DAQ-2025-002564

DAQE-AN111680016-25

{{$d1 }}

Kirt Rasmussen
Urban Oil and Gas Group, LLC
1000 East 14th Street
Plano, TX 75074
[e-mail]

Dear Mr. Rasmussen:

Re: Approval Order: Administrative Amendment to Approval Order DAQE-AN111680015-22 for
Replacement-In-Kind of One (1) Compressor Engine
Project Number: N111680016

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on March 14,
2025. Urban Oil and Gas Group, LLC must comply with the requirements of this AO, all applicable state
requirements (R307), and Federal Standards.

The project engineer for this action is Mr. Tim DeJulis, who can be contacted at [phone] or
[e-mail]. Future correspondence on this AO should include the engineer's name as well as the
DAQE number shown on the upper right-hand corner of this letter.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:TD:jg

cc: Southeastern Utah District Health Department

195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Tim Davis
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

May 21, 2025

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

{{#s=Sig_es_:signer1:signature}}
{{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}}
{{#d2=date1_es_:signer1:date:format(date, "mmmm d, yyyy"):align(center)}}

APPROVAL ORDER
DAQE-AN111680016-25
Administrative Amendment to Approval Order
DAQE-AN111680015-22 for Replacement-In-Kind of
One (1) Compressor Engine

Prepared By
Mr. Tim DeJulis, Engineer
[phone]
[e-mail]

Issued to
Urban Oil and Gas Group, LLC - Helper Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

May 21, 2025
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 4
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ..................................................................................................................... 8
ACRONYMS ................................................................................................................................. 9

DAQE-AN111680016-25
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Urban Oil and Gas Group, LLC Urban Oil and Gas Group, LLC - Helper Station

Mailing Address Physical Address
1000 East 14th Street 3 miles north-east of Price
Plano, TX 75074 Helper, UT 84526

Source Contact UTM Coordinates
Name: Kirt Rasmussen 518,300 m Easting
Phone: [phone],387,750 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 1311 (Crude Petroleum & Natural Gas)

SOURCE INFORMATION
General Description
Urban Oil and Gas Group, LLC (Urban), owns and operates the Helper Station, a natural gas compressor
station northeast of Price in Carbon County. The station operates natural gas compressor engines that
allow for the transfer of natural gas through pipelines to downstream operations and eventual distribution
to customers.

NSR Classification
Administrative Amendment

Source Classification
Located in Attainment Area
Carbon County
Airs Source Size: SM

Applicable Federal Standards
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

DAQE-AN111680016-25
Page 4

Project Description
Urban has requested a replacement-in-kind to AO DAQE-AN111680015-22, dated March 23, 2022, for
one (1) of the compressor engines rated 1,340 hp (de-rated to 1,206 hp for operation). The engine
qualifies for a replacement-in-kind as per the requirements of R307-401-11. No changes were made to the
limits on the compressor engines.

SUMMARY OF EMISSIONS

The emissions listed below are an estimate of the total potential emissions from the source. Some
rounding of emissions is possible.

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent 0 45171.00
Carbon Monoxide 0 93.40
Nitrogen Oxides 0 98.99
Particulate Matter - PM10 0 0.44
Particulate Matter - PM2.5 0 0.44
Volatile Organic Compounds 0 27.08

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 680
Acrolein (CAS #107028) 0 680
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 1120
Formaldehyde (CAS #50000) 0 18640
Generic HAPs (CAS #GHAPS) 0 900
Hexane (CAS #110543) 0 40
Toluene (CAS #108883) 0 2500
Xylenes (Isomers And Mixture) (CAS #1330207) 0 7340
Change (TPY) Total (TPY)
Total HAPs 0 15.95

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101]
I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1]
DAQE-AN111680016-25
Page 5

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8] I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to
the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]

I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]
I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]

I.8 The owner/operator shall submit documentation of the status of construction or modification to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT
II.A THE APPROVED EQUIPMENT II.A.1 Helper Station Natural Gas Compressor Station
II.A.2 Compressor Engines Four (4) Internal Combustion (IC) Compressor Engines (One (1) new) Manufacturer Rated Horsepower: 1,340 derated to 1,206 Fuel Type: Natural Gas Stack Height (above ground): minimum 24 feet (modeling requirement) II.A.3 Tri-ethylene Glycol Unit One (1) Tri-ethylene Glycol Dehydration Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 1.5 MMBTU/hr
II.A.4 Di-ethylamine (DEA) Unit One (1) Di-ethylamine (DEA) Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 4.4 MMBTU/hr
DAQE-AN111680016-25
Page 6

II.A.5 Di-ethylamine (DEA) Unit One (1) Di-ethylamine (DEA) Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 7.33 MMBTU/hr
II.A.6 One (1) Emergency Vent (Not Flared)
II.A.7 Electric Compressor One (1) Electrically Powered Natural Gas Compressor Note: Listed for informational purposes only and produces no emissions.

SECTION II: SPECIAL PROVISIONS II.B REQUIREMENTS AND LIMITATIONS
II.B.1 Site-wide Requirements
II.B.1.a The owner/operator shall not allow visible emissions from the following emission points to exceed the following values: A. All emergency vent stacks - 0% opacity B. All natural gas-fired compressors - 5% opacity C. All boiler exhaust stacks - 10% opacity D. All other points - 20% opacity. [R307-401-8]
II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8]

II.B.1.b The owner/operator shall use only pipeline-grade natural gas as fuel. [R307-401-8]
II.B.1.c The owner/operator shall not vent more than 200 million scf of natural gas to the atmosphere per
rolling 12-month period. The natural gas shall not be flared. [R307-401-8]
II.B.1.c.1 The owner/operator shall: A. Determine the amount of vented natural gas with the use of a flowmeter B. Record the amount of natural gas vented on a monthly basis C. Use the production data to calculate a new rolling 12-month total by the 20th day of each month using data from the previous 12 months D. Keep the records of natural gas venting for all periods the plant is in operation. [R307-401-8]
DAQE-AN111680016-25
Page 7

II.B.1.d The owner/operator shall not emit more than the following rates and concentrations from each 1206 hp IC Compressor Engine: Pollutant lb/hr g/bhp-hr NOx 5.32 2.00 CO 5.05 1.90 [R307-401-8] II.B.1.d.1 Compliance Demonstration
To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained in this AO. [R307-165-2, R307-401-8]

II.B.1.d.2 Initial Test The owner/operator shall conduct an initial stack test on the emission unit within 180 days after startup of the emission unit. [R307-165-2] II.B.1.d.3 Test Frequency
The owner/operator shall conduct a stack test on the emission unit within five (5) years after the
date of the most recent stack test of the emission unit, using methods 10 and 7E set forth in 40 CFR 60 Appendix A, or within two (2) years of the most recent stack test of the emission unit
using a portable analyzer. If methods 10 and 7E are used, test results shall be the average of three
(3) 30-minute test runs. Volumetric flow rate shall be determined stoichiometrically. The Director may require the owner/operator to perform a stack test at any time. [R307-165-2, R307-
401-8]

II.B.2 Stack Testing Requirements II.B.2.a The owner/operator shall conduct any stack testing required by this AO according to the
following conditions. [R307-401-8]

II.B.2.a.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8]
II.B.2.a.2 Testing & Test Conditions The owner/operator shall conduct testing according to the approved source test protocol and
according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]

II.B.2.a.3 Access The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or Mine Safety and Health Administration (MSHA)-approved access to the test location. [R307-401-8]
II.B.2.a.4 Reporting
No later than 60 days after completing a stack test, the owner/operator shall submit a written
report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8]

II.B.2.a.5 Possible Rejection of Test Results The Director may reject stack testing results if the test did not follow the approved source test protocol or for a reason specified in R307-165-6. [R307-165-6, R307-401-8]
DAQE-AN111680016-25
Page 8

II.B.2.b Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed below. [R307-401-8]
II.B.2.b.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K)
B. Pressure - 29.92 in Hg (101.3 kPa)
C. Averaging Time - As specified in the applicable test method. [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]

II.B.2.b.2 NOx 40 CFR 60, Appendix A, Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.b.3 CO
40 CFR 60, Appendix A, Method 10, or other EPA-approved testing method as acceptable to the
Director. [R307-401-8]
II.B.2.b.4 IC Engines Portable testing monitors may be used to test IC engines. If portable monitors are to be used, they shall be calibrated according to the manufacturer's recommendations prior to any test. Also, the portable monitor's operation and testing time shall be in accordance with manufacturer's recommendations. [R307-401-8]
PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN111680015-22 dated March 23, 2022 Is Derived From NOI dated March 14, 2025

DAQE-AN111680016-25
Page 9

ACRONYMS

The following lists commonly used acronyms and associated translations as they apply to this document:

40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by Environmental Protection Agency to classify
sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98,
Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal Division of Air Quality use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i)
GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818-
12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

