HomeMy WebLinkAbout20160031.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
1150 0 St
PO Box 758
Greeley, CO 80632
December 17, 2015
Dear Sir or Madam:
RECEIVED
DEC 2 2 .ii, 1
WELD C0.sfv TV
COMMISSIONERS
On December 23, 2015, the Air Pollution Control Division will begin a 30 -day public notice period for
Whiting Oil and Gas Corporation - Cottonwood 08E-0504. 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
RtActu,awsub
W17L., 14., tit 11O
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickenlooper, Governor { Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
2016-0031
Air Pollution Control Division
Notice of a Proposed Project or Activity Warranting Public
Comment
Website Title: Whiting Oil and Gas Corporation - Cottonwood 08E-0504 - Weld County
Notice Period Begins: December 23, 2015
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: Whiting Oil and Gas Corporation
Facility: Cottonwood 08E-0504
Oil and gas production facility
SW IA of NW IA Section 8, T9N, R57W
Weld County
The proposed project or activity is as follows: Source proposes to operate hydrocarbon liquid loading to
truck tanks, and flaring of gas produced when it is unable to be recompressed to sales pipeline.
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 15WE1247 have been
filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are
available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices
The Division hereby solicits submission of public comment from any interested person concerning the ability
of the proposed project or activity to comply with the applicable standards and regulations of the
Commission. The Division will receive and consider written public comments for thirty calendar days after
the date of this Notice. Any such comment must be submitted in writing to the following addressee:
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
1 I A"' COLORADO
z
STATE OF COLORADO
LOD T' • F P C HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
TELEPHONE: (303) 692-3150
CONSTRUCTION PERMIT
PERMIT NO: 15WE1247
Issuance 1
DATE ISSUED:
ISSUED TO: Whiting Oil & Gas Corporation
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Oil and gas exploration and production facility known as the Cottonwood 08E-0504,
located in the SW 1/4 of NW 1/4, Sec. 8, T9N, R57W, Weld County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
Facility
Equipment
ID
AIRS
Point
Description
Loadout
001
Hydrocarbon Loadout to Tanker Trucks. Emissions from the
loadout are not controlled.
SEP-01,
FLR-01
002
One (1) high-pressure 2 -phase separator and one (1) high-
pressure 3 -phase separator controlled by one enclosed flare
during downtime of Redtail Gas Plant. Flare is enclosed and has a
minimum control efficiency of 95%.
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 THOSE GENERAL TERMS AND CONDITIONS
INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS:
REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION
1. Within one hundred and eighty days (180) after commencement of operation or issuance
of this permit, whichever comes later, 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. (Reference: Regulation No. 3, Part B,
III.G.2).
2. 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
AIRS ID: 123/9E1 D Page 1 of 10
time of the
deadline per Reg
III.F.4.)
`3, Part B,
ealth and Environment
it Pollution Control Division
ion rliy grant extensions of the
rence: Regulation No. 3, Part B,
3. The operator shall complete all initial complianng and sampling as required in this
permit and submit the results to the Division�'part of the self -certification process.
(Reference: RegulonNo. 3, Part B, Section
4. The operator shall retain the permit final a
completion of self -certification, with the
construction permit alone does not provide fi
EMISSION LIMITATIONS AND RECORDS
5. Emissions of air pollutants shall not exceed
Division's preliminary analysis). (Reference:
Annual Limits:
letter issued by -the Division, after
rrent construction permit. This
ity for the operation of this source.
ng limitations (as calculated in the
n No'. 3, Part B, Section II.A.4)
Facility
Equipment ID
AIRS
Point
Tory Yea
Emission Type
NO,
CO
Loadout
001
—
5.0
—
Point
SEP-01, FLR-
01
002
4.6
52.1
24.8
Point
See `Notes to Permit Holder" for information on ern e facto►s and methods used to calculate
limits.
Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0
tpy.
Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy.
Compliance with the annual limits shall be d lned by recording the facility's annual
criteria pollutant emissions, (including all I-tA,p the de-minimis reporting level)
from each emission unit, on a rolling twelve (12 Month total. By the end of each month
a new twelve-month total shall be calculated }based tit the previous twelve months' data.
