HomeMy WebLinkAbout20131779.tiffSTATE OF COLORADO
John W. Hickenlooper, Governor
Christopher E. Urbina, MD, MPH
Executive Director and Chief Medical Officer
Dedicated to protecting and improving the health and environment of the people of Colorado
4300 Cherry Creek Dr. S.
Denver, Colorado 80246-1530
Phone (303) 692-2000
Located in Glendale, Colorado
http://www.cdphe.state.caus
Weld County Clerk & Recorder
1402 N 17th Ave
Greeley, CO 80631
June 25, 2013
Dear Sir or Madam:
Laboratory Services Division
8100 Lowry Blvd.
Denver, Colorado 80230-6928
(303) 692-3090
Colorado Department
of Public Health
and Environment
RECEIVED
JUL 0 8 2013
WELD Y
COMMI SI0NE S
On June 28, 2013, the Air Pollution Control Division will publish a public notice for EOG Resources — Lion
Creek 09-35H, in the The Greeley Tribune. 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 date the public notice is
published. Please send any comment regarding this public notice to the address below.
Colorado Dept. of Public Health & Environment
APCD-S S -B 1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Clara Gonzales
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
7163
2013-1779
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:
Stuart Siffring
Colorado Department of Public Health and Environment
4300 Cherry Creek Drive South, APCD-SS-B 1
Denver, Colorado 80246-1530
cdphe.commentsapcd@state.co.us
STATE OF COLORADO
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
TELEPHONE: (303) 692-3150
CONSTRUCTION PERMIT
PERMIT NO:
DATE ISSUED:
ISSUED TO:
11WE3170
EOG Resources, Inc.
Issuance 1
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Oil and gas production facility, known as Lion Creek 09-35H, located in the SESE of Section
35, Township 11 North, Range 64 West, in Weld County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
Facility
Equipment
ID
AIRS
Point
Description
Generator
RICE
Engine
001
One (1) Waukesha, Model F1197GU, Serial Number 317682,
natural gas -fired, naturally aspirated, 4SRB reciprocating internal
combustion engine, site rated at 136 horsepower at 1200 RPM.
This engine shall be equipped with a non -selective catalytic
reduction (NSCR) system and air -fuel ratio control. This emission
unit is used for primary power until electricity can be run to the
location.
Crude Oil
Storage
Tanks
002
Six (6) above ground 400 bbl atmospheric crude oil storage tanks.
Emissions from these tanks are controlled by a Cimarron
smokeless VCU unit with 95% control efficiency.
ET #4480
004
One (1) 400 BBL fixed roof storage tank used to store gas in the
event that there is a need to vent the gas around the flare.
Emissions from this tank are not controlled.
Flare
005
Separator controlled by a 40' flare stack. Flare has a minimum
combustion efficiency of 95%. The flare is not enclosed.
Fugitive
006
Equipment leaks (fugitive VOCs) from a natural gas production
facility.
Point 001 may be replaced with another engine in accordance with the temporary engine
replacement provision or with another Waukesha Model F1197GU engine in accordance with
the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this
permit as Attachment A.
THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR
QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND
AIRS ID: 123/9324/999
Page 1 of 18
Condensate Tank Version 2009-1
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
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. YOU MUST notify the APCD no later than fifteen days after issuance of this permit or
activity by submitting a Notice of Startup (NOS) form to the APCD. The Notice of
Startup (NOS) form may be downloaded online at
www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the
permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can
result in the revocation of the permit.
2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the
conditions contained on this permit shall be demonstrated to the Division. It is the permittee'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, II.G.2).
3. This permit shall expire if the owner or operator of the source for which this permit *as
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 fora 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 per
Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, 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.
(Reference: Regulation No. 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 (as calculated in the
Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4)
Annual Limits:
AIRS ID: 123/9324/999 Page 2 of 18
EOG Resources, Inc.
Permit No, 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
Facility
Equipment ID
AIRS
point
Tons per Year
Emission Type
yp
NO,
VOC
CO
Generator
RICE Engine
001
1.8
1.0
2.1
Point
Crude Oil
Storage Tanks
002
---
0.2
---
Point
ET #4480
004
---
2.5
---
Point
Flare
005
1.8
30.3
9.6
Point
Fugitive
006
---
6.2
---
Fugitive
See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate
limits.
Compliance with the synthetic minor status of this facility shall be determined by recording
the facility's annual criteria pollutant emissions, from each emission unit, on a rolling (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 monthly emissions and
keep a compliance record on site or at a local field office with site responsibility, for Division
review. This rolling twelve-month total shall apply to all emission units, requiring an APEN,
at this facility.
7. Point 001: This engine shall be equipped with a non -selective catalytic reduction (NSCR)
system and air -fuel ratio control. The NSCR shall reduce uncontrolled emissions of NOx
and CO from the unit to the emission levels listed in this section, above. Operating
parameters of the control equipment are identified in the operation and maintenance plan.
(Reference: Regulation No.3, Part B, Section III.E.)
8. Point 002: This emissions point shall be configured with an enclosed combustor. The
combustor shall reduce the uncontrolled emissions of VOC to the emission levels listed in
this section, above. Operating parameters of the control equipment are identified in the
operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.)
9. Point 005: This emissions point is a separator controlled by a 40' flare stack. The flare
shall reduce emissions of VOC to the emission levels listed in this section, above. Operating
parameters of the control equipment are identified in the operation and maintenance plan.
(Reference: Regulation No.3, Part B, Section III.E.)