DAQE-

RN111680016 May 15, 2025 Kirt Rasmussen Urban Oil and Gas Group, LLC 1000 E 14th St
Plano, TX 75074 [e-mail]
Dear Kirt Rasmussen, Re: Engineer Review - Administrative Amendment to DAQE-AN111680015-22 for
Replacement-In-Kind of One Compressor Engine Project Number: N111680016 The DAQ requests a company representative review and sign the attached Engineer Review (ER). This ER identifies all applicable elements of the New Source Review (NSR) permitting program. Urban Oil and Gas Group, LLC should complete this review within 10 business days of receipt. Urban Oil and Gas Group, LLC should contact Mr. Tim DeJulis at [phone] if there are questions or concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email Mr. Tim DeJulis at [e-mail] the signed cover letter. Upon receipt of the signed cover letter, the DAQ will prepare an Approval Order (AO) for signature by the DAQ Director.
If Urban Oil and Gas Group, LLC does not respond to this letter within 10 business days, the project will move forward without source concurrence. If Urban Oil and Gas Group, LLC has concerns that cannot
be resolved and the project becomes stagnant, the DAQ Director may issue an Order prohibiting construction.
Approval Signature _____________________________________________________________ (Signature & Date)
195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
Department of Environmental Quality
Tim Davis Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director
State of Utah
SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION
Project Number N111680016 Owner Name Urban Oil and Gas Group, LLC Mailing Address 1000 E 14th St
Plano, TX, 75074 Source Name Urban Oil and Gas Group, LLC - Helper Station (prev.
Castlegate) Source Location 3 miles north-east of Price Helper, UT 84526
UTM Projection 518,300 m Easting, 4,387,750 m Northing UTM Datum NAD83 UTM Zone UTM Zone 12 SIC Code 1311 (Crude Petroleum & Natural Gas) Source Contact Kirt Rasmussen Phone Number [phone] Email [e-mail] Billing Contact Kirt Rasmussen
Phone Number [phone] Email [e-mail]
Project Engineer Mr. Tim DeJulis, Engineer Phone Number [phone] Email [e-mail]
Notice of Intent (NOI) Submitted March 14, 2025 Date of Accepted Application March 18, 2025

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 2
SOURCE DESCRIPTION General Description
Urban Oil and Gas Group, LLC, (Urban) owns and operates the Helper Station, a natural gas compressor station, north-east of Price in Carbon County. The station operates natural gas compressor engines that allow for the transfer of natural gas through pipelines to downstream
operations and eventual distribution to customers. NSR Classification: Administrative Amendment Source Classification Located in Attainment Area Carbon County Airs Source Size: SM Applicable Federal Standards
MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
Project Proposal Administrative Amendment to DAQE-AN111680015-22 for Replacement-In-Kind of One
Compressor Engine Project Description Urban has requested a replacement-in-kind to DAQE-AN111680015-22, dated March 23, 2022 for one of the compressor engines rated 1,340 hp (de-rated to 1,206 hp for operation). The engine qualifies for a replacement-in-kind as per the requirements of R307-401-11. No changes were
made to the limits on the compressor engines. EMISSION IMPACT ANALYSIS
This is an administrative amendment that does not increase or decrease emissions at the facility. Therefore, modeling is not required per R307-410-4 and R307-410-5. [Last updated March 18, 2025]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 3
SUMMARY OF EMISSIONS
The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible.
Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent 0 45171.00 Carbon Monoxide 0 93.40
Nitrogen Oxides 0 98.99
Particulate Matter - PM10 0 0.44
Particulate Matter - PM2.5 0 0.44
Volatile Organic Compounds 0 27.08
Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Acetaldehyde (CAS #75070) 0 680
Acrolein (CAS #107028) 0 680
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 1120
Formaldehyde (CAS #50000) 0 18640
Generic HAPs (CAS #GHAPS) 0 900
Hexane (CAS #110543) 0 40 Toluene (CAS #108883) 0 2500 Xylenes (Isomers And Mixture) (CAS #1330207) 0 7340
Change (TPY) Total (TPY)
Total HAPs 0 15.95

Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 4
Review of BACT for New/Modified Emission Units 1. BACT review regarding BACT
This is an administrative amendment that is a replacement-in-kind for existing equipment. As there are no new sources of emissions or changes in emission rates, a BACT analysis is not required. [Last updated April 2, 2025]

SECTION I: GENERAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1]
I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8]
I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source.
All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]
I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107] I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 5
I.8 The owner/operator shall submit documentation of the status of construction or modification to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is
discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.A THE APPROVED EQUIPMENT
II.A.1 Helper Station Natural Gas Compressor Station

II.A.2 Compressor Engines Four (4) Internal Combustion (IC) Compressor Engines (One new) Manufacturer Rated Horsepower: 1,340 derated to 1,206 Fuel Type: Natural Gas Stack Height (above ground): minimum 24 feet (modeling requirement)
II.A.3 Tri-ethylene Glycol Unit One (1) Tri-ethylene Glycol Dehydration Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 1.5 MMBTU/hr II.A.4 Di-ethylamine (DEA) Unit One (1) Di-ethylamine (DEA) Unit with Natural Gas-fired Boiler
Maximum Boiler Rating: 4.4 MMBTU/hr

II.A.5 Di-ethylamine (DEA) Unit One (1) Di-ethylamine (DEA) Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 7.33 MMBTU/hr II.A.6 One (1) Emergency Vent (Not Flared)
II.A.7 Electric Compressor One (1) Electrically Powered Natural Gas Compressor
Note: Listed for informational purposes only and produces no emissions.

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 6
SECTION II: SPECIAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.B REQUIREMENTS AND LIMITATIONS
II.B.1 The Helper CPF Natural Gas Fired Compressor Station shall be subject to the following:
II.B.1.a The owner/operator shall not allow visible emissions from the following emission points to
exceed the following values: A. All emergency vent stacks - 0% opacity B. All natural gas-fired compressors - 5% opacity
C. All boiler exhaust stacks - 10% opacity D. All other points - 20% opacity. [R307-401-8] II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8]

II.B.1.b The owner/operator shall use only pipeline-grade natural gas as fuel. [R307-401-8]
II.B.1.c The owner/operator shall not vent more than 200 million scf of natural gas to the atmosphere per rolling 12-month period. The natural gas shall not be flared. [R307-401-8]
II.B.1.c.1 The owner/operator shall:
A. Determine the amount of vented natural gas with the use of a flowmeter B. Record the amount of natural gas vented on a monthly basis C. Use the production data to calculate a new rolling 12-month total by the 20th day of each month using data from the previous 12 months D. Keep the records of natural gas venting for all periods the plant is in operation. [R307-401-8]

II.B.1.d The owner/operator shall not emit more than the following rates and concentrations from each 1206 hp IC Compressor Engine: Pollutant lb/hr g/bhp-hr NOx 5.32 2.00 CO 5.05 1.90. [R307-401-8]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 7
II.B.1.d.1 Compliance Demonstration To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained
in this AO. [R307-165-2, R307-401-8] II.B.1.d.2 Initial Test The owner/operator shall conduct an initial stack test on the emission unit within 180 days after startup of the emission unit. [R307-165-2]
II.B.1.d.3 Test Frequency The owner/operator shall conduct a stack test on the emission unit within five years after the date of the most recent stack test of the emission unit, using methods 10 and 7E set forth in 40 CFR 60 Appendix A or within two years (2) of the most recent stack test of the emission unit using a portable analyzer. If methods 10 and 7E are used, test results shall be the average of three 30-minute test runs. Volumetric flow rate shall be determined stoichiometrically. The Director may require the owner/operator to perform a stack test at any time. [R307-165-2, R307-401-8]
II.B.2 Stack Testing Requirements
II.B.2.a The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8] II.B.2.a.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8]
II.B.2.a.2 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol and according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]
II.B.2.a.3 Access
The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or Mine Safety and Health Administration (MSHA)-approved access to the test location. [R307-401-8]

II.B.2.a.4 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8] II.B.2.a.5 Possible Rejection of Test Results The Director may reject stack testing results if the test did not follow the approved source test protocol or for a reason specified in R307-165-6. [R307-165-6, R307-401-8]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 8
II.B.2.b Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed
below. [R307-401-8] II.B.2.b.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K)
B. Pressure - 29.92 in Hg (101.3 kPa)
C. Averaging Time - As specified in the applicable test method [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]
II.B.2.b.2 NOx
40 CFR 60, Appendix A, Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8]
II.B.2.b.3 CO 40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.b.4 Internal Combustion (IC) Engines Portable testing monitors may be used to test IC engines. If portable monitors are to be used, they shall be calibrated according to the manufacturer's recommendations prior to any test. Also, portable monitor's operation and testing time shall be in accordance with manufacturer's recommendations. [R307-401-8]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 9
PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the
following documents: Supersedes DAQE-AN111680015-22 dated March 23, 2022
Is Derived From Replacement-in-Kind Notice dated March 18, 2025
REVIEWER COMMENTS