The permit holder shall calculate emissions as ,month and keep a compliance record
on site or at a local ` field office with site res l ility, for Division review. This rolling
twelve-month total shall apply to all permed,erritssion units, requiring an APEN, at this
facility.
The emission points in the table below shall bo grated and maintained with the control
equipment as listed in order to reduce ems to less than or equal to the limits
established in this permit (Reference: Regulation No.3, Part B, Section III.E.)
Facility
Equipment
ID
AIRS
Point
Control Device
Pollutants
Controlled
SEP-01,
FLR-01
002
Enclosed Flare
VOC and HAP
PROCESS LIMITATIONS ANQ RECORDS
AIRS ID: 123/9E1 D
Page 2 of 10
i Health and Environment
it Pollution Control Division
7. This source s- """ it t wi m pr- ' -.ing 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. (Reference:
Regulation 3, Part B, II.A.4)
Process/Consumption Limits
Facility
Equipment
ID
AIRS
Point
Process Parameter
Annual Limit
Loadout
001
Oil Loaded
118,260 BBUyr
SEP-01,
FLR-01
002
Gas flared from Separators
100.0 MMSCF/yr
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.
8. The owner or operator shall continuously monitor and record the volumetric flow rate of
natural gas flared from the separators using a flow meter. The flow meter shall
continuously measure flow rate and record total volumetric flow of gas from the
separators that is routed to the enclosed flare. The owner or operator shall use monthly
throughput records to demonstrate compliance with the limits specified in Condition 8
and to calculate emissions as described in this permit.
STATE AND FEDERAL REGULATORY REQUIREMENTS
9. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on
the subject equipment for ease of identification. (Reference: Regulation Number 3, Part
B, III.E.) (State only enforceable)
10. 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.
11. This source is subject to the odor requirements of Regulation No. 2. (State only
enforceable)
12. Point 001: The owner or operator shall follow loading procedures that minimize the
leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation
3, Part B, III.E):
a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or
other liquid or vapor loss during loading and unloading.
b. All compartment hatches (including thief hatches) shall be closed and latched at
all times when loading operations are not active, except for periods of
maintenance, gauging, or safety of personnel and equipment.
c. The owner or operator shall inspect loading equipment and operations on site at
the time of the inspection to ensure compliance with the conditions (a) and (b)
AIRS ID: 123/9E1D Page 3 of 10
li 1ealth and Environment
it Pollution Control Division
aboveccmortrfi, Each inspection shall be
documented in a log available to the Division on request.
13. Point 001: All hydrocarbon liquid loading operations, regardless of size, shall be
designed, operated and maintained so as to minimize leakage of volatile organic
compounds to the atmosphere to the maximum extent practicable.
14. Point 001: Oil loading to truck tanks shall be conducted by submerged fill. (Reference:
Regulation 3, Part B, III.E)
15. Point 002: The separators covered by this permit are 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.
16. Point 002: The flare covered by this permit is subject to Regulation No. 7, Section
XVII.B General Provisions (State only enforceable). These requirements include, but are
not limited to:
XVII.B.1.b 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, 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. The operator shall comply with all
applicable requirements of Section XVII.
XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped
with an operational auto -igniter upon installation of the combustion device.
OPERATING & MAINTENANCE REQUIREMENTS
17. Point 002: Upon startup of this point, 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 your O&M plan are subject to Division approval prior to
implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.)
COMPLIANCE TESTING AND SAMPLING
Initial Testing Reauirements
18. Point 002: The owner or operator shall complete an initial site specific extended gas
analysis within one hundred and eighty days (180) after commencement of operation or
issuance of this permit, whichever comes later, of the natural gas vented from this
emissions unit in order to verify the VOC content (weight fraction) of this emission
stream. Results of testing shall be used to calculate a site -specific emission factor for the
pollutant referenced above (in units of Ib/MMSCF gas vented) ° using Division approved
methods. Results of site -specific sampling and emissions factor analysis shall be
submitted to the Division as part of the self -certification and demonstrate the emission
factor established through this initial testing is less than or equal to, the emissions factor
established in the permit application and "Notes to Permit Holder" for this emissions
AIRS ID: 123/9E1 D Page 4 of 10
Health and Environment
it Pollution Control Division
point. If the si '"" c : i• or - + thro '; _ his sampling and analysis
is greater than the emissions factors established in the permit application and "Notes to
Permit Holder" the operator shall submit to the Division within 60 days, a request for
permit modification to update emissions factors and emissions limits specified in this
permit.
