HomeMy WebLinkAbout1.1 Application Part 2STATE OF COLORADO
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
TELEPHONE: (303) 692-3150
CONSTRUCTION PERMIT
PERMIT NO: 07GA0179L
DATE ISSUED: April 16, 2007
ISSUED TO: WILLIAMS PRODUCTION RMT CO
FINAL APPROVAL
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Land development project known as, Cottonwood 24" pipeline, located in Section 34, 6S, 95W,
Garfield County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
Overlot grading and associated construction activities.
THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR
QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND
CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED
IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS:
1. The fugitive particulate emission control measures listed on the attached page (as proposed in the
Fugitive Dust Control Plan submitted to the Division) shall be applied to the fugitive particulate emission
producing sources as required by Regulation No. 1.
2. This permit shall expire on 11/1/2007.
By:
Michael Harri , P.E.
Permit Engineer
AIRS ID: 046/0030/001
Bv:
R K Hancock III, P.E.
Unit Leader
Page 1 of 3
WILLIAMS PRODUCTION RMT CO
Permit No. 07GA0179L
Final Approval
Colorado Department of Public Health and Environment
Air Pollution Control Division
PARTICULATE EMISSIONS CONTROL PLAN
THE FOLLOWING PARTICULATE EMISSIONS CONTROL MEASURES SHALL BE USED FOR
ENFORCEMENT PURPOSES ON THE SOURCES COVERED BY THIS PERMIT, AS REQUIRED BY THE
AIR QUALITY CONTROL COMMISSION REGULATION NO 1. THIS SOURCE IS SUBJECT TO THE
FOLLOWING EMISSION GUIDELINES:
a. All Activities - Visible emissions not to exceed 20%, no off -property transport of visible emissions.
b. Haul Roads - No off -property transport of visible emissions shall apply to on-site haul roads, the nuisance
guidelines shall apply to off-site haul roads.
c. Haul Trucks - There shall be no off -property transport of visible emissions from haul trucks when
operating on the property of the owner or operator. There shall be no off -vehicle transport of visible
emissions from the material in the haul trucks when operating off of the property of the owner or operator.
Control Measures
1. All unpaved roads and other disturbed surface areas on site shall be watered as necessary to prevent
off -property transport of visible fugitive particulate emissions.
2. Vehicle speed on all unpaved roads and disturbed areas shall not exceed a maximum of 30 mph.
Speed limit signs shall be posted.
3. All disturbed surface areas shall be revegetated according to the information submitted by the applicant
with the permit application.
4. Surface area disturbed shall be minimized as described in the information submitted by the applicant
with the permit application.
5. Gravel entryways shall be utilized to prevent mud and dirt carryout onto paved surfaces. Any mud and
dirt carryout onto paved surfaces shall be cleaned uRdaily.
6. No earth work activities shall be performed when the wind speed exceeds 30 miles per hour.
AIRS ID: 046/0030/001 Page 2 of 3
WILLIAMS PRODUCTION RMT CO
Permit No. 07GA0179L
Final Approval
Colorado Department of Public Health and Environment
Air Pollution Control Division
GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5, 6, 7 AND 8)
1. 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, 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.
2. 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.
3. 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 final approval 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.
4. This permit and any required attachments must be retained and made available for inspection upon request at
the location set forth herein. With respect to a portable source that is moved to a new location, a copy of the
Relocation Notice (required by law to be submitted to the APCD whenever a portable source is relocated)
should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in
AQCC Regulation No. 3, Part 8, Section 11.8. upon a request for transfer of ownership and the submittal of a
revised APEN and the required fee.
5. Issuance (initial approval) of an emission permit does not provide "final" authority for this activity or operation of
this source. Final approval 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 approval 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. If the APCD,so determines, it will provide written documentation of
such final approval, which does constitute "final" authority to operate. Compliance with the permit conditions
must be demonstrated within 180 days after commencement of operation.
6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operation within 18
months after either the date of issuance of this permit or the date on which such construction or activity was
scheduled to commence as set forth in the permit, whichever is later; (2) discontinue construction for a period of
18 months or more; of (3) do not complete construction Within a reasonable time of the estimated completion
date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the
permittee prior to the expiration date.
7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to
commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7-
114.5(12)(a), C.R.S. and AQCC Regulation No. 3, Part B, Section III.G.1., and can result in the revocation of the
permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of
operation as stated in condition 5.
8. 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. Ifa 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.
9. 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. •
AIRS ID: 046/0030/001 Page 3 of 3
February 22, 2007
Mr. Roland Hea
Colorado Depai talent of Public Health and Environment
Air Pollution Control Division
Construction Permit Section
4300 Cherry Creek Drive South, APCD-SS-B1
Denver, Colorado 80246-1530
Re: Cottonwood 24" and Crawford 20" Pipelines
Fugitive Dust APEN and Control Plan Submittal
Dear Mr. Hea:
colitmwm20,e-ti _�1Qe_ 2 t) 0221,
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Williams.
EXPLORATION & PRODUCTION
Tower 3, Suite 1000
1515 Arapahoe Street
Denver, CO 80202
303/572-3900
303/629-8282 fax
Williams Production RMT Company (Williams) is submitting the attached land development Air
Pollution Emission Notices (APENs) and fugitive dust control plans as required by Colorado
Regulation 1. Williams is planning to install two segments of a natural gas gathering pipeline
along the routes noted in the attached area map, all of which will be located in Garfield County.
There will not be any excavated material hauled away from the disturbed areas. The disturbed
area is estimated to be approximately 103 acres for the Cottonwood segment and 167 acres for
the Crawford Trail segment, which requires the submittal of the land development APEN and
fugitive dust control plan. The Cottonwood segment is proposed to begin on July 9, 2007 and is
estimated to be complete by September 28, 2007. The Crawford Trail segment is proposed to
begin on June 18, 2007 and is estimated to be complete by October 29, 2007. The contents of
the application are included in two appendices as outlined below:
Appendix Description
A Permit Application and Land D.evelopment APENs
B Project Area Map
C Project Specification Record
Williams requests that the Division invoice Williams for the APEN fees associated with this
project along with the application processing fees. As the technical contact for this project, I will
be available to answer any questions you may have regarding the information contained in this
submittal. Please feel free to contact me at the letterhead address above, directly by phone at
303.606.4366 or by email at rick.matar@williams.com.
Sincerely,
Wilms Production RMT Company
Rick Matar
Air Quality Practice Leader
Enclosure
Appendix A
Permit Application Form
and
Land Development APENs
Air Pollution Control Division Construction Permit Application
LEASE READ INSTRUCTIONS ON REVERSE SIDE.
1. Permit to be issued to: Williams Production RMT Company
2. Mailing Address: 1515 Arapahoe Street
Tower 3, Suite 1000
Denver, CO 80202
3. General Nature of Business: Exploration and Production of Natural Gas
SIC code (if known) 1311
4. Air Pollution Source Description: Construction equipment will prepare two pipeline routes prior to the installation of
(List permit numbers if existing source, the pipelines. The pipelines will be installed and disturbed area will be reclaimed.
attach additional pages if needed)
5. Source Location Address (Include Location Map) If portable, include the initial location and home base location
Please see attached site area map.
Is this a Portable Unit? No
6. Reason for Application: (Check all that apply)
New or Previously Unreported Source
Modification of Existing Source
Request for Synthetic Minor Permit
Other:
7. Projected Stprtup Date:
Administrative Permit Amendments
❑ Transfer of Ownership (Complete Section 9 & 10 below)
❑ Company Name Change (Complete Section 9 below)
❑ Other:
Signature of Legally Authorized Person of Company listed in Section 1
Rick Matar, Air Quality Practice Leader
Type or Print Name and Official Title of Person Signing Above
8. Check appropriate box. if you want:
Z Copy of preliminary analysis conducted by Division
® To review a draft of the permit prior to issuance
Date Signed
Phone: 303.606.4366
Fax: 303.629.8285
These sections are to be completed only if a company name change or transfer of ownership has occurred.
9. Permit previously issued to:
10. Transfer of Ownership Information
Effective Date of Permit Transfer:
As responsible party for the emission source(s) listed above, I certify that the business associated with this source has been
sold, and agree to transfer the permit to said party.
Signature of Legally Authorized Person of Company listed in Section 9
Type or Print Name and Official Title of Person Signing Above
Date Signed
Phone:
Fax:
Mail completed application, APENs, and filing fee to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
4300 Cherry Creek Drive South, APCD-SS-B 1
Denver, Colorado 80246-1530
http://www.cdphe.state.co.us/ap/stationary.html
Phone: (303) 692-3150
D.. -.:..-J A nnA
Colorado Department of Public Health and Environment Page 1 of 3
Air Pollution Control Division
- LAND DEVELOPMENT -
Air Pollutant Emission Notice (APEN) — and — Application for Construction Permit
® New Facility 0 Transfer of Ownership * 0 Change in Production 0 No Change (APEN Update Only)
All sections of this APEN and application must be completed prior to submittal to the Division for both new and
existing facilities. An application with missing information may be determined incomplete and may result in
longer engineer processing times.
* Note: For transfer of ownership or company name change of a permit, you must also submit a Construction
Permit Application form.
Permit Number AIRS Number
Company Name:
Billing Address:
Person to Contact:
Email Address:
Williams Production RMT Company
1515 Arapahoe Street, Tower 3 Zip Code: 80202
Suite 1000
Denver, CO
Rick Matar Phone Number: 303.606.4366
rick.matar(2 wiliiams.com Fax Number: 303.629.8285
Please provide description of the activity: (Also, please provide a site map)
Construction activities to prepare area for pipeline installation. The project will consist of two pipeline segments
being constructed within near proximity to each other. See attached map for site details.
Project Name & Location:
(Begin) County: Garfield
Cottonwood 24" Pipeline
Section: 34 Township: 6S
(End) County: Garfield Section: 14 Township: 6S
Total area of land in project:
Date earthmoving will — Commence:
Total area subject to earthmoving:
Total disturbed area at any one time:
Area to be paved (roads, parking lots):
Date paving will be completed:
103.3 Acres
Range: 95W
Range: 94W
07/09/2007 Stop: -- 09/28/2007
103.3
103.3
0
Estimated time to complete entire project (includes buildings)
List any known or suspected contaminates in the soil:
NA
Acres
Acres
Acres
— 3 months
Brief description of how the project development will occur (attach an additional page if necessary):
Construction equipment will prepare the pipeline route prior to the installation of the pipeline. The pipeline will
be installed and the disturbed area will be reclaimed as necessary.
Revised September 2004 http://www.cdphe.state.co.us/ap/stationary.html
Colorado Department of Public Health. and Environment Page 2 of 3
Air Pollution Control Division
- LAND DEVELOPMENT -
FUGITIVE DUST CONTROL PLAN FOR LAND DEVELOPMENT
(This must be submitted with the Air Pollutant Emission Notice -and -Application for Emission Pennit)
Regulation No. 1 requires that a fugitive dust control plan be submitted by applicants whose source / activity results in fugitive
dust emissions. The control plan must enable the source to minimize emissions of fugitive dust to a level that is technologically
feasible and economically reasonable. If the control plan is not adequate in minimizing emissions a revised control plan may be
required. The control plan (if acceptable to the Division) will be used for enforcement purposes on the sources.
Please check the dust control measures which you propose for your activity. The Division will enforce the control measures
checked. Use separate sheets if more space is needed. Also note items with an asterisk (*). This indicates those measures which
will probably be required.
I. Control of Unpaved Roads on Site
El Watering
❑ Frequent (Watering Frequency of 2 or More Times Per Day)
As Needed
0 Application of Chemical Stabilizer
Vehicle Speed Control
Speeds limited to 25 mph maximum. Speed limit signs must be posted.
(Generally 30 mph is maximum approvable speed on site.)
0 Gravelling
11. Control of Disturbed Surface Areas on Site
❑ Watering
❑ Frequent (Watering Frequency of 2 or More Times Per Day)
O As Needed
❑ Application of Chemical Stabilizer
❑ Vehicle Speed Control
Speeds Limited To MPH Maximum. Speed Limit Signs Must Be Posted.
® Revegetation Revegetation Must Occur Within One Year Of Soil Disturbance
® Seeding with mulch
❑ Seeding without mulch
❑ Furrows at right angle to prevailing wind
Depth of furrows Inches (must be greater than 6")
❑ Compaction Of Disturbed Soil On A Daily Basis To Within 90 % Of Maximum Compaction
(As determined by a Proctor Test).
❑ Foundation areas only; or
❑ All disturbed soil.
❑ Wind Breaks
Type: (Example: Snow Fence, Silt Fence, etc.)
❑ Synthetic Or Natural Cover For Steep Slopes.
Type: (Netting, Mulching, etc.)
Revised September 2004 http://www.cdphe.state.co.us/ap/stationary.html
Colorado Department of Public Health and Environment
Air Pollution Control Division
-LAND DEVELOPMENT -
III. Prevention Of Mud And Dirt Carried Out Onto Paved Surfaces.
® Prevention
® Gravel Entry Ways
❑ Washing Vehicle Wheels
O Other:
0 Cleanup of Paved Areas Frequency:
❑ Street Sweeper
❑ Hose With Water
❑ Other:
Times Per Day
Additional Sources of Emissions
List any other sources of emissions or control methods
Non -road mobile sources as well as support vehicles. Dust emissions will mainly be controlled through speed control
and watering as needed for these sources.
/22/0
Signature of Legally Authorized Person (not a vendor or consultant) Date
Rick Matar Air Quality Practice Leader
Name (please print) Title
Check the appropriate box if you want:
® Copy of the Preliminary Analysis conducted by the Division
® To review a draft of the permit prior to issuance
(Checking any of these boxes may result in an increased fee and/or processing time)
Send this form along with $119.96 to:
Telephone: (303) 692-3150
Small Business Assistance Program
(303) 692-3148
Small Business Ombudsman
(303) 692-2135
Colorado Department of Public Health and Environment
Air Pollution Control Division
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Revised September 2004 http://www.cdphe.state.co.us/ap/stationary.html
Appendix 13
Project Area Map.
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TERRA:
Engine Speed (rpm)
Compression Ratio .
Aftercooler Inlet Temperature (°F)
Jacket Water Outlet Temperature (°F)
Ignition System
Exhaust Manifold
'Combustion System Type
l -. t , e Rett gil)a',a ' .-
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Air Flow (Wet, ® 77°F, 28.8 in Hg)
Aft Mass Flow (Wet)
Compressor Out Pressure
Compressor Out Temperature
Inlet Manifold Pressure
Inlet Manifold Temperature (10)
Timing (11)
Exhaust Stack Temperature
Exhaust Gas Flow (Wet, 0 stack temperature, 29.7 In Hg)
Exhaust Gas Mass Row (Wet).•
bhp
kW
Fuel
LHV of Fuel (Biu/SCF)
Fuel System
NAT GM
920
HPG IMPCO
Minimum Fuel Pressure (psig) 35
Methane Number at Conditions Shown 80
RatedAltitude (fl) 5000
at 77°F Design Temperature
fs.75%dim'
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740 555 370
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°F
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°F
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lb/hr
En Irie;Emissions Data � k Eit ;' ''
gmhp-hr
(Corr. 15% 02) ppm
(Corr. 15% 02)
Nitrous Oxides (NOx as NO2) (9)
Carbon Monoxide (CO) (9)
Total Hydrocarbons (THC) (9)
Non -Methane Hydrocarbons (NMHC) (9)
Exhaust Oxygen (9)
Lambda
Engine. Heat-BalanceaDataa
Input Energy LHV (1)
Work Output
Heat Rejection to Jacket (2) (6) •
Heat Rejection to Atmosphere (Radiated) (4)
Heat Rejection to Lube Oil (5)
Total Heat Rejection to Exhaust (to 77°F) (2)
Heat Rejection to Exhaust (LHV to 350°F) (2)
Heat Rejection to Aftercooler - stage 1 (3) (7) (8)
(Corr. 15% 02)
(Corr. 15% 02)
1554
6892
61.3
268
58.7
134
22.5
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7273
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983
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g/bhp-hr
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g/bhp-hr
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g/bhp-hr
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1.2 1.3 1.4
139 138 122
1.5 1.5 2.0
301 300 338
0.23 0.23 0.31
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2.0
1.6
1.12 1.11
26
Btu/min
BlWmin
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Btu/min
Btu/min
Bturmin
Btu/min
Btu/min
t h't
131836
44663
51811
4554
0
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17156
3941
104070
33498
43406
3795
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-ENGLISH- page 1 of 2 DM5144-00
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^iF^ u K�W S i 5sis'
,Altftudei Deratlon � Factors
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0.94
0.91
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0.75
0.72
0.70
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1.00
1.00
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0.93
0.89
0.86
0.83
0.80
0.77
0.74
0.71
1.00
1.00
1.00
1.00
0.98
0.94
0.91
0.87
0.84
0.81
0.78
0.75
0.72
1.00
1.00
1.00
1.00
1.00
0.98
0.92
0.89
0.86
0.82
0.79
0.76
0.73
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.91
0.87
0.84
0.81
0.78
0.75
1.00
1.00
1.00
1.00
1.00
0.99
0.96
0.92
0.89
0.85
0.82
0.79
0.76
1.00
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.81
0.77
1.00
1.00
1.00
1.00
1.00
1.00
0.99
0.96
0.92
0.89
0.85
0.82
0.79
1.00
1.00
1.00
1.00
1,00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.80
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
'c'
1.38
1.46
1.53
1.61
1.69
1.77
1.77
1.77 '
1.77
1.77
1.77
1.77
1.77
1.29
1.36
1.44
1.52
1.59
1.87
1.67
1.67
1.67
1.67
1.67
1.87
1.67
1.19
1.27
1.34
1.42
1.50
1.57
1,57
1.57
1.57
1.57
1.57
1.57
1.57
1.10
. 1.17
1.25
1.32
1.40
1.48
148
1.48
1.48
1.48
1.48
1.48
1.48
1.01
1.08
1.15
1.22
1.30
1.38
1.38
1.38
1.38
1.38
1.38
1.38
1.38
1.00
1.00
1.06
1.13
1.20
1.28
1.28
1,28
1.28
1.28
1.28
1.28
1.28
1.00
1.00
1.00
1.03
1.10
1,18
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.00
1.00
1.00
1.00
1.00
1.08
1.08
1.08 ,
1.08
1.08
1.08
1.08
1.08
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1,00
1.00
1.00
1.00
1.00
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
�j `Y "ti La`R' ICi�F4 (_111 G.J.iI^q'ar •'4 'fly 3,G:. - [g' ..
.-.,,DM5144.00 Data`Is intended -to be used;with;Gas' Engine!Performance,Book Parameteis ,;DM5900 00 on,page 8 \ i?
DM5144-00 -ENGLISH- page 2 of 2
27
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
PERMIT NO:
To be issued
Colorado Department of Public Health and Environment
DRAFT
PERMIT
INITIAL APPROVAL
DATE ISSUED:
ISSUED TO: Williams Production RMT Company
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Natural Gas pipeline booster compression and gas dehydration facility, known as the Rabbit Brush
Compressor Station, to be located in the NW '% of the SE ' of Section 32, Township 6 South, Range 95
West, approximately 2 miles northeast of Parachute in Garfield County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
This Is a facility -wide permit covering all equipment and activities at this facility. Details of equipment and
activities are given in 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
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:
1. 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. EPA Method 9 shall measure opacity.
(Reference: Regulation 1, Section II.A.1.& 4.)
2, This source is subject to the odor requirements of Regulation No. 2 (State only enforceable).
• 3. The permit number and AIRS.ID number shall be marked on the subject equipment for ease of identification.
(Reference: Reg. 3, Part B, III.E.) (State only enforceable)
4. This source shall be limited to maximum consumption, processing and/or operational rates as listed in
Attachment A and all other activities, operational rates and numbers of equipment as stated in the application.
Monthly records of the actual operational rates and activities shall be maintained by the applicant and made
available to the Division for inspection upon request. (Reference: Regulation 3, Part B,II.A.4)
During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption
limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly
limitation shall be required.
Compliance with the yearly consumption and operational 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 consumption and operational rates and keep a
compliance record on site or at a local field office with site responsibility, for Division review.
5. Facility -wide emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's
preliminary analysis): (Reference: Regulation 3, Part B, II.A.4).
Point Sources
Nitrogen Oxides. 163.8 tons per year, and 13.91 tons per month
Volatile Organic Compounds. 50.6 tons per year, and 4.30 tons per month
Carbon Monoxide: 49.6 tons per year, and 4.22 tons per month
Formaldehyde. 5.9 tons per year, and 1003 lbs per month
Fugitive Emissions
Volatile Organic Compounds. 7.5 tons per year, and 1272.4 pounds per month
Monthly limits are based on a 31 -day month.
Emissions from individual equipment and activities shall not exceed the limits specified in Attachment A.
Records of actual emissions shall be maintained and made available for Division review upon request.
AIRS ID: To Be Issued 1
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
DRAFT
PERMIT
During the first twelve (12) months of operation, compliance with both the monthly and yearly emission
limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly
limitation shall be required.
Compliance with the annual limits shall be determined 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 for Division review.
6. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Reg.3, Part A,II.C)
a. Annually 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 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. Within 14 calendar days of commencing operation of a permanent replacement engine under the
alternative operating scenario outlined In this permit. 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.
7. Within one hundred and eighty days (180) after commencement of operation, 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.
8. This permit shall expire if the owner or operator of the source for which the 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 initial approval 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 dale (See General Condition No. 6, Item 1). 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)
Natural Gas Internal Combustion Engines
9. Points 001, 002, 003, 004, and 005: the serial numbers of the subject equipment shall be provided to the
Division prior to Final Approval. (Reference: Regulation No. 3, Part B, III.E.)
10. The engines listed in Attachment A (AIRS ID: 001, 002, 003, 004 and 005) may be replaced with other engines
in accordance with the temporary engine replacement provision or with other engines of the same make and
model in accordance with the permanent replacement provision of the Altemate Operating Scenario (AOS),
included in this permit as Attachment B.
11. Source compliance tests shall be conducted on compressor engines to measure the emission rate(s) for the
pollutants listed below in order to show compliance with emission limits and to demonstrate the performance of
the emission control devices. 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. The protocol shall include manufacturers analysisof emissions at engine
maximum and minimum loads, at site-specific conditions. Engine operating parameters will be included in the
analysis with emissions reported in parts per dry volume and grams per actual horsepower -hour (g/bhp-hr) or
pounds per million BTU (ib/MMBtu). No compliance test shall be conducted without prior approval from the
Division. Any stack test conducted to show compliance with a monthly or annual emission limitation shall have
AIRS ID: To Be Issued 2
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
the results projected up to the monthly or annual averaging time by multiplying the test retie byJtlg4tlowable
number of operating hours for that averaging time (Ref: Regulation No. 3, Part B, Secti I
Nitrogen Oxides, Formaldehyde, Carbon Monoxide and Oxygen using EPA approved methods.
If the engines operating as points 001, 002, 003, 004, and 005 are of the same make and model, a compliance
test shall be required for one of these units, and a thirty -minute test run may be performed for the other identical
units. If the emissions from the shortened test on the second and subsequent units show that emissions are not
more than 10% above the emissions of the unit that had a full test series performed on it, then the Division will
consider the emissions from the second and subsequent units to be identical to the emissions from the first unit.
A full set of three test runs must be completed on any unit whose shortened test shows that emissions are
more than 10% of the unit undergoing the full test series.
'12. Points 001, 002, 003 and 004: these engines shall be equipped with oxidizing catalysts capable of reducing
uncontrolled emissions of volatile organic compounds by at least 93%, carbon monoxide by at least 93% and
formaldehyde by at least 75%. Operating parameters of the control equipment shall be identified prior to final
approval of this permit. The identified operating parameters will replace the control efficiency requirement on
the final permit. (Reference: Regulation No. 3, Part B, IV.E.)
13. Point 005: the generator engine shall be equipped with a 3 -way catalyst capable of reducing uncontrolled
emissions of nitrogen oxides by 90%, carbon monoxide by at least 75%, volatile organic compounds by at least
50% and formaldehyde by at least 50%. Operating parameters of the control equipment shall be identified prior
to final approval of this permits The identified operating parameters will replace the control efficiency
requirement on the final permit. (Reference: Regulation No. 3, Part B, IV.E.)
14. Point 005: the generator engine represents a potential major source, if left uncontrolled. As such, this unit is
subject to the requirements described in 40 CFR Part 64 Compliance Assurance Monitoring (CAM). This unit
must operate in compliance with a CAM plan submitted to the state for final approval, originally submitted with
the construction permit application. (Reference: Regulation No. 3, Part C, XIV)
By: By:
Blue Parish, P.E.
Permit Engineer
•
Roland C. Hea, P.E.
Unit Leader
Action
Date
Description
Initial Approval
This Issuance
Installation of four natural gas compressor engines (AIRS ID:
001, 002, 003 and 004), one generator engine (ID: 005), two
TEG dehys (AIRS ID: 006 and 007) and associated
equipment.
AIRS ID: To Be Issued
3
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Notes to Permit Holder:
Colorado Department of Public Health and Environment
. _.. .
DRAFT
PERMIT
1) The production or raw material processing limits and emission limits contained in this permit are based on the
production/processing rates requested in the permit application. These limits may be revised upon request of the
permittee providing there Is no exceedence 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.
2) This source Is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.
The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits
stated in this permit as soon as possible, but no later than two (2) hours after the start of the next working day,
followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or
is being taken to correct the conditions causing said violation and to prevent such excess emission in the future.
3) The following facility -wide emissions of non -criteria reportable air pollutants are estimated based upon equipment
and activity specifications as indicated in this permit. This Information is listed to inform the operator of the Division's
analysis of the specific compounds. This information is listed on the Division's emission inventory system.
C.A.S. # SUBSTANCE EMISSIONS fLB/YR)
50-00-0 Formaldehyde 11,810.3
71-43-2 Benzene 3,847.0
75-07-0 Acetaldehyde 3,611.6
107-02-8 Acrolein 2,252.2
108-88-3 Toluene 4,189.6
1330-20-7 Xylenes 1,062.6
110-54-3 n -Hexane 2,037.8
4) The emission levels contained in this permit are based on the following emission factors:
Compressor Engines (AIRS ID: 001, 002, 003 and 004): G3612LE TA -130 Lean Burn Units
Pollutant
Emis. Factor
Emis. Controls
Control Eff.%
Nitrogen Oxides
1.0 g/hp-hr
SCO
N/A
Carbon Monoxide
0.18 g/hp-hr
SCO
-93
Volatile Organic Compounds
0.10 g/hp-hr
SCO
-93
Acetaldehyde
AP -42
SCO
50
Acrolein
AP -42
SCO
50
Benzene
AP -42
SCO
50
Formaldehyde
AP -42
SCO
75
Generator Engine (AIRS ID: 005): G3516 TA -130 Rich Burn Unit
Pollutant
Em's. Factor
Emis. Controls
Control Eff.%
Nitrogen Oxides
2.0 g/hp-hr
NSCR
90
Carbon Monoxide
2.0 g/hp-hr
NSCR
78
Volatile Organic Compounds
0.25 g/hp-hr
NSCR
50
Acetaldehyde
AP -42
NSCR
50
Acrolein
AP -42
NSCR
50
Benzene -
AP -42
NSCR
50
Formaldehyde
AP -42
NSCR
50
5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid
for a term of five years. The five-year tens for this APEN expires on April 15, 2012. A revised APEN shall be
submitted no later than 30 days before the five-year term expires.
AIRS ID: To Be Issued
4
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
. _.. .
DRAFT
MaJor Source
PERMIT
6) This facility will be classified as follows upon issuance of this permit:
Operating Permit
Synthetic Minor:
Carbon Monoxide, Formaldehyde
Meier:
Nitrogen Oxides
MACT ZZZZ
Synthetic Minor:
Formaldehyde
MACT HH
Synthetic Minor:
HAPs
AIRS ID: To Be Issued 5
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
._...
DRAFT
PERMIT
GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8)
1. 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, 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.
2. 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.
3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of, a
condition herebf 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 final approval bythe Air Pollution Control Division (APCD)
on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air QualityControl 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.
4. This permit and any required attachments must be retained and made available for inspection upon request at the location
set forth herein. With respect to a portable source which is moved to a new location, a copy of the Relocation Notice
(required by law to be submitted to the APCD whenever a portable source is relocated) should be attached to this permit
The permit may be reissued to a new owner by the APCD as provided in AOCC Regulation No. 3, Part B, Section III.B.
upon a request for transfer of ownership and the submittal of a revised APEN and the required fee.