1. Comment regarding NSPS and MACT Review: 40 CFR 60 Subpart JJJJ applies to "owners and operators of stationary spark ignition (SI) internal combustion engines (ICE) as specified in paragraphs (a)(1) through (6) of this section" that were constructed after the applicability date listed in each of the referenced paragraphs. The four compressor engine are natural gas fired and are lean burn engines with "a maximum engine power greater than or equal to 500 HP and less than 1,350 HP." However, these compressor engines were constructed prior to the applicability date of January 1st, 2008. Therefore, this subpart is not applicable to the facility. 40 CFR 63 Subpart ZZZZ applies to owners and operators of "stationary RICE at a major or area source of HAP emissions..." The facility operates multiple stationary RICE as defined by this
subpart, therefore, this subpart is applicable to the compressor engines. The owner/operator must follow the applicable requirements of this subpart, listed in table 2d (8) of this subpart. These requirements include: 1. Change oil and filter every 2,160 hours of operation or annually, whichever comes first; 2. Inspect spark plugs every 2,160 hours of operation or annually, whichever comes first, and replace as necessary; and 3. Inspect all hoses and belts every 2,160 hours of operation or annually, whichever comes first, and replace as necessary. [Last updated April 2, 2025]
2. Comment regarding Title V Review: Title V of the 1990 Clean Air Act (Title V) applies to the following:
1. Any major source 2. Any source subject to a standard, limitation, or other requirement under Section 111 of the Act, Standards of Performance for New Stationary Sources; 3. Any source subject to a standard or other requirement under Section 112 of the Act, Hazardous Air Pollutants. 4. Any Title IV affected source. This facility is not a major source and is not a Title IV source. The facility is not subject to 40 CFR 60 (NSPS) or 40 CFR 61 (NESHAP) regulations. The facility is subject to 40 CFR 63 Subpart ZZZZ (MACT) regulations. MACT subpart ZZZZ exempts sources from the obligation to obtain a permit under a Title V permit, if the source is not otherwise required by law to obtain a permit. There are no other reasons why this source would be required to obtain a part 70 permit; therefore, Title V does not apply to this facility. [Last updated April 2, 2025]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 10
3. Comment regarding Evaluation of Replacement-in-Kind: To qualify as a replacement-in-kind, the replacement compressor engines must meet the following
criteria from R307-401-11: (a) the potential to emit of the process equipment is the same or lower - The engine have the same rating as the engine being replaced, and will comply with the same enforceable emission limits as the previous equipment.
(b) the number of emission points or emitting units is the same or lower - The number of emitting units will remain the same as one existing engine is being replaced with one new engine.
(c) no additional types of air pollutants are emitted as a result of the replacement - No additional air
pollutants are being emitted as a result of this replacement, as the engine ratings and fuel type are the same. (d) the process equipment or pollution control equipment is identical to or functionally equivalent to the replaced equipment - The engines is identical/functionally equivalent to the replaced equipment,
and will meet the same emission limits and use the same pollution control methods
(e) the replacement does not change the basic design parameters of the process unit or pollution control equipment - No changes are being made to the process equipment or any pollution controls. (f) the replaced process equipment or pollution control equipment is permanently removed from the stationary source, otherwise permanently disabled, or permanently barred from operation - The engine being replaced will be removed from the facility prior to the installation of the replacement
engine. (g) the replacement process equipment or pollution control equipment does not trigger New Source Performance Standards or National Emissions Standards for Hazardous Air Pollutants under 42 U.S.C. 7411 or 7412 - The replacement equipment will be subject to the same NSPS and NESHAP
or MACT standards as the previous equipment, therefore no additional standards under 42 U.S.C 7411 or 7412 will be applicable. (h) the replacement of the control apparatus or process equipment does not violate any other provision of Title R307 - This replacement does not violate any other provisions under UAC R307. Therefore, the installation of the one replacement compressor engine qualifies as a replacement-in-kind under R307-401-11. No changes to the equipment list are necessary as a result of this action. [Last updated May 15, 2025]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 11
ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document:
40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology
CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by EPA to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1 COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal UDAQ use EPA Environmental Protection Agency
FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i) GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/HR Pounds per hour
LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units
NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit
R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year
UAC Utah Administrative Code VOC Volatile organic compounds

March 13th, 2025 Bryce Bird, Director
Utah Department of Environmental Quality Division of Air Quality P.O. Box 144820 Salt Lake City, UT 84114 RE: Written Notification of Engine Replacement-in-Kind
Urban Oil and Gas Group, L.L.C. Helper #1 Station

Dear Mr. Bird,

Urban Oil and Gas Group, L.L.C. (Urban) is the owner/operator of the Helper #1 Station that is
permitted and operating under Approval Order (AO) No. DAQE-AN111680012-14. Urban
intends to implement a Replacement-in-Kind of one of the four existing compressor engines at
the Helper #1 Station. In accordance with the conditions set forth in Utah Code R307-401-11 (2)
Replacement-in-Kind Procedures (a) and (b), Urban is submitting this “written notification to the
director before replacing the equipment”, that “contains a description of the replacement-in-kind
equipment, including control capability of any control apparatus and a demonstration that the
conditions of R307-401-11 (1) are met.”

Description of the Replacement-in-Kind
Urban plans to replace one of the existing four Caterpillar G3516 TALE compressor engines at
the Helper #1 Station with an engine of the same make and model, and equipped with the same
ADEM3 air-fuel ratio control apparatus. The replacement engine will be of the same
configuration and will have the same specifications and emission limits of the engine being
replaced. A completed Form 11 Internal Combustion Engines for the replacement engine is
attached to this written notification. Also included is a diagram showing the location of the
planned engine replacement at the Helper #1 Station.

All existing engines at the Helper #1 Station are subject to 40 CFR Part 60 Subpart JJJJ, as is the
replacement engine. They are required to have initial compliance tests and be tested every five
years. The replacement engine will adhere to the same testing requirements as the existing
engines at the facility.

Demonstration of Compliance with R307-401-11 (1) (a through h)
R307-401-11 (1) (a): The potential to emit of process equipment is the same or lower
The potential to emit for the replacement engine is equal to the potential to emit for the engine
being replaced.
R307-401-11 (1) (b): The number of emission points or emitting units is the same or lower

The number of emission units at the Helper #1 Station will remain the same.
R307-401-11 (1) (c): No additional types of air contaminants are emitted as a result of the
replacement
No additional types of air contaminants will be emitted as a result of the engine replacements.
R307-401-11 (1) (d): The process equipment or pollution control equipment is identical to or
fully functionally equivalent to the replaced equipment
The replacement engine and associated pollution control equipment are identical to and/or
functionally equivalent to that of the replaced equipment.
R307-401-11 (1) (e): The replacement does not change the basic design parameters of the
process unit or pollution control equipment
The replacement engine and associated pollution control equipment do not change the basic
parameters of the process unit or pollution control equipment.
R307-401-11 (1) (f): The replaced process equipment or pollution control equipment is
permanently removed from the stationary source, otherwise permanently
disabled or permanently barred from operation
The replaced engine and associated pollution control equipment will be removed permanently
from the Helper #1 Station prior to installation of the replacement engine and associated
pollution control equipment.
R307-401-11 (1) (g): The replaced process equipment or pollution control equipment does not
trigger New Source Performance Standards or National Emission
Standards for Hazardous Air Pollutants under 42 U.S.C. 7411 or 7412
The replacement engine and associated pollution control equipment are subject to the same
regulatory applicability as the replaced engine and associated pollution control equipment. As
such, neither New Source Performance Standards nor National Emission Standards for
Hazardous Air Pollutants are triggered as a result of the Like-Kind engine replacement.
R307-401-11 (1) (h): The replacement of the control apparatus or process equipment does not
violate any other provision of Title R307
To the best of the Owner/Operator’s knowledge, the Like-Kind engine replacement does not
violate any other provision of Title R307.
Applicability of Replacement-in-Kind Guidelines DAQ-2017-018841
In accordance with the referenced Guidelines, and through the submittal of this written
notification, Urban understands that the Air Quality Division shall compare the information
contained in this notification to the AO for the Helper #1 Station to determine whether an update
to the source’s AO is necessary. Based on the information submitted herein, Urban believes that
the AO for the Helper #1 Station does not need to be updated and that the Air Quality Division

will place this written notification (modification) in the source file in accordance with the
referenced Guidelines. Urban will await confirmation from the Air Quality Division prior to
initiating the engine replacement described herein.

If you have any questions or need any additional information, please feel free to contact me at
[phone].

Sincerely,

Kirt Rasmussen
Urban Oil and Gas
6825 South 5300 West
Price, Utah 84501
Cell: [phone]

Attachment

Unit 1801 In-Kind Engine Replacement

Utah Division of Air Quality
New Source Review Section
Form 11
Company Urban Oil & Gas
Site/Source Helper #1 Station
Date March 13, 2025
Internal Combustion Engines
Equipment Information
1.Manufacturer: Caterpillar
Model no.: G3516TALE
The date the engine was reconstructed April/May 2025
2.Operating time of Emission Source:
maximum average
24 Hours/day
7 Days/week
52 Weeks/year
24 Hours/day
7 Days/week
52 Weeks/year
Kw 3.Manufacturer's rated output at baseload, ISO 1340 hp or
Proposed site operating range ________________ 1206 ________ hp or Kw
Gas Firing
4.Are you operating site equipment on pipeline quality natural gas: x Yes □ No
5.Are you on an interruptible gas supply:
□Yes x No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
______________57.4__________ MMSCF/Year
7. Maximum firing rate:
_______________7469______________ BTU/Hp-hr
8. Average firing rate:
_______________9.0______________MMBTU/hr
Oil Firing
9. Type of oil:
Grade number □ 1 □ 2 □ 4 □ 5 □ 6 Other specify ___________
10. Annual consumption: ______________ gallons 11. Heat content:______________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight 13. Ash content: ____________% by weight
14. Average firing rate: gal/hr 15. Maximum firing rate: gal/hr
16. Direction of firing: □ horizontal □ tangential □ other: (specify)
Page 1 of 4 
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17.Application:
□Electric generation
______ Base load ______ Peaking
□Emergency Generator
□x Driving pump/compressor
□Exhaust heat recovery
□Other (specify) ________________________
18.Cycle
□x Simple cycle
□Regenerative cycle
□Cogeneration
□Combined cycle
Emissions Data
19.Manufacturer’s Emissions in grams per hour (gr/hp-hr): ___2.0____ NOX ____1.9___ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection x Other (specify)__ADEM3 AFR__
□Other low-NOx combustor □SCR catalyst □Steam injection
Additional Information
21. On separate sheets provide the following:
A. Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and
model and manufacturer's information. Example details include: controller input variables and operational
algorithms for water or ammonia injection systems, combustion mode versus engine load for variable mode
combustors, etc.
B. Exhaust parameter information on attached form.
C. All calculations used for the annual emission estimates must be submitted with this form to be deemed
complete.
D. All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using
SCREEN3.
E. If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF EMISSION PT. (6) EXIT DATA
NUMBER NAME COMPONENT OR AIR CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
12 518308 4387739 30 12 1
CO
NOx 5.32
5.05
23.3
22.1
ENG-3
ENG-3
Facility Diagram