19. Point 002: 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)
ADDITIONAL REQUIREMENTS
20. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation
No. 3, Part A, II.C)
a. 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 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.
b. Whenever there is a change in the owner or operator of any facility, process, or
activity; or
c. Whenever new control equipment is installed, or whenever a different type of
control equipment replaces an existing type of control equipment; or
d. Whenever a permit limitation must be modified; or
e. No later than 30 days before the existing APEN expires.
21. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit)
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 No. 3
Part D).
GENERAL TERMS AND CONDITIONS
22. 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
AIRS ID: 123/9E1D Page 5 of 10
ealth and Environment
it Pollution Control Division
AQCC .Regua regliat for transfer of ownership
and the submittal of revised APEN and the required fee.
23. If this permit specifically states thatfinal authorization has been granted, then the
remainder of this condition is not applicable. Otherwise, the issuance of this construction
permit does not proms '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 No. 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. Onceset-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.
24. This permit is issued in reliance upon the accuracy and completeness of information
supplied by the own 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.
25. 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.
26 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 revoket,at any time prior to self -certification and final authorization by the
Air Pollution Control„ ision (APCD) on grounds set forth in the Colorado Air Quality
Control Act and r g a ions of the Air Quality Control Commission (AQCC), including
failure to meet any'wexpress term or condition of the permit. If the Division denies a
permit, conditions unposed upon a permit are contested by the owner or operator, or the
Division revokes a permit, the owner or operator of a source may request a hearing
before the AQCC for review of the Division's action.
27. 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.
28. 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
AIRS ID: 123/9E1D Page 6 of 10
Permit Histo
li Health and Environment
it Pollution Control Division
Issuance
Date
Description
Issuance 1
This Issuance
Issued to Whiting Oil & Gas Corporation
AIRS ID: 123/9E1 D Page 7 of 10
Ith and Environment
olfution Control Division
Notes to Permit Holder �R1e'llfne
1) The permit holder is required to pay feet -for the processing time for this permit. An invoice for these
fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of
receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference:
Regulation No. 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 applicitiorr. 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
permitas 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 11.E.1 of the Common Provisions
Regulation. See: htto://vow.colorado.ggv/cs/Satellite?c=Docu t C&childoaaename=CDPHE-
Ma in%2FDocument C%2FCBONAddLinkView&cid=125159938964 aaename=CBONWraaaer
4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process
limb 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
Emission
Rate
(lb/yr)
Are the
emissions
reportable?
Controlled
Emission Rate
(Ib/yr)
001
Benzene
71432
14
No
14
n -Hexane
110543
76
No
76
Toluene
108883
44
No
44
Xylenes
1330207
39
No
39
002
Benzene
71432
5745
Yes -
287
n -Hexane
-110543
35640
Yes
` 1782
Toluene ,
108883
4518
Yes
226
Ethylbenzene
100414
588
Yes
29
Xylenes
1330207
951
Yes
48
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
Pollutant
Emission Factors
Uncontrolled
lb/BBL loaded
-
Source
VOC
0.0846
AP -42
The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1
(version 1/95) using the following values:
AIRS ID: 123/9E1 D
Page 8 of 10
Ii '`Health and Environment
it Pollution Control Division
L= 12.
S = 0.6 (Submerged loading: dedicated normal service)
P (true vapor pressure) = 2.8 psia
M (vapor molecular weight) = 50 Ib/Ib-mol
T (temperature of liquid loaded) = 519.7 °R
The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by
multiplying the mass fraction of each NCRP in the pressurized liquid sample by the VOC
emission factor.
