HomeMy WebLinkAbout20170370.tiffCOLORADO
Department of Public
Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150O St
PO Box 758
Greeley, CO 80632
February 8, 2017
Dear Sir or Madam:
RECEIVED
FEB 16 2017
WELD COUNTY
COMMISSIONERS
On February 9, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for
Kerr-McGee Oil Et Gas Onshore LP - Battery 36221021. 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
Pc) G RA—Vi€LA CC '• PLCmm/-rP),FLcPN,
va�aai�-1 PWCE Ur
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2017-0370
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Kerr-McGee Oil Et Gas Onshore LP - Battery 36221021 - Weld County
Notice Period Begins: February 9, 2017
Notice is hereby given that an application for a proposed project or activity has been submitted to the
Colorado Air Pollution Control Division for the following source of air pollution:
Applicant: Kerr-McGee Oil Et Gas Onshore LP
Facility: Battery 36221021
Oil and gas production facility
SESW Sec 13 T1 N R66W
Weld County
The proposed project or activity is as follows: Source is operating a low pressure separator (heater -treater)
which vents emissions to an enclosed flare while emissions are unable to be recycled by a vapor recovery
unit (VRU).
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):
• 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 16WE0525 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 wilt receive and consider written public comments for thirty calendar days after
the date of this Notice. Any such comment must be submitted in writing to the following addressee:
Bradley Eades
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
cdphe. commentsapcd®state. co. us
Aff?�� . " COLORADO
?.,K xn,,.
Colorado Air Permitting Project
Version No. 1.00
Project Details
Review Engineer:
Package #:
Received Date:
Review Start Date:
Section 01- Facility Information
Company Name:
County AIRS ID:
Plant AIRS ID:
Facility Name:
Physical Address/Location:
Type of Facility:
What industry segment?
Is this facility located in a NAAQS non -attainment area? yes
If yes, for what pollutant? ❑ Carbon Monoxide (CO) 0 Particulate Matter (PM)
Bradley Eades
344879
2/29/2016
12/15/2016
Kerr McGee Oil and Gas Onshore LP
123
9E71
Battery 36221021 (Lochbuie 4C 30C-13)
SESW Sect. 13 T1N R66W
Exploration & Production Weil Pad
Oil & Natural'Gas Production & Processin
Section 02 - Emissions Units In Permit Application
0 Ozone (NOx & VOC)
AIRs Point #
Emissions Source Type
Emissions
Control?
Permit it
Issuance #
Self Cert
Required?
Action
Engineering Remarks
003
002
Pro
ed
:er'Storage Tank
Yes
Yes
L6WE0526.X1
16WE0525
XP
1
APEN Required /;
Permit Exempt
,Initia
<1% crude oil by
venting during: VRU
downtime
Section 03 - Description of Project
This application isrequesting a permit fora new "Generation 4" tank battery facility in Weld County (non -attainment): KMG is requesting permit
coverage for one (1) vapor recovery tower (VRT). Hydrocarbon liquid produced at this faciltiy flows from a HIP separator to a VRT prior to storage in
atmospheric tanks. During normal operation, gas vented fro mthe VRT is routed to a vapor recovery unit (VRU) which compresses the gas and directs
it to the sales gas gathering pipeline: During periods of VRU downtime, the gas vented from the VRT is routed to enclosed corn bustors (ECDs).
Emissions while VRT gas is routed to the ECDs (flare run-time) is a function of condensate throughput. Source is permitting condensate storage tanks
under GP01 and produced water tanks will be issued an exemption based on <1% crude oil by volume.
Section 04 - Public Comment Requirments
Is Public Comment Required?
If yes, why?'
Requ
het£c M1nor Pei
Section 05 - Ambient Air Impact Analysis Requirements
Was a quantitative modeling analysis required?2
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, explain what programs and which pollutants here:
Prevention of Significant Deterioration (PSD):
Title V Operating Permits (OP) : VOC
Non -Attainment New Source Review (NANSR): VOC
Is this stationary source a major source?
If yes, explain what programs and which pollutants here:
No:;.,
Yes
One (1) vapor recovery tower (VRT) that processes liquid from the second stage of separation to cree r
third stage of liquid/gas separation. Overhead flash gas from the VRT,is routed to the vapor recovery uni
(VRUs) in a closed loop process. When the VRUs are unable to capture the entire overhead gas stream,
002
flash gas is routed to an enclosed combustion device (ECU). The ECD has a minimum control efficiency of
95%. Emissions are a function of condensate throughput while overhead gas is routed to the ECD It is
assumed that the flash gas is routed to the ECD 30% of the time. This'pemtit covers emissions when flash
gas is routed to the ECDs.
Equipment Description
This source vents natural gas from: one 1) vapor recovtower
Emissions from this source are: r.
Natural gas venting from one (1) vapor recovery tower. Emissions from this source are routed to a flare.