Prepared For:
Prepared By:
7/22/2021
Helper CPF #1
Latitude: 39.63995
Longitude: -110.78685
API #(s): NA
Carbon County, Utah
Legend
= Valve
= Prod. Water Tank
= Underground Flowline
= Surface Flowline
= Condensate Tank
Diagram Not To Scale
Flowline Locations Representative Only
NSCT = Non-SPCC Applicable Chem Tank
Urban Oil and Gas Group, LLC
Compressor (6)
Compressor (5)
Compressor (4)
Compressor (3)
Unit 1801 to be Swapped
Compressor (2)
Compressor (1)
500 GAL Oil-
Raised
resulting in no
tank footprint
Transformer Switchgear
Electric
Bertha
Starter
Work Shop Storage Shed
50 GAL
- NSCT
Slop
50 GAL - NSCT
Slop
Blow
Case
Blow Case
1000 GAL Lube Oilin 11.7'x8.25'x.58'
Containment
50 GAL - NSCT
Slop
Sumps
Glycol
Contactor
300 GAL
Anitfreeze
-NSCT
1000 GAL
Chemical Tank
500 GAL Lube Oil
in 7.5'x4.1'x2'Containment
Sales
Scrubber
Fuel
Scrubber
Gas
Cooler
400 BBL
Used
Oil
210
BBLLube
Oil
24
BBL
Used
Oil
400 BBL
Slop
Oil
500 GAL
Lube Oil-
Raised
resulting in no tank footprint
80 GAL
Chemical Tank
Truck
Loading
46.75'
9'
18.5'
84'
66'
75'
Steel Containment
Height= 2.25'
Amine
Reboiler Flash
Tank
Blow
Case
1500 GAL
Ucarsol AP Solvent
814- Raised resulting in no tank footprint
Still
1000 GAL DI Water - NSCT Tail Scrubber
Amine Contactor
(1) 1 BBL & (1) 35
GAL Antifoam - NSCT
Building
Meter
House
Sh
o
p
Scrubber
Scrubber
Yellow Plastic
Slop Drip Flare
Reflux Cooler Troughs Troughs
Amine/
Reflux Cooler
21' x 14'
Concrete Berm Height= 1.3'
Flash
Tank
Blo
w

Ca
s
e
Gly
c
o
l
Re
b
o
i
l
e
r
(2) 300 GAL
Triethylene Glycol-
NSCT
1000 GAL DI Water-
NSCT
Still
Metal Skid with Sump
Drain
Building
Tail Scrubber Contactor
Of
f
i
c
e
Bu
i
l
d
i
n
g
Amine
Reboiler
El
e
c
t
r
i
c
a
l

Bu
i
l
d
i
n
g
T
400
BBL
FW
Air
Compressor
Breaker
20 GAL
- NSCT
Slop Can
Building
Irregular Shaped Perimeter
Berm Area = 234,580 ft2
Earthen Berm Height = 1'
Fence
Tank Sizes
400 BBL = 12'D x 20'H
210 BBL = 10'D x 15'H
24 BBL = 10'D
500 GAL
Anitfreeze
-NSCT
Blow Case
Shown with Optional Equipment
CAT® ENGINE SPECIFICATIONS
V-16, 4-Stroke-CycleBore ................................170 mm (6.7 in.)Stroke ..............................190 mm (7.5 in.)Displacement .......................69 L (4210 cu. in.)Aspiration ...................Turbocharged-AftercooledDigital Engine Management Governor and Protection .....Electronic (ADEM™ A3)Combustion ................Low Emission (Lean Burn)Engine Weight, net dry (approx) .....8015 kg (17,670 lb)Power Density ...................8 kg/kW (13.2 lb/bhp)Power per Displacement ....................19.3 bhp/LTotal Cooling System Capacity .......217.7 L (57.5 gal) Jacket Water .......................200.6 L (53 gal)Aftercooler Circuit .......................17 L (4.5 gal)Lube Oil System (refill) .................424 L (112 gal)Oil Change Interval .......................1000 hoursRotation (from flywheel end) .........CounterclockwiseFlywheel and Flywheel Housing ............SAE No. 00Flywheel Teeth ..................................183
LEHW0036-00 Page 1 of 4Supersedes LEHW6046-02
G3516 LE Gas PetroleumEngine
858-999 bkW1150-1340 bhp1200-1400 rpm
2.0 g/bhp-hr NOx (NTE)
FEATURES
Engine Design- Proven reliability and durability - Ability to burn a wide spectrum of gaseous fuels - Robust diesel strength design prolongs life and lowers owning and operating costs- Broad operating speed range
EmissionsMeets U.S. EPA Spark Ignited Stationary NSPS Emissions for 2007/8
Lean Burn Engine TechnologyLean-burn engines operate with large amounts of excess air. The excess air absorbs heat during combustion reducing the combustion temperature and pressure, greatly reducing levels of NOx. Lean-burn design also provides longer component life and excellent fuel consumption.
Advanced Digital Engine ManagementADEM A3 control system providing integrated ignition, speed governing, protection, and controls, including detonation-sensitive variable ignition timing. ADEM A3 has improved: user interface, display system, shutdown controls, and system diagnostics.
Ease of OperationSide covers on block allow for inspection of internal components
Full Range of AttachmentsLarge variety of factory-installed engine attachments reduces packaging time
TestingEvery engine is full-load tested to ensure proper engine performance.
Gas Engine Rating Pro GERP is a PC-based program designed to provide site performance capabilities for Cat® natural gas engines for the gas compression industry. GERP provides engine data for your site’s altitude, ambient temperature, fuel, engine coolant heat rejection, performance data, installation drawings, spec sheets, and pump curves.
Product Support Offered Through Global Cat Dealer NetworkMore than 2,200 dealer outlets
Cat factory-trained dealer technicians service every aspect of your petroleum engine
Cat parts and labor warranty
Preventive maintenance agreements available for repair-before-failure options
S•O•SSM program matches your oil and coolant samples against Caterpillar set standards to determine:- Internal engine component condition- Presence of unwanted fluids- Presence of combustion by-products- Site-specific oil change interval
Over 80 Years of Engine Manufacturing ExperienceOver 60 years of natural gas engine production
Ownership of these manufacturing processes enables Caterpillar to produce high quality, dependable products.- Cast engine blocks, heads, cylinder liners, and flywheel housings- Machine critical components- Assemble complete engine
Web SiteFor all your petroleum power requirements, visit www.catoilandgas.cat.com.
G3516 LE GAS PETROLEUM ENGINE
858-999 bkW (1150-1340 bhp)
LEHW0036-00 Page 2 of 4Supersedes LEHW6046-02
Air Inlet SystemAir cleaner — intermediate-duty with service indicator
Control SystemA3 ECUAir-fuel ratio control
Cooling SystemThermostats and housingJacket water pumpAftercooler water pumpAftercooler core for sea-air atmosphereAftercooler thermostats and housing
Exhaust SystemWatercooled exhaust manifolds
Flywheels & Flywheel HousingsSAE No. 00 flywheelSAE No. 00 flywheel housingSAE standard rotation
Fuel SystemGas pressure regulatorNatural gas carburetor
Ignition SystemA3 ECU
InstrumentationPL1000 Advisor panel
Lubrication SystemCrankcase breather — top mountedOil coolerOil filter — RHOil bypass filterOil pan — shallowOil sampling valveTurbo oil accumulator
Mounting SystemRails, engine mounting — 254 mm (10 in)
Protection SystemElectronic shutoff systemGas shutoff valve
GeneralPaint — Cat yellowVibration damper and guard — dual 484 mm (23 in)
STANDARD EQUIPMENT
Air Inlet SystemRemote air inlet adaptersPrecleaner
Charging SystemBattery chargersCharging alternators
Cooling SystemAftercooler coreThermostatic valveTemperature switchConnectionsExpansion and overflow tankWater level switch gauge
Exhaust SystemFlexible fittingsElbowsFlangeFlange and exhaust expandersRain capMufflers
Fuel SystemLow pressure gas conversionsPropane gas valve and jet kitsFuel filter
InstrumentationPL1000 communications modules
Lubrication SystemOil bypass filter removal and oil pan accessoriesSump pumpAir prelube pumpManual prelube pumpLubricating oil
Mounting SystemRailsVibration isolators
Power Take-OffsFront accessory drivesAuxiliary drive shafts and pulleysFront stub shaftPulleys
Protection SystemExplosion relief valves, status control box interconnect wiring harness
Starting SystemAir starting motorAir pressure regulatorAir silencerElectric air start controlsElectric starting motors — dual 24-voltStarting aidsBattery sets (24-volt dry), cables, and rack
GeneralFlywheel intertia weightGuard removalEngine barring groupPremium 8:1 pistonsPremium cylinder heads
OPTIONAL EQUIPMENT
G3516 LE GAS PETROLEUM ENGINE
858-999 bkW (1150-1340 bhp)
LEHW0036-00 Page 3 of 4Supersedes LEHW6046-02
TECHNICAL DATA
G3516 LE Gas Petroleum Engine
Fuel System 2 g NOx NTE Rating 2 g NOx NTE Rating DM8618-01 DM8620-01
Engine Power @ 100% Load bkW (bhp) 999 (1340) 858 (1150) @ 75% Load bkW (bhp) 749 (1004) 643 (862)
Engine Speed rpm 1400 1200 Max Altitude @ Rated Torque and 38°C (100°F) m (ft) 304.8 (1000) 1219.2 (4000) Speed Turndown @ Max Altitude, Rated Torque, and 38°C (100°F) % 25 9.2
SCAC Temperature °C (°F) 54 (130) 54 (130)
Emissions* NOx g/bkW-hr (g/bhp-hr) 2.68 (2) 2.68 (2) CO g/bkW-hr (g/bhp-hr) 2.49 (1.86) 2.35 (1.75) CO2 g/bkW-hr (g/bhp-hr) 632 (471) 624 (466) VOC** g/bkW-hr (g/bhp-hr) 0.35 (0.26) 0.4 (0.3)
Fuel Consumption*** @ 100% Load MJ/bkW-hr (Btu/bhp-hr) 10.48 (7405) 10.36 (7324) @ 75% Load MJ/bkW-hr (Btu/bhp-hr) 10.79 (7628) 10.76 (7605)
Heat Balance Heat Rejection to Jacket Water @ 100% Load bkW (Btu/mn) 741 (42,123) 639 (36,343) @ 75% Load bkW (Btu/mn) 616.7 (35,075) 554 (31,480)
Heat Rejection to Aftercooler @ 100% Load bkW (Btu/mn) 167.8 (9546) 131.9 (7509) @ 75% Load bkW (Btu/mn) 108.6 (6179) 72.2 (4108)
Heat Rejection to Exhaust @ 100% Load bkW (Btu/mn) 837.8 (47,643) 694.6 (39,536) LHV to 25° C (77° F) @ 75% Load bkW (Btu/mn) 630.4 (35,848) 524.1 (29,806) LHV to 25° C (77° F)
Exhaust System Exhaust Gas Flow Rate @ 100% Load m3/min (cfm) 217.0 (7663) 182.9 (6460) @ 75% Load m3/min (cfm) 163.8 (5785) 138.9 (4905) Exhaust Stack Temperature @ 100% Load °C (°F) 467.22 (873) 452.2 (846) @ 75% Load °C (°F) 467.22 (873) 450.5 (843)
Intake System Air Inlet Flow Rate @ 100% Load m3/min (scfm) 80.6 (2847) 69.5 (2453) @ 75% Load m3/min (scfm) 60.8 (2147) 52.8 (1864)
Gas Pressure kPag (psig) 241.5-275.8 241.5-275.8 (35-40) (35-40)
*at 100% load and speed, all values are listed as not to exceed**Volatile organic compounds as defined in U.S. EPA 40 CFR 60, subpart JJJJ***ISO 3046/1
G3516 LE GAS PETROLEUM ENGINE
858-999 bkW (1150-1340 bhp)
GAS PETROLEUM ENGINE
Note: General configuration not to be used for installation. See general dimension drawings for detail (drawing #289-2971).
Dimensions are in mm (inches).
DIMENSIONS
Length mm (in.) 3339.3 (131.47)
Width mm (in.) 1820.6 (71.68)
Height mm (in.) 1863.7 (73.37)
Shipping Weight kg (lb) 8015 (17,670)
3339.3 (131.47)1820.6 (71.68)
1863.7(73.37)
01 01 01
03 03
03 03
Engine performance is obtained in accordance with SAE J1995, ISO3046/1, BS5514/1, and DIN6271/1 standards.
Transient response data is acquired from an engine/generator combination at normal operating temperature and in accordance with ISO3046/1 standard ambient conditions. Also in accordance with SAE J1995, BS5514/1, and DIN6271/1 standard reference conditions.
Conditions: Power for gas engines is based on fuel having an LHV of 33.74 kJ/L (905 Btu/cu ft) at 101 kPa (29.91 in. Hg) and 15° C (59° F). Fuel rate is based on a cubic meter at 100 kPa (29.61 in. Hg) and 15.6° C (60.1° F). Air flow is based on a cubic foot at 100 kPa (29.61 in. Hg) and 25° C (77° F). Exhaust flow is based on a cubic foot at 100 kPa (29.61 in. Hg) and stack temperature.
RATING DEFINITIONS AND CONDITIONS
Materials and specifications are subject to change without notice. The International System of Units (SI) is used in this publication.CAT, CATERPILLAR, their respective logos, ADEM, “Caterpillar Yellow” and the “Power Edge” trade dress, as well ascorporate and product identity used herein, are trademarks of Caterpillar and may not be used without permission. Performance Numbers: DM8618-01, DM8620-01 ©2009 CaterpillarLEHW0036-00 (11-09) All rights reserved.Supersedes LEHW6046-02
DAQE-