Point 002:
Pollutant
Weight
Fraction of
Gas (%)
Emission
Factors
Uncontrolled
lb/MMscf
Emission
Factors
Controlled
Ib/MMscf
Source
NOx
---
90.78
90.78
AP -42, Chapter 13
CO
---
493.95
493.95
VOC
32.89
20828.00
1041.40
Gas Analysis
Benzene
0.09
57.45
2.87
Toluene
0.07
45.18
2.26
Ethylbenzene
0.01
5.88
0.29
Xylenes
0.02
9.51
0.48
n -hexane
0.56
356.40
17.82
Note: Emissions were calculated based on an extended natural gas analysis obtained from Razor
27K CTB on December 9, 2014 and the Displacement Equation found in EPA Emission Inventory
Improvement Program Publication: Volume II, Chapter 10 — Displacement Equation (10.4-3).
6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with
this permit is valid for a term of five years from the date it was received by the Division. A revised
APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the
most recent annual fee invoice to determine the APEN expiration date for each emissions point
associated with this permit. For any questions regarding a specific expiration date call the Division at
(303)-692-3150.
7) This facility is classified as follows:
Applicable
Requirement
Status
Operating Permit
Synthetic Minor Source of:
VOC, n -Hexane, Total HAP
PSD
Synthetic Minor/Major Source of:
VOC
MACT HH
Area Source Requirements: Not Applicable
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. g po access. q ov/
AIRS ID: 123/9E1D
Page 9 of 10
Iic�Health and Environment
it Pollution Control Division
Part 60: Standards'OiT6 fo ourcaill6
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 7777 - Subpart MMMMM
MACT
63.8980 -End
Subpart NNNNN - Subpart )OUWC(
9) A self certification form and guidance on how to self -certify compliance as required by this permit may
be obtained online at: htta://Www.colorado.aov/oacific/cdoheiair-permit-self-derdf ation
AIRS ID: 123/9E1 D Page 10 of 10
Division Information
Engineer:
Bradley Eades
Control Engineer:
Christopher Laplante
Review Date:
12/08/2015
Application Date:
05/05/2015
Facility Identifiers
Permit No.
15WE1247
AIRs
County#
123 'Weld
Facility #
9E1 D
Facility Type:
exploration and production facility
O Located in the 8 -hour non -attainment area?
Administrative Information
Potentially located in ozone nonattainment area
0 True Minor
0 Synthetic Minor for:
Ir voc
Company Name:
Whiting Oil & Gas Corporation
Source Name:
Cottonwood 08E-0504
Source Location:
SIC:
SW 1/4 of NW 1/4, Sec. 8, T9N, R57W
1311
Mailing
Address
Address 1:
Address 2:
ty, State Zip:
Whiting Oil & Gas Corporation
1700 Broadway, Suite 2300
Denver, CO 80290
Person To
Contact
Name:
Phone:
Fax:
Email:
Chenine Wozniak
303-802-8369
000-000-0000
CDPHECorresbondence@whiting.com
'Requested Action
Self Certification Required?
Issuance Number:
Yes
1
r NOx r Co
Source Description:
Oil and gas exploration and production facility known as the Cottonwood 08E-0504, located in the SW 1/4 of NW 1/4,
Sec. 8, T9N, R57W, Weld County, Colorado.
Point
Name
Type
Control
Action
001
Loadout
Loadout
None
Newly
reported
source
002
SEP-01
FLR-01,
Separator Venting
Flare
Newly
reported
source
001
Hydrocarbon Loadout to Tanker Trucks
Calculations
L =12.46*S*P*M/T (AP -42: Chapter 5.2, Equation 1)
L = loading losses in lb per 1000 gallons loaded
Factor
Meaning
Value
Units
Source
S
Saturation Factor
0.6
AP -42
P
True Vapor Pressure
2.8
psia
AP -42, Tab
M
Molecular Weight of Val
50
lb/lb-mole
AP -42, Tab
T
Liquid Temperature
519.67
deg. R
Field Data I
2.01 lb/10^3 gal
8.46E-02 lb/bbl
Annual requested Throughput
Annual requested VOC emissions
Control: None
Efficiency: 0.00%
NCRPs
Component.