5. Issuance (Initial approval) of an emission permit does not provide "final' authority for this activity or operation of this
source. Final approval of the permit must be secured from the APCD in wilting in accordance with the provisions of 25-7-
114.5(12)(a) C.R.S. and ADCC Regulation No. 3, Part B, Section IV.H. Final approval 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. If the APCD so determines, it will provide written documentation of such final approval, which does constitute
"final" authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after
commencement of operation.
6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operation within 18 months after
either the date of issuance of this permit pr the date on which such construction or activitywas scheduled to commence as
set forth In the permit, whichever is later, (2) discontinue construction for a period of 18 months or more; or (3) do not
complete construction within a reasonable time of the estimated completion data Extensions of the expiration date may be
granted by the APCD upon a showing of good cause by the permittee prior to the expiration date.
7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement of the
permitted operation or activity. Failure to do so is a violation of Section 25.7.114.5(12)(a), C.R.S. and AQCC Regulation
No. 3, Pad 8, Section IV.H.1., and can result in the revocation of the permit. You must demonstrate compliance with the
permit conditions within 180 days after commencement of operation es stated in condition 5.
8. 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 requesling a cancellation of the permit Upon notification, annual fee billing will
terminate.
9. 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.
AIRS ID: To Be Issued 6
ATTACHMENT A - RABBIT BRUSH COMPRESSOR STATION
vities covered under this facility -wide permit
AIRS ID
N
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
001
One (1) Caterpillar, Model:
low emissions design, reciprocating
24,000,000 BTU/hr, site rated
engine is equipped with an automatic
control of emissions of Carbon
Operational Limits:
Consumption of natural gas as
based on a typical gas heat value
G3612LE TA -130, SM: N/A, natural gas fired, 4 -stroke,
internal combustion engine, site heat input
output at 3,550 HP, powering a natural gas compressor.
air -to -fuel ratio controller and an Oxidation
Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG -0I.
a fuel shall not exceed 202.1 MMscf1yr and 18.6 MMscVmonth.
of 1,040 RTU/SCF (HHV)
lean -bum,
rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
tail and subsequent
portable testing.
Emission Limits:
Pollutant
Anneal Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carbon Monoxide
6.0 tom per year
1019 lbs/month
Volatile Organic Compounds
3.4 tons per year
570.6 Ibs/rnonth
Formaldehyde
1.39 tom per year
2353 lbs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(F/bhp-lir)
Ib/MMbtu
Nitrogen Oxides
1.0
-
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolcin
-
0.00257
002
One(I) Caterpillar, Model: G3612LE TA -130, S/N: N/A, nature gas fired, 4 -stroke,
0w emissions design, reciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air -to -fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG -02.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yr and 18.6 MMsctlmonih.
based on a typical gas heat value of 1,040 BTU/SCF (HNV)
Emission Limits:
lean -bum,
input rated at
This
Catalyst for the
Hazardous Air
TLis is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carbon Monoxide
6.0 tons per year
1019 lbs/month
Volatile Organic Compounds
3.4 tons per year
570.6 Ibshnonih
Formaldehyde
1.39 tons per year
235.7 lbs/month
Emission Factors:
Pollutant
Controlled Emissio Factors
telbhp-hr)
Ib/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
Volatile Organic Coinpounds
0.10
-
Formaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acroicin
-
0.00257
AIRS ID
fi
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
003
One (I) Caterpillar, Model: G3612LE TA-130, SM: N/A, natural gas fired, 4-stroke,
low emission design, reciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air-to-fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG-03.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscUyr and 18.6 MMscimanth.
based on a typical gas beat value of 1,040 BTU/SCF (HHV)
Emission Limits:
lean-bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 Ibs/month
Carbon Monoxide
6.0 tons per year
1019lbs/month
Volatile Organic Compounds
3.4 tons per year
570.6 lbs/mooth
Formaldehyde
1.39 tons per year
235.7 Rs/month
Emission Factors:
Pollutant
Controlled Emission Factors
ht/bhp-hr)
Ib/MMbtu
Nirogea Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Fomnaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
004
One (I) Caterpillar, Model. G3612LE TA-130, S/N• N/A, natural gas fired, 4-stroke,
low emissions design, eciprocating intemal combustion engine, site heat
24,000,000 BTU/lir, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air-to-fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG-04.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yrand 18.6 MMscf/month.
based on a typical gas heat value of 1,040 BTU/SCF (HHV)
Emission Limits:
lean-bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carbon Monoxide
6.0 tons perycar
1019 lbs/month
Volatile Organic Compounds
3.4 tons per year
570.6 lbs/month
Formaldehyde
1.39 mess per year
235.7 Ibs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(P/bhp-hr)
1b/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaklehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
AIRS ID
p
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
005
One (I) Caterpillar, Model: 63516TA-130, S/N: N/A, natural gas fired, 4 -stroke,
reciprocating internal combustion engine, site heat input rated at 9,130,000 BTU/hr,
output at 1,053 HP, powering a natural gas compressor. This engine is equipped
automatic air -to -fuel ratio controller and a 3 -way catalyst for the control of emissions
Oxides, Carbon Monoxide, Volatile Organic Compounds and Hazardous Air
unit is identified as ENG -05.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 66.6 MMscf/yr and 5.7 MMsctYmonth.
based on a typical gas heat value of 1,040 BTU/SCF (HH V)
Emission Limits:
rich -bum
site rated
with an
of Nitrogen
Pollutants. This
71tis is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
40 CFR Pad 64
Compliance Assurance
Monitoring
Po0utant
Annual Limit
Monthly Limit
Nitrogen Oxides
- 20.3 tons per year
3,454 lbs/month
Carbon Monoxide
20.3 tons per year
3,454 nu/month
Volatile Organic Compounds
2.5 tons per ytmr
432 lbs/month
Formaldehyde
0.36 tons per year
60.3 lbs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(g/bhp-hr)
1b/MMbtu
Nitrogen Oxides
2.0
Carbon Monoxide
2.0
-
Volatile Organic Compounds
0.25
-
Formaldebyde
-
0.01025
Acetaldehyde
-
0.00140
Acrolein
-
0.00132
006
One triethylene glycol (TEG) natural gas dehydration
90,000,000 SCF per day, lean TEG circulation rate
consists of: gas/glycol contactor, Bash tank and gas
captured by a Vapor Recover Unit. This
Operational Limits:
Potential Natural Gas processed in the dehydration system:
Lean TEG circulation rale: 24 gallons/minute
Emission Limits:
system, S/N:
at 24 gallons
driven glycol
is identified
90,000,000
N/A, feed gas design rated at
per minute. This system
pump. All emissions will be
as DENY -01.
SCF/DAY
Equipped with
condenser and all
emissions captured
by VRU; assumed up
to 5% VRU
downtime.
VOC/HAP DRE: >95%
Overall
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
L4 tons per year
Toluene
1,871 lbs per year
Xylenes
442 lbs per year
Benzene
1,722 lbs per year
AIRS 117
#
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
007
One triethylene glycol (TEG) natural gas dehydration
90,000,000 SCF per day, lean TEG circulation rate
consists of: gas/glycol contactor, flash tank and gas
captured by a Vapor Recover Unit. This
Operational Limits:
Potential Natural Gas processed in the dehydration system:
Lean TEG circulation rate: 24 gallunsdmIncite
Emission Limits:
system, S/N: N/A, feed gas design rated at
at 24 gallons per minute. This system
driven glycol pump. All emissions will be
is identified as DEHY-02.
90,000,000 SCF/DAY
Equipped with
condenser and all
emissions captured
by VRU; assumed up
to 5% VRU
downtime.
VOC/HAP DRE: >95%
Overall
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
8.4 tons per year
Toluene
1 871 lbs per year
Xylenes
442 lbs per year
Benzene
1,722 lbs per year
008
Three (3) custom, vertical fixed roof tanks, each wi
together. Flash emissions captured in the flash tank
Additional flashing from the flash tank down to atm
The tanks are identified
Operational Limits:
Condensate throughput limit: 14,600 barrels per year
Emission Limits:
h a capacity of400 barrels and manifolded
are routed to a Vapor Recovery Unit.
spheric pressure are vented to atmosphere.
as TK-01.
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
17.5 tons per year
Benzene
1321bs/yr
009
One natural gas fired process heater with a maximum
be used to for TEG regeneration, storage tank heating,
loads. This heat medium system will
Operational Limits:
The maximum heat input rating of this heater is: 15.0
Fuel Consumption: 126,346,000 SCF/YR
Fuel consumption based on 1040 Btu/scf heating value
Emission Limits:
heat rating of 15 MMbiu/hr. This unit will
building heat and miscellaneous heat
be identified as HTR-0l.
MMbtu/hr.
Compliance Plan.
Subject to HSPS Dc
Pollutant
Annual Limit
Nitrogen Oxides
6.32 tons per year
Carbon Monoxide
5.31 tons per year
Volatile Oresit Compounds
0.35 tons per year
PM-10
0.48 tons per year
AIRS ID
q
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
010
DescHption
Fugitive emissions from equipment leaks. The facility ID
Operational Limits:
The source shall be limited to a maximum equipment configuration
for this unit is,
as listed below.
n. belches, dump
FUG-1.
arms and Merriment
Tale 2-4
Component
Non-Residue Gas
Service
NGL
Service
Valves
376
89
Connector
925
468
Flanges
228
144
Seals
-
14
Other`
48
-
VOC Content (wt%)
10.79%
100%
' Other equipment Includes compresson, PRY:, relieIvalves, diaphragms, drains, ve
Emission Limits:
Pollutant
Annual Limit
Monthly Limit
Volatile Organic Compounds
7.49 tons per year
1272 lbs/month
Emission Factors (Ib/hr-componentb
Sourre: PPA-453nt-95-012,
Component
Non-Residue Gas
Service
NGL
Service
Valves
0.00992
0.00551
Connector
0.00044
0.00046
Flanges
0.00086
0.00024
Seals
0.00529
0.02866
Other
0.0194
0.01653
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
ATTACHMENT B
1. Alternative Operating Scenarios
The following Alternative Operating Scenario (AOS) for temporary and permanent engine replacement has been
reviewed In accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -
Alternative Operating Scenarios, and Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, and
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 permittee
shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new
Construction Permit.
1.1 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 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 counts towards the 90
day total. Note that the compliance demonstrations and any periodic monitoring required by this AOS are in addition to
any compliance demonstrations or periodic monitoring required by the permit.
All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit
(including monitoring and record keeping).
Results of all tests and the associated calculations pursuant required by this AOS shall be submitted to the Division
within 30 calendar days of the test. Results of all tests shall be kept on site for five (5) years and made available to the
Division upon request.
The permittee shall maintain a log on-site, or at a local field office with site responsibility, to contemporaneously record
the start and stop date of any engine replacement, the manufacturer, 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.
1.1.1 The permittee may temporarily replace the 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 emissions from the temporary
replacement engine comply with the emission limitations for the existing permitted engine as determined in section 1.2.
Measurement of emissions from the temporary replacement engine shall be made as set forth In section 1.2.
1.1.2 The permittee may permanently replace the 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 without modifying this pennit,
so long as the emissions from the permanent replacement engine comply with the emission limitations for the existing
permitted engine as determined in section 1.2, Measurement of emissions from the temporary replacement engine shall
be made as set forth in section 1.2.
An Air Pollution 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 and a cover letter explaining that the permittee is exercising an alternative operating scenario
and is installing a permanent replacement engine.
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 permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to
theDivlslon in regard to any permanent engine replacement.
If 40 CFR Part 63, Subpart ZZZZ is newly triggered by a permanent replacement engine, the permittee must apply fora
revision to their operating permit within 90 days of installation.
AIRS ID: To Be Issued 7
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
1.2 Portable Analyzer Testing
The permittee shall measure nitrogen oxide (NO.) 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
temporary replacement engine. •
All portable analyzer testing required by this permit shall be conducted using the Division's Portable
Analyzer Monitoring Protocol as found on the Division's website at:
http://www.cdohe.state co us/ao/down/oortanalyzeproto.pdf
Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an
annual or short term emission limit, the results of the tests shall be covered to a Ib/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.
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 lest until a portable analyzer test indicates
compliance with both the NOx and CO emission limitations or until the engine is taken offline.
1.3 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 ensile engine has to go
through the appropriate Construction/Operating permitting process prior to installation.
AIRS ID: To Be Issued 8
Attachment 2
Webster Hifi Compressor Station Revised APENs
Proposed Draft Permit
CAM Plan
Williams Production RMT Company, Rabbit Brush Compressor Station ENG -5 CAM Plan
Submitted January 3, 2007
Compliance Assurance Monitoring
Rabbit Brush Compressor Station
Williams Production RMT Company
Emission Unit
a) Facility: Rabbit Brush Compressor Station
b) Location: NW ''A SE ''A of Sec. 32, T6S, R95 W in Garfield County
c) Description: One G3516 TA -130 rich -burn engine w/NSCR and AFR
d) Const. Permit Number: Pending
Background
The proposed Rabbit Brush Compressor Station generator engine (ID: ENG -5) meets the
applicability requirements as described in 40 CFR 64 Compliance Assurance Monitoring
(CAM).
• The unit will be located at a proposed major source;
• The unit is subject to emission limitations or standards for an applicable regulated air
pollutant;
• The emission unit will use an add-on control device to achieve compliance with an
emission limit; and
• The emission unit has a potential to emit without the control device of greater than
100 tons per year of NOx.
The CAM regulation requires the following of an affected source:
• Proposed indicators of performance relevant to compliance;
• Indicator ranges or conditions, or the process by which such indicators will be established;
• Performance criteria that satisfy 40 CFR 64.3(b);
• Indicator ranges and performance criteria.
The regulation requires affected sources to monitor at least one indicator of performance for the
control device. For these sources a minimum of one observation per 24 hours of the chosen
parameter must be performed and recorded.
Rationale of Selection of Performance Indicators
The pressure drop across the catalyst is monitored weekly. AAP exceeding limits in indicator
range may indicate that the catalyst is becoming fouled.
Temperature into the unit is measured because temperature excursions can indicate problems
with engine operation and can retard the chemical reduction taking place in the catalyst bed.
Williams Production RMT Company, Rabbit Brush Compressor Station ENG -5 CAM Plan
Submitted January 3, 2007
Monitoring Approach
The key elements of the monitoring approach for NO,, emissions, including the indicators to be
monitored, indicator ranges and performance criteria are presented in Table 1 below.
TABLE 1. Rabbit Brush Rich -burn Engine CAM
Indicator No.1
Indicator No.2
Indicator No.3
I. Indicator
Pressure drop across the
catalyst
Temperature of exhaust
gas into catalyst
Temperature of exhaust
gas out of catalyst.
Measurement Approach
Differential pressure
transmitter
Thermal device
Thermal device
II. Indicator Range
AP < 2" H2O from
baseline. Excursions
trigger corrective action.
750 °F < T < 1350 °F.
Excursions trigger
corrective action.
INLET °F < T c 1350
°F. Excursions trigger
corrective action.
IH. Performance Criteria
A. Data
Representativeness
Standard accuracy to
th2% FS.
Standard accuracy to
±2% FS.
Standard accuracy to
±2% FS.
B. Verification of
Operational Status
AP reading.within
indicated range.
Temperature reading
within indicated range.
Temperature reading
within indicated range.
C. QA/QC Practice and
And criteria.
Calibration annually
Calibration annually
Calibration annually
D. Monitoring
Frequency
Weekly
Daily
Daily
E. Data Collection
Procedures
Spot AP noted on Site
Log Weekly.
Spot Temperature noted
on Site Log Daily
Spot Temperature noted
on Site Log Daily
F. Averaging Period
None
None
None
October 31, 2006
Colorado Department of Public Health & Environment
Construction Permit Section, APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Re: Construction Permit Application
Rabbit Brush Compressor Station
Garfield County, Colorado
Dear Mr. Roland Hea:
fes;}Brwk CS- Rfp-0001103110
Williams.
UMORATTON 8c PRODUCTION
Tower 3, Suite 1000
1515 Anphoe Stint
Dans CO 80202
303/572-3903
303/629.8282 &z
Williams Production RMT Company (Williams) is submitting the attached Facility -Wide
Construction Permit Application for a proposed natural gas compression facility, the
Rabbit Brush Compressor Station. The Rabbit Brush Compressor Station (Rabbit Brush)
will be located in the NW % of the SE '4 of Section 32, Township 6S, Range 95W in
Garfield County, situated at an elevation of approximately 5155 ft above sea level.
This facility is designed with a capacity to gather and compress up to 180 MMacf/day of
incoming natural gas at a typical field pressure of 200-245 psig. Inlet field natural gas
will be routed through an inlet separator to rove entrained liquids from the inlet gas
stream. The gas will be compressed by several reciprocating, interval combustion
engine -driven compressors to a pressure of approximately 900-950 psig, and routed
through two parallel triethylene glycol (TEG) dehydration units to remove moisture from
the gas stream. The dehydrated natural gas stream will then Ieave the facility via
pipeline. Williams plans to instal four inteamal combustion engine driven compressors,
one internal combustion engine driven generator, one process heater, two 90 MMscflday
TEG dehydration units, one vapor recovery unit (VRU), and three 400 -bbl condensate
storage tanks at the facility.
A site location map, facility plot plan, and process flow diagrams are provided in
Attachment 1. A completed Permit Application form and completed APENs for
emissions sources are provided in Attachment 2.
FacfHty-Wlde So{utc8 and .nilnlon:
Internal Combustion-} noires
There will be five (5) natural gas fired reciprocating internal combustion engines at the
Rabbit Brush Compressor Station. There will be four Caterpillar 3612LE TA -130 4 -
cycle lean burn engines each site -rated at 3,550 hp and equipped with selective catalytic
oxidation (SCO) mission control systems that will operate in inlet natural gas
compression service (source ID: ENG -01 through ENG -04). Site -rated horsepower
ratings are based on non -derated manufacturer specifications. The NOJCONOC
E
Roland Hes - CDPHE
Ouober 31, 2006
Page 2
emission factors for these engines will be 0.7 g/hphr NO., 0.18 g/hp-br CO, and 0.1 g/hp-
hr VOC based on ms's emission factors and emission testing malts obtained
for like -kind engines operating at the Williams Parachute Crede Gas Plant. The annual
potential emissions of NO., CO, and VOC from each engine will be 24.0 tpy, 6.0 tpy, and
3.4 tpy.
The fifth engine will be a Catapillar G3516 TALE generator engine site -rated at 1,053
hp (1,200 rpm), also equipped with an SCO emission control system that will provide
backup electrical power to the site. This unit will be permitted at mniminn operational
capacity of 8,760 hra/year based on non -derated manufacturer specifications. The
NO./CO/VOC emission factors for this proposed controlled engine will be 1.510.5/0.5
g/hp-hr with maximum annual NO., CO, and VOC emissions of 15.3 tpy, 5.1 tpy, and 5.1
tln .
Triethvlene GlvcoLDdrvdration.Iinits.,,,a„-
There will be two TEO dehydration units (Source ID: DEHY-1 and DEHY-2), plumbed
in parallel, and each designed to remove water from the natural gas after it has been
compressed to 900-950 psig by the booster compression units. Each TEG dehy is
designed to process up to 90 MMscflday of field natural gas and both will operate with a
flash tank and a regenerator still vent condenser emission control.
Under normal operating conditions, the flash tank ovabead vapor streams and the
regenerator still vent condense' overhead streams from both TEG dehydration units will
be routed to the VRU. The dehydration units therefore are designed to operate as closed-
loop systems with no emissions to ahnosphers.
Consistent with Division recommendations, Williams is classifying the VRU as a control
device rather than a permitted process unit, and is listing the VRU as such on the
completed APEN forms for the two dehydration units. HYBON Engineering, the
proposed VRU manufacturer, guarantees a minimum 95% runtime, which corresponds
to a maximum of 18 days of down-time per year for routine repair and maintenance. The
control efficiency of each dehy, as listed on the APENs, was ddmnined based on the
VRU vendor run-time patentee, a copy of which is provided in Attachment 3.
Controlled emissions listed on the dehydration unit APENs were calculated based on the
assumption that each dehydration unit operates with condenser controls at all times and a
VRU downtime of 5%. When the VRU is not operating, VOC and 11AP are emitted from
the flash tank and the regenerator still vent condenser outlet of each dehydration unit.
The estimated annual permitted VOC emissions from each dehydration unit are 3.6 tpy
from each flash tank and 4.8 tpy from each regenerator still vent condenser outlet, for a
total of 8.4 tpy for each dehydration unit.
L
Roland Ha - CDPHE
October 31, 2006
Page 3
Condensate Stmaowa.
Williams plans to install three 400 -bbl aboveground atmospheic condensate storage
tanks. The three stock tanks (ID: TANK -01) will be manifoldcd together and will be
designated as one emission point. Condensate at a maximum inlet pressure of
approximately 245 prig will be routed from the inlet gas separator to a pressurized
condensate flash tank process vessel which will operate at approximately 20 psig.
Condensate flash vapors produced as the condensate pressure is reduced from the inlet
separator pressure to 20 psig am routed to the VRU whew they are reoompressed and
muted back into the facility inlet gas stream with zero emissions to atmosphere.
Additional dash gas is produced as the 20 psig condensate leaves the flash tank process
vessel and is routed to the stock tanks operating at atmospheric press' e. This flash gas
will be emitted through the TANK -01 vents to atmosphere. A process flow diagram of
the VRU is presented is Attachment 1;
Permitted VOC emissions from the TANK -01 emission source are calculated as the
combined total of estimated flash and working/hreathing emissions from the tanks during
normal operating conditions with the VRU operating (dash from 20 prig to atmosphere,
8,322 fir/yr), phis estimated flash and working/breathing emissions during VRU down-
time (flash from 245 psig to atmosphere, 438 hr/yr). An average daily condensate
production rate of 40 bbl/day is assumed. Annual VOC emissions from the TANK -01
emission source during normal operating conditions, estimated using the API E&P
TANKS 2.0 computer model and including flash and working/breathing Iosses, aro 15.0
tpy. Annual VOC_emissions from the TANK -01 emission source during upset conditions
when the VRU is not operating are estimated at 2.5 tpy. Total requested VOC emissions
from the TANK -01 emission source am 17.5 tpy. The calculated overall control
efficiency for the VRU in controlling all potential VOC emissions from the TANK -01
emission source is 65%.
Consistent with Division recommendations, Williams is classifying the VRU as a control
device rather than a permitted process unit, and is listing the VRU as such on the
completed APEN for the TANK -01 emission source. Due to the inherent seasonal
variability of condensate production in the Piceance Basin, Williams requests that APCD
lists only an annual condensate throughput limit in the permit.
Vapor Recovery UAL
As described above, Williams will use one VRU as a VOC and HAP emission contuA
device for both dehydration units and the condensate tank mission unit. The permitted
emissions from the dehydration units and the condensate storage tanks are estimated
based on the vendor guarantee of a 95% control efficiency for the vapor streams being
controlled by the VRU, based an a 100% control efficiency while operational, and
assuming a maximum down-time of 5% (I8 days per year) when the VRU is non-
operational. A process flow diagram of the proposed VRU is provided in Attachment 1.
Roland Hes - CDPHE
October 31, 2006
Page 4
Pions Resor
Williams will install a heat medium system that will be used to support various process
unit operations including TEG regeneration, building heat, storage tank heating and other
miscellaneous heat loads. This natural gas fiord process heater (ID: HTR -01) has a
maximum heat rating of 15.0 MMBtu/hr. Emssions of NO., CO, and VOC are estimated
at 632 tpy, 531 tpy and 0.35 tpy, based _ Fion AP -42 natural gas combustion emission
factors. An equipment specification sheet for this heater is provided in Attachment 3.
.rtdput
Periodically, condensate will be loaded from the condensate storage tanks at Rabbit
Brush into trucks for transport off site (ID: LOAD -01). The estimated total condensate
production rate of 40 bbis/day and molecular weight data from the E&P TANKS 2.0
model were used in conjunction with the USEPA loadout equation to estimate VOC
emissions from this source. Emissions of VOC from this source are estimated to be
below the thresbold limit of 2 tpy for APEN reporting. Therefore, the LOAD -01
condensate loadout source is an insignificant omission source that will not be included in
the facility -wide permit. A condensate loadout calculation sheet is provided in
Attachment 3.
jrunitive VOC from 1 eakinv Pnuipmait
Potential fugitive VOC emissions from leaking equipment (ID: FUG -01) are estimated at
7.5 tpy VOC, using estimated equipment component counts, a representative inlet gas
analysis from a compressor station in the same field, and US EPA Oil and Gas
Production Operations emission factors. A fugitive VOC emissions calculation sheet is
provided in Attachment 3.
Total Facility -Wide Potential Emissions
Total facility -wide potential emissions for all sources included in the facility -wide permit
and all sources that are exempt from permitting are 117.6 tpy NO,,, 34.5 tpy CO, and 60.7
tpy VOC at Rabbit Brush. Potential emissions of regulated non -criteria reportable
pollutants (HAP) flan the facility are estimated at 14.7 tpy aggregate, with formaldehyde
being the highest single HAP emission at 6.0 tpy. An emissions spreadsheet is provided
in Attachment 3.
Compliance wick National Ambient Mr Quality Stoudards (NAAOSI
Williams used the US EPA SCREENS model to demonstrate that the NO, emissions
from the five internal combustion ergines at Rabbit Brush will not result in a violation of
the annual NAAQS for NO2 of 100 µglm3. The combined maximum annual ambient air
NO2 concentration is estimated at 40.0 gghn3 at the nearest property boundary
approximately 150 feet from the primary compressor engine building. Adding an
Roland Hea- CDPHE
October 31, 2006
Page S
accepted background NO2 concentration of 7.5 pg/m3, provided by Doris Jung of the
APCD, results in a total combined maximum ambient air concatration of 47.5 µg/m3.
This value is well blow the annual NAAQS for NO2 of 100 µg/m3 and the proposed
facility will not cause an off-site violation of the NAAQS. Copies of the NAAQS
calculation sheet and SCREEN3 input and output rcpuit are provided in Attachment 4.
We request that the Division invoice Williams for the APEN fees associated with this
application. If you have any questions related to this submittal, or if you require
additional information please call me at the Williams Denver office at (303) 606-4386.
Sincerely,
Williams Production RMT Co
G. Alberts
Principal Environmental Specialist
attachments
ATTACHMENTS
Attachment 1: Area Map, Facility Piot Plan, Process Flow and VRIJ Diagrams
Attachment 2: Permit Application and Completed APENs
Attachment 3: Emissions Inventory Spreadsheet and Supporting Calculation Sheets
Attachment 4: SCREEN3 Modeling Summary
Attachment 1
Area Map, Facility Plot Pian, Procen Flow and'VRU Diagrams
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RABBIT BRUSH COMPRESSOR STATION
SITE LOCATION MAP
1
WI LIAMS PRODUCTION RMT COMPANY
Lat 39°28.5' North 10/16/06
Long I08°I.2' West MS
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Attachment 2
Completed Application for Construction Permit
Completed APENs
Air Pollution Control Division Construction Permit Application
PLEASE READ INSTRUCTIONS ON REVERSE SIDE. '
1. Permit to be issued to: Williams Production RMT Company
2. Mailing Address: 1515 Arapahoe St., Tower 3, Suite 1000
Denver, Colorado 80202
3. General Nature of Business: Exploration and Production of Natural Gas
SIC code (if known) 1311
4. Air Pollution Source Description: Natural Gas Gathering and Compression
(List permit numbers if existing source, N/A
attach additional pages if needed)
5. Source Location Address (Include Location Map)
Rabbit Brush Compressor Station
Is this a Portable Unit? No
If portable, include the initial location and home base location
NW '/4 of the SE '4 of Section 32, Township 6 South, Range 95 West
Garfield County, Colorado
6. Reason for Application: (Check all that apply)
❑
New or Previously Unreported Source
Modification of Existing Source
Request for Synthetic Minor Permit
Other:
7. Projected Startu •,Date: M
Administrative Permit Amendments
❑ Transfer of Ownership (Complete Section 9 & 10 below)
❑ Company Name Change (Complete Section 9 below)
❑ Other.