10. Point 006: The operator shall calculate actual emissions from this emissions point based
on representative component counts for the facility with the most recent gas and liquids
analyses, as required in the Compliance Testing and Sampling section of this permit. The
operator shall maintain records of the results of component counts and sampling events
used to calculate actual emissions and the dates that these counts and events were
completed. These records shall be provided to the Division upon request.
PROCESS LIMITATIONS AND RECORDS
11. This source shall be limited to the following maximum consumption, processing and/or
operational rates as listed below. Monthly records of the actual throughput shall be
maintained by the applicant and made available to the Division for inspection upon request.
(Reference: Regulation 3, Part B, II.A.4)
AIRS ID: 123/9324/999 Page 3 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
Process/Consumption Limits
Facility
Equipment ID
AIRS
Point
Process Parameter
Annual Limit
Generator
RICE Engine
001
Consumption of natural gas as a fuel
9.0 MMscf/yr
Crude Oil
Storage Tanks
002
Crude oil throughput
9,213 BBL/yr
ET #4480
004
Natural gas venting to atmosphere
140,200 SCF/yr
Flare
005
Natural gas flaring
34.2 MMSCF/yr
Compliance with the yearly 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 monthly crude oil throughput
and keep a compliance record on site or at a local field office with site responsibility, for
Division review.
STATE AND FEDERAL REGULATORY REQUIREMENTS
12. The permit number and AIRS ID number shall be marked on the subject equipment for ease
of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable)
13. 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. (Reference: Regulation No. 1, Section II.A.1. & 4.).
14. No owner or operator of a smokeless flare or other flare for the combustion of waste
gases shall allow or cause emissions into the atmosphere of any air pollutant which is in
excess of 30% opacity for a period or periods aggregating more than six minutes in any
sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.).
15. These sources are subject to the odor requirements of Regulation No. 2. (State only
enforceable)
16. Point 001: This equipment is subject to the control requirements for natural gas -fired
reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State
only enforceable). The owner or operator of any natural gas -fired reciprocating internal
combustion engine that is either constructed or relocated to the state of Colorado from
another state after the date listed in the table below shall operate and maintain each engine
according to the manufacturer's written instructions or procedures to the extent practicable
and consistent with technological limitations and good engineering and maintenance
practices over the entire life of the engine so that it achieves the emission standards
required in the table below: Note that this condition may not apply if the engine is subject to
standards under NSPS or MACTs (see Reg 7 XVII.B.4). Note that there must be an actual
emission standard under NSPS/MACT in order for Reg 7 to not apply. Note also that in
most cases, the NSPS/MACT standards will be the same as what would be required for
Reg. 7:
Maximum Engine
Construction or
Emission Standard in g/hp-hr
AIRS ID: 123/9324/999
Page 4 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
HP
Relocation Date
NOx
CO
VOC
<100HP
Any
N/A
N/A
N/A
≥100HP and
January 1, 2008
2.0
4.0
1.0
<500HP
January 1, 2011
1.0
2.0
0.7
≥500HP
July 1, 2007
July 1, 2010
2.0
1.0
4.0
2.0
1.0
0.7
OPERATING & MAINTENANCE REQUIREMENTS
17. Points 001, 002 and 005: Upon startup of these points, the applicant shall follow the
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 Requirements
18. Point 001: A source initial compliance test shall be conducted on emissions point 001 to
measure the emission rate(s) for the pollutants listed below in order to demonstrate
compliance with the emissions limits contained in this permit. The test protocol must be in
accordance with the requirements of the Air Pollution Control Division Compliance Test
Manual and shall be submitted to the Division for review and approval at least thirty (30)
days prior to testing. No compliance test shall be conducted without prior approval from the
Division. Any compliance test conducted to show compliance with a monthly or annual
emission limitation shall have the results projected up to the monthly or annual averaging
time by multiplying the test results by the allowable number of operating hours for that
averaging time (Reference: Regulation No. 3, Part B., Section III.G.3)
Oxides of Nitrogen
Carbon Monoxide
Volatile Organic Compounds
19. Point 002: The operator shall complete site specific sampling including a compositional
analysis of the pre -flash pressurized crude oil routed to these storage tanks and a sales oil
analysis to determine RVP and API gravity. Testing shall be in accordance with the
guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site -
specific emissions factor using Division approved methods. Results of site -specific sampling
and analysis shall be submitted to the Division as part of the self -certification and used to
demonstrate compliance with the emissions factors chosen for this emissions point.
20. Points 004 and 005: The operator shall complete an initial site specific extended gas
analysis of the natural gas produced at this site that is either routed to the open flame flare
or vented through the emergency blowdown tank in order to verify the VOC, benzene,
toluene, ethylbenzene, xylenes, n -hexane, and 2,2,4-trimethylpentane content (weight
fraction) of this emission stream used in the permit application. Results of testing shall be
used to determine site -specific emission factors using Division approved methods. Results
of site -specific sampling and analysis shall be submitted to the Division as part of the self -
AIRS ID: 123/9324/999 Page 5 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
certification and used to demonstrate compliance with the emissions factors chosen for this
emissions point.
For example, the benzene emission factor shall be calculated according to the following
equation using the benzene weight fraction and the natural gas's average molecular weight
determined in the site -specific gas analysis:
lb bense>ae ibsnoi. a, 1s6scf
x = benzene wt. frac.* k �14W ,no'-
MM:cf 379.3 EC - gaa lb ,no' 1MMscf,
21. Point 005: The owner or operator shall demonstrate compliance with Condition 16 using
EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section
I I.A.5).
