DAQ-2024-007951

DAQE-AN161890001-24

{{$d1 }}

Ted Meinhold
Kinder Morgan Altamont LLC
1001 Louisiana Street, Suite 1000
Houston, TX 77002
[e-mail]

Dear Mr. Meinhold:

Re: Approval Order: New Approval Order for the Hideout Compressor Station
Project Number: N161890001

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on December
22, 2023. Kinder Morgan Altamont LLC must comply with the requirements of this AO, all applicable
state requirements (R307), and Federal Standards.

The project engineer for this action is Tad Anderson, 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:TA:jg

cc: TriCounty 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

April 24, 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-AN161890001-24
New Approval Order for the Hideout Compressor Station

Prepared By
Tad Anderson, Engineer
[phone]
[e-mail]

Issued to
Kinder Morgan Altamont LLC - Hideout Compressor Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

April 24, 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 .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ..................................................................................................................... 9
ACRONYMS ............................................................................................................................... 10

DAQE-AN161890001-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Kinder Morgan Altamont LLC Kinder Morgan Altamont LLC - Hideout
Compressor Station

Mailing Address Physical Address
1001 Louisiana Street, Suite 1000 4 Miles Northeast of Myton
Houston, TX 77002 Duchesne County, UT

Source Contact UTM Coordinates
Name: Erin Dunman 585,094.62 m Easting
Phone: [phone],453,138.81 m Northing
Email: [e-mail] Datum NAD27
UTM Zone 12

SIC code 1311 (Crude Petroleum & Natural Gas)

SOURCE INFORMATION
General Description
Kinder Morgan Altamont LLC (Kinder Morgan) has requested to construct and operate the new Hideout
Compressor Station. The new Hideout Compressor Station will be designed to compress, treat, and
dehydrate up to 100 MMscfd of natural gas and generate up to 260 bpd of condensate.

NSR Classification
New Minor Source

Source Classification
Located in Uinta Basin O3 NAA
Duchesne 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), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After September 18,
2015
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
DAQE-AN161890001-24
Page 4

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
Kinder Morgan has requested to construct and operate the new Hideout Compressor Station. The new
Hideout compressor station consists of ten (10) compressor engines, a heater/boiler, a stabilizer heater, a
TEG dehydration unit (still vent and flash tank), two (2) combustors, a flare, six (6) condensate tanks, a
truck loading station, and five (5) process tanks. All equipment located at the Hideout Compressor
Station will be operated on pipeline-quality natural gas, except for the gas recovered from the TEG
dehydration flash tank.

The Hideout Compressor Station's primary function will be to compress and dehydrate field gas, as well
as boost pipeline gas. The low-pressure inlet stream will consist of natural gas from the Altamont field
entering the facility through a pipeline.

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 107120.00
Carbon Monoxide 96.89
Nitrogen Oxides 67.15
Particulate Matter - PM10 9.41
Particulate Matter - PM2.5 9.41
Sulfur Oxides 0.40
Volatile Organic Compounds 94.24

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
2,2,4-Trimethylpentane (CAS #540841) 60
Acrolein (CAS #107028) 360
Benzene (Including Benzene From Gasoline) (CAS #71432) 1020
Ethyl Benzene (CAS #100414) 2
Formaldehyde (CAS #50000) 7280
Hexane (CAS #110543) 7220
Methanol (CAS #67561) 420
Toluene (CAS #108883) 240
Xylenes (Isomers And Mixture) (CAS #1330207) 40
Change (TPY) Total (TPY)
Total HAPs 8.32

DAQE-AN161890001-24
Page 5

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

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

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 Hideout Compressor Station
Natural Gas Compressor Station

II.A.2 RICE-1 through 10 (NEW)
Natural Gas Fired IC Engine, 4SRB
Capacity: 1,900 hp
Control: Non-selective catalytic reduction catalyst, Air-fuel-ratio controller
Federal Applicable: 40 CFR 60 Subpart JJJJ

DAQE-AN161890001-24
Page 6

II.A.3 DEHY
TEG Dehydration Unit Process Vents
Capacity: 45 MMscf/day

II.A.4 H-1
Natural Gas Fired Heater/Reboiler
Capacity: 1.5 MMBtu/hr

II.A.5 H-2
Natural Gas Fired Heater Stabilizer
Capacity: 1.5 MMBtu/hr

II.A.6 COM-1
Enclosed Combustor
Capacity:
Control: All Tanks
Federal Applicable: 40 CFR 60, Subpart A

II.A.7 COM-2
Enclosed Combustor
Control: BTEX unit
Federal Applicable: 40CFR 60, Subpart A

II.A.8 T-1 through 6
Condensate Storage Tanks
One (1) Gunbarrel tank
Capacity: 16,800 gallons
Five (5) condensate tanks
Capacity: 16,800 gallons each

II.A.9 MT-Tank
Methanol Storage Tank
Capacity: 16,800 gallons

II.A.10 MIS-Tanks
Miscellaneous Storage Tanks
Contents: lube oil, used oil, antifreeze

II.A.11 TRK-1
Truck Loading

II.A.12 FUG-1
Fugitive Emissions
Component Leaks, compressor blow-down events, pigging,

DAQE-AN161890001-24
Page 7

SECTION II: SPECIAL PROVISIONS

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Site Wide Requirements
II.B.1.a Visible emissions from the following emission points shall not exceed the following values:

A. All-natural gas operated equipment and tanks - 10% opacity.

B. All other points - 20% opacity.

[R307-401-8]

II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted according to 40
CFR 60, Appendix A, Method 9. [R307-401-8]

II.B.1.b The compressor station production limit shall not exceed 100 million standard dry cubic feet of
processed natural gas per day. [R307-401-8]

II.B.1.b.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the twentieth day of each month using data from the previous 12 months.
Records of production shall be kept for all periods when the plant is in operation. Production
shall be determined by gas flow meters for natural gas and hours of operation. The records of
processing and production shall be kept on a daily basis. Hours of operation shall be determined
by supervisor monitoring and maintaining of an operations log. [R307-401-8]

II.B.1.c All emissions from the Dehydration unit (DEHY) must be routed to either Combustors (COM-1
or COM-2). [R307-401-8]

II.B.2 Engine Testing Requirements
II.B.2.a The owner/operator shall not emit more than the following rates and concentrations from the
indicated emissions unit(s):

Source: RICE-1 through RICE-10

Pollutant lb/hr
NOX 1.26(each)
CO 1.27(each)
VOC 1.26(each)

[R307-401-8]

II.B.2.a.1 Standard Conditions & Emission Limit Parameters:

A. Temperature - 68 degrees Fahrenheit (293 K).

B. Pressure - 29.92 in Hg (101.3 kPa).

C. Concentration (ppmdv) - 3% oxygen, dry basis.

D. Averaging Time - As specified in the applicable test method.

[R307-401-8]

DAQE-AN161890001-24
Page 8

II.B.2.a.2 Initial Test
The owner/operator shall conduct an initial emission test within 180 days after startup.
[R307-401-8]

II.B.2.a.3 Test Frequency
The owner/operator shall conduct subsequent emission tests within three (3) years or 8,760 hours
of operation after the date of the most recent emission test. The Director may require the
owner/operator to perform an emission test at any time. [R307-401-8]

II.B.2.a.4 Notification
At least 30 days prior to conducting an emission test, the owner/operator shall submit a source
test protocol to the Director. The source test protocol shall include:

A. The date, time, and place of the proposed test.

B. The proposed test methodologies.

C. The stack to be tested.

D. The procedures to be used.

E. Any deviation from an EPA-approved test method.

F. Explanation of any deviation from an EPA-approved test method.

If directed by the Director, the owner/operator shall attend a pretest conference.

[R307-401-8]

II.B.2.a.5 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.2.a.6 CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the
Director. [R307-401-8]

II.B.2.a.7 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 Combustors and Flare Requirements
II.B.3.a All combustors and flare shall operate with a continuous pilot flame and be equipped with an
auto-igniter. [R307-401-8]

II.B.3.b All combustors and flare shall operate with no visible emissions. [R307-401-8]

II.B.3.b.1 Visual determination of emissions from each combustor and flare shall be conducted according
to 40 CFR 60, Appendix A, Method 22. [R307-401-8]

II.B.4 Condensate Storage Tank Requirements
II.B.4.a The owner/operator shall not produce more than 94,900 barrels (1 barrel = 42 gallons) of
condensate per rolling 12-month period from the Hideout Compressor Station. [R307-401-8]

DAQE-AN161890001-24
Page 9

II.B.4.a.1 The owner/operator shall:

A. Determine condensate production with process flow meters and/or sales records.

B. Record condensate production on a daily basis.

C. Calculate a new 12-month total by the 20th day of each month using data from
the previous 12 months.

D. Keep the production records for all periods the plant is in operation.

[R307-401-8]

II.B.4.b All emissions from the Condensate Storage Tanks (T-1 thru T-6) must be routed to either
Combustors (COM-1 or COM-2). [R307-401-8]

II.B.5 Truck Loading Requirements
II.B.5.a The owner/operator shall load the tanker trucks on site by the use of submerged loading.
[R307-401-8]

II.B.5.b The owner/operator shall connect a vapor capture line to the operating combustor for use during
on-site condensate truck loading operations at the Hideout Compressor Station. The vapor
capture line shall be used at all times during loading operations. [R307-401-8]

II.B.6 Fugitive Emissions Requirements
II.B.6.a The Hideout Compressor Station is subject to the LDAR requirements in 40 CFR 60 Subpart
OOOOa and OOOOb. [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 December 22, 2023

DAQE-AN161890001-24
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-IN161890001-24

March 14, 2024

Ted Meinhold
Kinder Morgan Altamont LLC
1001 Louisiana Street, Suite 1000
Houston, TX 77002
[e-mail]

Dear Mr. Meinhold:

Re: Intent to Approve: New Approval Order for the Hideout Compressor Station
Project Number: N161890001

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, Tad Anderson, as well as the
DAQE number as shown on the upper right-hand corner of this letter. Tad Anderson, can be reached at
[phone] or [e-mail], if you have any questions.

Sincerely,

{{$s }}

Jon L. Black, Manager
New Source Review Section

JLB:TA:jg

cc: TriCounty 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

* ) ' & — - F v A ? A C @ G w A B ˜
STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

INTENT TO APPROVE
DAQE-IN161890001-24
New Approval Order for the Hideout Compressor Station

Prepared By
Tad Anderson, Engineer
[phone]
[e-mail]

Issued to
Kinder Morgan Altamont LLC - Hideout Compressor Station

Issued On
March 14, 2024

{{$s }}

New Source Review Section Manager
Jon L. Black
{{#s=Sig_es_:signer1:signature}}

* ) ' & — - F v A ? A C @ G w A B ˜

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............................................................................................... 5
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ................................................................................................................... 10
ACRONYMS ............................................................................................................................... 11

DAQE-IN161890001-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Kinder Morgan Altamont LLC Kinder Morgan Altamont LLC - Hideout
Compressor Station

Mailing Address Physical Address
1001 Louisiana Street, Suite 1000 4 Miles Northeast of Myton
Houston, TX 77002 Duchesne County, UT

Source Contact UTM Coordinates
Name: Erin Dunman 585,094.62 m Easting
Phone: [phone],453,138.81 m Northing
Email: [e-mail] Datum NAD27
UTM Zone 12

SIC code 1311 (Crude Petroleum & Natural Gas)

SOURCE INFORMATION
General Description
Kinder Morgan Altamont LLC (Kinder Morgan), has requested to construct and operate the new Hideout
Compressor Station. The new Hideout Compressor Station will be designed to compress, treat, and
dehydrate up to 100 MMscfd of natural gas and generate up to 260 bpd of condensate.
NSR Classification
New Minor Source

Source Classification
Located in , Uinta Basin O3 NAA
Duchesne 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), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After September 18,
2015
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
DAQE-IN161890001-24
Page 4

Natural Gas Production Facilities
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

Project Description
Kinder Morgan has requested to construct and operate the new Hideout Compressor Station. The new
Hideout compressor station consists of ten (10) compressor engines, a heater/boiler, a stabilizer heater, a
TEG dehydration unit (still vent and flash tank), two (2) combustors, a flare, six (6) condensate tanks, a
truck loading station, and five (5) process tanks. All equipment located at the Hideout Compressor
Station will be operated on pipeline-quality natural gas, except for the gas recovered from the TEG
dehydration flash tank.

The Hideout Compressor Station's primary function will be to compress and dehydrate field gas, as well
as boost pipeline gas. The low-pressure inlet stream will consist of natural gas from the Altamont field
entering the facility through a pipeline.

