DAQ-2024-010420

DAQE-AN162010001-24

{{$d1 }}

Steven Tedesco
Running Foxes Petroleum, Inc.
14550 East Easter Avenue, Suite 200
Centennial, CO 80112
[e-mail]

Dear Mr. Tedesco:

Re: Approval Order: New Grand Central Data Center
Project Number: N162010001

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on February
26, 2024. Running Foxes Petroleum, Inc. must comply with the requirements of this AO, all applicable
state requirements (R307), and Federal Standards.

The project engineer for this action is Dungan Adams, 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. No public comments were
received on this action.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:DA: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

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

August 20, 2024

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-AN162010001-24
New Grand Central Data Center

Prepared By
Dungan Adams, Engineer
[phone]
[e-mail]

Issued to
Running Foxes Petroleum, Inc. - Grand Central Data Center

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

August 20, 2024
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 ..................................................................................................................... 9
ACRONYMS ............................................................................................................................... 10

DAQE-AN162010001-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Running Foxes Petroleum, Inc. Running Foxes Petroleum, Inc. - Grand Central
Data Center

Mailing Address Physical Address
14550 East Easter Avenue, Suite 200 3 Miles North of Exit 214 on I-70
Centennial, CO 80112 Grand County, UT

Source Contact UTM Coordinates
Name: Steven Tedesco 649,434 m Easting
Phone: [phone],326,443 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12

SIC code 1389 (Oil & Gas Field Services, NEC)

SOURCE INFORMATION
General Description
Running Foxes Petroleum, Inc. (Running Foxes) has requested to operate a new data center located in
Grand County. The facility will process a raw natural gas stream using a triethylene glycol (TEG)
dehydrator. Liquids from the TEG dehydrator will flow into a produced water storage tank, where they
are stored prior to being transported offsite via tanker truck. The dry gas from the TEG dehydrator will
pass through a JT skid to knock out any natural gas liquids (NGLs). All NGLs will be stored in
pressurized tanks before being transported offsite. The treated natural gas will be used as fuel for eleven
(11) 295-hp (220 kW) generator engines, which will power the data center. Each engine will be equipped
with nonselective catalytic reduction (NSCR) technology. Other sources of emissions include fugitive
emissions, truck loading, pneumatic devices, and a water storage tank.

NSR Classification
New Minor Source

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

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
DAQE-AN162010001-24
Page 4

NSPS (Part 60), OOOOb: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After November 15, 2021
MACT (Part 63), A: General Provisions
MACT (Part 63), HH: National Emission Standards for Hazardous Air Pollutants From Oil and
Natural Gas Production Facilities
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

Project Description
Running Foxes has requested a new data center. The natural gas stream will be processed using one (1)
0.4 million standard cubic feet per day (MMSCFD) TEG dehydrator equipped with one (1) flash tank, one
(1) condenser, and one (1) 0.5 million British thermal units per hour (MMBtu/hr) reboiler. NGLs will be
removed by one (1) JT Skid and sent to two (2) pressurized bullet tanks before being sent offsite. The
remaining gas is used to power eleven (11) 295-hp (220 kW) natural gas-fired generator engines, which
are used to operate the data center. Additionally, any produced water will be stored in one (1) 300-barrel
water tank.

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 17533.00
Carbon Monoxide 17.41
Nitrogen Oxides 16.17
Particulate Matter - PM10 2.79
Particulate Matter - PM2.5 2.79
Sulfur Dioxide 0.08
Volatile Organic Compounds 4.85

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Benzene (Including Benzene From Gasoline) (CAS #71432) 120
Formaldehyde (CAS #50000) 580
Generic HAPs (CAS #GHAPS) 400
Hexane (CAS #110543) 280
Change (TPY) Total (TPY)
Total HAPs 0.69

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]

DAQE-AN162010001-24
Page 5

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]

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 Grand Central Data Center

II.A.2 Eleven (11) Generator Engines
Rating: 295-hp (220 kW)
Fuel: Natural Gas
Control: Non-selective Catalytic Reduction (NSCR)
NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ

II.A.3 One (1) TEG Dehydration Unit
Processing Rate: 0.4 MMscf/day
Includes: Glycol Regenerator, Flash Tank, Condenser, and One (1) Attached 0.5 MMBtu/hr
Reboiler (Natural Gas)
NSPS/MACT Applicability: 40 CFR 63 Subpart HH

II.A.4 One (1) JT Skid

DAQE-AN162010001-24
Page 6

II.A.5 One (1) Storage Tank
Contents: Produced Water
Capacity: 300 bbl (12,600 gallons)
Color: White, Aluminum, etc.

II.A.6 Two (2) Pressurized Bullet Storage Tanks
Contents: NGLs

II.A.7 Various Pneumatic Devices

SECTION II: SPECIAL PROVISIONS

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Facility Wide Conditions
II.B.1.a The owner/operator shall not allow visible emissions from any source on site to exceed 10%
opacity. [R307-401-8]

II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Method 9. [R307-401-8]

II.B.2 Natural Gas-Fired Generator Engines
II.B.2.a The owner/operator shall use only natural gas as fuel for all internal combustion generator
engines on site. [R307-401-8]

II.B.2.b The owner/operator shall equip each natural gas-fired generator engine with a NSCR device.
[R307-401-8]

II.B.3 Stack Testing Conditions
II.B.3.a The owner/operator shall not emit more than the following rates from each 295-hp Generator
Engine:

Pollutant lb/hr
NOx 0.33
CO 0.33
VOC 0.04

[R307-401-8]

II.B.3.a.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.3.a.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.3.a.3 Test Frequency
The owner/operator shall conduct a stack test on the emission unit within three (3) years after the
date of the most recent stack test of the emission unit or subsequently after 8,760 operational
hours of the emission unit, whichever comes first. The Director may require the owner/operator
to perform a stack test at any time. [R307-165-2, R307-401-8]

DAQE-AN162010001-24
Page 7

II.B.3.b The owner/operator shall conduct any stack testing required by this AO according to the
following conditions. [R307-401-8]

II.B.3.b.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.3.b.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.3.b.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.3.b.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.3.b.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]

II.B.3.c 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.3.c.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.3.c.2 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]

II.B.3.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A,
Method 320; or other EPA-approved testing method as acceptable to the Director.
[R307-401-8]

II.B.3.c.4 CO
40 CFR 60, Appendix A, Method 10, or other EPA-approved testing method as acceptable to the
Director. [R307-401-8]

DAQE-AN162010001-24
Page 8

II.B.4 Triethylene Glycol Dehydration Unit Requirements
II.B.4.a The owner/operator shall use an enclosed combustion device to control emissions from the TEG
dehydration unit. [40 CFR 63 Subpart HH, R307-401-8]

II.B.5 Truck Loading Requirements
II.B.5.a The owner/operator shall load the atmospheric tank trucks on site by the use of submerged
bottom filling or a submerged fill pipe. [R307-401-8]

II.B.6 Pneumatic Device Requirements
II.B.6.a The owner/operator shall design and operate each pneumatic device with zero methane and VOC
emissions to the atmosphere. [40 CFR 60 Subpart OOOOb]

II.B.7 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair)
II.B.7.a The owner/operator shall develop a fugitive emissions monitoring plan. At a minimum, the plan
shall include:

A. Monitoring frequency.

B. Monitoring technique and equipment.

C. Procedures and timeframes for identifying and repairing leaks.

D. Recordkeeping practices.

E. Calibration and maintenance procedures.

[R307-401-8]

II.B.7.a.1 The plan shall address monitoring for "difficult-to-monitor" and "unsafe-to-monitor"
components. [R307-401-8]

II.B.7.b The owner/operator shall conduct monitoring surveys on site to observe each "fugitive emissions
component" for "fugitive emissions."

A. "Fugitive emissions component" means any component that has the potential to emit
fugitive emissions of VOC, including but not limited to valves, connectors, pressure
relief devices, open-ended lines, flanges, covers and closed vent systems, thief hatches
or other openings, compressors, instruments, and meters.

B. "Fugitive emissions" are considered any visible emissions observed using optical gas
imaging or a Method 21 instrument reading of 500 ppm or greater. [R307-401-8]

II.B.7.b.1 Monitoring surveys shall be conducted according to the following schedule:

A. No later than 60 days after startup of production, as defined in 40 CFR 60.5430b.

B. Semiannually after the initial monitoring survey. Consecutive semiannual monitoring
surveys shall be conducted at least 4 months apart.

C. Annually after the initial monitoring survey for "difficult-to-monitor" components.

D. As required by the owner/operator's monitoring plan for "unsafe-to-monitor"
components.

[40 CFR 60 Subpart OOOOb, R307-401-8]

DAQE-AN162010001-24
Page 9

II.B.7.b.2 Monitoring surveys shall be conducted using one or both of the following to detect fugitive
emissions:

A. Optical gas imaging (OGI) equipment. OGI equipment shall be capable of imaging
gases in the spectral range for the compound of highest concentration in the potential
fugitive emissions.

B. Monitoring equipment that meets U.S. EPA Method 21, 40 CFR Part 60, Appendix A.

[R307-401-8]

II.B.7.c If fugitive emissions are detected at any time, the owner/operator shall repair the fugitive
emissions component as soon as possible, but no later than 15 calendar days after detection.

If the repair or replacement is technically infeasible, would require a vent blowdown, a well
shutdown, or well shut-in, or would be unsafe to repair during operation of the unit, the repair or
replacement must be completed during the next well shutdown, well shut-in, after an
unscheduled, planned, or emergency vent blowdown, or within 24 months, whichever is earlier.

[R307-401-8]

II.B.7.c.1 The owner/operator shall resurvey the repaired or replaced fugitive emissions component no later
than 30 calendar days after the fugitive emissions component was repaired. [R307-401-8]

II.B.7.d The owner/operator shall maintain records of the fugitive emissions monitoring plan, monitoring
surveys, repairs, and resurveys. [R307-401-8]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:

Is Derived From NOI dated February 26, 2024
Incorporates Additional Information dated April 30, 2024
Incorporates Additional Information dated June 12, 2024

DAQE-AN162010001-24
Page 10

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-IN162010001-24

July 8, 2024

Steven Tedesco
Running Foxes Petroleum, Incorporated
14550 East Easter Avenue, Suite 200
Centennial, CO 80112
[e-mail]

Dear Mr. Tedesco:

Re: Intent to Approve: New Grand Central Data Center
Project Number: N162010001

The attached document is the Intent to Approve (ITA) for the above-referenced project. The ITA is
subject to public review. Any comments received shall be considered before an Approval Order (AO) is
issued. The Division of Air Quality is authorized to charge a fee for reimbursement of the actual costs
incurred in the issuance of an AO. An invoice will follow upon issuance of the final AO.

Future correspondence on this ITA should include the engineer's name, Dungan Adams, as well as the
DAQE number as shown on the upper right-hand corner of this letter. Dungan Adams, can be reached at
[phone] or [e-mail], if you have any questions.

Sincerely,

{{$s }}

Alan D. Humpherys, Manager
New Source Review Section

ADH:DA: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

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

INTENT TO APPROVE
DAQE-IN162010001-24
New Grand Central Data Center

Prepared By
Dungan Adams, Engineer
[phone]
[e-mail]

Issued to
Running Foxes Petroleum, Incorporated - Grand Central Data Center

Issued On
July 8, 2024

{{$s }}

New Source Review Section Manager
Alan D. Humpherys
{{#s=Sig_es_:signer1:signature}}

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
PUBLIC NOTICE STATEMENT............................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 6
PERMIT HISTORY ................................................................................................................... 10
ACRONYMS ............................................................................................................................... 11

DAQE-IN162010001-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Running Foxes Petroleum, Incorporated Running Foxes Petroleum, Incorporated - Grand
Central Data Center

Mailing Address Physical Address
14550 East Easter Avenue, Suite 200 3 Miles North of Exit 214 on I-70
Centennial, CO 80112 Grand County, UT

Source Contact UTM Coordinates
Name: Steven Tedesco 649,434 m Easting
Phone: [phone],326,443 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12

SIC code 1389 (Oil & Gas Field Services, NEC)

SOURCE INFORMATION
General Description
Running Foxes Petroleum, Incorporated (Running Foxes) has requested to operate a new data center
located in Grand County. The facility will process a raw natural gas stream using a triethylene glycol
(TEG) dehydrator. Liquids from the TEG dehydrator will flow into a produced water storage tank, where
they are stored prior to being transported offsite via tanker truck. The dry gas from the TEG dehydrator
will pass through a JT skid to knock out any natural gas liquids (NGLs). All NGLs will be stored in
pressurized tanks before being transported offsite. The treated natural gas will be used as fuel for eleven
(11) 295-hp (220 kW) generator engines, which will power the data center. Each engine will be equipped
with nonselective catalytic reduction (NSCR) technology. Other sources of emissions include fugitive
emissions, truck loading, pneumatic devices, and a water storage tank.
NSR Classification
New Minor Source

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

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
NSPS (Part 60), OOOOb: Standards of Performance for Crude Oil and Natural Gas Facilities
DAQE-IN162010001-24
Page 4

for which Construction, Modification or Reconstruction Commenced After November 15, 2021
MACT (Part 63), A: General Provisions
MACT (Part 63), HH: National Emission Standards for Hazardous Air Pollutants From Oil and
Natural Gas Production Facilities
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

Project Description
Running Foxes has requested a new data center. The natural gas stream will be processed using one (1)
0.4 million standard cubic feet per day (MMSCFD) triethylene glycol dehydrator equipped with one (1)
flash tank, one (1) condenser, and one (1) 0.5 million British thermal units per hour (MMBtu/hr) reboiler.
Natural gas liquids (NGL) will be removed by one (1) JT Skid and sent to two (2) pressurized bullet tanks
before being sent offsite. The remaining gas is used to power eleven (11) 295-hp (220 kW) natural
gas-fired generator engines, which are used to operate the data center. Additionally, any produced water
will be stored in one (1) 300-barrel water tank.

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 17533.00
Carbon Monoxide 17.41
Nitrogen Oxides 16.17
Particulate Matter - PM10 2.79
Particulate Matter - PM2.5 2.79
Sulfur Dioxide 0.08
Volatile Organic Compounds 4.85

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Benzene (Including Benzene From Gasoline) (CAS #71432) 120
Formaldehyde (CAS #50000) 580
Generic HAPs (CAS #GHAPS) 400
Hexane (CAS #110543) 280
Change (TPY) Total (TPY)
Total HAPs 0.69

PUBLIC NOTICE STATEMENT

The NOI for the above-referenced project has been evaluated and has been found to be consistent with the
requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be
constructed, installed, established, or modified prior to the issuance of an AO by the Director.

A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the
intent to approve will be published in the Times Independent Printing on July 11, 2024. During the public
comment period the proposal and the evaluation of its impact on air quality will be available for the
DAQE-IN162010001-24
Page 5

public to review and provide comment. If anyone so requests a public hearing within 15 days of
publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as close as
practicable to the location of the source. Any comments received during the public comment period and
the hearing will be evaluated. The proposed conditions of the AO may be changed as a result of the
comments received.

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.

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]

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]

DAQE-IN162010001-24
Page 6

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.

II.A THE APPROVED EQUIPMENT

II.A.1 Grand Central Data Center

II.A.2 Eleven (11) Generator Engines
Rating: 295 hp (220 kW)
Fuel: Natural Gas
Control: Non-selective Catalytic Reduction (NSCR)
NSPS/MACT Applicability: 40 CFR 60 Subpart JJJJ, 40 CFR 63 Subpart ZZZZ

II.A.3 One (1) Triethylene Glycol (TEG) Dehydration Unit
Processing Rate: 0.4 MMscf/day
Includes: Glycol Regenerator, Flash Tank, Condenser, and One (1) Attached 0.5 MMBtu/hr
Reboiler (Natural Gas)
NSPS/MACT Applicability: 40 CFR 63 Subpart HH

II.A.4 One (1) JT Skid

II.A.5 One (1) Storage Tank
Contents: Produced Water
Capacity: 300 bbl (12,600 gallons)
Color: White, Aluminum, etc.

II.A.6 Two (2) Pressurized Bullet Storage Tanks
Contents: Natural Gas Liquids (NGL)

II.A.7 Various Pneumatic Devices

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.

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Facility Wide Conditions
II.B.1.a The owner/operator shall not allow visible emissions from any source on site to exceed 10%
opacity. [R307-401-8]

II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Method 9. [R307-401-8]

II.B.2 Natural Gas-Fired Generator Engines
II.B.2.a The owner/operator shall use only natural gas as fuel for all internal combustion generator
engines on site. [R307-401-8]

DAQE-IN162010001-24
Page 7

II.B.2.b The owner/operator shall equip each natural gas-fired generator engine with a non-selective
catalytic reduction (NSCR) device. [R307-401-8]

II.B.3 Stack Testing Conditions
II.B.3.a The owner/operator shall not emit more than the following rates from each 295-hp Generator
Engine:

Pollutant lb/hr

NOx 0.33
CO 0.33
VOC 0.04

[R307-401-8]

II.B.3.a.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.3.a.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.3.a.3 Test Frequency
The owner/operator shall conduct a stack test on the emission unit within three (3) years after the
date of the most recent stack test of the emission unit or subsequently after 8,760 operational
hours of the emission unit, whichever comes first. The Director may require the owner/operator
to perform a stack test at any time. [R307-165-2, R307-401-8]

II.B.3.b The owner/operator shall conduct any stack testing required by this AO according to the
following conditions. [R307-401-8]

II.B.3.b.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.3.b.2 Testing and 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.3.b.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.3.b.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.3.b.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-IN162010001-24
Page 8

II.B.3.c 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.3.c.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.3.c.2 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]

II.B.3.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A,
Method 320; or other EPA-approved testing method as acceptable to the Director. [R307-401-8]

II.B.3.c.4 CO
40 CFR 60, Appendix A, Method 10, or other EPA-approved testing method as acceptable to the
Director. [R307-401-8]

II.B.4 Triethylene Glycol Dehydration Unit Requirements
II.B.4.a The owner/operator shall use an enclosed combustion device to control emissions from the TEG
dehydration unit. [40 CFR 63 Subpart HH, R307-401-8]

II.B.5 Truck Loading Requirements
II.B.5.a The owner/operator shall load the atmospheric tank trucks on site by the use of submerged
bottom filling or a submerged fill pipe. [R307-401-8]

II.B.6 Pneumatic Device Requirements
II.B.6.a The owner/operator shall design and operate each pneumatic device with zero methane and VOC
emissions to the atmosphere. [40 CFR 60 Subpart OOOOb]

II.B.7 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair)
II.B.7.a The owner/operator shall develop a fugitive emissions monitoring plan. At a minimum, the plan
shall include:

A. Monitoring frequency.

B. Monitoring technique and equipment.

C. Procedures and timeframes for identifying and repairing leaks.

D. Recordkeeping practices.

E. Calibration and maintenance procedures.

[R307-401-8]

II.B.7.a.1 The plan shall address monitoring for "difficult-to-monitor" and "unsafe-to-monitor"
components. [R307-401-8]

DAQE-IN162010001-24
Page 9

II.B.7.b The owner/operator shall conduct monitoring surveys on site to observe each "fugitive emissions
component" for "fugitive emissions."

A. "Fugitive emissions component" means any component that has the potential to emit
fugitive emissions of VOC, including but not limited to valves, connectors, pressure
relief devices, open-ended lines, flanges, covers, closed vent systems, thief hatches
or other openings, compressors, instruments, and meters.

B. "Fugitive emissions" are considered any visible emissions observed using optical gas
imaging or a Method 21 instrument reading of 500 ppm or greater.

[R307-401-8]

II.B.7.b.1 Monitoring surveys shall be conducted according to the following schedule:

A. No later than 60 days after startup of production, as defined in 40 CFR 60.5430b.

B. Semiannually after the initial monitoring survey. Consecutive semiannual monitoring
surveys shall be conducted at least 4 months apart.

C. Annually after the initial monitoring survey for "difficult-to-monitor" components.

D. As required by the owner/operator's monitoring plan for "unsafe-to-monitor"
components.

[40 CFR 60 Subpart OOOOb, R307-401-8]

II.B.7.b.2 Monitoring surveys shall be conducted using one or both of the following to detect fugitive
emissions:

A. Optical gas imaging (OGI) equipment. OGI equipment shall be capable of imaging
gases in the spectral range for the compound of highest concentration in the potential
fugitive emissions.

B. Monitoring equipment that meets U.S. EPA Method 21, 40 CFR Part 60, Appendix A.

[R307-401-8]

II.B.7.c If fugitive emissions are detected at any time, the owner/operator shall repair the fugitive
emissions component as soon as possible, but no later than 15 calendar days after detection.

If the repair or replacement is technically infeasible, would require a vent blowdown, a well
shutdown, or well shut-in, or would be unsafe to repair during operation of the unit, the repair or
replacement must be completed during the next well shutdown, well shut-in, after an
unscheduled, planned, or emergency vent blowdown, or within 24 months, whichever is earlier.

[R307-401-8]

II.B.7.c.1 The owner/operator shall resurvey the repaired or replaced fugitive emissions component no later
than 30 calendar days after the fugitive emissions component was repaired. [R307-401-8]

II.B.7.d The owner/operator shall maintain records of the fugitive emissions monitoring plan, monitoring
surveys, repairs, and resurveys. [R307-401-8]

DAQE-IN162010001-24
Page 10

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:

Is Derived From NOI dated February 26, 2024
Incorporates Additional Information dated April 30, 2024
Incorporates Additional Information dated June 12, 2024

DAQE-IN162010001-24
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 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

Times-Independent
Publication Name:
Times-Independent
Publication URL:
www.moabtimes.com
Publication City and State:
Moab, UT
Publication County:
Grand
Notice Popular Keyword Category:
Notice Keywords:
running foxes
Notice Authentication Number:
202407111123219372377
3429962642
Notice URL:
Back
Notice Publish Date:
Thursday, July 11, 2024
Notice Content
NOTICE A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been
received for consideration by the Director: Company Name: Running Foxes Petroleum, Incorporated Location: Running Foxes Petroleum,
Incorporated - Grand Central Data Center – 3 Miles North of Exit 214 on I-70, Grand County, UT Project Description: Running Foxes
Petroleum, Incorporated has requested a new data center located in Grand County. The facility will process a raw natural gas stream using a
triethylene glycol (TEG) dehydrator. Liquids from the TEG dehydrator will flow into a produced water storage tank, where they are stored
prior to being transported offsite via tanker truck. The dry gas from the TEG dehydrator will pass through a JT skid to knock out any natural
gas liquids (NGLs). All NGLs will be stored in pressurized tanks before being transported offsite. The treated natural gas will be used as fuel
for eleven (11) 295-hp (220 kW) generator engines, which will power the data center. Each engine will be equipped with nonselective
catalytic reduction (NSCR) technology. Other sources of emissions include fugitive emissions, truck loading, pneumatic devices, and a water
storage tank. The completed engineering evaluation and air quality impact analysis showed the proposed project meets the requirements of
federal air quality regulations and the State air quality rules. The Director intends to issue an Approval Order pending a 30-day public
comment period. The project proposal, estimate of the effect on local air quality and draft Approval Order are available for public inspection
and comment at the Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments received by the Division
at this same address on or before August 10, 2024, will be considered in making the final decision on the approval/disapproval of the
proposed project. Email comments will also be accepted at [e-mail]. If anyone so requests to the Director in writing within
15 days of publication of this notice, a hearing will be held in accordance with R307-401-7, UAC. Under Section 19-1-301.5, a person who
wishes to challenge a Permit Order may only raise an issue or argument during an adjudicatory proceeding that was raised during the public
comment period and was supported with sufficient information or documentation to enable the Director to fully consider the substance and
significance of the issue. Date of Notice: July 11, 2024 SLT0028466
Back

DAQE-NN162010001-24

July 8, 2024

Times Independent Printing
Legal Advertising Dept.
P.O. Box 12935 E Center
Moab, UT 84532

RE: Legal Notice of Intent to Approve

This letter will confirm the authorization to publish the attached NOTICE in the Times Independent
Printing on July 11, 2024.

Please mail the invoice and affidavit of publication to the Utah State Department of Environmental
Quality, Division of Air Quality, P.O. Box 144820, Salt Lake City, Utah 84114-4820. If you have any
questions, contact Jeree Greenwood, who may be reached at [phone].

Sincerely,

{{$s }}

Jeree Greenwood
Office Technician

Enclosure

cc: Grand County
cc: Southeastern Association of Governments

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

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

DAQE-NN162010001-24
Page 2
NOTICE

A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah
Administrative Code (UAC), has been received for consideration by the Director:

Company Name: Running Foxes Petroleum, Incorporated
Location: Running Foxes Petroleum, Incorporated - Grand Central Data Center – 3 Miles
North of Exit 214 on I-70, Grand County, UT
Project Description: Running Foxes Petroleum, Incorporated has requested a new data center located
in Grand County. The facility will process a raw natural gas stream using a
triethylene glycol (TEG) dehydrator. Liquids from the TEG dehydrator will flow
into a produced water storage tank, where they are stored prior to being
transported offsite via tanker truck. The dry gas from the TEG dehydrator will
pass through a JT skid to knock out any natural gas liquids (NGLs). All NGLs
will be stored in pressurized tanks before being transported offsite. The treated
natural gas will be used as fuel for eleven (11) 295-hp (220 kW) generator
engines, which will power the data center. Each engine will be equipped with
nonselective catalytic reduction (NSCR) technology. Other sources of emissions
include fugitive emissions, truck loading, pneumatic devices, and a water storage
tank.

The completed engineering evaluation and air quality impact analysis showed the proposed project meets
the requirements of federal air quality regulations and the State air quality rules. The Director intends to
issue an Approval Order pending a 30-day public comment period. The project proposal, estimate of the
effect on local air quality and draft Approval Order are available for public inspection and comment at the
Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments
received by the Division at this same address on or before August 10, 2024, will be considered in making
the final decision on the approval/disapproval of the proposed project. Email comments will also be
accepted at [e-mail]. If anyone so requests to the Director in writing within 15 days of
publication of this notice, a hearing will be held in accordance with
R307-401-7, UAC.

Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or
argument during an adjudicatory proceeding that was raised during the public comment period and was
supported with sufficient information or documentation to enable the Director to fully consider the
substance and significance of the issue.

Date of Notice: July 11, 2024

{{#s=Sig_es_:signer1:signature}}

NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME LB/HR TONS/YR ZONE
EAST
(METERS)
NORTH
(METERS)DIA (FT)
VELO
(FPS)TEMP (oF)
VOC 0.02 0.11
BENZENE <0.01 <0.01
HAPs <0.01 0.01
VOC 0.27 1.17
BENZENE 0.00 0.01
HAPs 0.01 0.05
VOC 0.07 0.28 649405 4326489
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649411 4326489
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649417 4326489
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649423 4326489
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649430 4326489
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649437 4326490
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649405 4326481
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649411 4326481
NOx 7.48 32.76
CO 7.80 34.19
1371

GEN7 PSI 13L Generator 12S 10.5 0.5 157.5
1371
GEN6 PSI 13L Generator 12S 10.5 0.5 157.5 1371
GEN5 PSI 13L Generator 12S 10.5 0.5 157.5
1371
GEN4 PSI 13L Generator 12S 10.5 0.5 157.5 1371
GEN3 PSI 13L Generator 12S 10.5 0.5 157.5
1371
GEN2 PSI 13L Generator 12S 10.5 0.5 157.5 1371
GEN1 PSI 13L Generator 12S 10.5 0.5 157.5
N/A
PNEU Pneumatic Devices 12S 649435 4326443 3 N/A N/A N/A
FUGITIVES Fugitive Emissions:
Equipment Leaks
12S 649435 4326443 3 N/A N/A
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
EMISSION POINT CHEMICAL
COMPOSITION OF TOTAL
STREAM
AIR CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT.
STACK SOURCES
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT (FT)
EXIT DATA
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649417 4326481
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649423 4326481
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28 649430 4326481
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
BENZENE 0.01 0.01
H2S <0.01 <0.01
HAPs 0.03 0.06
VOC 0.07 0.28
BENZENE 0.30 <0.01
H2S <0.01 <0.01
HAPs 1.33 <0.01
TL-NGL NGL Loading VOC 0.07 0.28 12S 649435 4326443 3 N/A N/A N/A
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 0.02
HCHO <0.01 <0.01
HAPs 0.02 0.10
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: 4,300 ft
N/A
DEHYRB TEG Reboiler (0.50
MMBTU/Hr + DEHY)12S 649435 4326443 12 0.3 TBD 600
TL-W Water Loading 12S 649435 4326443 3 N/A N/A
1371
WTK1 Water Tank (300 BBL)12S 649435 4326443 20 N/A N/A N/A
GEN11 PSI 13L Generator 12S 10.5 0.5 157.5
1371
GEN10 PSI 13L Generator 12S 10.5 0.5 157.5 1371
GEN9 PSI 13L Generator 12S 10.5 0.5 157.5
GEN8 PSI 13L Generator 12S 10.5 0.5 157.5 1371

ZONE EAST
(METERS)
NORTH
(METERS)
LENGTH
(METERS)
WIDTH
(METERS)
HEIGHT
(METERS)
BLD1 12S 649469 4326482 9.5 6.2 3.1
BLD2 12S 649447 4326450 18.0 7.5 3.1
BLD3 12S 649447 4326414 5.9 8.5 1.5
UTM COORDINATES OF BUILDING DIMENSIONS ON BUILDING
BUILDING

DAQE-MN162010001-24

M E M O R A N D U M

TO: Dungan Adams, NSR Engineer

FROM: Dave Prey, Air Quality Modeler

DATE: April 4, 2024

SUBJECT: Modeling Analysis Review for the Notice of Intent for Running Foxes Petroleum
– Grand Central Data Center, Grand County, Utah
__________________________________________________________________________________________________
This is not a Major Prevention of Significant Deterioration (PSD) Source.

I. OBJECTIVE
Running Foxes Petroleum, Inc (Running Foxes) has submitted a Notice of Intent (NOI) for a new
data center located in Grand County. The facility will process a raw natural gas stream, sending
natural gas liquids (NGLs) offsite. The treated natural gas will be used as fuel for eleven (11)
generator engines which will power the data center. Each engine will be equipped with nonselective
catalytic reduction (NSCR) technology.

This report, prepared by the Staff of the New Source Review Section (NSR), contains a review of
the air quality impact analysis (AQIA) including the information, data, assumptions and modeling
results used to determine if the facility would be in compliance with State and Federal
concentration standards.

II. APPLICABLE RULE(S)

Utah Air Quality Rules:

R307-401-6 Condition for Issuing an Approval Order
R307-410-3 Use of Dispersion Models
R307-410-4 Modeling of Criteria Pollutants in Attainment Areas

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

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

DA
D
DP
DAQE-MN162010001-24
Page 2
III. MODELING METHODOLOGY

A. Applicability

Emissions from the facility include PM10, NOx, CO, SO2, and HAPs. This modeling is part of a
modified approval order. The emission rate for NOx warranted a modeling review to
demonstrate compliance with the one-hour NO2 NAAQS. Modeling was performed by the
UDAQ.

B. Assumptions

1. Topography/Terrain

The Plant is at an elevation 4632 feet with terrain features that have little affect on
concentration predictions.

a. Zone: 12

b. Approximate Location:

UTM (NAD83): 649405 meters East
4326489 meters North

2. Urban or Rural Area Designation

After a review of the appropriate 7.5 minute quadrangles, it was concluded the area is
“rural” for air modeling purposes.

3. Ambient Air

It was determined the Plant boundary used in the AQIA meets the State’s definition of
ambient air.

4. Building Downwash

The source was modeled with the AERMOD model. All structures at the plant were used in
the model to account for their influence on downwash.

5. Meteorology

Five (5) years of off-site surface and upper air data were used in the analysis consisting of
the following:

Surface – Canyonlands Airport, UT NWS: 2016-2020
Upper Air – Grand Junction, CO NWS: 2016-2020

DAQE-MN162010001-24
Page 3
6. Background

The background concentrations were based on concentrations measured in Price, Utah.

7. Receptor and Terrain Elevations

The modeling domain used consisted of receptors including property boundary receptors.
This area of the state contains mountainous terrain and the modeling domain has simple and
complex terrain features in the near and far fields. Therefore, receptor points representing
actual terrain elevations from the area were used in the analysis.

8. Model and Options

The State-accepted AERMOD model was used to predict air pollutant concentrations under
a simple/complex terrain/wake effect situation. In quantifying concentrations, the
regulatory default option was selected.