22. Point 006: Within one hundred and eighty days (180) after issuance of permit the operator
shall complete a hard count of components at the source and establish the number of
components that are operated in "heavy liquid service", "light liquid service", "water/oil
service" and "gas service". The operator shall submit the results to the Division as part of
the self -certification process to ensure compliance with emissions limits.
23. Point 006: Within one hundred and eighty days (180) after issuance of permit, the permittee
shall complete the initial extended gas analysis of gas samples and extended natural gas
liquids analysis of liquids that are representative of volatile organic compound (VOC) and
hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended
gas and liquids analyses shall be used in the compliance demonstration as required in the
Emission Limits and Records section of this permit. The operator shall submit the results of
the gas and liquids analyses and emission calculations to the Division as part of the self -
certification process to ensure compliance with emissions limits.
Periodic Testing Requirements
24. Point 001: This engine is subject to the periodic testing requirements as specified in the
operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M
plan are subject to Division approval. Replacements of this unit completed as Alternative
Operating Scenarios may be subject to additional testing requirements as specified in
Attachment A.
25. Points 004 and 005: On an annual basis, the operator shall complete a site specific
extended gas analysis of the natural gas produced at this site that is routed to the flare in
order to verify the VOC content (weight fraction) of this emission stream used in the permit
application. Results of testing shall be used to determine site -specific emission factors using
Division approved methods.
26. Point 006: On an annual basis, the owner or operator shall complete a gas analysis of gas
samples that are representative of volatile organic compounds (VOC) and hazardous air
pollutants (HAP) that may be released as fugitive emissions. This gas analysis shall be
used in the compliance demonstration as required in the Emission Limits and Records
section of this permit.
ADDITIONAL REQUIREMENTS
27. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3,
Part A, II.C)
a. Annually whenever a significant increase in emissions occurs as follows:
AIRS ID: 123/9324/999 Page 6 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
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 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.
f. Point 001 Within 14 calendar days of commencing operation of a permanent
replacement engine under the alternative operating scenario outlined in this permit
as Attachment A. The APEN shall include the specific manufacturer, model and
serial number and horsepower of the permanent replacement engine, the
appropriate APEN filing fee and a cover letter explaining that the permittee is
exercising an alternative -operating scenario and is installing a permanent
replacement engine.
28. Federalregulatory 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
29. 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 No. 3, Part B, Section II.B upon a request for transfer of ownership and the
submittal of a revised APEN and the required fee.
30. 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 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. 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.
31. This permit is issued in reliance upon the accuracy and completeness of information
supplied by the applicant and is conditioned upon conduct of the activity, or construction,
AIRS ID: 123/9324/999 Page 7 of 18
EOG Resources, Inc:
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
installation and operation of the source, in accordance with this information and with
representations made by the applicant or applicant's agents. It is valid only for the
equipment and operations or activity specifically identified on the permit.
32. 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.
33. Each and every condition of this permit is a material part hereof and is not severable. Any
challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit
and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be
revoked at any time prior to self -certification and final authorization by the Air Pollution
Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and
regulations of the Air Quality Control Commission (AQCC), including failure to meet any
express term or condition of the permit. If the Division denies a permit, conditions imposed
upon a permit are contested by the applicant, or the Division revokes a permit, the applicant
or owner or operator of a source may request a hearing before the AQCC for review of the
Division's action.
34. 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.
35. 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:
Stuart Siffring
Permit Engineer
Air Pollution Control Division
Permit Histo
Issuance
Date
Description
Issuance
1
This
Issuance
Facility -wide permit for: (1) Generator RICE, (6) crude oil tanks and VCU,
(1) emergency tank, (1) tornado flare, (1) produced water tank , facility
fugitive emissions, and crude oil loadout. New synthetic minor facility.
AIRS ID: 123/9324/999
Page 8of18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
Notes to Permit Holder:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees
will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of
the invoice. Failure to pay the invoice will result in revocation of this permit (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 application. These limits may be revised upon request of
the permittee 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 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 permittee 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:
http://www.cdphe.state.co. us/regulations/airreqs/100102agcccommonprovisionsreq. pdf.
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 #
BIN
Uncontrolled
Emission
Rate
(lb/yr)
Are the
emissions.
reportable?
Controlled
Emission
Rate (lb/yr)
001
Formaldehyde
50000
A
188
Yes
188
Acetaldehyde
75070
A
25
No
25
Acrolein
107028
A
24
No
24
Benzene
71432
A
14
No
14
002
Benzene
71432
A
53
Yes
3
Toluene
108883
C
53
No
3
Ethylbenzene
100414
C
0
No
0
Xylenes
1130207
C
0
No
0
n -Hexane
110543
C
368
No
18
2,2,4-
Trimethylpentane
540841
C
53
No
3
004
Benzene
71432
A
10
No
10
Toluene
108883
C
8
No
8
Ethylbenzene
100414
C
2
No
2
Xylenes
1130207
C
3
No
3
n -Hexane
110543
C
68
No
68
005
Benzene
71432
A
1246
Yes
62
Toluene
108883
C
941
No
47
AIRS ID: 123/9324/999
Page 9 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
Ethylbenzene
100414
C
159
No
8
Xylenes
1130207
C
391
No
20
n -Hexane
110543
C
8112
Yes
406
006
Benzene
71432
A
89
Yes
89
Toluene
108883
C
198
No
198
Ethylbenzene
100414
C
13
No
13
Xylenes
1130207
C
231
No
231
n -Hexane
110543
C
561
No
561
5) The emission levels contained in this permit are based on the following emission factors:
Point 001:
CAS
Pollutant
Emission
Uncontrolled
lb/MMBtu
Factors -
g/bhp-hr
Emission
Controlled
Ib/MMBtu
Factors —
g/bhp-hr
NOx
2.86
10
0.40
1.3
CO
11.2
39
0.45
1.6
VOC
0.217
0.93
0.217
0.93
50000
Formaldehyde
0.0205
0.0874
0.0205
0.0874
75070
Acetaldehyde
0.0028
0.0119
0.0028
0.0119
107028
Acrolein
0.0026
0.0112
0.0026
0.0112
71432
Benzene
0.0016
0.0067
0.0016
0.0067
Emission factors are based on a Brake -Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site -rated
horsepower value of 136, and a fuel heat value of 1020 Btu/scf.