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 107120.00 107120.00
Carbon Monoxide 96.89 96.89
Nitrogen Oxides 67.15 67.15
Particulate Matter - PM10 9.41 9.41
Particulate Matter - PM2.5 9.41 9.41
Sulfur Oxides 0.40 0.40
Volatile Organic Compounds 94.24 94.24

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
2,2,4-Trimethylpentane (CAS #540841) 60 60
Acrolein (CAS #107028) 360 360
Benzene (Including Benzene From Gasoline) (CAS #71432) 1020 1020
Ethyl Benzene (CAS #100414) 2 2
Formaldehyde (CAS #50000) 7280 7280
Hexane (CAS #110543) 7220 7220
Methanol (CAS #67561) 420 420
Toluene (CAS #108883) 240 240
Xylenes (Isomers And Mixture) (CAS #1330207) 40 40
Change (TPY) Total (TPY)
Total HAPs 8.32 8.32

DAQE-IN161890001-24
Page 5

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 Vernal Express on March 20, 2024. During the public comment
period the proposal and the evaluation of its impact on air quality will be available for the 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]

DAQE-IN161890001-24
Page 6

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

SECTION II: PERMITTED EQUIPMENT

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO.

II.A THE APPROVED EQUIPMENT

II.A.1 Hideout Compressor Station
Natural Gas Compressor Station

II.A.2 RICE-1 through 10
Natural Gas Fired IC Engine, 4SRB
Capacity: 1,900 hp
Control: Non-selective catalytic reduction catalyst, Air-fuel-ratio controller
Federal Applicable: 40 CFR 60 Subpart JJJJ

II.A.3 DEHY
TEG Dehydration Unit Process Vents
Capacity: 45 MMscf/day

II.A.4 H-1
Natural Gas Fired Heater/Reboiler
Capacity: 1.5 MMBtu/hr

II.A.5 H-2
Natural Gas Fired Heater Stabilizer
Capacity: 1.5 MMBtu/hr

II.A.6 COM-1
Enclosed Combustor
Capacity:
Control: All Tanks
Federal Applicable: 40 CFR 60, Subpart A

II.A.7 COM-2
Enclosed Combustor
Control: BTEX unit
Federal Applicable: 40CFR 60, Subpart A

II.A.8 T-1 through 6
Condensate Storage Tanks
One (1) Gunbarrel tank
Capacity: 16,800 gallons
Five (5) condensate tanks
Capacity: 16,800 gallons each

DAQE-IN161890001-24
Page 7

II.A.9 MT-Tank
Methanol Storage Tank
Capacity: 16,800 gallons

II.A.10 MIS-Tanks
Miscellaneous Storage Tanks
Contents: lube oil, used oil, antifreeze

II.A.11 TRK-1
Truck Loading

II.A.12 FUG-1
Fugitive Emissions
Component Leaks, compressor blow down events, pigging

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 Site Wide Requirements
II.B.1.a Visible emissions from the following emission points shall not exceed the following values:

A. All-natural gas operated equipment and tanks - 10% opacity

B. All other points - 20% opacity.

[R307-401-8]

II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted according to 40
CFR 60, Appendix A, Method 9. [R307-401-8]

II.B.1.b The following production limits shall not exceed 100 million standard dry cubic feet of
processed natural gas per day. [R307-401-8]

II.B.1.b.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the twentieth day of each month using data from the previous 12 months.
Records of production shall be kept for all periods when the plant is in operation. Production
shall be determined by gas flow meters for natural gas and hours of operation. The records of
processing and production shall be kept on a daily basis. Hours of operation shall be determined
by supervisor monitoring and maintaining of an operations log. [R307-401-8]

II.B.1.c All emissions from the Dehydration unit (DEHY) must be routed to either Combustors (COM-1
or COM-2). [R307-401-8]

DAQE-IN161890001-24
Page 8

II.B.2 Engine Testing Requirements
II.B.2.a The owner/operator shall not emit more than the following rates and concentrations from the
indicated emissions unit(s):

Source: RICE-1 through RICE-10
Pollutant lb/hr
NOX 1.26(each)
CO 1.27(each)
VOC 1.26(each).

[R307-401-8]

II.B.2.a.1 Standard Conditions & Emission Limit Parameters:

A. Temperature - 68 degrees Fahrenheit (293 K)

B. Pressure - 29.92 in Hg (101.3 kPa)

C. Concentration (ppmdv) - 3% oxygen, dry basis

D. Averaging Time - As specified in the applicable test method.

[R307-401-8]

II.B.2.a.2 Initial Test
The owner/operator shall conduct an initial emission test within 180 days after startup.
[R307-401-8]

II.B.2.a.3 Test Frequency
The owner/operator shall conduct subsequent emission tests within three (3) years or 8,760 hours
of operation after the date of the most recent emission test. The Director may require the
owner/operator to perform an emission test at any time. [R307-401-8]

II.B.2.a.4 Notification
At least 30 days prior to conducting an emission test, the owner/operator shall submit a source
test protocol to the Director. The source test protocol shall include:

A. The date, time, and place of the proposed test

B. The proposed test methodologies

C. The stack to be tested

D. The procedures to be used

E. Any deviation from an EPA-approved test method

F. Explanation of any deviation from an EPA-approved test method.

If directed by the Director, the owner/operator shall attend a pretest conference.

[R307-401-8]

II.B.2.a.5 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]

DAQE-IN161890001-24
Page 9

II.B.2.a.6 CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the
Director. [R307-401-8]

II.B.2.a.7 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 Combustors and Flare Requirements
II.B.3.a All combustors and flare shall operate with a continuous pilot flame and be equipped with an
auto-igniter. [R307-401-8]

II.B.3.b All combustors and flare shall operate with no visible emissions. [R307-401-8]

II.B.3.b.1 Visual determination of emissions from each combustor and flare shall be conducted according
to 40 CFR 60, Appendix A, Method 22. [R307-401-8]

II.B.4 Condensate Storage Tank Requirements
II.B.4.a The owner/operator shall not produce more than 94,900 barrels (1 barrel = 42 gallons) of
condensate per rolling 12-month period from the Hideout Compressor Station. [R307-401-8]

II.B.4.a.1 The owner/operator shall:

A. Determine condensate production with process flow meters and/or sales records

B. Record condensate production on a daily basis

C. Calculate a new 12-month total by the 20th day of each month using data from
the previous 12 months

D. Keep the production records for all periods the plant is in operation.

[R307-401-8]

II.B.4.b All emissions from the Condensate Storage Tanks (T-1 thru T-6) must be routed to either
Combustors (COM-1 or COM-2). [R307-401-8]

II.B.5 Truck Loading Requirements
II.B.5.a The owner/operator shall load the tanker trucks on site by the use of submerged loading.
[R307-401-8]

II.B.5.b The owner/operator shall connect a vapor capture line to the operating combustor for use during
on-site condensate truck loading operations at the Hideout Compressor Station. The vapor
capture line shall be used at all times during loading operations. [R307-401-8]

II.B.6 Fugitive Emissions Requirements
II.B.6.a The Hideout Compressor Station is subject to the LDAR requirements in 40 CFR 60 Subpart
OOOOa and OOOOb. [R307-401-8]

DAQE-IN161890001-24
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 December 22, 2023

DAQE-IN161890001-24
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

Kinder Morgan 16189 0001 - Page 1 of 2
FILER
Jeree Greenwood
[e-mail]
[phone]
FILING FOR
Vernal Express
Columns Wide:1
Total Column Inches:6.56
Number of Lines:59
Ad Class:Legals
INTERIM AD DRAFT
T h i s is t he p r oo f o f yo ur ad sc he du l ed to r u n in Ve rn a l Ex p r es s o n t he d a te s in dic ate d be l ow. If
c h a n ge s a r e ne ed ed , p l ea se co nt a ct us pr i o r to d ea dlin e a t (4 35 ) 9 38 -7 11 2.
Notice ID: GncRz2OzDWf77X2QINEN | Proof Updated: Mar. 14, 2024 at 10:43am MDT
Notice Name: Kinder Morgan 16189 0001
This is not an invoice. Below is an estimated price, and it is
subject to change. You will receive an invoice with the final
price upon invoice creation by the publisher.
03/20/2024: General Legal and Public
Notice
79.35
Upload Fee 0.25
Subtotal $79.60
Tax $0.00
Processing Fee $0.00
Total $79.60
See Proof on Next Page
Kinder Morgan 16189 0001 - Page 2 of 2

DAQE-NN161890001-24

March 14, 2024

Vernal Express
Legal Advertising Dept.
60 East 100 North
Vernal, UT 84078-2122

RE: Legal Notice of Intent to Approve

This letter will confirm the authorization to publish the attached NOTICE in the Vernal Express
(Account Number: 2307) on March 20, 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: Duchesne County
cc: Uintah Basin 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-NN161890001-24
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: Kinder Morgan Altamont LLC
Location: Kinder Morgan Altamont LLC - Hideout Compressor Station – 4 Miles
Northeast of Myton, Duchesne County, UT
Project Description: Kinder Morgan Altamont, LLC (Kinder Morgan), has requested to construct and
operate the new Hideout Compressor Station.

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 April 19, 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: March 20, 2024

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

DAQE-

RN161890001
February 15, 2024

Ted Meinhold
Kinder Morgan Altamont LLC
1001 Louisiana Street, Suite 1000
Houston, TX 77002
[e-mail]

Dear Ted Meinhold,

Re: Engineer Review:
New Approval Order for the Hideout Compressor Station
Project Number: N161890001

The DAQ requests a company representative review and sign the attached Engineer Review (ER). This
ER identifies all applicable elements of the New Source Review permitting program. Kinder Morgan
Altamont LLC should complete this review within 10 business days of receipt.

Kinder Morgan Altamont LLC should contact Tad Anderson at [phone] if there are questions or
concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email
Tad Anderson at [e-mail] the signed cover letter. Upon receipt of the signed cover letter,
the DAQ will prepare an ITA for a 30-day public comment period. At the completion of the comment
period, the DAQ will address any comments and will prepare an Approval Order (AO) for signature by
the DAQ Director.

If Kinder Morgan Altamont LLC does not respond to this letter within 10 business days, the project will
move forward without source concurrence. If Kinder Morgan Altamont LLC has concerns that cannot be
resolved and the project becomes stagnant, the DAQ Director may issue an Order prohibiting
construction.

Approval Signature _____________________________________________________________
(Signature & Date)

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

Kimberly D. Shelley Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird Director

State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION

Project Number N161890001
Owner Name Kinder Morgan Altamont LLC
Mailing Address 1001 Louisiana Street, Suite 1000
Houston, TX, 77002

Source Name Kinder Morgan Altamont LLC- Hideout Compressor Station
Source Location 4 Miles Northeast of Myton
Duchesne County, UT

UTM Projection 585,094.62 m Easting, 4,453,138.81 m Northing
UTM Datum NAD27
UTM Zone UTM Zone 12
SIC Code 1311 (Crude Petroleum & Natural Gas)

Source Contact Erin Dunman
Phone Number [phone]
Email [e-mail]

Billing Contact Erin Dunman
Phone Number 303-914-7605
Email [e-mail]

Project Engineer Tad Anderson, Engineer
Phone Number [phone]
Email [e-mail]

Notice of Intent (NOI) Submitted December 22, 2023

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 2
SOURCE DESCRIPTION

General Description
Kinder Morgan Altamont, LLC (Kinder Morgan), has requested to construct and operate the new
Hideout Compressor Station. The new Hideout Compressor Station will be designed to
compress, treat, and dehydrate up to 100 MMscfd of natural gas and generate up to 260 bpd of
condensate.

NSR Classification:
New Minor Source

Source Classification
Located in, Uinta Basin O3 NAA, Duchesne 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), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After September 18,
2015
NSPS (Part 60), OOOOb: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After December 6, 2022
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 Proposal
New Approval Order for the Hideout Compressor Station

Project Description
Kinder Morgan Altamont, LLC (Kinder Morgan), has requested to construct and operate the new
Hideout Compressor Station. The new Hideout compressor station consists of ten compressor
engines, a heater/boiler, a stabilizer heater, a TEG dehydration unit (still vent and flash tank), two
combustors, a flare, six tanks, a truck loading station and five process tanks. All equipment
located at the Hideout Compressor Station will be operated on pipeline quality natural gas, except
the gas recovered from the TEG dehydration flash tank.

The Hideout Compressor Station's primary function will be to compress and dehydrate field gas,
as well as boosting pipeline gas. The low-pressure inlet stream will consist of natural gas from the
Altamont field entering the facility through a pipeline.

