become permit limitations. Requested limit(s) should consider future growth.
6 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to
report all wells that are serviced by the equipment reported on this APEN form.
Section 5 - Stack Information
Geographical Coordinates
(Latitude/Longitude or UTM)
40.62922, -104.26171
Operator Stack
ID No.
Discharge Height Above
Ground Level (feet)
Temp.
(°F)
Flow Rate
(ACFM)
Velocity
(ft/sec)
TBD
TBD
TBD
TBD
TBD
Indicate the direction of the stack outlet: (check one)
▪ Upward ❑ Downward
O Horizontal O Other (describe):
Indicate the stack opening and size: (check one)
❑✓ Circular Interior stack diameter (inches):
O Square/rectangle Interior stack width (inches):
O Other (describe):
❑ Upward with obstructing raincap
TBD
Interior stack depth
(inches):
Form APCD-210 - Crude Oit Storage Tank(s) APE%I - Revision 7/2018
COLORADO
3 I A_ :�
Permit Number:
��U7E C AIRS ID Number: \-1. /9Fco/c.
[Leave blank unless APCD has already assigned a permit and AIRS ID]
Section 6 - Control Device Information
❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section.
Vapor
❑ Recovery
Unit (VRU):
Pollutants Controlled:
Size: Make/Model:
Requested Control Efficiency: %
VRU Downtime or Bypassed (emissions vented): %
❑ Combustion
Device:
Pollutants Controlled: VOC/HAPs
Rating: 0.21
Type: ECD
MMBtu/hr
Make/Model: TBD
Requested Control Efficiency: 08 q %
Manufacturer Guaranteed Control Efficiency: .95- C�� %
Minimum Temperature:
Waste Gas Heat Content:
Constant Pilot Light: Yes O No Pilot Burner Rating:
2,334
0.05
Btu/scf
MMBtu/hr
O Closed Loop System
Description of the closed loop system:
❑ Other:
Pollutants Controlled:
Description:
Control Efficiency Requested:
%
Section 7 - Gas/Liquids Separation Technology Information (E£tP Sites Only)
What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 35 psig
Describe the separation process between the well and the storage tanks: Inlet separator to slop tanks
7-Aco`1,KK_ fieX O cSeict0&
u(tel,�
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 7/2018 4 A¢
COLORADO
cl:y
Permit Number:
AIRS ID Number: (t7 /gfLp/
(Leave blank unless APCD has already assigned a permit r and AIRS ID]
Section 8 - Emissions Inventory Information
Attach all emissions calculations and emission factor documentation to this APEN form.
If multiple emission control methods were identified in Section 6, the following table can be used to state the
overall (or combined) control efficiency (% reduction):
Pollutant
Description of Control Method(s)
Overall Requested Control
Efficiency
(% reduction in emissions)
VOC
ECD
95%
NOx
CO
HAPs
ECD
95%
Other:
From what year is the following reported actual annual emissions data?
Criteria Pollutant Emissions Inventory
Pollutant
Emission Factor
Actual Annual Emissions
Requested Annual Permit
Emission Limit(s)5
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., , etc.)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions8
(tons/year)
Uncontrolled
Emissions
(tons/year)
Controlled
Emissions
(tons/year)
VOC
3.0`-1
lb/bbl
ProMax
—
--
85.19 wt..;
446 1.11
NOx
0.068
lb/MMBtu
AP -42
--
—
0.08
0.08
CO
0.31
Ib/MMBtu
AP -42
--
--
0.36
0.36
Non -Criteria Reportable Pollutant Emissions Inventory
Chemical Name
Chemical
Abstract
Service (CAS)
Number
Emission Factor
Actual Annual Emissions
Uncontrolled
Basis
Units
Source
(AP -42,
Mfg., etc.)
g
Uncontrolled
Emissions
(pounds/year)
(pounds/ ear
Controlled
Emissions8
(pounds/year)
Benzene
71432
0.0158
lb/bbl
ProMax
371 (PTE)
18.55 (PTE)
Toluene
108883
0.0107
lb/bbl
ProMax
251.54 (PTE)
12.58 (PTE)
Ethylbenzene
100414
Xylene
1330207
n -Hexane
110543
0.0902
lb/bbl
ProMax
2,118, PTE)
105.94 (PTE)
2,2,4-
Trimethylpentane
540841
Requested values will become permit limitations. Requested limits) should consider futu e grow
Attach crude oil laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific
emissions factors according to the guidance in PS Memo 14-03.
8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave
blank.
iCOLORADO
Form APCD-210 - Crude Oil Storage Tankls) APENI - Revision 7/2018
Permit Number:
\cG O j AIRS ID Number: � /ClFco/ DUI
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 9 - Applicant Certification
I hereby certify that all information contained herein and information submitted with this application is complete,
true, and correct. If this is a registration for coverage under General Permit GP08, I further certify that this source
is and will be operated in full compliance with each condition of the applicable General Permit.
/12". /0/1//)
t�
Signature of Legally Authorized Person(not a vendor or consultant) te
g g Y
Andrew Perdue
Sen for Project 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 $191.13 and the General Permit
registration fee of $312.50, if applicable, to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Make check payable to:
Colorado Department of Public Health and Environment
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
APCD Main Phone Number
(303) 692-3150
Or visit the APCD website at:
https: //www.colorado.gov/cdphe/apcd
Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 7/2018 6 I A
'COLORADO
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