RN111680016 May 15, 2025 Kirt Rasmussen Urban Oil and Gas Group, LLC 1000 E 14th St
Plano, TX 75074 [e-mail]
Dear Kirt Rasmussen, Re: Engineer Review - Administrative Amendment to DAQE-AN111680015-22 for
Replacement-In-Kind of One Compressor Engine Project Number: N111680016 The DAQ requests a company representative review and sign the attached Engineer Review (ER). This ER identifies all applicable elements of the New Source Review (NSR) permitting program. Urban Oil and Gas Group, LLC should complete this review within 10 business days of receipt. Urban Oil and Gas Group, LLC should contact Mr. Tim DeJulis at [phone] if there are questions or concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email Mr. Tim DeJulis at [e-mail] the signed cover letter. Upon receipt of the signed cover letter, the DAQ will prepare an Approval Order (AO) for signature by the DAQ Director.
If Urban Oil and Gas Group, LLC does not respond to this letter within 10 business days, the project will move forward without source concurrence. If Urban Oil and Gas Group, LLC has concerns that cannot
be resolved and the project becomes stagnant, the DAQ Director may issue an Order prohibiting construction.
Approval Signature _____________________________________________________________ (Signature & Date)
195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
Department of Environmental Quality
Tim Davis Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director
State of Utah
SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION
Project Number N111680016 Owner Name Urban Oil and Gas Group, LLC Mailing Address 1000 E 14th St
Plano, TX, 75074 Source Name Urban Oil and Gas Group, LLC - Helper Station (prev.
Castlegate) Source Location 3 miles north-east of Price Helper, UT 84526
UTM Projection 518,300 m Easting, 4,387,750 m Northing UTM Datum NAD83 UTM Zone UTM Zone 12 SIC Code 1311 (Crude Petroleum & Natural Gas) Source Contact Kirt Rasmussen Phone Number [phone] Email [e-mail] Billing Contact Kirt Rasmussen
Phone Number [phone] Email [e-mail]
Project Engineer Mr. Tim DeJulis, Engineer Phone Number [phone] Email [e-mail]
Notice of Intent (NOI) Submitted March 14, 2025 Date of Accepted Application March 18, 2025

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 2
SOURCE DESCRIPTION General Description
Urban Oil and Gas Group, LLC, (Urban) owns and operates the Helper Station, a natural gas compressor station, north-east of Price in Carbon County. The station operates natural gas compressor engines that allow for the transfer of natural gas through pipelines to downstream
operations and eventual distribution to customers. NSR Classification: Administrative Amendment Source Classification Located in Attainment Area Carbon County Airs Source Size: SM Applicable Federal Standards
MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines
Project Proposal Administrative Amendment to DAQE-AN111680015-22 for Replacement-In-Kind of One
Compressor Engine Project Description Urban has requested a replacement-in-kind to DAQE-AN111680015-22, dated March 23, 2022 for one of the compressor engines rated 1,340 hp (de-rated to 1,206 hp for operation). The engine qualifies for a replacement-in-kind as per the requirements of R307-401-11. No changes were
made to the limits on the compressor engines. EMISSION IMPACT ANALYSIS
This is an administrative amendment that does not increase or decrease emissions at the facility. Therefore, modeling is not required per R307-410-4 and R307-410-5. [Last updated March 18, 2025]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 3
SUMMARY OF EMISSIONS
The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible.
Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent 0 45171.00 Carbon Monoxide 0 93.40
Nitrogen Oxides 0 98.99
Particulate Matter - PM10 0 0.44
Particulate Matter - PM2.5 0 0.44
Volatile Organic Compounds 0 27.08
Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Acetaldehyde (CAS #75070) 0 680
Acrolein (CAS #107028) 0 680
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 1120
Formaldehyde (CAS #50000) 0 18640
Generic HAPs (CAS #GHAPS) 0 900
Hexane (CAS #110543) 0 40 Toluene (CAS #108883) 0 2500 Xylenes (Isomers And Mixture) (CAS #1330207) 0 7340
Change (TPY) Total (TPY)
Total HAPs 0 15.95

Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 4
Review of BACT for New/Modified Emission Units 1. BACT review regarding BACT
This is an administrative amendment that is a replacement-in-kind for existing equipment. As there are no new sources of emissions or changes in emission rates, a BACT analysis is not required. [Last updated April 2, 2025]

SECTION I: GENERAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1]
I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8]
I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source.
All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]
I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns.
[R307-107] I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 5
I.8 The owner/operator shall submit documentation of the status of construction or modification to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is
discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.A THE APPROVED EQUIPMENT
II.A.1 Helper Station Natural Gas Compressor Station

II.A.2 Compressor Engines Four (4) Internal Combustion (IC) Compressor Engines (One new) Manufacturer Rated Horsepower: 1,340 derated to 1,206 Fuel Type: Natural Gas Stack Height (above ground): minimum 24 feet (modeling requirement)
II.A.3 Tri-ethylene Glycol Unit One (1) Tri-ethylene Glycol Dehydration Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 1.5 MMBTU/hr II.A.4 Di-ethylamine (DEA) Unit One (1) Di-ethylamine (DEA) Unit with Natural Gas-fired Boiler
Maximum Boiler Rating: 4.4 MMBTU/hr

II.A.5 Di-ethylamine (DEA) Unit One (1) Di-ethylamine (DEA) Unit with Natural Gas-fired Boiler Maximum Boiler Rating: 7.33 MMBTU/hr II.A.6 One (1) Emergency Vent (Not Flared)
II.A.7 Electric Compressor One (1) Electrically Powered Natural Gas Compressor
Note: Listed for informational purposes only and produces no emissions.