Mass Fraction
Benzene
0.140%
n -hexane ;
0.760%
Toluene
0.440%
Xylenes
.0.390%
Source: Pressurized oil Razor 27K Pad
Emissions Summary Table
118260 BBL/yr
4966920 gal/yr
10004 lb/yr
5.00 tpy
le 7.1-2
7.1-3
Pollutant
Emission Factor
Emissions
Controlled Emissions
Source
VOC
0.0846
_Uncontrolled
lb/bbl
5.0 tpy
5.0 tpy
AP -42
Benzene
0.0001
lb/bbl
14.0 lb/yr
14.0 lb/yr
AP -42
n -Hexane
0.0006
lb/bbl
76 lb/yr
76 lb/yr
AP -42
Toluene
9.0004
lb/bbl
44 lb/yr
44 lb/yr
AP -42
Xylenes _
0.0003
_
lb/bbl
39 lb/yr
_ 39 lb/yr
AP -42
Regulatory Review
Is this site considee!ed an exploration and production location (e.g. well pad)?
If yes, review the following two exemptions for applicability:
Doss an *Water unload INN than 10.000 Mons (23$ BMA) par day of crud* oN on an mutual average basis?
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1
Does this operator unload less than 6,750 bbls per year of condensate via splash fill or
16,308 bbls per year of condensate via submerged fill procedure?
If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.I
No
Yes
No
One high pressure, 2 -phase separator controlled by one enclosed flare during downtime of Redtail Gas
002 Plant. Flare is enclosed and has a minimum control efficiency of 95%.
Equipment Description
This source vents natural gas from:
Emissions from this source are:
a well head separator
routed to a flare
Natural gas venting from a well head separator. Emissions from this source are routed to a flare.
Calculations
Emission Calculation Method
EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3)
Ex =Q*MW*Xx/C
Ex = emissions of pollutant x
Q = Volumetric flow rate/volume of gas processed
MW = Molecular weight of gas = SG of gas * MW of air
Xx = mass fraction of x in gas
C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm
Throughput (Q)
MW
100
MMscf/yr
Ib/Ib-mol
16666.66667
scf/hr
MMscf/d
24.023
0.4
mole %
MW
lbx/Ibmol
mass fraction
lb/hr
lb/yr
tpy
Helium
0.02
4.0026
0.001
0.000
0.04
211.22
0.11
CO2
2.64
44.01
1.162
0.048
51.09
306560.42
153.28
N2
1.15
28.013
0.322
0.013
14.17
84999.87
42.50
methane
71.06
16.041
11.399
0.475
501.30
3007772.15
1503.89
ethane
10.77
30.063
3.237
0.135
142.36
854154.08
427.08
propane
8.48
44.092
3.739
0.156
164.43
986567.23
493.28
isobutane
0.82
58.118
0.477
0.020
20.99
125927.44
62.96
n -butane
2.98
58.118
1.730
0.072
76.08
456463.99
228.23
isopentane
0.52
72.114
0.377
0.016
16.58
99494.49
49.75
n -pentane
0.68
72.114
0.492
0.020
21.62
129729.09
64.86
cyclopentane
0.06
70.13
0.046
0.002
2.00
12009.07
6.00
n -Hexane
0.16
86.18
0.135
0.006
5.95
35677.16
17.84
cyclohexane
0.04
84.16
0.037
0.002
1.63
9792.76
4.90
Other hexanes
0.28
86.18
0.242
0.010
10.64
63827.77
31.91
heptanes
0.14
100.21
0.145
0.006
6.37
38206.72
19.10
methylcyclohexane
0.03
98.19
0.033
0.001
1.46
8756.79
4.38
224-TMP
0.00
114.23
0.002
0.000
0.09
512.38
0.26
Benzene
0.03
78.12
0.022
0.001
0.96
5750.79
2.88
Toluene
0.02
92.15
0.017
0.001
0.75
4522.40
2.26
Ethylbenzene
0.00
106.17
0.002
0.000
0.10
588.28
0.29
Xylenes
0.00
106.17
0.004
0.000
0.16
952.45
' 0.48
C8+ Heavies
0.09
471.1770047
0.402
0.017
17.67
106045.91
53.02
VOC mass fraci
0.3289
Total VOC (Uncontrolled)
Notes
Mole %, MW, and mass fractions from Razor 27K CTB gas analysis collected 12/09/2014.
Emissions are based on 6000 hours of flaring per year.
I calculated the average MW of C8+ based on the average MW on the analysis for the gas.