Calculations
The site specific emission factors developed for this source were determined through the use of two pressurized liquid samples, and two E&P Tanks
simulations associated with the pressurized liquids samples. The pressurized liquid samples were obtained from two different wells at the facility on January
20, 201&. The wells from which the samples were taken are as follow: Lochbuie 4C-13HZ & Lochbuie 30C-13HZ. Two separate E&P Tanks simulations were.
conducted using the two pressurized liquid samples. The results of the simulation were averaged to determine the site specific emission factors. The
simulation uses a sales oil API gravity of 44 degrees. The following tables contain the information from the E&P Tanks simulations used to determine the
emission factors:
E&P Tanks Simulation 1 (Lochbuie 30C-13HZ)
Throughput: 24 bbl/day
Pollutant
Emission Rate
Emission Rate
Uncontrolled Emission
Factor
VOC
12.027
lb/hr
105356.52
lb/year
12.03
lb/bbl
Benzene
0.015
lb/hr
131.40lb/year
0.02
lb/bbl
Toluene
0.012
lb/hr
105.12
lb/year
0.01
lb/bbl
Ethylbenzene
0.001
lb/hr
8.76
lb/year
0.00
lb/bbl
Xylenes
0.003
lb/hr
26.28
lb/year
0.00
lb/bbl
n -Hexane
0.087
lb/hr
762.12
lb/year
0.09
lb/bbl
2,2,4-TMP
0.006
lb/hr
52.56
lb/year
0.01
lb/bbl
Note: The E&P Tanks simulation was run on a basis of 24 bbUday (6780
from lb/hr to lb/bbl results in the same value.
E&P Tanks Simulation 2 (Lochbuie 4C-13HZ)
Throughput: 24 bbl/day
Pollutant
can
Emission Rate
Emission Rate
Uncontrolled Emission
VOC
14.419
lb/hr
126310.44
lb/year
14.42
lb/bbl
Benzene
0.016
lb/hr
140.16
lb/year
0.02
lb/bbl
Toluene
0.013
lb/hr
113.88
lb/year
-1.01
lb/bbl
Ethylbenzene
0.001
lb/hr
8.76
lb/year
0.00
lb/bbl
Xylenes
0.003
lb/hr
26.28
lb/year
0.00
lb/bbl
n -Hexane
0.096
lb/hr
840.96lb/year
0.10
lb/bbl
2,2,4-TMP
0,007
lb/hr
61.32
lb/year
0.01
th
lb/bbl
ersiorc
Note: The. E&P Tanks simulation was run on a oasts of 24 bbl/day (8760 bbi/year}. Rs a resuH e v
from lb/hr to lb/bbl results in the same value.
Average of Simulation 1 and 2
Throughput: 24 bbl/day
Pollutant
Emission Rate
Emission Rate
Uncontrolled Emission
VOC
13.223
lb/hr
115833.48
lb/year
13.223
lb/bbl
Benzene
0.0155
lb/hr •
135.78
lb/year
0.016
lb/bbl
Toluene
0.0125
lb/hr
109.50
lb/year
0.013
lb/bbl
Ethylbenzene
0.001
lb/hr
8.76
lb/year
0.001
lb/bbl
Xylenes
0.003
lb/hr
26.28
lb/year
0.003
lb/bbl
n -Hexane
0-0915
lb/hr
801.54
lb/year
0.092
lb/bbl
2,2,4-TMP
0.0065
lb/hr
56.94lb/year
0.007
lb/bbl
Iblh f
Note: The overall emission rates (Ib/tu) were determined using a stmpie average of tine emtsscon rates ( r) ar
each pollutant obtained from the Underhill 27C-17HZ and Underhill 28N-17NZ simulations.
16WE0525.CP1.xlsm
One (1} vapor recovery tower (VRT)that processesliquid.from the second stage of separation to create a
third stage of Iiquid/gas separation. Overhead flash gas from the VRT is muted to the vapor recovery units
(VRUs} in a'closed loop process. When the VRlJs are unable td capture the entire overhead;gas stream,
flash gas is routed to an enclosed combustion device (ECD}. The ECD has a minimum control efficiency of
95%. Emissions are a function of condensate throughput while overhead; gas is routed to control
It is
assumed that the flash gas is routed
to the ECD 30% of the
time-
Tills
Permit
covers
emissions
when flash
gas is rotated to the ECDs.
Requested Throughput:
Total throughput to VRT:
VRU downtime:
VRT Throughput during VRU downtime:
Flaring Information
Equipment Description
Three (3) enclosed combus
Manufacturer
TBD
r
Model
TBD
Serial Number
TBD
Control Efficiency
95.00%
203,238 bbl/year
30%
60,972 bbl/year
Combustion emission factor source:
0.0037 Ilb NOx/Ib VOC
Emissions Summary Table
CDPHE Inter -Office Communication (2005-03-22)
0.0094 III) CO/lb VOCI
Pollutant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
VOC
13.223
lb/bbl
0.661 lb/bbl
403.12 tpy
20.16 tpy
E&P Tanks
NOx
0.0489
lb/bbl
0.0489 lb/bbl
1.49 tpy
1.49 tpy
CDPHE
CO
0.1243
lb/bbl
0.1243 lb/bbl
3.79 tpy
3.79 tpy
CDPHE
Benzene
0.0150
lb/bbl
7.50000E-04 lb/bbl
914.6 lb/yr
45.7 lb/yr
E&P Tanks
Toluene
0.0115
lb/bbl
5.75000E-04 lb/bbl
701.2 lb/yr
35.1 lb/yr
E&P Tanks
Ethylbenzene
0.0010
lb/bbl
5.00000E-05 Ib/bbl
61.0 lb/yr
3.0 lb/yr
E&P Tanks
Xylenes
0.0030
lb/bbl
1.50000E-04 lb/bbl
182.9 lb/yr
9.1 lb/yr
E&P Tanks
n -Hexane
0.0875
lb/bbl
4.37500E-03 lb/bbl
5335.1 lb/yr
266.8 lb/yr
E&P Tanks
2,2,4-TMP
0.0065
lb/bbl
3.25000E-04 lb/bbl
396.3 lb/yr
19.8 lb/yr
E&P Tanks
Regulatory Applicability
AQCC Regulation 1
This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other
flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in
excess of 30% opacity.'