2007 •.nstruction); June 2007 startup
of Legally A+ +i o i7 R Person of Company listed in Section 1
Gerard G. Alberts - Principal Environmental Specialist
Type or Print Name and Official Title of Person Signing Above
8. Check appropriate box if you want:
❑ Copy of preliminary analysis conducted by Division
O To review a draft of the permit prior to issuance
1,v-3lra
Date Signed
Phone: (303) 6064386
Fax: (303) 629-8275
These secdons are to be completed only /f a company name change or transfer of ownership has occurred
9. Permit previously issued to:
10. Transfer of Ownership Information
Effective Date of Permit Transfer:
As responsible party for the emission source(s) listed above, I certify that the business associated with this source bas been
sold, and agree to transfer the permit to said party.
Signature of Legally Authorized Person of Company listed in Section 9
Type or Print Name and Official Title of Person Signing Above
Date Signed
Phone:
Fax:
Mail completed application, APENs, and filing fee to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
4300 Cherry Creek Drive South, APCD-SS-B 1
Denver, Colorado 80246-1530
htto://www.cdohe.state.co.us/au/stationarvasm
Phone: (303) 692-3150
Revised August 2004
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captured by Vapor Recovery Unit with SA. dowadme of VRU
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Previus APEN is expiring I
Repast for Emissice Reduction Credit t
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Seasonal Fuel Use (X ofAonud Use) 1
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dna mpdpsnest B REACH NOTICE FILED.
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OCTOBER 2006 - RABBIT BRUSH COMPRESSOR STATION
Rabbit Brush Compressor Station
Modeled Source Impacts to Verify
Compliance with NO2 NAAQS
Summary of Maximum Combined NO= Ambient Air Quality
Impacts at the Property Boundary
Emission Max. 1-11r Annual Ave.
Source (Pe/m3 N0,'(urtm3 NO,1
ENG -0I 83.7 6.70
ENG -02 83.7 6.70
ENG -03 83.7 6.70
ENG -04 83.7 6.70
ENG -05 165.0 13.20
TOTAL 499.96 40,00
Bacicground NA 7.50
Tot.+Bkgnd NA 47.50
Standard NA 100.00
10/2712006 Rabbit Brash Emissions
10/26/06
14:58:49
*** SCREENS MODEL RUN ***
*** VERSION DATED 96043 ***
Rabbit Brush Compressor Station Engines 1-4
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) _ .520000
STACK HEIGHT (M) = 8.5300
STK INSIDE DIAM (M) _ .4600
STK EXIT VELOCITY (M/S)= 67.4000
STK GAS EXIT TEMP (K) = 732.0000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) _ .0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 7.3200
MIN HORIZ BLDG DIM (M) = 18.2900
MAX HORIZ BLDG DIM (M) = 67.0600
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED
BUOY. FLUX = 20.969 M**4/S**3; MOM. FLUX = 96.190 M**4/S**2.
*** FULL METEOROLOGY ***
**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
10. .2232E-15 6 1.0 1.0 10000.0 76.54 8.18 8.17 NO
100. 70.25 4 15.0 15.0 4800.0 9.74 8.20 6.74 SS
200. 34.36 4 15.0 15.0 4800.0 12.18 15.56 10.43 SS
300. 19.83 4 15.0 15.0 4800.0 14.81 22.61 13.56 SS
400. 14.56 4 15.0 15.0 4800.0 15.54 29.45 16.66 SS
500. 11.37 4 15.0 15.0 4800.0 15.54 36.15 19.63 SS
600. 9.971 4 10.0 10.0 3200.0 23.43 42.72 21.76 SS
700. 8.690 4 10.0 10.0 3200.0 23.43 49.19 24.57 SS
800. 7.557 4 8.0 8.0 2560.0 29.58 55.57 26.84 SS
900. 6.856 4 8.0 8.0 2560.0 29.58 61.88 29.52 SS
1000. 6.188 4 8.0 8.0 2560.0 29.58 68.13 32.09 SS
MAXIMUM 1 -HR CONCENTRATION AT OR BEYOND 10. M:
65. 83.74 4 15.0 15.0 4800.0 9.10 5.58 5.24 SS
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
*********************************
*** SCREEN DISCRETE DISTANCES ***
*********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC UlOM USTK MIX HT
(M) (UG/M**3) STAB (M/S) (M/S) (M)
46. 83.59 4 20.0 20.0 6400.0
DWASH= MEANS
DWASH=NO MEANS
DWASH=HS MEANS
DWASH=SS MEANS
DWASH=NA MEANS
NO CALC MADE (CONC = 0.0)
NO BUILDING DOWNWASH USED
HUBER-SNYDER DOWNWASH USED
SCHULMAN-SCIRE DOWNWASH USED •
DOWNWASH NOT APPLICABLE, X<3*LB
****************************************
*** REGULATORY (Default) ***
PERFORMING CAVITY CALCULATIONS
WITH ORIGINAL SCREEN CAVITY MODEL
(BRODE, 1988)
****************************************
*** CAVITY CALCULATION
CONC (UG/M**3)
CRIT WS 810M (M/S)
CRIT WS 8 HS (M/S) =
DILUTION WS (M/S) _
CAVITY HT (M)
CAVITY LENGTH (M) =
ALONGWIND DIM (M)
1 ***
.0000
99.99
99.99
99.99
7.77
35.67
18.29
PLUME SIGMA SIGMA
HT (M) Y (M) Z (14) DWASH
8.71 3.99 4.80 SS
*** CAVITY CALCULATION -
CONC (UG/M**3) _
CRIT WS 81014 (M/S) =
CRIT WS 8 HS (M/S) _
DILUTION WS (M/S) =
CAVITY HT (M) _
CAVITY LENGTH (M)
ALONGWIND DIM (M) =
2 ***
.0000
99.99
99.99
99.99
7.32
19.70
67.06
CAVITY CONC NOT CALCULATED FOR CRIT WS > 20.0 M/S. CONC SET = 0.0
****************************************
END OF CAVITY CALCULATIONS
****************************************
**********************kik**************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************
CALCULATION
PROCEDURE
SIMPLE TERRAIN
MAX CONC DIST TO TERRAIN
(UG/M**3) MAX (M) HT (M)
83.74 65. 0.
***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************
10/26/06
15:06:47
*** SCREEN3 MODEL RUN ***
*** VERSION DATED 96043 ***
Rabbit Brush Compressor Station Engine 5
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) _ .330000
STACK HEIGHT (M) = 7.3200
STK INSIDE DIAM (M) = .3000
STK EXIT VELOCITY (M/S)= 27.3900
STK GAS EXIT TEMP (K) = 735.4000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) _ .0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 6.1000
MIN HORIZ BLDG DIM (M) = 9.1400
MAX HORIZ BLDG DIM (M) = 18.2900
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.
BUOY. FLUX = 3.636 M**4/8**3; MOM. FLUX = 6.725 M**4/S**2.
*** FULL METEOROLOGY ***
**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
10. .0000 1 1.0 1.0 320.0 63.73 4.68 3.63 NO
100. 101.4 4 8.0 8.0 2560.0 8.84 8.20 6.82 SS
200. 57.64 4 5.0 5.0 1600.0 12.97 15.56 9.87 SS
300. 43.44 4 5.0 5.0 1600.0 12.97 22.61 13.06 SS
400. 33.59 4 4.0 4.0 1280.0 16.10 29.45 15.86 SS
500. 27.34 4 3.5 3.5 1120.0 18.42 36.15 18.66 SS
600. 23.07 4 3.0 3.0 960.0 21.55 42.72 21.31 SS
700. 19.83 4 2.5 2.5 800.0 25.97 49.19 24.03 SS
800. 17.64 4 2.5 2.5 800.0 25.97 55.57 26.78 SS
900. 15.63 4 2.0 2.0 640.0 32.58 61.88 29.47 SS
1000. 14.35 4 2.0 2.0 640.0 32.58 68.13 32.09 SS
MAXIMUM 1 -HR CONCENTRATION AT OR BEYOND 10. M:
37. 168.5 4 8.0 8.0 2560.0 7.58 3.34 4.05 SS
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
*********************************
*** SCREEN DISCRETE DISTANCES ***
*** TERRAIN HEIGHT OP 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST
(M)
CONC
(UG/M**3)
U1OM USTK MIX HT
STAB (M/S) (M/S) (M)
46. 165.0 4 8.0 8.0 2560.0
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
****************************************
*** REGULATORY (Default) ***
PERFORMING CAVITY CALCULATIONS
WITH ORIGINAL SCREEN CAVITY MODEL
(ERODE, 1988)
****************************************
*** CAVITY CALCULATION -
CONC (UG/M**3)
CRIT WS 010M (M/S)
CRIT WS 0 HS (M/S)
DILUTION WS (M/S)
CAVITY HT (M)
CAVITY LENGTH (M)
ALONGWIND DIM (M)
1 ***
.0000
99.99
99.99
99.99
7.49
16.72
9.14
CAVITY CONC NOT CALCULATED FOR CRIT WS
PLUME SIGMA SIGMA
HT (M) Y (M) Z (M) DWASH
7.69 3.99 4.44 SS
*** CAVITY CALCULATION
CONC (UG/M**3)
CRIT WS 010M (M/S)
CRIT WS 0 HS (M/S)
DILUTION WS (M/S)
CAVITY HT (M)
CAVITY LENGTH (M)
ALONGWIND DIM (M)
_ 2 ***
.0000
99.99
99.99
99.99
6.30
11.64
18.29
> 20.0 M/S. CONC SET = 0.0
****************************************
END OF CAVITY CALCULATIONS
****************************************
***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************
CALCULATION
PROCEDURE
SIMPLE TERRAIN
MAX CONC DIST TO TERRAIN
(UG/M**3) MAX (M) HT (M)
168.5 37. 0.
***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************
--R..b13fi3ta,GS_ ?g. 2Do+01 03
Williams.
January 3, 2007
Mr. Roland Hea
Colorado Department of Public Health and Environment
Air Pollution Control Division, APCD-SSP-B1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Re: Rabbit Brush Compressor Station Revised APENs/Draft Permit
Dear Mr. Hea:
EXPLORATION & PRODUCTION
Tower 3, Suite 1000
1515 Arapahoe Street
Denver, CO 80202
303/572-3900
303/629-8282 fax
Williams is submitting several revised APENs for the proposed engines at the Rabbit
Brush Compressor Station. The original permit application for this facility was delivered
to CDPHE in late October 2006. Based on the need for greater operational flexibility,
Williams requests that the NQ emission factor for the proposed Caterpillar G3612
TALE -130 engines is increased from 0.7 g/hp-hr to 1.0 g/hp-hr. In addition, the proposed
1,053 hp generator engine to provide backup electric power to this facility is now slated
to be a G3516 TA -130 rich -burn engine, equipped with a 3 -way catalyst for controlling
NOa, CO and VOC emissions. The generator engine was incorrectly listed as lean -burn
unit in the original application submittal. This rich -burn generator engine will be subject
to 40 CFR Part 64 Compliance Assurance Monitoring (CAM) and will follow the
proposed CAM planattached with this letter to verify that the controls are operating
properly. Revised facility -wide emission calculations are attached along with the revised
engine APENs. These should replace the original APENs submitted for the proposed
engines at the Rabbit Brush Compressor Station.
Williams has also attached a proposed draft permit summary to help facilitate CDPHE
review and response to this application. If you have any questions related to this
submittal please call me at (303) 606-4246 or Rick Matar at (303) 606-4366.
Sincerely
Williams Production
� RMT Company
_Lliiafti W9
Dirk Wold
Senior Air Quality Specialist
Attachments: Revised APENs/Draft Permits/CAM Plan
Attachment 1
Rabbit Brush Compressor Station Revised APENs
Proposed Draft Permit
CAM Plan
Fuel Gas Hatlog Value - 1040 Etu/sc(
Serial Maximum Horsepower Hat lint Fad Fuel Volumetric Exhaust Exhaust Steck Stack' Exhaust
Number Opemtlag SiteRatIag Input Rate Use Use Flow Velocity Velocity Diameter Height Temp.
HwM'r Hp MMBtulbr RtJHp4r acf/hr MMscf/yr actor f/mia ft/tec fat feet deg. P.'
NA 8760 3550 24.0 6760 23075 202.14 23461 13276 221.3 1.50 28.00 856
NA 8760 3550 24.0 6760 23075 202.14 23461 13276 221.3 1.50 28.00 838
NA 8760 3550 24.0 6760 23075 202.14 23461 13276 221.3 150 28.00 858
NA 8760 3550 24.0 6760 23075 202.14 23461 13276 221.3 1.50 28.00 858
NA 8760 1053 791 7515 7609 66.65 4235 5392 89.9 1.00 24.00 864
NA 8760 NA NA NA NA NA NA NA NA 1.27 20.00 800
1 NA 8760 NA NA NA NA NA NA NA NA 1.27 20.00 800
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NA 8760 NA NA NA NA NA NA NA NA 0.17 15 Ambinmt I
NA 8760 NA NA NA NA NA NA NA NA NA NA NA
1.8 1.1 89 5.9 0.1 1.0 2.1 03
TOTAL AGGREGATE IIAP (tpyk 143
HIGHEST SINGLE HAP (tpyk. 5.9 Formaldehyde
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glbbp-hr 4/hr too/yr F/bbpbr Ib/hr too/yr gibbpar IbNr too/yr OVMMEIu Why' ton/yr IbMMBnr @Por ten/yr
1.00 7.53 343 0.18 137 6.0 0.10 0.77 3.4 0.00999 024 1.0 0.00059 0.01 0.1
1.00 7.83 343 0.18 1.37 6.0 0.10 0.77 3.4 0.00999 0.24 1.0 0.00059 0.01 0.1
1.00 7.83 34.3 0.18 1.37 6.0 0.10 0.77 3.4 0.00999 0.24 1.0 0.00059 0.01 0.1
1.00 7.83 34.3 0.18 1.37 6.0 0.10 0.77 3.4 0.00999 0.24 1.0 0.00059 0.01 0.1
2.0 4.64 20.34 2.0 4.64 20.34 0.25 058 2.5 0.01941 0.15 0.67 0.00059 0.00 0.0
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TOTAL AGGREGATE IIAP (tpyk 143
HIGHEST SINGLE HAP (tpyk. 5.9 Formaldehyde
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0.4 878.7 03 5403 0.0 46.2 1.4 2774.9 0.0 4.2 0.I 116.7 0.0 42.9 0.0 19.3
0.4 878.7 0.3 5403 0.0 46.2 1.4 2774.9 0.0 4.2 OA 116.7 0.0 42.9 0.0 19.3
0.4 878.7 03 540.3 0.0 46.2 1.4 2774.9 0.0 4.2 0.1 116.7 0.0 42.9 0.0 19.3
0.4 878.7 03 540.3 0.0 462 1.4 2774.9 0.0 42 0.1 116.7 0.0 42.9 0.0 19.3
0.0 96.7 0.0 91.2 0.0 54.8 036 710.5 0.0 0.9 0.0 385 0.0 193 0.0 6.8
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NA NA NA NA 0.0 29.8 NA NA 0.0 3.1 0.1 1011 0.0 54.0 0.0 24.9
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TOTAL AGGREGATE IIAP (tpyk 143
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Rabbit Brush Compressor Station - ENC -5
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Gas`Generat°nSgt EngSine P.etfiOMabee
TERP
Engine Speed (rpm)
Compression Ratio .
Aftercooler Inlet Temperature (°F)
Jacket Water Outlet Temperature (°F)
Ignition System
Exhaust Manifold
Combustion System Type
1200
9.0:1
130
210
EIS
WATER COOLED
STANDARD
Engine Ra(IngiDate ati
Engine Power (w/o fan)
Generator Set Power (w/o fan)
x,.:rxa-�raa,u- -rra
iEnglne;,Datatre I° v:r-e a<j. "r 1`j
Specific Fuel Consumption (BSFC) (1)
Air Flow (Wet, @ 77°F, 28.8 in Hg)
Alr Mass Flow (Wel)
Compressor Out Pressure
Compressor Out Temperature
Inlet Manifold Pressure
Inlet Manifold Temperature (10)
Timing (11)
Exhaust Stack Temperature
Exhaust Gas Flow (Wet, @ stack temperature, 29.7 In Hg)
Exhaust Gas Mass Flow (Wet)-
-h,"
'Engine]Emiselons$Data s.
Nitrous Oxides (NOx as NO2) (9)
Carbon Monoxide (CO) (9)
Total Hydrocarbons (THC) (9)
Non -Methane Hydrocarbons (NMHC) (9)
Exhaust Oxygen (9)
Lambda
;Engine Heat48alance,Data j���`
Input Energy LHV (1)
Work Output
Heat Rejection to Jacket (2) (6)
Heat Rejection to Atmosphere (Radiated) (4)
Heat Refection to Lube Oil (5)
Total Heat Rejection to Exhaust (to 77°F) (2)
Heat Rejection to Exhaust (LHV to 350°F) (2)
Heat Rejection to Aftercooler - stage 1 (3) (7) (8)
ztTrk`ki re
(Corr. 15% 02)
(Corr. 15% 02)
(Corr. 15%02)
(Corr. 15% 02)
Fuel
LHV of Fuel (Btu/SCF)
Fuel System
Minimum Fuel Pressure (psig)
Methane Number at Conditions Shown
Rated Altitude (ft).
at 77°F Design Temperature
,�'�SLoatlm e
bhp
kW
Btu/bhp-hr
SCFM
Ib/hr
in. HG (abs)
°F
in. HG (abs)
°F
°BTDC
°F
CFM
Ib/hr
g/bhp-hr
ppm
NAT GAS
920
HPG IMPCO
35
80
5000
491,1613%9Valftila, ?SW
526
370
1053 790
740 555
.i'F`y';11frslFr?•aa�sz.�?f pi
7909 8676
1244 963
5514 4271
59 52.2
240 202
49.5 39.9
133 133
22.5 22.5
840 793
3329 2487
5820 4510
7515 .
1554
6892
61.3
268
58.7
134
22.5
864
4235
7273
nithi +4r�zi,a4i�4'%'�t
19.9 17.5 17.5
1476
1190 798
g/bhp-hr
ppm
g/bhp-hr
ppm
g/bhp-hr
ppm
12 1.3 1.4
139 138 122
1.5 1.5 2.0
301 300 338
0.23
15
0.23
14
0.31
16
2.0 1.6 1.3
1.12 1.11 1.10
26
Btu/min
Btu/min
Btu/min
Blu/min
Btu/min
Btu/min
Btu/min
Btu/min
41.
-ENGLISH- page 1 of 2
Ass a, '1'O ���K+c 4C �1-�la: X0.5 911e
131836 104070
44663 33498
51811 43406
4554 3795
0 0
26862 20819
17156 13089
3941 2549
76107
22332
34134
3037
0
15237
9156
1365
DM5144-00
11/44cicPlJoc- AFR
cresS»ar
Generator Set Engme:Porfonnnagnces
TERPILL
e .'AWA:i42i(5't4_
yEngin Nolee Data _at 100"k loaddtyft;
100 dBA
111 dBA
Noise -Mechanical 4 1 m
Nolse - Exhaust 0 1.5 m
°Fuel'Usaege g
ter'
Derate Factor/ Engine Timing vs Methane Number
twfrn
:See:uea"fir *s�r'S
80 to
<30 30 35 40 45 50 55 60 65 70 75 100
0 0.59/14 0.59/15 0.59/16 0.59/17 0.90/14 0.90/15 0.90/16 1.0/16 1.0/18 1.0/20 1.0/23
AltltudeSl11on1Faclorsh`?14fArLi,,,�r+�„
130
120
ut 110
~ 100
90
Z_ 80
CC 70
60
(°F) 50
1.00
1.00
1.00
; 0.98
0.94
0.91
0.88
0.84
0.81
0.78
0.75
0.72
0.70
1.00
1.00
1.00
1.00
0.96
0.93
0.89
0.86
0.83
0.80
0.77
0.74
0.71
1.00
1.00
1.00
1.00
0.98
0.94
0.91
0.87
0.84
0.81
0.78
0.75
0.72
1.00
1.00
1.00
1.00
1.00
0.96
0.92
0.89
0.86
0.82
0.79
0.76
0.73
1.00
1.00
1.00
1,00
1.00
0.98
0.94
0.91
0.87
0.84
0.81
0.78
0.75
1.00
1.00
1.00
1.00
1.00
0.99
0.96
0.92
0.89
0.85
0.82
0.79
0.76
1.00
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.81
0.77
1.00
1.00
1.00
1.00
1.00
1.00
0.99
0.96
0.92
0.89
0.85
0.82
0.79
1.00
1.00
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.60
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
-'., , -ole; Heatf . r$.t iun Factors
130
120
110
100
J 90
80
¢ 70
60
(°F) 50
ttle
1.38
1.46
1.53
1.61
1.69
1.77
1.77
1.77 '
1.77
1.77
1.77
1.77
1.77
1.29
1.36
1.44
1.52
1.59
1.67
1.67
1.67
1.67
1.67
1.67
1.87
1.67
1.19
1.27
1.34
1.42
1.50
1.57
1.57
1.57
1.57
1.57
1.57
1.57
1.57
1.10
. 1.17
1.25
1.32
1.40
1.48
1.48
1.48
1.48
1.48
1.48
1.48
1.48
1.01
1.08
1.15
1.22
1.30
1.38
1.38
1.38
1.38
1.38
1.36
1.38
1.38
1.00
1.00
1.06
1.13
1.20
1.28
1.28
1.28
1.28
1.28
1.28
1.28
1.28
1.00
1.00
1.00
1.03
1.10
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.00
1.00
1.00
1.00
1.00
1.08
1.08
1.08
, 1.08
1.08
1.08
1.08
1.08
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
: i , '�^`t •h:•'Ix K -.I-.��,:e.^ 3 . ! >j ' t.l S: %P'r. h .:. > ' .Y - .:.. a ' `:::t� ..v. ..:IRJi[9 ' ..v. �.
, k, DM5144:00. Data Is intended: to,be�used,with Gas-Enginelperformence; Book Parameters.; DM5900.00 on,page;8.,„:
DM5144-00 -ENGLISH- page 2 of 2
27
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
PERMIT NO: To be issued
DATE ISSUED:
ISSUED TO:
Colorado Department of Public Health and Environment
. _.. .
DRAFT
PERMIT
INITIAL APPROVAL
Williams Production RMT Company
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Natural Gas pipeline booster compression and gas dehydration facility, known as the Rabbit Brush
Compressor Station, to be located in the NW ''A of the SE ' of Section 32, Township 6 South, Range 95
West, approximately 2 miles northeast of Parachute in Garfield County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
This Is a facility -wide permit covering all equipment and activities at this facility. Details of equipment and
' activities are given in Attachment A.
THIS PERMIT 1S GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR
QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND
CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED
IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS:
1. 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. EPA Method 9 shall measure opacity.
(Reference: Regulation 1, Section II.A.1.& 4.)
2. This source is subject to the odor requirements of Regulation No. 2 (State only enforceable).
3. The permit number and AIRS.ID number shall be marked on the subject equipment for ease of identification.
(Reference: Reg. 3, Part B, III.E.) (State only enforceable)
4. This source shall be limited to maximum consumption, processing and/or operational rates as listed in
Attachment Aand all other activities, operational rates and numbers of equipment as stated in the application.
Monthly records of the actual operational rates and activities shall be maintained by the applicant and made
available to the Division for Inspection upon request. (Reference: Regulation 3, Part B,II.A.4)
During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption
limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly
limitation shall be required.
Compliance With the yearly consumption and operational 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 consumption and operational rates and keep a
compliance record on site or at a local field office with site responsibility, for Division review. . •
5. FacIlity-wide emissions of air pollutants shall not exceed the following limitations (as calculated In the Division's
preliminary analysis): (Reference: Regulation 3, Part B,11.A.4).
Point Sources
Nitrogen Oxides. 163.8 tons par year, and 13.91 tons per month
Volatile Organic Compounds. 50.6 tons per year, and 4.30 tons per month
Carbon Monoxide. 49.6 tons per. year, and 4.22 tons per month
Formaldehyde' 5.9 tons per year, and 1003 lbs per month
Fugitive Emissions
Volatile Organic Compounds. 7.5 tons per year. and 1272.4 pounds per month
Monthly limits are based on a 31 -day month.
Emissions from individual equipment and activities shall not exceed the limits specified in Attachment A.
Records of actual emissions shall be maintained and made available for Division review upon request.
AIRS ID: To Be Issued 1
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
DRAFT
PERMIT
During the first twelve (12) months of operation, compliance with both the monthly and yearly emission
limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly
limitation shall be required.
Compliance with the annual limits shall be determined 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 for Division review.
6. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Reg.3, Part A,II.C)
a. Annually 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 any non-criterla 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. Within 14 calendar days of commencing operation of a permanent replacement engine under the
alternative operating scenario outlined in this permit. 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.
7. Within one hundred and eighty days (180) after commencement of operation, 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.
B. This permit shall expire if the owner or operator of the source for which the 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 initial approval perm0 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 (See General Condition No. 6, Item 1). The Division may grant extensions of the
deadline per Regulation No. 3, Part 8, III.F.4.b. (Reference: Regulation No. 3, Part 8, III.F.4)
Natural Gas Internal Combustion Engines
9. Points 001, 002, 003, 004, and 005: the serial numbers of the subject equipment shall be provided to the
Division prior to Final Approval. (Reference: Regulation No. 3, Part 8,111.E.)
10. The engines listed in Attachment A (AIRS ID: 001, 002, 003, 004 and 005) may be replaced with other engines
in accordance with the temporary engine replacement provision or with other engines of the same make and
model in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS),
Included in this permit as Attachment B.
11. Source compliance tests shall be conducted on compressor engines to measure the emission rate(s) for the
pollutants listed below in order to show compliance with emission limits and to demonstrate the performance of
the emission control devices. 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. The protocol shall Include manufacturer's analysis.of emissions at engine
maximum and minimum loads, at site-specific conditions. Engine operating parameters will be included in the
analysis with emissions reported In parts per dry volume and grams per actual horsepower -hour (g/bhp-hr) or
pounds per million BTU (Ib/MMBtu). No compliance lest shall be conducted without prior approval from the
Division. Any stack test conducted to show compliance with a monthly or annual emission limitation shall have
AIRS ID: To Be Issued 2
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
the results projected up to the monthly or annual averaging time by multiplying the test revjtdg4llowable
number of operating hours for that averaging lime (Ref: Regulation No. 3, Part 8, Secti ppl I II
Nitrogen Oxides, Formaldehyde, Carbon Monoxide and Oxygen using EPA approved methods.
If the engines operating as points 001, 002, 003, 004, and 005 are of the same make and model, a compliance
test shall be required for one of these units, and a thirty -minute test run may be performed for the other identical
units. If the emissions from the shortened test on the second and subsequent units show that emissions are not
more than 10% above the emissions of the unit that had a full test series performed on it, then the Division will
consider the emissions from the second and subsequent units to be identical to the emissions from the first unit.
A full set of three test runs must be completed on any unit whose shortened test shows that emissions are
more than 10% of the unit undergoing the full test series.
12. Points 001, 002, 003 and 004: these engines shall be equipped with oxidizing catalysts capable of reducing
uncontrolled emissions of volatile organic compounds by at least 93%, carbon monoxide by at least 93% and
formaldehyde by at least 75%. Operating parameters of the control equipment shall be identified prior to final
approval of this permit. The Identified operating parameters will replace the control efficiency requirement on
the final permit. (Reference: Regulation No. 3, Part B, IV.E.)
13. Point 005: the generator engine shall be equipped with a 3 -way catalyst capable of reducing uncontrolled
emissions of nitrogen oxides by 90%, carbon monoxide by at least 75%, volatile organic compounds by at least
50% and formaldehyde by at least 50%. Operating parameters of the control equipment shall be identified prior
to final approval of this permit. The identified operating parameters will replace the control efficiency
requirement on the final permit. (Reference: Regulation No. 3, Part B, IV.E.)
14. Point 005: the generator engine represents a potential major source, if left uncontrolled. As such, this unit is
subject to the requirements described in 40 CFR Part 64 Compliance Assurance Monitoring (CAM). This unit
must operate in compliance with a CAM plan submitted to the state for final approval, originally submitted with
the construction permit application. (Reference: Regulation No. 3, Part C, XIV)
By: By:
Blue Parish, P.E.
Permit Engineer
Permit History:
Roland C. Hea, P.E.