Emission Factor Sources:
CAS
Pollutant
Uncontrolled EFSource
Controlled EF Source
NOx
Manufacturer
Manufacturer
CO
Manufacturer
Manufacturer
VOC
Manufacturer
Manufacturer
50000
Formaldehyde
AP -42
AP -42
Point 002:
CAS #
Pollutant
Emission Factors
Uncontrolled
Emission Factors
Controlled
Source
NOx
0.068 lb/MMBtu
0.068 lb/MMBtu
AP -42, Table 13.5-1
CO
0.37 lb/MMBtu
0.37 lb/MMBtu
AP -42, Table 13.5-1
VOC
0.74 lb/bbl
0.037 lb/ bbl
E&P Tanks
71432
Benzene
0.00084 lb/bbl
0.000042 lb/bbl
E&P Tanks
Note: The controlled emissions factors for point 002 are based on the combustor control efficiency
of 95%. These emission factors were developed using a pressurized liquids analysis from the
nearby Critter Creek 2-03H well.
AIRS ID: 123/9324/999
Page 10 of 18
EOG Resources, Inc.
Permit No. 11WE317O
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
Point 004:
CAS #
Pollutant
Emission Factors
Uncontrolled
Lb/MMscf
Weight Fraction of
Gas r/o)
Source
VOC
35428 lb/MMscf
48.72
Engineering
Calculation
71432
Benzene
74.9333 lb/MMscf
0.11
Engineering
Calculation
108883
Toluene
56.5333 lb/MMscf
0.08
Engineering
Calculation
100414
Ethylbenzene
9.60 lb/MMscf
0.01
Engineering
Calculation
1330207
Xylenes
23.4667 lb/MMscf
0.03
Engineering
Calculation
110543
n -hexane
459.4667 lb/MMscf
0.67
Engineering
Calculation
The emission levels in this permit for this point are based on the use of this tank to blowdown produced
natural gas when the flare used to combust the natural gas is down at three (3) events per year and
twelve (12) hours of venting through this tank per event at a maximum gas flow rate of 140200 scf/day.
The VOC content of the produced gas used in the application was based on a gas sample from the
Critter Creek 2-03H well (weight percents for VOC and HAP components from this analysis are listed
in the table above).
Point 005:
CAS #
Pollutant
Weight
Fraction
of Gas
(%)
Emission
Factors
Uncontrolled
Emission
Factors
Controlled
Source
NOx
0.068 lb/MMBtu
0.068 lb/MMBtu
AP -42
CO
0.37 lb/MMBtu
0.37 lb/MMBtu
AP -42
VOC
48.72
35487 lb/mmscf
1680 lb/mmscf
Engineering
Calculation
PM10
40 ugh'
40 ugh
AP -42, Table
13.5-1
SOx
0.00036
lb/MMBtu
0.00036
lb/MMBtu
0.002 gr/scf
71432
Benzene
0.11
36.5 Ib/MMscf
1.825 lb/mmscf
Engineering
Calculation
108883
Toluene
0.08
27.6 lb/MMscf
1.38 lb/mmscf
Engineering
Calculation
100414
Ethylbenzene
0.01
4.65 lb/MMscf
lb/mmscf
Engineering
allat
Calculation
1330207
Xylenes
0.03
11.46 lb/MMscf
0.573 lb/mmscf
Engineering
Calculation
110543
n -hexane
0.67
237.8 lb/MMscf
11.89 lb/mmscf
Engineering
Calculation
Note: The uncontrolled VOC and HAP emissions for this point were calculated using the analysis of
a gas sample collected from the Critter Creek 2-03H well. The controlled VOC and HAP
emissions factors for point 005 are based on the flare control efficiency of 95%.
Point 006:
AIRS ID: 123/9324/999
Page 11 of18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
Component
Gas Service
Heavy Oil
Light Oil
Water/Oil
Service
Connectors
432
---
390
39
Flanges
4
---
24
4
Open -Ended Lines
9
---
7
5
Pump Seals
---
---
2
---
Valves
42
---
54
18
Other
26
---
12
4
VOC Content (wt%)
3.5% _
100%
99.86%
100%
Benzene Content (wt%)
0.023%
---
0.027%
---
Toluene Content (wt%) _
0.039%
---
0.075%
---
Ethylbenzene (wt %)
0.002%
---
0.017%
---
Xylenes Content (wt%)
0.01%
---
0.036%
---
n-hexane Content (wt%)
0.67%
---
4.08%
---
*Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains,
dump arms, hatches, instrument meters, polish rods and vents
TOC Emission Factors (kg/hr-component):
Component
Gas Service
Heavy Oil
Light Oil
Water/Oil
Service
Connectors
2.0E-04
7.5E-06
2.1E-04
1.1E-04
Flanges
3.9E-04
3.9E-07
1.1E-04
2.9E-06
Open-ended Lines
2.0E-03
1.4E-04
1.4E-03
2.5E-04
Pump Seals
2.4E-03
NA
1.3E-02
2.4E-05
Valves
4.5E-03
8.4E-06
2.5E-03
9.8E-05
Other
8.8E-03
3.2E-05
7.5E-03
1.4E-02
Source: EPA -453/R95-017
Compliance with emissions limits in this permit will be demonstrated by using the TOC emission
factors listed in the table above with representative component counts, multiplied by the VOC
content from the most recent gas and liquids analyses
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
VOC
PSD
Synthetic Minor Source
VOC
AIRS ID: 123/9324/999
Page 12 of 18
EOG Resources, Inc.