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 6
SECTION II: SPECIAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.B REQUIREMENTS AND LIMITATIONS
II.B.1 The Helper CPF Natural Gas Fired Compressor Station shall be subject to the following:
II.B.1.a The owner/operator shall not allow visible emissions from the following emission points to
exceed the following values: A. All emergency vent stacks - 0% opacity B. All natural gas-fired compressors - 5% opacity
C. All boiler exhaust stacks - 10% opacity D. All other points - 20% opacity. [R307-401-8] II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8]

II.B.1.b The owner/operator shall use only pipeline-grade natural gas as fuel. [R307-401-8]
II.B.1.c The owner/operator shall not vent more than 200 million scf of natural gas to the atmosphere per rolling 12-month period. The natural gas shall not be flared. [R307-401-8]
II.B.1.c.1 The owner/operator shall:
A. Determine the amount of vented natural gas with the use of a flowmeter B. Record the amount of natural gas vented on a monthly basis C. Use the production data to calculate a new rolling 12-month total by the 20th day of each month using data from the previous 12 months D. Keep the records of natural gas venting for all periods the plant is in operation. [R307-401-8]

II.B.1.d The owner/operator shall not emit more than the following rates and concentrations from each 1206 hp IC Compressor Engine: Pollutant lb/hr g/bhp-hr NOx 5.32 2.00 CO 5.05 1.90. [R307-401-8]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 7
II.B.1.d.1 Compliance Demonstration To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained
in this AO. [R307-165-2, R307-401-8] II.B.1.d.2 Initial Test The owner/operator shall conduct an initial stack test on the emission unit within 180 days after startup of the emission unit. [R307-165-2]
II.B.1.d.3 Test Frequency The owner/operator shall conduct a stack test on the emission unit within five years after the date of the most recent stack test of the emission unit, using methods 10 and 7E set forth in 40 CFR 60 Appendix A or within two years (2) of the most recent stack test of the emission unit using a portable analyzer. If methods 10 and 7E are used, test results shall be the average of three 30-minute test runs. Volumetric flow rate shall be determined stoichiometrically. The Director may require the owner/operator to perform a stack test at any time. [R307-165-2, R307-401-8]
II.B.2 Stack Testing Requirements
II.B.2.a The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8] II.B.2.a.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8]
II.B.2.a.2 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol and according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]
II.B.2.a.3 Access
The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or Mine Safety and Health Administration (MSHA)-approved access to the test location. [R307-401-8]

II.B.2.a.4 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8] II.B.2.a.5 Possible Rejection of Test Results The Director may reject stack testing results if the test did not follow the approved source test protocol or for a reason specified in R307-165-6. [R307-165-6, R307-401-8]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 8
II.B.2.b Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed
below. [R307-401-8] II.B.2.b.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K)
B. Pressure - 29.92 in Hg (101.3 kPa)
C. Averaging Time - As specified in the applicable test method [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]
II.B.2.b.2 NOx
40 CFR 60, Appendix A, Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8]
II.B.2.b.3 CO 40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.b.4 Internal Combustion (IC) Engines Portable testing monitors may be used to test IC engines. If portable monitors are to be used, they shall be calibrated according to the manufacturer's recommendations prior to any test. Also, portable monitor's operation and testing time shall be in accordance with manufacturer's recommendations. [R307-401-8]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 9
PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the
following documents: Supersedes DAQE-AN111680015-22 dated March 23, 2022
Is Derived From Replacement-in-Kind Notice dated March 18, 2025
REVIEWER COMMENTS

1. Comment regarding NSPS and MACT Review: 40 CFR 60 Subpart JJJJ applies to "owners and operators of stationary spark ignition (SI) internal combustion engines (ICE) as specified in paragraphs (a)(1) through (6) of this section" that were constructed after the applicability date listed in each of the referenced paragraphs. The four compressor engine are natural gas fired and are lean burn engines with "a maximum engine power greater than or equal to 500 HP and less than 1,350 HP." However, these compressor engines were constructed prior to the applicability date of January 1st, 2008. Therefore, this subpart is not applicable to the facility. 40 CFR 63 Subpart ZZZZ applies to owners and operators of "stationary RICE at a major or area source of HAP emissions..." The facility operates multiple stationary RICE as defined by this
subpart, therefore, this subpart is applicable to the compressor engines. The owner/operator must follow the applicable requirements of this subpart, listed in table 2d (8) of this subpart. These requirements include: 1. Change oil and filter every 2,160 hours of operation or annually, whichever comes first; 2. Inspect spark plugs every 2,160 hours of operation or annually, whichever comes first, and replace as necessary; and 3. Inspect all hoses and belts every 2,160 hours of operation or annually, whichever comes first, and replace as necessary. [Last updated April 2, 2025]
2. Comment regarding Title V Review: Title V of the 1990 Clean Air Act (Title V) applies to the following:
1. Any major source 2. Any source subject to a standard, limitation, or other requirement under Section 111 of the Act, Standards of Performance for New Stationary Sources; 3. Any source subject to a standard or other requirement under Section 112 of the Act, Hazardous Air Pollutants. 4. Any Title IV affected source. This facility is not a major source and is not a Title IV source. The facility is not subject to 40 CFR 60 (NSPS) or 40 CFR 61 (NESHAP) regulations. The facility is subject to 40 CFR 63 Subpart ZZZZ (MACT) regulations. MACT subpart ZZZZ exempts sources from the obligation to obtain a permit under a Title V permit, if the source is not otherwise required by law to obtain a permit. There are no other reasons why this source would be required to obtain a part 70 permit; therefore, Title V does not apply to this facility. [Last updated April 2, 2025]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 10
3. Comment regarding Evaluation of Replacement-in-Kind: To qualify as a replacement-in-kind, the replacement compressor engines must meet the following
criteria from R307-401-11: (a) the potential to emit of the process equipment is the same or lower - The engine have the same rating as the engine being replaced, and will comply with the same enforceable emission limits as the previous equipment.
(b) the number of emission points or emitting units is the same or lower - The number of emitting units will remain the same as one existing engine is being replaced with one new engine.
(c) no additional types of air pollutants are emitted as a result of the replacement - No additional air
pollutants are being emitted as a result of this replacement, as the engine ratings and fuel type are the same. (d) the process equipment or pollution control equipment is identical to or functionally equivalent to the replaced equipment - The engines is identical/functionally equivalent to the replaced equipment,
and will meet the same emission limits and use the same pollution control methods
(e) the replacement does not change the basic design parameters of the process unit or pollution control equipment - No changes are being made to the process equipment or any pollution controls. (f) the replaced process equipment or pollution control equipment is permanently removed from the stationary source, otherwise permanently disabled, or permanently barred from operation - The engine being replaced will be removed from the facility prior to the installation of the replacement
engine. (g) the replacement process equipment or pollution control equipment does not trigger New Source Performance Standards or National Emissions Standards for Hazardous Air Pollutants under 42 U.S.C. 7411 or 7412 - The replacement equipment will be subject to the same NSPS and NESHAP
or MACT standards as the previous equipment, therefore no additional standards under 42 U.S.C 7411 or 7412 will be applicable. (h) the replacement of the control apparatus or process equipment does not violate any other provision of Title R307 - This replacement does not violate any other provisions under UAC R307. Therefore, the installation of the one replacement compressor engine qualifies as a replacement-in-kind under R307-401-11. No changes to the equipment list are necessary as a result of this action. [Last updated May 15, 2025]

Engineer Review N111680016: Urban Oil and Gas Group, LLC - Helper Station (prev. Castlegate) May 15, 2025 Page 11
ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document:
40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology
CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by EPA to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1 COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal UDAQ use EPA Environmental Protection Agency
FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i) GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/HR Pounds per hour
LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units
NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit
R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year
UAC Utah Administrative Code VOC Volatile organic compounds

March 13th, 2025 Bryce Bird, Director
Utah Department of Environmental Quality Division of Air Quality P.O. Box 144820 Salt Lake City, UT 84114 RE: Written Notification of Engine Replacement-in-Kind
Urban Oil and Gas Group, L.L.C. Helper #1 Station

Dear Mr. Bird,

Urban Oil and Gas Group, L.L.C. (Urban) is the owner/operator of the Helper #1 Station that is
permitted and operating under Approval Order (AO) No. DAQE-AN111680012-14. Urban
intends to implement a Replacement-in-Kind of one of the four existing compressor engines at
the Helper #1 Station. In accordance with the conditions set forth in Utah Code R307-401-11 (2)
Replacement-in-Kind Procedures (a) and (b), Urban is submitting this “written notification to the
director before replacing the equipment”, that “contains a description of the replacement-in-kind
equipment, including control capability of any control apparatus and a demonstration that the
conditions of R307-401-11 (1) are met.”

Description of the Replacement-in-Kind
Urban plans to replace one of the existing four Caterpillar G3516 TALE compressor engines at
the Helper #1 Station with an engine of the same make and model, and equipped with the same
ADEM3 air-fuel ratio control apparatus. The replacement engine will be of the same
configuration and will have the same specifications and emission limits of the engine being
replaced. A completed Form 11 Internal Combustion Engines for the replacement engine is
attached to this written notification. Also included is a diagram showing the location of the
planned engine replacement at the Helper #1 Station.

All existing engines at the Helper #1 Station are subject to 40 CFR Part 60 Subpart JJJJ, as is the
replacement engine. They are required to have initial compliance tests and be tested every five
years. The replacement engine will adhere to the same testing requirements as the existing
engines at the facility.