Unit Leader
Action
Date
Description
Initial Approval
This Issuance
Installation of four natural gas compressor engines (AIRS ID:
001, 002, 003 and 004), one generator engine (ID: 005), two
TEG dehys (AIRS ID: 006 and 007) and associated
equipment.
AIRS ID: To Be Issued
3
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Notes to Permit Holder:
Colorado Department of Public Health and Environment
. _.. .
DRAFT
PERMIT
1) The production or raw material processing limits and emission limits contained in this permit are based on the
production/processing rates requested in the permit application. These limits may be revised upon request of the
permittee providing there Is no exceedence 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.
2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.
The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits
stated In this permit as soon as possible, but no later than two (2) hours after Ole start of the next working day,
followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or
is being taken to correct the conditions causing said violation and to prevent such excess emission in the future.
3) The following facility -wide emissions of non -criteria reportable air pollutants are estimated based upon equipment
and activity specifications as indicated in this permit. This information is listed to inform the operator of the Division's
analysis of the specific compounds. This information is listed on the Division's emission inventory system.
C.A.S. fi SUBSTANCE EMISSIONS ILB/YR)
50-00-0 Formaldehyde 11,810.3
7143-2 Benzene 3,847.0
75-07-0 Acetaldehyde 3,611.6
107-02-8 Acrolein 2,252.2
108-88-3 Toluene 4,189.6
1330-20-7 Xylenes 1,062.6
110-54-3 n -Hexane 2,037.8
4) The emission levels contained in this permit are based on the following emission factors:
Compressor Engines (AIRS ID: 001, 002, 003 and 004): G3612LE TA -130 Lean Burn Units
Pollutant
Emis. Factor
Emis. Controls
Control Eff.%
Nitrogen Oxides
1.0 glhp-hr
SCO
NIA
Carbon Monoxide
0.18 g/hp-hr
SCO
-93
Volatile Organic Compounds
0.10 g/hp-hr
SCO
-93
Acetaldehyde
AP -42
SCO
50
Acrolein
AP -42
SCO
50
Benzene
AP -42
SCO
50
Formaldehyde
AP -42
SCO
75
Generator Engine (AIRS ID: 005): G3516 TA -130 Rich Bum Unit
Pollutant
Emis. Factor
Em's. Controls
Control Eff.%
Nitrogen Oxides
2.0 g/hp-hr
NSCR
90
Carbon Monoxide
2.0 g/hp-hr
NSCR
78
Volatile Organic Compounds
0.25 g/hp-hr
NSCR
50
Acetaldehyde
AP -42
NSCR
50
Acrolein
AP -42
NSCR
50
Benzene
AP -42
NSCR
50
Formaldehyde
AP -42
NSCR
50
5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid
for a term of five years. The five-year term for this APEN expires on April 15, 2012. A revised APEN shall be
submitted no later than 30 days before the five-year term expires.
AIRS ID: To Be Issued 4
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
DRAFT
PERMIT
6) This facility will be classified as follows upon issuance of this permit:
Major Source
Operating Permit
Synthetic Minor:
Carbon Monoxide, Formaldehyde
Major:
Nitrogen Oxides
MACT 27
Synthetic Minor
Formaldehyde
-ZZ
MACT 1-11-1
Synthetic Minor:
HAPs
AIRS ID: To Be Issued 5
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8)
1. 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, 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.
2. 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(7Xa), C.R.S.
3. 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 final approval 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.
4. This permit and any required attachments must be retained and made available for Inspection upon request at the location
set forth herein. With respect to a portable source which is moved to a new location, a copy of the Relocation Notice
(required by law to be submitted to the APCD whenever e portable source is relocated) should be attached to this permit.
The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section 111.8.
upon a request for transfer of ownership and the submittal of a revised APEN and the required fee.
5. Issuance (Initial approval) of an emission permit does not provide 'final" authority for this activity or operation of this
source. Final approval of the permit must be secured from the APCD in writing in accordance with the provisions o125 -7-
114.5(12)(a) C.R.S. and AOCC Regulation No. 3, Part B, Section IV.H. Final approval 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. If the APCD so determines, it will provide written documentation of such final approval, which does constitute
"final" authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after
commencement of operation.
8. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operationwithin 18 months after
either the date of issuance of this permit or the date on which such construction or activity was scheduledto commence as
set forth in the permit, whichever is later, (2) discontinue construction for a period of 18 months or more; or (3) do not
complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be
granted by the APCD upon a showing of good cause by the permittee prior to the expiration date.
7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement of the
permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12)(a), C.R.S. and AQCC Regulation
No. 3, Part 8, Section IV.H.1., and can result in the revocation of the permit. You must denwnsfrate compliance with the
permit conditions within 180 days after commencement of operation as stated in condition 5.
8. 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.
•
9. 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.
AIRS ID: To Be Issued 6
ATTACHMENT A - RABBIT BRUSH COMPRESSOR STATION
Details of equipment/activities covered under this facility -wide permit
AIRS ID
p
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
001
One (1) Caterpillar, Model: 03612LE TA -I 30, SM: N/A, natural gas fired, 4 -stroke,
low emissions design, reciprocating internal combustion engine, site heat
24,000,000 ETU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air -to -fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG -01.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscfyr and 18.6 MMscGmonth.
based on a typical gas beat value of 1,040 RTU/SCF (HHV)
Emission Limits:
lean -bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable resting.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carbon Monoxide
6.0 tom per year
1019Ibs/month
Volatile Organic Compounds
3.4 tons per year
570.61bs/month
Formaldehyde
1.39 tons per year
235.71bs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(g/bbp-hr)
Ib/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
002
One (1) Caterpillar, Model G3612LE TA -130, S/14: N/A, natura gas fired, 4 -stroke,
low emissions design, reciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output al 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air -to -fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG -02.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscflyr and 18.6 MMscf/month.
based on a typical gas beat value of 1,040 BTU/SCF (HHV)
Emission Limits:
lean -burn,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carbon Monoxide
6.0 tom per year
1019Ibs/month
Volatile Organic Compounds
3.4 tons per year
570.6 Ibshnonth
Formaldehyde
1.39 tons per year
235.7 lb./mouth
Emission Factors:
Pollutant
Controlled Emission Factors
(p/bhp-hr)
Ib/MMbtu
Nitrogen Oxides
1.0
-
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrokin
-
0.00257
AIRS ID
q
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
003
One0) Caterpillar, Model: 03612LE TA-130, S/N: N/A, natural gas fired, 4-stroke,
low emissions design, reciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air-to-fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG-03.
Operational limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yr and 18.6 MMscf/monih.
based on a typical gas heat value of 1,040 BTU/SCF (H11V)
Emission Limits: .
lean-bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Unfit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carlon Monoxide
6.0 tons per year
1019 lbs/mouth
Volatile Organic Compounds
3.4 tons per year
570.6 lbs/month
Formaldehyde
1.39 tons per year
235.7 lbs/month
Emission Factors:
Pollutant
Controlled Emission Futon
(r/bhp-hr)
Ib/MMbtu
Nitrogen Oxides -
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
004
One(1) Caterpillar, Model: G3612LE TA-130, S/N: N/A, nature gas Orad, 4-stroke,
low emissions design, eciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output al 3,550 HP, powering a natural gas compressor,
engine is equipped with an automatic air-to-fuel ratio controller and an Oxidation
control of emissions of C rbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG-04.
Operadonal Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yr and 18.6 MMscf/mmnh.
based on a typical gas heat value of 1,040 BTU/SCP (IIHV)
Emission Limits:
lean-bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 lbs/month
Carbon Monoxide
6.0 tons per year
1019lbstmonth
Volatile Organic Compounds
3.4 tons per year
570.6 lbs/month
Formaldehyde
1.39 tom per year
235.7 lbs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(a/bhp-hr)
Ib/MMbti,
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acroleio-
..i.._0.00257
AIRS ID
H
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
005
One (1) Caterpillar, Model: G3516TA-130, S/N: N/A, natural gas fired, 4-stroke,
reciprocating internal combustion engine, site heat input rated 819,130,000 BTU/hr,
output at 1,053 HP, powering a natural gas compressor. This engine is equipped
automatic air-to-fuel ratio controller and a 3-way catalyst for the control of emissions
Oxides, Carbon Monoxide, Volatile Organic Compounds and Hazardous Air
unit is identified as ENG-O5.
Operational Limits:
Consumption of natural gas as a fuel shall not exrezd 66.6 MMscUyr and 5.7 MMsctlmomh.
based on a typical gas heat value of 1,040 BTU/SCF (HIIV)
Emission Limits:
rich-bum
site rated
with an
of Nitrogen
Pollutants. This
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
40 CFR Part 64
Compliance Assurance
Monitoring
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
20.3 tons per year
3,454 lbs/month
Carbon Monoxide
20.3 tons per year
3,454 Ibs/month
Volatile Organic Compounds
2.5 tons per year
432 lbs/month
Formaldehyde
0.36 tons per year
60.31bs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(g/bhp-hr)
Ib/MMbtu
Nitrogen Oxides
2.0
Carbon Monoxide
2.0
-
Volatile Organic Compounds
0.25
-
Fonnaldehyde
-
0.01025
Acetaldehyde
-
0.00140
Acmkin
-
0.00132
006
One methylene glycol (TEG) natural gas dehydration
90,000,000 SCF per day, lean TEG circulation rate
consists of: gas/glycol contactor, flash tank and gas
captured by a Vapor Recover Unit. This
Operational Limits:
Potential Natural Gas processed in the dehydration system:
Lean TEG circulation rale: 24 gallons/minute
Emission Limits:
system, S/N: N/A, feed gas design rated at
at 24 gallons per minute. This system
driven glycol pump. All emissions will be
is identified as DEH Y-01.
90,000,000 SCF/DAY
Equipped with
condenser and all
emissions captured
by VRU; assumed up
to 5% VRU
downtime.
VOCMAP DRE: >95%
Overall
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
8.4 tons per year
Toluene
1,871 lbs per year
Xylenes
442 lbs per year
Benzene
1,722 lbs per year
AIRS ID
p
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
007
One Methylene glycol (TEG) natural gas dehydration
90,000,000 SCF per day, lean TEG circulation rale
consists of: gas/glycol contactor, Dash tank and gas
captured by a Vapor Recover Unit This
Operational Limits:
Potential Natural Gas processed in the dehydration system:
Lean TEG circulation ram: 24 gallons/minute
Emission Limits:
system, S/N: N/A, feed gas design rated at
at 24 gallons per minute. This system
driven glycol pump. All emissions will be
is identified as DEHY-02.
90,000,000 SCF/DAY
Equipped with
condenser and all
emissions captured
by VRU; assumed up
to 5% VRU
downtime.
V0C/HAP DRE: >95%
Overall .
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
8.4 tons per year
Toluene
1,871 lbs per year
Xylenes
442 lbs per year
Benzene
1,722 lbs per year
008
Three (3) custom, vertical fixed roof tanks, each wi
together. Flash emissions captured in the flash tank
Additional flashing from the flash tank down to atmospheric
The tanks are identified
Operational Limits:
Condensate throughput limit: 14,600 barrels per year
Emission Limits:
h a capacity of 400 barrels and manifolded
are routed to a Vapor Recovery Unit.
pressure are vented to atmosphere.
as TK-01.
Compliance Plan
Pollutant
Annual Lhnit
Volatile Organic Compounds
17.5 tons per year
Benzene
132 lbs/yr
009
One natural gas fired pmcess heater with a maximum
be used to for TEG regeneration, storage tank hea
loads. This heat medium system will
Operational Limits:
The maximum heat input re ing of this heater is: 15.0
Fuel Consumption: 126,346 000 SCF/YR
Fuel consumption based on 1040 Btu/scf heating value
Emission Limits:
heat rating of 15 MMbtu/hr. This unit will
ing, building heat and miscellaneous heat
be identified as HTR-0t.
MMbtu/br.
Compliance Plan.
Subject to NSPS Dc
Pollutant
Annual Limit
Nitrogen Oxides
6.32 tons per year
Carbon Monoxide
5.31 tons per year
Volatile Organic Compounds
0.35 tons per year
PM-10
0.48 tons per year
AIRS ID
N
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
010
Description
Fugitive emissions from equipment leaks. The facility ID
Operational Limits:
The source shall be limited to a maximum equipment configuration
for this unit
as listed below.
hatches, dump
is, FUG -1.
arms and (nrmmment
Table 2-4
Component
Non -Residue Gas
Service
NGL
Service
Valves
376
89
Connectors
925
468
Flanges
228
144
Seals
-
14
Other'
48
-
VOCConlenl (wt%)
10.79%
100%
`Other egaipmem includes compressors, PRVs. relief valves, diaphr gms, drains, vents,
Emisstoo Limits:
Pollutant
Annual Limit
Monthly Limit
Volatile Organic Compounds
7.49 tons per year
1272 lbs/month
Emission Factors (Ib/hr•componen0:
Source: EPA -453/1-95-p11.
Component
Non -Residue Gas
Service
NCL
Service
Valves
0.00992
0.00551
Connectors
0.00044
0.00046
Flanges
0.00086
0.00024
Seals
0.00529
0.02866
Other
0.0194
0.01653
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
ATTACHMENT B
1. Alternative Operating Scenarios
The following Altemative Operating Scenario (AOS) for temporary and permanent engine replacement has been
reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -
Alternative Operating Scenarios, and Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, and
has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be
considered a construction perinitfor any engine replacement performed in accordance with this AOS, and the permittee
shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new
Construction Permit.
1.1 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 for90 operating days or less in any 12 month period.
`Permanent" is defined as in the same service for more than 90 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 counts towards the 90
day total. Note that the compliance demonstrations and any periodic monitoring required by this AOS are In addition to
any compliance demonstrations or periodic monitoring required by the permit.
All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit
(Including monitoring and record keeping).
Results of all tests and the associated calculations pursuant required by this AOS shall be submitted to the Division
within 30 calendar days of the test. Results of all tests shall be kept on site for five (5) years and made available to the
Division upon request.
The permittee shall maintain a log on-site, or at a local field office with site responsibility, to contemporaneously record
the start and stop date of any engine replacement, the manufacturer, 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.
1.1.1 The permittee may temporarily replace the 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 emissions from the temporary
replacement engine comply with the emission limitations for the existing permitted engine as determined in section 1.2.
Measurement of emissions from the temporary replacement engine shall be made as set forth In section 1.2.
1,1.2 The permittee may permanently replace the 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 without modifying this permit,
so long as the emissions from the permanent replacement engine comply with the emission limitations for the existing
permitted engine as determined in section 1.2. Measurement of emissions from the temporary replacement engine shall
be made as set forth in section 1.2.
An Air Pollution 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 and a cover letter explaining that the permittee is exercising an atematve operating scenario
and is installing a permanent replacement engine.
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 permittee 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.
If 40 CFR Part 63, Subpart ZZZZ is newly triggered by a permanent replacement engine, the permittee must apply fora
revision to their operating permit within 90 days of Installation.
AIRS ID: To Be Issued 7
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
1.2 Portable Analyzer Testing
The permittee shall measure nitrogen oxide (N04 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
temporary replacement engine.
•
All portable analyzer testing required by this permit shall be conducted using the Division's Portable
Analyzer Monitoring Protocol as found on the Division's website at:
htto://www.cdphe.state.co.us/ao/down/portanalvzeproto.odf
Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an
annual or short term emission limit, the results of the tests shall be covered to a Ib/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.
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.
1.3 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: To Be Issued 8
Attachment 2
Webster Hifi Compressor Station Revised APENs
Proposed Draft Permit
CAM Plan
Williams Production RMT Company, Rabbit Brush Compressor Station ENG -5 CAM Plan
Submitted January 3, 2007
Compliance Assurance Monitoring
Rabbit Brush Compressor Station
Williams Production RMT Company
Emission Unit
a) Facility: Rabbit Brush Compressor Station
b) Location: NW ''A SE of Sec. 32, T6S, R95W in Garfield County
c) Description: One G3516 TA -130 rich -burn engine w/NSCR and AFR
d) Const. Permit Number: Pending
Background
The proposed Rabbit Brush Compressor Station generator engine (ID: ENG -5) meets the
applicability requirements as described in 40 CFR 64 Compliance Assurance Monitoring
(CAM).
• The unit will be located at a proposed major source;
• The unit is subject to emission limitations or standards for an applicable regulated air
pollutant;
• The emission unit will use an add-on control device to achieve compliance with an
emission limit; and
• The emission unit has a potential to emit without the control device of greater than
100 tons per year of NO,„
The CAM regulation requires the following of an affected source:
• Proposed indicators of performance relevant to compliance;
• Indicator ranges or conditions, or the process by which such indicators will be established;
• Performance criteria that satisfy 40 CFR 64.3(b);
• Indicator ranges and performance criteria.
The regulation requires affected sources to monitor at least one indicator of performance for the
control device. For these sources a minimum of one observation per 24 hours of the chosen
parameter must be performed and recorded.
Rationale of Selection of Performance Indicators
The pressure drop across the catalyst is monitored weekly. AAP exceeding limits in indicator
range may indicate that the catalyst is becoming fouled.
Temperature into the unit is measured because temperature excursions can indicate problems
with engine operation and can retard the chemical reduction taking place in the catalyst bed.
Williams Production RMT Company, Rabbit Brush Compressor Station ENG -5 CAM Plan
Submitted January 3, 2007
Monitoring Approach
The key elements of the monitoring approach for NO,, emissions, including the indicators to be
monitored, indicator ranges and performance criteria are presented in Table 1 below.
TABLE 1. Rabbit Brush Rich -burn Engine CAM
Indicator No.1
Indicator No.2
Indicator No.3
I. Indicator
Pressure drop across the
catalyst
Temperature of exhaust
gas into catalyst
Temperature of exhaust
gas out of catalyst.
Measurement Approach
Differential pressure
transmitter
Thermal device
Thermal device
11. Indicator Range
AP < 2" HZO from
baseline. Excursions
trigger corrective action.
750 °F < T < 1350 °F.
Excursions trigger
corrective action.
INLET °F < T < 1350
°F. Excursions trigger
corrective action.
111. Performance Criteria
A. Data
Representativeness
Standard accuracy to
12% FS.
Standard accuracy to
±2% FS.
•
Standard accuracy to
*2% FS.
B. Verification of
Operational Status
AP reading .within
indicated range.
Temperature reading
within indicated range.
Temperature reading
within indicated range.
C. QA/QC Practice and
And criteria.
Calibration annually
Calibration annually
Calibration annually
D. Monitoring
Frequency
Weekly
Daily
Daily
E. Data Collection
Procedures
Spot AP noted on Site
Log Weekly.
Spot Temperature noted
on Site Log Daily
Spot Temperature noted
on Site Log Daily
F. Averaging Period
None
None
None
\J_Os,vik1Gs_1/4_z0o-401 t53
RAJ
Willie s.
January 3, 2007
Mr. Roland Hea
Colorado Department of Public Health and Environment
Air Pollution Control Division, APCD-SSP-B 1
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Re: Webster Hill Compressor Station Revised APENs/Draft Permit
Dear Mr. Hea:
EXPLORATION & PRODUCr7ON
Tower 3, Suite 1000
1515 Arapahoe Street
Denver; CO 80202
303/572-3900
303/629-8282 Fax
Williams is submitting several revised APENs for the proposed engines at the Webster
Hill Compressor Station. Theoriginal permit application for this facility was delivered to
CDPHE in late October 2006. Based on the need for greater operational flexibility,
Williams requests that the NO, emission factor for the proposed Caterpillar G3612
TALE -130 engines is increased from 0.7 g/hp-hr to 1.0 g/hp-hr. In addition, the proposed
1,053 hp generator engine to provide backup electric power to this facility is now slated
to be a 63516 TA -130 rich -burn engine, equipped with a 3 -way catalyst for controlling
NO,t, CO and VOC emissions. The generator engine was incorrectly listed as lean -burn
unit in the original application submittal. This rich -bum generator engine will be subject
to 40 CFR Part 64 Compliance Assurance Monitoring (CAM) and will follow the
proposed CAM plan attached with this letter to verify that the controls are operating
properly. Revised facility -wide emission calculations are attached along with the revised
engine APENs. These should replace the original APENs submitted for the proposed
engines at the Webster Hill Compressor Station.
Williams has also attached a proposed draft permit summary to help facilitate CDPHE
review and response to this application. If you have any questions related to this
submittal please call me at (303) 606-4246 or Rick Matar at (303) 606-4366.
Sincerely
Williams Production RMT Company
vt a, (.t1
Dirk Wold
Senior Air Quality Specialist
Attachments: Revised APENs/Draft Permits/CAM Plan
Attachment 1
Webster Hill Compressor Station Revised APENs
Proposed Draft Permit
CAM Plan
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;TERPIL'
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-ENGLISH- page 1 of 2
2.0 1.6 1.3
1.12 1.11 1.10
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0.83
0.80
0.77
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0.91
0.87
0.84
0.81
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0.89
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0.76
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0.94
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0.87
0.84
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0.89
0.85
0.82
0.79
0.76
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1.00
1.00
1.00
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0.94
0.90
0.87
0.84
0.81
0.77
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1.00
1.00
1.00
1.00
1.00
0.99
0.96
0.92
0.89
0.85
0.82
0.79
1.00
1.00
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.80
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
?MO e!A HeeiMe ecNdntFac 6
130
• 120
W^ 110
100
J 80
Z 80
70
• 60
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1.38
1.46
1.53
1.61
1.69
1.77
1.77
1.77
1.77
1.77
1.77
1.77
1.77
1.29
1.36
1.44
1.52
1.59
1.87
1.67
1.67
1.67
1.67
1.67
1.67
1.67
1.19
1.27
1.34
1.42
1.50
1.57
1.57
1.57
1.57
1.57
1.57
1.57
1.57
1.10
1.17
1.25
1.32
1.40
1.48
1.48
1.48
1.48
1.48
1.48
1.48
1.48
1.01
1.08
1.15
1.22
1.30
1.38
1.38
1.38
1.38
1.38
1.38
1.38
1.38
1.00
1:00
1.06
1.13
1.20
1.28
1.28
1.28
1.28
1.28
1.28
1.28
1.28
1.00
1.00
1.00
1.03
1.10
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.00
1.00
1.00
1.00
1.00
1.08
1.08
1.08
1.08
1.08
1.08
1.08
1.08
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
,-a DM5144--00 Data' Is; Intended, 10 be'used witfi;Gas;Engine:Performance,B.00k Parameter`s'°`�,DM590D-00,on.page;8 , ;,
DM5144-00 -ENGLISH- page 2 of 2
27
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
PERMIT NO: To be issued
DATE ISSUED:
ISSUED TO:
INITIAL APPROVAL
Williams Production RMT Company
THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS:
Natural Gas pipeline booster compression and gas dehydration facility, known as the Webster Hill
Compressor Station, to be located in the NW % of the SW '% of Section 14, Township 6 South, Range 94
West, approximately 3 miles west of Rifle in Garfield County, Colorado.
THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING:
This is a facility -wide permit covering all equipment and activities at this facility. Details of equipment and
activities are given in 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
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:
1. 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. EPA Method 9 shall measure opacity.
(Reference: Regulation 1, Section II.A.1.& 4.)
2. This source is subject to the odor requirements of Regulation No. 2 (State only enforceable).
3. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification.
(Reference: Reg. 3, Part B, III.E.) (State only enforceable)
4. This source shall be limited to maximum consumption, processing.andfor operational rates as listed in
Attachment A and all other activities, operational rates and numbers of equipment as stated in the application.
Monthly records of the actual operational rates and activities shall be maintained by the applicant and made
available to the Division for inspection upon request. (Reference: Regulation 3, Part B,II.A.4)
During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption
limitations shall be required. After the first twelve (12) months of operation, compliance with only the yearly
limitation shall be required.
Compliance with the yearly consumption and operational 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 consumption and operational rates and keep a
compliance record on site or at a local field office with site responsibility, for Division review. •
5. Facility -wide emissions of air pollutants shall not exceed the following limitations (as calculated In the Division's
preliminary analysis): (Reference: Regulation 3, Part B, II.A.4).
Point Sources
Nitrogen Oxides. 163.8 tons per year, and 13.91 tons per month
Volatile Organic Compounds- 50.6 tons per year, and 4.30 tons per month
Carbon Monoxide: 49.6 tons per year, and 4.22 tons per month
Formaldehyde. 5.9 tons per year, and 1003 lbs per month
Fugitive Emissions
Volatile Organic Compounds. 7.5 tons per year, and 1272.4 pounds per month
Monthly limits are based on a 31 -day month.
Emissions from individual equipment and activities shall not exceed the limits specified in Attachment A.
Records of actual emissions shall be maintained and made available for Division review upon request.
AIRS ID: To Be Issued 1
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
. _.. .
DRAFT
PERMIT
During the first twelve (12) months of operation, compliance with both the monthly and yearly emission
limitations shall be required. After the first twelve (12) months, of operation, compliance with only the yearly
limitation shall be required.
Compliance with the annual limits shall be determined 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 for Division review.
6. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Reg.3, Part A,II.C)
a. Annually 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 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. Within 14 calendar days of commencing operation of a permanent replacement engine under the
alternative operating scenario outlined in this permit. 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.
7. Within one hundred and eighty days (180) after commencement of operation, 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.
8. This permit shall expire if the owner or operator of the source for which the 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 initial approval 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; (til) does not complete construction within a reasonable time of the
estimated completion date (See General Condition No. 6, Item, 1). The Division may grant extensions of the
deadline per Regulation No. 3, Part B, 1II.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4)
Natural Gas Internal Combustion Engines
9. Points 001, 002, 003, 004, and 005: the serial numbers of the subject equipment shall be provided to the
Division prior to Final Approval. (Reference: Regulation No. 3, Part B, III.E.)
10. The engines listed in Attachment A (AIRS ID: 001, 002, 003, 004 and 005) may be replaced with other engines
in accordance with the temporary engine replacement provision or with other engines of the same make and
model in accordance with the permanent replacement provision of the Altemate Operating Scenario (AOS),
included in this permit as Attachment B.
11. Source compliance tests shall be conducted on compressor engines to measure the emission rate(s) for the
pollutants listed below in order to show compliance with emission limits and to demonstrate the performance of
the emission control devices. 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. The protocol shall include manufacturer's analysis of emissions at engine
maximum and minimum loads, at site-speclfic conditions. Engine operating parameters will be included in the
analysis with emissions reported in parts per dry volume and grams per actual horsepower -hour (g/bhp-hr) or
pounds per million BTU (Ib/MMBtu). No compliance test shall be conducted without prior approval from the
Division. Any stack test conducted to show compliance with a monthly or annual emission limitation shall have
AIRS ID: To Be Issued 2
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
the results projected up to the monthly or annual averaging time by multiplying the test r a;yaq�owable
number of operating hours for that averaging time (Ref: Regulation No. 3, Part B, Secti 1Itt44ggf�)1I
Nitrogen Oxides, Formaldehyde, Carbon Monoxide and Oxygen using EPA approved methods.
If the engines operating as points 001, 002, 003, 004, and 005 are of the same make and model, a compliance
test shall be required for one of these units, and a thirty -minute test run may be performed for the other identical
units. If the emissions from the shortened test on the second and subsequent units show that emissions are not
more than 10% above the emissions of the unit that had a full test series performed on it, then the Division will
consider the emissions from the second and subsequent units to be identical to the emissions from the first unit.
A full set of three test runs must be completed on any unit whose shortened test shows that emissions are
more than 10% of the unit undergoing the full test series.
12. Points 001, 002, 003 and 004: these engines shall be equipped with oxidizing catalysts capable of reducing
uncontrolled emissions of volatile organic compounds by at least 93%, carbon monoxide by at least 93% and
formaldehyde by at least 75%. Operating parameters of the control equipment shall be identified prior to final
approval of this permit. The identified operating parameters will replace the control efficiency requirement on
the final permit. (Reference: Regulation No. 3, Part B, IV.E.)
13. Point 005: the generator engine shall be equipped with a 3 -way catalyst capable of reducing uncontrolled
emissions of nitrogen oxides by 90%, carbon monoxide by at feast 75%, volatile organic compounds by at least
50% and formaldehyde by at least 50%. Operating parameters of the control equipment shall be identified prior
to final approval of this permit, The Identified operating parameters will replace the control efficiency
requirement on the final permit. (Reference: Regulation No. 3, Part B, IV.E.)