EMISSION IMPACT ANALYSIS
Modeling was conducted for NOx and NO2. The summary of the modeling information is documented in the
modeling memo DAQE-MN161890001-24. [Last updated February 14, 2024]

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 3

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 4
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 107120.00 107120.00
Carbon Monoxide 96.89 96.89
Nitrogen Oxides 67.15 67.15
Particulate Matter - PM10 9.41 9.41
Particulate Matter - PM2.5 9.41 9.41
Sulfur Oxides 0.40 0.40
Volatile Organic Compounds 94.24 94.24

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
2,2,4-Trimethylpentane (CAS #540841) 60 60
Acrolein (CAS #107028) 360 360
Benzene (Including Benzene From Gasoline) (CAS #71432) 1020 1020
Ethyl Benzene (CAS #100414) 2 2
Formaldehyde (CAS #50000) 7280 7280
Hexane (CAS #110543) 7220 7220
Methanol (CAS #67561) 420 420
Toluene (CAS #108883) 240 240
Xylenes (Isomers And Mixture) (CAS #1330207) 40 40
Change (TPY) Total (TPY)
Total HAPs 8.32 8.32

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

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 5
Review of BACT for New/Modified Emission Units

1. BACT review regarding Sitewide BACT
The notice of intent includes an analysis of the best available control technology (BACT) as per
R307-401-5 for all equipment at the proposed source. This BACT analysis focused on the four-
stroke rich burn (4SRB) Spark-Ignited Reciprocating Internal Combustion Engines (SI RICE) .
The SI RICE, as a group, are the largest contributors of air emissions at the Hideout Compressor
Station. The other emission sources were addressed with current BACT for each respective source
type.

4SRB SI-RICE
The BACT analysis took into consideration the following control technologies to control NOx
emissions from the new SI-RICE: AFR controller, Pre-Stratified Charge, Lean Burn Technologies,
Ultra Lean Burn (ULB) Technology, Selective Non-catalytic Reduction (SNCR), Non-Selective
Catalytic Reduction (NSCR) and Selective Catalytic Reduction (SCR). Pre-Stratified Charge and
Lean Burn Technologies are not technically feasible for rich burn engines. The SNCR and SCR are
not technically feasible for a 4SRB. The remaining control technology left is NSCR. The Exhaust
stacks for each of the units will be equipped with a NSCR (3-way) catalyst to reduce the NOx
emissions rates by more than 97% to achieve 0.30 g/bhp-hr. BACT to control NOx for the ten
4SRB SI-RICE is the addition of the NSCR with a 0.30 g/bhp-hr and a 10% opacity limit

All other criteria pollutants were addressed in the BACT analysis but the focus for 4SRB SI-RICE
is NOX.

Triethylene Glycol (TEG) Dehydrator Vent
The still vent for the TEG regeneration processes at the Hideout Compressor Station will be routed
through a condenser with all non-condensable vapors from the condenser vent being directed to an
enclosed combustor. The combustor will achieve a destruction efficiency of 95% or greater. The
TEG dehydrator flash tank vapors will be collected and used in the fuel system at the station.
BACT to control VOC and HAPs from the TEG Dehydrator is the use of a condenser and
combustor.

Storage Tanks
The organic liquids storage tanks with the largest VOC emissions are Condensate Tanks T-1
through T-6. The vapors for these tanks are collected with an enclosed vapor collection system and
directed to an enclosed combustor with a VOC destruction efficiency of 95% or greater. BACT to
control VOC emissions from the condensate storage tanks is the use of a vapor collection system
and enclosed combustor.

Tank Truck Loading
Current truck loading requirements in UAC R307-504 establish specific control requirements for
the loading and unloading of liquids containing volatile organic compounds (VOCs) at oil or gas
well sites. These control requirements include the use of bottom fill or submerged fill pipe as well
as a "Vapor Capture Line" from the truck loading being routed to an enclosed combustor for
destruction. BACT to control VOC emissions from the Tank Truck Loading compliance with UAC
R307-504 and vapor capture line being routed to combustor. [Last updated February 14, 2024]

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 6
SECTION I: GENERAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]

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

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon
request, and the records shall include the two-year period prior to the date of the request.
Unless otherwise specified in this AO or in other applicable state and federal rules, records
shall be kept for a minimum of two (2) years. [R307-401-8]

I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators
shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air
pollution control practice for minimizing emissions. Determination of whether acceptable
operating and maintenance procedures are being used will be based on information available
to the Director which may include, but is not limited to, monitoring results, opacity
observations, review of operating and maintenance procedures, and inspection of the source.
All maintenance performed on equipment authorized by this AO shall be recorded. [R307-
401-4]

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

I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-
150]

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

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

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 7

II.A THE APPROVED EQUIPMENT

II.A.1
NEW
Hideout Compressor Station
Natural Gas Compressor Station

II.A.2
NEW
RICE-1 through 10 (NEW)
Natural Gas Fired IC Engine, 4SRB
Capacity: 1,900 hp
Control: Non-selective catalytic reduction catalyst, Air-fuel-ratio controller
Federal Applicable: 40 CFR 60 Subpart JJJJ

II.A.3
NEW
DEHY
TEG Dehydration Unit Process Vents
Capacity: 45 MMscf/day

II.A.4
NEW
H-1
Natural Gas Fired Heater/Reboiler
Capacity: 1.5 MMBtu/hr

II.A.5
NEW
H-2
Natural Gas Fired Heater Stabilizer
Capacity: 1.5 MMBtu/hr

II.A.6
NEW
COM-1
Enclosed Combustor
Capacity:
Control: All Tanks
Federal Applicable: 40 CFR 60, Subpart A

II.A.7
NEW
COM-2
Enclosed Combustor
Control: BTEX unit
Federal Applicable: 40CFR 60, Subpart A

II.A.8
NEW
T-1 through 6
Condensate Storage Tanks
1 Gunbarrel tank
Capacity: 16,800 gallons
5 condensate tanks
Capacity: 16,800 gallons each

II.A.9
NEW
MT-Tank
Methanol Storage Tank
Capacity: 16,800 gallons

II.A.10
NEW
MIS-Tanks
Miscellaneous Storage Tanks
Contents: lube oil, used oil, antifreeze

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 8
II.A.11
NEW
TRK-1
Truck Loading

II.A.12
NEW
FUG-1
Fugitive Emissions
Component Leaks, compressor blow down events, pigging,

SECTION II: SPECIAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label):

II.B REQUIREMENTS AND LIMITATIONS

II.B.1
NEW
Site Wide Requirements
II.B.1.a
NEW
Visible emissions from the following emission points shall not exceed the following values:

A. All-natural gas operated equipment and tanks - 10% opacity
B. All other points - 20% opacity. [R307-401-8]

II.B.1.a.1
NEW
Opacity observations of emissions from stationary sources shall be conducted according to 40
CFR 60, Appendix A, Method 9. [R307-401-8]

II.B.1.b
NEW
The following production limits shall not exceed 100 million standard dry cubic feet of
processed natural gas per day. [R307-401-8]

II.B.1.b.1
NEW
To determine compliance with a rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the twentieth day of each month using data from the previous 12
months. Records of production shall be kept for all periods when the plant is in operation.
Production shall be determined by gas flow meters for natural gas and hours of operation. The
records of processing and production shall be kept on a daily basis. Hours of operation shall
be determined by supervisor monitoring and maintaining of an operations log. [R307-401-8]

II.B.1.c
NEW
All emissions from the Dehydration unit (DEHY) must be routed to either Combustors (COM-
1 or COM-2). [R307-401-8]

II.B.2
NEW
Engine Testing Requirements
II.B.2.a
NEW
The owner/operator shall not emit more than the following rates and concentrations from the
indicated emissions unit(s):

Source: RICE-1 through RICE-10
Pollutant lb/hr
NOX 1.26(each)
CO 1.27(each)
VOC 1.26(each). [R307-401-8]

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 9
II.B.2.a.1
NEW
Standard Conditions & Emission Limit Parameters
A. Temperature - 68 degrees Fahrenheit (293 K)
B. Pressure - 29.92 in Hg (101.3 kPa)
C. Concentration (ppmdv) - 3% oxygen, dry basis
D. Averaging Time - As specified in the applicable test method. [R307-401-8]

II.B.2.a.2
NEW
Initial Test
The owner/operator shall conduct an initial emission test within 180 days after startup. [R307-
401-8]

II.B.2.a.3
NEW
Test Frequency
The owner/operator shall conduct subsequent emission tests within three years or 8,760 hours
of operation after the date of the most recent emission test. The Director may require the
owner/operator to perform an emission test at any time. [R307-401-8]

II.B.2.a.4
NEW
Notification
At least 30 days prior to conducting an emission test, the owner/operator shall submit a source
test protocol to the Director. The source test protocol shall include:
A. The date, time, and place of the proposed test
B. The proposed test methodologies
C. The stack to be tested
D. The procedures to be used
E. Any deviation from an EPA-approved test method
F. Explanation of any deviation from an EPA-approved test method

If directed by the Director, the owner/operator shall attend a pretest conference. [R307-401-8]

II.B.2.a.5
NEW
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.2.a.6
NEW
CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to
the Director. [R307-401-8]

II.B.2.a.7
NEW
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
NEW
Combustors and Flare Requirements
II.B.3.a
NEW
All combustors and flare shall operate with a continuous pilot flame and be equipped with an
auto-igniter. [R307-401-8]

II.B.3.b
NEW
All combustors and flare shall operate with no visible emissions. [R307-401-8]

II.B.3.b.1
NEW
Visual determination of emissions from each combustor and flare shall be conducted
according to 40 CFR 60, Appendix A, Method 22. [R307-401-8]

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 10
II.B.4
NEW
Condensate Storage Tank Requirements
II.B.4.a
NEW
The owner/operator shall not produce more than 94,900 barrels (1 barrel = 42 gallons) of
condensate per rolling 12-month period from the Hideout Compressor Station. [R307-401-8]

II.B.4.a.1
NEW
The owner/operator shall:

A. Determine condensate production with process flow meters and/or sales records.
B. Record condensate production on a daily basis.
C. Calculate a new 12-month total by the 20th day of each month using data from the
previous 12 months.
D. Keep the production records for all periods the plant is in operation. [R307-401-8]

II.B.4.b
NEW
All emissions from the Condensate Storage Tanks (T-1 thru T-6) must be routed to either
Combustors (COM-1 or COM-2). [R307-401-8]

II.B.5
NEW
Truck Loading Requirements
II.B.5.a
NEW
The owner/operator shall load the tanker trucks on site by the use of submerged loading.
[R307-401-8]

II.B.5.b
NEW
The owner/operator shall connect a vapor capture line to the operating combustor for use
during on-site condensate truck loading operations at the Hideout Compressor Station. The
vapor capture line shall be used at all times during loading operations. [R307-401-8]

II.B.6
NEW
Fugitive Emissions Requirements
II.B.6.a
NEW
The Hideout Compressor Station is subject to the LDAR requirements in 40 CFR 60 Subpart
OOOOa and OOOOb. [R307-401-8]

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 11
PERMIT HISTORY

When issued, the approval order shall supersede (if a modification) or will be based on the
following documents:

Is Derived From NOI dated December 22, 2023

REVIEWER COMMENTS

1. Comment regarding Emission Estimates:
The ten compressor engines emission estimates used manufacturer information for NOx, CO, VOC
and Formaldehyde emissions. Additional controls reduction was added to the emissions for the
NSCR with control efficiency from the manufacture for NOx and CO. The rest of the criteria
emissions and HAP emissions were estimated using AP-42 emissions factors and 8760 hours of
operation annually.

The heaters emission estimates AP-42 emissions factors and 8760 hours of operation annually.

The combustors emission estimates used emission factors developed by Wyoming for NOx, CO, and
VOCs. The PM10 and PM2.5 emissions estimates used emissions factors from AP-42.

The flare emission estimates used AP-42 emission factors for NOx, CO, PM10 and PM2.5. The VOCs
estimates used manufacturer information. The PM10 and PM2.5 emissions estimates used emissions
factors from AP-42.

The condensate storage tanks emission estimates used ProMax model for the tank emissions from
operation and the combustors manufactures destruction efficiency.

The miscellaneous storage tanks emissions estimates used TANKS model.