Permit No. 11 WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
MACT HH
Area Source Requirements: Not Applicable
MACT ZZZZ
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.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
9) An Oil and Gas Industry Construction Permit Self -Certification Form is included with this permit packet.
Please use this form to complete the self -certification requirements as specified in the permit conditions.
Further guidance on self -certification can be found on our website at:
http://www.cdphe.state.co.us/ap/oilgaspermitting.html
AIRS ID: 123/9324/999 Page 13 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
ATTACHMENT A:
ALTERNATIVE OPERATING SCENARIOS
RECIPROCATING INTERNAL COMBUSTION ENGINES
October 12, 2012
2. Alternative Operating Scenarios
The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired
reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3.,
Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction
Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant
Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit
incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this
AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to
this permit or obtaining a new Construction Permit.
2.1 Engine Replacement
The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic
routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent
replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period.
"Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the
total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a
single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS
are in addition to any compliance demonstrations or periodic monitoring required by this permit.
All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit
(including monitoring and record keeping).
The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30
calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or
MACT requirements.
Results of all tests shall be kept on site for five (5) years and made available to the Division upon request.
The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine
replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that
are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the
replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports
required under section 2.1.2 and make them available to the Division upon request.
2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits
set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different
manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary
replacement engine complies with all permit limitations and other requirements applicable to the existing engine.
Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2.
AIRS ID: 123/9324/999 Page 14 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same
manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement
engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new.
applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine
and compliance with the applicable emission limitations shall be made as set forth in section 2.2.
An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and
horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine
within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the.
appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating
scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the
replacement engine. Example Applicability
Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a
certification from the Responsible Official indicating that "based on the information and belief formed after reasonable
inquiry, the statements and information included in the submittal are true, accurate and complete".
This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that
is not subject to emission limits.
The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information
submitted to the Division in regard to any permanent engine replacement.
2.2 Portable Analyzer Testing
Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable
Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing
requirements.
Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the
permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under
the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months).
The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this
Condition, if approved in advance by the Division.
The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the
replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the
replacement engine.
All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer
Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at:
litto://www.colorado.govics/Satellite/CDPHE-APiCBON/125 1596520270.
Results of the portable analyzer tests shall be used to monitor the compliance status of this unit.
For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be
converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in
order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the
maximum number of hours in the month or year (8760), whichever applies.
For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration
based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the
AIRS ID: 123/9324/999 Page 15 of 18
EOG Resources, Inc.
Permit No. 11 WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer
Monitoring Protocol document.
If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of
credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO
emission limitations for the relevant time period.
Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable
analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be
considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates
compliance with both the NOX and CO emission limitations or until the engine is taken offline.
2.3 Applicable Regulations for Permanent Engine Replacements
2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2
All permanent replacement engines that are located in an area that is classified as attainment/maintenance or
nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is
attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be
applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment,
except as follows:
In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PMIO at any level of emissions and to
NOX and SO2, as precursors to PMIO, if the potential to emit of NOX or SO2 exceeds 40 tons/yr.
For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal
combustion engines:
VOC: The emission limitations in NSPS JJJJ
CO: The emission limitations in NSPS JJJJ
NOX: The emission limitations in NSPS JJJJ
S02: Use of natural gas as fuel
PM10: Use of natural gas as fuel
As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or
less of total sulfur per 100 standard cubic feet.
2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only
conditions).
Control Requirements: Section XVI
Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the
applicable control requirements specified in Regulation No. 7, section XVI, as specified below:
Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and
air fuel controller to reduce emission.
Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to
reduce emissions.
The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained
according to manufacturer specifications. -
AIRS ID: 123/9324/999 Page 16 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2.
Emission Standards: Section XVII E — State -only requirements
Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date
listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or
procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance
practices over the entire life of the engine so that it achieves the emission standards required in the table below:
Construction or
Emission Standards in G/hp-hr
Max Engine HP
Relocation Date
NOx
CO
VOC
January 1, 2008
2.0
4.0
1.0
100<Hp<500
January 1, 2011
1.0
2.0
0.7
500<Hp
July 1, 2007
July 1, 2010
2.0
1.0
4.0
2.0
1.0
0.7
The source shall submit copies of the relevant Applicability Reports required under Condi ion 2.1.2.
2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ
A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp,
7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines
greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp
and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable
monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the
Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by
this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under
Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame
specified in Condition 2.2.
Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the
State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation
No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes
of determining the applicability of NSPS JJJJ requirements).
However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine
subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional
step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § IB (which is
referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is
considered to be a new source, subject to the requirements of NSPS JJJJ.
2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ
A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part
63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the
permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing
required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can
serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such
test is conducted within the time frame specified in Condition 2.2.
AIRS ID: 123/9324/999 Page 17 of 18
EOG Resources, Inc.