14. Point 005: the generator engine represents a potential major source, if left uncontrolled. As such, this unit is
subject to the requirements described in 40 CFR Part 64 Compliance Assurance Monitoring (CAM). This unit
must operate in compliance with a CAM plan submitted to the state for final approval, originally submitted with
the construction permit application. (Reference: Regulation No. 3, Part C, XIV)
By: By:
Blue Parish, P:E.
Permit Engineer
Roland C. Hea, P.E.
Unit Leader
rc,nu, , nm..,r.
Action
Date
Description
•
Initial Approval
This Issuance
Installation of four natural gas compressor engines (AIRS ID:
001, 002, 003 and 004), one generator engine (ID: 005), two
TEG dehys (AIRS ID: 006 and 007) and associated
equipment.
AIRS ID: To Be Issued
3
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Notes to Permit Holder:
Colorado Department of Public Health and Environment
DRAFT
PERMIT
1) The production or raw material processing limits and emission limits contained in this permit are based on the
production/processing rates requested In the permit application. These limits may be revised upon request of the
permittee providing there is no exceedence 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.
2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.
The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits
stated in this permit as soon as possible, but no later than two (2) hours after the start of the next working day,
followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or
is being taken to correct the conditions causing said violation and to prevent such excess emission in the future.
3) The following facility -wide emissions of non -criteria reportable air pollutants are estimated based upon equipment
and activity specifications as indicated in this permit. This information is listed to Inform the operator of the Division's
analysis of the specific compounds. This information is listed on the Division's emission inventory system.
C.A.S. # SUBSTANCE EMISSIONS ILB/YRI
50-00-0 Formaldehyde 11,810.3
71-43-2 Benzene 3,847.0
75-07-0 Acetaldehyde 3,611.6
107-02-8 Acrolein 2,252.2
108-88-3 Toluene 4,189.6
1330-20-7 Xylenes 1,062.6
110-54-3 n -Hexane 2,037.8
4) The emission levels contained in this permit are based on the following emission factors:
Compressor Enalnes (AIRS ID: 001, 002, 003 and 004): G3612LE TA -130 Lean Burn Units
Pollutant
Emis. Factor
Emis. Controls
Control Eff.%
Nitrogen Oxides
1.0 g/hp-hr
SCO
N/A
Carbon Monoxide
0.18 g/hp-hr
SCO
—93
Volatile Organic Compounds.
0.10 g/hp-hr
SCO
—93
Acetaldehyde
AP -42
SCO
50
Acrolein
AP -42.
SCO
50
Benzene
AP -42
SCO
50
Formaldehyde.
AP -42
SCO
75
Generator Engine (AIRS ID: 005): G3516 TA -130 Rich Burn Unit
Pollutant
Emis. Factor
Emis. Controls
Control Eff.%
Nitrogen Oxides
2.0 g/hp-hr
NSCR
90
Carbon Monoxide
2.0 g/hp-hr
NSCR
78
Volatile Organic Compounds
0.25 glhp-hr
NSCR
50
Acetaldehyde
AP -42
NSCR
50
Acrolein
AP -42
NSCR
50
Benzene
AP -42
NSCR
50
Formaldehyde
AP -42
NSCR
50
5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid
for a term of five years. The five-year term for this APEN expires on April 15, 2012. A revised APEN shall be
submitted no later than 30 days before the five-year term expires.
AIRS ID: To Be Issued 4
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
Air Po' _ ._.
DRAFT
Major Source
6) This facility will be classified as follows upon issuance of this permit:
Operating Permit
Synthetic Minor:
Carbon Monoxide, Formaldehyde
Major:
Nitrogen Oxides
MACT ZZZZ
Synthetic Minor:
Formaldehyde
MACT HH
Synthetic Minor:
HAPs
AIRS ID: To Be Issued 5
Williams Production RMT Company
Permit No: To Be Issued
INITIAL APPROVAL
Colorado Department of Public Health and Environment
DRAFT
PERMIT
GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,8,7 AND 8)
1. 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, 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.
2. Unless specifically stated otherwise, the general and specific conditions contained in this permit have beendetermined by
the APCD to be necessary to assure compliance with the provisions of Section 25.7-114.5(7)(a), C.R.S.
3. 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 abinitio. This permit may be revoked at any time prior to final approval 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.
4. This permit and any required attachments must be retained and made available for inspection upon request at the location
set forth herein. With respect to a portable source which is moved to a new location, a copy of the Relocation Notice
(required by law to be submitted to the APCD whenever a portable source Is relocated) should be attached to this permit.
The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section III.B.
upon a request for transfer of ownership and the submittal of a revised APEN and the required fee.
5. Issuance (initial approval) of an emission permit does not provide "final" authority for this activity or operation of this
source. Final approval 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 IV.H. Final approval 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. If the APCD so determines, it will provide written documentation of such final approval, which does constitute
"final" authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after
commencement of operation.
6. THIS PERMIT AUTOMATICALLY EXPIRES IF you (1) do not commence construction or operation within 18 months after
either the date of issuance of this permit or the date on which such construction or activitywas scheduled to commence as
set forth in the permit, whichever is later; (2) discontinue construction for a period of 18 months or more; or (3) do not
complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be
granted by the APCD upon a showing of good cause by the permittee prior to the expiration date.
7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) pdorto commencement of the
permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12)(a), C.R.S. and AQCC Regulation
No. 3, Part 8, Section IV.H.1., and can result in the revocation o1 the permiL You must demonstrate compliance with the
permit conditions within 180 days after commencement of operation as stated in condition 5.
8. 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.
9. Violation of the terms of a pen -nit 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.
AIRS ID: To Be Issued 6
ATTACHMENT A - WEBSTER HILL COMPRESSOR STATION
ctivities covered under this facility -wide permit
AIRS ID
N
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
001
One (1) Caterpillar, Model: G3612LE TA -130, SIN: N/A, natural gas fired, 4 -stroke,
low emissions design, reciprocating internal combustion engine, site heat input
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air -to -fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG -01.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscUyr and 18.6 MMscimonth.
based on a typical gas heal value of 1,040 BTU/SCF (HHV)
Emission Limits:
lean -bum,
rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides -
34.3 tons per year
5,822 Ibs/month
Carbon Monoxide
6.0 tons per year
1019 Ibs/month
Volatile Organic Compounds
3.4 Ions per year
570.6 lbs/month
Formaldehyde
1.39 tons per year
235.7 Ibs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(a/bhp-hr)
Ib/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Fomialdchyde
-
0.0132
Acetaldehyde
-
0.00418
Aerolein
-
0.00257
002
One (I) Caterpillar, Model: G3612LE TA -130, SIN: N/A, natura gas fired, 4 -stroke,
low emissions design, eciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a atural gas compressor.
engine is equipped with an utomatic air -to -fuel ratio controller a d an Oxidation
control of emissions ofC rbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENC -02.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yr and 18.6 MMscfmonth.
based on a typical gas heat value of 1,040 BTU/SCP (HHV)
Emission Limits:
lean -bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollmaat
Anneal Limit
Monthly Limll
Nitrogen Oxides
M.3 tons per year
5,822 Ibshnoath
Carbon Monoxide
6.0 tons per year
1019Ibs/month
Volatile Organic Compounds
3.4 tons per year
570.6 Rs/month
Formaldehyde
1.39 tons per year
235.7 lbs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(Wbhp-hr)
Ib/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldebyde
•
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
AIRS ID
p
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
003
One (1) Caterpillar, Model: G36I2LE TA-130, S/N: N/A, natural gas fired, 4-stroke,
low emissions design, reciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air-to-fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENC-03.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMschyr and 18.6 MMscf/month.
based on a typical gas heat value of 1,040 BTU/SCF (HHV)
Emission Limits:
lean-bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limlr
Nitrogen Oxides
34.3 tons per year
5,822 Ibs/month
Carbon Monoxide
6.0 tons per year
1019 Ibs/month
Volatile Organic Compounds
3A tons per year
570.6 Ibs/month
Formaldehyde
1.39 tons per year
235.7 Ibs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(g/bhp-hr)
Ib/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
-
Volatile Organic Compounds
0.10
-
Formaldchyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
004
Onc(1) Caterpillar, Model: G3612LE TA-130, S/N: N/A, natural gas fired, 4-stroke,
low emissions design, reciprocating internal combustion engine, site heat
24,000,000 BTU/hr, site rated output at 3,550 HP, powering a natural gas compressor.
engine is equipped with an automatic air-to-fuel ratio controller and an Oxidation
control of emissions of Carbon Monoxide, Volatile Organic Compounds and
Pollutants. This is identified as ENG-04.
Operational Limits:
Consumption of natural gas as a fuel shall not exceed 202.1 MMscf/yr and 18.6 MMscf/month.
based on a typical gas heat value of 1,040 BTU/SCF (HIIV)
Emission Limits:
lean-bum,
input rated at
This
Catalyst for the
Hazardous Air
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
34.3 tons per year
5,822 Ibs/month
Carbon Monoxide
6.0 tons per year
1019lbs/month
Volatile Organic Compounds
3.4 tons per year
570.6 Ibs/month
Formaldehyde
1.39 tons per year
235.7 Ibs/month
Emission Factors:
Pollutant
Controlled Emission Factors
(Pfbbp-hr)
lb/MMbtu
Nitrogen Oxides
1.0
Carbon Monoxide
0.18
•
Votatik Organic Compounds
0.10
-
Fonnaldehyde
-
0.0132
Acetaldehyde
-
0.00418
Acrolein
-
0.00257
AIRS ID
N
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
005
One (1) Caterpillar, Model: G3516TA-130, S/N: N/A, natural gas fired, 4 -stroke,
reciprocating internal combustion engine, site heat input rated at 9,130,000 BTU/hr,
output at 1,053 HP, powering a natural gas compressor. This engine is equipped
automatic air -to -fuel ratio controller and a 3 -way catalyst for the control of emissions
Oxides, Carbon Monoxide, Volatile Organic Compounds and Hazardous Air
unit is identified as ENG -05.
Operational Limits:
Consumption ofgas as a fuel shall not exceed 66.6 MMsco and 51 MMscf/month.
P y<
based on a typical gas heat value of 1,040 BTU/SCF (HHV)
Emission Limits:
rich -bum
site rated
with an
of Nitrogen
Pollutants. This
This is
Compliance plan.
Initial compliance
test and subsequent
portable testing.
40 CFR Part 04
Compliance Assurance
Monitoring
Pollutant
Annual Limit
Monthly Limit
Nitrogen Oxides
20.3 tons per year
3,454 !ha/month
Carbon Monoxide
20.3 tons per year
3,454lbs/month
Volatile Organic Compounds
2.5 tons per year
432 Ills/month
Formaldehyde
0.36 tons per year
60.3 Is/month
Emission Factors:
Pollutant
Controlled Emission
Factors
(P(bhp-hr)
Ib/MMbm
Nitrogen Oxides
2.0
-
Carbon Monoxide
2.0
Volatile Organic Compounds
0.25
-
Fonnaldehyde
-
0.01025
Acetaldehyde
-
0.00140
Acrolein
-
0.00132
006
One Methylene glycol (TEG) nalural gas dehydration
90,000,000 SCF per day, lean TEC circulation rate
consists of: gas/glycol contactor, flash tank and gas
captured by a Vapor Recover Unit. This
Operational Limits:
Potential Natural Gas processed in the dehydration system:
Lean TEG circulation rate: 24 gallons/minute
Emission Limits
system, S/N:
at 24 gall
driven glycol
is identified
90,000,000
N/A, feed gas design rated at
ns per minute. This system
pump. All emissions will be
as DENY -01.
SCF/DAY
Equipped with
condenser and all
emissions captured
by VRU; assumed up
to5%VRU
downtime.
VOCIHAP DRE: >95%
Overall
Compliance Plan
Pollutant
Metal Limit
Volatile Organic Compounds
8.4 tons per year
Toiueae
1,871 lbs per year
Xylenes
442 lbs per year
Benzene
1,722 lbs per year
AIRS ID
#
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
007
One Methylene glycol (TEG) natural gas dehydration system, S/N: N/A, feed gas design rated at
90,000,000 SCF per day, lean TEC circulation rate at 24 gallons per minute. This system
consists of: gas/glycol contactor, flash tank and gas driven glycol pump. All emissions will be
captured by a Vapor Recover Unit. This is identified as DEHV-02.
Operational Limits:
Potential Natural Gas processed in the dehydration system: 90,000,000 SCF/DAY
Lean TEG circulation rate: 24 gallons/minute
Emission Limits:
Equipped with
condenser and all
emissions captured
by VRU; assumed up
to 5% VRU
downtime.
VOCMAP DRE: >95%
Overall
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
8.4 tons per year
Toluene
1,871 lbs per year
Xylenes
442 Ms per year
Benzene
1,722 lbs per year
008
Three (3) custom, vertical fixed roof tanks, each wi
together. Flash emissions captured in the flash tank
Additional flashing from the flash tank down to atmospheric
The tanks are identified
Operational Limits:
Condensate throughput limit: 14,600 barrels per year
Emission Limits:
h a capacity of 400 barrels and manifolded
are routed to a Vapor Recovery Unit.
pressure are vented to atmosphere.
as TK-01.
Compliance Plan
Pollutant
Annual Limit
Volatile Organic Compounds
17.5 tons per year
Benzene
132 lbs/yr
009
One natural gas fired process healer with a maximum
be used to for TEG regeneration, storage tank heating,
loads. This heat medium system will
Operational Limits:
The maximum heat input ra ing of this heater is: 15.0
Fuel Consumption: 126,346 000 SCF/YR
Fuel consumption based on 1040 Btu/sef heating value
Emission Limits:
heat rating of 15 MMbluiltr. This unit will
building heat and miscellaneous heat
be identified as HTR-01.
MMhtu/hr.
Compliance Plan.
Subject to NSPS De
Pollutant
Annual Limit
Nitrogen Oxides
6.32 tons per year
Carbon Monoxide
5.31 tons per year
Volatile Organic Compounds
0.35 tons per year
PM-10
0.48 tons per year
AIRS ID
#
Description
Make, Model, Serial Number, Design Rate, Capacity, Controls, Emission Factors
Specific Provisions
010
Description
Fugitive emissions from equipment leaks. The facility ID
Operational Limits:
The source shall be limited to a maximum equipment configuration
for this unit is,
as listed below.
n, hatcher, dump
FUG -I.
amu and inslr4meat
Table 2-4
Component
Non -Residue Gas
Service
NGL
Service
Valves
376
89
Connectors
925
468
Flanges
228
144
Seals
-
14
Other*
48
-
VOCContent (we%)
10.79%
/00%
• Otherequfpmant includes conpres ors, PRY; relief Paha, diaphragm, drain:, ve
Emission Limits:
Pollutant
Annual Limit
Monthly Limit
Volatile Organic Compounds
7.49 tons per year
12721bs/month
Emission Factors (lblhr-com-ronent):
Source : EPA -4531R-95.0/7,
Component
Non -Residue Gas
Service
NGL
Service
Valves
0.00992
0.00551
Connectors
0.00044
0.00046
Flanges
0.00086
0.00024
Seals
0.00529
0.02866
Other
0.0194
0.01653
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
ATTACHMENT B
1. Alternative Operating Scenarios
The following Alternative Operating Scenario (AOS) for temporary and permanent engine replacement has been
reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -
Alternative Operating Scenarios, and Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, and
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 permittee
shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new
Construction Permit.
1.1 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 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 counts towards the 90
day total. Note that the compliance demonstrations and any periodic monitoring required by this AOS are in addition to
any compliance demonstrations or periodic monitoring required by the permit.
All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit
(including monitoring and record keeping).
Results of all tests and the associated calculations pursuant required by this AOS shall be submitted to the Division
within 30 calendar days of the test. Results of all tests shall be kept on site for five (5) years and made available to the
Division upon request.
The permittee shall maintain a log on-site, or at a local field office with site responsibility, to contemporaneously record
the start and stop date of any engine replacement, the manufacturer, 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.
1.1.1 The permittee May temporarily replace the 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 emissions from the temporary
replacement engine comply with the emission limitations for the existing permitted engine as determined in section 1.2.
Measurement of emissions from the temporary replacement engine shall be made as set forth in section 1.2.
1.1.2 The permittee may permanently replace the 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 without modifying this permit,
so long as the emissions from the pemranent replacement engine comply with the emission limitations for the existing
permitted engine as determined in section 1.2. Measurement of emissions from the temporary replacement engine shall
be made as set forth in section 1.2.
An Air Pollution 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 and a cover letter explaining that the permittee is exercising an altemative operating scenario
and is installing a permanent replacement engine.
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 permittee shall agree to pay fees based on the normal permit processing rate for review of infonnationsubmitted to
the Division in regard to any permanent engine replacement.
If 40 CFR Part 63, Subpart ZZZZ is newly triggered by a permanent replacement engine, the permittee must apply for a
revision to their operating permit within 90 days of installation.
AIRS ID: To Be Issued 7
Williams Production RMT Company Colorado Department of Public Health and Environment
Permit No: To Be Issued
INITIAL APPROVAL DRAFT
PERMIT
1.2 Portable Analyzer Testing
The permittee shall measure nitrogen oxide (NO„) 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
temporary replacement engine.
All portable analyzer testing required by this permit shall be conducted using the Division's Portable
Analyzer Monitoring Protocol as found on the Division's website at:
http://www.cdr he.state.cp.us/ao/down/oortanalvzeproto.pdf
Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an
annual or short term emission limit, the results of the tests shall be covered to a Ib/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.
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.
1.3 Additional Sources
The replacement of an existing engine with a new engine is viewed byte 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: To Be Issued 8
Williams Production RMT Company, Webster Hill Compressor Station ENG -S CAM Plan
Submitted January 3, 2007
Compliance Assurance Monitoring
Webster Hill Compressor Station
Williams Production RMT Company
Emission Unit
a) Facility: Webster Hill Compressor Station
b) Location: NW `'/ SW % of Sec. 14, T6S, R94W in Garfield County
c) Description: One G3516 TA -130 rich -burn engine w/NSCR and AFR
d) Const. Permit Number: Pending
Background
The proposed Webster Hill Compressor Station generator engine (ID: ENG -5) meets the
applicability requirements as described in 40 CFR 64 Compliance Assurance Monitoring
(CAM).
• The unit will be located at a proposed major source;
• The unit is subject to emission limitations or standards for an applicable regulated air
pollutant;
• The emission unit will use an add-on control device to achieve compliance with an
emission limit; and
• The emission unit has a potential to emit without the control device of greater than
100 tons per year of NO,E.
The CAM regulation requires the following of an affected source:
• Proposed indicators of performance relevant to compliance;
• Indicator ranges or conditions, or the process by which such indicators will be established;
• Performance criteria that satisfy 40 CFR 64.3(b);
• Indicator ranges and performance criteria.
The regulation requires affected sources to monitor at least one indicator of performance for the
control device. For these sources a minimum of one observation per 24 hours of the chosen
parameter must be performed and recorded.
Rationale of Selection of Performance Indicators
The pressure drop across the catalyst is monitored weekly. ADP exceeding limits in indicator
range may indicate that the catalyst is becoming fouled.
Temperature into the unit is measured because temperature excursions can indicate problems
with engine operation and can retard the chemical reduction taking place in the catalyst bed.
Williams Production RMT Company, Webster Hill Compressor Station ENC -5 CAM Plan
Submitted January 3, 2007
Monitoring Approach
The key elements of the monitoring approach for NO„ emissions, including the indicators to be
monitored, indicator ranges and performance criteria are presented in Table 1 below.
TABLE 1. Webster Hill Rich -burn Engine CAM
Indicator No.1
Indicator No.2
Indicator No.3
I. Indicator
Pressure drop across the
catalyst
Temperature of exhaust
gas into catalyst
Temperature of exhaust
gas out of catalyst.
Measurement Approach
Differential pressure
transmitter
Thermal device
Thermal device
11. indicator Range
AP < 2" H2O from
baseline. Excursions
trigger corrective action.
750 °F < T < 1350 °F.
Excursions trigger
corrective action.
INLET °F < T < 1350
°F. Excursions trigger
corrective action.
111. Performance. Criteria
A. Data
Representativeness
Standard accuracy to
±2% FS.
Standard accuracy to
±2% FS.
Standard accuracy to
±2% FS.
B. Verification of
Operational Status
AP reading within
indicated range.
Temperature reading
within indicated range.
Temperature reading
within indicated range.
C. QA/QC Practice and
And criteria.
Calibration annually
Calibration annually
Calibration annually
D. Monitoring
Frequency
Weekly
Daily
Daily
E. Data Collection
Procedures
Spot AP noted on Site
Log Weekly.
Spot Temperature noted
on Site Log Daily
Spot Temperature noted
on Site Log Daily
F. Averaging Period
None
None
None
October 31, 2006
Colorado Department of Public Health & Environment
Construction Pennit Section, APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Re: Construction Permit Application
Webster Hill Compressor Station
Garfield County, Colorado
Dear Mr. Roland Hea:
we //;/fC3_ op,-- &mazesrfo
Williams.
EXPLORATION & PRODUCTION
Taw 3, Suite 1000
1515 Arapahoe Street
Dams, CO 80202
303/572-3900
303/629-8282 rax
Williams Production RMT Company (Williams) is submitting the attached Facility -Wide
Construction Pennit Application for a new natural gas compression facility called the
Webster Hill Compressor Station. The Webster Hill Compressor Station (Webster Hill)
will be located in the NW '/4 of' the SW '/4 of Section 14, Township 6S, Range 94W in
Garfield County at an elevation of approximately 5,500 ft above mean sea level.
This facility is designed with a capacity to gather and compress up to 180 MMsef/day of
incoming natural gas at a typical field pressure of 200-245 psig. Inlet field natural gas
will be routed through an inlet separator to remove entrained liquids from the inlet gas
stream. The gas will be compressed by several reciprocating, internal combustion
engine -driven compressors to a pressure of approximately 900-950 psig, and routed
through two parallel triethylene glycol (TEG) dehydration units to remove moisture from
the gas stream. The dehydrated natural gas stream will then leave the facility via
pipeline. Williams plans to install four internal combustion engine driven compressors,
one internal combustion engine driven generator, one process heater, two 90 MMscf/day
TEG dehydration units, one vapor recovery unit (VRU), and three 400 -bbl condensate
storage tanks at the facility.
A site location map, facility plot plan, and process flow diagram are provided in
Attachment 1. A completed Permit Application form and completed APENs for
emissions sources are provided in Attachment 2.
Facility -Wide Sources and Emissions
Internal Combustion Engines
There will be five (5) natural gas fired reciprocating internal combustion engines at the
Webster Hill Compressor Station. There will be four Caterpillar 3612LE TA -I30 4 -cycle
lean burn engines each site -rated at 3,550 hp and equipped with selective catalytic
oxidation (SCO) emission control systems that will operate in inlet natural gas
compression service (source ID: ENG -01 through ENG -04). Site -rated horsepower
ratings are based on non -derated manufacturer specifications. The NOx/CO/VOC
Roland Hea - CDPHE
October 31, 2006
Page 2
emission factors for these engines will be 0.7 g/hphr NO„, 0.18 g/hp-br CO, and 0.1 g/hp-
hr VOC based on manufacturer's emission factors and emission testing results obtained
for like -kind engines operating at the Williams Parachute Creek Gas Plant. The annual
potential emissions of NO„, CO, and VOC from each engine will be 24.0 tpy, 6.0 tpy, and
3.4 tpy.
The fifth engine will be a Caterpillar G3516 TALE generator engine site -rated at 1,053
hp (1,200 rpm), also equipped with an SCO emission control system that will provide
backup electrical power to the site. This unit will be permitted at maximum operational
capacity of 8,760 brs/year based on non -derated manufacturer specifications. The
NOx/CO/VOC emission factors for this proposed controlled engine will be 1.5/0.5/0.5
g/hp-hr with maximum annual NO„, CO, and VOC emissions of 15.3 tpy, 5.1 tpy, and 5.1
tpY.
Triethvlene Glycol Dehydration Units
There will be two TEG dehydration units (Source ID: DEHY-1 and DEHY-2), plumbed
in parallel, and each designed to remove water from the natural gas after it has been
compressed to 900-950 psig by the booster compression units. Each TEG dehy is
designed to process up to 90 MMscf/day of field natural gas and both will operate with a
flash tank and a regenerator still vent condenser emission control.
Under normal operating conditions, the flash tank overhead vapor streams and the
regenerator still vent condenser overhead streams from both TEG dehydration units will
be routed to the VRU. The dehydration units therefore are designed to operate as closed-
loop systems with no emissions to atmosphere.
Consistent with Division recommendations, Williams is classifying the VRU as a control
device rather than a permitted process runt, and is listing the VRU as such on the
completed APEN forms for the two dehydration units. HYBON Engineering, the
proposed VRU manufacturer, guarantees a minimum 95% run-time, which corresponds
to a maximum of 18 days of down-time per year for routine repair and maintenance. The
control efficiency of each dehy, as listed on the APENs, was determined based on the
VRU vendor run-time guarantee, a copy of which is provided in Attachment 3.
Controlled emissions listed on the dehydration unit APENs were calculated based on the
assumption that each dehydration unit operates with condenser controls at all times and a
VRU downtime of 5%. When the VRU is not operating, VOC and HAP are emitted from
the flash tank and the regenerator still vent condenser outlet of each dehydration unit.
The estimated annual permitted VOC emissions from each dehydration unit are 3.6 tpy
from each flash tank and 4.8 tpy from each regenerator still vent condenser outlet, for a
total of 8.4 tpy for each dehydration unit.
Roland Hea • CDPHR
October 31, 2006
Page 3
Condensate Storage Tanks
Williams plans to install three 400 -bbl aboveground atmospheric condensate storage
tanks. The three stock tanks (ID: TANK -01) will be manifolded together and will be
designated as one emission point. Condensate at a maximum inlet pressure of
approximately 245 psig will be routed from the inlet gas separator to a pressurized
condensate flash tank process vessel which will operate at approximately 20 psig.
Condensate flash vapors produced as"the condensate pressure is reduced from the inlet
separator pressure to 20 psig are routed to the VRU where they are recompressed and
routed back into the facility inlet gas stream with zero emissions to atmosphere.
Additional flash gas is produced as the 20 psig condensate leaves the flash tank process
vessel and is routed to the stock tanks operating at atmospheric pressure. This flash gas
is emitted through the TANK -01 vents to atmosphere. A process flow diagram of the
VRU is presented is Attachment 1.
Permitted VOC emissions from the TANK -01 emission source are calculated as the
combined total of estimated flash and working/breathing emissions from the tanks during
normal operating conditions with the VRU operating (flash from 20 psig to atmosphere,
8,322 hr/yr), plus estimated flash and working/breathing emissions during VRU down-
time (flash from 245 psig to atmosphere, 438 hr/yr). An average daily condensate
production rate of 40 bbl/day is assumed. Annual VOC emissions from the TANK -01
emission source during normal operating conditions, estimated using the API E&P
TANKS 2.0 computer model and including flash and working/breathing losses, are 15.0
tpy. Annual VOC emissions from the TANK -01 emission source during upset conditions
when the VRU is not operating are estimated at 2.5 tpy. Total requested VOC emissions
from the TANK -01 emission source are 17.5 tpy. The calculated overall control
efficiency for the VRU in controlling all potential VOC emissions from the TANK -01
emission source is 65%.
Consistent with Division recommendations, Williams is classifying the VRU as a control
device rather than a permitted process unit, and is listing the VRU as such on the
completed APEN form for the TANK -01 emission source. Due to the inherent seasonal
variability of condensate production in the Piceance Basin, Williams requests that APCD
lists only an annual condensate throughput limit in the permit.
Vapor Recovery Unit
As described above, Williams will use one VRU as a VOC and HAP emission control
device for both dehydration units and the condensate tank emission unit. The permitted
emissions from the dehydration units and the condensate storage tanks are estimated
based on the vendor guarantee of a 95% control efficiency for the vapor streams being
controlled by the VRU, based on a 100% control efficiency while operational, and
assuming a maximum down-time of' 5% (18 days per year) when the VRU is non-
operational. A process flow diagram of the VRU is provided in Attachment 1.
Roland Ilea - COMM
October 31, 2006
Page 4
Process Heater
Williams will install a heat medium system that will be used to support various process
unit operations including TEG regeneration, building heat, storage tank heating and other
miscellaneous heat loads. This natural gas fired process heater (ID: HTR -01) has a
maximum heat rating of 15.0 MMBtu/hr. Emissions of NO„ CO, and VOC are estimated
at 6.32 tpy, 5.31 tpy and 0.35 tpy, based on AP -42 natural gas combustion emission
factors. An equipment specification sheet for this heater is provided in Attachment 3.