AQCC Regulation 2
Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air
contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits:
For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air
has been diluted with seven (7) or more volumes of odor free air."
AQCC Regulation 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014'?
Yes
This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, Section XV1I.B.2
Additional Notes:
1. The operator did not provide a sales oil analysis with this application. As a result, it was suggested to the applicant that a sales oil API gravity of 44 degrees be used
based sales oil data from the COGCC . Operator agreed to re -run the model using this value and submitted revised calculations and APEN addendum on 1/23/2017. The
original application assumed a post-VRT API gravity of 52 degrees. Initial sampling will not be required with this issuance since samples were taken from two producing
wells at this facility within 1 year of application submittal.
2. This is a Anadarko Gen 4 Tank Battery and as such, emissions are estimated per discussions with Division staff on 12/16/14. Per this discussion, KMG uses a sample
pulled downstream of the inlet HLP separator (upstream of the VRT) as input composition to E&P Tank. The E&P Tank model is run assuming the bottom of the HLP
separator as the E&P Tank separator, and the VRT as the E&P Tank oil tank.
3. The amount of time that a valve is open allowin ggas to the ECED is monitored on a daily basis. The total monthly liquid throughput to the VRT is multiplied by the
percentage of time the VRU is down (i.e. while valve is open allowing gas to the ECD) to obtain throughput to VRT during VRU downtime. For the purposes of
establishing permit limits, a maximum VRU downtime of 30% is assumed.
4. Secondary emissions from combustion of the waste gas are calculated using emission factros from a 2005 APCD memo for use on storage tanks (Ib/IbVOC). I
calculated emissions using the "GOR" (scf/bbl) and heating value of the waste gas calculated in the E&P tanks run (average of the two model runs). This resulted in a
less conservative estimate of emissions of CO and NOx and therefore the calculations proposed with the original application are being used here. It was communicated
that the Division prefers the use of AP -42 factors and calculated waste stream data to the lb/lb VOC factor referenced in the 2005 APCD Memo.
5. O&M plan outlines continous monitoring of VRU downtime and calcualtion methods used to demonstrate compliance with the liquid throughput limits in this permit.
16WE0525.CP1.xlsm
Condensate Storage Tank(s) Emissions Inventory
Issuance Date: December 30, 2015
Section 01- Adminstrative Information
Facility AIRS ID:
123
County
9E71k
Plant
003
Point
Section 02 - Equipment Description Details
Detailed Emissions Unit
Description:
Emission Control Device
Description:
Requested Overall VOC & HAP Control
Efficiency %:
One (1) 210 bbl produced water tank. Emisstonsfrom the produpi
Emissions are routed to an enclosed combustor
Section 03 - Processing Rate Information for Emissions Estimates
Primary Emissions - Storage Tank(s)
Actual Produced Water Throughput =
Requested Permit Umit Throughput =
Potential to Emit (PTE) Produced Water
Throughput =
Secondary Emissions - Combustion Device(s)
Heat content of waste gas= NA" Btu/scf
Volume of waste gas emitted per BBL of liquids'.
produced = NA scf/bbl
Actual heat content of waste gas routed to combustion device =
Request heat content of waste gas routed to combustion device =
141,876 Barrels (bbl) per year
70,251. Barrels (bbl) per year
70,251.: Barrels (bbl) per year
Actual Produced Water Throughput While Emissions Controls Operating = 141,8766
NA MMBTU per year
NA MMBTU per year
Potential to Emit (PTE) heat content of waste gas routed to combustion device = NA
Section 04- Emissions Factors & Methodologies
Will this storage tank emit flash emissions?
Pollutant
Produced Water Storage Tanks
Uncontrolled E.F.
(Ibs/bbl Produced
Water
Throughput)
Controlled E.F.
(Ibs/bbl
Produced
Water
Throughput)
Uncontrolled E.F.
(Ibs/Ib VOC)
Control Device
Uncontrolled
E.F. (Ibs/bbl
Produced
Water
Throughput)
MMBTU per year
PM10 VIIIIINI
`NN XXX_WCZEIMILXXXVIO\�� �
VOC `O.26 s6t W\X NX
0.0094'; 0.0025„
0.007 0.000 1.A
MIIEMMEMI 0.000 r: ,p
0.000 4III.V4faXIIIII.14NNW
MIMSTEMMIll 0.000 VIVII0lIkVIIII XXXVI4IILVI6IXIIIIIN 74040467%.,
n -Hexane
Section 05 - Emissions Inventory
Emissions Factor Source Citation
Criteria Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
PM10
PM2.5
NOx
VOC
CO
#VALUE!
#VALUE!
#VALUE!
#VALUE!
#VALUE!
#VALUE!
#VALUEI
#VALUE!
#VALUE!
#VALUE!