1042.41
15WE1247.CP1.xlsm
Overall Control
95.00%
One high pressure, 2 -phase separator controlled by one enclosed flare during downtime of Redtail Gas
002 Plant. Flare is enclosed and has a minimum control efficiency of 95%.
Flaring Information
Equipment Description
Flare to combust low-pressure separator gas during Redtail Gas Plant downtime.
Manufacturer •,
SteRes
Model
SHP-6
Serial Number
102842
Gas Heating Value
1335
Btu/scf
Throughput
133500
MMBtuNr
"Flare has a custom built shroud to conform with Regulation 7 Section XVII control device requirments.
VRU Information
Equipment Description
ire to
to sales line.
Combustion emission faator source:
AP -42: Chapter 13.5
0.07 IIb NOXItlABtu
0.37 Ib COl1MABtu
Emissions Summary Table
Polknant
Uncontrolled Emission Factor
Controlled Emission Factor
Uncontrolled Emissions
Controlled Emissions
Source
V0C
20848
Ib/MMscf
1042.41 b/4 esd
1042.4 tpy
52.1 tpy i
Gas Analysis
Nox
90.78
lb/MMscf
90.78 b/MPMd
4.5 tpy
4.5 tpy- j
,AP 42
CO
, 493.95
Ib/MMscf
493.95 b/MMsd
24.7 tpy
24.7 tpy
AP -42
Benzene
57.51
lb/MMsd
3.88 lb/MMscf
5751 lb/yr
288 lb/yr
Gas Analysis
n -Hexane
36&77
le/MMscf
17.8386 Ib/MMsd
35677 lb/yr
1784 lb/yr
Gas Analysis
Toluene
45.224
lb/MMscf
2.2612 b/MMSCf
4522 lb/yr
226'b/yr
Gas Analysis
Xylenes
9.524
b/MMscf
0.4762 thiMPAscf
952 lb/yr
48 lb/yr
Gas Analysis
Ethylbenzene
5.883
Ib/MMscf
0.2941 Ib/MMscf
588 lb/yr
29 lb/yr
Gas Analysis
Emissions Summary Table (Reflected In Notes to Pe WWI,
Pollutant
Uncontrolled Emission Factor
Controlled Emission
Uncontrolled Emissions
Controlled Emissions
Source
V0C
20828.00
b/MMscf
1041.40
1041.4 tpy
52.1 tpy
Gas Analysis
Nox
90.78
b/MSABTU
90.78
4.5 tpy
4.5 tpy
AP -42.
CO
493.95
Ito/MMBTU
49195
r24.7 tpy
24.7 tpy
AP -42
Benzene
57.45
b/MMscf
2.87
5745 lb/yr
287 'Ib/yr
Gas Analysis
n -Hexane
358.40
b/MMscf
17.8200
35640 lb/yr
1782 lb/yr
Gas Analysis
Toluene
45.18
lb/aMilscf
2.2590
4518 lb/yr
226 lb/yr
Gas Analysis
Xylenes
9.51
lb/Wed
0.4755 b/MMgf
951 lb/yr
48 lb/yr
Gas Analysis
Ethylbenzene
5.88
Ib/MWscf
0.2940
588 lb/yr
29 lb/yr
Gas Analysis
As calculated by applicant
Regulatory Applicability
AQCC Regulation 1
This source is subject to the opacity requirements for flares in Section IIA.5:'No owner or operator of a smokeless flare or oth r
flare for the combustion of waste gases shall allow or cause emissions Wall* atmosphere of any air pollutant which is in 1
excess of 30% opacity.'
AQCC Regulation 2
Section IA apples to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air
contaminants from arty single source such as to result in detectable odors which are measured in excess of the laboring 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"
AOCC Regulation 7
Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014?
yes 02/14/2015 was projected startup date
This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, Section XVII.B.2
Application Notes:
15WE1247.CPLxIsm
One high pressure, 2 -phase separator controlled by one enclosed flare during downtime of Redtail Gas
002 Plant. Flare is enclosed and has a minimum control efficiency of 95%.
*Whiting has equipped the open flare with a custom built shroud capable of meeting the requirements of Reg. 7 Section XVII.