Loadout
Periodically, condensate will be loaded from the condensate storage tanks at Webster Hill
into trucks for transport off site (ID: LOAD -01). The estimated maximum condensate
production rate of 40 bbl per day and molecular weight data from the E&P TANKS 2.0
model were used in conjunction with the USEPA loadout equation to estimate VOC
emissions from this source. Emissions of VOC from this source are estimated to be
below the threshold limit of 2 tpy for APEN reporting. Therefore, the LOAD -01
condensate loadout source is an insignificant emission source that will not be included in
the facility -wide permit. A condensate loadout calculation sheet is provided in
Attachment 3.
Fugitive VOC from Leaking Equipment
Potential fugitive VOC emissions from leaking equipment (ID: FUG -01) are estimated at
7.5 tpy VOC, using estimated equipment component counts, a representative inlet gas
analysis from a compressor station in the same field, and US EPA Oil and Gas
Production Operations emission factors. A fugitive VOC emissions calculation sheet is
provided in Attachment 3.
Total Facility -Wide Potential Emissions
Total facility -wide potential emissions for all sources included in the facility -wide permit
and all sources that are exempt from permitting are 117.6 tpy NOx, 34.5 tpy CO, and 60.7
tpy VOC. Potential emissions of regulated non -criteria reportable pollutants (HAP) from
the facility are estimated at 14.7 tpy aggregate, with formaldehyde being the highest
single HAP emission at 6.0 tpy. An emissions spreadsheet is provided in Attachment 3.
Compliance with National Ambient Air Quality Standards (NAAOS)
Williams used the US EPA SCREEN3 model to demonstrate that the NO„ emissions
from the five internal combustion engines at Webster Hill will not result in a violation of
the annual NAAQS for NO2 of 100 µg/m3. The combined maximum annual ambient air
NO2 concentration is estimated at 40.0 µg/m3 at the nearest property boundary
approximately 150 feet from the primary compressor engine building. Adding an
accepted background NO2 concentration of 7.5 µg/m3, provided by Doris Jung of the
APCD, results in a total combined maximum ambient air concentration of 47.5 µg/m3.
Roland Ilea • CDPHE
October 31, 2006
Page 5
This value is well below the annual NAAQS for NO2 of 100 pg/m3 and the proposed
facility will not cause an off-site violation of the NAAQS. Copies of the NAAQS
calculation sheet and SCREEN3 input and output report are provided in Attachment 4.
We request that the Division invoice Williams for the APEN fees associated with this
application. If you have any questions related to this submittal, or if you require
additional information please call me at the Williams Denver office at (303) 6064386.
Sincerely,
Williams Production RMT ompa
Gerard ii. Alberts
Principal Environmental Specialist
attachments
ATTACIIMENTS
Attachment 1: Area Map, Facility Plot Plan and Process Flow Diagrams
Attachment 2: Permit Application Form and Completed APENs
Attachment 3: Emissions Inventory Spreadsheet and Supporting Calculation Sheets
Attachment 4: SCREEN3 Modeling Summary
Attachment 1
Area Map, Facility Plot Plan, Process Flow and VRU Diagrams
i
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WEBSTER HILL COMPRESSOR STATION
SITE LOCATION MAP
WG564 107°46.000' W
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Let: 39°31.4' North
Long: 107°51.7' West
10/16/06
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Attachment 2
Completed Application for Construction Permit
Completed APENs
Air Pollution Control Division Construction Permit Application
PLEASE READ INSTRUC77ONS ON REVERSE SIDE.
1. Permit to be issued to:
2. Mailing Address:
3. General Nature of Business:
SIC code (if (mown)
4. Air Pollution Source Description:
(List permit numbers if existing source,
attach additional pages if needed)
5. Source Location Address (Include
Webster Hill Compressor Station
Williams Production RMT Company
1515 Arapahoe St, Tower 3, Suite 1000
Denver, Colorado 80202
Exploration and Production of Natural Gas
1311
Natural Gas Gathering and Compression
N/A
Is this a Portable Unit? No
Location Map) If portable, include the initial location and home base location
NW ''A of the SW % of Section 14, Township 6 South, Range 94 West
Garfield County, Colorado
6. Reason
for Application (Check all that apply)
New or Previously Unreported Source
Modification of Existing Source
Request for Synthetic Minor Permit
Other
Administrative Permit Amendments
10 below)
below)
Ci
❑
• Transfer of Ownership (Complete Section 9 &
•
❑ Company Name Change (Complete Section 9
❑ Other:
❑
7. Projected
Startup a ate: March
s 7
1•
(Construction); June 1, 2007
Si tura f Legally A •. .
Gerard G. Alberts - Principal Environmental
Person o
onrpany listed in Section 1 Date Signed
Specialist Phone: (303) 6064386
Type or Print Name and Official Title of Person
8. Check appropriate box if you want:
❑ Copy of preliminary analysis conducted
❑ To review a draft of the permit prior
Signing Above Fax: (303) 629-8275
by Division
to issuance
These sections are to be completed
9. Permit previously issued to:
10. Transfer of Ownership Information
Effective Date of Permit Transfer:
As responsible party for the emission
sold, and agree to transfer the permit
only if a company name change or transfer of ownership has occurred
been
source(s) listed above, I certify that the business associated with this source has
to said party.
Signature of Legally Authorized Person of Company listed in Section 9 Date Signed
Phone:
Type or Print Name and Official Title of Person
Signing Above Fax:
Mail completed application, APENs, and filing fee to:
Colorado Department of Public Health and Environment
Air Pollution Control Division
4300 Cherry Creek Drive South, APCD-SS-BI
Denver, Colorado 80246-1530
bttn://www,cdohe,statc co.us/ap/stationary asp
Phone: (303) 692-3150
Revised August 2004
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FEATURES
Shown with
Optional Equipment
• FULL RANGE OF ATTACHMENTS
• Wide range of bolt -on system expansion
attachments, factory designed and tested
Ix UNMATCHED PRODUCT SUPPORT
OFFERED THROUGH WORLDWIDE
CATERPILLAR DEALER NETWORK
• More than 1,500 dealer outlets
• Caterpillar factory -trained dealer
technicians service every aspect of your
petroleum engine
• 99.7% of parts orders filled within 24
hours — worldwide
• Caterpillar parts and labor warranty
• Preventive maintenance agreements
available for "repair before failure"
options
• Scheduled Oil Sampling (S•O•S'"')
program matches your oil sample
against Caterpillar set standards to
determine:
- internal engine component condition
- presence of unwanted fluids
- presence of combustion by-products
■ SINGLE -SOURCE SUPPLIER
• Caterpillar.
- casts engine blocks, heads,
cylinder liners, and flywheel housings
- machines critical components
- assembles complete engine
Ownership of these manufacturing
processes enables Caterpillar to produce
high quality, dependable product.
• Factory -designed systems built at
Caterpillar ISO certified facilities
Gas G3612
Petroleum 3195-3550 bhp
2383-2647 bkW
Engine 900-1000 rpm
CATERPILLAR• ENGINE SPECIFICATIONS
V-12, 4 -Stroke -Cycle
Bore — in (mm) 11.8 (300)
Stroke — in (mm) 11.8 (300)
Displacement — cu in (L) 15,528 (254.4)
Aspiration Turbocharged and Aftercooled
Capacity for Liquids — U.S. gal (L)
Jacket Water Circuit' 177 (669)
Aftercooler Circuit' 17 (84)
Lube Oil System (refill) 272 (1030)
Package Shipping Weight
(Dry) — Ib (kg) 55,300 (25 084)
Engin• only
■ G3612
• Low emissions
• Broad operating speed range and
ability to burn a wide spectrum of
gaseous fuels
• Caterpillar Advanced Digital Engine
Management (ADEM III) control system
with detonation -sensitive timing control
for individual cylinders
• Robust diesel strength design provides
prolonged life and lower owning and
operating costs.
■ TESTING
• Prototype testing on every model:
- proves computer design
- verifies system torsional stability
- functionality tests every model
• Every Caterpillar engine is dynamometer
tested under full load to ensure proper
engine performance.
■ WEBSITE
• For additional Information on all your
petroleum power requirements, visit
www.cat-oilandgas.com.
CE
LEImOOI4-01
r
CATERPILLAR'
G3612 GAS PETROLEUM ENGINE
FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT
SYSTEM
STANDARD
Air Inlet Air cleaner — standard -duty
Inlet air adapter
Charging System
OPTIONAL
Heavy-duty air cleanereatwith precleaners
Heavy-duty air Bever skfffle10 pr*taction
Charging alf♦ernat,Qsr- ,,,;
Control System Caterpillar ADEM III control system
provides electronic governing integrated
with air/fuel ratio control and individual
cylinder ignition timing control
Cooling System Jacket water pump
Jacket water thermostats and housing
After000ler pump
Aftercooler water thermostats and housing
Single -stage aftercooler•
Custom control system software Is available
for non-standard ratings. Software 1s field
programmable using flesh memory.
Expansion tank
Flexible connections
Jacket water heater
SIZI l ;i< WN' a .. .. _ • .
Exhaust System Dry wrapped exhaust manifolds
Vertical outlet adapter
Flexible bellows adapters
Exhaust expander
....Weldfienges
Flywheel/ SAE No. 00 flywheel
flywheel Housing SAE No. 00 flywheel housing
SAE standard rotation
Fuel System Gas admission valves with electronically
controlled fuel supply pressure
Ignition System
ADEM III control system senses Individual
cylinder detonation and controls
Individual cylinder timing
Fuel filter
Gas pressure regulator
Flexible connection
Low energy fuel system
Corrosive gas fUUeeaystep),-re _
CSA certification
Insmtmentatlon LCD display panel monitors engine
parameters and displays diagnostic codes
Luba System
Crankcase breathers (top mounted)
OII cooler
Oil filter
Oil pan drain valve
Remote data monitoring and speed control
'Conipatlble with Cet Electronic Technician IET)
and Data View
Customer Communication Module (CCM)
egg igneld o/}, o, )51
Mounting System Engine mounting feet (six total)
Power Take -Offs
'Alt or electric motor -driven pretube
Duplex oil filter
LH or RH service
Luba coil makeup .`i*rem .
_Mounting plates 4f,04.;
't.1.:....t..
Front stub shafts
Protection
Electronic shutoff system with purge cycle
Crankcase explosion relief valves
Gas shutoff valve
Starting System Air starting system
Air pressure reducing valve
Natural gas starting system
General Paint, Caterpillar yellow
Vibration dampers
Engine barring device
Damper guard
LEHW0914-01
G3612 GAS PETROLEUM ENGINE
TECHNICAL DATA
CATERPILLAR'
G3612 Gas Petroleum Engine -- 900-1000 rpm
"*.1,44.;44-"A tnAA..,...•- 4
DM5310-00
Engine Power
(� 100% Load
® 75% Load
bhp (bkW)
bhp (bkW)
Engine Speed
rpm
3195 (23831
szh+liift, .+4 7 iPp'1'.k< y..
SCAC Temperature
°F (°C)
3550(2647)
2862(1985)
eatallailza tr •.4
149.1541..,,
1000
130 (54)
Compression Ratio
:Yak, '44e...4“tA'
a
9.0:1
Emissions*
NOK
CO
Total Hydrocarbons N
g/bhp-hr
g/bhp-hr
g/bhp-hr
0.70
-2.50
0.70
2.50
6.15
Fuel Consumption
0 100% Load
75% Load
Hest Balance
Heat Rejection to Jacket Water
0 100% Load
®75% Load
Heat Rejection to Aftercooler
100% Load
0 75% Load
Heat Rejection to Exhaust
® 100% Load
® 76% Load
Exhaust System.
Exhaust Gas Flow Rate
0 100% Load
0 75% Load
Exhaust Stack Temperature
0 100% Load
0 75% Load
Btu/bhp-hr (MJ/bkW-hr) 6.570 (9.30)
Bttbhp-hr (MJ/bkW-hr) 6, 05 (9.63j
asm- ,b.t.*
Btu/mn (bkW)
Btu/mn (bkW)
BtWmn (bkW)
BtWmn (bkW)
Btu/mn (bkW)
Btu/mn (bkW)
32168 (566)
28,721 (605)
21,222 (373)
9,333 (164)
134,721 (2389)
107,091 1883.
6,760 (9.57)
7.050 (9.98)
36,195 (636)
31,271 (550)
28,509 (466)
14,525 (255)
154,873 (2720)
123,769 (2176)
e(m (m'/min)
cfm (m'/min)
°F (°C)
°F 1°CI
20,834 (584)
16,100 (456)
846 (462)
86714134)
..�.,. '.'40, P.i :.;pry..: ..
23,461 (664)
18,654 (625)
858 (459)
878 (470)
Intake System
Air Inlet Flow Rate
0 100% Load
da 75% Load
cfm (nWmin)
cfm (nWmin)
8,527 (241)
9,598 (212)
7.477 (212)
Ges Pressure
°at 100% load and speed
pat (kPa)
43 (295)
43 (296)
LEIIW0814.01
CATERPILLAR'
G3612 GAS PETROLEUM ENGINE
GAS PETROLEUM ENGINE
DIMENSIONS
Length
In (mra) _all9,42,(473§.,+>1)
Width
in (mm)
93.68 (2379.5)
Height
injmmj,
128.77 (3219 ,9).
Shipping Weight
Ib (k(t)
55,300 (25 084)
RATING DEFINITIONS AND CONDITIONS
Engine performance is obtained in accordance
with SAE J1995, IS03046/1, 8S551411, and
DIN6271/1 standards.
Transient response data is acquired from an
engine/generator combination at normal
operating temperature and in accordance with
IS03046/1 standard ambient conditions. Also in
accordance with SAE J1995, 0S5514/1, and
DIN6271/1 standard reference conditions.
Note: General configuration not to be used
for installation. See general dimension
drawings for detail.
Conditions: Power for gas engines is based on
fuel having an LHV of 905 Btu/cu ft (33.74 kJ/L)
at 29.91 in. Hg (101 kPa) and 59° F (15° C). Fuel
rate is based on a cubic meter at 29.61 in. Hg
(100 kPa) and 60.1° F (15.6° C). Air flow is
based on a cubic foot at 29.61 in. Hg (100 kPa)
and 77° F125° C). Exhaust flow is based on a
cubic foot at 29.61 in. Hg (100 kPa) and stack
temperature.
TMI Reference No.: DM5312A0, DM5310-09
Materiels and apedocadons are subject to change etttout nodce. The International Sygem of Units ISO Is used in this publication.
lEHW0914-0119A1) Primed In U.S.A. 02001 Caterpillar
All rights reserved.
116
M
G3516 TA Gas Generator Set Engine Performance
CATERPILLAR
Engine Speed (rpm)
Compression Ratio
Aftercooler Inlet Temperature (W)
Jacket Water Outlet Temperature (°F)
Ignition System
Exhaust Manifold
Combustion System Type
Engine Rating Data
Engine Power (w/o fan)
Generator Set Power (w/o fan)
1200
9.0:1
130
210
EIS
WATER COOLED
STANDARD
Engine Data
Specific Fuel Consumption (BSFC) (1)
Air Flow (Wet, 0 77°F, 28.8 in Hg)
Air Mass Flow (Wet)
Compressor Out Pressure
Compressor Out Temperature
Inlet Mangold Pressure
Inlet Manifold Temperature (10)
liming (11)
Exhaust Stack Temperature
Exhaust Gas Flow (Wet, 0 stack temperature, 29,7 In Hg)
Exhaust Gas Mass Flow (Wet)
Engine Emission* Data
Nitrous Oxides (NOx as NO2) (9)
Carbon Monoxide (CO) (9)
Total Hydrocarbons (THC) (9)
Non -Methane Hydrocarbons (NMHC) (9)
Exhaust Oxygen (9)
Lambda
(Corr. 15% 02)
(Cort. 15% 02)
(Corr. 15%02)
(Corr. 15% 02)
Engine Heat Balance Data
Input Energy LHV (1)
Work Output
Heat Rejection to Jacket (2) (6)
Heat Rejection to Atmosphere (Radiated) (4)
Heat Rejection to Lube O8 (5)
Total Heat Rejection to Exhaust (to 77°F) (2)
Heat Rejection to Exhaust (LHV to 350°F) (2)
Heat Rejection to Aftercooler - stage 1 (3) (7) (8)
26
Fuel
LHV of Fuel (Btu/SCF)
Fuel System
Minimum Fuel Pressure (prig)
Methane Number at Condftkms Shown
Rated Altitude (ft)
at 77°F Design Temperature
% Load
bhp
kW
Btu/bhp-hr
SCFM
lb/hr
in. HG (abs)
°F
in. HG (abs)
°F
°BTDC
°F
CFM
lb/hr
9bhP
Ppm
NAT GAS
920
HPG IMPCO
35
80
5000
100% 75% 50%
1053 790 528
740 555 370
7515 7909 8678
1554 1244 963
8892 5514 4271
81.3 59 52.2
268 240 202
58.7 49.5 39.9
134 133 133
22.5 22.5 223
864 840 793
4235 3329 2487
7273 5820 4510
19.9 17.5 17.5
1476 1190 798
g4mp.hr
PPm
g)bhp-hr
Pflm
—r
Ppm
1.2 1.3 1.4
139 138 122
1.5 1.5 2.0
301 300 338
0.23 0.23 0.31
15 14 16
Btu/min
BtWmin
Btu/min
Btu/min
Btu/min
Btu/min
ShAmin
Btuhnin
2.0
1.6
1.12 1.11
1.3
1.10
131838 104070 78107
44683 33498 22332
51811 43408 34134
4554 3795 3037
0 0 0
26882 20819 15237
17156 13089 9156
3941 2549 1385
-ENGLISH- page 1 0f 2 DM5144-00
03513 TA Gas Generator Set Engine Performance
CATERPILLAR
Engine Noise Data - at 100% Toad
Noise -Mechanical O 1 m
Noise - Exhaust -O 1.5 m
Fuel Usage Guide
100 dBA
111 dBA
Derate Factor/ Engine Timing vs Methane Number
80 to
<30 30 35 40 45 50 55 80 65 70 75 100
0 0.59/14 0.59/15 0.59/16 0.59/17 0.90/14 0.90/15 0.90/18 1.0/18 1.0/18 1.0/20 1.0/23
Altitude Deration Factors
130
iW 120
ja 110
100
90
J
Z 80
CC 70
R ea
ten 50
1.00
1.00
1.00
0.98
0.94
0.91
0.88
0.84
0.91
0.78
0.75
0.72
0.70
1.00
1.00
1.00
1.00
0.96
0.93
0.89
0.86
0.83
0.80
0.77
0.74
0.71
1.00
1.00
1.00
1.00
0.98
0.94
0.91
0.87
0.84
0.61
0.78
0.75
0.72
1.00
1.00
1.00
1.00
1.00
0.96
0.92
0.89
0.98
0.82
0.79
0.78
0.73
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.91
0.87
0.84
0.81
0.78
0.75
1.00
1.00
1.00
1.00
1.00
0.99
0.98
0.92
0.89
0.85
0.82
0.79
0.76
1.00
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.81
0.77
1.00
1.00
1.00
1.00
1.00
1.00
0.99
0.98
0.92
0.89
0.85
0.82
0.79
1.00
1.00
1.00
1.00
1.00
1.00
1.00
0.98
0.94
0.90
0.87
0.84
0.80
0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
Altercooler Heat Refection Factors
2
en
130
120
110
100
90
80
70
60
50
1.38
1.46
1.53
1.61
1.69
1.77
1.77
1.77
1.77
1.77
1.77
1.77
1.77
1.29
1.36
1.44
1.52
1.59
1.57
1.67
1.67
1.87
1.87
1.67
1.67
1.67
1.19
1.27
1.34
1.42
1.50
1.57
1.57
1.57
1,57
1.57
1.57
1.57
1.67
1.10
1.17
1.25
1.32
1.40
1.48
1.48
1.48
1.48
1.48
1.48
1.48
1.48
1.01
1.06
1.15
122
1.30
1.38
1.38
1.38
1.38
1.38
1.38
1.38
1.38
1.00
1.00
1.06
1.13
1.20
128
1.28
128
128
128
1.28
128
1.28
1.00
1.00
1.00
1.03
1.10
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.18
1.00
1.00
1.00
too
too
1.08
1.08
1.08
1.08
1.08
1.08
1.08
1.08
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
1.00
0 1000 2000 3000 4000 5000 8000 7000 8000 9000 10000 11000 12000
ALTITUDE (FEET ABOVE SEA LEVEL)
DM5144-00 Data Is Intended to be used with Gas Engine Performance Book Parameters - DM590000 on page 8
DM5144-00 -ENGLISH- page 2 of 2
27
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Webster Hill Compressor Station
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1
ElOOONoGddoGOGOOOOO
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et oN
Engineering Company, Inc.
(432) 887.2292 (432) 520.2292 Fax (432) 697.2310
P, O. BOX 4185 MIDLAND, TEXAS 79704
2404 COMMERCE MIDLAND, TEXAS 79703
mm.hybon.com
Date: October 11, 2006
Mr. Gerard G. Alberts
Williams Company
Principal Environmental Specialist
1515 Arapahoe St., Tower 3, Suite 1000
Denver, CO 80202
Mr. Alberts,
Per our conversation yesterday, electric drive vapor recovery units have very
minimal down time. As a packager of vapor recovery units for over 50 years, as
well as a company that maintains over 100 similar slze units in a rental fleet that
are often on "run time" contracts, we estimate average run time on Hy -Bon electric
drive vapor recovery units to average 95%. This down time percentage assumes
that the unit is properly installed and properly maintained.
This percentage coincides with the "over 95%" quoted in an article we had
published in the American 011 and Gas Reporter (attached — see last sentence in
the article). It also matches the figures used by the Natural Gas STAR program.
The STAR presentation on vapor recovery states "vapor recovery can capture up
to 95% of the gas from the tanks".
We can make no assertions as to the run time viability of other manufacturer's
equipment — especially in vapor recovery service. Vapor recovery Is a very
specialized application that requires a great deal of experience In working with wet
gas at very low pressures. Many companies represent that they sell "vapor
recovery units" but actually have little or no experience in this niche application —
resulting in projects with extremely poor run times capturing gas.
However, we are confident in the run time estimates we provide for Hy -Bon
equipment, and it's my sincere hope we have an opportunity to work with Williams
Company on this project.
Best Regards.
Lary S Rickards'
Larry S. Richards
President
1
web5ter.90MM5cfd
GRI-GLYCa1c VERSION 4.0 - AGGREGATE CALCULATIONS REPORT
case Name: Webster Hill - Using Clough Inlet Analysis
File Name: C:\Williams\New sites\Webster Hill\Wesbster_90MMDEHY.ddf
Date: october 18, 2006
DESCRIPTION:
Description: 90 MMscf/day TEG Flash to condenser; 120 deg
F Condenser at 950 psi contactor pressure
40 psi Flash Tk @ 100E w/all emissions to
VRU;
Assumed up to 5% downtime of vnu
Annual Hours of Operation: 438.0 hours/yr
EMISSIONS REPORTS:
CONTROLLED REGENERATOR EMISSIONS
Component
lbs/hr lbs/day tons/yr
Methane 1.6398 39.355 0.3591
Ethane 2.2995 55.188 0.5036
Propane 2.9590 71.016 0.6480
Isobutane 1.4177 34.024 0.3105
n -Butane 1.9666 47.198 0.4307
Isopentane 0.9084 21.802 0.1989
n -Pentane 0.8366 20.078 0.1832
Cyclopentane 0.1731 4.155 0.0379
n -Hexane 0.5444 13.067 0.1192
cyclohexane 1.0905 26.172 0.2388
other Hexanes 0.9421 22.609 0.2063
Heptanes 0.7341 17.619 0.1608
Methylcyclohexane 1.3061 31.346 0.2860
2,2,4-Trimethylpentane 0.0277 0.665 0.0061
Benzene 3.8178 91.627 0.8361
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
4.1068
0.1015
0.9652
0.0132
98.564
2:437
23.166
0.316
0.8994
0.0222
0.2114
0.0029
Total Emissions 25.8502
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
UNCONTROLLED REGENERATOR EMISSIONS
25.8502
21.9109
9.5635
8.9914
620.404 5.6612
620.404
525.861
229.525 .0944
215.794
1.9691
Component lbs/hr lbs/day tons/yr
Page 1
webster_9OMMscfd
Methane 1.6432 39.436 0.3599
Ethane 2.3228 55.748 0.5087
Propane 3.1090 74.615 0.6809
Isobutane 1.5603 37.446 0.3417
n -Butane 2.2385 53.724 0.4902
Isopentane 1.2498 29.995 0.2737
n -Pentane 1.2046 28.910 0.2638
cyclopentane 0.2816 6.758 0.0617
n -Hexane •1.1141 26.738 0.2440
cyclohexane 2.7231 65.353 0.5963
other Hexanes 1.6517 39.642 0.3617
Heptanes 2.8233 67.758 0.6183
Methylcyclohexane 5.2727 126.546 1.1547
2,2,4-Trimethylpentane 0.1066 2.559 0.0234
Benzene 11.0735 265.764 2.4251
Toluene
Ethyl benzene
xylenes
C8+ Heavies
26.8005
1.8720
19.9723
13.5530
643.211 5.8693
44.927 0.4100
479.336 4.3739
325.271 2.9681
Total Emissions 100.5724 2413.738 22.0254
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
FLASH TANK OFF GAS
100.5724
96.6064
60.9390
59.7183
2413.738
2318.554
1462.536
1433.239
22.0254
21.1568
13.3456
13.0783
component lbs/hr lbs/day tons/yr
Methane 34.6533 831.679 7.5891
Ethane 12.8050 307.319 2.8043
Propane 7.1099 170.637 1.5571
isobutane 2,2071 52.971 0.4834
n -Butane 2.3344 56.026 0.5112
Isopentane 1.0741 25.779 0.2352
n -Pentane 0.8122 19.493 0.1779
cyclopentane 0.0492 1.181 0.0108
n -Hexane 0.3857 9.257 0.0845
Cyclohexane 0.2409 5.782 0.0528
other Hexanes 0.7747 18.593 0.1697
Heptanes 0.4439 10.653 0.0972
Methylcyclohexane 0.3421 8.210 0.0749
2,2,4-Trimethylpentane 0.0347 0.834 0.0076
Benzene 0.1151 2.762 0.0252
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
0.1663
0.0062
0.0443
0.1970
3.990
0.150
1.064
4.728
0.0364
0.0014
0.0097
0.0431
Total Emissions 63.7962 1531.108 13.9714
Total Hydrocarbon Emissions 63.7962 1531.108 13.9714
Page 2
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
COMBINED REGENERATOR VENT/FLASH
websterrv90MMscfd
16.3379 392.110
0.7524 18.057
0.3319 7.967
GAS EMISSIONS
0.1648
0.0727
Component
lbs/hr
lbs/day tons/yr
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
cyclohexane
Other Hexanes
Heptanes
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
36.2931
15.1044
10.0689
3.6248
4.3010
1.9825
1.6488
0.2224
0.9301
1.3314
1.7167
1.1780
1.6482
0.0624
3.9329
4.2731
0.1078
1.0096
0.2102
871.034
362.507
241.653
86.995
103.224
47.581
39.571
5.337
22.323
31.954
41.202
28.271
39.556
1.499
94.389
102.554
2.586
24.230
5.044
7.9482
3.3079
2.2051
0.7938
0.9419
0.4342
0.3611
0.0487
0.2037
0.2916
0.3760
0.2580
0.3609
0.0137
0.8613
0.9358
0.0236
0.2211
0.0460
Total Emissions
Total Hydrocarbon Emissions
Total v0C Emissions
Total HAP Emissions
Total BTEX Emissions
89.6463
89.6463
38.2488
10.3159
9.3233
2151.512 19.6325
2151.512
917.971
247.582
223.760
COMBINED REGENERATOR VENT/FLASH GAS EMISSION CONTROL REPORT:
2.0418
Component
Uncontrolled
tons/yr
controlled % Reduction
tons/yr
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
cyclohexane
other Hexanes
Heptanes
7.9489
3.3130
2.2379
0.8251
1.0015
0.5089
0.4417
0.0724
0.3284
0.6491
0.5314
0.7155
Page 3
7.9482
3.3079
2.2051
0.7938
0.9419
0.4342
0.3611
0.0487
0.2037
0.2916
0.01
0.15
1.47
3.78
5.95
14.69
18.25
32.78
37.98
55.08
0.3760 29.25
0.2580 63.94
Methylc clohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
websterL90MMscfd
1.2296
0.0310
2.4503
5.9057
0.4113
4.3837
3.0112
0.3609
0.0137
0.8613
0.9358
0.0236
0.2211
0.0460
70.65
55.83
64.85
84.15
94.26 •
94.96
98.47
Total Emissions
Total Hydrocarbon Emissions
Total VOC Emissions
Total HAP Emissions
Total BTEX Emissions
EQUIPMENT REPORTS:
•
35.9967
35.9967
24.7348
13.5104
13.1510
19.6325
19.6325
8.3765
2.2592
2.0418
45.46
45.46
66.13
83.28
84.47
CONDENSER
Condenser outlet Temperature:
condenser Pressure:
condenser Duty:
Hydrocarbon Recovery:
Produced Water:
voC control Efficiency:
HAP control Efficiency:
BTEX control Efficiency:
Dissolved Hydrocarbons in water:
Component
120.0
12.5
2.88e-00
6.0
25.3
77.3
84.3
84.9
620.4
Emitted
0 deg. F
0 psia
1 MM BTO/hr
1 bbls/day
1 %bbls/day
4 %
1 mg/L
Condensed
Water
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
other Hexanes
Heptanes
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethylbenzene
xylenes
0.64%
98.83%
99.68%
99.79%
99.00%
95.18%
90.86%
87.85%
72.68%
69.45%
61.48%
48.87%
40.05%
57.03%
26.00%
24.77%
25.97%
34.48%
15.32%
5.42%
4.83%
Page 4
99.36%
1.17%
0.32%
0.21%
1.00%
4.82%
9.14%
12.15%
27.32%
30.55%
38.52%
51.13%
59.95%
42.97%
74.00%
75.23%
74.03%
65.52%
84.68%
94.58%
95.17%
webster_90MMscfd
C8+ Heavies 0.10%
ABSORBER
99.90%
NOTE: Because the calculated Absorber stages was below the minimum
allowed, GRI-GLYCalc has set the number of Absorber stages to 1.25
and has calculated a revised Dry Gas Dew Point.