0.1
0.1
0.1
0.1
0.1
22.3
22.3
1.1
18.6
0.9
0.2
0.2
0.2
0.2
0.2
Hazardous Air Pollutants
Potential to Emit
Uncontrolled
(tons/year)
Requested Permit Limits
Uncontrolled Controlled
(tons/year) (tons/year)
Actual Emissions
Uncontrolled Controlled
(tons/year) (tons/year)
Benzene
Toluene
Ethylbenzene
Xylene
n -Hexane
224 TMP
6.0E-01
6.0E-01
3.0E-02
5.0E-Ol
2.5E-02
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
0.0E+00
1.9E+00
1.9E+00
9.4E-02
1.6E+00
7.8E-02
0.0E+00
0.0E+00
0.0E+0D
0.0E+00
0.0E+00
Section 06- Regulatory Summary Analysis _
Regulation 3, Parts A, B
Regulation 7, Section XVII.B, C.1, C.3
Regulation 7, Section XVII.C.2
Regulation 6, Part A, NSPS Subpart 0000
(See regulatory applicability worksheet for detailed analysis)
Source requires APEN, is permit exempt
Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3, a
Storage tank is subject to Regulation 7, Section XVII.C.2, as provide
Storage Tank is not subject to NSPS 0000
4 of 7
K:\PA\2016\16W E0525.CP1.xlsm
Condensate Storage Tank(s) Emissions Inventory
Issuance Date: December 30, 2015
section 07- Initial and Periodic Sampling and Testing Requirements
Does the company use a site specific emisions factor to estimate emissions? �-
If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn
at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered
representative which generally means site -specific and collected within one year of the application received date.
However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to
use an older site -specific sample.
If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. SeP PSMemo14-03, Questions 5.9 and 5.12 for additional guidance on testing.
Does the company request a control device efficiency greater than 95% for a flare or combustion device?
If yes, the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling
Section o8 - Technical Analysis Notes
Source is claiming exemption for <1% oil by volume per Regulation 3, P
Section 09 - Inventory SCC Coding and Emissions Factors
rt I3, ion ll.D.1.M;:<
AIRS Point # Process # SCC Code
003 01 4-04-003-15 Fixed Roof Tank, Produced Water, workingcbreathing+Flashing losses
Uncontrolled
Emissions
Pollutant Factor Control % Units
PM10 #VALUE! 0 lb/1,000 gallons liquid throughput
PM2.5 #VALUE! 0 lb/1,000 gallons liquid throughput
NOx 0.02 0 lb/1,000 gallons liquid throughput
VOC 6.2 95 lb/1,000 gallons liquid throughput
CO 0.06 0 lb/1,000 gallons liquid throughput
Benzene 0.17 95 lb/1,000 gallons liquid throughput
Toluene 0.00 95 lb/1,000 gallons liquid throughput
Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput
Xylene 0.00 95 lb/1,000 gallons liquid throughput
n -Hexane 0.52 95 lb/1,000 gallons liquid throughput
224 TMP 0.00 95 lb/1,000 gallons liquid throughput
5 of7
K:\PA\2016\16W E0525.CP1.xlsm
Produced Water Storage Tank Regulatory Analysis Worksheet
Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb.
Colorado Regulation 3 Parts Aand 0- APEN and Permit Requirements
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. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M)
3. Are total facility uncontrolled VOC emissions greater than 5 TPY, MOO greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3(?
(Not enough information
NON ATTAINMENT
1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)?
2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M(
3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.0.2)7
(Source requires APES. is permit exempt
Colorado Regulation 7. Section XVII
1. Is this tank located at a transmission/storage facility?
2. Is this produced water storage tank' located at an oil and gas exploration and production operation, well production facility', natural gas compressor station' or natural gas processing plant?
3. Is this produced water storage tank a fixed roof storage tank?
4. Are uncontrolled actual emissions of this storage tank equal to or greater than 6 tons per year VOC?
'Storage tank is subject to Regulation 7, Section 3011, B, Cl S C.3, as provided below
Section X011.0 — General Provisions for Air Pollution Control Equipment and Prevention of Emissions
Section XVII.C.1- Emissions Control and Monitoring Provisions
section XVII.C.3- Recordkeeping Requirements
5. Does the produced water storage tank contain only"stabilized" liquids? If no, the following additional provisions apply.
'Storage tank is subject to Regulation?, Section XVII.C.2, as provided below
Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment
40 CFR, Part 60. Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production. Transmission and Distribution
1. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after August 23, 2011?
2. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430?
3. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry?
4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year?
'Storage Tank is not subject to NSPS 0000
Subpart A, General Provisions per §60.5425 Table 3
§60.5395 - Emissions Control Standards for VOC
§60.5413 -Testing and Procedures
460.5395(g) - Notification, Reporting and Recordkeeping Requirements
§60.5416(cl - Cover and Closed Vent System Monitoring Requirements
§60.5417 - Control Device Monitoring Requirements
[Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2)
even if potential VOC emissions drop below 6 tons per year]
NA
Yes;.
Yet
Source Rey
Source is Al
Source is Al
Go to next i
Go to then.
Go to then
Source is su
Go to then
Go to the n.
Go to then
Storage Tar
AIRS (County/Plant) 123/9E71
Permit No. 16WE0525 & 16WE0526
Date 1/30/2017
Point #
002
SCC
31000205
Pollutant or CAS
Uncontrolled Emission Factor
Emission Factor Source
Controlled
Actual
Emissions
(tpy)
Controlled
Requested
Emissions
PTE
Ctrl. Elf
NCRP =
reportable
002
31000205
VOC
13.223 lb/bbl
Gas Analysis/ProMax
(tpy)
20.2
(tpy)
%
?