The fugitive VOC emission estimates from pigging, blow down, and leaks used "Protocol for
Equipment Leak Emission Estimates" (EPA-453/R-95-017). [Last updated February 14, 2024]

2. Comment regarding Project Type:
The Kinder Morgan, Hideout Compressor Station is classified as a minor source since all criteria
emissions are below 100 TPY, the combined HAPs are below 25 TPY and all HAPs are below 10
TPY. [Last updated February 14, 2024]

3. Comment regarding HAPs Modeling:
A HAPs analysis was conducted according to UAC Section R307-410-5. Formaldehyde from the
large 4-Stroke Rich Burn Spark Ignition compressor engines was the only HAP that exceeded the
emissions threshold value (ETV). The formaldehyde emissions are emitted from emissions units
that are subject to an emission standard promulgated under 42 U.S.C. 7412 (NESHAP Subpart
ZZZZ) and are exempt from the requirements of UAC Sections R307-410- 5(c)(i)(A) through (C)
which is a comparison of the emission unit emissions to ETVs. [Last updated February 14, 2024]

4. Comment regarding Criteria Modeling:
The construction of the new Hideout Compressor Station results in total controlled NOx emission
increases greater than those listed in the Utah Administrative Code (UAC) R307-410-4. Kinder
Morgan submitted a dispersion modeling analysis as part of a Notice of Intent. The Notice of Intent

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 12
package contains analysis for the potential project emissions for oxides of nitrogen that exceed the
emissions thresholds listed in UAC R307-410-4. The Notice of Intent package also contains an
analysis to demonstrate that the proposed project will not cause or contribute to an exceedance of the
annual and 1-hour average NO2 National Ambient Air Quality Standards (NAAQS). A modeling
memo was generated DAQE-MN161890001-24 with all information per UAC R307-410-4. [Last
updated February 14, 2024]

5. Comment regarding Nonattainment Area:
The new Kinder Morgan, Hideout Compressor Station is located in an Ozone Nonattainment Area
(Uinta Basin Nonattainment Area). This new Compressor Station is classified as a minor source and
not subject to UAC R307-403, "New and Modified sources in Nonattainment Areas and
Maintenance Area". [Last updated February 14, 2024]

6. Comment regarding Federal Applicable Regulations:
Kinder Morgan, Hideout Compressor Station is subject to 40 CFR 60 Subpart A (General
Provisions) and JJJJ (Standards of Performance for Stationary Spark Ignition Internal Combustion
Engines) and OOOOa/OOOOb (Standards of Performance from Crude Oil and Natural Gas
Production, Transmission, and Distribution); and 40 CFR 63 Subparts A (General Provisions), HH
(National Emission Standards for Hazardous Air Pollutants from Oil and Gas Production Facilities),
and ZZZZ (National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating
Internal Combustion Engines). [Last updated February 14, 2024]

7. Comment regarding Source Classification:
The Kinder Morgan, Hideout Compressor Station is classified as an area source (not major). The
emissions for this new compressor station are within 20% of the major classification emissions level
(CO = 96.89 TPY and VOC=94.24 TPY), so the source is classified as a Synthetic Minor area
source. [Last updated February 14, 2024]

Engineer Review N161890001: Kinder Morgan Altamont LLC- Hideout Compressor Station
February 15, 2024
Page 13
ACRONYMS
The following lists commonly used acronyms and associated translations as they apply to this
document:
40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by EPA to classify sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal UDAQ use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i)
GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/HR Pounds per hour
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

DAQE-MN161890001-24

M E M O R A N D U M

TO: Tad Anderson, NSR Engineer

FROM: Jason Krebs, Air Quality Modeler

DATE: February 13, 2024

SUBJECT: Modeling Analysis Review for the Notice of Intent for Kinder Morgan Altamont LLC –
Hideout Compressor Station, Duchesne County, Utah
_____________________________________________________________________________________
This is not a Major Prevention of Significant Deterioration (PSD) Source.

I. OBJECTIVE
Kinder Morgan Altamont LLC (Applicant) is seeking an approval order for their Hideout
Compressor Station located in Duchesne County, Utah.

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 will be in compliance with applicable 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

III. MODELING METHODOLOGY

A. Applicability

Emissions from the facility include PM10, NOx, CO, SO2, and HAPs. This modeling is part of a
new approval order. The emission rates for NOx triggered the requirement to model under
R307-410. Modeling was performed by the Applicant.

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

JK
DAQE- MN161890001-24
Page 2
B. Assumptions

1. Topography/Terrain

The Plant is at an elevation 5090 feet with terrain features that have an affect on
concentration predictions.

a. Zone: 12

b. Approximate Location:

UTM (NAD83): 585095 meters East
4453139 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 – Vernal, UT NWS: 2016-2020
Upper Air – Grand Junction, CO NWS: 2016-2020

6. Background

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

7. Receptor and Terrain Elevations

The modeling domain used by the Applicant 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.

DAQE- MN161890001-24
Page 3
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

Kinder Morgan Altamont LLC – Hideout Compressor Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
C_1 585022 4453075 1.26 5.50 8760
C_2 585038 4453075 1.26 5.50 8760
C_3 585055 4453075 1.26 5.50 8760
C_4 585071 4453075 1.26 5.50 8760
C_5 585087 4453074 1.26 5.50 8760
C_6 585103 4453074 1.26 5.50 8760
C_7 585120 4453075 1.26 5.50 8760
C_8 585136 4453075 1.26 5.50 8760
C_9 585152 4453075 1.26 5.50 8760
C_10 585169 4453075 1.26 5.50 8760
H_1 585107 4453148 0.12 0.51 8760
FL_1 585178 4453161 1.99 8.74 8760
COM_1 584996 4453072 0.39 1.70 8760
COM_2 585111 4453158 0.12 0.47 8760
H_2 585108 4453167 0.12 0.51 8760

Total 15.28 66.94
AG Mining Solutions, LLC – Betts Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
GEN1AG 558530 4448068 2.16 9.47 8760
GEN2AG 558548 4448063 2.16 9.47 8760
GEN3AG 558560 4448059 2.16 9.47 8760
GEN4AG 558579 4448053 2.16 9.47 8760
GEN5AG 558591 4448050 2.16 9.47 8760
GEN6AG 558612 4448043 2.16 9.47 8760
GEN7AG 558624 4448039 2.16 9.47 8760
DAQE- MN161890001-24
Page 4

Total 15.13 66.28
XCL Sandco, LLC – Anderson Sand Mine PM10
Source
UTM Coordinates Modeled Emission Rates
Easting Northing PM10
(m) (m) (lb/hr) (tons/yr) hrs/year
DRYER 569768 4461031 3.01 13.18 8760
PILE2 569848 4461058 0.08 0.35 8760
PILE3 569854 4460949 0.08 0.35 8760
PILE1 569981 4460886 0.11 0.48 8760
LDOUTRD 569989 4461121 0.80 3.50 8760
CRUSH 570073 4460875 0.32 1.40 8760
SCREENS 569910 4460957 1.25 5.48 8760
DISAREA 569745 4460896 2.72 11.91 8760
MINEEXCAV 570157 4460882 0.36 1.58 8760
MINERD 570119 4460781 1.12 4.91 8760
LDERDRY 569803 4461059 0.18 0.79 8760
LDERCRSH 570048 4460841 0.36 1.58 8760
TPWP 569997 4460905 0.36 1.58 8760
RJTRMNRD 569870 4460962 0.33 1.45 8760
PILE4 569983 4460808 0.05 0.22 8760
REJTTRSF 569874 4460963 0.06 0.26 8760
DRYPLNT 569738 4461045 0.35 1.53 8760
BLAST 570415 4460697 2.63 11.52 8760
DOME2 569710 4461091 0.02 0.07 8760
DOME1 569681 4461062 0.02 0.07 8760

Total 14.20 62.20
SCL Sandco, LLC – Anderson Sand Mine PM2.5
Source
UTM Coordinates Modeled Emission Rates
Easting Northing PM2.5
(m) (m) (lb/hr) (tons/yr) hrs/year
DRYER 569768 4461031 3.01 13.18 8760
PILE2 569848 4461058 0.04 0.18 8760
PILE3 569854 4460949 0.04 0.18 8760
PILE1 569981 4460886 0.06 0.26 8760
LDOUTRD 569989 4461121 0.08 0.35 8760
CRUSH 570073 4460875 0.06 0.26 8760
DAQE- MN161890001-24
Page 5
SCREENS 569910 4460957 0.16 0.70 8760
DISAREA 569745 4460896 0.41 1.80 8760
MINEEXCAV 570157 4460882 0.05 0.22 8760
MINERD 570119 4460781 0.11 0.48 8760
LDERDRY 569803 4461059 0.03 0.13 8760
LDERCRSH 570048 4460841 0.05 0.22 8760
TPWP 569997 4460905 0.05 0.22 8760
RJTRMNRD 569870 4460962 0.03 0.13 8760
PILE4 569983 4460808 0.02 0.09 8760
REJTTRSF 569874 4460963 0.01 0.04 8760
DRYPLNT 569738 4461045 0.05 0.22 8760
BLAST 570415 4460697 0.51 2.23 8760
DOME2 569710 4461091 0.01 0.02 8760
DOME1 569681 4461062 0.01 0.02 8760

Total 4.78 20.94
SCL Sandco, LLC – Anderson Sand Mine
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
DRYER 569768 4461031 6.90 30.22 8760
BLAST 570415 4460697 6.48 10.64 3285

Total 13.38 40.87
Uinta Wax Operating, LLC – Zager Booster Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
COMP1 579793 4440973 2.93 12.83 8760
COMP2 579794 4440965 2.93 12.83 8760
GEN1 579781 4441010 0.26 1.14 8760
COMBST 575582 4459169 0.46 2.01 8760
UFLARE 579882 4441012 0.02 0.08 8760
TNKHEAT 579790 4440911 0.05 0.21 8760

Total 6.65 29.11

DAQE- MN161890001-24
Page 6
XCL AssetCo, LLC – Patry Booster Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
COMBST 575582 4459169 0.46 2.01 8760
ENG1 575619 4459112 1.52 6.66 8760
ENG2 575609 4459117 1.52 6.66 8760
ENG3 575598 4459123 1.52 6.66 8760

Total 5.02 21.99
Crusoe Energy Systems – Osguthorpe Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
EU01 576128 4457887 0.83 3.64 8760
EU02 576128 4457869 0.83 3.64 8760
EU03 576128 4457851 0.83 3.64 8760
EU04 576128 4457833 0.83 3.64 8760
EU05 576128 4457815 0.83 3.64 8760
EU06 576202 4457887 0.83 3.64 8760
EU07 576202 4457869 0.83 3.64 8760
EU08 576202 4457851 0.83 3.64 8760
EU09 576202 4457833 0.83 3.64 8760
EU10 576202 4457815 0.83 3.64 8760

Total 8.30 36.35
Crusoe Energy Systems – Residue Booster
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
RES01 572727 4457532 0.83 3.64 8760
RES02 572727 4457514 0.83 3.64 8760
RES03 572727 4457496 0.83 3.64 8760
RES04 572727 4457478 0.83 3.64 8760
RES05 572727 4457460 0.83 3.64 8760
RES06 572801 4457532 0.83 3.64 8760
RES07 572801 4457514 0.83 3.64 8760
DAQE- MN161890001-24
Page 7
RES08 572801 4457496 0.83 3.64 8760
RES09 572801 4457478 0.83 3.64 8760
RES10 572801 4457460 0.83 3.64 8760

Total 8.30 36.35
Crusoe Energy Systems – Myton Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
SRC00041 576596 4444511 0.83 3.64 8760
SRC00042 576596 4444493 0.83 3.64 8760
SRC00043 576596 4444456 0.83 3.64 8760
SRC00044 576596 4444438 0.83 3.64 8760
SRC00045 576512 4444511 0.83 3.64 8760
SRC00046 576512 4444493 0.83 3.64 8760
SRC00047 576512 4444474 0.83 3.64 8760
SRC00048 576512 4444456 0.83 3.64 8760
SRC00049 576512 4444438 0.83 3.64 8760
SRC00050 576596 4444474 0.83 3.64 8760

Total 8.30 36.35
Crusoe Energy Systems – West Lateral Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
WLAT01 562442 4452957 0.83 3.64 8760
WLAT02 562461 4452957 0.83 3.64 8760
WLAT03 562479 4452957 0.83 3.64 8760
WLAT04 562497 4452957 0.83 3.64 8760
WLAT05 562515 4452957 0.83 3.64 8760
WLAT06 562442 4452867 0.83 3.64 8760
WLAT07 562461 4452867 0.83 3.64 8760
WLAT08 562479 4452867 0.83 3.64 8760
WLAT09 562497 4452867 0.83 3.64 8760
WLAT10 562515 4452867 0.83 3.64 8760

Total 8.30 36.35
DAQE- MN161890001-24
Page 8
Crusoe Energy Systems – Mullins Tap Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
MULL01 578212 4452907 0.83 3.64 8760
MULL02 578230 4452907 0.83 3.64 8760
MULL03 578248 4452907 0.83 3.64 8760
MULL04 578266 4452907 0.83 3.64 8760
MULL05 578285 4452907 0.83 3.64 8760
MULL06 578212 4452819 0.83 3.64 8760
MULL07 578230 4452819 0.83 3.64 8760
MULL08 578248 4452819 0.83 3.64 8760
MULL09 578266 4452819 0.83 3.64 8760
MULL10 578285 4452819 0.83 3.64 8760

Total 8.30 36.35
Crusoe Energy Systems - Duchesne Data Center Power Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
TURBINE 567796 4460080 13.33 58.40 8760
GEN1 567878 4460114 0.83 3.62 8760
GEN2 567878 4460095 0.83 3.62 8760
GEN3 567879 4460077 0.83 3.62 8760
GEN4 567879 4460060 0.83 3.62 8760
GEN5 567879 4460040 0.83 3.62 8760
GEN6 567951 4460114 0.83 3.62 8760
GEN7 567951 4460095 0.83 3.62 8760
GEN8 567952 4460077 0.83 3.62 8760
BOOST1 567793 4460065 0.17 0.76 8760
BOOST2 567793 4460048 0.17 0.76 8760
REB1 567757 4460042 0.05 0.24 8760
REB2 567763 4460047 0.05 0.24 8760
EGEN1 567879 4460019 2.45 10.73 100
EGEN2 567879 4460011 2.45 10.73 100
GEN9 567952 4460058 0.83 3.62 8760
GEN10 567952 4460041 0.83 3.62 8760

DAQE- MN161890001-24
Page 9
Total 26.95 96.80
Ovinitive USA Inc. – Pleasant Valley Compressor Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
ENGINE1 576727 4444313 2.95 12.92 8760
ENGINE2 576718 4444313 2.95 12.92 8760
ENGINE3 576700 4444313 2.95 12.92 8760
FLARE 576669 4444216 0.09 0.39 8760
HEATER 576716 4444266 0.09 0.40 8760
REBOILER 576748 4444267 0.13 0.55 8760
ENGINE4 576709 4444313 2.95 12.92 8760
TNKHTR1 576789 4444273 0.02 0.07 8760
TNKHTR2 576790 4444268 0.02 0.07 8760
INCINER 576788 4444251 0.47 2.06 8760
ENGINE5 576735 4444313 2.95 12.92 8760
PVGEN 576747 4444333 0.14 0.61 8760
TNKHTR3 576790 4444263 0.02 0.07 8760
TNKHTR4 576790 4444258 0.02 0.07 8760

Total 15.73 68.89
Kinder Morgan Compressor Stations
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
CUMUL1 564020 4467280 78.19 342.48 8760
CUMUL2 551427 4463055 74.10 324.54 8760
CUMUL3 548123 4457879 93.45 409.33 8760

Total 245.74 1076.36

DAQE- MN161890001-24
Page 10
10. Source Location and Parameters
Source Type
Source Parameters
Elev, Ht Temp Flow Dia
(ft) (m) (ft) (K) (m/s) (ft)
C_1 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_2 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_3 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_4 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_5 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_6 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_7 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_8 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_9 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_10 POINT 5089.0 12.2 40.0 866 38.20 0.36
H_1 POINT 5089.0 6.1 20.0 589 3.24 0.25
FL_1 POINT 5089.0 18.3 60.0 1273 20.00 0.36
COM_1 POINT 5089.0 3.7 12.0 1255 4.41 0.51
COM_2 POINT 5089.0 3.7 12.0 1255 0.92 0.51
H_2 POINT 5089.0 6.1 20.0 589 3.24 0.25
GEN1AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN2AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN3AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN4AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN5AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN6AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN7AG POINT 5416.7 7.0 23.0 738 26.49 0.51
C1 POINT 5956.9 7.6 25.0 866 38.20 0.36
C2 POINT 5958.1 7.6 25.0 866 38.20 0.36
C3 POINT 5958.9 7.6 25.0 866 38.20 0.36
CMB1 POINT 5954.9 3.7 12.0 1255 2.41 0.51
REB1 POINT 5961.0 7.6 25.0 589 3.24 0.25
CMB2 POINT 5961.9 3.7 12.0 1255 2.41 0.51
FLARE POINT 5962.2 18.3 60.0 1273 20.00 0.36
KMC1 POINT 5869.6 9.6 31.5 616 0.78 0.40
KMC2 POINT 5870.3 9.1 30.0 700 21.19 0.30
KMC3 POINT 5871.4 9.1 30.0 700 26.98 0.30
KMWESTC1 POINT 6640.9 9.1 30.0 700 21.18 0.30
KMWESTC2 POINT 6639.1 9.1 30.0 700 21.18 0.30
DAQE- MN161890001-24
Page 11
C4 POINT 5958.9 7.6 25.0 866 38.20 0.36
DRYER POINT 5902.6 11.7 38.2 422 16.09 1.37
BLAST AREA_POLY 5897.2 0.0 0.0
COMBST POINT 5355.4 7.7 25.3 922 0.03 1.22
ENG1 POINT 5350.7 3.3 10.7 741 45.01 0.30
ENG2 POINT 5351.5 3.3 10.7 741 45.01 0.30
ENG3 POINT 5352.2 3.3 10.7 741 45.01 0.30
EU01 POINT 5307.9 7.6 25.0 861 56.60 0.33
EU02 POINT 5307.6 7.6 25.0 861 56.60 0.33
EU03 POINT 5307.9 7.6 25.0 861 56.60 0.33
EU04 POINT 5306.2 7.6 25.0 861 56.60 0.33
EU05 POINT 5304.3 7.6 25.0 861 56.60 0.33
EU06 POINT 5304.7 7.6 25.0 861 56.60 0.33
EU07 POINT 5305.2 7.6 25.0 861 56.60 0.33
EU08 POINT 5304.8 7.6 25.0 861 56.60 0.33
EU09 POINT 5302.7 7.6 25.0 861 56.60 0.33
EU10 POINT 5300.8 7.6 25.0 861 56.60 0.33
CUMUL1 POINT 6107.2 9.5 31.0 700 21.19 0.31
TURBINE POINT 5825.4 12.2 40.0 765 46.40 1.83
GEN8 POINT 5821.1 7.6 25.0 861 56.60 0.33
BOOST1 POINT 5823.7 7.6 25.0 944 16.47 0.33
BOOST2 POINT 5821.7 7.6 25.0 944 16.47 0.33
REB2 POINT 5822.4 5.5 18.0 450 6.10 0.30
EGEN1 POINT 5823.6 5.5 18.0 765 16.73 0.46
EGEN2 POINT 5820.9 5.5 18.0 765 16.73 0.46
GEN9 POINT 5820.3 7.6 25.0 861 56.60 0.33
GEN10 POINT 5818.8 7.6 25.0 861 56.60 0.33
RES01 POINT 5448.7 7.6 25.0 861 56.60 0.33
RES02 POINT 5448.6 7.6 25.0 861 56.60 0.33
RES03 POINT 5448.3 7.6 25.0 861 56.60 0.33
RES04 POINT 5447.9 7.6 25.0 861 56.60 0.33
RES05 POINT 5447.9 7.6 25.0 861 56.60 0.33
RES06 POINT 5446.0 7.6 25.0 861 56.60 0.33
RES07 POINT 5445.6 7.6 25.0 861 56.60 0.33
RES08 POINT 5445.0 7.6 25.0 861 56.60 0.33
RES09 POINT 5444.4 7.6 25.0 861 56.60 0.33
RES10 POINT 5444.1 7.6 25.0 861 56.60 0.33
WLAT01 POINT 5477.6 7.6 25.0 861 56.60 0.33
WLAT02 POINT 5476.7 7.6 25.0 861 56.60 0.33
WLAT03 POINT 5476.2 7.6 25.0 861 56.60 0.33
DAQE- MN161890001-24
Page 12
WLAT04 POINT 5476.4 7.6 25.0 861 56.60 0.33
WLAT05 POINT 5477.0 7.6 25.0 861 56.60 0.33
WLAT06 POINT 5488.1 7.6 25.0 861 56.60 0.33
WLAT07 POINT 5487.7 7.6 25.0 861 56.60 0.33
WLAT08 POINT 5487.5 7.6 25.0 861 56.60 0.33
WLAT09 POINT 5486.5 7.6 25.0 861 56.60 0.33
WLAT10 POINT 5484.9 7.6 25.0 861 56.60 0.33
ENGINE1 POINT 5375.5 15.8 52.0 806 58.16 0.30
ENGINE2 POINT 5375.5 15.8 52.0 806 58.16 0.30
ENGINE3 POINT 5375.4 15.8 52.0 806 58.16 0.30
HEATER POINT 5375.8 3.0 10.0 373 3.80 0.15
REBOILER POINT 5375.7 3.0 10.0 373 3.80 0.15
ENGINE4 POINT 5375.5 15.8 52.0 730 49.71 0.30
TNKHTR1 POINT 5375.5 6.1 20.0 373 3.80 0.15
TNKHTR2 POINT 5375.5 6.1 20.0 373 3.80 0.15
INCINER POINT 5375.6 6.1 20.0 981 1.92 1.22
ENGINE5 POINT 5375.5 15.8 52.0 806 58.16 0.30
PVGEN POINT 5374.0 2.4 8.0 704 28.46 0.15
TNKHTR3 POINT 5375.5 6.1 20.0 373 3.80 0.15
TNKHTR4 POINT 5375.5 6.1 20.0 373 3.80 0.15
SRC00041 POINT 5365.5 7.6 25.0 861 56.60 0.33
SRC00042 POINT 5366.2 7.6 25.0 861 56.60 0.33
SRC00043 POINT 5368.3 7.6 25.0 861 56.60 0.33
SRC00044 POINT 5369.9 7.6 25.0 861 56.60 0.33
SRC00045 POINT 5366.2 7.6 25.0 861 56.60 0.33
SRC00046 POINT 5366.7 7.6 25.0 861 56.60 0.33
SRC00047 POINT 5367.5 7.6 25.0 861 56.60 0.33
SRC00048 POINT 5368.8 7.6 25.0 861 56.60 0.33
SRC00049 POINT 5370.3 7.6 25.0 861 56.60 0.33
SRC00050 POINT 5366.9 7.6 25.0 861 56.60 0.33
MULL01 POINT 5270.6 7.6 25.0 861 56.60 0.33
MULL02 POINT 5269.8 7.6 25.0 861 56.60 0.33
MULL03 POINT 5268.7 7.6 25.0 861 56.60 0.33
MULL04 POINT 5267.4 7.6 25.0 861 56.60 0.33
MULL05 POINT 5266.0 7.6 25.0 861 56.60 0.33
MULL06 POINT 5260.5 7.6 25.0 861 56.60 0.33
MULL07 POINT 5259.6 7.6 25.0 861 56.60 0.33
MULL08 POINT 5259.0 7.6 25.0 861 56.60 0.33
MULL09 POINT 5258.7 7.6 25.0 861 56.60 0.33
MULL10 POINT 5258.3 7.6 25.0 861 56.60 0.33
DAQE- MN161890001-24
Page 13
COMP1 POINT 5329.8 7.3 24.0 718 57.88 0.36
COMP2 POINT 5331.1 7.3 24.0 718 57.88 0.36
UFLARE POINT 5325.1 21.3 70.0 811 96.81 0.30
TNKHEAT POINT 5341.6 6.1 20.0 373 3.80 0.15

IV. RESULTS AND CONCLUSIONS

A. 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 81.9 7.5 31.4 20.6 133.9 188 71.2%
Annual 3.9 1.0 37.5 1.3 34.9 100 34.9%

JMK:jg

December 22, 2023

Mr. Bryce Bird
Utah Division of Air Quality (UDAQ)
Utah Department of Environmental Quality
195 North 1950 West
Salt Lake City, Utah 84116
Re: Notice of Intent to Construct New Natural Gas Compressor Station
Hideout Compressor Station Electronic Submittal Only
Dear Mr. Bird:
In accordance with Utah’s Administrative Code Rule R307-401, Kinder Morgan Altamont, LLC (Kinder Morgan) is submitting this Notice of Intent (NOI) to construct a new green-field natural gas compressor
station known as the “Hideout Compressor Station”.
The following equipment is proposed:
Emission Unit # Description
C-1 Inlet compressor driven by a Waukesha L7044GSI S5*
C-2 Inlet compressor driven by a Waukesha L7044GSI S5*
C-3 Inlet compressor driven by a Waukesha L7044GSI S5*
C-4 Inlet compressor driven by a Waukesha L7044GSI S5*
C-5 Inlet compressor driven by a Waukesha L7044GSI S5*
C-6 Inlet compressor driven by a Waukesha L7044GSI S5*
C-7 Inlet compressor driven by a Waukesha L7044GSI S5*
C-8 Inlet compressor driven by a Waukesha L7044GSI S5*
C-9 Inlet compressor driven by a Waukesha L7044GSI S5*
C-10 Inlet compressor driven by a Waukesha L7044GSI S5*
H-1 Heater/Boiler
H-2 Gas Fired Stabilizer Heater
DEHY TEG Dehydration Unit Process Vents (Still Vent & Flash Tank)
COM-1 Tank Combustor
COM-2 BTEX Combustor
FL-1 Flare
T-1 through T-6 (1) Gunbarrel & (5) Condensate Tanks
TRK-1 Truck Loading
LO-Tank Lube Oil Tank
ULO-Tank Used Lube Oil Tank
MT-Tank Methanol Storage Tank
50/50-Tank Antifreeze Tank (50/50)
FAB Ultra-fab H2S Removal System (closed loop)
FAB-Tank H2S Removal
PIG Pigging Emissions (Launcher/Receiver)
BLW DWN Compressor Blow Down Events
FUG-1 Fugitive – Component Leaks
*Fired with pipeline quality natural gas.

The following NOI application includes all the elements outlined in UDAQ/s NOI Completeness Checklist,
and is organized in appendices as follows:

• Appendix A: UDAQ NOI Forms
o Appendix A-1: Form 3-Process Information, Project Description, Facility Description and
Stack Parameters
o Appendix A-2: Equipment Forms
• Appendix B: Site Location Map, Simplified Process Flow Diagram
• Appendix C: Emission Calculations
• Appendix D: Facility Emission Forms
• Appendix E: Source Size Determination
• Appendix F: Offset Requirements
• Appendix G: BACT Discussion
• Appendix H: Emissions Controls
• Appendix I: Federal and State Rule Applicability
• Appendix J: Emissions Impact Analysis

Please accept this NOI application and begin processing as soon as possible; Kinder Morgan remains
ready to answer any questions or provide further information for this important project upon your
request. A check to cover the application filing fee and review fee will be mailed shortly. Please contact
me at [phone] or by email at [e-mail] if you have any questions about
this submittal.

Sincerely,

Erin Dunman Environmental Engineer
Appendix A 
UDAQ NOI Forms 
Appendix A‐1 
•Form 3 - Process Information
•Project Description 
•Facility Description
•Stack Parameters 
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):
________________
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.
36,500 MMscf/yr4.17 MMscfh
100 MMSCFD
Kinder Morgan
Hideout Compressor Station Air Application
December 6, 2023
SLR Project No.: 132.01110.0010
A-1
Appendix A Hideout Compressor Station
A.1 Project Description
Kinder Morgan Altamont LLC proposes to construct the Hideout Compressor Station which
is a new natural gas compressor station designed to compress, treat, and dehydrate up to
100 MMscfd of natural gas and generate up to 260 bpd of condensate. The facility is
designed for continuous operation (8,760 hours per year).
A.2 Facility/Process Description
The Hideout Compressor Station’s primary function will be to compress and dehydrate field
gas, as well as boosting pipeline gas. The low pressure inlet stream will consist of natural
gas from the Altamont field entering the facility via pipeline. A high pressure inlet natural gas
stream received from the Farm compressor station will be boosted by onsite compression
and sent further down the pipeline.
The incoming low pressure field gas will first be sent through a slug catcher where free
liquids are separated from the field gas. The free liquids are directed to a gunbarrel tank
where the liquid is separated into water and condensate. Separated condensate is sent to
one of five condensate tanks where it is stored until it is transported via truck load-out.
Separated water remains in the gunbarrel tank where it is removed via truck load-out.
Overhead vapors from the gunbarrel tank, condensate tanks and truck load-out system are
sent to an enclosed combustion device (COM-1).
Overhead gas from the low pressure gas slug catcher is directed to a natural gas manifold
connected to seven 3-stage compressors driven by 1,900 hp Waukesha L7044 GSI S5
natural-gas fired four-stroke rich-burn reciprocating internal combustion engines (RICE).
Fuel for the engines will be provided via pipeline from the Altamont Gas Plant, and therefore
will contain no H2S. Any liquid removed throughout the three compression stages is recycled
back to the inlet slug catcher to be captured in the gunbarrel tank. Compressed gas is
directed to a sulfur scrubbing vessel for removal of potential H2S. After treatment, the gas is
discharged to the triethylene glycol (TEG) dehydrator, equipped with a flash tank and still
vent condenser, for the removal of entrained water. Gas from the TEG dehydrator flash tank
is captured and used onsite as fuel gas. Vapors from the TEG dehydrator still vent are
directed to an atmospheric condenser from which liquids are captured in a tank and non-
condensable vapors are routed to an enclosed combustor (COM-2).
High pressure natural gas received from the Farm Compressor Station is sent through a slug
catcher to remove free liquids. Overhead gas from the slug catcher is directed to three
single-stage compressors driven by 1,900 hp Waukesha L7044 GSI S5 natural-gas fired
four-stroke rich-burn RICE. Liquids removed during compression are recycled back to the
inlet slug catcher to be captured in the gunbarrel tank. Compressed natural gas from the
single stage compression is sent through a filter separator before being discharged to the
pipeline.
The Hideout Compressor Station will be equipped with a single flare (FL-1) to manage any
unplanned pressure relief events, plant emergency shut downs, as well as equipment
depressurization during planned maintenance activities.
A.3 Units Added
The following air emission units are proposed to be added to the Facility:
Kinder Morgan
Hideout Compressor Station Air Application
December 6, 2023
SLR Project No.: 132.01110.0010
A-2
Table A.1: Hideout Compressor Station Emission Units
Emission
Unit ID
EU Description Make/Model Add-On Controls
C-1 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-2 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-3 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-4 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-5 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-6 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-7 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-8 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-9 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
C-10 Inlet Compressor 4SRB SI-ICE Waukesha 7044 GSI S5 NSCR
H-1 Heater / Reboiler TBD None
H-2 Gas Fired Stabilizer Heater TBD None
DEHY TEG Dehydration Unit Process
Vents (Still Vent & Flash Tank)
Combustor (COM-2)Combustor (COM-2)
COM-1 Tank Combustor TBD NA
COM-2 BTEX Combustor TBD NA
FL-1 Flare TBD NA
T-1 through
T-6
(1) Gunbarrel & (5) Condensate
Tanks
NA Combustor (COM-1)
TRK-1 Truck Loading NA Combustor (COM-1)
LO-Tank Lube Oil Tank NA None
ULO-Tank Used Lube Oil Tank NA None
MT-Tank Methanol Storage Tank NA None
50/50-Tank Antifreeze Tank (50/50)NA None
FAB Ultra-fab H2S Removal System
(closed loop)
NA NA
FAB-Tank H2S Removal NA NA
PIG Pigging Emissions
(Launcher/Receiver)
NA FL-1
BLW DWN Compressor Blow Down Events NA FL-1
FUG-1 Fugitive - Component Leaks NA NA
All proposed fuel-burning devices will be fired with pipeline quality natural gas. Note that a
relatively small amount of gas recovered from the TEG dehydrator flash tank will be used
onsite as fuel gas.
Kinder Morgan
Hideout Compressor Station Air Application
December 6, 2023
SLR Project No.: 132.01110.0010
A-3
A.4 Raw Materials and Fuel Used
This proposed equipment constitutes a natural gas compression process designed to
remove free liquids and entrained water from the incoming field gas. All combustion
equipment at the facility will use pipeline quality natural gas.
No bulk commercial raw materials are used in this process.
Kinder Morgan
Hideout Compressor Station Air Application
December 6, 2023
SLR Project No.: 132.01110.0010
A-4
A.5 Stack Parameters
All of the specific stack information for each proposed combustion emissions unit is summarized in Table A-2 below.
Table A.2: Emission Unit Stack Parameters
Stack/Exhaust Parameters
Emission
Unit ID
Emission
Unit
Direction Capped?Height
Above
Grade
Diameter Flow
(ACFM)
Velocity
(ft/s)
Temperature Easting Northing
C-1 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585022.19 4453074.75
C-2 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585038.31 4453074.78
C-3 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585054.62 4453074.61
C-4 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585070.87 4453074.55
C-5 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585087.31 4453074.09
C-6 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585103.40 4453074.06
C-7 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585119.71 4453074.71
C-8 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585136.04 4453074.77
Kinder Morgan
Hideout Compressor Station Air Application
December 6, 2023
SLR Project No.: 132.01110.0010
A-5
Stack/Exhaust Parameters
C-9 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585152.32 4453074.59
C-10 Inlet
Compressor
4SRB SI-ICE
Vertical No 40.0 ft 1.167 ft 8,043
acfm
125.32 1100° F 585168.57 4453074.63
H-1 NG Heater -
Dehy TEG
Reboiler
Vertical No 20.0 ft 0.83 ft 345 acfm 10.63 600° F 585106.81 4453148.26
H-2 NG Heater -
Stabilizer
Vertical No 20.0 ft 0.83 ft 345 acfm 10.63 600° F 585107.60 4453166.93
COM-1 Enclosed
Combustor
(All Tanks)
Vertical No 12 ft 1.67 ft 1,894
acfm
14.47 1800° F 584995.88 4453071.98
COM-2 Enclosed
Combustor
(BTEX Unit)
Vertical No 12 ft 1.67 ft 393 acfm 3.00 1800° F 585111.12 4453158.33
FL-1 Flare
(Repairs,
Maintenance,
Emergency)
Vertical No 60.0 ft 1.17 ft N/A N/A N/A 585178.02 4453160.93
Appendix A‐2 
Equipment Forms
1.C-1 - 7044GSI Inlet Compressor (Form 11)
2.C-2 - 7044GSI Inlet Compressor (Form 11)
3.C-3 - 7044GSI Inlet Compressor (Form 11)
4.C-4 - 7044GSI Inlet Compressor (Form 11)
5.C-5 - 7044GSI Inlet Compressor (Form 11)
6.C-6 - 7044GSI Inlet Compressor (Form 11)
7. C-7 - 7044GSI Inlet Compressor (Form 11)
8. C-8 - 7044GSI Inlet Compressor (Form 11)
9. C-9 - 7044GSI Inlet Compressor (Form 11)
10. C-10 - 7044GSI Inlet Compressor (Form 11)
11.Waukesha 7044 GSI S5 Manufacturer's Data
12. Dehy - TEG Regenerator Still Vent (Form 2)
13. H-1 - TEG Reboiler Heater (Form 19)
14. H-2 - Stabilizer Heater (Form 19)
15. LO-Tank - Fresh Lube Oil Tank (Form 20)
16. ULO-Tank - Used Lube Oil Tank (Form 20)
17. T-1 through T-6 - Gunbarrel & Condensate Storage Tanks (Form 20)
18. MT-Tank Methanol Tank (Form 20)
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-1
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
C-1 Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
585022.19 4453074.75
5090
1.26 12 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-2
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-2
5090
1.26 12 585038.31 4453074.78 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-3
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-3
5090
1.26 12 585054.62 4453074.61 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-4
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-4
5090
1.26 12 585070.87 4453074.55 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-5
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-5
5090
1.26 12 585087.31 4453074.09 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-6
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-6
5090
1.26 12 585103.40 4453074.06 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-7
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-7
5090
1.26 12 585119.71 4453074.71 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-8
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-8
5090
1.26 12 585136.04 4453074.77 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-9
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-9
5090
1.26 12 585152.32 4453074.59 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
Utah Division of Air Quality
New Source Review Section Company_______________________
Site/Source_____________________
Form 11 Date___________________________
Internal Combustion Engines
Equipment Information
1. Manufacturer: __________________________
Model no.: __________________________
The date the engine was constructed or
reconstructed ________________________
2. Operating time of Emission Source:
average maximum
______ Hours/day ______ Hours/day
Days/week Days/week
______ Weeks/year ______ Weeks/year
3. Manufacturer's rated output at baseload, ISO hp or Kw
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:
_____________________________ MMSCF/Year
7. Maximum firing rate:
_____________________________ BTU/hr
8. Average firing rate:
_____________________________ 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 
Waukesha
Kinder Morgan Altamont LLC
Hideout Compressor Station
7044 GSI S5
TBD - New
24 24
7 7
52 52
1900
1900
15,448,90015,448,900
(N/A)
Engine C-10
105.68
December 19, 2023
Page 2 of 4 
Internal Combustion Engine
Form 11 (Continued)
Operation
17. Application:
□Electric generation
______ Base load ______ Peaking
□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): _______ NOX _______ CO ______ VOC
_______ Formaldehyde
20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O
for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed
operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual
emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions
in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected
to dry, 15% oxygen conditions.
Method of Emission Control:
□Lean premix combustors □Oxidation catalyst □ Water injection □ 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.
NSCR
Emissions shown are controlled
0.3 0.3 0.3
0.02
Page 3 of 4 
INSTRUCTIONS – Form 11 Internal Combustion Engine
NOTE: 1. Submit this form in conjunction with Form 1 and Form 2.
2.Call the Division of Air Quality (DAQ) at [phone] if you have problems or questions in
filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help!
1.Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed.
2.Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per
week, and weeks per year.
3.Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard
Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site
operating range is in megawatts or horsepower.
4. Indicate the origin of the gas used in the engine.
5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens.
6.Specify what the annual consumption of fuel is in million standard cubic feet (MMscf).
7. Supply the maximum firing rate in BTU/hr.
8. Supply the average firing rate in BTU/hr.
9. Indicate the grade of oil being used.
10.Supply the annual consumption calculated in gallons of oil.
11. Indicate the heat content of the oil in BTU/lb or BTU/gal.
12. Indicate the sulfur content of the oil in percent by weight.
13. Indicate the ash content of the oil.
14. Supply the average firing rate of oil.
15. Supply the maximum firing rate of oil.
16. Indicate what the firing direction is.
17. Indicate what the engine will be used for.
18.Indicate what type of cycle the engine will have.
19. Indicate the manufacturer’s emissions rate in grams/hp-hr
20.Provide manufacturer's emission information for the engine. Also indicate what method of emission control to
be used.
21.Provide details of the operation of emission controls and exhaust parameter information.
f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc
Revised 12/20/10
Page 4 of 4 
INTERNAL COMBUSTION ENGINE
FORM 11 (continued)
EMISSION SOURCES
Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form.
AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS
STACK SOURCES (7) EMISSION POINT
(1)
CHEMICAL COMPOSITION
OF TOTAL STREAM
AIR
CONTAMINANT
EMISSION RATE
UTM COORDINATES OF
EMISSION PT. (6) EXIT DATA
NUMBER NAME
COMPONENT OR AIR
CONTAMINANT NAME
(2)
CONC.
(%V) (3)
LB/HR
(4)
TONS/YR
(5)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT
ABOVE
GROUND
(FT)
HEIGHT
ABOVE
STRUCT.
(FT)
DIA.
(FT)
VELO.
(FPS)
TEMP.
(OF)

GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet.
UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA.
General Instructions for this form.
1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each
emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK.
2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK.
3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream.
4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant.
5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule.
6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned
with respect to the benchmark. Please show emission point UTM coordinates if known.
7. Supply additional information as follows if appropriate:
(a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note.
(b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack.
Inlet Comp.NOx
CO
VOC
HCHO
PM10
PM2.5
SO2
5.5
5.57
5.5
0.37
0.64
0.64
0.04
C-10
5090
1.26 12 585168.57 4453074.63 40 12 1.167 125.3 1100
1.27
1.26
0.0838
0.147
0.147
0.00908
VHP - L7044GSI S5
Gas Compression
ENGINE SPEED (rpm):1200 NOx SELECTION (g/bhp-hr):
DISPLACEMENT (in3):7040 COOLING SYSTEM:JW, IC + OC
COMPRESSION RATIO:9.7:1 INTERCOOLER WATER INLET (°F):130
IGNITION SYSTEM:ESM2 JACKET WATER OUTLET (°F):180
EXHAUST MANIFOLD:Water Cooled JACKET WATER CAPACITY (gal):100
COMBUSTION:Rich Burn, Turbocharged AUXILIARY WATER CAPACITY (gal):11
ENGINE DRY WEIGHT (lbs):24250 LUBE OIL CAPACITY (gal):190
AIR/FUEL RATIO SETTING:0.38% CO MAX. EXHAUST BACKPRESSURE (in. H2O):20
ENGINE SOUND LEVEL (dBA)102.7 MAX. AIR INLET RESTRICTION (in. H2O):15
IGNITION TIMING:ESM2 Controlled EXHAUST SOUND LEVEL (dBA)98.9
SITE CONDITIONS:
FUEL:Fuel Gas ALTITUDE (ft):5175
FUEL PRESSURE RANGE (psig):43 - 60 MAXIMUM INLET AIR TEMPERATURE (°F):105
FUEL HHV (BTU/ft3):1,122.7 FUEL WKI:77.0
FUEL LHV (BTU/ft3):1,014.9
SITE SPECIFIC TECHNICAL DATA
UNITS SITE DATA
(See note 18)100%75%52%
CONTINUOUS ENGINE POWER BHP 1825 1814 1360 950
OVERLOAD % 2/24 hr 0 0 --
MECHANICAL EFFICIENCY (LHV)%34.7 34.6 33.8 32.1
CONTINUOUS POWER AT FLYWHEEL BHP 1825 1814 1360 950
based on no auxiliary engine driven equipment
RPM
FUEL CONSUMPTION (LHV)BTU/BHP-hr 7341 7350 7524 7937
FUEL CONSUMPTION (HHV)BTU/BHP-hr 8121 8131 8323 8780
FUEL FLOW based on fuel analysis LHV SCFM 220 219 168 124
JACKET WATER (JW)BTU/hr x 1000 3703 3706 2944 2266
LUBE OIL (OC)BTU/hr x 1000 479 478 425 369
INTERCOOLER (IC)BTU/hr x 1000 741 751 436 209
EXHAUST BTU/hr x 1000 3523 3487 2633 1912
RADIATION BTU/hr x 1000 568 553 533 515
NOx (NO + NO2)g/bhp-hr 11.5 11.6 12.6 12.9
CO g/bhp-hr 9.0 9.0 9.0 9.3
THC g/bhp-hr 0.3 0.3 0.5 0.8
NMHC g/bhp-hr 0.08 0.08 0.13 0.18
NM,NEHC (VOC)g/bhp-hr 0.02 0.02 0.03 0.04
CO2 g/bhp-hr 458 458 469 495
CO2e g/bhp-hr 464 465 479 509
CH2O g/bhp-hr 0.050 0.050 0.050 0.050
CH4 g/bhp-hr 0.26 0.26 0.41 0.57
INDUCTION AIR FLOW SCFM 2508 2495 1915 1412
EXHAUST GAS MASS FLOW lb/hr 11658 11600 8905 6564
EXHAUST GAS FLOW at exhaust temp, 14.5 psia ACFM 8088 8043 6095 4440
EXHAUST TEMPERATURE °F 1101 1100 1080 1062
TOTAL JACKET WATER CIRCUIT (JW)BTU/hr x 1000 4203
TOTAL AUXILIARY WATER CIRCUIT (IC + OC)BTU/hr x 1000 1395
JACKET WATER PUMP MIN. DESIGN FLOW GPM 450
JACKET WATER PUMP MAX. EXTERNAL RESTRICTION psig 16
AUX WATER PUMP MIN. DESIGN FLOW GPM 79
AUX WATER PUMP MAX. EXTERNAL RESTRICTION psig 36
AIR INTAKE / EXHAUST GAS
HEAT EXCHANGER SIZING12
Customer Catalyst
MAX RATING
AT 100 °F
AIR TEMP
950 - 1200AVAILABLE TURNDOWN SPEED RANGE
SITE RATING AT MAXIMUM INLET AIR
TEMPERATURE OF 105 °F
POWER RATING
FUEL CONSUMPTION
COOLING SYSTEM WITH ENGINE MOUNTED WATER PUMPS
HEAT REJECTION
EMISSIONS (ENGINE OUT):
All data provided per the condtions listed in the notes section on page three.
Data Generated by EngCalc Program Version 4.0 INNIO Waukesha Gas Engines, Inc.
10/17/2019 1:48 PM Page 1 of 3
Pre-Catalyst
VHP - L7044GSI S5
Gas Compression
FUEL COMPOSITION
HYDROCARBONS:Mole or Volume %FUEL:Fuel Gas
Methane CH4 85.186 FUEL PRESSURE RANGE (psig):43 - 60
Ethane C2H6 11.325 FUEL WKI:77.0
Propane C3H8 1.9193
Iso-Butane I-C4H10 0.121 FUEL SLHV (BTU/ft3):997.24
Normal Butane N-C4H10 0.1668 FUEL SLHV (MJ/Nm3):39.22
Iso-Pentane I-C5H12 0.0151
Normal Pentane N-C5H12 0.0122 FUEL LHV (BTU/ft3):1014.90
Hexane C6H14 0.0013 FUEL LHV (MJ/Nm3):39.91
Heptane C7H16 0
Ethene C2H4 0 FUEL HHV (BTU/ft3):1122.68
Propene C3H6 0 FUEL HHV (MJ/Nm3):44.15
SUM HYDROCARBONS 98.747 FUEL DENSITY (SG):0.64
NON-HYDROCARBONS:
Nitrogen N2 0.4494
Oxygen O2 0
Helium He 0
Carbon Dioxide CO2 0.8041
Carbon Monoxide CO 0
Hydrogen H2 0
Water Vapor H2O 0
TOTAL FUEL 100
FUEL CONTAMINANTS
Total Sulfur Compounds % volume Total Sulfur Compounds 0 µg/BTU
Total Halogen as Cloride % volume Total Halogen as Cloride 0 µg/BTU
Total Ammonia % volume Total Ammonia 0 µg/BTU
Siloxanes Total Siloxanes (as Si)0 µg/BTU
Tetramethyl silane 0 % volume
Trimethyl silanol 0 % volume
Hexamethyldisiloxane (L2)0 % volume
Hexamethylcyclotrisiloxane (D3)0 % volume
Octamethyltrisiloxane (L3)0 % volume
Octamethylcyclotetrasiloxane (D4)0 % volume
Decamethyltetrasiloxane (L4)0 % volume
Decamethylcyclopentasiloxane (D5)0 % volume
Dodecamethylpentasiloxane (L5)0 % volume
Dodecamethylcyclohexasiloxane (D6)0 % volume
Others 0 % volume
No water or hydrocarbon condensates are allowed in the engine. Requires liquids removal.
0
0
Standard Conditions per ASTM D3588-91 [60°F and 14.696psia] and
ISO 6976:1996-02-01[25, V(0;101.325)].
Based on the fuel composition, supply pressure and temperature, liquid
hydrocarbons may be present in the fuel. No liquid hydrocarbons are
allowed in the fuel. The fuel must not contain any liquid water. Waukesha
recommends both of the following:
1) Dew point of the fuel gas to be at least 20°F (11°C) below the
measured temperature of the gas at the inlet of the engine fuel regulator.
2) A fuel filter separator to be used on all fuels except commercial quality
natural gas.
Refer to the 'Fuel and Lubrication' section of 'Technical Data' or contact
the Waukesha Application Engineering Department for additional
information on fuels, or LHV and WKI* calculations.
* Trademark of INNIO Waukesha Gas Engines Inc.
Calculated fuel contaminant analysis will depend on
the entered fuel composition and selected engine
model.
0
All data provided per the condtions listed in the notes section on page three.
Data Generated by EngCalc Program Version 4.0 INNIO Waukesha Gas Engines, Inc.
10/17/2019 1:48 PM Page 2 of 3
VHP - L7044GSI S5
Gas Compression
NOTES
SPECIAL REQUIREMENTS
20. In cold ambient temperatures, heating of the engine jacket water, lube oil and combustion air may be required. See Waukesha Technical Data.
18. Continuous Power Rating: The highest load and speed that can be applied 24 hours per day, seven days per week, 365 days per year except for normal
maintenance at indicated ambient reference conditions and fuel. No engine overload power rating is available.
19. emPact emission compliance available for entire range of operable fuels; however, fuel system and/or O2 set point may need to be adjusted in order to
maintain compliance.
12. Heat exchanger sizing values given as the maximum heat rejection of the circuit, with applied tolerances and an additional 5% reserve factor.
10. Cooling circuit capacity, lube oil capacity, and engine dry weight values are typical.
16. Due to variation between test conditions and final site conditions, such as exhaust configuration and background sound level, sound pressure levels under
site conditions may be different than those tabulated above.
6. Air flow is based on undried air with a tolerance of ± 7%.
15. Engine sound data taken with the microphone at 1 m (3.3 ft) from the side of the engine at the approximate front-to-back centerline. Microphone height was
at intake manifold level. Engine sound pressure data may be different at front, back and opposite side locations. Exhaust sound data taken with microphone 1
meter (3.3 ft) away and 1 meter (3.3 ft) to the side of the exhaust outlet.
3. Fuel consumption is presented in accordance with ISO 3046/1 with a tolerance of -0 / +5% at maximum rating. Fuel flow calculation based on fuel LHV and
fuel consumption with a tolerance of -0/+5 %. For sizing piping and fuel equipment, it is recommended to include the 5% tolerance.
1. All data is based on engines with standard configurations unless noted otherwise.
9. Inlet air restrictions based on full rated engine load. Exhaust backpressure based on 178.1 PSI BMEP and 1200 RPM. Refer to the engine specification
section of Waukesha's standard technical data for more information.
17. Cooling system design flow is based on minimum allowable cooling system flow. Cooling system maximum external restriction is defined as the allowable
restriction at the minimum cooling system flow.
5. Emission levels for engines with Waukesha supplied 3-way catalyst are given at catalyst outlet flange. For all other engine models, emission levels are given
at engine exhaust outlet flange prior to any after treatment. Values are based on a new engine operating at indicated site conditions, and adjusted to the
specified timing and air/fuel ratio at rated load. Catalyst out emission levels represent emission levels the catalyst is sized to achieve. Manual adjustment may
be necessary to achieve compliance as catalyst/engine age. Catalyst-out emission levels are valid for the duration of the engine warranty. Emissions are at