Calculated Absorber Stages:
calculated Dry Gas Dew Point:
Temperature:
Pressure:
Dry Gas Flow Rate:
Glycol Losses with Dry Gas:
Wet Gas Water Content:
calculated Wet Gas Water Content:
Specified Lean Glycol Recirc. Ratio:
Component
1.25
7.17 lbs. H20/MMSCF
120.0 deg. F
950.0 psig
90.0000 MMSCF/day
3.1841 lb/hr
saturated
105.96 lbs. H20/MMscF
3.80 gal/lb H2O
Remaining
in Dry Gas
Absorbed
in Glycol
Water
carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
cyclohexane
Other Hexanes
Heptanes
Methyl cyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
FLASH TANK
6.75%
99.70%
99.97%
99.97%
99.92%
99.89%
99.85%
99.81%
99.82%
99.78%
99.05%
99.66%
98.52%
99.73%
99.43%
98.48%
99.75%
88.86%
85.20%
82.11%
76.16%
97.91%
93.25%
0.30%
0.03%
0.03%
0.08%
0.11%
0.15%
0.19%
0.18%
0.22%
0.95%
0.34%
1.48%
0.27%
0.57%
1.52%
0.25%
11.14%
14.80%
17.89%
23.84%
2.09%
Flash control: Vented to atmosphere
Flash Temperature: 100.0 deg. F
Flash Pressure: 40.0 psig
Left in
Page 5
Removed in
Component
websterL9OMMscfd
Glycol Flash Gas
Water
carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
other Hexanes
Heptanes
Methylc clohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
REGENERATOR
99.98%
41.06%
4.33%
4.53%
15.35%
30.42%
41.41%
48.95%
54.01%
59.93%
85.19%
74.41%
92.13%
68.39%
86.48%
94.15%
75.79%
99.02%
99.43%
99.70%
0.02%
58.94%
95.67%
95.47%
84.65%
69.58%
58.59%
51.05%
45.99%
40.07%
14.81%
25.59%
7.87%
31.61%
13.52%
5.85%
24.21%
0.98%
0.57%
0.30%
99.81% 0.19%
98.74% 1.26%
No Stripping Gas used in regenerator.
Remaining Distilled
in Glycol overhead
Component
water
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
cyclopentane
n -Hexane
cyclohexane
other Hexanes
Heptanes
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethylbenzene
34.12%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.00%
0.93%
0.83%
0.59%
0.67%
3.47%
1.46%
0.58%
4.25%
1.98%
5.05%
7.95%
10.44%
Page 6
65.88%
100.00%
100.00%
100.00%
100.00%
100.00%
100.00%
100.00%
99.07%
99.17%
99.41%
99.33%
96.53%
98.54%
99.42%
95.75%
98.02%
94.95%
92.05%
89.56%
websterry 90MMscfd
xylenes 12.95%
C8+ Heavies 12.17%
STREAM REPORTS:
87.05%
87.83%
WET GAS STREAM
Temperature: 120.00 deg. F
Pressure: 964:70 psia
Flow Rate: 3.76e+006 scfh
Component
conc. Loading
(vol%) (lb/hr)
Water 2.23e-001 3.98e+002
carbon Dioxide 2.95e+000 1.29e+004
Nitrogen 1.O1e-001 2.80e+002
Methane 8.65e+001 1.37e+005
Ethane 6.69e+000 1.99e+004
Propane 2.04e+000 8.91e+003
isobutane 4.43e-001 2.55e+003
n -Butane 4.21e-001 2.43e+003
isopentane 1.82e-001 1.30e+003
n -Pentane 1.26e-001 8.99e+002
Cyclopentane
n -Hexane
Cyclohexane
other Hexanes
Heptanes
4.99e-003 3.47e+001
5.19e-002 4.43e+002
2.39e-002 2.00e+002
1.07e-001 9.12e+002
5.79e-002 5.75e+002
Methylcyclohexane 3.79e-002 3.69e+002
2,2,4-Trimethylpentane 4.99e-003 S.65e+001
Benzene 1.30e-002 1.00e+002
Toluene 2.00e-002 1.82e+002
Ethylbenzene 9.98e-004 1.05e+001
xylenes 7.98e-003 8.40e+001
C8+ Heavies 3.89e-002 6.57e+002
Total Components 100.00 1.91e+005
DRY GAS STREAM
Temperature:
Pressure:
Flow Rate: 3
120.00 deg. F
964.70 psia
.75e+006 scfh
Component
Conc. Loading
(vol%) (lb/hr)
water 1.51e-002 2.69e+001
carbon Dioxide 2.95e+000 1.28e+004
Nitrogen 1.O1e-001 2.80e+002
Page 7
webster_9oMMscfd
Methane 8.67e+001 1.37e+005
Ethane 6.70e+000 1.99e+004
Propane 2.04e+000 8.90e+003
Isobutane 4.44e-001 2.55e+003
n -Butane 4.21e-001 2.42e+003
isopentane 1.82e-001 1.30e+003
n -Pentane 1.26e-001 8.97e+002
Cyclopentane 4.95e-003 3.43e+001
n -Hexane 5.18e-002 4.42e+002
Cyclohexane 2.37e-002 1.97e+002
other Hexanes 1.07e-001 9.09e+002
Heptanes 5.77e-002 5.71e+002
Methylcyclohexane 3.74e-002 3.63e+002
2,2,4-Trimethylpentane 4.99e-003 5.63e+001
Benzene 1.16e-002 8:92e+001
Toluene 1.70e-002 1.55e+002
Ethylbenzene 8.21e-004 8.62e+000
Xylenes 6.10e-003 6.40e+001
C8+ Heavies 3.82e-002 6.43e+002
Total Components 100.00 1.90e+005
LEAN GLYCOL STREAM
Temperature: 120.00 deg. F
Flow Rate: 2.28e+001 gpm
component
conc. Loading
(wt%) (ib/hr)
TEG 9.84e+001 1.26e+004
Water 1.50e+000 1.92e+002
carbon Dioxide 2.98e-011 3.82e-009
Nitrogen 6.46e-014 8.28e-012
Methane 9.S1e-018 1.22e-015
Ethane 5.57e-008 7.14e-006
Propane 3.24e-009 4.16e-007
isobutane 8.81e-010 1.13e-007
n -Butane 8.85e-010 1.13e-007
Isopentane 9.11e-005 1.17e-002
n -Pentane 7.90e-005 1.O1e-002
cyclopentane 1.30e-005 1.66e-003
n -Hexane 5.88e-005 7.54e-003
cyclohexane 7.64e-004 9.80e-002
Other Hexanes 1.91e-004 2.45e-002
Heptanes 1.28e-004 1.64e-002
Methylcyyclohexane 1.82e-003 2.34e-001
2,2,4-Trimethyipentane 1.68e-005 2.15e-003
Benzene 4.59e-003 5.89e-001
Toluene 1.80e-002 2.31e+000
Ethylbenzene 1.70e-003 2.18e-001
xylenes 2.32e-002 2.97e+000
CS+ Heavies 1.46e-002 1.88e+000
Page 8
webster 90MMscfd
Total components
RICH GLYCOL STREAM
100.00 1.28e+004
Temperature:
Pressure:
Flow Rate:
NOTE: stream
120.00 deg. F
964.70 psia
2.39e+001 gpm
has more than one
Component
phase.
Conc. Loading
(wt%) (lb/hr)
TEG
Water
carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
Other Hexanes
He Lanes
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethylbenzene
Xylenes
C8+ Heavies
9.42e+001
4.21e+000
2.85e-001
6.19e-004
2.71e-001
1.13e-001
7.63e-002
2.81e-002
3.42e-002
1.74e-002
1.51e-002
2.48e-003
1.13e-002
2.29e-002
1.83e-002
2.45e-002
4.37e-002
1.07e-003
8.80e-002
2.19e-001
1.57e-002
1.72e-001
1.17e-001
1.26e+004
5.64e+002
3.82e+001
8.28e-002
3.63e+001
1.51e+001
1.02e+001
3.77e+000
4.57e+000
2.34e+000
2.03e+000
3.32e-001
1.51e+000
3.06e+000
2.45e+000
3.28e+000
5.85e+000
1.44e-001
1.18e+001
2.93e+001
2.10e+000
2.30e+001
1.56e+001
Total Components 100.00 1.34e+004
FLASH TANK OFF GAS STREAM
Temperature: 100.00 deg. F
Pressure: 54.70 psia
Flow Rate: 1.29e+003 scfh
component
Conc. Loading
(vol%) (lb/hr)
water 1.73e-001 1.06e-001
carbon Dioxide 1.50e+001 2.25e+001
Nitrogen 8.31e-002 7.92e-002
Methane 6.35e+001 3.47e+001
Ethane 1.25e+001 1.28e+001
Propane 4.74e+000 7.11e+000
Page 9
websterrv90MMscfd
Isobutane 1.12e+000 2.21e+000
n -Butane 1.18e+000 2.33e+000
Isopentane 4.38e-001 1.07e+000
n -Pentane 3.31e-001 8.12e-001
Cyclopentane 2.06e-002
n -Hexane 1.32e-001
Cyclohexane 8.41e-002
other Hexanes 2.64e-001
Heptanes 1.30e-001
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethyl benzene
Xylenes
c8+ Heavies
1.02e-001
8.94e-003
4.33e-002
5.30e-002
1.73e-003
1.23e-002
3.40e-002
4.92e-002
3.86e-001
2.41e-001
7.75e-001
4.44e-001
3.42e-001
3.47e-002
1.15e-001
1.66e-001
6.24e-003
4.43e-002
1.97e-001
Total components
FLASH TANK GLYCOL STREAM
100.00 8.65e+001
Temperature: 100.00 deg. F
Flow Rate: 2.38e+001 gpm
Component
Conc. Loading
(wt%) (lb/hr)
TEG
Water
carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
Other Hexanes
Heptanes
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethyl benzene
Xylenes
C8+ Heavies
9.48e+001
4.24e+000
1.18e-001
2.70e-005
1.24e-002
1.75e-002
2.34e-002
1.17e-002
1.68e-002
9.48e-003
9.13e-003
2.13e-003
8.43e-003
2.12e-002
1.26e-002
2.13e-002
4.14e-002
8.18e-004
8.77e-002
2.19e-001
1.57e-002
1.72e-001
1.16e-001
1.26e+004
5.64e+002
1.57e+001
3.59e-003
1.64e+000
2.32e+000
3.11e+000
1.56e+000
2.24e+000
1.26e+000
1.21e+000
2.83e-001
1.12e+000
2.82e+000
1.68e+000
2.84e+000
5.51e+000
1.09e-001
1.17e+001
2.91e+001
2.09e+000
2.29e+001
1.54e+001
Total Components
100.00 1.33e+004
Page 10
webster_.90MMscfd
REGENERATOR OVERHEADS STREAM
Temperature: 212.00 deg. F
Pressure: 14.70 psia
Flow Rate: 8.42e+003 scfh
component
Conc. Loading
(vol%) (lb/hr)
Water
Carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
Cyclopentane
n -Hexane
Cyclohexane
other Hexanes
Heptanes
Methylcyclohexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethylbenzene
Xylenes
c8+ Heavies
9.29e+001
1.61e+000
5.77e-004
4.61e-001
3.48e-001
3.18e-001
1.21e-001
1.73e-001
7.80e-002
7.52e-002
1.81e-002
5.82e-002
1.46e-001
8.63e-002
1.27e-001
2.42e-001
4.20e-003
6.39e-001
1.31e+000
7.94e-002
3.71e+002
1.57e+001
3.59e-003
1.64e+000
2.32e+000
3.11e+000
1.56e+000
2.24e+000
1.25e+000
1.20e+000
2.82e-001
1.11e+000
2.72e+000
1.65e+000
2.82e+000
5.27e+000
1.07e-001
1.11e+001
2.68e+001
1.87e+000
8.47e-001 2.00e+001
3.58e-001 1.36e+001
Total Components
CONDENSER VENT GAS STREAM
100.00 4.88e+002
Temperature: 120.00 deg. F
Pressure: 12.50 psia
Flow Rate: 3.68e+002 scfh
Component
Conc. Loading
(vol%) (lb/hr)
Water
carbon Dioxide
Nitrogen
Methane
Ethane
Propane
Isobutane
n -Butane
Isopentane
n -Pentane
1.37e+001
3.63e+001
1.32e-002
1.05e+001
7.88e+000
6.92e+000
2.51e+000
3.49e+000
1.30e+000
1.20e+000
2.39e+000
1.55e+001
3.57e-003
1.64e+000
2.30e+000
2.96e+000
1.42e+000
1.97e+000
9.08e-001
8.37e-001
Cyclopentane 2.54e-001 1.73e-001
Page 11
websten_90MMscfd
n -Hexane 6.51e-001 5.44e-001
Cyclohexane 1.34e+000 1.09e+000
Other Hexanes 1.13e+000 9.42e-001
Heptanes 7.55e-001 7.34e-001
Methyl cyclohexane 1.37e+000 1.31e+000
2,2,4-Trimethylpentane 2.50e-002 2.77e-002
Benzene 5.04e+000 3.82e+000
Toluene 4.59e+000 4.11e+000
Ethylbenzene 9.86e-002 1.02e-001
Xylenes 9.37e-001 9.65e-001
C8+ Heavies 7.98e-003 1.32e-002
Total Components 100.00 4.37e+001
CONDENSER PRODUCED WATER STREAM
Temperature: 120.00 deg. F
Flow Rate: 7.38e-001 gpm
Component Conc. Loading
(wt%) (lb/hr) (ppm)
Water 9.99e+001 3.69e+002 999109.
carbon Dioxide 2.71e-002 9.99e-002 271.
Nitrogen 1.63e-007 6.00e-007 0.
Methane 1.44e-004 5.31e-004 1.
Ethane 2.30e-004 8.49e-004 2.
Propane 3.06e-004 1.13e-003 3.
Isobutane 7.99e-005 2.95e-004 1.
n -Butane 1.47e-004 5.43e-004 1.
Isopentane 4.80e-005 1.77e-004 0.
n -Pentane 4.74e-005 1.75e-004 0.
Cyclopentane 6.90e-005 2.55e-004 1.
n -Hexane 2.56e-005 9.46e-005 0.
otherlHexanes 3.57e e-005 1.3204 e-004 0.
Heptanes 1.92e-005 7.08e-005 0.
Methylcyclohexane 1.65e-004 6.11e-004 2.
2,2,4-Trimethylpentane 4.83e-007 1.78e-006 0.
Benzene 2.85e-002 1.05e-001 285.
Toluene 2.53e-002 9.33e-002 253.
Ethylbenzene 4.71e-004 1.74e-003 5.
Xylenes 6.21e-003 2.29e-002 62.
c8+ Heavies 2.18e-007 8.07e-007 0.
Total components 100.00 3.69e+002 1000000.
CONDENSER RECOVERED OIL STREAM
Temperature: 120.00 deg. F
Flow Rate: 1.75e-001 gpm
Component conc. Loading
Page 12
webster_90MMscfd
(wt%) (lb/hr)
water 4.70e-002 3.51e-002
Carbon Dioxide 1.13e-001 8.43e-002
Nitrogen 1.45e-005 1.08e-005
Methane 3.84e-003 2.86e-003
Ethane 3.01e-002 2.25e-002
Propane 1.99e-001 1.49e-001
Isobutane 1.91e-001 1.42e-001
n -Butane 3.64e-001 2.71e-001
isopentane 4.57e-001 3.41e-001
n -Pentane 4.93e-001 3.68e-001
Cyclopentane 1.45e-001 1.08e-001
n -Hexane 7.63e-001 5.70e-001
Cyclohexane 2.19e+000 1.63e+000
Other Hexanes 9.51e-001 7.10e-001
Heptanes 2.80e+000 2.09e+000
Methylcyclohexane 5.32e+000 3.97e+000
2,2,4-Trimethylpentane 1.06e-001 7.89e-002
Benzene 9.58e+000 7.15e+000
Toluene 3.03e+001 2.26e+001
Ethylbenzene 2.37e+000 1.77e+000
Xylenes 2.54e+0O1 1.90e+001
c8+ Heavies 1.81e+001 1.35e+001
Total Components 100.00 7.46e+001
Page 13
Williams Production RMT
Proposed Process Heater Detail Sheat
Source ID Number
Equipment ID
Source Description
Equipment Usage
Equipment Make
Equipment Model
Date in Service 2007
Emission Controls None
HTRA
HTR•1
Medium Heater
Process Heater
Fuel Heating Value
Heat Input
• Assume 80% efident
Permit Status
Potential Emissions
1040 Btu/scf
15.00 MMBtu/hr
•
Source Location Zone: 13
UTME(m): 253990
UTMN(m): 4378720
Potential operation 8760 hr/yr
Potential fuel usage 126.35 MMsc/yr
Stack ID
Stack Height
Stalk Diameter
Exit Vetodty
Exit Temperature
Volume Flow Rate
HTR
20 ft
2ft
20 6/s
500 deg F
3,770 IN/min
Pollutant Emission Factor
(lb/MMsc) (Ib/MMBIu)
NOx
CO
VOC
SOx
PM10
100.00
84.00
5.50
0.60
7.60
Nominal Hra of
Rating Operation
(MMBlwhr (h )
15.00 8760
15.00 8760
15.00 8760
15.00 8760
15.00 8760
Estimated Emissions
b/hr)
1.44
1.21
0.08
0.01
0.11
SIPY)
6.32
5.31
0.35
0.04
0.48
Source of
Emission
Factor
AP42
AP42
AP42
AP42
AP42
Webster_Hill Printed on 10/18/2006
OCTOBER 2006 • WEBSTER BILL COMPRESSOR STATION
WEBSTER RILL COMPRESSOR STATION
NORMAL OPERATION WITH VRV RUNNING 8.322 HOURS PER YEAR
CONDENSATE PLASH TO VRU. TANK WORKING/BREATHING (ASSES VENTED TO ATMOSPHERE
TANK -01 E&P TANK2A CONDENSATE TANK WORKING/3REATHING TASSE.9
Annual Fks of Operation
Number flanks
Condensate Flow Rate
Operating HouMYear
Wet Separator Temperature
Wel Separator Pratte,
Site Atmnphaic Pressure
Stable OS API Gravity
Stable Oil Reid Vapor Pres.
EAP TANK2.0 OuWut
VOC. C3+
Benzene
Toluene
Ethylbemene
Xylene
n -Hexane
Methene
Ethane
Aggrepte HAP
8322 (c.. 8760 Myr)
3
40.0 bbl/day total
365 homa/yr
74 deg F
245 Fag
12.5 pada
58.5 deg. API
S psis
Uncontrolled
11.312 47.9
0.055 0.2
0.080 0.3
0.003 0.0
0.025 0.1
0.213 0.9
5.648 23.5
4.581 19.1
0.376 1.6
Permitted/Controlled
!Met fa
3.609 15.02
0.013 0.05
0.020 0.08
0.001 0.00
0.007 0.03
0.052 0.22
0.173 0.72
0.836 3.48
0.093 0.39
Pressurized TUMOR Composition
Tem &SP FANS Maki Ant
Quastraa
Hydrogen Sulfide
Chcfgen
Carbon Dioxide
t4hogen
Methane
Ethane
Propene
Isobcrane
n-Bulane
ROpentem
Pentanes
Hexane
fomes
OOuna
Noumea
Deana+
Benzene
Toluene
Ed04bcnzene
Xylenes
n-Hexam
2,2,4•Tzimedalpenum
Total MI Constituents
Uquid
f% Vol.)
0.000
0.000
0.332
0.000
0.851
1,598
2.644
1.611
2333
2.464
2.570
8.093
18.839
14.037
12.157
16.019
1.094
5.403
0.660
5.811
3.466
0.021
100.000
WEBSTER HILL COMPRESSOR STATION
ALTERNATIVE/MAINTENANCE OPERATION MYTH VRU DOWNTIME OF 431 HOURS PER YEAR
CONDENSATE PLASH AND TANK WORICING/BREAT ING LOSSES VENTED TO ATMOSPHERE
TANK -0I EAP TANK2.0 CONDENSATE INPUT
Memel Etre of Operation
Number of Tanks
Condensate flow Rate
Operating Howl/Year
Bulk Condensate Temperate.
Huh rank Prison
Site Atmospheric Pressure
Stable Oil API Gravity
Stable Oil Reid Vapor Pau
E*P TANK2A Oamat
VOC, C3+
Benzene
Toluene
Ethyibenzene
Xylenes
n-Hexs e
Methane
Ethane
Aggregate HAP
438 (<- 8760 hr/yr)
3
40.0 bbt/day total
365 betesyr
60 deg F
20 pig
123 psis
58.5 deg. API
5 pan
Permitted/Uncontrolled
111.5131
2
0.055
0.080
0.003
0.025
0.213
5.648
4.581
0.316
5042
5042
24
35
1
11
93
2474
2006
165
2..5252
0.01
042
0.00
0,01
0.05
1.24
1.00
0.08
Pressurized Condensate Analysis
Arai 2k2 1003
Samsoard
Hydrogen Sulfide
Oxygen
Carbon Dioxide
Nitrogen
Malan
Ethane
Propane
Isobuuae
n-Butait
Repentant
Pentanes
Haunts
Monate
Octan
Nowa
Dania+
Became
Toluene
Ethylbenzeoe
Xylenes
n -Hexane
2,2A•Tdmeebylpentan
Tota All Constituents
ugtde
(54 Voll
0.00D
0.000
1.175
0.000
7,799
3.360
3.149
1.604
2.239
2.251
2.328
7.231
16.755
12.466
10.792
14.219
0.975
4.801
0.586
5.159
3.092
0.019
100.000
wanrr_Bnn.
11/24/2046
OCTOBER 2006- WEBSTER HILL COMPRESSOR STATION
WEBSTER HILL COMPRESSOR STATION
TOTAL PERMITTED TANX FLASH AND WORKING/BREATHING EMISSIONS TO ATMOSPHERE
TOTALOPE.RATEIG HOURS 8,760 HOURS PER YEAR
Normal PermSNed/Malntengee
Total Permitted
Operation Operations
Tank Operadent
Maximum 31om1/Yr
8322 438
8760
ifrm1Red EmLd9Y
VOC Emission OPT)
15.0 23
173
Benzene Emission (Ib/yr)
108 24.1
132
Benzene Emission (tpy)
0,1 0.0
0.1
Toluene Emission (1byr)
166 35.0
201
Toluene Emission (Ipy)
0.1 0.0
0.1
EOiibenzene Emission (111yr;
8 1.3
10
EOIylbenzene Emiasimu (tpy)
0.0 0.0
0.0
Xylenes Emission (R✓yr)
58 11.0
69
Xylenes Emission (tpy)
0.0 0.0
0,0
n -Rename Emission (IbIyr)
433 933
526
n-Hexans Emission (tpy)
01 OA
0.3
Az{. HAP Emission (tpy)
0.4 0,1
03
PTPIUneontroned Egoista
47.0 23
80A
VOC Emission (tpy)
Benzene Emission Ob/yr)
458 24,1
482
Battens Emission (tpy)
02 0.0
0.2
Toluene Emission (Myr)
666 35.0
701
Toluene Emission (tpy)
0,3 0.0
0.4
Etbyibenzete Emission (Myr;
25 1.3
26
Ethylbenzene Emissions (Ipy)
0.0 0.0
0.0
Xylenes Emission (Myr)
208 11,0
219
Xylenes Emission(tpy)
0.1 0.0
0.1
n-Hacuw Emiuion (ib/yr)
1773 933
1066
n-Hexsne Emission (Ipy)
0.9 0,0
0.9
Au. HAPEnduton On)
1.6 0.1
1.6
Ovens Control Efficiency:
65V.
Webster enb
LAP RAWL 72.0 Calculation *sport--- pavelcsed by DX Robinson a Associates Ltd. 10/24/2006
•
• Project Satup Information
•
Project sit.
Plowshaat Sanction
Calculation Kethod
Control iffioiegoy
Known Separator Stream
Interium Air Composition
Piled Name
Well Race
Well ID
Nate
s Ks\Ln ireumental Affairs\.tao6+la\Sork1n8\Oatbaria8\Webster Sill CS%Passit 7.
: oil Tank with Separator
: RVP Distillation
I 0.0%
s Sigh Pressure Oil
s No
: Webster Rill C.B.
t Shsrrard Park Compressor StationAM 2003 Pressurised Condensate Sample
$ Pros 145 psis Separator to Plash Tank 0 10 psis to Atmospheric Uncontrolled 4:
✓ 10/23/2006
• Data Input
r
Separator Pressure
Separator Temperature
Ambient Pressure
Ambient Temperature
010+ SO
010. KM
-- Nigh Pressure Oil
No. Component
1 318
2 02
3 CO2
4 K1
3 01
6 C2
7 C3
8 i -C4
9 n -C4
10 1-05
11 n-05
11 C6
13 C7
14 CO
13 09
16 010+
17 Benzene
18 Toltese
19 i-eensene
20 XYlan.s
21 n -C6
22 224Triaethylp
-- Sales Oil
$ 245.00[paig]
r 74.00(11
: 12.301p2ia)
s 30.00[11
r 0.7440
: 133.89
mo1 %
0.0000
0.0000
1.1750
0.0000
7.7990
3.3600
3.1490
1.6040
1.1390
2.2510
1.3190
7.2310
16.7330
12.4660
10.7120
14.2190
0.9730
4.8010
0.5060
5.1590
3.0920
0.0190
Production Rate
Days of Anneal Operation
ApI gravity
Reid Vapor Pressure
✓ 40(bbl/day]
4 365 (days/Pear]
r 58.5
: 5.00(psia)
• Calculation Results
•
-- mission Sumeary
Itas Uncontrolled
[ton/yrl
Uncontrolled Controlled
(lb/hr) (ton/yr]
page 1
Controlled
(lb/hr]
149 TANK V2.0 Calculation Report--- Developed by DB Robinson A Associates Ltd.
10/24/2006
Total BAPS
total EC
VOCs, C2+
VGCs, C3+
1.650
95.223
70.405
50.423
Uncontrolled Recovery info.