002
31000205
NOx
0.049 lb/bbl
AP -42
403.1
1.49
95%
---
002
31000205
CO1.49
0.124lb/bbl
AP -42
3.79
0%
--
002
31000205
Benzene
0.015 lb/bbl
Gas Analysis/ProMax
45.7
3.79
914.6
0%
—
002
31000205
n -Hexane
0.088 lb/bbl
Gas Analysis/ProMax
266.8
5335.1
95%
Yes
002
31000205
Toluene
0.012 lb/bbl
Gas Analysis/ProMax
35.1
95%
Yes
002
31000205
Ethylbenzene
0.001 lb/bbl
Gas Analysis/ProMax
3
701.2
61
95%
Yes
003
40400315
Xylenes
0.003 Ib/bbl
Gas Analysis/ProMax
9.1
95%
No
003
40400315
VOC
6.238 lb/1000 gallons
CDPHE
0.9
182.9
95%
No
003
40400315
Benzene
0.167 lb/1000 gallons
CDPHE
49.7
18.6
993.1
95%
-
n -Hexane
0.524 lb/1000 gallons
CDPHE
156.1
3121.3
95%
Yes
95%
Yes
Permit number:
Date issued:
Issued to:
Co
Air Po
Depart
CONSTRUCTION PERMIT
16WE0525
Issuance:
1
Kerr-McGee Oil and Gas Onshore LP
Facility Name: Tank Battery #36221021
Plant AIRS ID: 123/9E71
Physical Location: SESW Sec 13 T1 N R66W
County: Weld County
General Description: Well Production Facility
Equipment or activity subject to this permit:
Facility
Equipment
ID
AIRS
Point
Equipment Description
Emissions Control
Description
VRT
002
One (1) vapor recovery tower (VRT) that processes
liquid from the second stage of separation to create a
third stage of liquid/gas separation. Overhead flash
gas from the VRT is routed to the vapor recovery
units (VRUs) in a closed loop process. When the VRUs
are unable to capture the entire overhead gas
stream, flash gas is routed to an enclosed combustor.
Emissions are a function of condensate throughput
while overhead gas is routed to the ECD.
Enclosed
Combustor
This permit is granted subject to all rules and regulations of the Colorado Air Quality Control
Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to this
specific general terms and conditions included in this document and the following specific terms and
conditions.
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of
the latter of commencement of operation or issuance of this permit, by submitting a Notice of
Startup form to the Division for the equipment covered by this permit. The Notice of Startup
form may be downloaded online at www.cotorado.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.
COLORADO
Air Pollution Control Division
Page 1 of 8
2. Within one hundred and -fight d . s 80) the t r of ommencement of operation or
issuance of this permit, om • a e ith - on i ns c tained in this permit shall be
demonstrated to the per 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.>yov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B,
Section III.G.2.)
3. This permit shall expire if the owner or operator of the source for which this permit was issued:
(i) does not commence construction/modification or operation of this source within 18 months
after either, the date of issuance of this construction permit or the date on which such
construction or activity was scheduled to commence as set forth in the permit application
associated with this permit; (ii) discontinues construction for a period of eighteen months or
more; (iii) does not complete construction within a reasonable time of the estimated
completion date. The Division may grant extensions of the deadline. (Regulation Number 3,
Part B, Section III.F.4.)
4. The operator shall complete all initial compliance testing and sampling as required in this
permit and submit the results to the Division as part of the self -certification process.
(Regulation Number 3, Part B, Section III.E.)
5. The operator shall retain the permit final authorization letter issued by the Division, after
completion of self -certification, with the most current construction permit. This construction
permit alone does not provide final authority for the operation of this source.
EMISSION LIMITATIONS AND RECORDS
6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3,
Part B, Section II.A.4.)
Annual Limits:
Facility
Equipment ID
C
AIRS
Point
Tons per Year
Emission
Type
PM2.5
NO,
VOC
CO
VRT
002
---
1.5
'__'__'
20.2
r_—__- __A
3.8
.....H...A.. ...ea
Point
*r. nlenlntc
Note: See "Notes to Permit Holder" for informati
limits.
Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per
year.
Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year.
The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted
emission units at this facility.
Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be
determined on a rolling twelve (12) month total. By the end of each month a new twelve
month total is calculated based on the previous twelve months' data. The permit holder shall
calculate actual emissions each month and keep a compliance record on site or at a local field
office with site responsibility for Division review.
;COLORADO
Air Pollution Control Division
Page 2 of 8
7. The emission points in t
control equipment as lis
established in this perm
maintained with the emissions
ess than or equal to the limits
III.E.)
Facility
Equipment ID
AIRS
Point
Control Device
Pollutants
Controlled
VRT
002
Emissions from the VRT are routed to an
Enclosed Combustor during Vapor Recovery
Unit (VRU) downtime
VOC and HAP
PROCESS LIMITATIONS AND RECORDS
8. This source shall be limited to the following maximum processing rates as listed below. Monthly
records of the actual processing rates shall be maintained by the owner or operator and made
available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.)
Process Limits
Facility
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
VRT
002
Condensate throughput while emissions
are routed to enclosed combustor
60,972 bbl/yr
omp lance wit the annual throughput limits shall be determined on a rolling twelve (12)
month total. By the end of each month a new twelve-month total is calculated based on the
previous twelve months' data. The permit holder shall calculate throughput each month and
keep a compliance record on site or at a local field office with site responsibility, for Division
review.