Permit No. 11WE3170
Issuance 1
Colorado Department of Public Health and Environment
Air Pollution Control Division
2.4 Additional Sources
The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new
emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced
construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that
is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing
onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation.
AIRS ID: 123/9324/999 Page 18 of 18
Construction Permit Application
Preliminary Analysis Summary
Section 1 —Applicant Information
Company Name:
EOG Resources, Inc.
Permit Number:
11WE3170
Source Location:
SESE S35, T11 N, R64W, Weld County (Attainment)
Equipment Description:
Point 001: 4SRB internal combustion engine
Point 002: (6) 400 BBL above ground atmospheric crude oil storage
tanks
Point 004: (1) 400 BBL above ground atmospheric emergency storage
tank for vented gas.
Point 005: Plant flare with a minimum combustion efficiency of 95%.
Point 006: Fugitive emissions
AIRS ID:
123-9324
Date:
7/30/12
Review Engineer:
Stuart Siffring
Control Engineer:
Carissa Money
Section 2 — Action Completed
Grandfathered
Modification i
APEN Required/Permit Exempt
X
CP1
Transfer of Ownership I
APEN Exempt/Permit Exempt
"If tank is a true minor source at a true minor facility, it shall be granted "Final Approval"
Section 3 — Applicant Completeness Review
Was the correct APEN submitted for this source type?
X
Yes
No
Is the APEN signed with an original signature?
X
Yes
No
Was the APEN filled out completely?
Yes
No
Did the applicant submit all required paperwork?
Yes
No
Did the applicant provide ample information to determine emission rates?
Yes
No
If you answered "no" to any of the above,
when did you mail an Information
Request letter to the source?
On what date was this application
complete?
08/11/2011
Section 4 — Source Description
AIRS Point
Equipment Description
001
002
One (1) Waukesha, Model F1197GU, Serial Number 317682, natural gas -fired,
naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at
136 horsepower at 1200 RPM. This engine shall be equipped with a non -selective
catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is
used for primary power until electricity can be run to the location.
Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from
these tanks are controlled by a Cimarron smokeless combustor (vapor recovery
unit) with 95% control efficiency.
Page 1
004
One (1) 400 BBL fixed roof storage tank used to store gas in the event that there is
a need to vent the gas rather than put it into the pipeline. Emissions from this tank
are not controlled.
005
Separator controlled by a 40' flare stack. Flare has a minimum combustion
efficiency of 95%. The flare is not enclosed.
006
Fugitive emission leaks from connectors, valves, flanges and other equipment.
Is this a portable source?
Yes X
No
Is this location in a non -attainment area for any criteria
pollutant?
Yes
X
No
If "yes", for what pollutant?
PM10
CO
Ozone
Is this location in an attainment maintenance area for
any criteria pollutant?
Yes
X
No
If "yes'; for what pollutant?
(Note: These pollutants are subject to minor source
RACT per Regulation 3, Part B, Section III.D.2)
PM1D
CO
Ozone
Is this source located in the 8 -hour ozone non -
attainment region? (Note: If "yes" the provisions of
Regulation 7, Sections XII and XVII.C may apply)
Yes
X
No
Section 5 — Emission Estimate Information
AIRS Point
Emission Factor Source
001
Manufacturer emission factors for NOx, VOC and CO
AP -42 for HAPS
002
Site -specific using E&P Tanks
004
Site -specific using VOC weight fraction
005
AP -42 for NOx and CO, Site -specific using VOC weight fraction
006
Site -specific using VOC weight fraction and EPA factors
Did the applicant provide actual process data for the emission inventory?
X
Yes
No
Basis for Potential to Emit (PTE)
AIRS Point
Process Consumption/Throughput/Production
001
9.0 MMscf/yr
002
9,213 BBL per year
004
140,200 scf/yr => 0.14 MMSCF/yr
005
93,500 scf/day => 34.13 mmscf/yr
006
6.2 tons per year VOC from fugitive leaks
Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory)
AIRS Point
Process Consumption/Throughput/Production
Data Year
001
9.0 MMscf/yr
2011
002
9,213 BBL per year
004
140,200 scf/yr => 0.14 MMSCF/yr
005
93,500 scf/day => 34.13 mmscf/yr
006
6.2 tons per year VOC from fugitive leaks
Basis for Permitted Emissions (Permit Limits)
AIRS Point
Process Consumption/Throughput/Production
Page 2
001
9.0 MMscf/yr
002
9,213 BBL per year
004
140,200 scf/yr => 0.14 MMSCF/yr
005
93,500 scf/day => 34.13 mmscf/yr
006
6.2 tons per year VOC from fugitive leaks
Does this facility use control devices?
X
Yes
No
AIRS Point
Process
Control Device Description
% Reduction
Granted
001
01
NSCR and AFRC
NOx: 86%;
CO: 96%;
002
01
Cimarron smokeless combustor (VCU)
95
005
01
Tornado 40' flare stack
95
Section 6 — Emission Summary (tons
oer year)
Point
NO„
VOC
CO
SOx
PM10
Single HAP
Total
HAP
PTE:
001
13.1
1.0
51.2
---
---
0.1
(formaldehyde)
0.2
002
0.02
3.4
0.03
---
--'
0.1
(n -hexane)
0.2
004
---
.2.5
---
---
-__
0.3
(n -hexane)
0.5
005
1.8
605.3
9.6
---
--
4.1
(n -hexane)
5.5
006
---
6.2
---
---
--
0.1 (n -hexane)
0.4
Uncontrolled point
source emission rate:
001
13.1
1.0
51.2
---
---
0.1
(formaldehyde)
0.2
002
0.02
3.4
0.03
---
---
0.1
(n -hexane
0.2
004
---
2.5
---
---
---
0.3 {n hexane}
0.5
005
1.8
605.3
9.6
---
---
4.1
(n -hexane)
5.5
006
---
6.2
---
---
---
0.1 (n -hexane)
0.4
TOTAL (TPY)
14.9
619.8
60.9
---
---
4.7 (n -hexane)
6.6
Controlled point
source emission rate:
001
1.77
1.0
2.1
---
-"
0.1
(formaldehyde)
0.2
002
0.02
0.17
0.03
---
---
0.1 (n -hexane)
0.2
004
---
2.5
---
---
--
0.3
{n -hexane}
0.5
005
1.8
30.27
9.6
---
---
0.3
(n -hexane)
0.5
006
---
6.2
---
---
---
0.1 (n -hexane)
0.2
INSIGNIFICANTS
(TPY)
0.4
0.0
0.4
---
__
0.14 (n-
hexane)
0.17
TOTAL PERMITTED
(TPY)
3.6
41.0
11.7
---
--
0.6 (n -hexane)
1.1
Section 7 — Non -Criteria / Hazardous Air Pollutants
Pollutant
CAS #
BIN
Uncontrolled
Emission Rate
(Ib/yr)
Are the
emissions
reportable?
Controlled Emission
Rate (lb/yr)
Page 3
Point 001
Formaldehyde
50000
A
188
Yes
188
Acetaldehyde
75070
A
25
No
25
Acrolein
107028
A
24
No
24
Benzene
71432
A
14
No
14
Point 002
Benzene
71432
A
53
Yes
3
Toluene
108883
C
53
No
3
Ethylbenzene
100414
C
0
No
0
Xylenes
1130207
C
0
No
0
n -Hexane
110543
C
368
No
18
2,2,4-Trimethylpentane
540841
C
53
No
3
Point 004
Benzene
71432
A
10
No
10
Toluene
108883
C
8
No
8
Ethylbenzene
100414
C
2
No
2
Xylenes
1130207
C
3
No
3
n -Hexane
110543
C
68
No
68
Point 005
Benzene
71432
A
1246
Yes
62
Toluene
108883
C
941
No
47
Ethylbenzene
100414
C
159
No
8
Xylenes
1130207
C
391
No
20
n -Hexane
110543
C
8112
Yes
406
Point 006
Benzene
71432
A
89
Yes
89
Toluene
108883
C
198
No
198
Ethylbenzene
100414
C
13
No
13
Xylenes
1130207
C
231
No
231
n -Hexane
110543
C
561
No
561
Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non -criteria air
pollutants are based on potential emissions without credit for reductions achieved by control
devices used by the operator.
Section 8 —Testing Requirements
Will testing be required to show compliance with any emission rate or regulatory
standard?
X
Yes
No
If "yes", complete the information listed below
AIRS Point
Process
Pollutant
Regulatory Basis
Test Method
001
01
VOC
NOx, CO,
Regulation No. 3, Part B., Section III.G.3
Stack test
Page 4
002 01
VOC
CDPHE PS Memo 05-01
Site -specific
sampling
{
004 ! 01
VOC ,
HAPS
State only requirement
Site -specific gas
analysis
005 01
VOC,
HAPS
State only requirement
Site -specific gas
analysis
Section 9 — Source Classification
Is this a new previously
un- ermitted source?
001
002
004
005
006 I
YES
X
X
X
X
X
NO
What is this point
classification?
True Minor , X
X
X
X
-
Synthetic Minor
X
Major
What is this facility
classification?
I True
Minor
X
Synthetic
Minor
Major
Classification relates to
what programs?
X
Title V
X
PSD
NA NSR
MACT
Is this a modification to an
existing permit?
Yes
No
If "yes" what kind of
modification?
Minor
Synthetic Minor
Major
Section 10 — Public Comment
Does this permit require public comment per CAQCC Regulation 3?
X
Yes
No
If "yes", for which pollutants? Why? VOC
For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)?
X
Yes
No
For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)?
Yes
No
For Reg. 3, Part B. III.C.1.d (synthetic minor emission limits)?
X
Yes
No
Section 11 — Modeling
Is modeling requ red to demonstrate compliance with National Ambient
Air Quality Standards (NAAQS)?
If "yes", for which pollutants? Why?
NOx emissions are less than 40 TPY.
Yes
X
No
AIRS Point
Section 12 — Regulatory Review
Regulation 1'- Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide
001, 002,
004-006
Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator
of a source shall allow or cause the emission into the atmosphere of any air pollutant which
is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings
taken at 15 -second intervals for six minutes. The approved reference test method for
visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July,
1992)) in all subsections of Section II. A and B of this regulation.
Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner
or operator of a smokeless flare or other flare for the combustion of waste gases shall
allow or cause emissions into the atmosphere of any air pollutant which is in excess of
30% opacity for a period or periods aggregating more than six minutes in any sixty
consecutive minutes.
Regulation 2 — Odor "`°'`
Page 5
001, 002,
004-006
Section I.A - No person, wherever located, shall cause or allow the emission of odorous air
contaminants from any single source such as to result in detectable odors which are
measured in excess of the following limits: For areas used predominantly for residential or
commercial purposes it is a violation if odors are detected after the odorous air has been
diluted with seven (7) or more volumes of odor free air.
Requlation 3 - APENs, Construction Permits, Operating Permits, PSD
001, 002,
004-006
Part A-APEN Requirements
Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for:
each individual emission point in an attainment area with uncontrolled actual emissions of
two tons per year or more of any individual criteria pollutant (pollutants are not summed) for
which the area is attainment.
(Applicant is required to file an APEN since emissions from production exceed 2
tons per year VOC)
001, 002,
004-006
Part B — Construction Permit Exemptions
Applicant is required to file a permit since uncontrolled VOC emissions are greater
than the 5.0 TPY threshold (Reg. 3, Part B, Section 11.D.3.a)
Requlation 6 - New Source Performance Standards
002, 004-
006
None
001
NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ when
their manufacturer date is on or after July 1, 2008. The operator provided a
manufacturer date of 1/7/2008, which is prior to the threshold date. Therefore, this engine
is not subject to NSPS JJJJ.
Requlation 7 — Volatile Organic Corn Otirids
002, 004-
006
XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS
This facility is not located in the 8 -hr ozone control area; therefore, this facility is not
subject to Section XII of this regulation.
XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS...
This facility is an oil and gas operation that does not operate any equipment subject
to Section XVII of this regulation. Because tanks store crude oil.
001
This engine is subject to Regulation 7, Section XVII.E because it was relocated into
the State of Colorado on 1/7/2008, which is after January 1, 2008.
Regulation 8 — Hazardous Air Pollutants :,
002, 004-
006
None
001
MACT 7777: Engines subject to area source MACT ZZZZ are engines with a
commencement of construction date on or after June 12, 2006. The operator provided
a construction commencement date of 1/7/2008, which is after the threshold date,
therefore, is considered an affected engine and is subject to area source MACT ZZZZ
requirements.
Section 13 — Aerometric Information Retrieval System Coding Information
Point
Process
Emission
Process Description Factor
Pollutant /
CAS #
Fugitive
(Y/N)
Emission Factor
Source
Control
(%)
001
01
Reciprocating internal
combustion engine
227
lb/mmscf
VOC
No
Manufacturer
0
3003
Ib/mmscf
N0x
No
Manufacturer
86
11760
Ib/mmscf
CO
No
Manufacturer
96
20.9
Ib/mmscf
Formaldehyde
No
AP -42
0
2.93
Ib/mmscf
Acetaldehyde
No
AP -42
0
2.76
Ib/mmscf
Acrolein
No
AP -42
0
1.66
Ib/mmscf
Benzene
No
AP -42
0
SCC
20200253: 4 -cycle
rich burn i
Page 6
002
01
17.6 lb/1000
gal
VOC
No
E&P Tanks
95
0.068
lb/MMBtu
NOx
No
AP -42,
Table 13.5-1
NA
0.37
lb/MMBtu
CO
No
AP -42,
Table 13.5-1
NA
0.0204
lb/1000 gal
Benzene
No
E&P Tanks
95
Crude oil Storage Tanks
0.0180
lb/1000 gal
Toluene
No
E&P Tanks
95
0.0005
lb/1000 gal
Ethylbenzene
y
No
E&P Tanks
95
0.0068
lb/1000 gal
Xylenes
No
E&P Tanks
95
0.1370
lb/1000 gal
n -hexane
No
E&P Tanks
95
0.0112
lb/1000 gal
2,2,4-TMP
No
E&P Tanks
95
SCC
40400312 — Fixed Roof
Tank, Oil field
storage of crude, breathing losses
004
01
35428
lb/MMscf
VOC
No
Engineering
Calculation
0
74.9333
lb/MMscf
Benzene
No
Engineering
Calculation
0
56.5333
lb/MMscf
Toluene
No
Engineering
Calculation
0
Gas Storage Tank
9.60
lb/MMscf
Ethlybenzene
No
Engineering
Calculation
0
23.4667
lb/MMscf
Xylenes
y
No
Engineering
Calculation
0
459.4667
lb/MMscf
n -hexane
No
Engineering
Calculation
0
SCC
40400152 -Vapor collection
losses
35487
lb/MMscf
VOC
No
Engineering
Calculation
95
005
01
0.068
lb/MMBtu
NOx
No
AP -42,
Table 13.5-1
NA
0.37
lb/MMBtu
CO
No
AP -42,
Table 13.5-1
NA
36.5
lb/MMscf
Benzene
No
Engineering
Calculation
95
Flare
27.6
lb/MMscf
Toluene
No
Engineering
Calculation
95
4.65
lb/MMscf
Ethlybenzene
No
Engineering
Calculation
95
11.46
lb/MMscf
Xylenes
Engineering
No l Calculation
95
237.8
lb/MMscf
n -hexane
No ! Engineering
- Calculation
95
SCC
31000205 -Flares
006
01
12,400 lb/yr
VOC
Yes
AP -42
0
89 lb/yr
Benzene
Yes
AP -42
0
Fugitive Emissions
198 lb/yr
Toluene
Yes
AP -42
0
13 lb/yr
Ethylbenzene
Yes
AP -42
0
231 lb/yr
Xylenes
Yes
AP -42
0
561 lb/yr
n -hexane Yes
AP -42
0
SCC
31000220: All Equip. Leak Fugitives (Va ves, flanges, connections, seals, drains)
Section 14— Miscellaneous Application Notes
Facility -wide
Facility Review
Page 7
Points 003 and 007 are APEN exempt and filled under 13WE1905 and 13WE1906.
A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit
threshold) and is a synthetic minor source for VOC and n -hexane. Minor for total HAPS.
Page 8
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Section 03 — General Information
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