*A representative gas analysis was used for calculating emissions and emission factors from the Razor 27K Pad. A site -specific sample and emission factor
analysis will be required as an initial testing requirement to demonstrate compliance with the emissino factors identified in "notes to permit holder".
*Calculated emissions and emission factors varied slightly from calculations supplied by applicant. Differences are due to rounding and are insignificant.
Values in Notes to Permit Holder represent values as calculated by applicant.
*Chenine Wozniak was provided with a draft permit for comment on 12/9/2015. Chenine requested the following:
1 -The equipment/process description be revised to reflect "one high pressure separator" to replace "one low pressure separator•'
2 -Request NOS requirement be removed. They were submitted with the application in May 2015.
3-Process/Consumption Limits "Process Parameter be changed from "Gas Vented from Separator' to "Gas flared from separator"
4 -Change reference in condition 15 from "condensate" to "crude oil".
In response I agreed with and revised the permit to reflect request #2, #3 and #4. In response to request #1, I asked for clarification of the produced gas
source (2 -phase separator and/or 3 -phase separator) and the correct description was added.
15WE1247.CP1.xlsm E1247.CP1.xlsm
AIRS (County/Plant) 12319E1 D
Permit No. 15WE1247
Date 12/8/2015
Point *
SCC
Pollutant or CAS
Uncontrolled Emission
Factor
Emisison
Factor
Source
Controlled
Actual
Emissions
(tpy)'
Conbnled
Requested
Emissions
(tpy)•
PTE
(tpy)*
Ctrl.
Efl%
NCRP =
reportable
?
001
40600132
VOC
2.014 6/1000 ga
AP -42
5.00
5.00
0%
Yes
001 P40600132
Benzene
0. 0/1000 paAP-42
1400
f4.00
0%
No
001
40800132
n -Hexane
0.015 6/1000 ga
AP -42
76.00
76.00
0%
No
001
40800132
Toluene
0.009 611000 ga
AP 42
44.00
44.00
0%
No
001
40800132
Xylenes
0.008 611000 ga
AP -42
39.00
39.00
0%
No
002
31000205
VOC
20828 b4/IAMd
Gas Analysis
52.10
1041A0
95%
Yes
002
31000205
NOx
90.78 b/AOAed
AP -42
4.50
4.50
0%
Yes
002
31000205
CO
493.95 IbliadIsd
AP -42
24.70
24.70
0%
Yes
002
31000205
Benzene
57.45 b/MMsct
Gas Analysis
287.30
5745.00
95%
Yes
002
31000205
n -Hexane
356.4 b MMscf
Gas Analysis
1782.00
35840.00
95%
Yes
002
31000205
Toluene
45.18 b/MMsd
Gas Analysis
225.90
4518.00
95%
Yes
002
31000205
Ethylbenzene
5.88 6/MMsd
Gas Analysis
29.40
588.00
95%
Yes
002
31000205
Xylenes
9.51 b/MMscf
Gas Analysis
47.60
951.00
95%
Yes
1A
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Section 02 — Re
Section 01— Administrative Information
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303-802-8369
Phone Number:
Chenine Wozniak
Person To Contact:
303-861-4023
Fax Number:
E-mail Address:
100 MMscf/yr of flaring equates to 6,000 hr/yr of flaring
Section 03 — General Information
On
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For new or reconstructed sources, the projected startup date is:
For existing sources, operation began on:
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Section 08 — Emissions Invento
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4
Estimation
Method or
Emission
Factor Source
Gas Analysis I
N
N
I Gas Analysis I
Mg
T'
Ts
U
Gas Analysis
Gas Analysis
Gas Analysis
pollutants not listed above.
Requested Permitted Emissions
Controlled
(Tons/Year)
52.07
4.55
24.78
-
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Emission Factor
Units
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Control
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Overall
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Control Device Description
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Section 02 —Re
Section 01 — Administrative Information
General Permit GP07
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E-mail Address:
Phone Number: 303-802-8369
Addl. Info. & Notes:
Section 03 — General Information
days/week 52
Normal Hours of Source Operation:
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Date operation began or projected startup date:
Truck Loadout of crude oil.
General description of equipment and purpose:
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