9. The owner or operator shall continuously monitor and record Vapor Recovery Unit (VRU)
downtime while emissions are routed to the control device.
10. The owner or operator must use monthly VRU downtime records, monthly condensate
throughput records, calculation methods detailed in the OfrM Plan, and the emission factors
established in the Notes to Permit Holder to demonstrate compliance with the process and
emissions limits specified in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
11. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001)
shall be marked on the subject equipment for ease of identification. (Regulation Number 3,
Part B, Section III.E.) (State only enforceable)
12. This source is subject to the odor requirements of Regulation Number 2. (State only
enforceable)
COLORADO
Air Pollution Control Division
TX"k':i v1 P .alt: i Ie tth k J.l" ;:±
Page 3 of 8
13. The combustion device - pew is b'ect Regulation Number 7, Section
XVII.B.2. General Provisi• to enf • ble I a fl or other combustion device is
used to control emission. • at - -r• - o - - to c ly with Section XVII, it shall be
enclosed; have no visible emissions during normal operations, as defined under Regulation
Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation
from the outside of the enclosed flare or combustion device, or by other convenient means
approved by the Division, determine whether it is operating properly. This flare must be
equipped with an operational auto -igniter according to the following schedule:
• All combustion devices installed on or after May 1, 2014, must be equipped with an
operational auto -igniter upon installation of the combustion device;
• All combustion devices installed before May 1, 2014, must be equipped with an
operational auto -igniter by or before May 1, 2016, or after the next combustion device
planned shutdown, whichever comes first.
14. The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only).
On or after August 1, 2014, gas coming off a separator, produced during normal operation from
any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be
routed to a gas gathering line or controlled from the date of first production by air pollution
control equipment that achieves an average hydrocarbon control efficiency of 95%. If a
combustion device is used, it must have a design destruction efficiency of at least 98% for
hydrocarbons.
OPERATING & MAINTENANCE REQUIREMENTS
15. Upon startup of these points, the owner or operator shall follow the most recent operating and
maintenance (OEM) plan and record keeping format approved by the Division, in order to
demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to
the OEtM plan are subject to Division approval prior to implementation. (Regulation Number 3,
Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Requirements
16. The owner or operator shall demonstrate compliance with opacity standards, using EPA
Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of
visible emissions. "Visible Emissions" means observations of smoke for any period or periods of
duration greater than or equal to one minute in any fifteen minute period during normal
operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16)
Periodic Testing Requirements
17. This source is not required to conduct periodic testing, unless otherwise directed by the
Division or other state or federal requirement.
ADDITIONAL REQUIREMENTS
18. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A,
II.C.)
• Annually by April 30th whenever a significant increase in emissions occurs as follows:
For any criteria pollutant:
For sources emitting less than 100 tons per year, a change in actual emissions of five
(5) tons per year or more, above the level reported on the last APEN; or
For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone
nonattainment areas emitting less than 100 tons of VOC or NOX per year, a change in
COLORADO
Air Pollution Control Division
•
Page 4 of 8
annual actual em sion .f �nR 1) t� "�•er y r or m're or five percent, whichever is
greater, above th leve e d o ast P N; or
For sources emi a e, a.J►ange in actual emissions of five
percent or 50 tons per year or more, whichever is less, above the level reported on the
last APEN submitted; or
For any non -criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less, above the
level reported on the last APEN submitted to the Division.
• Whenever there is a change in the owner or operator of any facility, process, or
activity; or
• Whenever new control equipment is installed, or whenever a different type of control
equipment replaces an existing type of control equipment; or
• Whenever a permit limitation must be modified; or
• No later than 30 days before the existing APEN expires.
19. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any
such time that this source becomes major solely by virtue of a relaxation in any permit
condition. Any relaxation that increases the potential to emit above the applicable Federal
program threshold will require a full review of the source as though construction had not yet
commenced on the source. The source shall not exceed the Federal program threshold until a
permit is granted. (Regulation Number 3, Parts C and D).
GENERAL TERMS AND CONDITIONS
20. 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.
21. 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.
22. 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.
23. 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.
24. 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
COLORADO
Air Pollution Control Division
hlean v L'. ;YCDIirr_'1C
Page 5 of 8
regulations of the Air Qu- tr l mi .i (A C , inc ding failure to meet any express
term or condition of the • - - Di • de e a p it, conditions imposed upon a
permit are contested by - n. • - - or Divis evokes a permit, the owner or
operator of a source may request a hearing before the AQCC for review of the Division's action.
25. 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.
26. 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:
Bradley Eades
Permit Engineer
Permit History
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Kerr-McGee Oil and Gas Onshore LP
"COLORADO
Air Pollution Control Division
;f Putiss tieit°r:
Page 6 of 8
Notes to Permit Holder at the tim
1) The permit holder is requir- _ ' ay-Lesng ti for this permit. An invoice for
these fees will be issued after the permit is issued. The permit holder shall pay the invoice within
30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit.
(Regulation Number 3, Part A, Section VI.B.)
2) The production or raw material processing limits and emission limits contained in this permit are
based on the consumption rates requested in the permit application. These limits may be revised
upon request of the owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice
(APEN) and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written
notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions
Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-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.