Demonstration of Compliance with R307-401-11 (1) (a through h)
R307-401-11 (1) (a): The potential to emit of process equipment is the same or lower
The potential to emit for the replacement engine is equal to the potential to emit for the engine
being replaced.
R307-401-11 (1) (b): The number of emission points or emitting units is the same or lower

The number of emission units at the Helper #1 Station will remain the same.
R307-401-11 (1) (c): No additional types of air contaminants are emitted as a result of the
replacement
No additional types of air contaminants will be emitted as a result of the engine replacements.
R307-401-11 (1) (d): The process equipment or pollution control equipment is identical to or
fully functionally equivalent to the replaced equipment
The replacement engine and associated pollution control equipment are identical to and/or
functionally equivalent to that of the replaced equipment.
R307-401-11 (1) (e): The replacement does not change the basic design parameters of the
process unit or pollution control equipment
The replacement engine and associated pollution control equipment do not change the basic
parameters of the process unit or pollution control equipment.
R307-401-11 (1) (f): The replaced process equipment or pollution control equipment is
permanently removed from the stationary source, otherwise permanently
disabled or permanently barred from operation
The replaced engine and associated pollution control equipment will be removed permanently
from the Helper #1 Station prior to installation of the replacement engine and associated
pollution control equipment.
R307-401-11 (1) (g): The replaced process equipment or pollution control equipment does not
trigger New Source Performance Standards or National Emission
Standards for Hazardous Air Pollutants under 42 U.S.C. 7411 or 7412
The replacement engine and associated pollution control equipment are subject to the same
regulatory applicability as the replaced engine and associated pollution control equipment. As
such, neither New Source Performance Standards nor National Emission Standards for
Hazardous Air Pollutants are triggered as a result of the Like-Kind engine replacement.
R307-401-11 (1) (h): The replacement of the control apparatus or process equipment does not
violate any other provision of Title R307
To the best of the Owner/Operator’s knowledge, the Like-Kind engine replacement does not
violate any other provision of Title R307.
Applicability of Replacement-in-Kind Guidelines DAQ-2017-018841
In accordance with the referenced Guidelines, and through the submittal of this written
notification, Urban understands that the Air Quality Division shall compare the information
contained in this notification to the AO for the Helper #1 Station to determine whether an update
to the source’s AO is necessary. Based on the information submitted herein, Urban believes that
the AO for the Helper #1 Station does not need to be updated and that the Air Quality Division

will place this written notification (modification) in the source file in accordance with the
referenced Guidelines. Urban will await confirmation from the Air Quality Division prior to
initiating the engine replacement described herein.

If you have any questions or need any additional information, please feel free to contact me at
[phone].

Sincerely,

Kirt Rasmussen
Urban Oil and Gas
6825 South 5300 West
Price, Utah 84501
Cell: [phone]

Attachment

Unit 1801 In-Kind Engine Replacement

Utah Division of Air Quality
New Source Review Section
Form 11
Company Urban Oil & Gas
Site/Source Helper #1 Station
Date March 13, 2025
Internal Combustion Engines
Equipment Information
1.Manufacturer: Caterpillar
Model no.: G3516TALE
The date the engine was reconstructed April/May 2025
2.Operating time of Emission Source:
maximum average
24 Hours/day
7 Days/week
52 Weeks/year
24 Hours/day
7 Days/week
52 Weeks/year
Kw 3.Manufacturer's rated output at baseload, ISO 1340 hp or
Proposed site operating range ________________ 1206 ________ hp or Kw
Gas Firing
4.Are you operating site equipment on pipeline quality natural gas: x Yes □ No
5.Are you on an interruptible gas supply:
□Yes x No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
______________57.4__________ MMSCF/Year
7. Maximum firing rate:
_______________7469______________ BTU/Hp-hr
8. Average firing rate:
_______________9.0______________MMBTU/hr
Oil Firing
9. Type of oil:
Grade number □ 1 □ 2 □ 4 □ 5 □ 6 Other specify ___________
10. Annual consumption: ______________ gallons 11. Heat content:______________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight 13. Ash content: ____________% by weight
14. Average firing rate: gal/hr 15. Maximum firing rate: gal/hr
16. Direction of firing: □ horizontal □ tangential □ other: (specify)
Page 1 of 4 
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17.Application:
□Electric generation
______ Base load ______ Peaking
□Emergency Generator
□x Driving pump/compressor
□Exhaust heat recovery
□Other (specify) ________________________
18.Cycle
□x Simple cycle
□Regenerative cycle
□Cogeneration
□Combined cycle
Emissions Data
19.Manufacturer’s Emissions in grams per hour (gr/hp-hr): ___2.0____ NOX ____1.9___ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection x Other (specify)__ADEM3 AFR__
□Other low-NOx combustor □SCR catalyst □Steam injection
Additional Information
21. On separate sheets provide the following:
A. Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and
model and manufacturer's information. Example details include: controller input variables and operational
algorithms for water or ammonia injection systems, combustion mode versus engine load for variable mode
combustors, etc.
B. Exhaust parameter information on attached form.
C. All calculations used for the annual emission estimates must be submitted with this form to be deemed
complete.
D. All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using
SCREEN3.
E. If this form is filled out for a new source, forms 1 and 2 must be submitted also.
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF EMISSION PT. (6) EXIT DATA
NUMBER NAME COMPONENT OR AIR CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
12 518308 4387739 30 12 1
CO
NOx 5.32
5.05
23.3
22.1
ENG-3
ENG-3
Facility Diagram

Prepared For:
Prepared By:
7/22/2021
Helper CPF #1
Latitude: 39.63995
Longitude: -110.78685
API #(s): NA
Carbon County, Utah
Legend
= Valve
= Prod. Water Tank
= Underground Flowline
= Surface Flowline
= Condensate Tank
Diagram Not To Scale
Flowline Locations Representative Only
NSCT = Non-SPCC Applicable Chem Tank
Urban Oil and Gas Group, LLC
Compressor (6)
Compressor (5)
Compressor (4)
Compressor (3)
Unit 1801 to be Swapped
Compressor (2)
Compressor (1)
500 GAL Oil-
Raised
resulting in no
tank footprint
Transformer Switchgear
Electric
Bertha
Starter
Work Shop Storage Shed
50 GAL
- NSCT
Slop
50 GAL - NSCT
Slop
Blow
Case
Blow Case
1000 GAL Lube Oilin 11.7'x8.25'x.58'
Containment
50 GAL - NSCT
Slop
Sumps
Glycol
Contactor
300 GAL
Anitfreeze
-NSCT
1000 GAL
Chemical Tank
500 GAL Lube Oil
in 7.5'x4.1'x2'Containment
Sales
Scrubber
Fuel
Scrubber
Gas
Cooler
400 BBL
Used
Oil
210
BBLLube
Oil
24
BBL
Used
Oil
400 BBL
Slop
Oil
500 GAL
Lube Oil-
Raised
resulting in no tank footprint
80 GAL
Chemical Tank
Truck
Loading
46.75'
9'
18.5'
84'
66'
75'
Steel Containment
Height= 2.25'
Amine
Reboiler Flash
Tank
Blow
Case
1500 GAL
Ucarsol AP Solvent
814- Raised resulting in no tank footprint
Still
1000 GAL DI Water - NSCT Tail Scrubber
Amine Contactor
(1) 1 BBL & (1) 35
GAL Antifoam - NSCT
Building
Meter
House
Sh
o
p
Scrubber
Scrubber
Yellow Plastic
Slop Drip Flare
Reflux Cooler Troughs Troughs
Amine/
Reflux Cooler
21' x 14'
Concrete Berm Height= 1.3'
Flash
Tank
Blo
w

Ca
s
e
Gly
c
o
l
Re
b
o
i
l
e
r
(2) 300 GAL
Triethylene Glycol-
NSCT
1000 GAL DI Water-
NSCT
Still
Metal Skid with Sump
Drain
Building
Tail Scrubber Contactor
Of
f
i
c
e
Bu
i
l
d
i
n
g
Amine
Reboiler
El
e
c
t
r
i
c
a
l

Bu
i
l
d
i
n
g
T
400
BBL
FW
Air
Compressor
Breaker
20 GAL
- NSCT
Slop Can
Building
Irregular Shaped Perimeter
Berm Area = 234,580 ft2
Earthen Berm Height = 1'
Fence
Tank Sizes
400 BBL = 12'D x 20'H
210 BBL = 10'D x 15'H
24 BBL = 10'D
500 GAL
Anitfreeze
-NSCT
Blow Case
Shown with Optional Equipment
CAT® ENGINE SPECIFICATIONS
V-16, 4-Stroke-CycleBore ................................170 mm (6.7 in.)Stroke ..............................190 mm (7.5 in.)Displacement .......................69 L (4210 cu. in.)Aspiration ...................Turbocharged-AftercooledDigital Engine Management Governor and Protection .....Electronic (ADEM™ A3)Combustion ................Low Emission (Lean Burn)Engine Weight, net dry (approx) .....8015 kg (17,670 lb)Power Density ...................8 kg/kW (13.2 lb/bhp)Power per Displacement ....................19.3 bhp/LTotal Cooling System Capacity .......217.7 L (57.5 gal) Jacket Water .......................200.6 L (53 gal)Aftercooler Circuit .......................17 L (4.5 gal)Lube Oil System (refill) .................424 L (112 gal)Oil Change Interval .......................1000 hoursRotation (from flywheel end) .........CounterclockwiseFlywheel and Flywheel Housing ............SAE No. 00Flywheel Teeth ..................................183
LEHW0036-00 Page 1 of 4Supersedes LEHW6046-02
G3516 LE Gas PetroleumEngine
858-999 bkW1150-1340 bhp1200-1400 rpm
2.0 g/bhp-hr NOx (NTE)
FEATURES
Engine Design- Proven reliability and durability - Ability to burn a wide spectrum of gaseous fuels - Robust diesel strength design prolongs life and lowers owning and operating costs- Broad operating speed range
EmissionsMeets U.S. EPA Spark Ignited Stationary NSPS Emissions for 2007/8
Lean Burn Engine TechnologyLean-burn engines operate with large amounts of excess air. The excess air absorbs heat during combustion reducing the combustion temperature and pressure, greatly reducing levels of NOx. Lean-burn design also provides longer component life and excellent fuel consumption.
Advanced Digital Engine ManagementADEM A3 control system providing integrated ignition, speed governing, protection, and controls, including detonation-sensitive variable ignition timing. ADEM A3 has improved: user interface, display system, shutdown controls, and system diagnostics.
Ease of OperationSide covers on block allow for inspection of internal components
Full Range of AttachmentsLarge variety of factory-installed engine attachments reduces packaging time
TestingEvery engine is full-load tested to ensure proper engine performance.
Gas Engine Rating Pro GERP is a PC-based program designed to provide site performance capabilities for Cat® natural gas engines for the gas compression industry. GERP provides engine data for your site’s altitude, ambient temperature, fuel, engine coolant heat rejection, performance data, installation drawings, spec sheets, and pump curves.
Product Support Offered Through Global Cat Dealer NetworkMore than 2,200 dealer outlets
Cat factory-trained dealer technicians service every aspect of your petroleum engine
Cat parts and labor warranty
Preventive maintenance agreements available for repair-before-failure options
S•O•SSM program matches your oil and coolant samples against Caterpillar set standards to determine:- Internal engine component condition- Presence of unwanted fluids- Presence of combustion by-products- Site-specific oil change interval
Over 80 Years of Engine Manufacturing ExperienceOver 60 years of natural gas engine production
Ownership of these manufacturing processes enables Caterpillar to produce high quality, dependable products.- Cast engine blocks, heads, cylinder liners, and flywheel housings- Machine critical components- Assemble complete engine
Web SiteFor all your petroleum power requirements, visit www.catoilandgas.cat.com.
G3516 LE GAS PETROLEUM ENGINE
858-999 bkW (1150-1340 bhp)
LEHW0036-00 Page 2 of 4Supersedes LEHW6046-02
Air Inlet SystemAir cleaner — intermediate-duty with service indicator
Control SystemA3 ECUAir-fuel ratio control
Cooling SystemThermostats and housingJacket water pumpAftercooler water pumpAftercooler core for sea-air atmosphereAftercooler thermostats and housing
Exhaust SystemWatercooled exhaust manifolds
Flywheels & Flywheel HousingsSAE No. 00 flywheelSAE No. 00 flywheel housingSAE standard rotation
Fuel SystemGas pressure regulatorNatural gas carburetor
Ignition SystemA3 ECU
InstrumentationPL1000 Advisor panel
Lubrication SystemCrankcase breather — top mountedOil coolerOil filter — RHOil bypass filterOil pan — shallowOil sampling valveTurbo oil accumulator
Mounting SystemRails, engine mounting — 254 mm (10 in)
Protection SystemElectronic shutoff systemGas shutoff valve
GeneralPaint — Cat yellowVibration damper and guard — dual 484 mm (23 in)
STANDARD EQUIPMENT
Air Inlet SystemRemote air inlet adaptersPrecleaner
Charging SystemBattery chargersCharging alternators
Cooling SystemAftercooler coreThermostatic valveTemperature switchConnectionsExpansion and overflow tankWater level switch gauge
Exhaust SystemFlexible fittingsElbowsFlangeFlange and exhaust expandersRain capMufflers
Fuel SystemLow pressure gas conversionsPropane gas valve and jet kitsFuel filter
InstrumentationPL1000 communications modules
Lubrication SystemOil bypass filter removal and oil pan accessoriesSump pumpAir prelube pumpManual prelube pumpLubricating oil
Mounting SystemRailsVibration isolators
Power Take-OffsFront accessory drivesAuxiliary drive shafts and pulleysFront stub shaftPulleys
Protection SystemExplosion relief valves, status control box interconnect wiring harness
Starting SystemAir starting motorAir pressure regulatorAir silencerElectric air start controlsElectric starting motors — dual 24-voltStarting aidsBattery sets (24-volt dry), cables, and rack
GeneralFlywheel intertia weightGuard removalEngine barring groupPremium 8:1 pistonsPremium cylinder heads
OPTIONAL EQUIPMENT
G3516 LE GAS PETROLEUM ENGINE
858-999 bkW (1150-1340 bhp)
LEHW0036-00 Page 3 of 4Supersedes LEHW6046-02
TECHNICAL DATA
G3516 LE Gas Petroleum Engine
Fuel System 2 g NOx NTE Rating 2 g NOx NTE Rating DM8618-01 DM8620-01
Engine Power @ 100% Load bkW (bhp) 999 (1340) 858 (1150) @ 75% Load bkW (bhp) 749 (1004) 643 (862)
Engine Speed rpm 1400 1200 Max Altitude @ Rated Torque and 38°C (100°F) m (ft) 304.8 (1000) 1219.2 (4000) Speed Turndown @ Max Altitude, Rated Torque, and 38°C (100°F) % 25 9.2
SCAC Temperature °C (°F) 54 (130) 54 (130)
Emissions* NOx g/bkW-hr (g/bhp-hr) 2.68 (2) 2.68 (2) CO g/bkW-hr (g/bhp-hr) 2.49 (1.86) 2.35 (1.75) CO2 g/bkW-hr (g/bhp-hr) 632 (471) 624 (466) VOC** g/bkW-hr (g/bhp-hr) 0.35 (0.26) 0.4 (0.3)
Fuel Consumption*** @ 100% Load MJ/bkW-hr (Btu/bhp-hr) 10.48 (7405) 10.36 (7324) @ 75% Load MJ/bkW-hr (Btu/bhp-hr) 10.79 (7628) 10.76 (7605)
Heat Balance Heat Rejection to Jacket Water @ 100% Load bkW (Btu/mn) 741 (42,123) 639 (36,343) @ 75% Load bkW (Btu/mn) 616.7 (35,075) 554 (31,480)
Heat Rejection to Aftercooler @ 100% Load bkW (Btu/mn) 167.8 (9546) 131.9 (7509) @ 75% Load bkW (Btu/mn) 108.6 (6179) 72.2 (4108)
Heat Rejection to Exhaust @ 100% Load bkW (Btu/mn) 837.8 (47,643) 694.6 (39,536) LHV to 25° C (77° F) @ 75% Load bkW (Btu/mn) 630.4 (35,848) 524.1 (29,806) LHV to 25° C (77° F)
Exhaust System Exhaust Gas Flow Rate @ 100% Load m3/min (cfm) 217.0 (7663) 182.9 (6460) @ 75% Load m3/min (cfm) 163.8 (5785) 138.9 (4905) Exhaust Stack Temperature @ 100% Load °C (°F) 467.22 (873) 452.2 (846) @ 75% Load °C (°F) 467.22 (873) 450.5 (843)
Intake System Air Inlet Flow Rate @ 100% Load m3/min (scfm) 80.6 (2847) 69.5 (2453) @ 75% Load m3/min (scfm) 60.8 (2147) 52.8 (1864)
Gas Pressure kPag (psig) 241.5-275.8 241.5-275.8 (35-40) (35-40)
*at 100% load and speed, all values are listed as not to exceed**Volatile organic compounds as defined in U.S. EPA 40 CFR 60, subpart JJJJ***ISO 3046/1
G3516 LE GAS PETROLEUM ENGINE
858-999 bkW (1150-1340 bhp)
GAS PETROLEUM ENGINE
Note: General configuration not to be used for installation. See general dimension drawings for detail (drawing #289-2971).
Dimensions are in mm (inches).
DIMENSIONS
Length mm (in.) 3339.3 (131.47)
Width mm (in.) 1820.6 (71.68)
Height mm (in.) 1863.7 (73.37)
Shipping Weight kg (lb) 8015 (17,670)
3339.3 (131.47)1820.6 (71.68)
1863.7(73.37)
01 01 01
03 03
03 03
Engine performance is obtained in accordance with SAE J1995, ISO3046/1, BS5514/1, and DIN6271/1 standards.
Transient response data is acquired from an engine/generator combination at normal operating temperature and in accordance with ISO3046/1 standard ambient conditions. Also in accordance with SAE J1995, BS5514/1, and DIN6271/1 standard reference conditions.
Conditions: Power for gas engines is based on fuel having an LHV of 33.74 kJ/L (905 Btu/cu ft) at 101 kPa (29.91 in. Hg) and 15° C (59° F). Fuel rate is based on a cubic meter at 100 kPa (29.61 in. Hg) and 15.6° C (60.1° F). Air flow is based on a cubic foot at 100 kPa (29.61 in. Hg) and 25° C (77° F). Exhaust flow is based on a cubic foot at 100 kPa (29.61 in. Hg) and stack temperature.
RATING DEFINITIONS AND CONDITIONS
Materials and specifications are subject to change without notice. The International System of Units (SI) is used in this publication.CAT, CATERPILLAR, their respective logos, ADEM, “Caterpillar Yellow” and the “Power Edge” trade dress, as well ascorporate and product identity used herein, are trademarks of Caterpillar and may not be used without permission. Performance Numbers: DM8618-01, DM8620-01 ©2009 CaterpillarLEHW0036-00 (11-09) All rights reserved.Supersedes LEHW6046-02