9. Air Pollutant Emission Rates

Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
GEN1 649405 4326489 0.33 1.45 8760
GEN2 649411 4326489 0.33 1.45 8760
GEN3 649417 4326489 0.33 1.45 8760
GEN4 649423 4326489 0.33 1.45 8760
GEN5 649430 4326489 0.33 1.45 8760
GEN6 649437 4326490 0.33 1.45 8760
GEN7 649405 4326481 0.33 1.45 8760
GEN8 649411 4326481 0.33 1.45 8760
GEN9 649417 4326481 0.33 1.45 8760
GEN10 649423 4326481 0.33 1.45 8760
GEN11 649430 4326481 0.33 1.45 8760
DEHYRB 649435 4326443 0.12 0.53 8760

Total 3.75 16.43
Nearby sources

Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
DAQE-MN162010001-24
Page 4
GEN1 657472 4330683 4.25 18.62 8760
GEN2 657472 4330692 4.25 18.62 8760
VCU 657350 4330612 0.94 4.12 8760
H1 657716 4330476 0.12 0.53 8760
FWPUMP1 657543 4330474 3.45 0.17 100
FWPUMP2 657550 4330474 3.45 0.17 100

Total 16.46 42.22
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
TURB1 642890 4310626 17.9001 78.402 8760
TURB2 642909 4310646 17.9001 78.402 8760
BOILR 642940 4310674 0.2500 1.095 8760
EGEN 642951 4310672 7.4700 1.868 500
Total 43.5202 159.7673
10. Source Location and Parameters

Source Type
Source Parameters
Elev, Ht Temp Flow Dia
(ft) (m) (ft) (K) (m/s) (m)
GEN1 POINT 4632.0 3.2 10.5 1017 48.01 0.15
GEN2 POINT 4632.0 3.2 10.5 1017 48.01 0.15
GEN3 POINT 4632.0 3.2 10.5 1017 48.01 0.15
GEN4 POINT 4631.9 3.2 10.5 1017 48.01 0.15
GEN5 POINT 4631.7 3.2 10.5 1017 48.01 0.15
GEN6 POINT 4631.6 3.2 10.5 1017 48.01 0.15
GEN7 POINT 4631.5 3.2 10.5 1017 48.01 0.15
GEN8 POINT 4631.6 3.2 10.5 1017 48.01 0.15
GEN9 POINT 4631.6 3.2 10.5 1017 48.01 0.15
GEN10 POINT 4631.6 3.2 10.5 1017 48.01 0.15
GEN11 POINT 4631.6 3.2 10.5 1017 48.01 0.15
DEHYRB POINT 4630.5 3.7 12.0 589 1.00 0.09
VCU POINT 4483.6 3.0 10.0 394 20.00 0.10
FWPUMP1 POINT 4478.9 4.9 16.0 726 1.56 1.52
H1 POINT 4505.5 3.0 10.0 533 10.00 0.20
FWPUMP2 POINT 4479.6 4.9 16.0 726 1.56 1.52
DAQE-MN162010001-24
Page 5
TURB1 POINT 4405.2 15.9 52.1 789 72.76 0.90
TURB2 POINT 4404.0 12.8 42.1 789 72.76 0.90
BOILR POINT 4403.7 5.6 18.5 478 12.19 0.41
EGEN POINT 4404.0 4.4 14.4 932 98.79 0.10
CT_GEN1 POINT 4491.6 8.5 28.0 701 10.56 0.41
CT_GEN2 POINT 4492.6 8.5 28.0 701 10.56 0.41

IV. RESULTS AND CONCLUSIONS

1. National Ambient Air Quality Standards

The below table provides a comparison of the predicted total air quality concentrations with the
NAAQS. The predicted total concentrations are less than the NAAQS.

Air
Pollutant Period Prediction Class II
Significant
Impact Level
Background Nearby
Sources* Total NAAQS Percent
(μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) NAAQS
NO2 1-
Hour 172.8 7.5 6.8 6.1 179.6 188 95.5%

DP:jg

Dungan Adams <[e-mail]>
Running Foxes NOI information request
18 messages
Dungan Adams <[e-mail]>Mon, Mar 11, 2024 at 3:42 PM
To: [e-mail]
Cc: [e-mail]
Hi Kat,
Thanks for reaching out last Thursday to introduce yourself and provide your contact information. I was out of the office
the past few days, so I apologize for missing your phone call.
Based on the proximity to other compressor stations in the area, our modeling department will conduct in house modeling
for NO2. Please provide the following information:
- The precise UTM coordinates for each of the engine's stacks (right now all engines are all listed with the same
UTM coordinates in Form11)
- Site plan with building locations and dimensions
Let me know if you have any questions.
Thanks,
Dungan

Dungan Adams
Environmental Engineer I | Minor NSR Section
M: [phone]
airquality.utah.gov
Form11.pdf
134K
Kat Galloway <[e-mail]>Mon, Mar 11, 2024 at 3:44 PM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Dear Mr. Adams,

We will get you this information asap.

6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…1/10
Thanks!
Kat

Kat Galloway
President

Bright Sky Environmental, LLC
11701 FM 2244, Suite 215-B
Bee Cave, Texas 78738
Phone: [phone]

[e-mail]
www.BrightSkyENV.com
[Quoted text hidden]
Dungan Adams <[e-mail]>Mon, Mar 11, 2024 at 3:46 PM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Great, thank you!
Thanks,
Dungan
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Kat Galloway <[e-mail]>Thu, Mar 14, 2024 at 10:54 AM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Dear Mr. Adams,

Please find attached revised plot plan and an excel workbook containing the modified coordinates of the 11
proposed generators and modeling information for the three buildings. Please let us know if you need any
additional information.

6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…2/10
Thanks,
[Quoted text hidden]
2 attachments
2024-03-14 Running Foxes Plot Plan.pdf
822K
2024-03-14 Running Foxes Stack parameters_buildings.xlsx
29K
Dungan Adams <[e-mail]>Thu, Mar 14, 2024 at 11:21 AM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Kat,
Great, thanks! I've forwarded this information to our modeling department and will let you know if they need anything
else.
Thanks,
Dungan
[Quoted text hidden]
Dungan Adams <[e-mail]>Fri, Mar 15, 2024 at 11:43 AM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Hi Kat,
Can you please provide the proposed height of the data center building?
Thanks,
Dungan
[Quoted text hidden]
Dungan Adams <[e-mail]>Tue, Apr 2, 2024 at 11:40 AM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Hi Kat,
I am following up about the proposed height of the data center building. Please provide this information as soon as
possible so our modeling can begin conducting in-house modeling.
Thanks,
Dungan
[Quoted text hidden]
Kat Galloway <[e-mail]>Tue, Apr 2, 2024 at 11:50 AM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
The building is 10’ high.

-Kat
6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…3/10
[Quoted text hidden]
Dungan Adams <[e-mail]>Tue, Apr 2, 2024 at 11:54 AM
To: Kat Galloway <[e-mail]>
Great, thanks.
-Dungan
[Quoted text hidden]
Dungan Adams <[e-mail]>Tue, Apr 23, 2024 at 4:59 PM
To: Kat Galloway <[e-mail]>
Cc: [e-mail]
Hi Kat,
The emission calculations you have submitted for the pneumatic devices depend on the count of pneumatic devices.
Because of that, the equipment will not be able to be titled "various pneumatic devices" in the Approval Order (AO). I'm
going to put in ten (10) pneumatic devices into AO since that is what was used to estimate emissions. If you end up using
less on site, there shouldn't be any compliance issues.
The other thing I wanted to bring up is 40 CFR 60 NSPS Subpart OOOOb (Standards of Performance for Crude Oil and
Natural Gas Facilities for Which Construction, Modification or Reconstruction Commenced After December 6, 2022).
Currently, the new Subpart is scheduled to be effective May 7, 2024, but there is some ongoing litigation with the rule as I
understand it. This project will eventually be subject to NSPS OOOOb as construction of the facility will commence after
December 6, 2022. I'm working on going through the rule and I've reached out to our compliance department to see how it
will impact projects like yours. I wanted to link the review of the rule here so you have it for reference.
I have just sent this project off for internal reviews. Let me know if you have any questions.
Thanks,
Dungan
[Quoted text hidden]
Kat Galloway <[e-mail]>Tue, Apr 23, 2024 at 6:05 PM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Thank you Mr. Adams,
We will certainly be addressing OOOOb compliance in an ongoing way.
-Kat
Sent from my iPhone
On Apr 23, 2024, at 5:59 PM, Dungan Adams <[e-mail]> wrote:
Hi Kat,
The emission calculations you have submitted for the pneumatic devices depend on the count of pneumatic
devices. Because of that, the equipment will not be able to be titled "various pneumatic devices" in the
Approval Order (AO). I'm going to put in ten (10) pneumatic devices into AO since that is what was used to
estimate emissions. If you end up using less on site, there shouldn't be any compliance issues.
The other thing I wanted to bring up is 40 CFR 60 NSPS Subpart OOOOb (Standards of Performance for
Crude Oil and Natural Gas Facilities for Which Construction, Modification or Reconstruction Commenced
After December 6, 2022). Currently, the new Subpart is scheduled to be effective May 7, 2024, but there is
some ongoing litigation with the rule as I understand it. This project will eventually be subject to NSPS
6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…4/10
OOOOb as construction of the facility will commence after December 6, 2022. I'm working on going through
the rule and I've reached out to our compliance department to see how it will impact projects like yours. I
wanted to link the review of the rule here so you have it for reference.
I have just sent this project off for internal reviews. Let me know if you have any questions.
Thanks,
Dungan
On Tue, Apr 2, 2024 at 11:54 AM Dungan Adams <[e-mail]> wrote:
Great, thanks.
-Dungan
On Tue, Apr 2, 2024 at 11:50 AM Kat Galloway <[e-mail]> wrote:
The building is 10’ high.

-Kat

Kat Galloway
President

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Bright Sky Environmental, LLC
11701 FM 2244, Suite 215-B
Bee Cave, Texas 78738
Phone: [phone]

[e-mail]
www.BrightSkyENV.com

6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…5/10
From: Dungan Adams <[e-mail]>
Sent: Monday, March 11, 2024 4:47 PM
To: Kat Galloway <[e-mail]>
Cc: [e-mail]
Subject: Re: Running Foxes NOI informaon request

Great, thank you!

Thanks,
Dungan

On Mon, Mar 11, 2024 at 3:44 PM Kat Galloway <[e-mail]> wrote:
Dear Mr. Adams,

We will get you this information asap.

Thanks!
Kat

Kat Galloway
President

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6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…6/10
image001.png
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Dungan Adams <[e-mail]>Tue, Apr 30, 2024 at 9:17 AM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Hi Kat,
Per our call earlier, here is discussion about the HAP emissions from the summary table. I've attached three pages of the
NOI for reference.
The uncontrolled emission summary table shows that each 220 kW engine produces 0.42 TPY of HAPs for a site-wide
total of 7.10 TPY. The controlled emission summary table shows that each 220 kW engine produces 0.04 TPY of HAPs for
a site-wide total of 0.69 TPY. The controlled HAPs summary table shows that each engine produces 0.42 TPY of HAPs (I
believe this is the uncontrolled #) for a site-wide total of 4.80 TPY. From adding up all of the individual HAPs and looking
at the emission rates of the engines I've proceeded with the 0.69 TPY site-wide HAPs because I believe it correctly
estimates controlled HAPs emitted from the facility.
If this is incorrect or I am missing something, please let me know.
Thanks,
Dungan
[Quoted text hidden]
2024_02_23_Grand_Central_Facility_NOI.pdf
104K
Dungan Adams <[e-mail]>Thu, Jun 6, 2024 at 3:39 PM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Hi Kat,
Both the Oil and Gas and New Source Review Compliance Departments wanted to review this project so I apologize for
the delay. The one question that was brought up from their reviews was about the pneumatic controllers present on site.
Subpart OOOOa requires that "each pneumatic controller affected facility at a location other than at a natural gas
processing plant must have a bleed rate less than or equal to 6 standard cubic feet per hour." Right now in the emission
calculations in the NOI, the bleed rate is 13.5 scf/hr/component. Are your controllers able to meet the 6 scf/hr rate? If not,
please provide justification.
Thanks,
Dungan
[Quoted text hidden]
Kat Galloway <[e-mail]>Wed, Jun 12, 2024 at 9:38 AM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Dear Mr. Adams,

6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…7/10
Running Foxes will be able to either run the pneumatics on low bleed (6 scf/hr) or instrument air to comply
with NSPS OOOOb.

Thanks,
Kat

Kat Galloway
President

[Quoted text hidden]
Dungan Adams <[e-mail]>Wed, Jun 12, 2024 at 1:12 PM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Great, thank you for this information. I am going to update the pneumatic controller emission calculations to use a
maximum bleed rate of 6 scf/hr. This will reduce fugitive VOC emissions from the controllers from 1.17 TPY to 0.52 TPY.
The site-wide VOC PTE will drop from 6.02 TPY to 5.37 TPY.
Please let me know if you have any questions or concerns.
Thanks,
Dungan
[Quoted text hidden]
Kat Galloway <[e-mail]>Wed, Jun 12, 2024 at 1:15 PM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
That sounds like a good plan!
-Kat
Sent from my iPhone
On Jun 12, 2024, at 2:12 PM, Dungan Adams <[e-mail]> wrote:
Great, thank you for this information. I am going to update the pneumatic controller emission calculations to
use a maximum bleed rate of 6 scf/hr. This will reduce fugitive VOC emissions from the controllers from
1.17 TPY to 0.52 TPY. The site-wide VOC PTE will drop from 6.02 TPY to 5.37 TPY.
Please let me know if you have any questions or concerns.
Thanks,
Dungan
6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…8/10
On Wed, Jun 12, 2024 at 9:38 AM Kat Galloway <[e-mail]> wrote:
Dear Mr. Adams,

Running Foxes will be able to either run the pneumatics on low bleed (6 scf/hr) or instrument
air to comply with NSPS OOOOb.

Thanks,
Kat

Kat Galloway
President

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Dungan Adams <[e-mail]>Tue, Jun 18, 2024 at 12:58 PM
To: Kat Galloway <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
Hi Kat,
After further discussion with our compliance section, 40 CFR 60 Subpart OOOOb has stricter requirements for pneumatic
devices (process controllers) than Subpart OOOOa. I've linked the language here if you would like to review. From my
understanding, all pneumatic devices at OOOOb affected facilities must design and operate pneumatic devices with zero
methane or VOC emissions to the atmosphere. The emissions should be either routed to a process through a closed vent
system or a self contained natural gas-driven controller should be used. I've gone ahead and removed the 1.17 tpy of
VOC emissions that were previously associated with bleed rate from the pneumatic devices from the site-wide totals. I
apologize for any confusion this has caused. Do you have any questions or concerns with meeting this requirement?
My manager is currently reviewing this project and I should have the draft permit for you to review soon.
Thanks,
Dungan
[Quoted text hidden]
Kat Galloway <[e-mail]>Tue, Jun 18, 2024 at 1:36 PM
To: Dungan Adams <[e-mail]>
Cc: "[e-mail]" <[e-mail]>
6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-68465024489804…9/10
Dear Mr. Adams,
The site can do instrument air if needed. We are fine with removing the emissions from the controllers altogether.
Looking forward to getting this finalized!
Thanks,
Kat
Sent from my iPhone
[Quoted text hidden]
6/18/24, 1:55 PM State of Utah Mail - Running Foxes NOI information request
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-a:r4985569464902141154&simpl=msg-a:r-6846502448980…10/10
14550 E Easter Ave #100
Centennial, CO 80112
runningfoxes.com
Mr. Alan Humpherys
Utah Department of Environmental Quality
195 North 1950 West
Salt Lake City, Utah 84116
Re: Running Foxes Petroleum, Inc.
Grand Central Facility
Grand County, Utah
Notice of Intent (NOI) for Construction and Operation
Dear Mr. Humpherys:
Running Foxes Petroleum, Inc. (“Running Foxes”) is submitting the enclosed NOI application for the Grand Central
Facility centralized tank battery in Grand County. Based on the potential emissions, the Grand Central Facility
will be a minor source for all criteria pollutants and hazardous air pollutants.
The documentation provided includes a process description, process flow diagram, potential emissions
calculations, and rule applicability for the centralized tank battery.
The current schedule is to begin construction and operation as soon as physically possible. Any assistance Utah
Department of Environmental Quality can provide to help Running Foxes meet this schedule would be greatly
appreciated.
If you have any questions, please contact Ms. Kat Galloway with Bright Sky Environmental at [e-mail]
and 281-217-8233.
Sincerely,
Steven Tedesco
Running Foxes Energy Inc.

Running Foxes Petroleum

Notice of Intent (NOI) for Construction and Operation

Grand Central Facility
Grand County, Utah

__
February 2024

Page | 1
Contents
1.0 Project Description. ............................................................................................................................................ 3
2.0 Process Description ............................................................................................................................................ 4
2.1 Emissions Impact Assessment .............................................................................................................................. 4
3.0 Emissions Calculations ............................................................................................................................................. 7
3.1 Gas and Liquid Analyses .............................................................................................................................. 7
3.2 Dehydrator Emissions .................................................................................................................................. 7
3.3 Storage Tank Emissions ............................................................................................................................... 7
3.4 External Combustion Sources ...................................................................................................................... 7
3.5 Engines ......................................................................................................................................................... 8
3.6 Fugitive Emissions ........................................................................................................................................ 8
3.7 Truck Loading ............................................................................................................................................... 9
3.8 Pneumatic Devices ....................................................................................................................................... 9
4.0 BACT Analysis ......................................................................................................................................................... 11
4.1 TEG Dehydration Unit ................................................................................................................................ 12
4.2 Engines ....................................................................................................................................................... 12
4.3 Storage Tank .............................................................................................................................................. 13
4.4 Liquid Loading ............................................................................................................................................ 13
4.5 Fugitive Emissions ...................................................................................................................................... 14
4.6 NGL Loading Emissions .............................................................................................................................. 14
5.0 REGULATORY APPLICABILITY ................................................................................................................................. 14
5.1 R307-401-1 General Requirements ........................................................................................................... 14
5.2 R307-505 Oil and Gas Industry: Registration Requirements ..................................................................... 15
5.3 R307-506 Oil and Gas Industry: Storage Vessel ......................................................................................... 15
5.4 R307-504 Oil and Gas Industry: Tank Truck Loading ................................................................................. 17
5.5 R307-507 Oil and Gas Industry: Dehydrators ............................................................................................ 17
5.6 R307-508 Oil and Gas Industry: VOC Control Devices ............................................................................... 18
5.7 R307-509 Oil and Gas Industry: Leak Detection and Repair Requirements .............................................. 19
5.8 R307-510 Oil and Gas Industry: Natural Gas Engine Requirements .......................................................... 20
5.9 R307-511 Oil and Gas Industry: Associated Gas Flaring ............................................................................ 21
5.10 Federal Rule Applicability .......................................................................................................................... 22

Page | 2

Appendix A – Emission Summary, Calculations, Process Modeling
Appendix B – Engine Specification Sheet, Gas Sample
Appendix C – Area Map
Appendix D – Forms

Page | 3

1.0 PROJECT DESCRIPTION
Running Foxes Petroleum, Inc. (“Running Foxes”) is submitting the NOI for construction and operation of the Grand
Central Facility, a centralized tank battery located in Grand County, Utah.
The facility will be located in Grand County, Utah, an area that is classified as attainment for all National Ambient Air
Quality Standards (NAAQS).
The facility is not a new major stationary source under the new source review requirements of the FCAA, Part C
(PSD). Oil and gas production operations are not a listed source category under 40 CFR §52.21(b)(1); therefore, the
facility would be considered a major source if criteria pollutant emissions are greater than or equal to the major
source threshold of 250 tpy for each pollutant. The maximum annual emission rates for each criteria pollutant are
less than 250 tpy. Therefore, the facility will be a minor source as defined in the rules, and PSD review is not triggered.
Furthermore, Title V permitting requirements are not applicable since the Title V major source thresholds are not
exceeded.
Enclosed are the required application materials consisting of the following: a process description, process flow
diagram, air emissions spreadsheets, laboratory analyses, and other documentation supporting the Permit by Rule
claim.

Page | 4

2.0 PROCESS DESCRIPTION
Running Foxes Petroleum is submitting the registration for the Grand Central Facility located in Grand County,
Utah. The centralized tank battery will consist of the following equipment:
 One (1) 300 barrel produced water tank;
 One (1) 0.4 million standard cubic feet per day (MMSCFD) triethylene glycol dehydrator with a flash tank
and BTEX condenser;
 One (1) 0.5 MMBtu/hr reboiler;
 Water loading;
 One JT skid (non-emitting);
 Two natural gas liquids (NGL) pressurized bullet tanks (non-emitting);
 NGL loadout points;
 Fugitive leak emissions; and
 Eleven (11) PSI 13L 220 kW generator engines with NSCR catalysts.

The purpose of the Facility is to collect intermediate hydrocarbon liquids and produced water not located at the well
sites, to dehydrate the gas for on-site use and, and monetize NGLs produced from the hydrocarbon value chain. The
natural gas stream enters the well site through a glycol dehydrator to remove water. The dry gas then passes through
a JT skid to knock out any NGLs before the gas is used to power generators. Any NGLs are sent to a bullet tank and
transported offsite. Liquids from dehydration flow into the produced water storage tanks where they are stored
prior to being transported offsite via tanker truck. The natural gas is consumed by generators for onsite use.
2.1 Emissions Impact Assessment
The potential emissions from the facility are presented below in Table 2-1 and compared to Utah Division of Air
Quality (UDAQ) modeling thresholds.
Table 2-1 Facility Potential Emissions
Pollutant Facility Potential Emissions
(ton/yr)
UDAQ Modeling Threshold
(ton/yr)
Carbon Monoxide 17.41 100
Lead -- 0.6
Oxides of Nitrogen 16.17 40
Particulate Matter < 2.5µm (PM2.5) 1.38 10 (fugitive & non-fugitive)
Particulate Matter < 10µm (PM10) 1.38 15 (non-fugitive) 5 (fugitive)
Sulfur Dioxide (SO2) 0.08 40
Source: UDAQ R307-410-4

Page | 5

Based on the Table 2-1 above, an emissions impact assessment is not required for criteria pollutants.
UAC R307-410-5 requires sources proposing any increase of HAPs emissions to submit all HAP emission levels and
pollutant release information for their facility. An evaluation for hazardous air pollutants was then conducted based
on the procedures outlined in R307-410-5. No HAP emissions are expected to exceed the emission threshold values
(ETV) for vertically unrestricted and restricted emission release points, as shown in Table 2-1 below.

Table 2-1 Facility Hazardous Air Pollutant Emissions Pollutants
Pollutant ETV
Type
Unrestricted
ETV < 50
metersa
(lb/hr)
Project
Unrestricted
emissions
(lb/hr)
Emissions
> ETV?
Restricted
ETV < 20
meters
(lb/hr)
Project Vertically
Restricted/Fugitive
Releases < 20 m
Emissions
> ETV?
Acetaldehyde Acute 6.9363 0.01 NO
Acrolein Acute 0.0353 0.01 NO
Benzene Chronic 0.3163 0.31 NO 0.0815 0.0089 NO
Ethylbenzene Chronic 17.194 6.53E-05 NO 4.429 0.0005 NO
Formaldehyde Acute 0.0567 0.05 NO
n-hexane Chronic 34.895 0.88 NO 8.988 0.01 NO
Methanol Chronic 55.132 0.098 NO
Toluene Chronic 14.922 0.16 NO 3.843 0.003 NO
Xylenes Chronic 85.97 0.03 NO 22.144 0.002 NO
a. Unrestricted emissions include engines, reboiler, tank, and loading. Vertically restricted emissions include
fugitive emissions, pneumatic devices, and NGL loading fugitives.

Page 1
December 2023 Grand Central Facility
Water Tanks (1) Water Water Truck Loading
Glycol
Dehydrator
Flash Gas
TEG Reboiler
Residual Glycol
Rich Glycol
Condenser
JT Skid
Condenser Liquids
Flash Tank Liquids
Glycol Flash Tank
Glycol
Regenerator
Lean Glycol
GasWet Gas
Flash Gas
Dry Gas
Facility Inlet
371 MSCFD
Generators Lean Gas
Natural Gas Liquids Bullet Tank Natural Gas Liquids NGL Truck Loading

Page | 7

3.0 Emissions Calculations
3.1 Gas and Liquid Analyses
The composition and physical properties of the gas are an average of the wells routed to the central tank battery.
Appendix C contains sampling data. The gas is sweet.
3.2 Dehydrator Emissions
A glycol dehydrator is used to remove water from the gas stream. The glycol dehydration unit includes a flash tank,
a glycol regenerator still, and a 0.5 MMBtu/hr reboiler.
Fuel Type & Quantity: The TEG dehydrator will have a field gas processing rate of 371,000 scf/day and 135 MMscf/yr.
Raw Materials & Final Products: No raw materials will be used, or final products created for the reboiler.
Operating Schedule: The dehydrator will have a normal operating schedule of 24 hours per day, 7 days per week, 52
weeks per year for a total of 8,760 hours per year.
Emissions Controls & Factors: The regenerator vent will be controlled by a condenser before being routed to the
reboiler. The reboiler burner management system sends the regenerator vent and flash tank vent to be combusted
in the reboiler with a 96% destruction efficiency. All dehydrator emissions were calculated using BR&E ProMax 6.0.
3.3 Storage Tank Emissions
The facility will have one 300 bbl produced water storage tank.
Fuel Type & Quantity: Not applicable
Raw Materials & Final Products: No raw materials will be used, or final products created for the storage tank.
Operating Schedule: Not applicable.
Emissions Controls & Factors: Emissions of volatile organic compounds (VOC) and hazardous air pollutants (HAPs)
from the produced water tank were estimated using BRE ProMax Process Simulator. This model accounts for both
flash emissions from the change in liquid stream pressure from the separator to ambient conditions and working
and breathing losses from the tanks. The emissions are based on the average daily processing rates, design operating
pressure and temperature of separators, and the physical properties of the process stream. Hourly and annual tank
flash and working/breathing emissions are conservatively based on the maximum storage tank liquid surface
temperature and maximum daily throughput. The tank emits less than 1 TPY VOC and is uncontrolled.
3.4 External Combustion Sources
A 0.5 MMBtu/hr reboiler will be located at the site.
Fuel Type & Quantity: The reboiler will have a field gas consumption rate of 470 scf/hour and 4.13 MMscf/yr.
Raw Materials & Final Products: No raw materials will be used, or final products created for the reboiler.
Operating Schedule: The reboiler will have a normal operating schedule of 24 hours per day, 7 days per week, 52
weeks per year for a total of 8,760 hours per year.
Emissions Controls & Factors: There are no controls associated with the glycol reboiler. External combustion source
emissions were calculated in accordance with AP-42 Section 1.4 (July 1998), using emission factors for small boilers
(less than 100 MMBtu/hr rating).

Page | 8

3.5 Engines
Eleven (11) small 4-stroke rich burn natural gas fired 220 kW PSI 13L generator engines will be located at the facility.
The engines are subject to and will comply with 40 CFR 60, Subpart JJJJ and 40 CFR 63, Subject ZZZZ. The engines will
consume the dehydrated gas and additional field gas to produced power used onsite at the facility.
Fuel Type & Quantity: The engines will have a total combined field gas rate of 24,606 cubic feet per hour (scf/hr),
590,544 scf/day, and 215.6 MMscf/year. The estimated heating value of the field gas is 1,065 Btu/scf. The percent
sulfur of the fuel is assumed to be a maximum of 25 ppm.
Raw Materials & Final Products: No raw materials will be used, or final products created for the engines.
Operating Schedule: The engines will have a normal operating schedule of 24 hours per day, 7 days per week, 52
weeks per year for a total of 8,760 hours per year.
Emissions Controls & Factors: Engine emissions were calculated in accordance with AP-42, according to fuel type
and engine type, and vendor specific emission factors. See engine specification sheet in Appendix B. Each engine will
be equipped with an NSCR catalyst, and following vendor manufacturer specifications:
 NOx: 0.50 g/hp-hr
 CO: 0.50 g/hp-hr
 VOC: 0.05 g/hp-hr
Hazardous air pollutants that are also VOCs are reduced by the same efficiency as the VOCs. This is footnoted in the
emissions calculations.
3.6 Fugitive Emissions
Equipment components in liquid service such as flanges, valves, connectors, open-ended lines, and pressure relief
valves as well as equipment components in gas service such as flanges, valves, connectors, open-ended lines, and
pressure relief valves, have the potential to leak hydrocarbon emissions during normal operations.

Fuel Type & Quantity: Not applicable.
Raw Materials & Final Products: No raw materials will be used, or final products created for the fugitive emissions.
Operating Schedule: Not applicable
Emissions Controls & Factors: There are no controls associated with the component fugitive emissions. Based on
the facility’s equipment counts, the number of components was estimated using 40 CFR Part 98 Subpart W Tables
W-1B and W-1C for production equipment in the Western United States. The total number of components in each
service was multiplied by the kilogram per hour emission factors obtained from, EPA- 453/R-95-017: Protocol for
Equipment Leak Emissions Estimates Table 2-4 to determine the total mass emitted from each component by service.

Page | 9

3.7 Truck Loading
Produced water may be loaded via truck.
Fuel Type & Quantity: Not applicable.
Raw Materials & Final Products: No raw materials will be used, or final products created for the storage tank.
Operating Schedule: It is expected that a truck may load up to 8,000 gallons per hour and 8,400 gallons per year.
Emissions Controls & Factors: Emissions from truck loading (EPN: TL1) of the produced water were estimated using
the loading losses emission factor based on Equation 1 from USEPA AP-42, Chapter 5.2 Transportation and Marketing
of Petroleum Liquids, dated June 2008:
LL = ଵଶ.ସ଺∗ௌ௉ெ
்
Where:
LL = loading losses (lb/Mgal);
S = saturation factor (dimensionless);
P = true vapor pressure of the liquid loaded (psia);
M= vapor molecular weight (lb/lbmol); and
T = temperature of the liquid loaded (R).
The saturation factors are provided in USEPA AP-42 Table 5.2-1. The saturation factor for the submerged loading of
a dedicated normal service truck was used. The Vapor Molecular Weight (M) is assumed to be the produced water
W&B gas molecular weight. VOC emissions assume the VOC and HAP speciation are based on the W&S composition
from the Promax results. Truck loading emissions are 0.02 TPY VOC and are uncontrolled.
3.8 Pneumatic Devices
Pneumatic devices may be present at the site.
Fuel Type & Quantity: Not applicable.
Raw Materials & Final Products: No raw materials will be used, or final products created for the pneumatic devices.
Operating Schedule: Pneumatic devices are actuated intermittently as-needed.
Emissions Controls & Factors: VOC emissions from pneumatic devices were calculated by multiplying the component
bleed rate by the total count of pneumatic devices and adjusted for the molar volume of VOC in the gas stream
composition. Although the devices at the facility are intermittent bleed, they were calculated assuming continuous
operation.

Emissions (TPY) = Total Bleed Rate (MMscf/hr) * Gas Molecular Weight (lb/lbmole) * Weight Percent VOC or HAP *
1/molar volume conversion (379.3 scf/lbmole) * 8760 hr/yr * 1 ton/2000 lb
3.9 NGL Loading

Natural gas liquids (NGLs) that accumulate in the Facility inlet following will be stored at pressure until loaded
offsite via tanker truck.

Page | 10

Fuel Type & Quantity: Not applicable.
Raw Materials & Final Products: No raw materials will be used, or final products created for the loading.
Operating Schedule: The estimated maximum number of truck loads per year will be six per year. The loading
events will occur on an as-needed basis.
Emission Controls & Factors: NGLs will be stored under pressure until loadout. Therefore, NGL storage
will not result in emissions to the atmosphere. Emissions from NGL loadout are based on truck loadout vent
line design and a conservative estimate of 100% VOC.

Page | 11

4.0 BACT Analysis
Utah Administrative Code (UAC) R307-401-2 defines BACT as:

“An emissions limitation (including a visible emissions standard) based on the maximum degree of reduction
for each air pollutant which would be emitted from any proposed stationary source or modification which
the director, on a case-by-case basis, taking into account energy, environmental, and economic impacts and
other costs, determines is achievable for such source or modification through application of production
processes or available methods, systems, and techniques, including fuel cleaning or treatment or innovative
fuel combustion techniques for control of such pollutant. In no event shall application of best available
control technology result in emissions of any pollutant which would exceed the emissions allowed by any
applicable standard under 40 CFR Parts 60 and 61. If the director determines that technological or economic
limitations on the application of measurement methodology to a particular emissions unit would make the
imposition of an emissions standard infeasible, a design, equipment, work practice, operational standard or
combination thereof, may be prescribed instead to satisfy the requirement for the application of best
available control technology. Such standard shall, to the degree possible, set forth the emissions reduction
achievable by implementation of such design, equipment, work practice or operation, and shall provide for
compliance by means which achieve equivalent results.”

UAC R307-401-8(1)(a) indicates that one condition for issuance of the AO is that the degree of pollution control for
emissions, including fugitive emissions, is at least BACT. Pollutants from the Facility include PM10, PM2.5, NOx,
SO2, CO, VOC, HAPs, and GHG.

Running Foxes proposes the following BACT for the Grand Central Facility:

Emission Source BACT
TEG Dehydration Unit  Regenerator vent controlled by a BTEX condenser.
 Post-condenser regenerator vent routed to the reboiler for
96% destruction.
 Flash tank routed to the reboiler for 96% destruction.
 The closed vent system will be inspected regularly for
defects that can result in air emissions.
Natural Gas Generators  Each engine is equipped with an NSCR catalyst
Produced Water Tank

VOC with partial pressure ≥ 0.5 psia at
maximum liquid surface temperature or
95 F (whichever is greater), and with
uncontrolled PTE of < 5 tpy from
working and breathing losses, including
flash emissions.

 Submerged fill
 Un-insulated tank exterior surfaces exposed to the sun shall
be of a color that minimizes the effects of solar heating
(including, but not limited to, white or aluminum). To meet
this requirement the solar absorptance should be 0.43 or
less, as referenced in Table 7.1-6 in AP-42. Paint shall be
maintained in good condition.
Truck Loading

VOC with partial pressure < 0.5 psia at
maximum liquid surface temperature or
95 F whichever is greater, or with
uncontrolled PTE of < 5 tpy VOC
 Loading performed with submerged filling

Page | 12

4.1 TEG Dehydration Unit
Running Foxes intends to route regenerator vapors to a BTEX condenser followed by the reboiler for 96% destruction
of the VOC emissions from the unit. Additionally, flash tank vapors will be routed to the reboiler for 96% control. The
closed vent system will be inspected regularly for defects that can result in air emissions. If defects are discovered,
the defects will be corrected or repaired as determined by the leak detection and repair (LDAR) program. Potential
VOC emissions will be less than 2 ton/yr VOC and benzene PTE will be less than 1 ton/yr.

The facility will include (1) 0.5 MMBtu/hr, natural gas tank heater. The NOx, CO, VOC, PM10, PM2.5, SO2, and HAPs
emissions are each less than 0.25 tons per year. Therefore, additional addon controls are technically infeasible due
to the inconsistent and low volume of emissions. Running Foxes proposes BACT to control emissions from the tank
heater is best operating practices and to limit opacity to 10%. DAQ has approved this limit as BACT within the last 30
days for other Approval Orders.
4.2 Engines
The proposed engines will be subject to 40 Code of Federal Regulations (CFR) Part 60 New Source Performance
Standards (NSPS) Subpart JJJJ and Part 63 National Emissions Standards for Hazardous Air Pollutants (NESHAP)
Subpart ZZZZ. The applicable emission limit for NOx is 1.0 grams per horsepower-hour (g/hp-hr), 2.0 g/hp-hr CO, and
0.7 g/hp-hr VOC for RICE units manufactured after January 1, 2011 with an engine power rating between 100 hp and
500 hp.

Proposed emission levels associated with NSCR for the proposed PSI 13L engine models for each pollutant and
emissions levels associated with this application are as follows:
 NOx: 0.50 g/hp-hr
 CO: 0.50 g/hp-hr
 VOC: 0.05 g/hp-hr
NOx
NOx emissions from natural gas-fired engines occurs primarily through the formation of thermal NOx. Thermal NOx
is created by the thermal dissociation and subsequent reaction of nitrogen (N2) and oxygen (O2) molecules in the
combustion air. Factors affecting the generation of NOx include flame temperature, residence time, quantity of
excess air, and nitrogen content of the fuel. Available pre-combustion controls include air-to-fuel ratio control and
ignition system controls. Available post-combustion catalytic technologies include selective catalytic reduction (SCR).
An SCR requires a specific exhaust temperature 480o F to 800o F) for optimal destruction. Because the compressor
engines within this application do not meet the required range, use of an SCR is not technically feasible.

The engine manufacturer has certified the engine to NSPS JJJJ standards (i.e. 1 g/hp-hr), and Running Foxes has
elected to equip each engine with an NSCR system that will limit NOx emission rates to 0.50 g/bhp-hr in each 220
kW engine. This emission rate is below the limit of 1.0 g/hp-hr of NOx specified in 40 CFR 60 Subpart JJJJ, and DAQ
has approved this limit as BACT within the last 30 days for other Approval Orders.
Carbon Monoxide (CO)
CO emissions from natural gas combustion occur due to incomplete combustion. CO is generated when there is
insufficient time at high temperature to complete the final step in hydrocarbon oxidation.
The engine manufacturer has certified the engine to NSPS JJJJ standards (i.e. 2.0 g/hp-hr), and Running Foxes has
elected to equip each engine with an NSCR system that will limit CO emission rates to 0.50 g/bhp-hr in each 220 kW

Page | 13

engine. This emission rate is below the limit of 2.0 g/hp-hr of CO specified in 40 CFR 60 Subpart JJJJ, and DAQ has
approved this limit as BACT within the last 30 days for other Approval Orders.
VOCs/HAPs
VOC emissions from natural gas combustion occur due to incomplete combustion. Many HAP components are
emitted through the same process as VOCs and the control technologies for VOCs also control HAPs.
The engine manufacturer has certified the engine to NSPS JJJJ standards (i.e. 0.7 g/hp-hr), and Running Foxes has
elected to equip each engine with an NSCR system that will limit VOC emission rates to 0.05 g/bhp-hr in each 220
kW engine. This emission rate is below the limit of 0.7 g/hp-hr of VOC specified in 40 CFR 60 Subpart JJJJ, and DAQ
has approved this limit as BACT within the last 30 days for other Approval Orders.
PM10/PM2.5
The combustion of natural gas in the engines will result in minor PM10/PM2.5 emissions. NSPS 40 CFR 60 Subpart JJJJ
does not set PM emission limits for these types of engines. Available control options for PM emissions include
conducting proper maintenance and good combustion practices. Running foxes proposes scheduled maintenance
program for these engines as BACT. DAQ has approved this limit as BACT within the last 30 days for other Approval
Orders.
Sulfur Dioxide (SO2)
Sulfur dioxide emissions are a result of sulfur present in natural gas. The only control option identified for reducing
SO2 is the use of good combustion practices. Running Foxes proposes a scheduled maintenance program for these
engines. DAQ has approved this limit as BACT within the last 30 days for other Approval Orders.
4.3 Storage Tank
Emissions from the storage tank results from displacement of headspace vapor during filling operations (working
losses) and from diurnal temperature and heating variations (breathing losses). Typically, filling losses constitute 80-
90% of the total losses for fixed roof tanks. For the storage tanks, the control technologies that were evaluated
include a vapor recovery system, submerged filling of tanks, and flaring. Vapor recovery systems typically control
highly volatile substances with high VOC waste streams. The storage tanks operate at a very low vapor pressure,
making this option technically infeasible. The storage tanks will be submerged filled to reduce working losses and
painted a light color to reduce breathing losses. The potential emissions from the storage tank are less than 1 TPY
VOC.
Additional control technology for the storage tanks includes good operating practices and maintenance. Running
Foxes will conduct proper maintenance and operating practices on the tank. Thief hatches on the storage tanks shall
be kept closed and latched except during vessel unloading or other maintenance activities.
4.4 Liquid Loading
Emissions from liquid loading operations are equal to 0.02 tpy of VOCs and less than 0.01 tpy of HAPs.
Using a pressurized tank transport vehicle to receive the oil/condensate can significantly reduce emissions from
VOCs. Running Foxes will use pressured vessels to loadout the liquids from the NGL bullet tanks. For the
unpressurized produced water loadout operations, Running Foxes will load the trucks on site by the use of bottom
filling or a submerged fill pipe. This reduces VOC emissions and is considered BACT. Additional add-on controls are
technically infeasible due to the inconsistent and low volume of VOC/HAPs emissions. DAQ has approved this limit
as BACT within the last 30 days for other Approval Orders.

Page | 14

4.5 Fugitive Emissions
Operations at the facility will generate fugitive VOC emissions. Running Foxes proposes BACT to control fugitive VOC
emissions is the implementation of a fugitive leak detection and repair program per NSPS OOOOa. DAQ has approved
this limit as BACT within the last 30 days for other Approval Orders.
4.6 NGL Loading Emissions
Emissions from NGL storage will not result in emissions to the atmosphere. However, VOC emissions will be released
during truck loadout operations. BACT to control VOC emissions from truck loadout is proposed to be best operating
practices. DAQ has approved this procedure as BACT within the last 30 days for other Approval Orders.
5.0 REGULATORY APPLICABILITY
The facility will have NGL and produced water storage preceded by a dehydrator. Utah R307-401-10(5) exemption
includes centralized tank batteries. Per the definition of centralized tank batteries in 307-506-2," Centralized Tank
Battery" means a separate tank battery surface site collecting crude oil, condensate, intermediate hydrocarbon
liquids, or produced water from wells not located at the well site.” Further, the site does not meet the definition of
a natural gas processing plant per NSPS OOOO/OOOOa, which is §60.5430a “any processing site engaged in the
extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or
both. A Joule-Thompson valve, a dew point depression valve, or an isolated or standalone Joule-Thompson skid is
not a natural gas processing plant.”
Per NSPS OOOO/OOOOa, the facility is not a natural gas processing plant and is not a compressor station. Per NSPS
OOOO/OOOOa, the facility is classified as a “separate tank battery surface site collecting intermediate hydrocarbon
liquids and produced wells not located at the well site (e.g., centralized tank batteries),” which is included in the
§60.5430a definition of a well site. According to the language of the NSPS and the R307-401-10(5) rule, the facility
qualifies for an exemption to obtain an approval order. The site will be subject to the General Requirements of R307-
401-4 and the registration requirements of R307-505.
5.1 R307-401-1 General Requirements

Running Foxes will comply with the R307-401-1 General Requirements as follows:
(1) Any control apparatus installed on an installation shall be adequately and properly maintained.

Running Foxes will maintain all equipment as required by the rule.

(2) If the director determines that an exempted installation is not meeting an approval order or State Implementation
Plan limitation, is creating an adverse impact to the environment, or would be injurious to human health or welfare,
the director may require the owner or operator to submit a notice of intent and obtain an approval order in
accordance with Sections R307-401-5 through R307- 401-8. The director will complete an appropriate analysis and
evaluation in consultation with the owner or operator before determining that an approval order is required.

Running Foxes acknowledges this rule.

Page | 15

(2) Low Oxides of Nitrogen Burner Technology.

(a) Except as provided in Subsection R307-401-4(3)(b), whenever existing fuel combustion burners are replaced, the
owner or operator shall install low oxides of nitrogen burners or equivalent oxides of nitrogen controls, as determined
by the director, unless such equipment is not physically practical or cost effective. The owner or operator shall submit
a demonstration that the equipment is not physically practical or cost effective to the director for review and approval
prior to beginning construction.

Running Foxes will maintain an industry-standard burner for its 0.5 MMBtu/hr dehydrator reboiler.

(b) The provisions of (a) above do not apply to non-commercial, residential buildings.

(4) A person shall not operate a source of air pollution that is required to have a permit under Rule R307-401 unless
the person has obtained a permit for the source under the procedures of Rule R307-401.

Running Foxes acknowledges this rule.
5.2 R307-505 Oil and Gas Industry: Registration Requirements
R307-505 applies to new and existing operations at a source with Standard Industrial Classification codes in the major
group 13, which includes but is not limited to industries involved in oil and natural gas exploration, production, and
transmission operations; well production facilities; natural gas compressor stations; natural gas processing plants
and commercial oil and gas disposal wells, and evaporation ponds.
The Grand Central Facility is a new operation at a source in the major group 13 and is a central tank battery.
R307-505-3. Registration Requirements.
(1) An owner or operator of a source identified in R307-505-2 that begins operations on or after January 1, 2018, shall
register with the director 30 days prior to commencing operation.
(2) An owner or operator of a source identified in R307-505-2 that is in operation before January 1, 2018, shall register
with the director by July 1, 2018.
(3) An owner or operator shall update the registration information within 30 days of any of the following:
(a) changes to company name,
(b) removal or addition of control devices, or
(c) termination of operations.
(4) Registration shall be completed online in a format provided by the Division and shall include the following general
information: company name, mailing address, source location, source manager or point of contact, process
description, capacity and quantity of emitting equipment on-site, fuel type of combustion related equipment (i.e.
diesel, natural gas, propane, or field gas), emissions control devices installed, emissions and certification that the
facility is in compliance with R307-506 through R307-510.

This registration application is being submitted to the director at least 30 days prior to commencing operation and
meets the requirements of the rule.
5.3 R307-506 Oil and Gas Industry: Storage Vessel
R307-506 applies to each storage vessel located at a well site as defined in 40 CFR 60.5430a, Subpart OOOOa,
Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution.
(2) R307-506 shall apply to centralized tank batteries.

Page | 16

(3) R307-506 does not apply to storage vessels that are subject to an approval order issued under R307-401-8.
This rule is applicable to the proposed centralized tank battery.
R307-506-4. Storage Vessel Requirements.
(1) Thief hatches on storage vessels shall be kept closed and latched except during vessel unloading or other
maintenance activities.

Running Foxes will comply with this requirement.

(2) All storage vessels located at a well site that are in operation as of January 1, 2018, with a site-wide throughput
of 8,000 barrels or greater of crude oil or 2,000 barrels or greater of condensate per year on a rolling 12-month basis
shall comply with R307-506-4(2)(a) unless the exemption in R307-506-4(2)(b) applies.
(a) VOC emissions from storage vessels shall either be routed to a process unit where the emissions are recycled,
incorporated into a product and/or recovered, or be routed to a VOC control device that is in compliance with R307-
508.
(b) All storage vessels located at a well site shall be exempt from R307-506-4(2)(a) if combined VOC emissions are
demonstrated to be less than four tons per year of uncontrolled emissions on a rolling 12-month basis.
(i) VOC working and breathing losses, and flash emissions shall be calculated using direct site-specific sampling data
and any software program or calculation methodology in use by industry that is based on AP-42 Chapter 7.

The proposed storage vessels at the facility will not handle 8,000 barrels or greater of crude oil or 2,000 barrels or
greater of condensate per year; therefore, compliance with R307-506-4(2)(a) is not required.

(3) All storage vessels that begin operations on or after January 1, 2018, are required to control VOC emissions in
accordance with R307-506-4(2)(a) upon startup of operation for a minimum of one year.

The proposed storage vessels are not required to control VOC emissions because R307-506(2)(a) is not applicable
to the facility.

(4) An emergency storage vessel located at a well site shall be exempt from R307-506-4(2)(a), if it meets the
following requirements:
(i) The emergency storage vessel shall not be used as an active storage tank.
(ii) The owner or operator shall empty the emergency storage vessel no later than 15 days after receiving fluids.
(iii) The emergency storage vessel shall be equipped with a liquid level gauge or equivalent device.
(5) An owner or operator that is required to control emissions in accordance with R307-506-4(2) and R307-506-4(3)
shall inspect at least once a month each closed vent system, including vessel openings, thief hatches, and bypass
devices, for defects that can result in air emissions according to 40 CFR 60.5416a(c).
(a) If defects are discovered, the defects shall be corrected or repaired within 15 days of identification.

There are no proposed emergency storage vessels at the facility.

(6) Modification to a well site shall require a re-evaluation of site-wide throughput and/or emissions in accordance
with R307-506-4(2).

Running Foxes will comply with this section of the rule if a modification is made.

(7) After a minimum of one year of operation, controls may be removed if site-wide throughput is less than 8,000

Page | 17

barrels of crude oil or 2,000 barrels of condensate on a rolling 12-month basis or uncontrolled actual emissions are
demonstrated to be less than four tons per year.

R307-506-5. Recordkeeping.
(1) Records of each closed vent system inspection, including vessel openings, thief hatches, pressure relief devices and
bypass device shall be kept for three years.
(a) Records of each closed vent system inspection, including vessel openings, thief hatches, pressure relief devices and
bypass device shall include the date of the inspection, the status of each closed vent system, including vessel openings,
thief hatches, pressure relief devices and bypass device, and the date of corrective action taken if required.
(2) Records of crude oil throughput shall be kept for three years and shall be determined on a monthly basis using the
production data reported to the Utah Division of Oil, Gas, and Mining.

Running Foxes will comply with recordkeeping requirements of the rule.
5.4 R307-504 Oil and Gas Industry: Tank Truck Loading
1) R307-504-4(1) applies to any person who loads or permits the loading of any intermediate hydrocarbon liquid or
produced water at a well site after January 1, 2015.

This rule is applicable to the proposed centralized tank battery.

(2) R307-504-4(2) applies to owners and operators that are required to control emissions from storage vessels in
accordance with R307-506.

As discussed in section 4.3, the facility is not required to control emissions from storage vessels in accordance with
R307-506; therefore, 504-4(2) is not applicable.
R307-504-4. Tank Truck Loading Requirements.
(1) Tanker trucks used for intermediate hydrocarbon liquid or produced water shall be loaded using bottom filling or
a submerged fill pipe.

Running Foxes will comply with the loading requirements of this rule.
5.5 R307-507 Oil and Gas Industry: Dehydrators
R307-507-3. Applicability.
(1) R307-507 applies to each dehydrator located at a well site as defined in 40 CFR 60.5430a, Subpart OOOOa,
Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution.
(2) R307-507 shall apply to centralized tank batteries, as defined in R307-506-2.
(3) R307-507 does not apply to a dehydrator that is subject to an approval order issued under R307-401-8.

This rule is applicable to the proposed centralized tank battery.
R307-507-4. Dehydrator Requirements.
(1) Dehydrators with VOC emissions of four tons of uncontrolled emissions per year or greater, either individually or
combined with VOC emissions from storage vessels, shall either be routed to a process unit where the emissions are
recycled, incorporated into a product, and/or recovered, or be routed to a VOC control device that is in compliance
with R307-508. Dehydrators in operation before January 1, 2018, shall determine applicability with calculated actual
emissions. Dehydrators in operation on or after January 1, 2018, shall determine applicability using potential to emit.

Page | 18

This proposed uncontrolled VOC emissions from the dehydrator exceed four tons per year. Running Foxes will
route the flash tank and post-condenser regenerator vent to the reboiler for at least 95% destruction efficiency.

(2) An owner or operator that is required to control emissions in accordance with R307-507-4(1) shall inspect, at least
once a month, each closed vent system, including vessel openings, thief hatches, and bypass devices, for defects that
can result in air emissions according to 40 CFR 60.5416a(c).

(a) If defects are discovered, the defects shall be corrected or repaired within 15 days of identification.

Running Foxes will comply with the inspection and repair requirements of this rule.

(3) Modification to a well site shall require a re-evaluation of emissions in accordance with R307-507-4(1).

Running Foxes will comply with this section of the rule if a modification is made.

(4) After a minimum of one year of operation, controls may be removed if uncontrolled actual emissions, individually
or combined with VOC emissions from storage vessels, are less than four tons per year on a rolling 12-month basis.

Running Foxes will comply with this section of the rule if a modification is applicable.

R307-507-5. Recordkeeping.
(1) Records of emission calculations shall be kept for all periods the plant is in operation if a control device is not
installed on-site.
(2) Records of each closed vent system inspection, including vessel openings, thief hatches, pressure relief devices and
bypass devices, shall be kept for three years.
(a) Records of each closed vent system inspection, including vessel openings, thief hatches, pressure relief devices and
bypass devices, shall include the date of the inspection, the status of each closed vent system, including vessel
openings, thief hatches, pressure relief devices and bypass devices, and the date of corrective action taken, if required.

Running Foxes will comply with recordkeeping requirements of the rule.
5.6 R307-508 Oil and Gas Industry: VOC Control Devices
R307-508-2. Applicability.
(1) Rule R307-508 applies to each VOC control device located at a well site as defined in 40 CFR 60.5430a Subpart
OOOOa Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution.
(2) Rule R307-508 shall apply to centralized tank batteries, as defined in Section R307-506-2.
(3) Rule R307-508 shall apply to VOC control devices subject to an Approval Order issued under Section R307-401-8
beginning December 1, 2023.

This rule is applicable to the proposed centralized tank battery.

R307-508-3. VOC Control Device Requirements.
(1) A VOC control device required by Rule R307-506 or R307-507 must have a control efficiency of 95% or greater.

The reboiler controlling VOC emissions from the dehydrator will have a control efficiency of 95% or greater.

(a) The VOC control device shall operate with no visible emissions.

Page | 19

The reboiler controlling VOC emissions from the dehydrator will operate with no visible emissions.

(b) The VOC control device must comply with Rule R307-503.
The reboiler controlling VOC emissions from the dehydrator is not considered to be a flare.

(2) A well site shall demonstrate compliance by meeting the performance test methods and procedures specified in
40 CFR 60.5413a.

The reboiler controlling VOC emissions from the dehydrator is not considered to be a flare.

(3) VOC control devices and all associated equipment shall be inspected monthly by audio, visual, or olfactory (AVO)
means to ensure the integrity of the equipment is maintained and is operational. If equipment is not operational,
corrective action shall be taken within 15 days of discovery.

Running Foxes will comply with the inspection and repair requirements of this rule.

R307-508-4. Recordkeeping.
(1) The owner or operator shall keep and maintain records of the VOC control device's control efficiency guaranteed
by the manufacturer. These records shall be retained for the life of the control equipment on site.
(2) The owner or operator shall keep and maintain records of the manufacturer's written operating and maintenance
instructions. These records shall be retained for the life of the control equipment.
(3) The owner or operator shall keep and maintain records of the VOC control device AVO inspections. These shall be
retained for a minimum of three years. These records shall include:
(a) the date of the inspection;
(b) the status of the control device and associated equipment; and
(c) date of corrective action taken, if applicable.

Running Foxes will comply with recordkeeping requirements of the rule.
5.7 R307-509 Oil and Gas Industry: Leak Detection and Repair Requirements
R307-509-3. Applicability.
(1) Rule R307-509 applies to each fugitive emissions component at a well site as defined in 40 CFR 60.5430a, Subpart
OOOOa, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution and shall
control emissions in accordance with Rules R307-506 and R307-507.
(a) A source meeting the requirements of 40 CFR 60.5397a is meeting the requirements of this rule.
(2) Sources subject to Rule R307-509 are subject until the well is shut in.
(3) Rule R307-509 shall apply to a fugitive emissions component that is subject to an Approval Order issued under
Section R307-401-8 beginning December 1, 2023.

This rule is applicable to the proposed centralized tank battery. Running Foxes will meet the requirements of 40
CFR 60.5397a and this rule.

R307-509-4. Leak Detection and Repair Requirements.
(1) Applicable sources shall comply with the following:
(a) The owner or operator shall develop an emissions monitoring plan that shall be available upon request to review
for each individual well site. At a minimum, the plan shall include:
(i) monitoring frequency;

Page | 20

(ii) monitoring technique and equipment;
(iii) procedures and timeframes for identifying and repairing leaks;
(iv) recordkeeping practices; and
(v) calibration and maintenance procedures for monitoring equipment.
(b) The plan shall address monitoring for difficult-to-monitor and unsafe-to-monitor components.

Running Foxes will develop an emissions monitoring plan that will meet the requirements of this rule.

(c) The owner or operator shall conduct monitoring surveys on site to observe each fugitive emissions component for
fugitive emissions.
(d) Monitoring surveys shall be conducted according to the following schedule:
(i) No later than 60 days after startup of production, as defined in 40 CFR 60 Subpart OOOOa Standards of
Performance for Crude Oil and Natural Gas Production, Transmission and Distribution.
(ii) Semiannually after the initial monitoring survey. Consecutive semiannual monitoring surveys shall be conducted
at least four months apart and no more than seven months apart.
(iii) Annually after the initial monitoring survey for "difficult-to-monitor" components.
(iv) As required by the owner or operator's monitoring plan for "unsafe-to-monitor" components.
(e) Monitoring surveys shall be conducted using one or both of the following to detect fugitive emissions:
(i) Optical gas imaging (OGI) equipment. OGI equipment shall be capable of imaging gases in the spectral range for
the compound of highest concentration in the potential fugitive emissions source.
(ii) Monitoring equipment that meets U.S. EPA Method 21, 40 CFR Part 60, Appendix A.
(f) If fugitive emissions are detected at any time, the owner or operator shall repair the fugitive emissions component
as soon as possible but no later than 15 calendar days after detection. If the repair or replacement is technically
infeasible, would require a vent blowdown, a well shutdown or well shut-in, or would be unsafe to repair during
operation of the unit, the repair or replacement shall be completed during the next well shutdown, well shut-in, after
an unscheduled, planned, or emergency vent blowdown or within 24 months, whichever is earlier.
(g) The owner or operator shall resurvey the repaired or replaced fugitive emission component no later than 30
calendar days after the fugitive emission component was repaired.

Running Foxes will conduct monitoring surveys and repairs as required by this rule.

R307-509-5. Recordkeeping.
(1) The owner or operator shall maintain records of the emissions monitoring plan. These records shall be retained
for the life of the well site.
(2) The owner or operator shall maintain records of the monitoring surveys, repairs, and resurveys. These records
shall be retained for a minimum of three years.

Running Foxes will comply with recordkeeping requirements of the rule.
5.8 R307-510 Oil and Gas Industry: Natural Gas Engine Requirements
R307-510-3. Applicability.
(1) R307-510 applies to each natural gas-fired engine at a well site as defined in 40 CFR 60.5430a, Subpart OOOOa
Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution, that began
operations, installed new engines, or made modifications to existing engines after January 1, 2016.
(2) R307-510 shall apply to centralized tank batteries, as defined in R307-506-2.
(3) R307-510 does not apply to a natural gas-fired engine that is subject to an approval order issued under R307-401-
8.

This rule is applicable to the proposed centralized tank battery.

Page | 21

R307-510-4. Engine Requirements.
(1) Regardless of construction, reconstruction, or modification date, each stationary engine at a well site shall comply
with the emission standards listed in Table 1 when the engine is installed, relocated, or modified.

(a) purchase a certified stationary internal combustion engine as defined in 40 CFR 60.4248, or
(b) conduct an initial performance test according to 40 CFR 60.4244.

The engines at the facility will comply with the emissions standards in Table 1. Running Foxes will conduct initial
performance tests to comply with this requirement.

(3) Each engine shall vent exhaust gases vertically unrestricted with the following stack height requirements:
(a) For site hp ratings of 306 or greater, each engine shall have an attached stack height of no less than 10 feet.
(b) For site hp ratings of 151 to 305 hp, each engine shall have an attached stack height of no less than 8 feet.
(c) For site hp ratings of 150 hp or less, there are no stack height requirements on engines.

The proposed engines at the facility are 295 horsepower and shall have an attached stack height of no less than 8
feet.

R307-510-5. Recordkeeping.
For each engine on site, the owner or operator shall maintain records of the engine certification or initial performance
test for the period of time the engine is on the well site.

Running Foxes will comply with recordkeeping requirements of the rule.
5.9 R307-511 Oil and Gas Industry: Associated Gas Flaring

The facility includes no proposed gas flaring; therefore, this rule is not applicable.

Page | 22

5.10 Federal Rule Applicability
The following federal regulations are applicable to the facility.
Table 4.1 Applicable Federal Regulations
Federal
Regulation
Citation
Title Applies? Unit(s) or
Facility Justification:
NSPS 40 CFR
60, Subpart A General Provisions Yes GEN1 –
GEN 11
This facility has units that are subject to 40 CFR 60. Therefore,
this regulation applies
NSPS 40
CFR60.40a,
Subpart Da
Subpart Da, Performance
Standards for Electric
Utility Steam Generating
Units
No N/A This facility does not include any electric utility steam
generating units. Therefore, this regulation does not apply.
NSPS 40
CFR60.40b
Subpart Db
Electric Utility Steam
Generating Units No N/A This facility does not include any electric utility steam
generating units. Therefore, this regulation does not apply.
40 CFR 60.40c,
Subpart Dc
Standards of Performance
for Small Industrial-
Commercial-Institutional
Steam Generating Units
No N/A
The facility does not have any steam generating units for
which construction, modification or reconstruction is
commenced after June 9, 1989 and that have a maximum
design heat input capacity of 29 MW (100 MMBtu/hr) or less,
but greater than or equal to 2.9 MW (10 MMBtu/hr).
Therefore, this regulation does not apply.
NSPS
40 CFR 60,
Subpart Ka
Standards of Performance
for Storage Vessels for
Petroleum Liquids for
which Construction,
Reconstruction, or
Modification Commenced
After May 18, 1978, and
Prior to July 23, 1984
No N/A This facility does not have any tanks with a volume of 420,000
gallons or larger. Therefore, this regulation does not apply.
NSPS
40 CFR 60,
Subpart Kb
Standards of Performance
for Volatile Organic Liquid
Storage Vessels (Including
Petroleum Liquid Storage
Vessels) for Which
Construction,
Reconstruction, or
Modification Commenced
After July 23, 1984
No N/A This facility does not have any storage vessels with a volume
of 75 cubic meters. Therefore, this regulation does not apply.
NSPS
40 CFR 60,
Subpart KKK
Standards of Performance
for Leaks of VOC from
Onshore Gas Plants
No N/A NSPS KKK is not applicable since the facility does not recover
a “Y-Grade” Product.

Page | 23

Federal
Regulation
Citation
Title Applies? Unit(s) or
Facility Justification:
NSPS
40 CFR 60,
Subpart LLL

Standards of Performance
for Onshore Natural Gas
Processing: SO2 Emissions
No N/A NSPS LLL is not applicable since the facility does not meet the
definition of an Onshore Natural Gas Processing Plant.
NSPS
40 CFR 60,
Subpart
OOOO
Standards of Performance
for Crude Oil and Natural
Gas Production,
Transmission, and
Distribution for which
Construction,
Modification or
Reconstruction
Commenced After August
23, 2011 and Before
September 18, 2015
No N/A The facility will be constructed after September 18, 2015;
therefore, NSPS OOOO is not applicable.
NSPS
40 CFR 60,
Subpart
OOOOa
Standards of Performance
for Crude Oil and Natural
Gas Facilities for which
Construction,
Modification or
Reconstruction
Commenced After
September 18, 2015
Yes N/A
The facility will be subject to OOOOa and will comply as
applicable. The water storage tank is not an affected facility
per NSPS OOOOa.
NSPS 40 CFR
60, Subpart IIII
Standards of Performance
for Stationary
Compression Ignition
Internal Combustion
Engines
No N/A There will be no compression ignition engines installed at this
facility. Therefore, this regulation does not apply.
NSPS
40 CFR 60,
Subpart JJJJ
Standards of Performance
for Stationary Spark
Ignition Internal
Combustion Engines
Yes N/A GEN1 – GEN 11 will be subject to the requirements of NSPS
JJJJ.
NSPS 40 CFR
60, Subpart
TTTT
Standards of Performance
for Greenhouse Gas
Emissions for Electric
Generating Units
No N/A There are no electric generating units at this facility.
Therefore, this regulation does not apply.
NSPS 40 CFR
60, Subpart
UUUU
Emissions Guidelines for
Greenhouse Gas
Emissions and
Compliance Times for
Electric Utility Generating
Units
No N/A There are no electric utility generating units at this facility.
Therefore, this regulation does not apply.
NESHAP
40 CFR 61,
Subpart A
General Provisions No N/A No units at this facility are subject to any of the subparts of
40 CFR 61.
NESHAP National Emission
Standards for Equipment
No N/A This facility is not a major source of HAPs. Therefore, this
regulation does not apply.

Page | 24

Federal
Regulation
Citation
Title Applies? Unit(s) or
Facility Justification:
40 CFR 61,
Subpart V
Leaks (Fugitive Emission
Sources)
MACT
40 CFR 63,
Subpart A
General Provisions Yes DEHY1 This facility is a stationary source with units that are subject
to 40 CFR 63. Therefore, this regulation applies.
MACT
40 CFR 63,
Subpart HH
National Emission
Standards for Hazardous
Air Pollutants for Oil and
Natural Gas Production
Facilities
Yes DEHY1
This facility is subject to the requirements of 40 CFR 63
Subpart HH, which includes requirements applicable to area
sources with TEG Dehydrators. The facility is not a major
source of HAPs, but an area source of HAPs and therefore is
subject to this subpart. The dehydrator has the potential to
emit less than 1 tpy (0.90 megagram per year) of benzene
post-control and is therefore exempt from the requirements
of §63.764(d) pursuant to §63.764(e)(1)(ii). The facility is
only required to maintain records of process vent benzene
emissions to atmosphere, as described in §63.764(e)(1)(ii).
Records of the process vent benzene emissions to
atmosphere will be maintained in accordance with
§63.772(b)(2), as required by §63.774(d)(1)(ii).
MACT
40 CFR 63,
Subpart HHH
National Emission
Standards for Hazardous
Air Pollutants for Natural
Gas Transmission and
Storage
No N/A
This subpart applies to owners and operators of natural gas
transmission and storage facilities that transport or store
natural gas prior to entering the pipeline to a local
distribution company or to a final end user. This facility is not
a natural gas transmission facility. Therefore, this regulation
does not apply.
MACT
40 CFR 63,
Subpart
DDDDD
National Emission
Standards for Hazardous
Air Pollutants for Major
Industrial, Commercial,
and Institutional Boilers &
Process Heaters
No N/A The facility is not major for HAPs; therefore, this regulation
does not apply.
MACT
40 CFR 63,
Subpart ZZZZ
National Emissions
Standards for Hazardous
Air Pollutants for
Stationary Reciprocating
Internal Combustion
Engines (RICE MACT)
Yes GEN1 –
GEN11
The facility is an area source of HAPs; therefore, the
stationary RICE will meet the MACT ZZZZ requirements by
complying with NSPS JJJJ per 40 CFR Part 63.6590(c)(1).

| Appendix

APPENDIX A
Emission Summary
Calculations
Process Modeling

lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY
Fugitive Emissions: Equipment Leaks FUGITIVES -- -- -- -- 0.05 0.23 -- -- -- -- 1.60E-04 7.00E-04 -- -- -- -- 2.71E-03 0.01
Pneumatic Devices PNEU --------0.271.17--------1.58E-030.01--------0.010.05
PSI 13L Generator (220 kW) GEN 1 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 2 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 3 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 4 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 5 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 6 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 7 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 8 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 9 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 10 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
PSI 13L Generator (220 kW) GEN 11 7.48 32.76 7.80 34.19 0.13 0.55 1.72E-03 0.01 0.03 0.12 4.62E-03 0.02 -- -- 0.06 0.26 0.09 0.42
Water Tank (300 BBL) WTK1 -- -- -- -- 0.41 0.98 -- -- -- -- 0.01 0.01 -- -- -- -- 0.03 0.06
Water Loading TL-W -- -- -- -- 20.48 0.02 -- -- -- -- 0.30 2.69E-04 8.02E-07 3.37E-06 -- -- 1.33 1.19E-03
NGL Loading TL-NGL --------1.71E-030.01------------------------
TEG Reboiler (0.50 MMBTU/Hr + products of
combustion)DEHYRB 0.05 0.22 0.04 0.18 0.00 0.01 2.94E-04 1.29E-03 0.00 0.02 1.05E-06 4.58E-06 -- -- 3.74E-05 1.64E-04 0.00 0.00
Dehydrator Flash Tank DEHYFT -- -- -- -- 4.55 19.93 -- -- -- -- 0.01 0.04 -- -- -- -- 0.14 0.61
Dehydrator Still Vent DEHYSC -- -- -- -- 5.95 26.77 -- -- -- -- 0.09 0.39 -- -- -- -- 0.02 1.79
lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY
82.33 360.59 85.90 376.23 33.09 55.14 0.02 0.08 0.31 1.36 0.46 0.68 8.02E-07 3.37E-06 0.66 2.89 2.58 7.10
* Methanol and glycol tank emissions are considered insignificant.
HCHO HAPs
HCHO HAPs
PM10 & 2.5 BENZENE
FACILITY WIDE EMISSIONS
NOx CO VOC
UNCONTROLLED EMISSION SUMMARY TABLE
EMISSION SOURCE DESCRIPTION* Emission Unit ID
NOx CO VOC SO2 PM10 & 2.5 BENZENE H2S
SO2 H2S
lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY
Fugitive Emissions: Equipment Leaks FUGITIVES -- -- -- -- 0.02 0.11 -- -- -- -- 1.60E-04 7.00E-04 -- -- -- -- 2.71E-03 0.01
Pneumatic Devices PNEU --------0.271.17--------1.58E-030.01--------0.010.05
PSI 13L Generator (220 kW) GEN 1 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 2 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 3 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 4 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 5 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 6 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 7 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 8 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 9 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 10 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
PSI 13L Generator (220 kW) GEN 11 0.33 1.42 0.33 1.42 0.04 0.17 1.72E-03 0.01 0.03 0.12 4.62E-04 2.02E-03 -- -- 0.01 0.03 0.01 0.04
Water Tank (300 BBL) WTK1 -- -- -- -- 0.41 0.98 -- -- -- -- 0.01 0.01 -- -- -- -- 0.03 0.06
Water Loading TL-W -- -- -- -- 20.48 0.02 -- -- -- -- 0.30 2.69E-04 8.02E-07 3.37E-06 -- -- 1.33 1.19E-03
NGL Loading TL-NGL --------1.71E-030.01------------------------
TEG Reboiler (0.50 MMBTU/Hr + DEHY) DEHYRB 0.12 0.51 0.40 1.74 0.42 1.88 2.94E-04 1.29E-03 0.01 0.04 3.84E-03 0.02 -- -- 3.74E-05 1.64E-04 0.02 0.10
Dehydrator Flash Tank DEHYFT
Dehydrator Still Vent DEHYSC
lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY
3.69 16.17 3.98 17.41 22.03 6.02 0.02 0.08 0.32 1.38 0.32 0.06 8.02E-07 3.37E-06 0.07 0.29 1.50 0.69
HAPs
Emissions Represented at Unit ID: DEHYRB
FACILITY WIDE EMISSIONS
NOx CO VOC SO2 HCHOPM10 & 2.5 BENZENE H2S
Emissions Represented at Unit ID: DEHYRB
CONTROLLED EMISSION SUMMARY TABLE
VOC SO2 PM10 & 2.5 BENZENEEMISSION SOURCE DESCRIPTION* Emission Unit ID
NOx CO H2S HAPsHCHO
lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY
Fugitive Emissions: Equipment Leaks FUGITIVES -- -- 5.61E-04 2.46E-03 3.95E-04 1.73E-03 4.75E-05 2.08E-04 1.81E-04 7.93E-04 1.67E-03 0.01 -- -- 2.86E-03 0.01
Pneumatic Devices PNEU -- -- 1.58E-03 0.01 2.13E-03 0.01 4.16E-04 1.82E-03 1.70E-03 0.01 0.01 0.02 -- -- 0.01 0.05
PSI 13L Generator (220 kW) GEN 1 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 2 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 3 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 4 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 5 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 6 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 7 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 8 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 9 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-05 2.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 10 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-052.50E-04--------0.090.42
PSI 13L Generator (220 kW) GEN 11 0.01 0.03 8.16E-04 3.57E-03 7.69E-04 3.37E-03 4.62E-04 2.02E-03 1.63E-04 7.15E-04 7.25E-06 3.18E-05 5.70E-052.50E-04--------0.090.42
Water Tank (300 BBL) WTK1 -- -- -- -- -- -- 0.01 0.01 3.76E-03 0.01 2.47E-04 4.35E-04 7.71E-04 1.34E-03 0.02 0.04 8.19E-05 1.62E-04 0.03 0.06
Water Loading TL-W -- -- -- -- -- -- 0.30 2.69E-04 0.15 1.37E-04 0.01 8.17E-06 0.03 2.52E-05 0.84 7.50E-04 3.39E-03 3.03E-06 1.33 1.19E-03
NGL Loading TL-NGL -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- --
TEG Reboiler (0.50 MMBTU/Hr + DEHY) DEHYRB 3.74E-05 1.64E-04 3.84E-03 0.02 2.42E-03 0.01 2.26E-04 1.04E-03 7.87E-04 3.61E-03 0.01 0.07 5.68E-05 2.62E-04 0.02 0.10
Dehydrator Flash Tank DEHYFT
Dehydrator Still Vent DEHYSC
lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY lb/hr TPY
0.07 0.29 0.01 0.04 0.01 0.04 0.32 0.06 0.16 0.04 0.01 3.86E-03 0.03 0.02 0.88 0.14 3.53E-03 4.27E-04 2.44 4.80
*Hourly Rates Include Instantaneous Flow Rates
TOTAL FACILITY WIDE EMISSIONS
Total HAPsETHYLBENZENE
Emissions Represented at EPN: DEHYRB
HCHO BENZENE TOLUENE XYLENE N-HEXANE
2, 2, 4-
TRIMETHYLPENTANEAcetaldehyde Acrolein
Emissions Represented at EPN: DEHYRB
CONTROLLED HAPS SUMMARY TABLE
EMISSION SOURCE DESCRIPTION Emission Unit ID
HCHO BENZENE TOLUENE ETHYLBENZENE XYLENE
2, 2, 4-
TRIMETHYLPENTANE Total HAPsN-HEXANEAcetaldehyde Acrolein
CO2
ton/yr
N2O
ton/yr
CH4
ton/yr
SF6
ton/yr
PFC/HFC
ton/yr2
Total
GHG Mass
Basis ton/yr4
Total
CO2e
ton/yr5
Unit No.GWPs 1 1 298 25 22,800 footnote 3
mass GHG 0.04 0.00E+00 1.94 - 1.97
CO2e 0.04 0.00E+00 48.46 - 48.50
mass GHG 0.39 0.00E+00 23.41 - 23.80
CO2e 0.39 0.00E+00 585.22 - 585.61
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 1,498 2.82E-03 0.03 - 1,498
CO2e 1,498 0.84 0.71 - 1,500
mass GHG 0.03 0.00E+00 0.01 - 0.04
CO2e 0.03 0.00E+00 0.17 - 0.20
mass GHG 5.46E-04 0.00E+00 1.24E-04 - 6.70E-04
CO2e 5.46E-04 0.00E+00 3.09E-03 - 3.64E-03
mass GHG 0.00E+00 0.00E+00 0.00E+00 - 0.00E+00
CO2e 0.00E+00 0.00E+00 0.00E+00 - 0.00E+00
mass GHG 280.74 4.72E-03 4.67 - 285.42
CO2e 280.74 1.41 117 - 399
mass GHG
CO2e
mass GHG
CO2e
mass GHG 16,764 0.04 30 - 16,794
CO2e 16,764 11 758 - 17,533
2 For HFCs or PFCs describe the specific HFC or PFC compound and use a separate column for each individual compound.
3 For each new compound, enter the appropriate GWP for each HFC or PFC compound from Table A-1 in 40 CFR 98.
4 Green house gas emissions on a mass basis is the ton per year green house gas emission before adjustment with its GWP.
5 CO2e means Carbon Dioxide Equivalent and is calculated by multiplying the TPY mass emissions of the green house gas by its GWP.
1 GWP (Global Warming Potential): Applicants must use the most current GWPs codified in Table A-1 of 40 CFR part 98. GWPs are subject to change, therefore, applicants need
to check 40 CFR 98 to confirm GWP values.
DEHYSC
Total
WTK1
GEN 10
GEN 11
DEHYFT
TL-W
TL-NGL
DEHYRB
Emissions Represented at UNIT ID: DEHYRB
Emissions Represented at UNIT ID: DEHYRB
GEN 9
GEN 4
GEN 5
GEN 6
GEN 7
GEN 8
GEN 1
GEN 2
GEN 3
Greenhouse Gas Emissions
FUGITIVES
PNEU
Operations Summary
Produced Gas 0.3710 MMSCFD
Produced Water 0.58 BWPD
Produced Water 211.6 bbl/year
Produced Dry Gas 0.371 MMSCFD
Lean Glycol Flow Rate 14.06 GPM
Burner 1 (Reboiler) 0.50 MMBTU/hr
Generator 1 220 kW
Generator 2 220 kW
Generator 3 220 kW
Generator 4 220 kW
Generator 5 220 kW
Generator 6 220 kW
Generator 7 220 kW
Generator 8 220 kW
Generator 9 220 kW
Generator 10 220 kW
Generator 11 220 kW
NGL Tanks NGL-1 and NGL-2
(non-emitting)
PW-TANK Produced Water Tank 300 bbl
MACT HH Yes See Section 5
NSPS OOOOa Yes See Section 5
NSPS JJJJ Yes See Section 5
NESHAP ZZZZ Yes See Section 5
Dehydration
THROUGHPUT
APPLICABILITY
Burners
EQUIPMENT
Generators
Tank Battery
Fugitive Count Estimation
Unit ID(s): FUGITIVES
Uncollected Emissions: Pollutant lb/hr tpy
VOC 0.02 0.11
H2S 0.00E+00 0.00E+00
Benzene 1.60E-04 7.00E-04
Total HAPs 2.71E-03 0.01
Valves Connectors Open-ended
lines
Pressure Relief
Valves Valves Connectors Open-ended
lines
Pressure Relief
Valves
Wellheads 0 100% 11 36 1 00000
Separators 0 100% 34 106 6 20000
Meters/piping4 1 100% 14 51 1 1 14 51 1 1
Compressors 0 100% 73 179 3 40000
In-line heaters 0 100% 14 65 2 10000
Dehydrators 1 100% 24 90 2 2 24 90 2 2
TOTAL:38 141 3 3
Valves Flanges Connectors Open-ended
lines
Other
Components Valves Flanges Connectors Open-ended
lines
Other
Components
Wellheads3 0 100% 5 10 4 0100000
Separators3 0 100% 6 12 10 0000000
Heater-treaters 0 100% 8 12 20 0000000
Headers 1 100% 5 10 4 0 0 5 10 4 0 0
TOTAL:510400
1For each type of type of equipment, associated fugitive components can be in gas service, liquid service, or both. Equipment that is in both gas and liquid service (such as wellheads or separators) is assumed to have 100% of its fugitive
components in gas service and 100% in liquid service, which is an over-conservative estimate
2From MRR Subpart W Table W-1B, for the Western U.S.
3The number of components for a particular type of equipment were calculated as follows: (Number of Components) = (Equipment Count) x (Components per Equipment) x (Percentage of Components in Gas Service)
4The MRR uses equipment types listed in a 1996 GRI/EPA study. The equipment type "meters/piping" can be found in the Fugitives report under onshore production. This equipment type is a catch-all category for counts of individual
fugitive components (such as valves, connectors, OELs, PRV's) that were not attached to another major piece of equipment. Therefore, there was one "meters/piping" per site. For more information, refer to Hummel, K.E., L.M. Campbell,
and M.R. Harrison. Methane Emissions from the Natural Gas Industry, Volume 8: Equipment Leaks , Final Report, GRI-94/0257.25 and EPA-600/R-96-080h. Gas Research Institute and U.S. Environmental Protection Agency, June 1996.
http://www.epa.gov/gasstar/documents/emissions_report/8_equipmentleaks.pdf, accessed April 28, 2011.
Components in Liquid Service:
Equipment Equipment Count
Percentage of
this Equipment
in Liquid
Service1,2
Default Component Counts - Liquid Service3
(per piece of equipment)Total Number of Components in Liquid Service4
Components in Gas Service:
Equipment Equipment Count
Percentage of
this Equipment
in Gas Service1
Default Component Counts - Gas Service2
(per piece of equipment)Total Number of Components in Gas Service3
Fugitive Potential Emissions Calculations
EPN(s): FUGITIVES
Uncontrolled
Emissions
Uncontrolled
Emissions
Controlled
Emissions
Controlled
Emissions
Table 2-4 Table 2-8 (lb/hr) (tpy) (lb/hr) (tpy)
Valves 38 9.92E-03 5.51E-05 0% VOC 0.043 0.0222 0.0970 0.0222 0.0970
Pump Seals 0 5.29E-03 7.72E-04 0% H2S 0.000 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Connectors 141 4.41E-04 2.20E-05 0% Benzene 0.000 1.31E-04 5.75E-04 1.31E-04 5.75E-04
Flanges 0 8.60E-04 1.26E-05 0% Toluene 0.000 1.76E-04 7.73E-04 1.76E-04 7.73E-04
Open-Ended Lines 3 4.41E-03 3.31E-05 0% E-Benzene 0.000 3.44E-05 1.51E-04 3.44E-05 1.51E-04
Other 0 1.94E-02 2.65E-04 0% Xylenes 0.000 1.41E-04 6.16E-04 1.41E-04 6.16E-04
Relief Valves 3 1.94E-02 2.65E-04 0% n-Hexane 0.001 4.72E-04 2.07E-03 4.72E-04 2.07E-03
Compressors 0 1.94E-02 0% 2,2,4 Trimethylpentane 0.000 3.37E-06 1.47E-05 3.37E-06 1.47E-05
Methane 0.866 0.4424 1.9376 0.4424 1.9376
Carbon Dioxide 0.014 0.0074 0.0324 0.0074 0.0324
Valves 1.85E-05 1.85E-05 0% VOC 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Pump Seals 0.00E+00 0.00E+00 0% H2S 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Connectors 1.65E-05 1.65E-05 0% Benzene 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Flanges 8.60E-06 8.60E-07 0% Toluene 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Open-Ended Lines 3.09E-04 1.59E-05 0% E-Benzene 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Other 3.09E-04 7.05E-05 0% Xylenes 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Relief Valves 3.09E-04 7.05E-05 0% n-Hexane 0.00E+00 0.00E+00 0.00E+00 0.00E+00
2,2,4 Trimethylpentane 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Methane 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Carbon Dioxide 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Valves 5 5.51E-03 4.19E-05 0% VOC 0.921 2.93E-02 1.28E-01 2.93E-02 1.28E-01
Pump Seals 0 2.87E-02 1.12E-03 0% H2S 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Connectors 4 4.63E-04 2.14E-05 0% Benzene 1.35E-02 4.30E-04 1.88E-03 4.30E-04 1.88E-03
Flanges 10 2.43E-04 5.29E-06 0% Toluene 6.87E-03 2.19E-04 9.57E-04 2.19E-04 9.57E-04
Open-Ended Lines 0 2.87E-03 3.09E-05 0% E-Benzene 4.10E-04 1.31E-05 5.72E-05 1.31E-05 5.72E-05
Other 0 1.65E-02 2.43E-04 0% Xylenes 1.27E-03 4.03E-05 1.77E-04 4.03E-05 1.77E-04
Relief Valves 0 1.65E-02 2.43E-04 0% n-Hexane 3.77E-02 1.20E-03 5.25E-03 1.20E-03 5.25E-03
2,2,4 Trimethylpentane 1.52E-04 4.85E-06 2.12E-05 4.85E-06 2.12E-05
Methane 0.006 1.98E-04 8.67E-04 1.98E-04 8.67E-04
Carbon Dioxide 0.027 8.73E-04 3.82E-03 8.73E-04 3.82E-03
Valves 0 2.16E-04 2.14E-05 0% VOC 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Pump Seals 0 5.29E-05 5.29E-05 0% H2S 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Connectors 0 2.43E-04 2.20E-05 0% Benzene 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Flanges 0 6.39E-06 6.39E-06 0% Toluene 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Open-Ended Lines 0 5.51E-04 7.72E-06 0% E-Benzene 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Other 0 3.09E-02 1.30E-04 0% Xylenes 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Relief Valves 0 3.09E-02 1.30E-04 0% n-Hexane 0.00E+00 0.00E+00 0.00E+00 0.00E+00
2,2,4 Trimethylpentane 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Methane 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Carbon Dioxide 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Fugitive Emission Summary
Footnotes:Uncontrolled Emissions Controlled Emissions
(lb/hr)(tpy)(lb/hr)(tpy)
VOC 0.05 0.23 0.05 0.23
HAPs 2.86E-03 0.01 2.86E-03 0.01
H2S 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Benzene 5.61E-04 2.46E-03 5.61E-04 2.46E-03
Toluene 3.95E-04 1.73E-03 3.95E-04 1.73E-03
E-Benzene 4.75E-05 2.08E-04 4.75E-05 2.08E-04
Xylenes 1.81E-04 7.93E-04 1.81E-04 7.93E-04
n-Hexane 1.67E-03 0.01 1.67E-03 0.01
2,2,4 Trimethylpentane 8.22E-06 3.60E-05 8.22E-06 3.60E-05
Methane 0.44 1.94 0.44 1.94
Carbon Dioxide 0.01 0.04 0.01 0.04
bGas fugitives based on inlet gas analysis. Light Oil liquid analysis from ProMax for Produced Water W&B.
Operating Hours:8760 hours/year
Emission Factor Source Standard EFs - EPA-453/R-95-017 Table 2-4
Control Efficiency Source:None
Emission Buffer (%):0
Service Component Type Count
Emission Factor
(lb/hr-source)a Control (%) Pollutant
Mass
Fractionb
Pollutanta Standard factors are taken from EPA Document EPA-453/R-095-017, November 1995, Table 2-4.
Screening factors taken from Table 2-8.
Gas
Heavy Oil
Light Oil
Water/Oil
Pneumatic Calculations
Unit ID(s): PNEU
Type Count
Bleed Rate
(scf/hr/component)
Total Bleed Rate
(MMscf/year)
VOC
(lb/hr)
VOC
(TPY)
Intermittent Bleed 10 13.5 1.183 0.268 1.17
Component wt% (lb/hr) tpy
TEG 0.00% 0.00 0.00
Water 0.00% 0.00 0.00
Helium 0.03% 0.00 0.01
Oxygen 0.04% 0.00 0.01
Hydrogen 0.00% 0.00 0.00
H2S 0.00% 0.00 0.00
Nitrogen 2.94% 0.18 0.79
Carbon Dioxide 1.45% 0.09 0.39
Methane 86.64% 5.34 23.41
Ethane 4.56% 0.28 1.23
Propane 1.24% 0.08 0.33
Isobutane 0.65% 0.04 0.18
n-Butane 0.37% 0.02 0.10
Isopentane 0.55% 0.03 0.15
n-Pentane 0.16% 0.01 0.04
Isohexane 0.48% 0.03 0.13
n-Hexane 0.09% 0.01 0.02
Benzene 0.03% 0.00 0.01
Toluene 0.03% 0.00 0.01
Ethylbenzene 0.01% 0.00 0.00
o-Xylene 0.03% 0.00 0.01
2,2,4-Trimethylpentane 0.00% 0.00 0.00
Isoheptane 0.38% 0.02 0.10
Octane 0.32% 0.02 0.09
Nonane 0.00% 0.00 0.00
Decane 0.00% 0.00 0.00
Gas wt %VOC 4.34%
Gas wt %HAPs 0.19%
Molecular Weight 17.33
Pneumatic Devices
Gas Composition
Note: devices used are snap acting versus throttling. The gas composition used is that of the high pressure separator gas composition.
Emissions (TPY) = Total Bleed Rate (MMscf/hr) * Gas Molecular Weight (lb/lbmole) * Weight Percent VOC or HAP * 1/molar volume
conversion (379.3 scf/lbmole) * 8760 hr/yr * 1 ton/2000 lb
Emissions
Generator (each)
Unit ID(s): GEN 1 - GEN 11, each
Engine Data
Manufacturer PSI
Model Number 13L
kW:220
Horsepower:295
Fuel Consumption (ft3/hr):2,734
(MMBtu/hr)2.93
Fuel heating value (Btu/scf):1,070
Fuel consumption (Btu/hp-hr):9,916
Hours of operation per year:8,760
Engine Type:4 Stroke, Rich-Burn
Fuel Data
Fuel Type natural gas
Fuel Consumption (BTU/bhp-hr)9,916
Fuel Gas Heat Value (HHV)1,037.00
Uncontrolled Engine Emissions
Manufacturer's Emission Factors
(g/hp-hr)
AP-42 Table 3.2-1
2 stroke, lean-burn
engine emission factors
(lb/MMBtu)
AP-42 Table 3.2-2
4 stroke, lean-burn engine
emission factors
(lb/MMBtu)
AP-42 Table 3.2-3
4 stroke, rich burn engine
emission factors
(lb/MMBtu)
Appropriate
AP-42 factor
Emission
factor used Units
Emissions
lb/hr
Emissions
tpy
VOC 0.100 0.12 0.118 0.0296 0.0296 0.1 g/hp-hr 0.07 0.28
NOx1 11.50 3.17 4.08 2.21 2.21 11.50 g/hp-hr 7.48 32.76
CO 12.00 0.386 0.317 3.72 3.72 12.00 g/hp-hr 7.80 34.19
PM10 0.0384 0.0000771 0.0095 0.0095 0.0095 lb/MMBtu 0.03 0.12
PM2.5 0.0384 0.0000771 0.0095 0.0095 0.0095 lb/MMBtu 0.03 0.12
SO2 0.000588 0.000588 0.000588 0.000588 0.000588 lb/MMBtu 0.00 0.01
Formaldehyde 0.0552 0.0528 0.0205 0.0205 0.0205 lb/MMBtu 0.06 0.26
Benzene 0.00194 0.00044 0.00158 0.00158 0.00158 lb/MMBtu <0.01 0.02
CO2 53.06 kg/MMBtu 1,498
CH4 1.00E-03 kg/MMBtu 0.03
N2O 1.00E-04 kg/MMBtu <0.01
Total CO2e (TPY) 1,500
Engine Emissions
Manufacturer's Emission Factors
(g/hp-hr)
AP-42 Table 3.2-1
2 stroke, lean-burn
engine emission factors
(lb/MMBtu)
AP-42 Table 3.2-2
4 stroke, lean-burn engine
emission factors
(lb/MMBtu)
AP-42 Table 3.2-3
4 stroke, rich burn engine
emission factors
(lb/MMBtu)
Appropriate
AP-42 factor
Emission
factor used Units
Emissions
lb/hr
Emissions
tpy
VOC 0.05 0.12 0.118 0.0296 0.0296 0.05 g/hp-hr 0.03 0.14
NOx1 0.50 3.17 4.08 2.21 2.21 0.50 g/hp-hr 0.33 1.42
CO 0.50 0.386 0.317 3.72 3.72 0.50 g/hp-hr 0.33 1.42
PM10 0.0384 0.0000771 0.0095 0.0095 0.0095 lb/MMBtu 0.03 0.12
PM2.5 0.0384 0.0000771 0.0095 0.0095 0.0095 lb/MMBtu 0.03 0.12
SO2 0.000588 0.000588 0.000588 0.000588 0.000588 lb/MMBtu 0.00 0.01
Formaldehyde 0.0552 0.0528 0.0205 0.0205 0.0205 lb/MMBtu 0.01 0.03
Benzene 0.00194 0.00044 0.00158 0.00158 0.00158 lb/MMBtu <0.01 0.00
CO2 53.06 kg/MMBtu 1,498
CH4 1.00E-03 kg/MMBtu 0.03
N2O 1.00E-04 kg/MMBtu <0.01
Total CO2e (TPY) 1,500
Example Calculation:
VOC Emissions (tpy) = 0.05 g/hp-hr x 295hp x 8,760 hr/yr / 454 g/lb / 2000 lb/ton = 0.14 tpy
PM10 Emissions (tpy) = 0.0095000 lb/MMBtu x 295 hp x 9,916 Btu/hp-hr x 1 MMBtu/1,000,000 Btu x 8,760 hr/yr / 2000 lb/ton = 0.12 tpy
HAP Emissions
Rich Burning 4 Stroke Engines
Pollutant AP-42 Table 3.2-3 Emission Factor
(lb/MMBtu)
Emissions
lb/hr
Emissions
tpy
Emissions
lb/hr
Emissions
tpy
1,1,2,2-Tetrachloroethane 2.53E-05 <0.01 <0.01 <0.01 <0.01
1,1,2-Trichloroethane 1.53E-05 <0.01 <0.01 <0.01 <0.01
1,3-Butadiene 6.63E-04 <0.01 0.01 <0.01 <0.01
1,3-Dichloropropene 1.27E-05 <0.01 <0.01 <0.01 <0.01
Acenaphthylene -- -- -- --
Acetaldehyde 2.79E-03 0.01 0.04 <0.01 <0.01
Acrolein 2.63E-03 0.01 0.03 <0.01 <0.01
Benzene 1.58E-03 <0.01 0.02 <0.01 <0.01
Benzo(b)flouanthene -- -- -- --
Benzo(e)pyrene -- -- -- --
Benzo(g,h,i)perylene -- -- -- --
Biphenyl -- -- -- --
Carbon Tetrachloride 1.77E-05 <0.01 <0.01 <0.01 <0.01
Chlorobenzene 1.29E-05 <0.01 <0.01 <0.01 <0.01
Chloroform 1.37E-05 <0.01 <0.01 <0.01 <0.01
Chrysene -- -- -- --
Ethylbenzene 2.48E-05 <0.01 <0.01 <0.01 <0.01
Ethylene Dibromide 2.13E-05 <0.01 <0.01 <0.01 <0.01
Flouranthene -- -- -- --
Flourene -- -- -- --
Formaldehyde 2.05E-02 0.06 0.26 0.01 0.03
Methanol 3.06E-03 0.01 0.04 <0.01 <0.01
Methylene Chloride 4.12E-05 <0.01 <0.01 <0.01 <0.01
n-Hexane -- -- -- --
Napthalene 9.71E-05 <0.01 <0.01 <0.01 <0.01
PAH 1.41E-04 <0.01 <0.01 <0.01 <0.01
Phenanthrene -- -- -- --
Phenol -- -- -- --
Pyrene -- -- -- --
Styrene 1.19E-05 <0.01 <0.01 <0.01 <0.01
Tetrachloroethane -- -- -- --
Toluene 5.58E-04 <0.01 0.01 <0.01 <0.01
Vinyl Chloride 7.18E-06 <0.01 <0.01 <0.01 <0.01
Xylene 1.95E-04 <0.01 <0.01 <0.01 <0.01
Totals 0.09 0.42 0.01 0.04
Uncontrolled Engine Emissions Controlled Engine Emissions
Water Tank Inputs
Tank Geometry Vertical Cylinder Roof Type Cone
Shell Length 15* ft Slope of Coned Roof 0.0625
Shell Diameter 12* ft Breather Vent Pressure 0.0300000 psi
Number of Storage Tanks 1* Breather Vacuum Pressure -0.0300000 psi
Maximum Fraction Fill of Tank 90 % Location Grand Junction, CO*
Average Fraction Fill of Tank 50 % Time Frame Year*
Minimum Fraction Fill of Tank 10 % Known Liquid Bulk Temperature? FALSE
Material Category Light Organics* Liquid Bulk Temperature 55.5932 °F
Insulation Uninsulated Use AP 42 Raoult's Vapor Pressure? FALSE
Bolted or Riveted Construction? FALSE Flashing Temperature 65.7350 °F
Vapor Balanced Tank? FALSE Average Daily Maximum Ambient Temperature 65.3 °F
Known Sum of Increases in Liquid Level? FALSE Average Daily Minimum Ambient Temperature 41.3 °F
Sum of Increases in Liquid Level 10.7 ft/yr Atmospheric Pressure at Tank Location 12.34 psia
Shell Color Tan* Daily Solar Insolation 1560 Btu/(day*ft^2)
Shell Paint Condition Average Average Wind Speed 7.8 mph
Roof Color Tan* Include Short Term Emissions FALSE
Roof Paint Condition Average
Working and Standing Properties : Scalar Data
Water Tank Emissions
Unit ID(s): WTK1
Water Throughput (bbl/day):0.53 Water Tank Count:1
ProMax Stream: WT Flash WT W&B Total
Component (lb/hr) (lb/hr) (lb/hr)
Triethylene Glycol 4.79E-10 6.46E-09 6.94E-09
Water 5.49E-04 0.01 0.01
Helium 5.22E-09 1.91E-10 5.41E-09
Oxygen 1.48E-08 3.97E-09 1.88E-08
Hydrogen -- ----
Hydrogen Sulfide -- ----
Nitrogen 6.96E-07 1.06E-07 8.02E-07
Carbon Dioxide 2.99E-03 4.15E-03 0.01
Methane 1.09E-03 5.79E-04 1.67E-03
Ethane 1.58E-03 4.74E-03 0.01
Propane 1.62E-03 0.02 0.02
Isobutane 1.34E-03 0.03 0.03
n-Butane 1.46E-03 0.04 0.04
Isopentane 3.08E-03 0.08 0.09
n-Pentane 1.19E-03 0.03 0.03
Isohexane 3.58E-03 0.09 0.10
n-Hexane 7.26E-04 0.02 0.02
Benzene 2.54E-04 0.01 0.01
Toluene 1.47E-04 3.61E-03 3.76E-03
Ethylbenzene 9.97E-06 2.37E-04 2.47E-04
o-Xylene 3.13E-05 7.40E-04 7.71E-04
2,2,4-Trimethylpentane 3.18E-06 7.87E-05 8.19E-05
Isoheptane 2.23E-03 0.06 0.06
Octane 5.93E-04 0.01 0.01
Nonane -- ----
Decane -- ----
Total 0.02 0.42 0.44
Total VOC 0.02 0.39 0.41
Total HAP 1.17E-03 0.03 0.03
Hourly Tank Vapors to Atmosphere
Truck Loading
Unit ID: TL-W
Uncollected Emissions: Pollutant lb/hr tpy
(Produced Water Loading)VOC 20.48 0.02
H2S 0.00E+00 0.00E+00
Benzene 0.30 2.69E-04
Total HAPs 1.33 1.19E-03
Water loading loss emissions were obtained from ProMax, and use total hydrocarbons as calculated using AP-42, Section 5.2. Produced water loading is uncontrolled
Background Information:
Produced Water
Number of Truck Loading Connections 1
Capacity of Trucks (gal) 5,040
Number of Days of Loading 365
Control Device None
Quantity to be loaded:
Produced Water
Daily Throughput (bbl/day) 0.53
Annual Loadout (gal/yr) 8,161
Hourly Loadout (gal/hr) 5,040
Equations used:
A. (Annual Loadout, gal/yr) = (Daily Throughput, bbl/day) x (Number of Days of Loading) x (42 gal/bbl)
B. (Hourly Loadout, gal/hr) = (Truck Capacity, gal) x (Number of Loading Connections)
Parameters Used in Calculations:
Hourly Annual
0.6 0.6
4.95 5.44
66.30 63.01
96.33 65.74
556.00 525.41
4.41 4.88
0% 0%
0% 0%
0% 0%
Equations:
A. (Temperature, ˚R) = (Temperature, ˚F) + 459.67
Stream Composition
Pollutant
Produced Water Loading
Vapors
(Wt%)
TEG 0.00
Water 2.07
Helium 0.00
Oxygen 0.00
Hydrogen 0.00
H2S 0.00
Nitrogen 0.00
Carbon Dioxide 2.74
Methane 0.62
Ethane 2.44
Propane 6.52
Isobutane 9.93
n-Butane 10.22
Isopentane 19.27
n-Pentane 7.15
Isohexane 19.77
n-Hexane 3.77
Benzene 1.35
Toluene 0.69
Ethylbenzene 0.04
o-Xylene 0.13
2,2,4-Trimethylpentane 0.02
Isoheptane 10.87
Octane 2.41
Nonane 0.00
Decane 0.00
VOC 92.13
H2S Reduction Factor
1Values were obtained from ProMax
B. (Total Loading Losses, lb/10 3 gal) = 12.46 x (Saturation Factor) x (True Vapor Pressure, psi) x (Molecular Weight of Vapor, lb/lb-mole) / (Temperature, ˚R)
Capture Efficiency
VOC Reduction Factor
Total LL [Loading loss (lb/103 gal)] - THC,B
Calculation Basis:
Produced Water
Loading Loss Equation Parameter
S [Saturation factor]
P [True vapor pressure (psi)]1
M [Molecular weight of vapor (lb/lb-mole)]1
T [Temperature of bulk liquid loaded (˚F)]1
T [Temperature of bulk liquid loaded (˚R)]A
Emission Calculations:
Produced Water Truck Loading
lb/hr tpy
TEG 4.72E-08 4.22E-11
Water 0.46 4.11E-04
Helium 2.29E-07 2.05E-10
Oxygen 1.47E-06 1.32E-09
Hydrogen 0.00E+00 0.00E+00
H2S 0.00E+00 0.00E+00
Nitrogen 5.75E-05 5.15E-08
Carbon Dioxide 0.61 5.46E-04
Methane 0.14 1.24E-04
Ethane 0.54 4.87E-04
Propane 1.45 1.30E-03
Isobutane 2.21 1.98E-03
n-Butane 2.27 2.04E-03
Isopentane 4.28 3.84E-03
n-Pentane 1.59 1.42E-03
Isohexane 4.40 3.94E-03
n-Hexane 0.84 7.50E-04
Benzene 0.30 2.69E-04
Toluene 0.15 1.37E-04
Ethylbenzene 0.01 8.17E-06
o-Xylene 0.03 2.52E-05
2,2,4-Trimethylpentane 3.39E-03 3.03E-06
Isoheptane 2.42 2.16E-03
Octane 0.54 4.81E-04
Nonane 0.00E+00 0.00E+00
Decane 0.00E+00 0.00E+00
VOC 20.48 0.02
HAPs 1.33 1.19E-03
Equations used:
A. (Total Loading Emissions per Pollutant, lb/hr) = (Loading Loss, lb/10 3 gal) x (Loading Rate, gal/hr) x (Pollutant Content, Wt%) x ( (100%) - (Reduction Factor, %) ) / (1,000 gal/10 3 gal)
C. (Collected Loading Emissions, lb/hr or tpy) = (Total Loading Emissions, lb/hr or tpy) x (Capture Efficiency, %)
D. (Uncollected Loading Emissions, lb/hr or tpy) = (Total Loading Emissions, lb/hr or tpy) x (100% - (Capture Efficiency, %))
B. (Total Loading Emissions per Pollutant, tpy) = (Loading Loss, lb/10 3 gal) x (Loading Rate, gal/yr) x (Pollutant Content, Wt%) x ( (100%) - (Reduction Factor, %) ) / (1,000 gal/10 3 gal) / (2,000 lb/ton)
Pollutant
Total Loading Emissions
Water Tank Emissions
Unit ID(s): TK-VENT
Water Throughput (bbl/day):0.53 Water Tank Count:1
ProMax Stream: WT Flash WT W&B Total
Component (tpy) (tpy) (tpy)
Triethylene Glycol 4.87E-12 2.25E-09 2.25E-09
Water 2.89E-05 0.02 0.02
Helium 1.20E-08 1.09E-08 2.29E-08
Oxygen 8.31E-09 7.01E-08 7.84E-08
Hydrogen -- ----
Hydrogen Sulfide -- ----
Nitrogen 6.34E-07 2.74E-06 3.37E-06
Carbon Dioxide 5.66E-04 0.03 0.03
Methane 3.73E-04 0.01 0.01
Ethane 2.22E-04 0.03 0.03
Propane 1.70E-04 0.07 0.07
Isobutane 1.20E-04 0.11 0.11
n-Butane 1.24E-04 0.11 0.11
Isopentane 2.40E-04 0.20 0.20
n-Pentane 8.99E-05 0.08 0.08
Isohexane 2.53E-04 0.21 0.21
n-Hexane 4.90E-05 0.04 0.04
Benzene 1.75E-05 0.01 0.01
Toluene 9.18E-06 0.01 0.01
Ethylbenzene 5.66E-07 4.34E-04 4.35E-04
o-Xylene 1.75E-06 1.34E-03 1.34E-03
2,2,4-Trimethylpentane 2.03E-07 1.61E-04 1.62E-04
Isoheptane 1.44E-04 0.12 0.12
Octane 3.34E-05 0.03 0.03
Nonane -- ----
Decane -- ----
Total 2.44E-03 1.06 1.06
Total VOC 1.25E-03 0.98 0.98
Total HAP 7.82E-05 0.06 0.06
Annual Tank Vapors to Atmosphere
Reboiler Burner Combustion Emissions
Unit ID(s): DEHYRB
Total Emissions: Pollutant lb/hr tpy
(per burner)VOC 2.74E-03 0.01
NOx 0.05 0.22
CO 0.04 0.18
PM 3.79E-03 0.02
SO2 2.94E-04 1.29E-03
H2S 0.00E+00 0.00E+00
Benzene 1.05E-06 4.58E-06
Formaldehyde 3.74E-05 1.64E-04
Total HAPs 9.41E-04 4.12E-03
Calculation Basis:
Background Information: Emission Calculations:
Reboiler Information
Reboiler Rating (MMBtu/hr) 0.50 lb/hr tpy
Number of Reboilers with this Rating 1 VOC 5.5 2.74E-03 0.01
Hours of operation per year 8,760 NOx 100 0.05 0.22
Fuel Data CO 84 0.04 0.18
Fuel type Natural Gas PM total2 7.6 3.79E-03 0.02
H2S content of fuel (ppm)0 SO2 0.60 2.94E-04 1.29E-03
H2S content of fuel (mol %)0%H2S 0.00 0.00E+00 0.00E+00
H2S Conversion Efficiency 98%HAPs
Fuel Heat Value1 (Btu/scf)1,020 Total HAPs -- 9.41E-04 4.12E-03
Facility Fuel Gas Heat Value2 (Btu/scf)1,037.00 Arsenic 2.00E-04 9.97E-08 4.37E-07
Constants Benzene 2.10E-03 1.05E-06 4.58E-06
scf/lbmole 379.3 Beryllium 1.20E-05 5.98E-09 2.62E-08
H2S molecular weight 34.08 Cadmium 1.10E-03 5.48E-07 2.40E-06
SO2 molecular weight 64.06 Chromium 1.40E-03 6.98E-07 3.06E-06
Conversion Factors Cobalt 8.40E-05 4.19E-08 1.83E-07
Btu/MMBtu 1,000,000 Dichlorobenzene 1.20E-03 5.98E-07 2.62E-06
scf/MMscf 1,000,000 Formaldehyde 0.08 3.74E-05 1.64E-04
lb/ton 2,000 n-Hexane 1.80 8.97E-04 3.93E-03
1Used for calculations with AP-42 emission factors, per Section 1.4 of AP-42 (dated 7/98).Lead 5.00E-04 2.49E-07 1.09E-06
Manganese 3.80E-04 1.89E-07 8.29E-07
Mercury 2.60E-04 1.30E-07 5.68E-07
Naphthalene 6.10E-04 3.04E-07 1.33E-06
Nickel 2.10E-03 1.05E-06 4.58E-06
POM 8.80E-05 4.39E-08 1.92E-07
Toluene 3.40E-03 1.69E-06 7.42E-06
Selenium 2.40E-05 1.20E-08 5.24E-08
1Emission factors are taken from AP-42, Chapter 1, Tables 1.4-1, 1.4-2, 1.4-3, and 1.4-4, dated July 1998.
2Assumes PM10 and PM2.5 are equal total PM based on footnote c to Table 1.4-2 of AP-42 (dated 7/98).
Equations used:
A. (Hourly Emissions, lb/hr) = (Reboiler Rating, MMBtu/hr) x (Emission Factor, lb/MMscf) x (1,000,000 Btu/MMBtu) / (Fuel Heat Value, Btu/scf) / (1,000,000 scf/MMscf)
B. (Annual Emissions, tpy) = (Hourly Emissions, lb/hr) x (Hours of Operation Per Year, hr/yr) / (2,000 lb/ton)
C. (SO 2 Emission Factor, lb/MMscf) = (H 2 S Content, mol%) x (SO 2 Molecular Weight, 64.06 lb/lb-mole) x (1,000,000 scf/MMscf) / (379.3 scf/lb-mole)
Natural gas-fired reboilers will be used to in association with the glycol dehydrator to heat the glycol mixture to help promote water removal. External combustion emissions were calculated
in accordance with AP-42 Section 1.4 (July 1998), using emission factors for Small Boilers (less than 100 MMBtu/hr rating). The H2S emissions were estimated using a material balance and
98% destruction efficiency, while SO2 emissions were estimated using a material balance conservatively assuming 100% conversion of H2S to SO2.
Pollutants
Emission Factor1
(lb/MMscf)
Total Emissions (per Reboiler)
D. (H 2 S Emission Factor, lb/MMscf) = (H 2 S Content, mol%) x (H 2 S Molecular Weight, 34.08 lb/lb-mole) x (1,000,000 scf/MMscf) x (1 - H 2 S Destruction Efficiency, %) / (379.3 scf/lb-mole)
Dehydrator - Controlled Hourly Emissions
Unit ID(s): DEHYRB
Component (lb/hr) (lb/hr) (lb/hr) (%) (lb/hr)
TEG 1.22E-04 5.19E-08 1.22E-04 0%1.22E-04 NOX 0.068 lb/MMBtu
Water 1.74E-02 0.16 0.18 0%0.18 CO 0.37 lb/MMBtu
Helium 4.54E-03 8.36E-05 4.63E-03 0%4.63E-03 SO2 -- --
Oxygen 2.69E-03 3.46E-05 2.72E-03 96%1.09E-04 PM10 7.60 lb/MMscf
Hydrogen 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00 PM2.5 7.60 lb/MMscf
H2S 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00 H2S -- --
Nitrogen 0.22 0.00 0.22 0%0.22
Carbon Dioxide 2.95 2.33 5.27 0%5.27
Methane 25.16 1.51 26.66 96%1.07 34.08
Ethane 3.59 0.92 4.52 96%0.18 64.06
Propane 1.34 0.74 2.08 96%0.08 379.30
Isobutane 0.71 0.54 1.26 96%0.05
n-Butane 0.50 0.57 1.07 96%0.04
Isopentane 0.65 1.14 1.79 96%0.07 8,760
n-Pentane 0.21 0.43 0.64 96%0.03 96%
Isohexane 5.75E-01 1.24 1.81 96%7.26E-02
n-Hexane 0.10 0.24 0.35 96%0.01
Benzene 9.92E-03 0.09 0.10 96%0.00
Toluene 1.39E-02 0.05 0.06 96%0.00
Ethylbenzene 2.69E-03 0.00 0.01 96%2.26E-04
o-Xylene 1.04E-02 0.01 0.02 96%7.87E-04
2,2,4-Trimethylpentane 4.03E-04 0.00 0.00 96%5.68E-05
Isoheptane 0.30 0.72 1.03 96%0.04
Octane 0.12 0.18 0.30 96%0.01
Nonane 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00
Decane 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00
Total 36.49 10.87 47.36 -- 7.34
Total VOC 4.55 5.95 10.50 -- 0.42
Total HAP 0.14 0.39 0.53 -- 0.02
Heating Value HHV (Btu/scf)1,114 1,779
1,200
Heating Value LHV (Btu/scf)1,002 1,601
1,080
Molecular Weight 19.83 40.26
Volumetric Flow (scf/hr)698.36 104.09 802
Heat Release (MMBtu/hr)0.78 0.19 0.96
Totals
(lb/hr) (lb/hr) (lb/hr)
Total NOx 0.05 0.01 0.07
Total CO 0.29 0.07 0.36
Total SO2 0.00E+00 0.00E+00 0.00E+00
Total PM10 0.01 7.91E-04 0.01
Total PM2.5 0.01 7.91E-04 0.01
Footnotes:
a Reboiler CO and NOx emission factors from AP-42, Table 13.5-1 & 13.5-2, February 2018. PM10 and PM2.5 emission factors from AP-42, Table 1.4-1 and 1.4-2, July 1998. SO2 emissions assume 100% conversion of H2S to SO2.
Component Emission Factor
Regenerator Vapors
Combustion Emissions from Reboiler
Total
Hourly Burner Destruction Efficiency
Stream:
Dehydration Vapors Controlled by Reboiler Burner Criteria Pollutant Emissions from Reboilera
Controlled Scenario Hours
H2S Molecular Weight
SO2 Molecular Weight
Gas Constant (scf/lb-mol)
Operation Variables
Emission Factor
Units
Constants
Flash Tank Vapors Hourly
Destruction
Reboiler Exhaust
(controlled)
Dehydrator - Controlled Annual Emissions
Unit ID(s): DEHYRB
Component (tpy) (tpy) (tpy) (%) (tpy)
TEG 5.36E-04 2.87E-07 5.37E-04 0%0.00 NOX 0.068 lb/MMBtu
Water 0.08 0.74 0.82 0%0.82 CO 0.37 lb/MMBtu
Helium 0.02 3.66E-04 0.02 0%0.02 SO2 -- --
Oxygen 0.01 1.52E-04 0.01 96%4.77E-04 PM10 7.60 lb/MMscf
Hydrogen 0.00 0.00E+00 0.00 96%0.00E+00 PM2.5 7.60 lb/MMscf
H2S 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00 H2S -- --
Nitrogen 0.96 0.01 0.98 0%0.98
Carbon Dioxide 12.91 10.19 23.10 0%23.10
Methane 110.19 6.60 116.79 96%4.67 34.08
Ethane 15.75 4.05 19.79 96%0.79 64.06
Propane 5.89 3.24 9.13 96%0.37 379.30
Isobutane 3.11 2.39 5.51 96%0.22
n-Butane 2.17 2.53 4.70 96%0.19
Isopentane 2.86 5.06 7.92 96%0.32 8,760
n-Pentane 0.91 1.93 2.84 96%0.11 96%
Isohexane 2.52 5.62 8.14 96%0.33
n-Hexane 0.45 1.11 1.56 96%0.06
Benzene 0.04 0.39 0.44 96%0.02
Toluene 6.11E-02 0.22 0.28 96%0.01
Ethylbenzene 1.18E-02 0.01 0.03 96%0.00
o-Xylene 4.58E-02 0.04 0.09 96%0.00
2,2,4-Trimethylpentane 1.77E-03 4.78E-03 6.55E-03 96%2.62E-04
Isoheptane 1.33 3.37 4.70 96%0.19
Octane 0.53 0.84 1.37 96%0.05
Nonane 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00
Decane 0.00E+00 0.00E+00 0.00E+00 96%0.00E+00
Total 159.85 48.36 208.21 -- 32.25
Total VOC 19.93 26.77 46.70 -- 1.87
Total HAP 0.61 1.79 2.40 -- 0.10
Annual Hours (Hrs)8,760 8,760 8,760
Heating Value HHV (Btu/scf)1,114 1,779 1,200
Heating Value LHV (Btu/scf)1,002 1,601 1,080
Molecular Weight 19.83 40.26
Volumetric Flow (scf/hr)698.36 104.09 802
Heat Release (MMBtu/yr)6,814 1,622 0.96
Totals
(tpy) (tpy) (tpy)
Total NOx 0.23 0.06 0.29
Total CO 1.26 0.30 1.56
Total SO2 0.00E+00 0.00E+00 0.00E+00
Total PM10 0.02 0.00 0.03
Total PM2.5 0.02 0.00
0.03
Footnotes:
a Reboiler CO and NOx emission factors from AP-42, Table 13.5-1 & 13.5-2, February 2018. PM10 and PM2.5 emission factors from AP-42, Table 1.4-1 and 1.4-2, July 1998. SO2 emissions assume 100% conversion of
H2S to SO2.
SO2 Molecular Weight
Gas Constant (scf/lb-mol)
Operation Variables
Total
Combustion Emissions from Reboiler
Hourly Burner Destruction Efficiency
Constants
Controlled Scenario Hours
H2S Molecular Weight
Criteria Pollutant Emissions from Reboilera
ProMax Stream: Flash Tank Vapors
Reboiler Exhaust
(controlled) Component Emission Factor
Emission Factor
Units
Dehydration Vapors Controlled by Reboiler Burner
Hourly
Destruction
Efficiency
Regenerator
Vapors
Natural Gas Liquid Truck Loading
Unit ID: TL-NGL
Estimated truck loads per year 6
Connection diameter 0.17 ft
Length between valves 5.00 ft
Connection volume 0.11 ft^3
Annual connection volume vented 0.66 ft^3
NGL density 31.21 lb/ft^3
Annual NGL vented 20.51 lb/yr
VOCs Vented1 0.01 tpy
1Calculations conservatively assume 100% of NGL vapors are VOCs.
Dehydration PStreams (yearly)
Process Streams Blowdown Dry Basis Gas Dry Gas Flash Gas Flash Tank Liquids Lean TEG Overheads Rich TEG TEG Wet Gas Feed WT Breathing WT Flash WT Output WT to Loading WT W&B WT Working
Composition Status: Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved
Phase: Total From Block: TEG Makeup -- Gas/Glycol HEX - A Rich Flash Rich Flash Reboiler Condenser Glycol Contactor -- SAT-1 Water Tank Water Tank Water Tank Water Tank MIX-101 Water Tank
To Block: -- VSSL-100 -- -- -- Cross Exchanger BTEX Condenser Reflux Coil TEG Makeup Glycol Contactor MIX-101 -- -- -- -- MIX-101
%% % % % % % % % %%% %%%
93.8148 0* 1.90152E-05 ######### 93.8148 0.0265033 90.2639 99.1725* 0 8.89893E-08 ######### ########## 0.137040 ######### 8.89893E-08
5.93019 0* 0.00315296 0.0523681 5.93019 6.62169 5.74695 0.827516* 0.0640881 7.22653 2.53379 11.2025 19.6761 7.22653 7.22653
########## 0.150000* 0.155110 0.0617027 9.58881E-11 0.00605841 0.00200315 0* 0.149904 1.62406E-05 ######### 0 0 ######### 1.62406E-05
########## 0.0200000* 0.0208510 ######### 9.82199E-13 0.000314000 0.000147381 0* 0.0199872 1.30327E-05 ######### 0 0 ######### 1.30327E-05
00* 00 0 0 00* 0 000 000
00* 00 0 0 00* 0 000 000
########## 1.82000* 1.89691 0.427026 9.06531E-11 0.0286467 0.0137839 0* 1.81884 0.000581873 0.0357449 0 0 ######### 0.000581873
########## 0.570001* 0.305700 3.63845 6.85590E-05 15.3744 0.207890 0* 0.569636 3.92681 20.3136 0 0 3.92681 3.92681
########## 93.6014* 94.4809 85.2154 1.49577E-06 27.2562 2.87932 0* 93.5414 2.44177 36.7210 0 0 2.44177 2.44177
########## 2.62941* 2.39929 6.49630 6.78021E-06 8.97440 0.260704 0* 2.62772 5.12159 11.6639 0 0 5.12159 5.12159
########## 0.486801* 0.395700 1.65707 1.62839E-05 4.96598 0.0825040 0* 0.486489 9.32147 6.06766 0 0 9.32147 9.32147
########## 0.193200* 0.148982 0.664861 2.05272E-05 2.88512 0.0384483 0* 0.193077 10.7653 3.25133 4.61735 0.207480 10.7653 10.7653
########## 0.111400* 0.0699364 0.463152 4.69766E-05 3.12430 0.0334724 0* 0.111329 11.0796 3.37800 9.43217 0.638622 11.0796 11.0796
########## 0.131200* 0.0684244 0.491567 0.000250532 5.61412 0.0494468 0* 0.131116 16.8301 5.24867 22.8650 4.04110 16.8301 16.8301
########## 0.0376001* 0.0133903 0.156764 0.000143029 2.25765 0.0186209 0* 0.0375760 6.24487 1.96605 8.99125 2.17248 6.24487 6.24487
0.00289647 0.0975002* 0.0251190 0.362834 0.00289647 7.17549 0.0572156 0* 0.0974377 14.4557 4.64216 22.6872 13.9385 14.4557 14.4557
0.00103109 0.0186000* 0.00235622 0.0642204 0.00103109 1.67394 0.0130384 0* 0.0185881 2.75365 0.897675 4.38320 4.06868 2.75365 2.75365
0.0243823 0.00570001* 0.00105900 ######### 0.0243823 0.660733 0.0276261 0* 0.00569636 1.08980 0.353270 1.72621 1.62674 1.08980 1.08980
0.0666968 0.00650001* 0.00169152 ######### 0.0666968 0.671377 0.0684448 0* 0.00649585 0.469528 0.157283 0.756000 2.63135 0.469528 0.469528
0.0212079 0.00110000* 0.000358068 ######### 0.0212079 0.0989995 0.0210404 0* 0.00109930 0.0243392 ######### 0.0389066 0.464653 0.0243392 0.0243392
0.123246 0.00450001* 0.00159026 ######### 0.123246 0.378248 0.121010 0* 0.00449713 0.0751394 0.0260734 0.119950 1.80833 0.0751394 0.0751394
########## 0.000100000* 6.18217E-06 ######### 7.65056E-06 0.0106948 7.73619E-05 0* 9.99361E-05 0.00840455 ######### 0.0135989 0.0404819 ######### 0.00840455
0.00338827 0.0661001* 0.00350481 0.164501 0.00338827 6.90535 0.0497527 0* 0.0660578 6.83348 2.26601 11.0265 23.8002 6.83348 6.83348
0.0116301 0.0489001* 0.00593498 0.0570897 0.0116301 5.28985 0.0446083 0* 0.0488688 1.33124 0.461429 2.14017 24.7482 1.33124 1.33124
00* 00 0 0 00* 0 000 000
00* 00 0 0 00* 0 000 000
%% % % % % % % % %%% %%%
99.0699 0* 0.000168400 ######### 99.0699 0.0817570 98.4063 99.9* 0 2.12074E-07 ######### ########## 0.249404 ######### 2.12074E-07
0.751257 0* 0.00334971 0.0475737 0.751257 2.45044 0.751614 0.1* 0.0666136 2.06599 1.18345 2.79453 4.29580 2.06599 2.06599
########## 0.0346410* 0.0366127 0.0124539 2.69889E-12 0.000498121 5.82067E-05 0* 0.0346179 1.03158E-06 ######### 0 0 ######### 1.03158E-06
########## 0.0369250* 0.0393468 ######### 2.21010E-13 0.000206394 3.42367E-05 0* 0.0369004 6.61800E-06 ######### 0 0 ######### 6.61800E-06
00* 00 0 0 00* 0 000 000
00* 00 0 0 00* 0 000 000
########## 2.94167* 3.13373 0.603225 1.78578E-11 0.0164844 0.00280320 0* 2.93971 0.000258674 0.0259607 0 0 ######### 0.000258674
########## 1.44736* 0.793396 8.07461 2.12173E-05 13.8988 0.0664199 0* 1.44640 2.74249 23.1777 0 0 2.74249 2.74249
########## 86.6381* 89.3848 68.9364 1.68739E-07 8.98193 0.335334 0* 86.5804 0.621633 15.2729 0 0 0.621633 0.621633
########## 4.56176* 4.25452 9.85020 1.43364E-06 5.54317 0.0569094 0* 4.55872 2.44390 9.09286 0 0 2.44390 2.44390
########## 1.23852* 1.02899 3.68466 5.04933E-06 4.49815 0.0264111 0* 1.23769 6.52287 6.93671 0 0 6.52287 6.52287
########## 0.647896* 0.510650 1.94864 8.38977E-06 3.44461 0.0162232 0* 0.647465 9.92947 4.89936 3.71609 0.146145 9.92947 9.92947
########## 0.373580* 0.239714 1.35745 1.92001E-05 3.73017 0.0141236 0* 0.373331 10.2194 5.09024 7.59111 0.449833 10.2194 10.2194
########## 0.546159* 0.291131 1.78843 0.000127107 8.32041 0.0258991 0* 0.545795 19.2697 9.81781 22.8429 3.53341 19.2697 19.2697
########## 0.156521* 0.0569729 0.570341 7.25658E-05 3.34596 0.00975319 0* 0.156417 7.15008 3.67756 8.98257 1.89955 7.15008 7.15008
0.00175522 0.484779* 0.127654 1.57670 0.00175522 12.7019 0.0357944 0* 0.484456 19.7688 10.3715 27.0717 14.5568 19.7688 19.7688
########## 0.0924810* 0.0119742 0.279072 0.000624824 2.96316 0.00815690 0* 0.0924194 3.76574 2.00557 5.23029 4.24914 3.76574 3.76574
0.0133927 0.0256891* 0.00487823 0.0271768 0.0133927 1.06017 0.0156659 0* 0.0256719 1.35090 0.715419 1.86708 1.53993 1.35090 1.35090
0.0432140 0.0345550* 0.00919106 0.0382057 0.0432140 1.27069 0.0457823 0* 0.0345319 0.686532 0.375715 0.964526 2.93822 0.686532 0.686532
0.0158328 0.00673799* 0.00224179 ######### 0.0158328 0.215898 0.0162163 0* 0.00673350 0.0410058 0.0231498 0.0571947 0.597826 0.0410058 0.0410058
0.0920092 0.0275645* 0.00995632 0.0286244 0.0920092 0.824881 0.0932655 0* 0.0275461 0.126592 0.0717655 0.176333 2.32661 0.126592 0.126592
########## 0.000659069* 4.16451E-05 ######### 6.14535E-06 0.0250946 6.41532E-05 0* 0.000658630 0.0152352 ######### 0.0215094 0.0560403 0.0152352 0.0152352
0.00238745 0.382150* 0.0207104 0.831199 0.00238745 14.2133 0.0361917 0* 0.381896 10.8662 5.88674 15.2991 28.9016 10.8662 10.8662
0.00934194 0.322285* 0.0399799 0.328845 0.00934194 12.4123 0.0369920 0* 0.322070 2.41318 1.36652 3.38512 34.2597 2.41318 2.41318
00* 00 0 0 00* 0 000 000
00* 00 0 0 00* 0 000 000
lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h
########## 0* 0.00116322 ######### 0 7825.28 0.0137249 7825.29 0 0 5.02535E-10 ######### ########## 0.0137249 ######### 1.01969E-11
########## 0* 0.0231381 0.0173618 0 59.3398 0.411366 59.7686 0 0.495553 0.00489562 ######### ########## 0.236400 ######### 9.93370E-05
########## 0.257530* 0.252902 ######### 0 2.13179E-10 8.36219E-05 0.00462861 0 0.257530 2.44445E-09 ######### 0 0 ######### 4.96004E-11
########## 0.274510* 0.271787 ######### 0 1.74570E-11 3.46483E-05 0.00272251 0 0.274510 1.56821E-08 ######### 0 0 ######### 3.18206E-10
00* 00 0 0 0 00 0 000 000
00* 00 0 0 0 00 0 000 000
########## 21.8691* 21.6462 0.220144 0 1.41054E-09 0.00276732 0.222911 0 21.8691 6.12959E-07 ######### 0 0 ######### 1.24375E-08
########## 10.7601* 5.48037 2.94679 0 0.00167590 2.33326 5.28172 0 10.7601 0.00649865 ######### 0 0 ######### 0.000131864
########## 644.090* 617.425 25.1580 0 1.33283E-05 1.50784 26.6658 0 644.090 0.00147303 ######### 0 0 ######### 2.98893E-05
########## 33.9133* 29.3880 3.59478 0 0.000113240 0.930558 4.52545 0 33.9133 0.00579110 ######### 0 0 ######### 0.000117507
########## 9.20747* 7.10772 1.34470 0 0.000398833 0.755125 2.10022 0 9.20747 0.0154567 ######### 0 0 0.0157703 0.000313632
########## 4.81663* 3.52731 0.711148 0 0.000662686 0.578262 1.29007 0 4.81663 0.0235291 ######### ########## 0.00804244 0.0240065 0.000477428
########## 2.77729* 1.65582 0.495395 0 0.00151656 0.626201 1.12311 0 2.77729 0.0242161 ######### ########## 0.0247545 0.0247075 0.000491370
########## 4.06029* 2.01098 0.652677 0 0.0100399 1.39678 2.05950 0 4.06029 0.0456618 ######### ########## 0.194445 0.0465884 0.000926525
########## 1.16362* 0.393540 0.208143 0 0.00573178 0.561701 0.775576 0 1.16362 0.0169430 ######### ########## 0.104533 0.0172868 0.000343790
########## 3.60398* 0.881767 0.575410 0 0.138640 2.13232 2.84637 0 3.60398 0.0468446 ######### ########## 0.801068 0.0477951 0.000950523
########## 0.687528* 0.0827118 0.101846 0 0.0493532 0.497440 0.648639 0 0.687528 0.00892337 ######### ########## 0.233833 ######### 0.000181064
########## 0.190979* 0.0336963 ######### 0 1.05786 0.177976 1.24575 0 0.190979 0.00320111 ######### ########## 0.0847429 ######### 6.49537E-05
########## 0.256891* 0.0634871 0.0139430 0 3.41336 0.213317 3.64062 0 0.256891 0.00162682 ######### ########## 0.161692 ######### 3.30098E-05
########## 0.0500920* 0.0154852 ######### 0 1.25059 0.0362437 1.28952 0 0.0500920 9.71682E-05 ######### ########## 0.0328987 ######### 1.97164E-06
########## 0.204922* 0.0687732 0.0104463 0 7.26757 0.138477 7.41649 0 0.204922 0.000299976 ######### ########## 0.128035 ######### 6.08681E-06
########## 0.00489969* 0.000287663 ######### 0 0.000485405 0.00421275 0.00510148 0 0.00489969 3.61016E-05 ######### ########## 0.00308393 ######### 7.32537E-07
########## 2.84100* 0.143057 0.303342 0 0.188578 2.38606 2.87798 0 2.84100 0.0257487 ######### ########## 1.59047 0.0262712 0.000522467
########## 2.39595* 0.276161 0.120010 0 0.737896 2.08371 2.94161 0 2.39595 0.00571832 ######### ########## 1.88533 ######### 0.000116030
00* 00 0 0 0 00 0 000 000
00* 00 0 0 0 00 0 000 000
Process Streams Blowdown Dry Basis Gas Dry Gas Flash Gas Flash Tank Liquids Lean TEG Overheads Rich TEG TEG Wet Gas Feed WT Breathing WT Flash WT Output WT to Loading WT W&B WT Working
Properties Status: Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved
Phase: Total From Block: TEG Makeup -- Gas/Glycol HEX - A Rich Flash Rich Flash Reboiler Condenser Glycol Contactor -- SAT-1 Water Tank Water Tank Water Tank Water Tank MIX-101 Water Tank
To Block: -- VSSL-100 -- -- -- Cross Exchanger BTEX Condenser Reflux Coil TEG Makeup Glycol Contactor MIX-101 -- -- -- -- MIX-101
Property Units
Temperature °F 297.198 37* 90* 93.5950 407.991 200.650 88.7586 100* 79.7391 65.7350 65.7350 65.7350 65.7350 65.7350 65.7350
Pressure psig 0.00405122 119* 990 40 40 0.504051 0.00405122 1015 1000* 1025 -2.35595 -2.35595 -2.35595 -2.35595 -2.35595 -2.35595
Molecular Weight lb/lbmol 142.207 17.3318 16.9571 19.8308 142.207 48.6818 137.747 149.079 17.3323 63.0146 38.5712 72.2185 82.5154 63.0146 63.0146
Mass Flow lb/h ########## 743.426 690.749 36.4945 0 7898.74 16.7875 7952.02 0 743.922 0.236962 ######### 0.00165166 5.50305 0.241770 0.00480819
Std Vapor Volumetric Flow MMSCFD ########## 0.390659* 0.371000 0.0167607 0 0.505873 0.00314068 0.525774 0 0.390910 3.42485E-05 ######### ########## 0.000607398 ######### 6.94937E-07
Std Liquid Volumetric Flow sgpm ########## 4.67863 4.41110 0.211392 0 14.0000 0.0574092 14.2688 0 4.67962 0.000767768 ######### ########## 0.0156247 ######### 1.55788E-05
API Gravity -6.68622 -6.68629 -4.94874 -7.21440 83.5727 68.5782
Gross Ideal Gas Heating ValuBtu/ft^3 3888.97 1033.80 1019.16 1113.85 3888.97 2281.90 3790.91 4095.08 1033.17 3329.12 1673.64 3866.61 4290.66 3329.12 3329.12
Mole Fraction
TEG
Water
Helium
Oxygen
H2S
n-Butane
Isopentane
n-Pentane
Hydrogen
Isohexane
n-Hexane
Benzene
Nitrogen
Carbon Dioxide
Methane
Ethane
Propane
Isobutane
Nonane
Decane
Mass Fraction
TEG
Water
Helium
Toluene
Ethylbenzene
o-Xylene
2,2,4-Trimethylpentane
Isoheptane
Octane
Propane
Isobutane
n-Butane
Isopentane
n-Pentane
Isohexane
Oxygen
H2S
Nitrogen
Carbon Dioxide
Methane
Ethane
Hydrogen
Isoheptane
Octane
Nonane
Decane
Mass Flow
TEG
n-Hexane
Benzene
Toluene
Ethylbenzene
o-Xylene
2,2,4-Trimethylpentane
Methane
Ethane
Propane
Isobutane
n-Butane
Isopentane
Water
Helium
Oxygen
H2S
Nitrogen
Carbon Dioxide
Hydrogen
o-Xylene
2,2,4-Trimethylpentane
Isoheptane
Octane
Nonane
Decane
n-Pentane
Isohexane
n-Hexane
Benzene
Toluene
Ethylbenzene
Dehydration PStreams (yearly)
Process Streams
Composition Status:
Phase: Total From Block:
To Block:
Process Streams
Properties Status:
Phase: Total From Block:
To Block:
Property Units
Temperature °F
Pressure psig
Molecular Weight lb/lbmol
Mass Flow lb/h
Std Vapor Volumetric Flow MMSCFD
Std Liquid Volumetric Flow sgpm
API Gravity
Gross Ideal Gas Heating ValuBtu/ft^3
Mole Fraction
TEG
Water
Helium
Oxygen
H2S
n-Butane
Isopentane
n-Pentane
Hydrogen
Isohexane
n-Hexane
Benzene
Nitrogen
Carbon Dioxide
Methane
Ethane
Propane
Isobutane
Nonane
Decane
Mass Fraction
TEG
Water
Helium
Toluene
Ethylbenzene
o-Xylene
2,2,4-Trimethylpentane
Isoheptane
Octane
Propane
Isobutane
n-Butane
Isopentane
n-Pentane
Isohexane
Oxygen
H2S
Nitrogen
Carbon Dioxide
Methane
Ethane
Hydrogen
Isoheptane
Octane
Nonane
Decane
Mass Flow
TEG
n-Hexane
Benzene
Toluene
Ethylbenzene
o-Xylene
2,2,4-Trimethylpentane
Methane
Ethane
Propane
Isobutane
n-Butane
Isopentane
Water
Helium
Oxygen
H2S
Nitrogen
Carbon Dioxide
Hydrogen
o-Xylene
2,2,4-Trimethylpentane
Isoheptane
Octane
Nonane
Decane
n-Pentane
Isohexane
n-Hexane
Benzene
Toluene
Ethylbenzene
1 2 3 4 5 6 7 8 9 52 53 56 57 58 59 61 64 65 66 67 68 70 - BTEX Flash 70 - BTEX HC Liquid 70 - BTEX Liquids 70 - BTEX Water
Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved
VSSL-100 CMPR-100 FAXR-100 Glycol Contactor VSSL-101 Glycol Regenerator Condenser VSSL-101 VSSL-100 Reflux Coil VLVE-100 Rich Flash Cross Exchanger Glycol Regenerator Reboiler Cross Exchanger TEG Makeup Glycol Pump Gas/Glycol HEX - B TEG Recycle -- BTEX Condenser BTEX Condenser MIX-100 BTEX Condenser
CMPR-100 FAXR-100 VSSL-101 Gas/Glycol HEX - A SAT-1 Condenser Glycol Regenerator -- -- VLVE-100 Rich Flash Cross Exchanger Glycol Regenerator Reboiler Glycol Regenerator TEG Makeup Glycol Pump Gas/Glycol HEX - B TEG Recycle Glycol Contactor SAT-1 -- MIX-100 Water Tank MIX-100
%%% % % % % %% % % % % % % % % % % % % % %
0 0 0 1.90152E-05 0 0.0616567 87.9451 90.2639 90.2639 93.2361 93.2361 76.9381 9.43160 93.8148 93.8148 93.8148 93.8148 93.8166 0* 1.59001E-07 0.000152665 0.129558 0.678341
0 0 0 0.00315296 0 6.62330 10.6606 5.74695 5.74695 5.93446 5.93446 21.3830 83.1943 5.93019 5.93019 5.93019 5.93019 5.92593 100* 3.43949 0.0576197 18.9954 99.3066
0.150000 0.150000 0.150000 0.155110 0.150000 0.00605599 1.66806E-06 ######### ######### 3.73813E-05 3.73813E-05 3.12096E-08 1.55665E-07 9.58881E-11 0 0 0 0 0* 0.00761601 2.27371E-06 1.85203E-06 6.37481E-08
0.0200000 0.0200000 0.0200000 0.0208510 0.0200000 0.000313875 5.28272E-08 ######### ######### 1.93742E-06 1.93742E-06 5.77920E-10 2.88567E-09 9.82199E-13 0 0 0 0 0* 0.000394549 9.77529E-07 7.92882E-07 9.83618E-09
0000000 000000000000*0 0 00
0000000 000000000000*0 0 00
1.82000 1.82000 1.82000 1.89691 1.82000 0.0286352 4.78466E-06 0.0137839 0.0137839 0.000176754 0.000176754 5.25155E-08 2.62215E-07 9.06531E-11 0 0 0 0 0* 0.0360038 4.80590E-05 3.89773E-05 4.63744E-07
0.570001 0.570001 0.570001 0.305700 0.570001 15.3683 0.0555146 0.207890 0.207890 0.0949300 0.0949300 0.00637662 0.0316089 6.85590E-05 ########## 6.85590E-05 6.85590E-05 8.22614E-05 0* 19.2723 0.266648 0.217740 0.0103325
93.6014 93.6014 93.6014 94.4809 93.6014 27.2453 0.0150158 2.87932 2.87932 0.168175 0.168175 0.000415929 0.00207366 1.49577E-06 ########## 1.49577E-06 1.49577E-06 1.93236E-06 0* 34.2296 0.173203 0.140335 0.000948388
2.62941 2.62941 2.62941 2.39929 2.62941 8.97081 0.0148837 0.260704 0.260704 0.0553799 0.0553799 0.000959300 0.00476938 6.78021E-06 ########## 6.78021E-06 6.78021E-06 8.44832E-06 0* 11.2101 0.347084 0.280950 0.000487386
0.486801 0.486801 0.486801 0.395700 0.486801 4.96400 0.0149198 0.0825040 0.0825040 0.0306569 0.0306569 0.00155310 0.00770038 1.62839E-05 ########## 1.62839E-05 1.62839E-05 1.92265E-05 0* 6.11239 0.628025 0.508229 0.000201458
0.193200 0.193200 0.193200 0.148982 0.193200 2.88397 0.0116511 0.0384483 0.0384483 0.0178220 0.0178220 0.00155390 0.00768739 2.05272E-05 ########## 2.05272E-05 2.05272E-05 2.31889E-05 0* 3.42590 0.966791 0.782332 8.11472E-05
0.111400 0.111400 0.111400 0.0699364 0.111400 3.12306 0.0175213 0.0334724 0.0334724 0.0193240 0.0193240 0.00298806 0.0147524 4.69766E-05 ########## 4.69766E-05 4.69766E-05 5.09210E-05 0* 3.61737 1.49166 1.20706 0.000116547
0.131200 0.131200 0.131200 0.0684244 0.131200 5.61190 0.0484500 0.0494468 0.0494468 0.0348888 0.0348888 0.0116897 0.0574466 0.000250532 ########## 0.000250532 0.000250532 0.000254400 0* 5.83971 5.85389 4.73693 0.000139167
0.0376001 0.0376001 0.0376001 0.0133903 0.0376001 2.25676 0.0227856 0.0186209 0.0186209 0.0140722 0.0140722 0.00616422 0.0302490 0.000143029 ########## 0.000143029 0.000143029 0.000137126 0* 2.22261 2.95843 2.39393 2.32886E-05
0.0975002 0.0975002 0.0975002 0.0251190 0.0975002 7.17267 0.128095 0.0572156 0.0572156 0.0471523 0.0471523 0.0650306 0.313567 0.00289647 0.00289647 0.00289647 0.00289647 0.00259409 0* 5.42947 17.2577 13.9648 2.44969E-05
0.0186000 0.0186000 0.0186000 0.00235622 0.0186000 1.67328 0.0363147 0.0130384 0.0130384 0.0113531 0.0113531 0.0208972 0.100362 0.00103109 0.00103109 0.00103109 0.00103109 0.000915554 0* 1.07663 4.93890 3.99650 8.19003E-06
######### ######### ######### 0.00105900 ######### 0.660515 0.115228 0.0276261 0.0276261 0.0283086 0.0283086 0.206526 0.935100 0.0243823 0.0243823 0.0243823 0.0243823 0.0250883 0* 0.419879 1.97350 1.59727 0.00179919
######### ######### ######### 0.00169152 ######### 0.671189 0.201616 0.0684448 0.0684448 0.0704277 0.0704277 0.426537 1.86590 0.0666968 0.0666968 0.0666968 0.0666968 0.0673595 0* 0.197693 3.10574 2.51326 0.000686978
######### ######### ######### 0.000358068 ######### 0.0989789 0.0474766 0.0210404 0.0210404 0.0216878 0.0216878 0.104325 0.436796 0.0212079 0.0212079 0.0212079 0.0212079 0.0212816 0* 0.0111459 0.544501 0.440611 3.60837E-05
######### ######### ######### 0.00159026 ######### 0.378194 0.243895 0.121010 0.121010 0.124819 0.124819 0.528253 2.14828 0.123246 0.123246 0.123246 0.123246 0.123464 0* 0.0348049 2.11775 1.71370 0.000167675
######### ######### ######### 6.18217E-06 ######### 0.0106906 0.000306326 ######### ######### 7.35915E-05 7.35915E-05 0.000180557 0.000872182 7.65056E-06 ########## 7.65056E-06 7.65056E-06 7.71443E-06 0* 0.00348498 0.0478621 0.0387295 3.10945E-08
0.0661001 0.0661001 0.0661001 0.00350481 0.0661001 6.90266 0.165632 0.0497527 0.0497527 0.0459743 0.0459743 0.0857805 0.415349 0.00338827 0.00338827 0.00338827 0.00338827 0.00323471 0* 2.79888 28.2666 22.8730 8.06151E-06
0.0489001 0.0489001 0.0489001 0.00593498 0.0489001 5.28783 0.254894 0.0446083 0.0446083 0.0441974 0.0441974 0.209613 1.00154 0.0116301 0.0116301 0.0116301 0.0116301 0.0129531 0* 0.614483 29.0039 23.4696 1.75369E-06
0000000 000000000000*0 0 00
0000000 000000000000*0 0 00
%%% % % % % %% % % % % % % % % % % % % % %
0 0 0 0.000168400 0 0.190063 97.6264 98.4063 98.4063 98.8600 98.8600 95.4583 38.9554 99.0699 99.0699 99.0699 99.0699 99.0687 0* 5.93149E-07 0.000238341 0.238885 5.38516
0 0 0 0.00334971 0 2.44929 1.41967 0.751614 0.751614 0.754860 0.754860 3.18266 41.2216 0.751257 0.751257 0.751257 0.751257 0.750693 100* 1.53924 0.0107915 4.20166 94.5754
0.0346410 0.0346410 0.0346410 0.0366127 0.0346410 0.000497568 4.93535E-08 ######### ######### 1.05643E-06 1.05643E-06 1.03208E-09 1.71365E-08 2.69889E-12 0 0 0 0 0* 0.000757255 9.46118E-08 9.10166E-08 1.34887E-08
0.0369250 0.0369250 0.0369250 0.0393468 0.0369250 0.000206165 1.24955E-08 ######### ######### 4.37726E-07 4.37726E-07 1.52785E-10 2.53963E-09 2.21010E-13 0 0 0 0 0* 0.000313623 3.25185E-07 3.11511E-07 1.66387E-08
0000000 000000000000*0 0 00
0000000 000000000000*0 0 00
2.94167 2.94167 2.94167 3.13373 2.94167 0.0164661 9.90788E-07 ######### ######### 3.49606E-05 3.49606E-05 1.21544E-08 2.02029E-07 1.78578E-11 0 0 0 0 0* 0.0250546 1.39962E-05 1.34063E-05 6.86757E-07
1.44736 1.44736 1.44736 0.793396 1.44736 13.8834 0.0180600 0.0664199 0.0664199 0.0294981 0.0294981 0.00231856 0.0382601 2.12173E-05 ########## 2.12173E-05 2.12173E-05 2.54570E-05 0* 21.0694 0.121998 0.117657 0.0240388
86.6381 86.6381 86.6381 89.3848 86.6381 8.97195 0.00178067 0.335334 0.335334 0.0190493 0.0190493 5.51277E-05 0.000914953 1.68739E-07 ########## 1.68739E-07 1.68739E-07 2.17983E-07 0* 13.6410 0.0288865 0.0276420 0.000804297
4.56176 4.56176 4.56176 4.25452 4.56176 5.53702 0.00330821 0.0569094 0.0569094 0.0117575 0.0117575 0.000238317 0.00394431 1.43364E-06 ########## 1.43364E-06 1.43364E-06 1.78630E-06 0* 8.37342 0.108498 0.103724 0.000774733
1.23852 1.23852 1.23852 1.02899 1.23852 4.49316 0.00486319 0.0264111 0.0264111 0.00954483 0.00954483 0.000565817 0.00933895 5.04933E-06 ########## 5.04933E-06 5.04933E-06 5.96156E-06 0* 6.69545 0.287899 0.275161 0.000469612
0.647896 0.647896 0.647896 0.510650 0.647896 3.44079 0.00500579 0.0162232 0.0162232 0.00731378 0.00731378 0.000746183 0.0122889 8.38977E-06 ########## 8.38977E-06 8.38977E-06 9.47738E-06 0* 4.94641 0.584174 0.558296 0.000249330
0.373580 0.373580 0.373580 0.239714 0.373580 3.72604 0.00752785 0.0141236 0.0141236 0.00793020 0.00793020 0.00143487 0.0235828 1.92001E-05 ########## 1.92001E-05 1.92001E-05 2.08115E-05 0* 5.22285 0.901324 0.861395 0.000358097
0.546159 0.546159 0.546159 0.291131 0.546159 8.31120 0.0258397 0.0258991 0.0258991 0.0177730 0.0177730 0.00696810 0.113994 0.000127107 ########## 0.000127107 0.000127107 0.000129066 0* 10.4663 4.39078 4.19621 0.000530794
0.156521 0.156521 0.156521 0.0569729 0.156521 3.34225 0.0121521 ######### ######### 0.00716860 0.00716860 0.00367441 0.0600247 7.25658E-05 ########## 7.25658E-05 7.25658E-05 6.95685E-05 0* 3.98349 2.21901 2.12067 8.88244E-05
0.484779 0.484779 0.484779 0.127654 0.484779 12.6879 0.0815978 0.0357944 0.0357944 0.0286900 0.0286900 0.0463000 0.743197 0.00175522 0.00175522 0.00175522 0.00175522 0.00157193 0* 11.6229 15.4609 14.7757 0.000111597
0.0924810 0.0924810 0.0924810 0.0119742 0.0924810 2.95990 0.0231329 ######### ######### 0.00690785 0.00690785 0.0148782 0.237871 0.000624824 ########## 0.000624824 0.000624824 0.000554794 0* 2.30474 4.42467 4.22858 3.73102E-05
0.0256891 0.0256891 0.0256891 0.00487823 0.0256891 1.05907 0.0665333 0.0156659 0.0156659 0.0156128 0.0156128 0.133282 2.00893 0.0133927 0.0133927 0.0133927 0.0133927 0.0137801 0* 0.814730 1.60258 1.53189 0.00742940
0.0345550 0.0345550 0.0345550 0.00919106 0.0345550 1.26944 0.137319 0.0457823 0.0457823 0.0458173 0.0458173 0.324697 4.72845 0.0432140 0.0432140 0.0432140 0.0432140 0.0436420 0* 0.452485 2.97491 2.84321 0.00334613
######### ######### ######### 0.00224179 ######### 0.215699 0.0372584 0.0162163 0.0162163 0.0162571 0.0162571 0.0915065 1.27541 0.0158328 0.0158328 0.0158328 0.0158328 0.0158873 0* 0.0293947 0.600963 0.574339 0.000202513
0.0275645 0.0275645 0.0275645 0.00995632 0.0275645 0.824178 0.191403 0.0932655 0.0932655 0.0935635 0.0935635 0.463344 6.27282 0.0920092 0.0920092 0.0920092 0.0920092 0.0921697 0* 0.0917898 2.33736 2.23381 0.000941042
######### ######### ######### 4.16451E-05 ######### 0.0250670 0.000258656 ######### ######### 5.93536E-05 5.93536E-05 0.000170400 0.00274014 6.14535E-06 ########## 6.14535E-06 6.14535E-06 6.19646E-06 0* 0.00988888 0.0568374 0.0543186 1.87766E-07
0.382150 0.382150 0.382150 0.0207104 0.382150 14.1977 0.122683 0.0361917 0.0361917 0.0325264 0.0325264 0.0710142 1.14467 0.00238745 0.00238745 0.00238745 0.00238745 0.00227917 0* 6.96680 29.4454 28.1405 4.27023E-05
0.322285 0.322285 0.322285 0.0399799 0.322285 12.3987 0.215227 0.0369920 0.0369920 0.0356464 0.0356464 0.197821 3.14655 0.00934194 0.00934194 0.00934194 0.00934194 0.0104043 0* 1.74364 34.4428 32.9164 1.05898E-05
0000000 000000000000*0 0 00
0000000 000000000000*0 0 00
lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h lb/h
0 0 0 0.00116322 0 0.0319422 0.0182172 0 0 7825.29 7825.29 7825.29 7825.29 8021.95 196.677 7825.28 7825.28 7825.28 7825.28 7825.29 0* 6.54959E-08 1.30868E-05 0.0137249 0.0137118
0 0 0 0.0231381 0 0.411631 0.000264913 0 0 59.7686 59.7686 59.7512 59.7512 267.459 208.119 59.3398 59.3398 59.3398 59.3398 59.2961 0.495553* 0.169964 0.000592533 0.241402 0.240809
0.257530 0.257530 0.257530 0.252902 0.257530 8.36219E-05 9.20944E-12 0 0 ######### ######### 8.36221E-05 8.36221E-05 8.67316E-08 8.65185E-08 2.13179E-10 0 0 0 0 0* 8.36167E-05 5.19491E-09 5.22925E-09 3.43450E-11
0.274510 0.274510 0.274510 0.271787 0.274510 3.46483E-05 2.33168E-12 0 0 ######### ######### 3.46483E-05 3.46483E-05 1.28395E-08 1.28220E-08 1.74570E-11 0 0 0 0 0* 3.46304E-05 1.78552E-08 1.78975E-08 4.23657E-11
000000000000000000000*0 0 00
000000000000000000000*0 0 00
21.8691 21.8691 21.8691 21.6462 21.8691 0.00276732 1.84883E-10 0 0 0.222911 0.222911 0.00276732 0.00276732 1.02141E-06 1.02000E-06 1.41054E-09 0 0 0 0 0* 0.00276655 7.68495E-07 7.70244E-07 1.74863E-09
10.7601 10.7601 10.7601 5.48037 10.7601 2.33326 3.37002E-06 0 0 5.28172 5.28172 2.33493 2.33493 0.194843 0.193167 0.00167590 0.00167590 0.00167590 0.00167590 0.00201081 0* 2.32650 0.00669863 0.00675983 6.12079E-05
644.090 644.090 644.090 617.425 644.090 1.50784 3.32275E-07 0 0 26.6658 26.6658 1.50785 1.50785 0.00463272 0.00461940 1.33283E-05 ########## 1.33283E-05 1.33283E-05 1.72182E-05 0* 1.50625 0.00158609 0.00158814 2.04791E-06
33.9133 33.9133 33.9133 29.3880 33.9133 0.930559 6.17318E-07 0 0 4.52545 4.52545 0.930671 0.930671 0.0200272 0.0199140 0.000113240 ########## 0.000113240 0.000113240 0.000141097 0* 0.924599 0.00595737 0.00595934 1.97264E-06
9.20747 9.20747 9.20747 7.10772 9.20747 0.755126 9.07478E-07 0 0 2.10022 2.10022 0.755524 0.755524 0.0475491 0.0471503 0.000398833 ########## 0.000398833 0.000398833 0.000470895 0* 0.739316 0.0158078 0.0158090 1.19573E-06
4.81663 4.81663 4.81663 3.52731 4.81663 0.578263 9.34088E-07 0 0 1.29007 1.29007 0.578925 0.578925 0.0627064 0.0620437 0.000662686 ########## 0.000662686 0.000662686 0.000748604 0* 0.546186 0.0320756 0.0320763 6.34848E-07
2.77729 2.77729 2.77729 1.65582 2.77729 0.626202 1.40471E-06 0 0 1.12311 1.12311 0.627718 0.627718 0.120581 0.119064 0.00151656 0.00151656 0.00151656 0.00151656 0.00164387 0* 0.576710 0.0494895 0.0494905 9.11791E-07
4.06029 4.06029 4.06029 2.01098 4.06029 1.39679 4.82172E-06 0 0 2.05950 2.05950 1.40682 1.40682 0.585572 0.575532 0.0100399 0.0100399 0.0100399 0.0100399 0.0101947 0* 1.15570 0.241087 0.241088 1.35151E-06
1.16362 1.16362 1.16362 0.393540 1.16362 0.561703 2.26760E-06 0 0 0.775576 0.775576 0.567433 0.567433 0.308783 0.303051 0.00573178 0.00573178 0.00573178 0.00573178 0.00549511 0* 0.439860 0.121840 0.121841 2.26166E-07
3.60398 3.60398 3.60398 0.881767 3.60398 2.13234 1.52263E-05 0 0 2.84637 2.84637 2.27096 2.27096 3.89088 3.75224 0.138640 0.138640 0.138640 0.138640 0.124164 0* 1.28340 0.848921 0.848921 2.84150E-07
0.687528 0.687528 0.687528 0.0827118 0.687528 0.497444 4.31663E-06 0 0 0.648639 0.648639 0.546793 0.546793 1.25031 1.20096 0.0493532 0.0493532 0.0493532 0.0493532 0.0438224 0* 0.254491 0.242948 0.242948 9.49997E-08
0.190979 0.190979 0.190979 0.0336963 0.190979 0.177988 1.24152E-05 0 0 1.24575 1.24575 1.23583 1.23583 11.2005 10.1427 1.05786 1.05786 1.05786 1.05786 1.08847 0* 0.0899631 0.0879941 0.0880130 1.89169E-05
0.256891 0.256891 0.256891 0.0634871 0.256891 0.213343 2.56238E-05 0 0 3.64062 3.64062 3.62668 3.62668 27.2863 23.8729 3.41336 3.41336 3.41336 3.41336 3.44722 0* 0.0499637 0.163345 0.163354 8.51996E-06
0.0500920 0.0500920 0.0500920 0.0154852 0.0500920 0.0362507 6.95247E-06 0 0 1.28952 1.28952 1.28683 1.28683 7.68985 6.43927 1.25059 1.25059 1.25059 1.25059 1.25492 0* 0.00324578 0.0329974 0.0329980 5.15640E-07
0.204922 0.204922 0.204922 0.0687732 0.204922 0.138512 3.57160E-05 0 0 7.41649 7.41649 7.40605 7.40605 38.9377 31.6701 7.26757 7.26757 7.26757 7.26757 7.28035 0* 0.0101355 0.128339 0.128341 2.39609E-06
######### ######### ######### 0.000287663 ######### 0.00421279 4.82656E-08 0 0 ######### ######### 0.00469815 0.00469815 0.0143197 0.0138343 0.000485405 ########## 0.000485405 0.000485405 0.000489449 0* 0.00109194 0.00312081 0.00312081 4.78093E-10
2.84100 2.84100 2.84100 0.143057 2.84100 2.38608 2.28928E-05 0 0 2.87798 2.87798 2.57463 2.57463 5.96776 5.77918 0.188578 0.188578 0.188578 0.188578 0.180028 0* 0.769279 1.61678 1.61678 1.08729E-07
2.39595 2.39595 2.39595 0.276161 2.39595 2.08375 4.01617E-05 0 0 2.94161 2.94161 2.82160 2.82160 16.6241 15.8863 0.737896 0.737896 0.737896 0.737896 0.821822 0* 0.192534 1.89117 1.89117 2.69639E-08
000000000000000000000*0 0 00
000000000000000000000*0 0 00
1 2 3 4 5 6 7 8 9 52 53 56 57 58 59 61 64 65 66 67 68 70 - BTEX Flash 70 - BTEX HC Liquid 70 - BTEX Liquids 70 - BTEX Water
Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved
VSSL-100 CMPR-100 FAXR-100 Glycol Contactor VSSL-101 Glycol Regenerator Condenser VSSL-101 VSSL-100 Reflux Coil VLVE-100 Rich Flash Cross Exchanger Glycol Regenerator Reboiler Cross Exchanger TEG Makeup Glycol Pump Gas/Glycol HEX - B TEG Recycle -- BTEX Condenser BTEX Condenser MIX-100 BTEX Condenser
CMPR-100 FAXR-100 VSSL-101 Gas/Glycol HEX - A SAT-1 Condenser Glycol Regenerator -- -- VLVE-100 Rich Flash Cross Exchanger Glycol Regenerator Reboiler Glycol Regenerator TEG Makeup Glycol Pump Gas/Glycol HEX - B TEG Recycle Glycol Contactor SAT-1 -- MIX-100 Water Tank MIX-100
72* 461.511 80* 89.8994 79.7391 221.761 200.650 72 88.8232 93.5950 93.5950 218* 277.693 407.991 297.198 297.198 300.221 90* 90 549.005 80* 80 80 80
119 1035 1030 995 1025 0.00405122 0.00405122 1025 119 1010 40* 40 35 0.504051 0.504051 0.00405122 0.00405122 1000* 995 995 1025 0.00405122 0.00405122 0.00405122 0.00405122
17.3318 17.3318 17.3318 16.9571 17.3318 48.7164 135.281 137.747 137.747 141.630 141.630 121.037 36.3588 142.207 142.207 142.207 142.207 142.212 18.0153 40.2557 96.1905 81.4458 18.9165
743.426 743.426 743.426 690.749 743.426 16.8061 0.0186601 0 0 7952.02 7952.02 7915.53 7915.53 8403.62 504.878 7898.74 7898.74 7898.74 7898.74 7898.85 0.495553 11.0421 5.49076 5.74538 0.254621
0.390659 0.390659 0.390659 0.371000 0.390659 0.00314193 1.25627E-06 0 0 0.525774 0.525774 0.509014 0.509014 0.632341 0.126468 0.505873 0.505873 0.505873 0.505873 0.505864 ######### 0.00249820 0.000519882 0.000642474 0.000122591
4.67863 4.67863 4.67863 4.41110 4.67863 0.0574424 3.32408E-05 0 0 14.2688 14.2688 14.0574 14.0574 15.0092 1.00923 14.0000 14* 14 14 14.0003 ######### 0.0409990 0.0159043 0.0164102 0.000505921
-5.88245 -6.41641 -5.42032 -6.68622 -6.68622 -6.82598 -6.82528 -6.82449 72.2106 69.4009 8.80947
1033.80 1033.80 1033.80 1019.16 1033.80 2282.47 3702.36 3790.91 3790.91 3879.06 3879.06 3269.97 793.964 3888.97 3888.97 3888.97 3888.97 3889.17 50.3100 1778.89 5218.70 4237.82 78.1156

| Appendix

APPENDIX B
Engine Specification Sheets
Gas Sampling

SPECSHEET
13L ENGINE
SPECIFICATION
SHEET
FEATURESGENERAL DATA
- High strength alloy steel forged
crankshaft
- Crankshaft gear-driven oil system
with cartridge-type filter
- Cast iron cylinder block with
inspection door per cylinder
- Forged Connecting Rod Aluminum
Alloy Pistons with Gallery Oil Cooling
- Thermostatically-controlled cooling
system with engine integrated oil
cooler
- High efficiency air filter
- 3-Way Catalytic Converter
- CANBUS J1939 Standard Interface
- High Capacity, Gear Driven Oil Pump
- Proven US ECU, fuel system and
engine control
- U.S. EPA-Certified and CARB-
Compliant, Stationary & Mobile
- Oil cooled light alloy pistons
with high performance piston
rings
- Hardened valves and valve
seats
- Valley mounted water cooled
exhaust manifold
- Telematics compatibility
- Advance diagnostics
ENGINE DATA
Model Number
Cylinders
Induction System
Combustion System
Cooling System
Displacement
Compression Ratio
Bore & Stroke
Fuel Type
Rotation
Dry Weight
Turbocharged
9.75:1
13 Litre
6
765 cid (12,500 cc)
5.00 in x 6.50 in
Natural gas/Propane
2,313(1050kg)
KWe values are based on standard assumptions for mechanical and electrical losses. Ratings and performance are
solely for referance only and subject to site conditions and Upstream application and ratings guidelines. Images are
for illustration purposes only. All information is subject to change without notice.
Upstream Data Inc
NATURAL GAS/PROPANE
5702-63 Avenue BAY 5 Lloydminster, AB T9V 3T7
[e-mail] blog.upstreamdata.ca
43.8 in / 1,113 mm
53.1 in
1,350 mm
84.1 in / 2,136 mm
53.1 in
1,350 mm
Water-cooled
Spark-ignited
Anti-clockwiseViewed from flywheel
POWER RATINGS
STANDBY
PRIME
NG
LPG
60hz (1800rpm)
300kWm
181kWm
NG
LPG
402hp
243hp
245kWm 329hp
181kWm 243hp
263kWe
158kWe
211kWe
158kWe
Global Leader in Emission Control Solutions
DCL America Inc. 27603 Commerce Oaks Drive, Oak Ridge North, TX 77385
Toll free:1-877-965-8989 Fax:[phone] Email:[e-mail] www.dcl-inc.com
Confidential
Quote #:
Date:
31014137
12/21/2023
Flaretech
RE: Catalytic Converter
Mr. Kevin Goehl,
I am pleased to provide this quote based on the following information. This quotation is valid
for a period of 90 days. If you have any questions or concerns please feel free to contact
myself or any of my associates at DCL America.
Please note: Our prices are based on today’s precious metal prices. DCL reserves the right to
revise this quote should changes occur in the spot prices of the precious metals used in the
product(s).
Also, this quotation is subject to DCL’s standard terms and conditions of sale attached. Copies
of the limited warranty statement are available from DCL upon request (DCL doc. No. X0000-
0000-K1).
Best Regards,
Jeff Evans
Regional Sales Manager
DCL America Inc.
Cell: 720-668-7725
[e-mail]
Global Leader in Emission Control Solutions
DCL America Inc. 27603 Commerce Oaks Drive, Oak Ridge North, TX 77385
Toll free:1-877-965-8989 Fax:[phone] Email:[e-mail] www.dcl-inc.com
Confidential
Catalytic Converter (Table 1A)
Application Power Generation
Engine Model PSI 13 liter engine
Engine Mechanical Power 329
Fuel Natural Gas (PQNG)
Exhaust Flowrate 1094 lb/hr x 2 = 2188 lb/hr
Exhaust Temperature 1371 deg. F
Catalyst Model DC10
Part Number C3905-LQ-0126-0103-02
Number of Elements 2
Catalyst Code 26/ 300 cpsi
Space Velocity (h-1)63308 h-1
Housing Material 304 Stainless steel
Inlet Connection Special Flange
Outlet Connection Special Flange
Dimensions Per drawing
Backpressure (Catalyst +
Housing)12.3 inches H2O
Pre-Catalyst Emissions NOx 11.50
g/bhp-h CO 12.00
NMNEHC 0.10
CH2O Not provided
Post-Catalyst NOx 0.50
g/bhp-h CO 0.30
NMNEHC 0.01
CH2O 90% Conversion
Limited Warranty (doc. X0000-0000-K2) one year or 8000 hours
operation, whichever first
56100046
1050
1100
451
in mm 5.0 162
in mm 6.5 11170
in3 L 764.9 45
in mm 3.15 -3.37 Min 26.5
in mm 3.5 Max 30.0
in-H2O kPa 29.9 2.1
in-Hg kPa 3.8 1.7
psi kPag 1.0 Idle 1.3 - 2.5
in-H2O kPa 10.8 Rated 3.5 - 5.5
in-H2O kPa 6.8 205
22
psi kPa 1.7 54
Clean Air Filter in-H2O kPa 12.0 320
Dirty Air Filter in-H2O kPa 24.9 Cracking 76
Full Open 88
in mm 0.020 103
110
50
HP kW 7.4 21
ft/min m/s 1949 8
gal/min L/min 159 340
HP kW 39 17
SCFM m3/min 26697 629
°F °C 111 48
RPM
High-Output Standby NG 60Hz NG 50Hz LP 60Hz LP 50Hz
1477 - 1519
70
1830Cooling Fan Speed
Volts
1778 - 1823
1800
m/s
Amps
22194
Bore
Stroke
Displacement
Compression Ratio
Exhaust Manifold Type
Turbo Exhaust Outlet Pipe Size
Maximum Allowable Intake
Restriction
Battery Voltage
Starter Motor Power
Nominal Engine Speed
Mean Piston Speed
Catalyst Dp
Charging Alternator Current
°C
51 - 80
Max Allowable Oil Temperature
12.0
Maximum Allowable Exhaust Back Pressure
Maximum Fuel System Pressure
Maximum Operating pressure to EPR
Minimum Operating pressure to EPR
Minimum Gas Supply Pipe Size5
Maximum Pressure Drop Across CAC
RPM Range (Min-Max) ISO 8528-5 G1
Charging Alternator Voltage
Spark Plug Coil - Primary Resistance
Standard Spark Plug Gap10
Spark Plug Part Number
Performance Data 60Hz3,5
90
Maximum Cooling Air Temp at Radiator 44 Maximum Cooling Air Temp at Radiator °F
37.8
Bosch R66857
3.0
6.2
Ohms 0.59Ω ± 10%
psi kPa 7.3
CAC Rise Above Ambient Specified
Volts
Radiator Weight (Dry)lb
ECU Coolant Temp Warning
kg 705
°C
Coolant Capacity (Radiator only)gal
°C
gal
2.7
°F
qts
°F °C
Coolant Capacity (Engine only)1-1/4" NPT
7.45
1066
Oil Specification SAE 15W-40 Low Ash Gas engine oil
(.25-.5% by wt), API CD/CF or higher
28.0
31.7
127.0 in
Catalyst Inlet Size
28Volts
Total Engine Coolant Flow
Cooling Fan Power11
Cooling Fan Speed 2200
Cooling Fan Air Flow11
qts
psi
165.1
L
psi bar
8238
6.4
30
Flywheel housing
Dry Weight (Fan to Flywheel)
Wet Weight (Fan to Flywheel)
CG From Flywheel Housing Rear Face
Flywheel
in
CG Above Crank Centerline
lb
lb
Engine Oil Capacity8
Moment of Inertia Abount Roll Axis lbf⋅ft2 kg·m2
mm
L
bar
Counter Clockwise
118
Max Bending Moment @ Rear of Block
L
ECU Low Oil Pressure Warning6
lbf⋅ft N⋅m
ECU Low Oil Pressure Shutdown6
Oil Pressure Operating
Range
6.9
0.5
psi bar
12.54
90
15
1.7
Water Cooled
9.75 : 1
80.0 - 85.6
1624Mean Piston Speed
1500RPM
70
9.9
RPM Range (Min-Max) ISO 8528-5 G1
Nominal Engine Speed
ft/min
Charging Alternator Current
600
29 Cooling Fan Power11 HP kW
Charged Cooled Forced Induction
1 - 5 - 3 - 6 - 2 - 4
Rev: 3
General Engine Data5
Inline 4-cycle
6
2313
2423
mm 17.8
Type
Number of cylinders
Aspiration
Firing Order
Rotation Viewed from Flywheel
SAE No. 1
kg
kg
SAE No. 14
756
28 Charging Alternator Voltage
RPM
RPM
RPM
Amps
Cooling Fan Air Flow11 SCFM m3/min
Total Engine Coolant Flow gal/min L/min
13L
[Stoich Turbocharged]
5.8
Thermostat Operating
Temperature Range9
Max External Coolant Friction Head
169
°F 190
°F °C
L
°F
230
RPM
23
5.5
24
Performance Data 50Hz3,5
25
°C
14.3
19 - 36
221
220
°F °CECU Coolant Temp Shutdown
psi bar
HP kWm 335 243
psi bar 231 140
lb/hr kg/hr 122 109
ft3/hr m3/hr 2734 -
gal/hr L/hr -26
lb/(hp-hr)g/(kW-hr)0.364 0.448
°F °C 1177 1260
lb/hr kg/hr 2200 1815
ACFM m3/min 1492 1285
lb/hr kg/hr 2094 1634
ACFM m3/min 472 368
°F °C 279 170
BTU/min kW 41629
BTU/min kW 14217
BTU/min kW 13023
BTU/min kW 1934
BTU/min kW 11374
BTU/min kW 1081
1 7
2
3 8
Standard Sump Capacity.
9
± 2 degrees Celsius.
4 10
± 0.002" or 0.05mm.
5 11
6
12
Fuel Consumption3,4,7,12 3418 97 77 ---
---97 20 75
At 0.5 in-H2O of Package Restriction at 50C Ambient Air
Temperature.
Volume calculated using density of 0.717 kg/m3 for NG, 0.51
kg/L for LPG
636
36.4
208 98
644
634
0.413 252
283 8.0
953
1395
1191
326
682
825
34
163 137
950
924 732
112
1157
Thermal Balance5
Heat Rejection CAC at Rated Power
52570
Combustion Air required (entire engine)
Mechanical Power
Heat Rejected to Cooling Water at Rated Load
575
181
9.6
49.4
16.0
>1400RPM.
2144
0.380 231
52.5 42.3
38
38
140
10.4
Heat Rejection to Exhaust (LHV to 150C)
Engine Radiated Heat
Standby
Power Rating1,2,3,4 Per ISO 3046
MEP (@ rated Load on NG)
BSFC
Turbine Outlet Temperature
Compressor Outlet Temperature2
Total Fuel
Exhaust Flow at Turbine Outlet Conditions (entire
engine)
Standby and overload ratings based on ISO 3046 gross flywheel power. See PSI Energy Technical Spec. 56100019 - Fuel Standard.
257
202 151402300250
651
1226 1000
741
1204
2701
Air Induction System5
5702551
16.3 13.4
27.01855
1257
222 273
NG 60Hz NG 50Hz
9.6
LP 60Hz LP 50Hz
All fuel and thermal calculations unless otherwise noted are done at ISO 3046 rated load using LHV for NG of 48.17 MJ/kg.
17072 300 250
All values in the following section are provided for informational purpose only and are non-binding.
14593
16299 287 229
200
2462 43 19
Technical data based on ISO 3046-1 standards of 77°F(25°C), absolute pressure 14.5Psia(100kPa) and 30% relative humidity.
Production tolerances in engines and installed components can account for power variations of ± 5%. Altitude, temperature and excessive
exhaust and intake restrictions should be applied to power calculations.
153 69 56 84
231 16.0
56100046
1050
1100
451
in mm 5.0 162
in mm 6.5 11170
in3 L 764.9 45
in mm 3.15 -3.37 Min 26.5
in mm 3.5 Max 30.0
in-H2O kPa 29.9 2.1
in-Hg kPa 3.8 1.7
psi kPag 1.0 Idle 1.3 - 2.5
in-H2O kPa 10.8 Rated 3.5 - 5.5
in-H2O kPa 6.8 205
22
psi kPa 1.7 54
Clean Air Filter in-H2O kPa 12.0 320
Dirty Air Filter in-H2O kPa 24.9 Cracking 76
Full Open 88
in mm 0.020 103
110
50
HP kW 7.4 21
ft/min m/s 1949 8
gal/min L/min 159 340
HP kW 39 17
SCFM m3/min 26697 629
°F °C 111 48
RPM
High-Output Standby NG 60Hz NG 50Hz LP 60Hz LP 50Hz
1477 - 1519
70
1830Cooling Fan Speed
Volts
1778 - 1823
1800
m/s
Amps
22194
Bore
Stroke
Displacement
Compression Ratio
Exhaust Manifold Type
Turbo Exhaust Outlet Pipe Size
Maximum Allowable Intake
Restriction
Battery Voltage
Starter Motor Power
Nominal Engine Speed
Mean Piston Speed
Catalyst Dp
Charging Alternator Current
°C
51 - 80
Max Allowable Oil Temperature
12.0
Maximum Allowable Exhaust Back Pressure
Maximum Fuel System Pressure
Maximum Operating pressure to EPR
Minimum Operating pressure to EPR
Minimum Gas Supply Pipe Size5
Maximum Pressure Drop Across CAC
RPM Range (Min-Max) ISO 8528-5 G1
Charging Alternator Voltage
Spark Plug Coil - Primary Resistance
Standard Spark Plug Gap10
Spark Plug Part Number
Performance Data 60Hz3,5
90
Maximum Cooling Air Temp at Radiator 44 Maximum Cooling Air Temp at Radiator °F
37.8
Bosch R66857
3.0
6.2
Ohms 0.59Ω ± 10%
psi kPa 7.3
CAC Rise Above Ambient Specified
Volts
Radiator Weight (Dry)lb
ECU Coolant Temp Warning
kg 705
°C
Coolant Capacity (Radiator only)gal
°C
gal
2.7
°F
qts
°F °C
Coolant Capacity (Engine only)1-1/4" NPT
7.45
1066
Oil Specification SAE 15W-40 Low Ash Gas engine oil
(.25-.5% by wt), API CD/CF or higher
28.0
31.7
127.0 in
Catalyst Inlet Size
28Volts
Total Engine Coolant Flow
Cooling Fan Power11
Cooling Fan Speed 2200
Cooling Fan Air Flow11
qts
psi
165.1
L
psi bar
8238
6.4
30
Flywheel housing
Dry Weight (Fan to Flywheel)
Wet Weight (Fan to Flywheel)
CG From Flywheel Housing Rear Face
Flywheel
in
CG Above Crank Centerline
lb
lb
Engine Oil Capacity8
Moment of Inertia Abount Roll Axis lbf⋅ft2 kg·m2
mm
L
bar
Counter Clockwise
118
Max Bending Moment @ Rear of Block
L
ECU Low Oil Pressure Warning6
lbf⋅ft N⋅m
ECU Low Oil Pressure Shutdown6
Oil Pressure Operating
Range
6.9
0.5
psi bar
12.54
90
15
1.7
Water Cooled
9.75 : 1
80.0 - 85.6
1624Mean Piston Speed
1500RPM
70
9.9
RPM Range (Min-Max) ISO 8528-5 G1
Nominal Engine Speed
ft/min
Charging Alternator Current
600
29 Cooling Fan Power11 HP kW
Charged Cooled Forced Induction
1 - 5 - 3 - 6 - 2 - 4
Rev: 3
General Engine Data5
Inline 4-cycle
6
2313
2423
mm 17.8
Type
Number of cylinders
Aspiration
Firing Order
Rotation Viewed from Flywheel
SAE No. 1
kg
kg
SAE No. 14
756
28 Charging Alternator Voltage
RPM
RPM
RPM
Amps
Cooling Fan Air Flow11 SCFM m3/min
Total Engine Coolant Flow gal/min L/min
13L
[Stoich Turbocharged]
5.8
Thermostat Operating
Temperature Range9
Max External Coolant Friction Head
169
°F 190
°F °C
L
°F
230
RPM
23
5.5
24
Performance Data 50Hz3,5
25
°C
14.3
19 - 36
221
220
°F °CECU Coolant Temp Shutdown
psi bar
HP kWm 314 243
psi bar 217 140
lb/hr kg/hr 114 109
ft3/hr m3/hr 2561 -
gal/hr L/hr -26
lb/(hp-hr)g/(kW-hr)0.365 0.448
°F °C 1166 1260
lb/hr kg/hr 2013 1815
ACFM m3/min 1388 1330
lb/hr kg/hr 1903 1630
ACFM m3/min 429 368
°F °C 258 234
BTU/min kW 36409
BTU/min kW 11943
BTU/min kW 11374
BTU/min kW 1582
BTU/min kW 10293
BTU/min kW 1217
1 7
2
3 8
Standard Sump Capacity.
9
± 2 degrees Celsius.
4 10
± 0.002" or 0.05mm.
5 11
6
12
At 0.5 in-H2O of Package Restriction at 50C Ambient Air
Temperature.
Volume calculated using density of 0.717 kg/m3 for NG, 0.51
kg/L for LPG
LP 50Hz
283
1191 644
84
273
NG 60Hz NG 50Hz
151202
9.6 140
1254 570
977 28
Air Induction System5
0.375 229
39
1184
222
1395 634
630
252
2028 922 863
2152 978 915
1499 42
LP 60Hz
21
748 640
283 126
181
25 28
43300
458 8.0
52123
Power Rating1,2,3,4 Per ISO 3046
MEP (@ rated Load on NG)
BSFC
Turbine Outlet Temperature
329 245 234
189 13.0 14.9
56
Exhaust Flow at Turbine Outlet Conditions (entire
engine)
2269 40
Total Fuel
Mechanical Power
640
140
13.0 12.1
Compressor Outlet Temperature2
Thermal Balance5
Combustion Air required (entire engine)
98
All values in the following section are provided for informational purpose only and are non-binding.
>1400RPM.
210
1405
Heat Rejected to Cooling Water at Rated Load
Heat Rejection CAC at Rated Power
Heat Rejection to Exhaust (LHV to 150C)
Engine Radiated Heat
13643
13706 241 200
240
Technical data based on ISO 3046-1 standards of 77°F(25°C), absolute pressure 14.5Psia(100kPa) and 30% relative humidity.
11539 203
Standby and overload ratings based on ISO 3046 gross flywheel power. See PSI Energy Technical Spec. 56100019 - Fuel Standard.
Production tolerances in engines and installed components can account for power variations of ± 5%. Altitude, temperature and excessive
exhaust and intake restrictions should be applied to power calculations.
All fuel and thermal calculations unless otherwise noted are done at ISO 3046 rated load using LHV for NG of 48.17 MJ/kg.
0.413
682
825
38
741
10.4
112
181
208
38
9.6
49.4
Prime
Fuel Consumption3,4,7,12 2758 78 73 ---
---97 20 75

EXTENDED NATURAL GAS ANALYSIS (*DHA)
MAIN PAGE
PRIMARY DB KEY: NAME/DESCRIP :UNION GOVERNMENT 11-1
LEASE #: WELL HEAD
FIELD/AREA:
PROJECT NO. :202401112 ANALYSIS NO. :01
COMPANY NAME :GREENFLARE INC.ANALYSIS DATE: FEBRUARY 01, 2024 07:55
OFFICE / BRANCH: DENVER, CO SAMPLE DATE : JANUARY 25, 2024 9:25
CUSTOMER REF: TO:
PRODUCER : EFFECTIVE DATE:
***FIELD DATA***
SAMPLE CYCLE: SAMPLE TYPE: SPOT
SAMPLE PRES. : 119 psig PROBE : NO
FLOW PRES. : psig CYLINDER NO. : 1039
LAB PRES: psig SAMPLED BY : GALE MCENDREE
SAMPLE TEMP. : 37 ºf SAMPLING COMPANY: EMPACT
AMBIENT TEMP.: ºf H2S BY STAIN TUBE: ppm mol
H2O BY STAIN TUBE: #/mmcf CO2 BY STAIN TUBE: Mol %
FIELD COMMENTS:
LAB COMMENTS:
GPM @ GPM @
COMPONENT MOLE % MASS % 14.73 14.65
ALCOHOLS 0.0003 0.0011 0.0000 0.0000
HELIUM 0.15 0.03 --- ---
HYDROGEN 0.00 0.00 --- ---
OXYGEN/ARGON 0.02 0.04 --- ---
NITROGEN 1.82 2.94 --- ---
CARBON DIOXIDE 0.57 1.45 --- ---
METHANE 93.6012 86.6303 --- ---
ETHANE 2.6294 4.5613 0.7041 0.7003
PROPANE 0.4868 1.2384 0.1346 0.1339
I-BUTANE 0.1932 0.6478 0.0633 0.0629
N-BUTANE 0.1114 0.3736 0.0352 0.0350
I-PENTANE 0.1312 0.5455 0.0482 0.0480
N-PENTANE 0.0376 0.1565 0.0141 0.0140
HEXANES PLUS 0.2489 1.3855 0.0991 0.0990
TOTALS 100.00000 100.00000 1.0986 1.0931
BTEX COMPONENTS MOLE% WT%
BENZENE 0.0057 0.0257 BTU @ 14.73 14.65
TOLUENE 0.0065 0.0346 LHV NET DRY REAL : 936.0 /scf 930.9 /scf
ETHYLBENZENE 0.0011 0.0068 NET WET REAL : 919.7 /scf 914.6 /scf
XYLENES 0.0045 0.0276 HHV GROSS DRY REAL : 1037.5 /scf 1031.9 /scf
TOTAL BTEX 0.0178 0.0947 GROSS WET REAL : 1019.5 /scf 1013.9 /scf
NET HEATING VALUE (60 °F ideal reaction): 20419.0 Btu/lbm
*(DETAILED HYDROCARBON ANALYSIS/NJ 1993)GROSS HEATING VALUE (60°F ideal reaction): 22637.7 Btu/lbm
Mod ASTM D6730,GPA 2261 & GPA 2286.RELATIVE DENSITY (AIR=1): 0.5977
DENSITY 0.04567 lbm/scf
**(CALC: GPA 2172, GPA 2145 & TP-17 @14.696 & 60 F)COMPRESSIBILITY FACTOR : 0.9978
REGULAR WOBBE INDEX 1336.0
The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion EMPACT Analytical Systems, Inc.
Results of the analysis can be affected by the sampling conditions, therefore, are only warranted through proper lab protocol. EMPACT assumes no responsibility
for interpretation or any consequences from application of the reported information and is the sole liability of the user. The reproduction in any media of this
reported information may not be made, in portion or as a whole, without the written permission of EMPACT Analytical Systems, Inc.
CALCULATED VALUES**
EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150
EXTENDED NATURAL GAS ANALYSIS (*DHA)
GLYCALC INFORMATION
PROJECT NO. :202401112 ANALYSIS NO. :01
COMPANY NAME :GREENFLARE INC.ANALYSIS DATE:FEBRUARY 01, 2024 07:55
ACCOUNT NO. : SAMPLE DATE :JANUARY 25, 2024 9:25
PRODUCER : CYLINDER NO. :1039
LEASE NO. : SAMPLED BY :GALE MCENDREE
NAME/DESCRIP :UNION GOVERNMENT 11-1
WELL HEAD

***FIELD DATA***SAMPLE TEMP. :37
SAMPLE PRES. :119 AMBIENT TEMP.:
H2S BY STAIN TUBE: ppm mol
COMMENTS :SPOT NO PROBE

Componet Mole %Wt %
Helium 0.15 0.03
Hydrogen 0.00 0.00
Carbon Dioxide 0.57 1.45
Nitrogen 1.82 2.94
Methane 93.6012 86.6303
Ethane 2.6294 4.5613
Propane 0.4868 1.2384
Isobutane 0.1932 0.6478
n-Butane 0.1114 0.3736
Isopentane 0.1253 0.5216
n-Pentane 0.0376 0.1565
Cyclopentane 0.0059 0.0239
n-Hexane 0.0186 0.0925
Cyclohexane 0.0143 0.0695
Other Hexanes 0.0832 0.4117
Heptanes 0.0439 0.2528
Methylcyclohexane 0.0222 0.1258
2,2,4 Trimethylpentane 0.0000 0.0000
Benzene 0.0057 0.0257
Toluene 0.0065 0.0346
Ethylbenzene 0.0011 0.0068
Xylenes 0.0045 0.0276
C8+ Heavies 0.0489 0.3385
Subtotal 99.97970 99.95890
Oxygen/Argon 0.02 0.04
Alcohols 0.0003 0.0011
Total 100.00000 100.00000
Total C6+C8+C10+
Calculated Values BTU @ 14.73 Sample Fraction Fraction Fraction
LHV Net Dry Real:936.0 4885.5 5920.4 6999.3 Btu/scf
Net Wet Real:919.7 4800.6 5817.5 6877.6 Btu/scf
HHV Gross Dry Real:1037.5 5253.6 6362.1 7527.0 Btu/scf
Gross Wet Real:1019.5 5162.3 6251.5 7396.1 Btu/scf
Other Calculated Values
Regualr Wobbe Index*1336.0 2851.3 3132.4 3394.4 Btu/scf
Net Heating Value (60 °F ideal reaction):20419.0 19319.9 19523.2 19068.3 Btu/lbm
Gross Heating Value (60°F ideal reaction):22637.7 20776.7 20982.9 20505.4 Btu/lbm
Molar Mass (MW):17.33321 96.412 118.422 141.588 g/mol
Relative Density (AIR=1):0.5977 3.3296 4.0887 4.8889 SG
Density:0.04567 0.25404 0.31205 0.37310 lbm/scf
Compressiblity Factor:0.9978 0.9926 0.9979 0.9994 Z
Liquid Volume real gas @:14.73 17.2759 0.0992 0.0231 0.001 gal/1000 scf
* The Wobbe pressure base in the number considered is based upon the given Pb of the HHV above.
#DIV/0 or 0 (zero) will appear in the Calculated Value Section when there is no C6+, C8+ or C10+ in the sample to calculate these factors.
BDL - Below Detection Limit. The H2S LOS has a detection limit of 0.25 ppm. A _ (an uderscore) indicates there was no tube pulled for H2S.
The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion EMPACT Analytical Systems, Inc.
Results of the analysis can be affected by the sampling conditions, therefore, are only warranted through proper lab protocol. EMPACT assumes no responsibility
for interpretation or any consequences from application of the reported information and is the sole liability of the user. The reproduction in any media of this
reported information may not be made, in portion or as a whole, without the written permission of EMPACT Analytical Systems, Inc.
EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150
EXTENDED NATURAL GAS ANALYSIS (*DHA)
DHA COMPONENT LIST
PRIMARY DB KEY: NAME/DESCRIP :UNION GOVERNMENT 11-1
LEASE #: WELL HEAD
FIELD/AREA:
PROJECT NO. :202401112 ANALYSIS NO. :01
COMPANY NAME :GREENFLARE INC.ANALYSIS DATE: FEBRUARY 01, 2024 07:55
OFFICE / BRANCH: DENVER, CO SAMPLE DATE : JANUARY 25, 2024 9:25
CUSTOMER REF: TO:
PRODUCER : EFFECTIVE DATE:
***FIELD DATA***
SAMPLE CYCLE: SAMPLE TYPE: SPOT
SAMPLE PRES. : 119 psig PROBE : NO
FLOW PRES. : psig CYLINDER NO. : 1039
LAB PRES: psig SAMPLED BY : GALE MCENDREE
SAMPLE TEMP. : 37 ºf SAMPLING COMPANY: EMPACT
AMBIENT TEMP.: ºf H2S BY STAIN TUBE: ppm mol
H2O BY STAIN TUBE: #/mmcf CO2 BY STAIN TUBE: Mol %
FIELD COMMENTS:
LAB COMMENTS:
GPM @ GPM @
COMPONENT PIANO # MOLE % MASS %14.73 14.65
Helium --- 0.15 0.03 --- ---
Oxygen/Argon ---0.02 0.04 --- ---
Nitrogen --- 1.82 2.94 --- ---
Carbon Dioxide --- 0.57 1.45 --- ---
Methane P1 93.6012 86.6303 --- ---
Ethane P2 2.6294 4.5613 0.704 0.700
Propane P3 0.4868 1.2384 0.135 0.134
i-Butane I4 0.1932 0.6478 0.063 0.063
Methanol X1 0.0001 0.0002 0.000 0.000
n-Butane P4 0.1114 0.3736 0.035 0.035
2,2-Dimethylpropane I5 0.0031 0.0129 0.001 0.001
i-Pentane I5 0.1222 0.5087 0.045 0.045
n-Pentane P5 0.0375 0.1561 0.014 0.014
t-Butanol X4 0.0002 0.0009 0.000 0.000
2,2-Dimethylbutane I6 0.0047 0.0234 0.002 0.002
Cyclopentane N5 0.0059 0.0239 0.002 0.002
2,3-Dimethylbutane I6 0.0083 0.0413 0.003 0.003
2-Methylpentane I6 0.0321 0.1596 0.013 0.013
3-Methylpentane I6 0.0205 0.1019 0.008 0.008
UnknownC5s U5 0.0001 0.0004 0.000 0.000
n-Hexane P6 0.0186 0.0925 0.008 0.008
2,2-Dimethylpentane I7 0.0016 0.0092 0.001 0.001
Methylcyclopentane N6 0.0174 0.0845 0.006 0.006
2,4-Dimethylpentane I7 0.0026 0.0151 0.001 0.001
2,2,3-Trimethylbutane I7 0.0005 0.0029 0.000 0.000
Benzene A6 0.0057 0.0257 0.002 0.002
3,3-Dimethylpentane I7 0.0008 0.0046 0.000 0.000
Cyclohexane N6 0.0143 0.0695 0.005 0.005
2-Methylhexane I7 0.0069 0.0399 0.003 0.003
2,3-Dimethylpentane I7 0.0029 0.0168 0.001 0.001
1,1-Dimethylcyclopentane N7 0.0020 0.0113 0.001 0.001
3-Methylhexane I7 0.0097 0.0561 0.004 0.004
EMPACT Analytical Systems, Inc
Page 1
365 S. Main Street, Brighton, CO 80601 303-637-0150
1c,3-Dimethylcyclopentane N7 0.0027 0.0153 0.001 0.001
1t,3-Dimethylcyclopentane N7 0.0024 0.0136 0.001 0.001
3-Ethylpentane I7 0.0005 0.0029 0.000 0.000
1t,2-Dimethylcyclopentane N7 0.0038 0.0215 0.002 0.002
UnknownC6s U6 0.0002 0.0010 0.000 0.000
n-Heptane P7 0.0061 0.0353 0.003 0.003
1c,2-Dimethylcyclopentane N7 0.0004 0.0023 0.000 0.000
Methylcyclohexane N7 0.0222 0.1258 0.009 0.009
2,2-Dimethylhexane I8 0.0013 0.0085 0.001 0.001
1,1,3-Trimethylcyclopentane N7 0.0003 0.0020 0.000 0.000
Ethylcyclopentane N7 0.0007 0.0040 0.000 0.000
2,5-Dimethylhexane I8 0.0010 0.0066 0.001 0.001
2,2,3-Trimethylpentane I8 0.0011 0.0073 0.001 0.001
2,4-Dimethylhexane I8 0.0001 0.0006 0.000 0.000
1c,2t,4-Trimethylcyclopentane N8 0.0009 0.0058 0.000 0.000
3,3-Dimethylhexane I8 0.0003 0.0020 0.000 0.000
2,3,4-Trimethylpentane I8 0.0001 0.0006 0.000 0.000
2,3,3-Trimethylpentane I8 0.0001 0.0006 0.000 0.000
Toluene A7 0.0065 0.0346 0.002 0.002
2,3-Dimethylhexane I8 0.0010 0.0066 0.001 0.001
2-Methyl-3-ethylpentane I8 0.0001 0.0006 0.000 0.000
2-Methylheptane I8 0.0027 0.0178 0.001 0.001
4-Methylheptane I8 0.0013 0.0086 0.001 0.001
3-Methyl-3-ethylpentane I8 0.0002 0.0013 0.000 0.000
3,4-Dimethylhexane I8 0.0001 0.0006 0.000 0.000
1c,2c,4-Trimethylcyclopentane N8 0.0001 0.0006 0.000 0.000
1c,3-Dimethylcyclohexane N8 0.0001 0.0006 0.000 0.000
3-Methylheptane I8 0.0025 0.0165 0.001 0.001
1c,2t,3-Trimethylcyclopentane N8 0.0038 0.0246 0.002 0.002
3-Ethylhexane I8 0.0003 0.0020 0.000 0.000
1t,4-Dimethylcyclohexane N8 0.0015 0.0097 0.001 0.001
1,1-Dimethylcyclohexane N8 0.0006 0.0039 0.000 0.000
2,2,5-Trimethylhexane I9 0.0001 0.0008 0.000 0.000
3c-Ethylmethylcyclopentane N8 0.0002 0.0013 0.000 0.000
3t-Ethylmethylcyclopentane N8 0.0002 0.0013 0.000 0.000
2t-Ethylmethylcyclopentane N8 0.0002 0.0013 0.000 0.000
1,1-Methylethylcyclopentane N8 0.0001 0.0006 0.000 0.000
2,2,4-Trimethylhexane I9 0.0001 0.0008 0.000 0.000
1t,2-Dimethylcyclohexane N8 0.0014 0.0091 0.001 0.001
1t,3-Dimethylcyclohexane N8 0.0001 0.0006 0.000 0.000
n-Octane P8 0.0045 0.0297 0.002 0.002
1c,4-Dimethylcyclohexane N8 0.0009 0.0058 0.000 0.000
i-Propylcyclopentane I8 0.0001 0.0006 0.000 0.000
2,3,5-Trimethylhexane I9 0.0003 0.0022 0.000 0.000
2,2,3,4-Tetramethylpentane I9 0.0001 0.0008 0.000 0.000
2,3,4-Trimethylhexane I9 0.0001 0.0008 0.000 0.000
1c,2-Dimethylcyclohexane N8 0.0001 0.0006 0.000 0.000
2,2-Dimethylheptane I9 0.0005 0.0037 0.000 0.000
1,1,4-Trimethylcyclohexane N9 0.0016 0.0117 0.001 0.001
2,2,3-Trimethylhexane I9 0.0002 0.0015 0.000 0.000
2,4-Dimethylheptane I9 0.0001 0.0008 0.000 0.000
Ethylcyclohexane N8 0.0008 0.0052 0.000 0.000
n-Propylcyclopentane N8 0.0008 0.0052 0.000 0.000
1c,3c,5-Trimethylcyclohexane N9 0.0002 0.0014 0.000 0.000
2,5-Dimethylheptane I9 0.0009 0.0066 0.001 0.001
3,3-Dimethylheptane I9 0.0002 0.0015 0.000 0.000
3,5-Dimethylheptane I9 0.0001 0.0008 0.000 0.000
2,6-Dimethylheptane I9 0.0002 0.0015 0.000 0.000
1,1,3-Trimethylcyclohexane N9 0.0001 0.0008 0.000 0.000
Ethylbenzene I8 0.0011 0.0068 0.000 0.000
1c,2t,4t-Trimethylcyclohexane N9 0.0001 0.0008 0.000 0.000
EMPACT Analytical Systems, Inc
Page 2
365 S. Main Street, Brighton, CO 80601 303-637-0150
2,3-Dimethylheptane I9 0.0002 0.0015 0.000 0.000
1,3-Dimethylbenzene (m-Xylene) A8 0.0029 0.0178 0.001 0.001
1,4-Dimethylbenzene (p-Xylene) A8 0.0007 0.0043 0.000 0.000
3,4-Dimethylheptane I9 0.0001 0.0008 0.000 0.000
3,4-Dimethylheptane (2) I9 0.0002 0.0015 0.000 0.000
4-Ethylheptane I9 0.0002 0.0015 0.000 0.000
4-Methyloctane I9 0.0009 0.0066 0.001 0.001
2-Methyloctane I9 0.0011 0.0081 0.001 0.001
1c,2t,3-Trimethylcyclohexane N9 0.0001 0.0008 0.000 0.000
3-Ethylheptane I9 0.0001 0.0008 0.000 0.000
3-Methyloctane I9 0.0002 0.0015 0.000 0.000
1c,2t,4c-Trimethylcyclohexane I9 0.0013 0.0095 0.001 0.001
1,1,2-Trimethylcyclohexane N9 0.0001 0.0008 0.000 0.000
3,3-Diethylpentane I9 0.0002 0.0015 0.000 0.000
1,2-Dimethylbenzene (o-Xylene) A8 0.0009 0.0055 0.000 0.000
i-Butylcyclopentane N9 0.0007 0.0051 0.000 0.000
n-Nonane P9 0.0037 0.0274 0.002 0.002
1,1-Methylethylcyclohexane N9 0.0004 0.0029 0.000 0.000
i-Propylbenzene A9 0.0002 0.0014 0.000 0.000
i-Propylcyclohexane N9 0.0001 0.0008 0.000 0.000
2,2-Dimethyloctane I10 0.0001 0.0008 0.000 0.000
2,4-Dimethyloctane I10 0.0002 0.0016 0.000 0.000
2,6-Dimethyloctane I10 0.0001 0.0008 0.000 0.000
2,5-Dimethyloctane I10 0.0001 0.0008 0.000 0.000
n-Butylcyclopentane N9 0.0006 0.0044 0.000 0.000
3,3-Dimethyloctane I10 0.0002 0.0016 0.000 0.000
n-Propylbenzene A9 0.0004 0.0028 0.000 0.000
3,6-Dimethyloctane I10 0.0002 0.0016 0.000 0.000
3-Methyl-5-ethylheptane I10 0.0001 0.0008 0.000 0.000
1,3-Methylethylbenzene A9 0.0004 0.0028 0.000 0.000
1,4-Methylethylbenzene A9 0.0001 0.0007 0.000 0.000
1,3,5-Trimethylbenzene A9 0.0002 0.0014 0.000 0.000
2-Methylnonane I10 0.0001 0.0008 0.000 0.000
t-Butylbenzene A10 0.0002 0.0016 0.000 0.000
i-Butylcyclohexane N10 0.0001 0.0008 0.000 0.000
UnknownC9s U9 0.0012 0.0089 0.001 0.001
1,2,3-Trimethylbenzene A9 0.0001 0.0007 0.000 0.000
UnknownC10s U10 0.0012 0.0099 0.001 0.001
TOTAL 100.00000 100.00000 1.0986 1.0931
BTEX COMPONENTS MOLE%WT%BTU @ 14.73 14.65
BENZENE 0.0057 0.0257 LHV NET DRY REAL : 936.0 /scf 930.9 /scf
TOLUENE 0.0065 0.0346 NET WET REAL : 919.7 /scf 914.6 /scf
ETHYLBENZENE 0.0011 0.0068 HHV GROSS DRY REAL : 1037.5 /scf 1031.9 /scf
XYLENES 0.0045 0.0276 GROSS WET REAL : 1019.5 /scf 1013.9 /scf
TOTAL BTEX 0.0178 0.0947 NET HEATING VALUE (60 °F ideal reaction): 20419.0 Btu/lbm
GROSS HEATING VALUE (60°F ideal reaction): 22637.7 Btu/lbm
*(DETAILED HYDROCARBON ANALYSIS/NJ 1993)RELATIVE DENSITY (AIR=1): 0.5977
Mod ASTM D6730,GPA 2261 & GPA 2286.DENSITY 0.04567 lb/scf
COMPRESSIBILITY FACTOR : 0.9978
**(CALC: GPA 2172, GPA 2145 & TP-17 @14.696 & 60 F)REGULAR WOBBE INDEX 1336.0
C6+ Fraction of DHA Gas Analysis @60⁰F, 14.696 psia
Net Dry Ideal BTU 4838.3 /scf Relative Density - SG (Air=1) 3.3296 C6+factors
Gross Dry Ideal BTU 5202.8 /scf Z Compressiblity Factor 0.99262 0.99167
Net Dry Ideal BTU 19319.9 /lb Density Factor 254.043 lbm/1000 ft3
Gross Dry Ideal BTU 20776.7 /lb Molar Mass or MW 96.412 g/mol
Volume Liquid Ideal gas 0.099 scf/gal 23.4
This hexanes plus fraction may be applied in place of published C6+ factors.  The Z & GPM need additional calc for C6+ factors.
#DIV/0 or 0 (zero) will appear in this section when there is no hexanes plus in the sample to calculate C6+ factors.
The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion EMPACT Analytical Systems, Inc.
Results of the analysis can be affected by the sampling conditions, therefore, are only warranted through proper lab protocol. EMPACT assumes no responsibility
for interpretation or any consequences from application of the reported information and is the sole liability of the user. The reproduction in any media of this
reported information may not be made, in portion or as a whole, without the written permission of EMPACT Analytical Systems, Inc.
CALCULATED VALUES**
EMPACT Analytical Systems, Inc
Page 3
365 S. Main Street, Brighton, CO 80601 303-637-0150

| Appendix

APPENDIX C
Area Map

| Appendix

APPENDIX D
Forms

Form 1 Date __________________
Notice of Intent (NOI) Application Checklist
Company __________________
Utah Division of Air Quality
New Source Review Section
Source Identification Information [R307-401-5]
1. Company name, mailing address, physical address and telephone number 
2. Company contact (Name, mailing address, and telephone number)
3.Name and contact of person submitting NOI application (if different than 2)
4.Source Universal Transverse Mercator (UTM) coordinates 
5. Source Standard Industrial Classification (SIC) code 
6.Area designation (attainment, maintenance, or nonattainment)
7.Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.)
8.Source size determination (Major, Minor, PSD)
9. Current Approval Order(s) and/or Title V Permit numbers 
NOI Application Information: [R307-401]










N/A 
N/A 
A.Air quality analysis (air model, met data, background data, source impact analysis) N/A 
1.Detailed description of the project and source process
2.Discussion of fuels, raw materials, and products consumed/produced
3.Description of equipment used in the process and operating schedule
4.Description of changes to the process, production rates, etc.
5.Site plan of source with building dimensions, stack parameters, etc.
6.Best Available Control Technology (BACT) Analysis [R307-401-8]
A.BACT analysis for all new and modified equipment
7.Emissions Related Information: [R307-401-2(b)]
A.Emission calculations for each new/modified unit and site-wide
(Include PM10, PM2.5, NOx, SO2, CO, VOCs, HAPs, and GHGs)
B.References/assumptions, SDS, for each calculation and pollutant
C.All speciated HAP emissions (list in lbs/hr)
8.Emissions Impact Analysis – Approved Modeling Protocol [R307-410]
A.Composition and physical characteristics of effluent
(emission rates, temperature, volume, pollutant types and concentrations)
9.Nonattainment/Maintenance Areas – Major NSR/Minor (offsetting only) [R307-403]
A.NAAQS demonstration, Lowest Achievable Emission Rate, Offset requirements
B.Alternative site analysis, Major source ownership compliance certification
10.Major Sources in Attainment or Unclassified Areas (PSD) [R307-405, R307-406]
B.Visibility impact analysis, Class I area impact
11.Signature on Application
N/A 
Note: The Division of Air Quality will not accept documents containing confidential information or data.
Documents containing confidential information will be returned to the Source submitting the application.
Not Applicable
Page 1 of 1
Form 3 Company____________________
Process Information Site________________________
Utah Division of Air Quality
New Source Review Section
Process Information - For New Permit ONLY
1.Name of process:2.End product of this process:
3.Process Description*:
Operating Data
4.Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
5.Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall _______
6.Maximum Hourly production (indicate units.):
_____________
7.Maximum annual production (indicate units):
135_____________
8.Type of operation:
Continuous Batch Intermittent
9.If batch, indicate minutes per cycle ________
Minutes between cycles ________
10. Materials and quantities used in process.*
Material Maximum Annual Quantity (indicate units)
11.Process-Emitting Units with pollution control equipment*
Emitting Unit(s) Capacity(s) Manufacture Date(s)
*If additional space is required, please create a spreadsheet or Word processing document and attach to form.
SCF/HR MMSCF/YR
Page 1 of 1
Company___________________________
Site _____________________________
Form 5
Emissions Information
Criteria/GHGs/ HAP’s
Utah Division of Air Quality
New Source Review Section
Potential to Emit* Criteria Pollutants & GHGs
Criteria Pollutants Permitted Emissions
(tons/yr)
Emissions Increases
(tons/yr)
Proposed Emissions
(tons/yr)
PM10 Total
PM10 Fugitive
PM2.5
NOx
SO2
CO
VOC
VOC Fugitive
NH3
Greenhouse Gases CO2e CO2e CO2e
CO2
CH4
N2O
HFCs
PFCs
SF6
Total CO2e
*Potential to emit to include pollution control equipment as defined by R307-401-2.
Hazardous Air Pollutants** (**Defined in Section 112(b) of the Clean Air Act )
Hazardous Air
Pollutant***
Permitted Emissions
(tons/yr)
Emission Increase
(tons/yr)
Proposed
Emission (tons/yr)
Emission Increase
(lbs/hr)
Total HAP
*** Use additional sheets for pollutants if needed
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1.Manufacturer: _PSI_________________________
Model no.:__13L______________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
maximum average
__24__ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
Kw 3.Manufacturer's rated output at baseload, ISO 295 hp
or Proposed site operating range _____________________________ hp or Kw
Gas Firing
4. Are you operating site equipment on pipeline quality natural gas: □ Yes □ No
5. Are you on an interruptible gas supply:
□Yes □ No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
___________________2734_______ MMSCF/Year
7. Maximum firing rate:
________________2,925,220___ BTU/hr
8. Average firing rate:
__________________2,925,220____ BTU/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 
7
52 52
7
24
220
Running Foxes Petroleum, Inc.
____________Grand Central Facility
2/29/2024
295 (each)
(each)
220
(each)
x
x
GEN 1 - GEN 11
N/Ax
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
□Emergency Generator
□Driving pump/compressor
□Exhaust heat recovery
□Other (specify) ________________________
18. Cycle
□Simple cycle
□Regenerative cycle
□Cogeneration
□Combined cycle
Emissions Data
19.Manufacturer’s Emissions in grams per hour (gr/hp-hr): _0.5__ NOX __0.5__ CO _0.05__ VOC
_0.0205__ 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 □ Other (specify)____________
□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.
x x
______ Base load ______ Peaking
x
100%
x NSCR
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME LB/HR TONS/YR ZONE
EAST
(METERS)
NORTH
(METERS)DIA (FT)VELO
(FPS)TEMP (oF)
VOC 0.02 0.11
BENZENE <0.01 <0.01
HAPs <0.01 0.01
VOC 0.27 1.17
BENZENE 0.00 0.01
HAPs 0.01 0.05
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
N/A N/A N/A
N/A N/A N/A
FUGITIVES Fugitive Emissions:
Equipment Leaks 12S 649435 4326443 3
PNEU Pneumatic Devices 12S 649435 4326443 3
GEN4 PSI 13L Generator
GEN5 PSI 13L Generator
157.5 1371
157.5 137112S 649435 4326443 10.5 0.5
157.5 1371
12S 649435 4326443 10.5 0.5 157.5 1371
GEN7 PSI 13L Generator
GEN6 PSI 13L Generator
10.5 0.5
10.5 0.5
12S 649435 4326443 10.5 0.5
12S 649435 4326443 10.5 0.5
1371157.50.510.5
157.5 1371
GEN3 PSI 13L Generator 12S 649435 4326443
432644364943512SPSI 13L GeneratorGEN1
GEN2 PSI 13L Generator 12S 649435 4326443
157.5 1371
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES
UTM COORDINATES OF
EMISSION PT.
AIR CONTAMINANT
EMISSION RATE
CHEMICAL
COMPOSITION OF
TOTAL STREAM
EMISSION POINT EXIT DATAHEIGHT
ABOVE
STRUCT
(FT)
HEIGHT
ABOVE
GROUND
(FT)
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 <0.01
H2S <0.01 <0.01
HCHO 0.01 0.03
HAPs 0.09 0.42
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
VOC 0.07 0.28
BENZENE 0.01 0.01
H2S <0.01 <0.01
HAPs 0.03 0.06
VOC 0.07 0.28
BENZENE 0.30 <0.01
H2S <0.01 <0.01
HAPs 1.33 <0.01
TL-NGL NGL Loading
VOC 0.07 0.28 12S 649435 4326443 3 N/A N/A N/A
VOC 0.07 0.28
NOx 7.48 32.76
CO 7.80 34.19
BENZENE <0.01 0.02
HCHO <0.01 <0.01
HAPs 0.02 0.10
PM10 0.03 0.12
PM2.5 0.03 0.12
SO2 <0.01 0.01
GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL: 4,300 ft
N/A N/A
20 N/A N/A N/A
12 0.3 TBD 60012S 649435 4326443
WTK1 Water Tank (300
BBL)12S 649435 4326443
157.5 1371GEN11 PSI 13L Generator 12S 649435
GEN10 PSI 13L Generator
4326443 10.5 0.5
12S 649435 4326443 3 N/A
1371
12S 649435 4326443 10.5 0.5 157.5 1371
12S 649435 4326443 10.5 0.5 157.5
12S 649435 4326443 10.5 0.5 157.5 1371GEN8 PSI 13L Generator
GEN9 PSI 13L Generator
TL-W Water Loading
DEHYRB
TEG Reboiler (0.50
MMBTU/Hr +
DEHY)
Utah Division of Air Quality
New Source Review Section Company _______________________
Site/Source _____________________
Form 19 Date ___________________________
Natural Gas Boilers and Liquid Heaters
Boiler Information
1.Boiler Manufacturer: ______________________________________________________________________
3.Serial Number: __________________________
4. Boiler Rating: _________________(10
6 Btu per Hour)
5.
6. Use: □ steam: psig □hot water
□Natural Gas □ LPG □ Butane □ Methanol
□Process Gas - H2S content in process gas __________ grain/100cu.ft.
7. Fuels:
□Fuel Oil - specify grade:□Other, specify: ______________________________________
Sulfur content % by weight Days per year during which unit is oil fired: ________________
Backup
Fuel □Diesel □ Natural Gas □ LPG □ Butane □ Methanol □ Other _________________
8. Is unit used to incinerate waste gas liquid stream? □ yes □ no
(Submit drawing of method of waste stream introduction to burners)
Gas Burner Information
9. Gas Burner Manufacturer: _____________________________________________________________________
10. No. of Burners: ______________________________11. Minimum rating per burner: _____________ cu. ft/hr
12. Average Load: _______%13. Maximum rating per burner: ____________ cu. ft/hr
14. Performance Guarantee (ppm dry corrected to 3% Oxygen):
NOx: ______________ CO: ______________ Hydrocarbons: ______________
□Manual □Automatic on-off15. Gas burner mode of control:
□Automatic hi-low □Automatic full modulation
Oil Burner Information
16. Oil burner manufacturer:
17. Model: _______________ number of burners: _________________ Size number: _______________
18. Minimum rating per burner: _____________ gal/hr 19. Maximum rating per burner: ___________ gal/hr
Page 1 of 3
Running Foxes Petroleum, Inc.
Grand Central Facility
2/29/2024
x
Operating Schedule: _______ hours per day __________ days per week ___________ weeks per year52
0
0.5
x
x
2.TBDModel Number: __________________________
triethylene glycolother hot liquid: _______________________________
N/A
TBD
1
100
482
482
N/A
TBD TBD TBD
TBD
Page 2 of 3
Form 11 - Natural Gas Boiler and Liquid Heater
(Continued)
Modifications for Emissions Reduction
20. Type of modification: □ Low NOX Burner □ Flue Gas Recirculation (FGR)
□Oxygen Trim □Other (specify) ______________________________________
For Low-NOX Burners
21. Burner Type: □ Staged air □ Staged fuel □ Internal flue gas recirculation
□Ceramic □Other (specify): ___________________________________________________
22. Manufacturer and Model Number: _______________________________________________________________
23. Rating: ______________________ 10
6 BTU/HR 24. Combustion air blower horsepower: ____________
For Flue Gas Recirculation (FGR)
25. Type: □ Induced □ Forced Recirculation fan horsepower: ______________________________________
26. FGR capacity at full load: scfm %FGR
27. FGR gas temperature or load at which FGR commences: OF % load
28. Where is recirculation flue gas reintroduced? _______________________________________________________
For Oxygen Trim Systems
29. Manufacturer and Model Number: ________________________________________________________________
30. Recorder: □ yes □ no Describe: ____________________________________________________________
Stack or Vent Data
31. Inside stack diameter or dimensions ____0.3 ft____
Stack height above the ground _____12 ft_______
Stack height above the building _______________
32. Gas exit temperature: ____600____ OF
33. Stack serves: □ this equipment only, □ other equipment (submit type and rating of all other equipment
exhausted through this stack or vent)
34. Stack flow rate: ______TBD_______ acfm Vertically restricted? □ Yes □No
Emissions Calculations (PTE)
35. Calculated emissions for this device
PM2.5 ___0.01_____Lbs/hr____0.04__ Tons/yr
SOx ___0.0003____Lbs/hr____0.001__ Tons/yr
VOC ___0.42____Lbs/hr ___1.88____Tons/yr
CH4 ___________Tons/yr
PM10 ____0.01____Lbs/hr____0.04__ Tons/yr
NOx ___0.12____Lbs/hr _____0.51___Tons/yr
CO _____0.4____Lbs/hr _____1.74__Tons/yr
CO2 ___________ Tons/yr
N2O ___________Tons/yr
HAPs_0.02____ Lbs/hr (speciate)__0.01____Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
x
x
N/Ax
Page 1 of 2
New Source Review Section
Date: _____________________________
Utah Division of Air Quality
Company: _________________________
Site/Source:________________________
Form 20
rganic Liquid Storage Tank O
Equipment
1. Tank manufacturer: ___________________________2. Identification number: _____________________
3. Installation date: ______________________________4. Volume: __________________________ gallons
5. Inside tank diameter: ______________________ feet 6. Tank height: ________________________ feet
7. True vapor pressure of liquid: _______________ psia 8.Reid vapor pressure of liquid: _______4.49__ psi
9. Outside color of tank: __________________________10.Maximum storage temperature: _____65__ OF
11.Average throughput: _____8560___ gallons per year 12.Turnovers/yearly 0.84 Monthly 0.07 Weekly 0.02
13.Average liquid height (feet): ____7.5______________ Yes No Number ______14. Access hatch: □ □
15. T
a. P
r
b. S
Type: ________________________________
16. D
ll Yes No Number_____
ll
ak
ype of Seals:
rimary seals:
□Mechanical shoe
□Resilient filled
□Liquid filled
□Vapor mounted
□Liquid mounted
□ Flexible wipe
econdary seal:
eck Fittings:
□Gauge float we □
Gauge hatch/
sample we □ Yes □ No Number_____
Roof drains □ Yes □ No Number_____
Rim vents □ Yes □ No Number_____
Vacuum bre □ Yes □ No Number_____
Roof leg □ Yes □ No Number_____
Ladder well □ Yes □ No Number_____
Column well □ Yes □ No Number_____
Other:_________________________________
17. S 18. T
______________________________________
hell Characteristics:
Condition: _________________________________
Breather Vent Settings: __0.03 psi______________
Tank Construction: ___Vertical Fixed Roof________
Roof Type: __Cone___________________________
Deck Construction: ___________________________
Deck Fitting Category: ________________________
ype of Construction:
□Vertical Fixed Roof
□Horizontal Fixed Roof
□Internal Floating Roof
□External Floating Roof
□Other (please specify)
19. Additional Controls:
Gas Blanket Venting Carbon Adsorption Thermal Oxidation Other:_______________□□ □□□
20.Single Liquid Information
Liquid Name: __________________________________
CAS Number: __________________________________
Avg. Temperature: ______________________________
Vapor Pressure: ________________________________
Liquid Molecular Weight: ________________________ Liquid Molecular Weight: ________________________
Liquid Name: __________________________________
CAS Number: __________________________________
Avg. Temperature: ______________________________
Vapor Pressure: ________________________________
Running Foxes Petroleum, Inc.
Grand Central Facility
2/29/2024
TBD 12,600
1512
4.95
Tan
xAverage
x
x
x
TBD WTK1
N/A
Page 2 of 2
Form 20 - Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name: ________________________________
Percent of Total Liquid Weight: ______100%__________
Molecular Weight: _____82 lb/lbmol__________________
Avg. Liquid Temperature: ________65 F
Vapor Pressure: ____5.44 psia_____________________ Vapor Pressure: ________________________________
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Emissions Calculations (PTE)
22.Calculated emissions for this device:
VOC ___0.41__Lbs/hr_0.98_ Tons/yr
HAPs___0.03___Lbs/hr (speciate)_0.06__Tons/yr (speciate)
Submit calculations as an appendix. Provide Material Safety Data Sheets for products being stored.
Instructions
Note: 1. Submit this form in conjunction with Form 1 and Form 2.
2. or questions in filling out this form.
Ask to speak with a New Source Review engineer. We will be glad to help!
on number that will appear on the tank.
s or barrels.
r in feet.
liquid (psi).
ach during storage (degrees Fahrenheit).
emptied and refilled per year, month or week.
ss hatches and the number.
17. Specify condition of the tank, also include the following:
d roof tanks
el construction sizes and seam length
olled, or detail
22.ations for all criteria pollutants and HAPs. Use AP-42 or manufacturers’ data to complete your
calculations.
ENERIC\Forms 2010\Form20 Organic Liquid Storage Tanks.doc
Revised 12/20/10
Call the Division of Air Quality (DAQ) at [phone] if you have problems
1. Indicate the tank manufacturer's name.
2. Supply the equipment identificati
3. Indicate the date of installation.
4. Indicate the capacity of the tank in gallon
5. Specify the inside tank diamete
6. Specify the tank height in feet.
7.Indicate the true vapor pressure of the liquid (psia).
8. Indicate the Reid vapor pressure of the
9. Indicate the outside color of the tank.
10. Supply the highest temperature the liquid will re
11. Indicate average annual throughput (gallons).
12. Specify how many times the tank will be
13. Specify the average liquid height (feet).
14. Indicate whether or not the tank has acce
15. Indicate what type of seals the tank has.
16.Indicate what types of deck fittings are installed.
Breather vent settings in (psig) for fixe
Tank construction, welded or riveted
Roof type; pontoon, double deck, or self-supporting roof
Deck construction; bolted or welded, sheet or pan
Deck fitting category; typical, contr
18. Indicate the type of tank construction.
19.Indicate other types of additional controls which will be used.
20. Provide information on liquid being stored, add additional sheets as necessary.
21. Provide information on chemicals being stored, add additional sheets as necessary.
Supply calcul
f:\aq\ENGINEER\G
Produced Water
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:2. End product of this process:
3.
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
Are there multiple exhausts: □ Yes □No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□Batch
□Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
11. Materials used in process
Raw Materials Principal Use Amounts
(Specify Units)
Page 1 of 3
Running Foxes Petroleum, Inc.
Grand Central Facility
2/29/2024
Natural Gas Dehydration Natural Gas
Still column, glycol
regenerator, flash tanPrimary process equipment: ______________k Manufacturer:__________________________________TBD
TBD
TBD
24
7
52
25
25
25
25
N/A
N/A
4.Method of exhaust ventilation:
□Stack □ Window fan □ Roof vent □x Other, describe __________________
x
Well gas Remove water
135 MMSCF/YR
142 MMSCF/YR
744
x
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item Primary Collector Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□Yes □No
If yes, identify sources:
16.□ Round, top inside diameter dimension
_________
□Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________
oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr_______ _ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
BTEX Condenser
TBD
TBD
TBD
TBD
Hydrocarbons
N/A
N/A
N/A
N/A
Reboiler
TBD
TBD
TBD
TBD
Hydrocarbons
41.7 lb/hr
N/A
96% DRE
N/A
0.42 1.87___
4.67
0.100.02
0.010.01
0.07
0.36
0.29
0.03 0.03
23.10
(reboiler)
DEHYRB 12
x
x
TBD
600
x
TBD TBD
1.56
N/A N/A
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:2. End product of this process:
3. Primary process equipment: _______________ Manufacturer:__________________________________
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
4. Method of exhaust ventilation:
□Stack □ Window fan □ Roof vent □ Other, describe _______________________
Are there multiple exhausts: □ Yes □No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□Batch
□Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
11. Materials used in process
Raw Materials Principal Use Amounts
(Specify Units)
Page 1 of 3
Running Foxes Petroleum, Inc.
Grand Central Facility
2/29/2024
Fugitive Emissions N/A
N/A
x fugitive release point
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
N/A
x
N/A N/A
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item Primary Collector Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□Yes □No
If yes, identify sources:
16.□ Round, top inside diameter dimension
_________
□Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________
oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr___________ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
0.05 0.23
.002 0.12
N/A - fugitive release point
N/A
1.940.04
0 0 0 0
0 0 0 0
0 0
0
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:2. End product of this process:
3. Primary process equipment: _______________ Manufacturer:__________________________________
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
4. Method of exhaust ventilation:
□Stack □ Window fan □ Roof vent □ Other, describe _______________________
Are there multiple exhausts: □ Yes □ No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□Batch
□Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
11. Materials used in process
Raw Materials Principal Use Amounts
(Specify Units)
Page 1 of 3
Running Foxes Petroleum, Inc
Grand Central Facility
2/29/2024
Water Truck Loading N/A
fugitive release pointx
N/A
N/A
N/A
1
7
52
TBD
TBD
TBD
TBD
22.23 22.23 200 BBL/YR
x
N/A
Truck Loading
N/A
N/A
N/AN/A
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item Primary Collector Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□Yes □No
If yes, identify sources:
16.□ Round, top inside diameter dimension
_________
□Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________
oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr___________ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
20.48 0.02
1.33 0.001
< 0.001 < 0.001
N/A
N/A - fugitive release point
0 0 0 0
0 000
0 0
0
Utah Division of Air Quality Company____________________________
New Source Review Section Site/Source__________________________
Date____________________
Form 2
Process Information
Process Data
1. Name of process:2. End product of this process:
3. Primary process equipment: _______________ Manufacturer:__________________________________
Make or model: _________________________ Identification #: ________________________________
Capacity of equipment (lbs/hr): Year installed:__________________________________
Rated _____________ Max.____________
(Add additional sheets as needed)
4. Method of exhaust ventilation:
□Stack □ Window fan □ Roof vent □ Other, describe _______________________
Are there multiple exhausts: □ Yes □No
Operating Data
5. Maximum operating schedule:
__________ hrs/day
__________days/week
__________weeks/year
6. Percent annual production by quarter:
Winter ________ Spring _______
Summer ________ Fall ________
7. Hourly production rates (lbs.):
Average ________ Maximum ________
8. Maximum annual production (indicate units):
__________________
Projected percent annual increase in production:
__________________
9. Type of operation: □ Continuous
□Batch
□Intermittent
10. If batch, indicate minutes per cycle ________
Minutes between cycles ________
11. Materials used in process
Raw Materials Principal Use Amounts
(Specify Units)
Page 1 of 3
Running Foxes Petroleum, Inc
Grand Central Facility
2/29/2024
NGL Truck Loading N/A
Truck Loading N/A
N/A
N/A
N/A
N/A
fugitive release pointx
1
7
52
TBD
TBD
TBD
TBD
5 GAL/YR
3.43
x
N/A N/A N/A
3.43
Page 2 of 3
Process
Form 2 (Continued)
12. Control equipment (attach additional pages if necessary)
Item Primary Collector Secondary Collector
a. Type
b. Manufacturer
c. Model
d. Year installed
e. Serial or ID#
f. Pollutant controlled
g. Controlled pollutant emission
rate (if known)
h. Pressure drop across control
device
i. Design efficiency
j. Operating efficiency
Stack Data
(attach additional pages if necessary)
13. Stack identification:14. Height: Above roof ________ft
Above ground ________ft
15. Are other sources vented to this stack:
□Yes □No
If yes, identify sources:
16.□ Round, top inside diameter dimension
_________
□Rectangular, top inside dimensions
length ________ x width ________
17. Exit gas: Temperature ________
oF Volume ________ acfm Velocity ________ ft/min
18. Continuous monitoring equipment: □ yes □ no
If yes, indicate: Type ____________________ Manufacturer _________________________________
Make or Model ____________ Pollutant(s) monitored __________________________
Emissions Calculations (PTE)
19. Calculated emissions for this device
PM10 ___________ Lbs/hr___________ Tons/yr PM2.5 ____________ Lbs/hr ___________ Tons/yr
NOx____________ Lbs/hr___________ Tons/yr SOx _____________ Lbs/hr___________ Tons/yr
CO ____________ Lbs/hr___________ Tons/yr VOC _____________ Lbs/hr___________ Tons/yr
CO2 ___________ Tons/yr CH4 _____________ Tons/yr
N2O ____________Tons/yr
HAPs_________ Lb s/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
N/A - fugitive release point
N/A
0.013.42
0 0 0 0
0 0 0 0
0 0
0
0
0 0
0
2/29/24, 8:33 AM State of Utah Mail - Fwd: NOI Submittal
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-f:1792170459848260694&simpl=msg-f:1792170459848260694 1/2
Dungan Adams <[e-mail]>
Fwd: NOI Submittal
1 message
Alan Humpherys <[e-mail]>Wed, Feb 28, 2024 at 12:01 PM
To: Dungan Adams <[e-mail]>
Dungan,
Can you please process this NOI. The source says it is a tank battery; however, it isn't one. Please let me know what
questions you have.
Site ID: 16201
Peer: Christine
Thanks,
Alan
---------- Forwarded message ---------
From: <[e-mail]>
Date: Mon, Feb 26, 2024 at 7:45 AM
Subject: NOI Submittal
To: <[e-mail]>
Recipient Data:
Time Finished: 2024-02-26 07:44:30 MST
IP: 70.114.238.122
ResponseID: R_5TZ0v63gmza5vih
Link to View Results: Click Here
URL to View Results: https://utahgov.iad1.qualtrics.com/apps/single-response-reports/reports/
YlXEoEehz3370CBvIgUcwfFvUlvS0pY85ZOf6sA9Y1BKKvtgOJlcJ6w3xWHLhEMun%
2EqEmSqNlYrn1XZMnJ7DcAYeuCiPqL1t%2EG0RBw7axOiMh4V6TuJNZRL1YKqa2mlr9jZghASZyutZgpEC08yveltTdt1
OU9yTIrk07ghzobxCLWSVBxIZBy0lM9DWZEGGIsMI9mnTyGRLWedqvEUZ3Gfv01mvHo9vpegnpnkFRHvXt8fmvEVE-
T2ziKAqVwtSNZ6w4TYCPILRpAvzbo3mMMPisjGb9W4oqq9k2Nl%2E0Lld7qmL3B8TBQ4ZC2mj9AVgF4ES
KHpUlV1cG75KXBoHIQ
Response Summary:
Company Name:
Running Foxes Petroleum, Inc.
Site Name:
Grand Central Facility
Contact Name:
Kat Galloway
Contact Email Address:
[e-mail]
Please Attach a copy of your complete application here
https://utahgov.co1.qualtrics.com/WRQualtricsControlPanel/File.php?F=F_3r1WVo9zLGnrCgU
Please sign acknowledging you are the responsible party to provide DAQ with this NOI.
2/29/24, 8:33 AM State of Utah Mail - Fwd: NOI Submittal
https://mail.google.com/mail/u/0/?ik=c52f18613a&view=pt&search=all&permthid=thread-f:1792170459848260694&simpl=msg-f:1792170459848260694 2/2
https://utahgov.co1.qualtrics.com/WRQualtricsControlPanel/File.php?F=F_3RgeY4B1jLoRhQQ
--
Alan Humpherys
Manager | Minor NSR Section
P: [phone]
F: [phone]
airquality.utah.gov
Emails to and from this email address may be considered public records and thus subject to Utah GRAMA
requirements.
2024_02_23_Grand_Central_Facility_NOI.pdf
4845K