AIRS
Point
Pollutant
CAS #
Uncontrolled
Emissions
(lb/yr)
Controlled
Emissions
(lb/yr)
002
Note All
Benzene
71432
915
46
Toluene
108883
701
35
Ethylbenzene
100414
61
3
Xylenes
1130207
183
9
n -Hexane
110543
5335
267
2,2,4-
Trimethylpentane
n t
540841
396
20
on cn erla 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 002:
CAS #
Pollutant
Uncontrolled
Emission Factors
(lb/bbl)
Controlled
Emission Factors
(lb/bbl)
Source
NOx
0.0489
0.0489
2005-03-22 APCD
Memo
CO
0.1243
0.1243
VOC
13.223
0.661
EEtP Tanks
71432
Benzene
0.015
7.5E-04
108883
Toluene
0.012
5.75E-04
110543
n -Hexane
0.088
4.4E-03
540841
2,
Trimethylpentane
0.007 0.007
3.25E-04
Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%.
COLORADO
Air Pollution Control Division
De nert cfPublic kfaE;^s io•irrrne
Page 7 of 8
The emission factors listed
separator pressure
6) In accordance with C.R.S. 2`- - .1, -. h -•ll . t" flissiorr tice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to
the most recent annual fee invoice to determine the APEN expiration date for each emissions point
associated with this permit. For any questions regarding a specific expiration date call the Division
at (303)-692-3150.
7) This facility is classified as follows:
(VRT) temperature of 50 °F and
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of: VOC
NANSR
Synthetic Minor Source of: VOC
8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be
found at the website listed below:
http://ecfr.gpoaccess.gov/
Part 60: Standards of Performance for New Stationary Sources
NSPS
60.1 -End
Subpart A - Subpart KKKK
NSPS
Part 60, Appendixes
Appendix A - Appendix I
Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories
MACT
63.1-63.599
Subpart A - Subpart Z
MACT
63.600-63.1199
Subpart AA - Subpart DDD
MACT
63.1200-63.1439
Subpart EEE - Subpart PPP
MACT
63.1440-63.6175
Subpart QQQ - Subpart YYYY
MACT
63.6580-63.8830
Subpart ZZZZ - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart XXXXXX
'COLORADO
Air Pollution Control Division
Page 8 of 8
�tA.k.a I /OLA
General APEN - Form APCD-200
Air Pollutant Emission Notice (APEN) and
Application for Construction Permit
All sections of this APEN and application must be completed for both new and existing facilities, including APEN
updates. An application with missing information may be determined incomplete and may be returned or result in
longer application processing times. You may be charged an additional APEN fee if the APEN is filled out
incorrectly or is missing information and requires re -submittal.
There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of
specialty APENs is available on the Air Pollution Control Division (APCD) website at
www. colorado. gov/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:
)(2 JJE Dias
i a.3 /95?i/c o.
AIRS ID Number: 123 / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 1 - Administrative Information
Company Name: Kerr-McGee Oil and Gas Onshore LP
Site Name: 36221021
Site Location: SESW Sect. 13 TIN R66W
Mailing Address: PO Box 173779
(Include Zip Code)
Portable Source
Home Base:
Denver,CO 80217.3779
Site Location
County: Weld
NAICS or SIC Code: 1311
Permit Contact: Krey, Carissa
Phone Number: (720) 929-6916
E -Mail Address: carissa.krey@anadarko.com
'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.
Form APCD-200 - General APEN - Revision 7/2015 1 I
COLORADO
N.vllp6f4whotunoul
Permit Number:
AIRS ID Number: 123/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 2- Requested Action
® NEW permit OR newly -reported emission source (check one below)
• STATIONARY source 0 PORTABLE source
-OR-
❑ MODIFICATION to existing permit (check each box below that applies)
O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit
O Change permit limit 0 Transfer of ownership2 ❑ Other (describe below)
-OR-
❑ APEN submittal for update only (Please note blank APENs will not be accepted)
- ADDITIONAL PERMIT ACTIONS -
• Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE)
❑ APEN submittal for permit exempt/grandfathered source
Additional Info Et Notes:
Requesting individual permit for vapor recovery tower (VRT)
2For 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:
Provide 3rd stage of gas/liquid separation
Manufacturer:
Model No.: Serial No.:
Company equipment Identification No. (optional): 2 3 3 5 4 4
For existing sources, operation began: / /
For new or reconstructed sources, the projected start-up date is: / /
® Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below:
Normal Hours of Source Operation: hours/day
Seasonal use percentage: Dec -Feb: Mar -May:
days/week weeks/year
June -Aug: Sept -Nov:
Form APCD-200 - General APEN - Revision 7/2015 2
IcOLoaaho
Depa.tmentelhb,c
Hiill114Enultenit nl
Permit Number:
AIRS ID Number:
1 23 / /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 4 - Processing/Manufacturing Information ft Material Use
❑ Check box if this information is not applicable to source or process
From what year is the actual annual amount?
3
Condensate throughput in
60972 bbl/yr
Flash gas
Requested values will become permit limitations. Requested limit(s) should consider future process growth.
Section 5 - Stack Information
40.044530 / -104.727760
❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a
stack. If this is the case, the rest of this section may remain blank.
ter,
`
Pf
z_ a O erator `
tack ID No vw
.3z',yuzs
2 :i5 .x, t...,, �?-"_-.. -�
s Ran
f zRlschanrge Heights �':j
0,
Above Ground Leve4
armFee t
..<"" _� _ a�`,. �,�_ ''H>r i„
c
�x
�F
r�,_#.�)�a�
t
� y
emp t�
r
p �z�
.. -, . t.s.,.� > T .�".
�
Flow Rateyelocrty
a
`ACF1) W
r' ;��'-a3 _x f ,t
{
t w
, i
�k f:
s ,
-ifE/sec�x
-,s'' ' ,.. .�,.�va
VRT ECD
20
Indicate the direction of the stack outlet: (check one)
❑ Downward
❑ Other (describe):
® Upward
❑ Horizontal
Indicate the stack opening and size: (check one)
® Circular
n Square/rectangle
❑ Other (describe):
Interior stack diameter (inches): 48
❑ Upward with obstructing raincap
Interior stack width (inches): Interior stack depth (inches):
Form APCD-200 - General APEN - Revision 7/2015 3 I
COLORADO
onni:m;e or
maim E. EIMIEMmint
TSP (PM)
Permit Number:
AIRS ID Number:
123/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 6 - Combustion Equipment Et Fuel Consumption Information
® Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated
with this emission source)
Design Input Rate
t'MMBTU/hr)
Actual:Annual Fuel Use
; (Specify Unttsl
Renested Annual Permit Limit'
s`q � -
(Spec�fy Unrts)
From what year is the actual annual fuel use data?
Indicate the type of fuel used4:
❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF)
❑ Field Natural Gas Heating value: BTU/SCF
❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon)
❑ Propane (assumed fuel heating value of 2,300 BTU/SCF)
❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content:
❑ Other (describe): Heating value (give units):
3 Requested values will become permit limitations. Requested limit(s) should consider future process growth.
4 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field.
Section 7 - Criteria Pollutant Emissions Information
Attach all emission calculations and emission factor documentation to this APEN form.
Is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No
If yes, please describe the control equipment AND state the overall control efficiency (% reduction):
ontrol Equipment
verall;Control Efficierc
reduction o missions)"
PMi o
PM2.5
SOx
NOx
CO
VOC
ECD
95
Other:
Form APCD-200 - General APEN - Revision 7/2015
4I
ICOL0 RADO
1,116En o, nm,c
HNn1�6EnvnPnmmY
Permit Number:
MRS ID Number: 123/ /
[Leave blank unless APCD has already assigned a permit # and AIRS ID]
Section 7 (continued)
From what year is the following reported actual annual emissions data?
Use the following table to report the criteria pollutant emissions from source:
(Use the data reported in Sections 4 and 6 to calculate these emissions.
Pollutant
Uncontrolled
Emission
k Factor
S'eci
{ fy Units)
` c Emission
Factor
Source
(AP 92 Mfq
;.efc
r r 5'''.61'4,
Actual Annual
r , N3
Ermssions�='�
-
�Reqte Annual Permit
E 3x Erfiissro irr
Uncontrolled_
Tons/ ear
C ontrolled5
Tons/ ear
Uncontrolled
0701.0 4e),',-
Controlled
Tons/ eat
TSP (PM)
PMio
PM2.5
SOX
NOX
0.0037 Ib/IbVOC
APCD 2005
1.49
CO
0.0094 Ib/IbVOC
APCD 2005
3.79
VOC
11.9021b/bbl
E&PTank
403.11
20.16
Other:
3 Requested values will become permit limitations. Requested limit(s) should consider future process growth
5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Section 8 - Non -Criteria Pollutant Emissions Information
Does the emissions source have any uncontrolled actual emissions of non -criteria
pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250
lbs/year?
® Yes ❑ No
If yes, use the following table to report the non -criteria pollutant (HAP i emissions from source•
CAS
Number
Chemical Name '.
Overall
Control
Efficiency
Uncontrolled
Emission
Factor
. ,.
,{specifyunrts)
Emission Factor
Source
(�P 42:.Mfg etc)
_.,; _ ,.. •
Uncontrolled
Actual
missions
.,€ ,(ibs/year)
Controlled
Actual
Emissions
(l13.0S44).'
Benzene
95%
0.015 ib/bbl
E&P Tank
914.57
45.73
Toluene
95%
0.0115 lb/bbl
E&P Tank
701.17
35.06
Ethylbenzene
95%
0.001 Ib/bbl
E&P Tank
60.97
3.05
Xylenes
95%
0.003 lb/bbl
E&P Tank
182.91
9.15
n-Hexan
95%
0.0875 lb/bbl
E&P Tank
5335.01
266.75
224-TMP
95%
0.0065 lb/bbl
E&P Tank
396.31
19.82
5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank.
Form APCD-200 - General APEN - Revision 7/2015
5I
(COLORADO
Uepimnent of nm.,
• Hold, 4Envltonre.11
Permit Number:
AIRS 1D Number: 123 / /
[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.
re of�e
Signat�Legally Authorized Person (not a vendor or consultant)
(la -3 / 17
Date
Krey, Carissa HSE Representative
Name (please print) Title
Check the appropriate box to request a copy of the:
❑ Engineer's Preliminary Analysis conducted
® Draft permit prior to issuance
® Draft permit prior to public notice
(Checking any of these boxes may result in an increased fee and/or processing time)
This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration
of the five-year term, or when a reportable change is made (significant emissions increase, increase production,
new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements.
Send this form along with $152.90 to:
Colorado Department of Public Health and
Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Telephone: (303) 692-3150
For more information or assistance call:
Small Business Assistance Program
(303) 692-3175 or (303) 692-3148
Or visit the APCD website at:
www.colorado.gov/pacific/cdphe/air-permits
Form APCD-200 - General APEN - Revision 7/2015 6
�-HwCOLORADO
nsistic
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