Vapor 7.0100
8C Vapor 6.5200
GOR 175.25
No
!mission Composition
Component
1 828
2 02
3 002
4 N2
5 C1
6 C2
7 C3
8 i -C4
9 a -C4
10 i-05
11 n-05
12 C6
13 C7
14 CO
15 09
16 C10+
17 Benzene
18 Toluene
19 R -Benzene
20 Xylenes
21 n -C6
•& zzaaramaC]T,xp
Total
-- Stream Data
No. Component
0.377
21.740
16 092
r11.512]
mem
[N80rn]
10CP/bbl]
1.650
95.223
70.485
50.423
0.377
21.740
16.092
11.512
Uncontrolled
[ton/yr]
0.000
0.000
10.264
0.000
24.737
20.063
23.776
6.921
6.670
3.194
2.373
2.822
2.265
0.542
0.169
0.045
0.242
0.349
0.014
0.109
0.935
U.UUI
105.486
Uncontrolled
[lb/hr]
0.000
0.000
2.343
0.000
5.648
4.581
5.428
1.580
1.523
0.729
0.542
0.644
0.517
0.124
0.037
0.010
0.055
0.080
0.003
0.025
0.213
0.00
24.084
Controlled
[ton/yr]
0.000
0.000
10.264
0.000
24.737
20.063
23.776
6.921
6.670
3.194
2.373
2.822
2.265
0.542
0.163
0.045
0.242
0.349
0.014
0.109
0.935
0.002
105.486
Controlled
[1b/hrl
0.000
0.000
2.343
0.000
5.648
4.581
5.428
1.580
1.523
0.729
0.542
0.644
0.517
0.124
0.037
0.010
0.055
0.080
0.003
0.025
0.213
0.000
24.084
1 828
2 02
3 CO2
4 N2
5 Cl
6 C2
7 C3
8 1-04
9 n-04
10 1-05
11 n-05
12 C6
13 C7
14 C8
15 C9
16 010+
17 Benzene
18 Toluene
19 B -Benzene
20 Xylenes
21 n -C6
22 224Triasthylp
MN
Stream Hole Ratio
Beating Value
Gas gravity
Bubble Rt. 6 1001
NN
34.80
32.00
44.01
20.01
16.04
30.07
44.10
58.12
68.12
72.15
72.15
86.16
100.20
114.23
128.28
153.89
78.11
92.13
106.17
106.17
86.18
114.24
L9 Oil
sol %
0.0000
0.0000
1.1728
0.0000
7.7545
3.3579
3.1497
1.6047
2.2401
2.2522
2.3293
7.2351
16.7646
12.4732
10.7982
14.2272
0.9756
4.8038
0.5863
5.1620
3.0938
0.0190
Plash Oil Bale Oi1 Plash Gas NUB Sas
mol ♦ sol % mol ♦ sol
0.0000 0.0000 0.0000 0.0000
0.0000 0.0000 0.0000 0.0000
0.1266 0.0000 7.3420 4.3776
0.0000 0.0000 0.0000 0.0000
0.2772 0.0000 51.8437 9.5870
0.7185 0.0030 18.9207 24.7502
1.7691 0.3277 11.2899 43.4612
1.3644 1.2115 3.0212 6.5029
2.0967 2.0029 3.0851 5.2488
2.4222 2.4445 1.2500 1.6731
2.5665 2.6062 0.9306 1.2326
8.3011 8.5106 0.9497 1.2632
19.4967 20.0502 0.6556 0.9054
14.5636 14.9934 0.1359 0.1969
12.6233 12.9976 0.0360 0.0584
16.6388 17.1338 0.0078 0.0133
1.1262 1.1562 0.0874 0.1183
5.6005 5.7628 0.1058 0.1504
0.6851 0.7054 0.0038 0.0056
6.0326 6.2110 0.0283 0.0425
3.5666 3.6603 0.3059 0.4117
0.0221 0.0228 0.0006 0.0008
95.05 106.18 108.10 29.44 41.89
1.0000 0.8550 0.8303 0.1450 0.0247
1543.47 2285.56
1.02 1.45
21.58 5.30
[BTO/BCP1
[Gam/Airl
[psis] 287.30
Page 2
Total tnissiocs
sol %
0.0000
0.0000
6.9102
0.0000
45.6889
19.7698
13.9758
3.5283
3.4002
1.3116
0.9746
0.9953
0.6920
0.1448
0.0392
0.0086
0.0919
0.1123
0.0040
0.0304
0.3213
0.0006
91.26
0.1697
1651.56
1.08
Lop TANK V2.0 Calculation Report--- Developed by 00 Robinson a Associates Ltd. 10/24/2006
AVM IF 1008 188181 67.91 10.89 4.91
8p41o. Gravity ! 1008 0.670 - 0.686 0.687
page 3
SOP Talo( V2.0 Calculation Report--- Developed by D8 Robinson 4 associates Ltd.
2006.10.24
Project getup Information
•
Project Tile
ila sheet Selection
Calculation Method
Control ifficiency
Known Separator Stream
Motoring air Composition
Piled tame
Well Mame
Mall XD
Date
Mi\snrironmental offairs\■sxasple\Working\0atberin0\webatsr Rill C0\Permit ap]
Oil Tank with Separator
IVP Distillation
0.0%
Low Pressure Oil
No
Webster 8111 C.B.
Sharrard Park CogvrassorStation AUG. 2003 Pressurised Condensate Sample
Plash Tank S 20 prig to atmosphere Uncontrolled
2006.10.23
Data Input
Separator Pressure
Separator Tesp'rature
Ambient Pra•sure
Ambient Teaperature
010+ SO
010+ 104
-- Lar Pressure Oil
No. Component
t 20.00(Psig]
I 74.00(t1
t
12.50/Pala]
t 50.00(fl
t 0.7800
t 153.89
1 828
2 02
3 CO2
4 42
5 01
6 c2
7 C3
8 i -C4
9 n -C4
10 i-05
11 n-05
12 C6
13 C7
14 C8
15 C9
16 C10+
17 Monsen*
18 Toluene
19 K -Kansan
20 Pylon's
21 a -C6
22 224Primethylp
-- Sales Oil
mol %
0.0000
0.0000
0.1266
0.0000
0.2772
0.7185
1.7691
1.3644
2.0967
2.4122
2.5665
8.3011
19.4967
14.5656
12.6235
16.6388
1.1262
5.6005
0.6851
6.0326
3.5666
0.0221
Production Rata
Days of annual Operation
JPI Gravity
881d Vapor Pressure
t 40(bb1/day]
e 365 (days/year]
t 58.5
3 5.001Psial
• Calculation Results
•
-- 'mission Wonsary
Item Uncontrolled
(ton/yrl
Uncontrolled Controlled
]ib/lml (ton/yrl
nage 1
Controlled
(lb/hr]
S&P TANK V2.0 Calculation Report--- Developed by DB Robinson & Associates Ltd.
2006.10.24
Total BlPs
Total BC
VOCs, C3+
VOCs, C3+
0.410
20,226
19.468
15.807
Uncontrolled Recovery Into.
Vapor 1.0300
BC Vapor 0.9800
GOR 25.75
-- =mission composition
Bo Component
1 628
2 01
3 CO2
4 42
5 C1
6 C2
7 C3
8 1-C4
9 n -C4
10 1-05
11 n-05
12 C6
13 C7
14 C8
15 C9
16 C10+
17 Benson
18 Toluene
19 r -Benson
20 Xylenes
21 n -C6
22 224Trimethylp
Total
-- Straws Data
No. Component
0.094
4.618
4.445
13.609 1
[mama
[MSCFDI
18C7/bbl]
0.410
20.226
19.468
15.807
0.094
4.618
4.445
3.609
Uncontrolled
[Con/yr]
0.000
0.000
0.949
0.000
0.758
3.662
9.009
1.958
1.682
0.731
0.547
0.676
0.580
0.150
0.051
0.011
0.057
0.089
0.004
0.030
0.238
0.001
21.173
Uaodatrolled
[lb/br]
0.000
0.000
0.217
0.000
0.173
0.836
2.057
0.447
0.384
0.167
0.125
0.154
0.132
0.034
0.012
0.003
0.013
0.020
0.001
0.007
0.052
0.000
4.834
Controlled
[ton/yr]
0.000
0.000
0.949
0.000
0.758
3.662
9.009
1.958
1.682
0.731
0.547
0.676
0.580
0.150
0.051
0.011
0.057
0.089
0.004
0.030
0.228
0.001
21.173
Controlled
]lb/hr]
0.000
0.000
0.217
0.000
0.173
0.836
2.057
0.447
0.384
0.167
0.125
0.154
0.132
0.034
0.012
0.003
0.013
0.020
0.001
0.007
0.051
0.000
4.634
1 620
2 02
3 CO2
4 BI
5 CL
6 C2
7 C3
8 i -C4
9 n -C4
10 1-05
11 n-05
12 C6
13 C7
14 C8
15 C9
16 C10+
17 Benson
18 Toluens
19 B-Bearene
20 Xylenes
21 n -C6
22 224Trimethylp
Mx
Stream Mole Ratio
Beating Value
Gas Gravity
Hubble Pt. 6 100E
MR
34.80
32.00
44.01
28.01
16.04
30.07
44.10
58.12
58.12
72.15
72.15
86.16
100.20
114.23
128.28
153.89
78.11
92.13
106.17
106.17
86.10
114.24
LP 011 Flash 011 Bale O11 Flash Gas xa8 Gas
mol % mol ♦ mol % nal % Rol %
0.0000 0.0000 0.0000 0.0000 0.0000
0.0000 0.0000 0.0000 0.0000 0.0000
0.1266 0.1164 0.0000 7.6185 4.1893
0.0000 0.0000 0.0000 0.0000 0.0000
0.2772 0.2178 0.0000 44.0132 7.8399
0.7185 0.6911 0.0038 20.9270 24.7401
1.7691 1.7532 0.5868 13.5131 42.5639
1.3644 1.3611 1.2016 3.7866 6.9428
2.0967 2.0942 1.9846 3.9172 5.9311
2.4222 2.4231 2.4335 1.6522 2.0638
2.5665 2.5683 2.5976 1.2473 1.5421
8.3011 8.3106 8.5012 1.3281 1.6389
19.4967 19.5219 20.0449 0.9626 1.2190
14.5656 14.5851 14.9940 0.2101 0.2755
12.6235 12.6406 12.9994 0.0584 0.0645
16.6388 16.6614 17.1371 0.0100 0.0149
1.1362 1.1276 1.1555 0.1196 0.1498
5.6005 5.6079 5.7625 0.1527 0.1980
0.6851 0.6860 0.7054 0.0057 0.0077
6.0326 6.0407 6.1117 0.0431 0.0582
3.5666 3.5709 3.6575 0.4336 0.5394
0.0221 0.0121 0.0227 0.0009 0.0011
106.18
1.0000
[BTU/BCF]
]Gee/air]
[aria] 21.90
page 2
106.28 108.08 32.27 43.22
0.9986 0.9709 0.0014 0.0277
1686.61 2360.34
1.11 1.49
19.77 5.42
Total Rmlusions
nal %
0.0000
0.0000
4.3490
0.0000
9.5249
24.5625
41.2107
6.7958
5.8373
2.0447
1.5284
1.6244
1.2070
0.2724
0.0833
0.0147
0.1484
0.1959
0.0076
0.0575
0.5345
0.0011
41.71
0.0291
2328.96
1.47
KP AOC V7.0 Calculation aeon. Developed by D® Robinson i aasoaiatas Ltd. 2006.10.24
RVP • 1007 (psis] 11.02 10.47 5.00
Span. Gravity • 1007
0.696 0.690 0.700
papa 3
OCTOBER 2006 - WEBSTER HILL COMPRESSOR STATION
WEBSTER HILL COMPRESSOR STATION
LOAD -1 CONDENgATE LOADOUT VOC EMISSIONS
USEPA Loadout natation
L=12.46*S*P*MW/(Te(1-eff))
from AP -42 Section 4.4
Molecular Weight of Vapors, MW
True Vapor Pressure, Pva ® T
Temperature of Bulk Liquid Loaded, T
Saturation Factor
Efficiency of controlled loading (%)
Annual throughput, v
Loading losses, L Q tank
L= 12.46SPMW/T(1-eft)
Annual losses ® tank, Vs?
Loading Frequency
Track Volume
Loading Rate
Loading Duration
Annual Hrs of Operation
Hourly VOC During Loading
50.81 lb/lb-mol
5 psia
F
R
80
540
0.6
0.0%
613
E&P TANK2.0
Estimated
Estimated
Dedicated service
1000 gallons
3.52 11,/1000 gallons
2,156.74 lb/yr 1.1 tpy
82
7500
75
100.0
136.67
15.78
trucks/yr
gal/truck
galhnin
min/truck
hr/yr
lb/hr (while loading)
10/18/2006 Webster 111
Webster Hill Compressor Station
FUG -I Fugitive Vt3C Detail Skeet
Component Counts Based on Typical Process Unit Counts
8760 Hours Per Year
J.
In
/%
&}
11
l
&|
�
J\
!/
i.
Comptessor Skid (5) 200 25 10 20 0 150 10 600 40
Separator(]) 6 4 2 0 0 8 2 120 30
Storage Tank (3) 12 18 6 0 6 15 30 45 90
Dehydration Unit (2) 150 40 8 0 8 40 100 100 300
,Flue (I)e 8 2 2 0. 0 ___ 15 2 60 8
!
!
n
Rii.
n
`
1
■
{
7
) \
!llgQe:=5;2on
Q'g
23.;®�®
lImmoom.Irodmo;q�$%
p|§§!K§§§§§
\d,aoci,cidd
il
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)J
WriiIIIII
ahc2?
iJ
_
ok
;=;;;
R"RUSas
,.%..k|�
Uf,44%§£\
��
-e9'i§�$
r@RlalQ!
cdaad
, $ 0$
1
1710
)§
(
/
|
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j
'I
!
1
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$
|
%$k§kkk
6-28s2
..
22-
&w;;+
411111
tics.c.01
]
,
OCTOBER 2006 - WEBSTER HILL COMPRESSOR STATION
WEBSTER HILL COMPRESSOR STATION
INLET GAS COMPOSITION
Date of analysis: 8/24/06 Analysis ID 200608124 (from Clough Compressor Station)
Pollutant
Molecular Volume
Gas Weight Corrected'
Weight Percent
Weight Fraction Wt. Fraction
(lb/lb-mol)
- (%)
(1b/Ibmol) (%) (%)
Methane
16.01 86.64%
13.8715 72.49% 77.90%
Ethane
30.02 6.71%
2.0131 10.52% 11.31%
Total HC (Non-VOC)
93.35%
83.01% 89.21%
Propane
44.03 2.04%
0.8995 4.70% 5.05%
i -Butane
58.04 0.44%
0.2577 1.35% 1.45%
n -Butane
58.04 0.42%
0.2449 1.28% 1.38%
i -Pentane
72.05 0.18%
0.1311 0.69% 0.74%
n -Pentane
72.05 0.13%
0.0908 0.47% 0.51%
n -Hexane
86.06 0,08%
0.0654 0.34% 0.37%
Other Hexanes
86.06 0.11 %
0.0921 0.48% 0.52%
Heptanes
100.07 0.06%
0.0580 0.30% 0.33%
Octanes +
114.08 0.04%
0.0445 0.23% 0.25%
Benzene
78.1 0.01%
0.0102 0.05% 0.06%
Toluene
92.1 0.02%
0.0184 0.10% 0.10%
Ethylbenzene
106.2 0.00%
0.0011 0.01% 0.01%
Xylenes
106.2 0.01%
0.0085 0.04% 0.05%
Total NMNE VOC
3.54%
10.04% 10.79%
Carbon Dioxide
43.99 2.96%
1.3012 6.80% NA
Nitrogen
28.02 0.10%
0.0283 0.15% NA
Hydrogen Sulfide
34.06 0.00%
0.0000 0.00% NA
Water
18 0.00%
0.0000 0.00% NA
Helium
4.00 0.01%
0.0002 0.00% NA
Totals 100.0%
19.1366 100.00% 100.00%
' Weight Fraction corrected to remove Carbon Dioxide,Nitrogen, 112S, and Helium content.
10/18/2006 Webster Hill
Attachment 4
SCREEN3 Dispersion Modeling Summary
OCTOBER 2006 - WEBSTER HILL COMPRESSOR STATION
Webster Hill Compressor Station
Modeled Source Inputs to Determine Compliance
with the NO2 Annual National Ambient Mr Quality Standard
NO2 Emissions from Engines ENG -01 -ENG -04 (w/SCO)
Emission Rate
Engines 1-4.• 24.0 tpy NO, Q 0.7 gfbhp-hr
Colorado Default NO2/N0, = 0.75 Per Section 4.1.1.3 Colorado Modeling Guidelines
Calculation of NO, Emission
- tpy NO, • 2000 Ib/ton "453.6 g/Ib " 1 yr/8760 hr * 1 hr/60 min • 1 min/60 sec * 0,75 NO2/NO,
Engine Stack Parameters
stack height (ft)
stack diam(ft)
velocity (ft/sec) --
Temp.
Temp. (deg F) =
Building Dimensions
height (ft) _
length (ft) =
width (ft)
0.69 g NO/sec * 0.75 0.52 g NO2/sec
24.00
220.00
60.00
28.0 - 8.53 meters
1.50 = 0.46 meters
221.3 = 67.44 meta/sac
858.0 = 458.9 deg. C = 732.0 deg K
7.32 meters
67.06 meters
= 18.29 meters
Distance t0 Nearest Property Boundary
approximate distance (ft)- 150.0 46 meters
Modeling Inputs
no complex or simple terrain
building downwasb
rural environment
full meteorology
automatic distance array of 10 to 1,000 meters
zero terrain height above stack base
Modeling Results
max. 1 -hr concentration/engine is 83.7 ug/m' NO2 at 65 meters
max. 1 -hr fenceline conefengine is 83.6 ug/m31402 at 46 meters
- conversion of 1 -hr concentration to annual concentration
83.7 * conversion factor 0.08 (see pg. 4-16 of SCREEN2 Users
Guide, Oct. 1992 version, EPA454/R-92-019)
83.7 • 0.08 6.70 ug/m2 NO2 annual average
10/15/2006
Webster RW
OCTOBER 2006 - WEBSTER HILL COMPRESSOR STATION
Webster Hill Compressor Station
Modeled Source Inputs to Determine Compliance
with the NO2 Annual National Ambient Air Quality Standard
NO2 Emissions from Engines ENG•05 (w/SCO)
Emission Rate
CAT 3516TALE - Engine 5 15.3 tpy NO, Q 1.5 g/bhp-hr
Colorado Default NO2/NO„ = 0.75 Per Section 4.1.1.3 Colorado Modeling Guidelines
Calculation of NO, Emission
= tpy NO„ " 2000 ib/ton "453.6 glib' 1 yr/8760 hr " 1 hr/60 min' t min/60 sec * 0.75 N01/N0,
Engine Stack Parameters
stack height (ft) _
stack diam(ft)
velocity (ft/sec) _
Temp, (deg F)
0.44 g NOJsec * 0.75 = 0.33 g NO2/sec
24.0 = 7.32 meters
1.00 = 0.30 meters
89.9 = 27.39 meter/sec
864.0 462.2 deg. C = 735.4 deg K
Building Dimensions
height (ft) = 20.00 = 6.10 meters
length (ft) = 60.00 = 18.29 meters
width (ft) = 30.00 = 9.14 meters
Distance to Nearest Property Boundary
approximate distance Op= 150,0 = 46 meters
Modeling !nuts
no complex or simple terrain
building downwash
rural environment
full meteorology
automatic distance array of 10 to 1,000 meters
zero terrain height above stack base
Modeling Results
max. 1 -hr concentration/engine is 168.5 ug/m3 NO2 at 37 meters
max. 1 -hr fenceline conc./engine is 165.0 ug/m3 NO2 at 46 meters
- conversion of 1 -hr concentration to annual concentration
165.0 * conversion factor 0.08 (see pg. 4-16 of SCREEN2 Users
Guide, Oct. 1992 version, EPA -454/R-92-019)
165.0 * 0.08 = 13.20 up/mi NO2 annual average
10/18/1006
Webster Itlll
OCTOBER 2006 - WEBSTER HILL COMPRESSOR STATION
Webster HIB Compressor Station
Modeled Source Impacts to Verify
Compliance with NO2 NAAQS
Summary of Maximum Combined NO2 Ambient Air Quality
hnpacts at the Property Boundary
Emission Max. ]-Hr Annual Ave.
Source (ug/m3 NO,'Jug/m3 N04
ENG -01 83.7 6.70
ENG -02 83.7 6.70
ENG -03 83.7 6.70
ENG -04 83.7 6.70
ENG -05 165.0 13.20
TOTAL 499.96 40,00
Background NA 7.50
Tot.+Bkgnd NA 47.50
Standard NA 100.00
10/18/2006 Webster_11111
10/02/06
09:55:10
*** SCREENS MODEL RUN ***
*** VERSION DATED 96043 ***
Webster Hill Compressor Station
a -sk - E1.16K
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (GIS) _ .520000
STACK HEIGHT (M) = 8.5300
STK INSIDE DIAM (M) _ .4600
STK EXIT VELOCITY (M/S)= 67.4000
STK GAS EXIT TEMP (K) = 732.0000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) = .0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 7.3200
MIN HORIZ BLDG DIM (M) = 18.3000
MAX HORIZ BLDG DIM (M) = 67.0000
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.
BUOY. FLUX = 20.969 M**4/S**3; MOM. FLUX = 96.190 M**4/S**2.
*** FULL METEOROLOGY ***
**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC U1OM USTX MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
10. .2232E-15 6 1.0 1.0 10000.0 76.54 8.18 8.17 140
100. 70.25 4 15.0 15.0 4800.0 9.74 8.20 6.74 SS
200. 34.36 4 15.0 15.0 4800.0 12.18 15.56 10.43 SS
300. 19.83 4 15.0 15.0 4800.0 14.81 22.61 13.56 SS
400. 14.56 4 15.0 15.0 4800.0 15.54 29.45 16.66 SS
500. 11.37 4 15.0 15.0 4800.0 15.54 36.15 19.63 SS
600. 9.971 4 10.0 10.0 3200.0 23.43 42.72 21.76 SS
700. 8.690 4 10.0 10.0 3200.0 23.43 49.19 24.57 SS
800. 7.557 4 8.0 8.0 2560.0 29.58 55.57 26.84 SS
900. 6.856 4 8.0 8.0 2560.0 29.58 61.88 29.52 SS
1000. 6.188 4 8.0 8.0 2560.0 29.58 68.13 32.09 SS
MAXIMUM 1 -HR CONCENTRATION AT OR BEYOND 10. M:
65. 83.74 4 15.0 15.0 4800.0 9.10 5.58 5.24 SS
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
*********************************
*** SCREEN DISCRETE DISTANCES ***
*********************************
*** TERRAIN HEIGHT OF
DIST
(M)
0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
CONC UIOM USTK MIX HT PLUME SIGMA SIGMA
(UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
46. 83.59 4 20.0 20.0 6400.0 8.71 3.99 4.80 SS
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
****************************************
*** REGULATORY (Default) ***
PERFORMING CAVITY CALCULATIONS
WITH ORIGINAL SCREEN CAVITY MODEL
(ERODE, 1988)
****************************************
*** CAVITY CALCULATION -
CONC (UG/M**3) _
CRIT WS 010M (M/S) =
CRIT WS 8 HS (M/S)
DILUTION WS (M/S) =
CAVITY HT (M) _
CAVITY LENGTH (M) =
ALONGWIND DIM (M) =
1 ***
.0000
99.99
99.99
99.99
7.77
35.66
18.30
*** CAVITY CALCULATION -
CONC (UG/M**3) _
CRIT WS 010M (M/S) =
CRIT WS B HS (M/S) =
DILUTION WS (M/S)
CAVITY HT (M)
CAVITY LENGTH (M)
ALONGWIND DIM (M)
CAVITY CONC NOT CALCULATED FOR CRIT WS > 20.0 M/S.
****************************************
END OF CAVITY CALCULATIONS
****************************************
***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************
CALCULATION
PROCEDURE
MAX CONC
(UG/M**3)
SIMPLE TERRAIN 83.74
DIST TO TERRAIN
MAX (M) HT (M)
65. 0.
***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************
2 ***
.0000
99.99
99.99
99.99
7.32
19.71
67.00
CONC SET = 0.0
10/12/06
12:39:30
• *** SCREEN3 MODEL RUN ***
*** VERSION DATED 96043 ***
Webster Hill Generators
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) _ .330000
STACK HEIGHT (M) = 7.3200
STK INSIDE DIAM (M) _ .3000
STK EXIT VELOCITY (M/S)= 27.3900
STK GAS EXIT TEMP (K) = 735.0000
AMBIENT AIR TEMP (R) = 293.0000
RECEPTOR HEIGHT (M) _ .0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 6.1000
MIN HORIZ BLDG DIM (M) = 9.1400
MAX HORIZ BLDG DIM (M) = 18.2900
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.
BUOY. FLUX = 3.634 M**4/S**3; MOM. FLUX = 6.729 M**4/S**2.
*** FULL METEOROLOGY ***
*********************.************r
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC U1OM USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
10. .0000 1 1.0 1.0 320.0 63.71 4.68 3.63 NO
100. 101.4 4 8.0 8.0 2560.0 8.84 8.20 6.82 SS
200. 57.66 4 5.0 5.0 1600.0 12.97 15.56 9.87 SS
300. 43.45 4 5.0 5.0 1600.0 12.97 22.61 13.06 SS
400. 33.60 4 4.0 4.0 1280.0 16.09 29.45 15.86 SS
500. 27.35 4 3.5 3.5 1120.0 18.41 36.15 18.66 SS
600. 23.07 4 3.0 3.0 960.0 21.55 42.72 21.31 SS
700. 19.83 4 2.5 2.5 800.0 25.96 49.19 24.03 SS
800. 17.65 4 2.5 2.5 800.0 25.96 55.57 26.78 SS
900. 15.64 4 2.0 2.0 640.0 32.57 61.88 29.47 SS
1000. 14.35 4 2.0 2.0 640.0 32.57 68.13 32.09 SS
MAXIMUM 1 -HR CONCENTRATION AT OR BEYOND 10. M:
37. 168.5 4 8.0 8.0 2560.0 7.58 3.34 4.05 55
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
*********************************
*** SCREEN DISCRETE DISTANCES ***
*********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC
(M) (UG/M**3)
46. 165.0
MASH=
DWASH=NO
DWASH=HS
DWASH=SS
DWASH=NA
MEANS
MEANS
MEANS
MEANS
MEANS
U10M USTK MIX HT
STAB (M/S) (M/S) (M)
4 8.0 8.0 2560.0
NO CALC MADE (CONC = 0.0)
NO BUILDING DOWNWASH USED
HUBER-SNYDER DOWNWASH USED
SCHULMAN-SCIRE DOWNWASH USED
DOWNWASH NOT APPLICABLE, X<3*LB
****************************************
*** REGULATORY (Default) ***
PERFORMING CAVITY CALCULATIONS
WITH ORIGINAL SCREEN CAVITY MODEL
(BRODE, 1988)
****************************************
*** CAVITY CALCULATION
CONC (UG/M**3)
CRIT WS 010M (M/S) =
CRIT WS 0 HS (M/S)
DILUTION WS (M/S)
CAVITY HT (14)
CAVITY LENGTH (M)
ALONGWIND DIM (M)
1 ***
.0000
99.99
99.99
99.99
7.49
16.72
9.14
CAVITY CONC NOT CALCULATED FOR CRIT WS
PLUME SIGMA SIGMA
HT (M) Y (M) Z (M) DWASH
7.69 3.99 4.44 SS
*** CAVITY CALCULATION - 2 ***
CONC (UG/M**3) = .0000
CRIT WS 010M (M/S)
CRIT WS 4 HS (M/S)
DILUTION WS (M/S)
CAVITY HT (M)
CAVITY LENGTH (M)
ALONGWIND DIM (M)
99.99
99.99
99.99
6.30
11.64
18.29
> 20.0 M/S. CONC SET = 0.0
*******************************M*******#
END OF CAVITY CALCULATIONS
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************
CALCULATION
PROCEDURE
SIMPLE TERRAIN
MAX CONC DIST TO TERRAIN
(UG/M**3) MAX (M) HT (14)
168.5 37. 0.
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **