HomeMy WebLinkAbout20142920.tiff STATE OF COLORADO
John W.Hickenlooper,Governor —
Larry Wolk,MD,MSPH of•
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Executive Director and Chief Medical Officer t m
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Dedicated to protecting and improving the health and environment of the people of Colorado . .� o •.
4300 Cherry Creek Dr.S. Laboratory Services Division ,•r\�e
876
Denver,Colorado 80246-1530 8100 Lowry Blvd. ---
Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department
Located in Glendale,Colorado (303)692-3090 of Public Health
www.colorado.gov/cdphe and Environment
Weld County-Clerk to the Board
1150 O St
PO Box 758
Greeley,CO 80632
September 16, 2014
Dear Sir or Madam:
On September 19,2014,the Air Pollution Control Division will publish a public notice for Noble Energy, Inc.
—Crow Creek Econode, 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-SS-B 1
4300 Cherry Creek Drive South
Denver,Colorado 80246-1530
Attention: Clara Gonzales
Regards,
2.a.t.a. crdi.try)
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
P.biscH tU J u) CC '• IPG,mot W, Nt
2014-2920
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STATE OF COLORADO
John W.Hickenlooper,Governor
Larry Wolk,MD,MSPH pp cOzo
Executive Director and Chief Medical Officer /tim
Dedicated to protecting and improving the health and environment of the people of Colorado (,6�
4300 Cherry Creek Dr.S. Laboratory Services Division *1676 s,
Denver,Colorado 80246-1530 8100 Lowry Blvd. ---
Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department
Located in Glendale,Colorado (303)692-3090 of Public Health
www.colorado.gov/cdphe and Environment
Website Title: Noble Energy, Inc.—Crow Creek Econode—Weld County
Released To: The Greeley Tribune
On: September 16,2014
Published: September 19,2014
PUBLIC NOTICE OF A PROPOSED PROJECT
OR ACTIVITY WARRANTING PUBLIC COMMENT
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: Noble Energy, Inc.
Facility: Crow Creek Econode
Oil and gas exploration and production facility
S/2 Section 36,T7N, R63W
Weld County
The proposed project or activity is as follows: Oil and gas exploration and production facility including a venting
flare, two reciprocating internal combustion engines and associated fugitive emissions.
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.I.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 14WE0583 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
D FTSTATE OF COLORADO
oc•cozo
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT `'
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AIR POLLUTION CONTROL DIVISION *e*
TELEPHONE: (303)6924150 *•1816•
CONSTRUCTION PERMIT
PERMIT NO: 14W E0583
Issuance 1
DATE ISSUED:
ISSUED TO: Noble Energy, Inc.
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Oil and gas facility, known as the Crow Creek Econode, located in S/2 Section 36, T7N,
R63W, in Weld County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
Facility AIRS Description
Equipment ID Point
Fugitives 004 Equipment leaks (fugitive VOCs)from a natural gas
exploration and production facility.
Flare 005 Separator controlled by a flare stack. Flare has a minimum
combustion efficiency of 95%. The flare is not enclosed.
One (1) Caterpillar, Model G3508B, Serial Number
RBK01277, natural gas-fired, naturally aspirated, 4SLB
GL Comp1 006 reciprocating internal combustion engine, site rated at 639
horsepower. This engine shall be equipped with an oxidation
catalyst and air-fuel ratio control. This emission unit is used
for natural gas compression.
One (1) Caterpillar, Model G3508B, Serial Number
RBK01275, natural gas-fired, naturally aspirated, 4SLB
GL Comp2 007 reciprocating internal combustion engine, site rated at 639
horsepower. This engine shall be equipped with an oxidation
catalyst and air-fuel ratio control. This emission unit is used
for natural gas compression.
Points 006 and 007: These engines may be replaced with another engine in accordance
with the temporary engine replacement provision or with another Caterpillar G3508B 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: 123/9C96 Page 1 of 16
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CONTROL ACT C.R.S. (25-7-101 et sea), 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 Air Pollution Control Division (the Division) no later than
fifteen days after issuance of this permit, by submitting a Notice of Startup form to
the Division. The Notice of Startup form may be downloaded online at
www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup
of the permitted source is a violation of Air Quality Control Commission (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 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).
3. This permit shall expire if the owner or operator of the source for which this permit was
issued: (i) does not commence construction/modification or operation of this source
within 18 months after either, the date of issuance of this construction permit or the date
on which such construction or activity was scheduled to commence as set forth in the
permit application associated with this permit; (ii) discontinues construction for a period
of eighteen months or more; (iii) does not complete construction within a reasonable
time of the estimated completion date. The Division may grant extensions of the
deadline 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 following information shall be provided to the Division within fifteen (15)days after
issuance of permit.
• manufacture date
• construction date
• order date
• date of relocation into Colorado
• manufacturer
• model number
• serial number
This information shall be included with the Notice of Startup submitted for the equipment.
(Reference: Regulation No. 3, Part B, III.E.)
6. 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
AIRS ID: 12319C96 Page 2 of 16
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Airblic PollutionHealth Control DivisionEnvironment
7. 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:
Facility AIRS Tons per Year
Emission Type
Equipment ID Point NO, VOC CO
Fugitives 004 --- 28.0 --- Fugitive
Flare 005 4.5 42.6 24.3 Point
GL Compl 006 3.1 4.3 1.2 Point
GL Comp2 007 3.1 4.3 1.2 Point
See "Notes to Permit Holder"for information on emission factors and methods used to calculate
limits.
Facility-wide emissions of each individual hazardous air pollutant shall 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 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 emissions each month
and keep a compliance record on site or at a local field office with site responsibility for
Division review.
8. The emission points in the table below shall be operated and maintained with the control
equipment as listed in order to reduce emissions to less than or equal to the limits
established in this permit (Reference: Regulation No.3, Part B, Section III.E.)
Facility AIRS Pollutants
Equipment Point Control Device Controlled
ID
Flare 005 Flare VOC, HAPS
GL Compl 006 Oxidation catalyst and air/fuel ratio controller VOC, CO,
formaldehyde
VOC, CO,
GL Comp2 007 Oxidation catalyst and air/fuel ratio controller
formaldehyde
9. Point 004: The operator shall calculate actual emissions from this emissions point
based on representative component counts for the facility with the most recent gas
analysis, 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
10. This source shall be limited to the following maximum processing rates as listed below.
Monthly records of the actual processing rate 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)
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Process/Consumption Limits
Facility AIRS
Equipment Point Process Parameter Annual Limit
ID
Flare 005 Natural gas flaring 99 MMscf/yr
GL Compl 006 Consumption of natural gas as a fuel 35.42 MMscf/yr
GL Comp2 007 Consumption of natural gas as a fuel 35.42 MMscf/yr
The owner or operator shall calculate monthly process rates based on the calendar
month.
Compliance with the annual throughput limits shall be determined on a rolling twelve (12)
month total. By the end of each month a new twelve-month total is calculated based on
the previous twelve months' data. The permit holder shall calculate throughput each
month and keep a compliance record on site or at a local field office with site
responsibility, for Division review.
STATE AND FEDERAL REGULATORY REQUIREMENTS
11. 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)
12. Visible emissions shall not exceed twenty percent(20%)opacity during normal operation
of the source. During periods of startup, process modification, or adjustment of control
equipment visible emissions shall not exceed 30% opacity for more than six minutes in
any sixty consecutive minutes. Emission control devices subject to Regulation 7,
Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation
No. 1, Section II.A.1. &4.)
13. This source is subject to the odor requirements of Regulation No. 2. (State only
enforceable)
14. Point 004: Minor sources in designated nonattainment or attainment/maintenance
areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part
B, shall apply Reassonaby Available Control Technology for the pollutants for which the
area is nonattainment or attainment/maintenance(Reference: Regulation No. 3, Part B,
III.D.2.a).
15. Point 004: This source is subject to Regulation No. 7, Section XII.C General Provisions
(State only enforceable). All condensate collection, storage, processing and handling
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. The operator shall comply with all applicable requirements of Section
XII.
16. Point 004: Minor sources in designated nonattainment or attainment/maintenance
areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part
B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for
which the area is nonattainment or attainment/maintenance (Reference: Regulation No.
3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by
installing/implementing the following emission controls:
AIRS ID: 123/9C96 Page 4 of 16
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a. Directed Inspection & Maintenance as described below shall satisfy the
requirement to apply RACT.
i. Auditory/visual/olfactory inspection (AVO) will be performed on a
quarterly basis.
ii. For each leak found in the AVO inspection, a gas detector may be
used to determine the size of the leak. The gas detector shall be
regularly calibrated. Component leaks greater than 10,000 ppm shall
be managed in accordance with Item (vi) below, unless it is unfeasible
to make the repair without shutting down the affected operation of the
facility. Component leaks less than 10,000 ppm shall not require
repair. For such component leaks that require a shutdown to be
repaired, repair shall occur during the first shutdown of the affected
operation after the leak is discovered.
iii. For repair, valves adjacent to the equipment to be repaired will be
closed if practicable, minimizing the volume released.
iv. Repaired components shall be re-screened using AVO to determine if
the leak is repaired.
v. The following records shall be maintained for a period of two years:
• The name of the site screened via AVO inspection and the
name of the inspector.
• Components evaluated with the gas detector.
• Repair methods applied.
• Dates of the AVO inspections, gas detector calibrations,
attempted repairs, successful repairs, repair delays, and post-
repair screenings.
vi. Leaks shall be repaired as soon as practicable, but no later than 15
calendar days after detection, unless it is technically or operationally
infeasible to make the repair within 15 calendar days. Records
documenting the rationale shall be maintained if it is technically or
operationally infeasible to make the repair within 15 calendar days.
17. Point 005: 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.)
18. Points 006 and 007: This equipment is subject to the control requirements for
stationary and portable engines in the 8-hour ozone control area under Regulation No. 7,
Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation
catalyst shall be required.
OPERATING & MAINTENANCE REQUIREMENTS
19. Point 004: 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
AIRS ID: 12319C96 Page 5 of 16
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Air Pollution Control Division
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
20. Point 004: Within one hundred and eighty days (180) after issuance of this permit, the
owner or operator shall complete the initial extended gas analysis of gas samples that
are representative of volatile organic compound (VOC) that may be released as fugitive
emissions. This extended gas analysis shall be used in the compliance demonstration
as required in the Emission Limits and Records section of this permit. The operator shall
submit the results of the gas analysis and emission calculations to the Division as part of
the self-certification process to ensure compliance with emissions limits.
21. Point 004: Within one hundred and eighty days (180) after issuance of this 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.
22. Point 005: The operator shall complete an initial site specific extended gas analysis of
the natural gas produced at this site 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-
certification and used to demonstrate compliance with the emissions factors chosen for
this emissions point.
23. Point 005: The owner or operator shall demonstrate compliance with Condition 17
using EPA Method 22 to measure opacity from the flare. (Reference: Regulation No. 1,
Section II.A.5).
24. Points 006 and 007: A source initial compliance test shall be conducted on emissions
point 006 to measure the emission rate(s) for the pollutants listed below in order to
demonstrate compliance with the emission limits 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 using EPA approved methods.
Carbon Monoxide using EPA approved methods.
Periodic Testing Requirements
AIRS ID: 123/9C96 Page 6 of 16
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Air Pollution Control Division
25. Point 004: On an annual basis, the owner or operator shall complete an extended gas
analysis of gas samples that are representative of volatile organic compounds (VOC)
and hazardous air pollutants (HAP) that may be released as fugitive emissions. This
extended gas analysis shall be used in the compliance demonstration as required in the
Emission Limits and Records section of this permit.
26. Point 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.
27. Points 006 and 007: 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.
ADDITIONAL REQUIREMENTS
28. 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 volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in
ozone nonattainment areas emitting less than 100 tons of VOC or NO, per
year, a change in annual actual emissions of one (1) ton per year or more or five
percent, whichever is greater, above the level reported on the last APEN; or
For sources emitting 100 tons per year or more, a change in actual emissions
of five percent or 50 tons per year or more, whichever is less, above the level
reported on the last APEN submitted; or
For any non-criteria reportable pollutant:
If the emissions increase by 50% or five (5) tons per year, whichever is less,
above the level reported on the last APEN submitted to the Division.
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. Points 006 and 007: 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
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manufacturer, model and serial number and horsepower of the permanent
replacement engine, the appropriate APEN filing fee and a cover letter explaining
that the owner or operator is exercising an alternative-operating scenario and is
installing a permanent replacement engine.
29. This source is subject to the provisions of Regulation No. 3, Part C, Operating Permits
(Title V of the 1990 Federal Clean Air Act Amendments). The application for the
Operating Permit is due within one year of the earliest commencement of operation of
any piece of equipment covered by this permit.
GENERAL TERMS AND CONDITIONS
30. 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.
31. 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.
32. This permit is issued in reliance upon the accuracy and completeness of information
supplied by the owner or operator and is conditioned upon conduct of the activity, or
construction, installation and operation of the source, in accordance with this information
and with representations made by the owner or operator or owner or operator's agents.
It is valid only for the equipment and operations or activity specifically identified on the
permit.
33. 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.
34. Each and every condition of this permit is a material part hereof and is not severable.
Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire
permit and upon such occurrence, this permit shall be deemed denied ab initio. This
permit may be revoked at any time prior to self-certification and final authorization by the
Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality
Control Act and regulations of the Air Quality Control Commission (AQCC), including
failure to meet any express term or condition of the permit. If the Division denies a
permit, conditions imposed upon a permit are contested by the owner or operator, or the
Division revokes a permit, the owner or operator of a source may request a hearing
before the AQCC for review of the Division's action.
35. 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
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Air Pollution Control Division
Division in writing requesting a cancellation of the permit. Upon notification, annual fee
billing will terminate.
36. 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:
Stephanie Chaousy, PE
Permit Engineer
Permit History
Issuance Date Description
Issuance 1 This Issuance Issued to Noble Energy, Inc. Newly permitted
venting flare, (2) reciprocating combustion
engines and associated fugitive emissions at a
synthetic minor facility.
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11
Notes to Permit Holder at the time of this permit issuance:
1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these
fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of
receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (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 owner or operator providing there is no exceedance of any specific emission
control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN)
and complete application form must be submitted with a request for a permit revision.
3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense
Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division
of any malfunction condition which causes a violation of any emission limit or limits stated in this
permit as soon as possible, but no later than noon of the next working day, followed by written notice
to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions
Regulation. See: htto://www.colorado.aov/cs/Satellite?c=Document C&childoagename=CDPHE-
Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper
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 tithe source(s)operate at the permitted limitations.
Uncontrolled Are the Controlled
Emission
AIRS Pollutant CAS# BIN emissions Emission
Point Rate reportable? Rate(Ib/yr)
(lb/yr)
Benzene 71432 A 1248 Yes 1248
Toluene 108883 C 1803 Yes 1803
004 Ethylbenzene 100414 C 139 No 139
Xylenes 1330207 C 693 Yes 693
n-Hexane 110543 C 2219 Yes 2219
Benzene 71432 A 11571 Yes 579
Toluene 108883 C 11571 Yes 579
005 Ethylbenzene 100414 C 5786 Yes 5289
Xylenes 1330207 C 5786 Yes 289
n-Hexane 110543 C 34714 Yes 1736
Formaldehyde 50000 A 3,455 Yes 370
Acetaldehyde 75070 A 385 Yes 385
006 Acrolein 107028 A 237 No 237
and Methanol 67561 C 115 No 115
007
each n-Hexane 110543 C 51 No 51
Benzene 71432 A 20 No 20
Toluene 108883 C 19 No 19
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5) The emission levels contained in this permit are based on the following emission factors:
Point 004:
Water/Oil
Component Gas Service Heavy Oil Light Oil
Service
Connectors 1408 588 240 66
Flanges 331 0 9 9
Open-ended Lines 22 0 0 0
Pump Seals 0 0 4 0
Valves 780 196 215 49
Other* 240 0 35 13
VOC Content(wt. 0.2947 1 1 1
fraction)
Benzene Content(wt. 0.009 0.009 0.009 0.009
fraction)
Toluene Content(wt. 0.013 0.013 0.013 0.013
fraction)
Ethylbenzene(wt. 0.001 0.001 0.001 0.001
fraction)
Xylenes Content(wt. 0.005 0.005 0.005 0.005
fraction)
n-hexane Content(wt 0.016 0.016 0.016 0.016
fraction)
*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 analysis.
Point 005:
Weight Emission Emission
CAS# Pollutant Fraction of Factors Factors Source
Gas (%) Uncontrolled Controlled
NOx 0.068 0.068 AP-42
lb/MMBtu lb/MMBtu
CO 0.37 AP-42
_
0.37 lb/MMBtu lb/MMBtu
AIRS ID: 12319C96 Page 11 of 16
D Co do p e o Public Health and Environment
Air Pollution Control Division
Weight Emission Emission
CAS# Pollutant Fraction of Factors Factors Source
Gas(%) Uncontrolled Controlled
VOC 29.47 18020.2020 901.0101 Engineering
lb/MMscf lb/mmscf Calculation
71432 Benzene 0.20 122.4444 6.1222 Engineering
lb/mmscf lb/mmscf Calculation
108883 Toluene 0.20 122.4444 6.1222 Engineering
lb/mmscf lb/mmscf Calculation
100414 Ethylbenzene 0.10 60.7273 3.0364 Engineering
lb/mmscf Ib/mmsd Calculation
1330207 Xylenes 0.10 60.7273 3.0364 Engineering
lb/mmscf lb/mmscf Calculation
110543 n-hexane 0.60 366.3232 18.3162 Engineering
lb/mmscf Ib/mmsd Calculation
Note: The uncontrolled VOC and HAP emissions for this point were calculated using an average
of three gas samples collected from the Crow Creek AC 36 well on January 3, 2014. The
controlled VOC and HAP emissions factors for point 005 are based on the flare control
efficiency of 95%.
Points 006 and 007:
Emission Factors- Emission Factors—
Uncontrolled Controlled
CAS Pollutant lb/MMBtu glbhp-hr lb/MMBtu g/bhp-hr
NOx 0.1340 0.50 0.1340 0.50
CO 0.8577 3.20 0.0536 0.20
VOC 0.4155 1.55 0.1876 0.70
50000 Formaldehyde 0.0751 0.28 0.0080 0.03
75070 Acetaldehyde 0.0084 0.03 0.0084 0.03
107028 Acrolein 0.0051 0.02 0.0051 0.02
67561 Methanol 0.0025 0.01 0.0025 0.01
110543 n-Hexane 0.0011 0.00 0.0011 0.00
71432 Benzene 0.0004 0.00 0.0004 0.00
108883 Toluene 0.0004 0.00 0.0004 0.00
Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8225 Btu/hp-hr, a
site-rated horsepower value of 639, and a fuel heat value of 1300 Btu/sd.
Emission Factor Sources:
CAS Pollutant Uncontrolled EFSource Controlled EF Source
NOx Manufacturer Manufacturer
CO Manufacturer Manufacturer
VOC Manufacturer Manufacturer
50000 Formaldehyde Manufacturer Manufacturer
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) Points 006 and 007: These engines are subject to 40 CFR, Part 60, Subpart JJJJ—Standards of
Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008
AIRS ID: 123/9C96 Page 12 of 16
1) Co do .S.p e o Pu Environment
Airblic PollutionHealthand Control Division
Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into
Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is
available on the EPA website at: http://www.epa.qov/ttn/atw/area/fr18ia08.pdf
8) Points 006 and 007: These engines are subject to 40 CFR, Part 63, Subpart 7777 - National
Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion
Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January
18, 2008 amendments to include requirements for area sources and engines ≤ 500 hp located at
major sources have not yet been incorporated into Colorado Air Quality Control Commission's
Regulation No. 8. A copy of the complete subpart is available on the EPA website at:
http://www.epa.qov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards
can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html
9) This facility is classified as follows:
Applicable Status
Requirement
Operating Permit Synthetic Minor Source of:
VOC
NANSR Synthetic Minor Source of:
VOC
MACT ZZZZ Area Source Requirements:Applicable
10) 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 M—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
11) 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:
www.coloradougov/cdphe/oiloaspermits
AIRS ID: 123/9O96 Page 13 of 16
D Co do e o 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. "Permanent" is defined as in the same service for more
than 270 operating days in any 12 month period.The 270 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
270 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.
2.1.2 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.
The AOS cannot be used for the permanent replacement of an entire engine at any source that is
currently a major stationary source for purposes of Prevention of Significant Deterioration or Non-
AIRS ID: 123/9C96 Page 14 of 16
Co A do ■ p e o Public Health and Environment
Air Pollution Control Division
Attainment Area New Source Review("PSD/NANSR") unless the existing engine has emission limits that
are below the significance levels in Reg 3, Part D, II.A.42.
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.
Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine
replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the
event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR
requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR
and applicable permitting requirements.
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:
http://www.colorado.aov/cs/Satellite/CDPH E-AP/CBON/1251596520270.
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
AIRS ID: 123/9C96 Page 15 of 16
Co do p e o Pu En
D Airblic PollutionHealthand Control Divisionvironment
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 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.
2.4 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: 123/9C96 Page 16 of 16
Construction Permit Application
Preliminary Analysis Summary
Section 1 —Applicant Information
Company Name: Noble Energy, Inc
Permit Number: 14WE0583
Source Location: Crow Creek EcoNode
S/2 Section 36,T7N, R63W, Weld County (non-attainment)
Point 001: Condensate tanks (Cancelled 7/2/14 via email)
Point 002: Produced water tanks (Cancelled 7/2/14 via email)
Point 003: Truck loadout(Cancelled 7/2/14 via email)
Equipment Description: Point 004: Fugitive emissions
Point 005: Wellhead gas flaring
Point 006: Caterpillar 4SLB engine
Point 007: Caterpillar 4SLB engine
AIRS ID: 123-9C96
Date: June 13, 2014
Review Engineer: Stephanie Chaousy
Control Engineer: Chris Laplante
Section 2—Action Completed
Grandfathered Modification APEN Required/Permit Exempt
X CP1 Transfer of Ownership APEN Exempt/Permit Exempt
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? X Yes No
Did the applicant submit all required paperwork? X Yes No
Did the applicant provide ample information to determine emission rates? X Yes No
If you answered"no"to any of the above, when did you mail an See Section 14
Information Request letter to the source?
On what date was this application complete? March 17, 2014
Section 4—Source Description
AIRS Point Equipment Description
004 Fugitive VOC leak emissions
005 Separator controlled by a flare stack. Flare has a minimum combustion efficiency of
95%. The flare is not enclosed.
One(1) Caterpillar, Model G3508B, Serial Number RBK01277, natural gas-fired,
006 naturally aspirated,4SLB reciprocating internal combustion engine,site rated at
639 horsepower.This engine shall be equipped with an oxidation catalyst and air-
fuel ratio control. This emission unit is used for natural gas compression.
Page 1
One(1)Caterpillar,Model G3508B,Serial Number RBK01275, natural gas-fired,
007 naturally aspirated,4SLB reciprocating Internal combustion engine,site rated at
639 horsepower.This engine shall be equipped with an oxidation catalyst and air-
fuel ratio control.This emission unit is used for natural gas compression.
Is this a portable source? Yes X No
Is this location in a non-attainment area for any criteria X Yes No
pollutant?
If"yes",for what pollutant? PM10 CO X Ozone
Is this location in an attainment maintenance area for Yes X No
any criteria pollutant?
If"yes",for what pollutant?
(Note:These pollutants are subject to minor source PM10 CO Ozone
RACT per Regulation 3, Part B,Section IlI.D.2)
Is this source located in the 8-hour ozone non-
attainment region?(Note: If"yes"the provisions of X Yes No
Regulation 7,Sections XII and XVII.C may apply)
Section 5—Emission Estimate Information
AIRS Point Emission Factor Source
004 EPA-453/R-95-017,Table 2-4
005 Site-specific using VOC weight fraction (Refer to Section 14 for calculations)
006 Manufacturer emissions provided for NOx,VOC, CO and formaldehyde.AP-42 used
for the rest of the HAP emissions.
007 Manufacturer emissions provided for NOx,VOC, CO and formaldehyde.AP-42 used
for the rest of the HAP emissions.
Did the applicant provide actual process data for the emission inventory? Yes X No
Basis for Potential to Emit(PTEI
AIRS Point Process Consumption/Throughput/Production
Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil
Heavy Liquid) Light Liquid)
Connectors 1408 588 240 66
004 Flanges 331 0 9 9
Open-Ended Lines 22 0 0 0
Pump Seals 0 0 4 0
Valves 780 196 215 49
Other 240 0 35 13
005 99 MMSCF per year
006 35.4 MMSCF per year
007 35.4 MMSCF per year
Basis for Permitted Emissions(Permit Limits)
AIRS Point Process Consumption/Throughput/Production
Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil
Heavy Liquid) Light Liquid)
Connectors 1408 588 240 66
004 Flanges 331 0 9 9
Open-Ended Lines 22 0 0 0
Pump Seals 0 0 4 0
Valves 780 196 215 49
Other 240 0 35 13
005 99 MMSCF per year
Page 2
006 35.4 MMSCF per year
007 35.4 MMSCF per year
Does this source use a control device? X Yes No
% Reduction
AIRS Point Process Control Device Description
Granted
005 01 Flare 95
VOC: 54.8%;
006 01 Oxidation catalyst and AFRC CO: 93.8%;
Formaldehyde:
89.3%
VOC: 54.8%;
007 01 Oxidation catalyst and AFRC CO: 93.8%;
Formaldehyde:
89.3%
Section 6—Emission Summary (tons per year)
Point NO. VOC CO Single HAP Total HAP
004 --- 28.0 --- 1.1 (n-hexane) 3.1
005 4.5 853.0 24.3 17.4 (n-hexane) 37.6
PTE: 1.7
006 3.1 9.6 19.8 (formaldehyde)1.7
2.0
007 3.1 9.6 19.8 2.0
(formaldehyde)
TOTAL(TPY) 10.7 900.2 63.9 18.5(n-hexane) 44.7
004 --- 28.0 --- 1.1 (n-hexane) 3.1
005 4.5 853.0 24.3 17.4 (n-hexane) 37.6
Uncontrolled point
1.7
source emission rate: 006 3.1 9.6 19.8 2.0
(formaldehyde)1.7
007 3.1 9.6 19.8 (formaldehyde) 2.0
TOTAL(TPY) 10.7 900.2 63.9 18.5(n-hexane) 44.7
004 --- 28.0 --- 1.1 (n-hexane) 3.1
005 4.5 42.6 24.3 0.9 (n-hexane) 1.9
Controlled point
0.2
source emission rate: 006 3.1 4.3 1.2 (formaldehyde)0.2
0.5
007 3.1 4.3 1.2 0.5
(formaldehyde)
TOTAL(TPY) 10.7 79.2 26.7 2.0 (n-hexane) 6.0
Section 7—Non-Criteria/ Hazardous Air Pollutants
Uncontrolled Are the Controlled Emission
Pollutant CAS# BIN Emission Rate emissions
(Ib/yr) reportable? Rate(lb/yr)
Point 004
Benzene - 71432 A 1248 Yes 1248
Toluene 108883 C 1803 Yes 1803
Ethylbenzene 100414 C 139 No 139
Xylenes 1330207 C 693 Yes 693
Page 3
n-Hexane 110543 C 2219 Yes 2219
Point 005
Benzene 71432 A 11571 Yes 579
Toluene 108883 C 11571 Yes 579
Ethylbenzene 100414 C 5786 Yes 5289
Xylenes 1330207 C 5786 Yes 289
n-Hexane 110543 C 34714 Yes 1736
2,2,4-TMP 540841 C 5786 Yes 289
Points 006 and 007 each
Formaldehyde 50000 A 3455 Yes 370
Acetaldehyde 75070 A 385 Yes 385
Acrolein 107028 A 237 No 237
Benzene 71432 A 20 No 20
Note: Regulation 3, Part A, Section ll.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 X Yes No
standard?
If"yes", complete the information listed below
AIRS Point Process Pollutant Regulatory Basis Test Method
004 01 VOC, State-only requirement Extended gas
HAPS analysis
004 01 VOC, State-only requirement Component hard
HAPS count
005 01 VOC, State-only requirement Extended gas
HAPSanalysis
006 01 Opacity Regulation No. 1,Section II.A.5 EPA Method 9
006,007 01 NOx, CO Regulation No.3, Part B.,Section III.G.3 Stack test
Section 9—Source Classification
Is this a new previously un-permitted source? X Yes No
What is this facility classification? True X Synthetic Major
Minor Minor
Classification relates to what programs? X Title V PSD X NA NSR X MACT
Is this a modification to an existing permit? Yes X No
If"yes"what kind of modification? Minor Synthetic Major
Minor
Section 10—Public Comment
Does this permit require public comment per CAQCC Regulation 3? X Yes No
If"yes",for which pollutants?Why?
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.ii (subject to MACT)? X Yes No
Page 4
For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No
Section 11 —Modeling
Is modeling required to demonstrate compliance with National Ambient Yes X No
Air Quality Standards(NAAQS)?
If"yes", for which pollutants?Why?
AIRS Point Section 12— Regulatory Review
Regulation 1 -Particulate.Smoke, Carbon Monoxide and Sulfur Dioxide
Section II.A.1 — Except as provided in paragraphs 2 through 6 below, no owner or operator
of a source shall allow or cause the emission into the atmosphere of any air pollutant which
is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings
taken at 15-second intervals for six minutes. The approved reference test method for
visible emissions measurement is EPA Method 9 (40 CFR, Part 60,Appendix A(July,
004-007 1992)) in all subsections of Section II. A and B of this regulation.
Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner
or operator of a smokeless flare or other flare for the combustion of waste gases shall allow
or cause emissions into the atmosphere of any air pollutant which is in excess of 30%
opacity for a period or periods aggregating more than six minutes in any sixty consecutive
minutes.
Regulation 2—Odor
Section LA—No person, wherever located, shall cause or allow the emission of odorous
air contaminants from any single source such as to result in detectable odors which are
004-007 measured in excess of the following limits: For areas used predominantly for residential or
commercial purposes it is a violation if odors are detected after the odorous air has been
diluted with seven (7)or more volumes of odor free air.
Regulation 3-APENs, Construction Permits, Operating Permits, PSD
Part A-APEN Requirements
Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for:
004-007 each individual emission point in a non-attainment area with uncontrolled actual emissions
of one ton per year or more of any individual criteria pollutant(pollutants are not summed)
for which the area is non-attainment.
(Applicant is required to file an APEN since emissions exceed 1 ton per year VOC)
Part B—Construction Permit Exemptions
004-007 Applicant is required to obtain a permit since uncontrolled VOC emissions from this
facility are greater than the 2.0 TPY threshold(Reg.3, Part 8, Section ILD.2a)
Part B, III.D.2—RACT requirements for new or modified minor sources
This section of Regulation 3 requires RACT for new or modified minor sources located in
nonattainment or attainment/maintenance areas. This source is/is not located in the 8-hour
ozone nonattainment area.
004
The date of interest for determining whether the source is new or modified is therefore
November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the fugitives
will be in service after the date above, this source is considered "new or modified."
Operator has agreed on the Division's standard conditions.
Regulation 6-New Source Performance Standards
NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production,
Transmission and Distribution. For fugitive emissions at natural gas processing
plants subject to NSPS OOOO. This subpart establishes emission standards and
compliance schedules for the control of volatile organic compounds(VOC)and
004 sulfur dioxide (SO2) emissions from affected facilities that commence construction,
modification or reconstruction after August 23, 2011.
Is this source at a"natural gas processing plant?" No
Is this source subject to NSPS OOOO? No
WHY? Facility does not meet the definition of a"natural gas processing plant"
005 None
Page 5
NSPS JJJJ: the date of construction is the date it was ordered or reconstructed/modified.
006,007 Both engines were manufactured after the 7/1/2008 effective date and are therefore
subject to NSPS JJJJ.
,ax,:ir.0.. ,-......p t7n Q a et+Kie.s9 _. u:aE RIPE__ ,' R. .....:. a_,.r ovs`r 4A„ ` _nnr
Section XII.G: If facility is a natural gas processing plant located in non-attainment
004 area,then subject to Section XII.G.
Source is not located at a natural gas processing plant, therefore, not subject to this
subpart.
005 None
006, 007 These engines are not subject to Regulation 7 because they are subject to NSPS
JJJJ and MACT ZZZZ.
...M ..... it t ltit8,:# : "-lknta'Atk" -. .W? .nr.., . . ' .,....., r .i...,. .r;. ��,..rBie,e
004 MACT HH
This source is not subject to MACT HH because it is not located at a major source of HAP.
005 None
006, 007 MACT ZZZZ:The date of construction is the first time the engine is installed at any
location, therefore engines are new sources for ZZZZ applicability
Section 13—Aerometric Information Retrieval System Coding Information
Emission
Emission Pollutant/ Fugitive Factor Control
Point Process Process Description Factor CAS# (Y/N (5/0)
Source
004 01 Fugitive VOC Leak Emissions VOC Yes EPA-453/R-95-017, NA
Table 2-4
SCC 31000220: All Equip. Leak Fugitives(Valves,flanges, connections,seals,drains)
18020.2020 VOC No Engineering 95
lb/MMscf - Calculation
0.068 2,
Ib/MMBtu NOx No Table�3.5-1 NA
0.37 AP-42,
Ib/MMBtu CO No Table 13.5-1 NA
122.4444 Engineering
Ib/mmscf Benzene No Calculation 95
01 Flare • 122.4444 Toluene No Engineering 95
005 Ib/mmscf Calculation
60.7273 Ethlybenzen No Engineering 95
Ib/mmscf a Calculation
60.7273 X lanes No Engineering 95
Ib/mmscf y Calculation
366.3232 n-hexane No Engineering 95
Ib/mmscf Calculation
60.7273 Engineering
Ib/mmscf 2,2.4-TMP No Calculation 95
SCC 31000205-Flares
0.5 g/hp-hr NOx No Manufacturer 0
1.55 g/hp- VOC No Manufacturer 54.8
hr
01 4SLB Engine
32
006 . g/hp-hr CO No Manufacturer 93.8
0.28 g/hp- Formaldehyde No Manufacturer 89.3
hr /50000
SCC 20200254—4-cycle lean burn
0.5 g/hp-hr NOx No Manufacturer 0
1.55 g/hp- VOC No Manufacturer 54.8
007 01 4SLB Engine hr
3.2 g/hp-hr CO No Manufacturer 93.8
0.28 g/hp- Formaldehyde No Manufacturer 89.3
hr /50000
Page 6
SCC 20200254-4-cycle lean burn
Section 14—Miscellaneous Application Notes
AIRS Point 001 Condensate Storage Tanks
Received a cancellation notice via email on 7/2/14 from Noble Energy cancelling this point source
because the source no longer exists.
AIRS Point 002 Produced Water Storage Tanks
Received a cancellation notice via email on 7/2/14 from Noble Energy cancelling this point source
because the source no longer exists.
AIRS Point 003 Truck Condensate Loadout
Received a cancellation notice via email on 7/2/14 from Noble Energy cancelling this point source
because the source no longer exists.
AIRS Point 004 Fugitive VOC Leak Emissions
A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit
threshold).
I emailed the operator on 6/13/14:
No HAP emissions from the fugitives? I would think with 28 TPY VOC, there would be some HAP
calculations.
Operator replied on 7/2/14 with revised fugitive calculations including the HAP emissions.
•
Page 7
AIRS Point 005 Flare
were calculated using EPA Emission Inventory Improvement Program Publication,Volume II, Chapter 10-
Displacement equation (10.4-3)where:
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
My calculations were a little different than what was provided in the application, but I believe that is
because of rounding issues. I will go with the emissions provided in the application. Emissions and
emission factors generated from the flare with a throughput of 99 mmscf/yr.
Uncontrolled Controlled Uncontrolled Controlled
Total Uncontrolled
(Itity Total Contr(Iblyrolled Emission factor Emission factor
(Ib/mmscf) (Ib/mmscf)
NOx 4.4 4.4 0.068 -
VOC 892 44.6 18020.2020 901.0101
CO 24.2 24.2 0.37 --
Benzene 12122 606 - 122.4444 6.1222
Toluene 12122 606 122.4.444 6.1222
Ethylbenzene 6012 301 60.7273 3.0364
Xylenes 6012 301 60.7273 3.0364
n-hexane 36266 1813 366.3232 18.3162
224-TMP 6012 301 60.7273 3.0364
An average of three gas analyses was provided in the application all dated 01/03/2014. The gas analysis
was perfomed less than a year of submittal.An extended gas analysis will be required because this
source is a new source and an actual sample was not available for emission calculations as well as the
analyses provided were not extended gas analyses. A test performed at the source once constructed will
provide an accurate emissions sampling.
I emailed the operator on 6/13/14: The venting flare: I think I am missing something...? I don't have the
gas analysis used to calculate the emissions. I know that I will ask for one in the permit, but I would think
I need something to at least estimate the emissions. Operator provided information for the flare on 7/2/14
and 7/7/14 via email.
I emailed a follow-up question on 07/07/14: [Looking at the gas analyses provided and the average from
the 3 analyses] It looks like one of the CO2 values was inputted incorrectly. It should be 2.464 not 0.2464
and it does change the emissions. Please check it out and let me know. I can redline the APEN if
necessary. She wrote back on 8/8/14: I'm fine with Red-lining the CO2 issue.
AIRS Point 006 4SLB Engine
A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit
threshold).
Engine is subject to NSPS JJJJ (manufacturer date of 4/1/13)and MACT 7777.
AIRS Point 007 4SLB Engine
A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit
threshold).
•
Engine is subject to NSPS JJJJ (manufacturer date of 3/28/13)and MACT 7777.
Page 8
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