an absolute humidity of 75 grains H2O/lb (10.71 g H2O/kg) of dry air. Emission levels may vary subject to instrumentation, measurement, ambient conditions,
fuel quality, and engine variation. Engine may require adjustment on-site to meet emission values, which may affect engine performance and heat output.
NOx, CO, THC, and NMHC emission levels are listed as a not to exceed limit, all other emission levels are estimated. CO2 emissions based on EPA Federal
Register/Vol. 74, No. 209/Friday, October 30, 2009 Rules and Regulations 56398, 56399 (3) Tier 3 Calculation Methodology, Equation C-5.
4. Heat rejection tolerances are ± 30% for radiation, and ± 8% for jacket water, lube oil, intercooler, and exhaust energy.
7. Exhaust temperature given at engine exhaust outlet flange with a tolerance of ± 50°F (28°C).
8. Exhaust gas mass flow value is based on a "wet basis" with a tolerance of ± 7%.
14. Fuel volume flow calculation in metric units is based on 100% relative humidity of the fuel gas at a combustion temperature of 25°C and metering
conditions of 0°C and 101.325 kPa (14.696 psia; 29.92 inches of mercury). This is expressed as [25, V(0;101.325)].
11. Fuel must conform to Waukesha's "Gaseous Fuel Specification" S7884-7 or most current version. Fuel may require treatment to meet current fuel
specification.
2. Power rating is adjusted for fuel, site altitude, and site air inlet temperature, in accordance with ISO 3046/1 with tolerance of ± 3%.
13. Fuel volume flow calculation in english units is based on 100% relative humidity of the fuel gas at standard conditions of 60°F and 14.696 psia (29.92
inches of mercury; 101.325 kPa).
21. Available Turndown Speed Range refers to the constant torque speed range available. Reduced power may be available at speeds outside of this range.
Contact application engineering.
All data provided per the condtions listed in the notes section on page three.
Data Generated by EngCalc Program Version 4.0 INNIO Waukesha Gas Engines, Inc.
10/17/2019 1:48 PM Page 3 of 3
VHP - L7044GSI S5
Gas Compression
ENGINE SPEED (rpm):1200 NOx SELECTION (g/bhp-hr):
DISPLACEMENT (in3):7040 COOLING SYSTEM:JW, IC + OC
COMPRESSION RATIO:9.7:1 INTERCOOLER WATER INLET (°F):130
IGNITION SYSTEM:ESM2 JACKET WATER OUTLET (°F):180
EXHAUST MANIFOLD:Water Cooled JACKET WATER CAPACITY (gal):100
COMBUSTION:Rich Burn, Turbocharged AUXILIARY WATER CAPACITY (gal):11
ENGINE DRY WEIGHT (lbs):24250 LUBE OIL CAPACITY (gal):190
AIR/FUEL RATIO SETTING:0.38% CO MAX. EXHAUST BACKPRESSURE (in. H2O):20
ENGINE SOUND LEVEL (dBA)102.7 MAX. AIR INLET RESTRICTION (in. H2O):15
IGNITION TIMING:ESM2 Controlled EXHAUST SOUND LEVEL (dBA)98.9
SITE CONDITIONS:
FUEL:Fuel Gas ALTITUDE (ft):5175
FUEL PRESSURE RANGE (psig):43 - 60 MAXIMUM INLET AIR TEMPERATURE (°F):105
FUEL HHV (BTU/ft3):1,122.7 FUEL WKI:77.0
FUEL LHV (BTU/ft3):1,014.9
SITE SPECIFIC TECHNICAL DATA
UNITS SITE DATA
(See note 18)100%85%79%
CONTINUOUS ENGINE POWER BHP 1825 1814 1542 1425
OVERLOAD % 2/24 hr 0 0 --
MECHANICAL EFFICIENCY (LHV)%34.7 34.6 34.3 34.0
CONTINUOUS POWER AT FLYWHEEL BHP 1825 1814 1542 1425
based on no auxiliary engine driven equipment
RPM
FUEL CONSUMPTION (LHV)BTU/BHP-hr 7341 7350 7433 7487
FUEL CONSUMPTION (HHV)BTU/BHP-hr 8121 8131 8222 8282
FUEL FLOW based on fuel analysis LHV SCFM 220 219 188 175
JACKET WATER (JW)BTU/hr x 1000 3703 3706 3248 3052
LUBE OIL (OC)BTU/hr x 1000 479 478 447 433
INTERCOOLER (IC)BTU/hr x 1000 741 751 554 477
EXHAUST BTU/hr x 1000 3523 3487 2967 2751
RADIATION BTU/hr x 1000 568 553 541 536
NOx (NO + NO2)g/bhp-hr 0.15 0.15 0.15 0.15
CO g/bhp-hr 0.3 0.3 0.3 0.3
THC g/bhp-hr 0.2 0.2 0.3 0.4
NMHC g/bhp-hr 0.06 0.06 0.08 0.09
NM,NEHC (VOC)g/bhp-hr 0.01 0.01 0.02 0.02
CO2 g/bhp-hr 471 472 477 480
CO2e g/bhp-hr 476 476 483 487
CH2O g/bhp-hr 0.001 0.001 0.001 0.001
CH4 g/bhp-hr 0.18 0.18 0.24 0.27
INDUCTION AIR FLOW SCFM 2508 2495 2144 1997
EXHAUST GAS MASS FLOW lb/hr 11658 11600 9970 9282
EXHAUST GAS FLOW at exhaust temp, 14.5 psia ACFM 8088 8043 6859 6365
EXHAUST TEMPERATURE °F 1101 1100 1088 1083
TOTAL JACKET WATER CIRCUIT (JW)BTU/hr x 1000 4203
TOTAL AUXILIARY WATER CIRCUIT (IC + OC)BTU/hr x 1000 1395
JACKET WATER PUMP MIN. DESIGN FLOW GPM 450
JACKET WATER PUMP MAX. EXTERNAL RESTRICTION psig 16
AUX WATER PUMP MIN. DESIGN FLOW GPM 79
AUX WATER PUMP MAX. EXTERNAL RESTRICTION psig 36
AIR INTAKE / EXHAUST GAS
HEAT EXCHANGER SIZING12
0.15
MAX RATING
AT 100 °F
AIR TEMP
950 - 1200AVAILABLE TURNDOWN SPEED RANGE
SITE RATING AT MAXIMUM INLET AIR
TEMPERATURE OF 105 °F
POWER RATING
FUEL CONSUMPTION
COOLING SYSTEM WITH ENGINE MOUNTED WATER PUMPS
HEAT REJECTION
EMISSIONS (CATALYST OUT):
All data provided per the condtions listed in the notes section on page three.
Data Generated by EngCalc Program Version 4.0 INNIO Waukesha Gas Engines, Inc.
10/17/2019 12:56 PM Page 1 of 3
Post-Catalyst
VHP - L7044GSI S5
Gas Compression
FUEL COMPOSITION
HYDROCARBONS:Mole or Volume %FUEL:Fuel Gas
Methane CH4 85.186 FUEL PRESSURE RANGE (psig):43 - 60
Ethane C2H6 11.325 FUEL WKI:77.0
Propane C3H8 1.9193
Iso-Butane I-C4H10 0.121 FUEL SLHV (BTU/ft3):997.24
Normal Butane N-C4H10 0.1668 FUEL SLHV (MJ/Nm3):39.22
Iso-Pentane I-C5H12 0.0151
Normal Pentane N-C5H12 0.0122 FUEL LHV (BTU/ft3):1014.90
Hexane C6H14 0.0013 FUEL LHV (MJ/Nm3):39.91
Heptane C7H16 0
Ethene C2H4 0 FUEL HHV (BTU/ft3):1122.68
Propene C3H6 0 FUEL HHV (MJ/Nm3):44.15
SUM HYDROCARBONS 98.747 FUEL DENSITY (SG):0.64
NON-HYDROCARBONS:
Nitrogen N2 0.4494
Oxygen O2 0
Helium He 0
Carbon Dioxide CO2 0.8041
Carbon Monoxide CO 0
Hydrogen H2 0
Water Vapor H2O 0
TOTAL FUEL 100
FUEL CONTAMINANTS
Total Sulfur Compounds % volume Total Sulfur Compounds 0 µg/BTU
Total Halogen as Cloride % volume Total Halogen as Cloride 0 µg/BTU
Total Ammonia % volume Total Ammonia 0 µg/BTU
Siloxanes Total Siloxanes (as Si)0 µg/BTU
Tetramethyl silane 0 % volume
Trimethyl silanol 0 % volume
Hexamethyldisiloxane (L2)0 % volume
Hexamethylcyclotrisiloxane (D3)0 % volume
Octamethyltrisiloxane (L3)0 % volume
Octamethylcyclotetrasiloxane (D4)0 % volume
Decamethyltetrasiloxane (L4)0 % volume
Decamethylcyclopentasiloxane (D5)0 % volume
Dodecamethylpentasiloxane (L5)0 % volume
Dodecamethylcyclohexasiloxane (D6)0 % volume
Others 0 % volume
No water or hydrocarbon condensates are allowed in the engine. Requires liquids removal.
0
0
Standard Conditions per ASTM D3588-91 [60°F and 14.696psia] and
ISO 6976:1996-02-01[25, V(0;101.325)].
Based on the fuel composition, supply pressure and temperature, liquid
hydrocarbons may be present in the fuel. No liquid hydrocarbons are
allowed in the fuel. The fuel must not contain any liquid water. Waukesha
recommends both of the following:
1) Dew point of the fuel gas to be at least 20°F (11°C) below the
measured temperature of the gas at the inlet of the engine fuel regulator.
2) A fuel filter separator to be used on all fuels except commercial quality
natural gas.
Refer to the 'Fuel and Lubrication' section of 'Technical Data' or contact
the Waukesha Application Engineering Department for additional
information on fuels, or LHV and WKI* calculations.
* Trademark of INNIO Waukesha Gas Engines Inc.
Calculated fuel contaminant analysis will depend on
the entered fuel composition and selected engine
model.
0
All data provided per the condtions listed in the notes section on page three.
Data Generated by EngCalc Program Version 4.0 INNIO Waukesha Gas Engines, Inc.
10/17/2019 12:56 PM Page 2 of 3
VHP - L7044GSI S5
Gas Compression
NOTES
SPECIAL REQUIREMENTS
Requires option code 1005 for 0.15g/bhp-hr catalyst.
20. In cold ambient temperatures, heating of the engine jacket water, lube oil and combustion air may be required. See Waukesha Technical Data.
18. Continuous Power Rating: The highest load and speed that can be applied 24 hours per day, seven days per week, 365 days per year except for normal
maintenance at indicated ambient reference conditions and fuel. No engine overload power rating is available.
19. emPact emission compliance available for entire range of operable fuels; however, fuel system and/or O2 set point may need to be adjusted in order to
maintain compliance.
12. Heat exchanger sizing values given as the maximum heat rejection of the circuit, with applied tolerances and an additional 5% reserve factor.
10. Cooling circuit capacity, lube oil capacity, and engine dry weight values are typical.
16. Due to variation between test conditions and final site conditions, such as exhaust configuration and background sound level, sound pressure levels under
site conditions may be different than those tabulated above.
6. Air flow is based on undried air with a tolerance of ± 7%.
15. Engine sound data taken with the microphone at 1 m (3.3 ft) from the side of the engine at the approximate front-to-back centerline. Microphone height was
at intake manifold level. Engine sound pressure data may be different at front, back and opposite side locations. Exhaust sound data taken with microphone 1
meter (3.3 ft) away and 1 meter (3.3 ft) to the side of the exhaust outlet.
3. Fuel consumption is presented in accordance with ISO 3046/1 with a tolerance of -0 / +5% at maximum rating. Fuel flow calculation based on fuel LHV and
fuel consumption with a tolerance of -0/+5 %. For sizing piping and fuel equipment, it is recommended to include the 5% tolerance.
1. All data is based on engines with standard configurations unless noted otherwise.
9. Inlet air restrictions based on full rated engine load. Exhaust backpressure based on 178.1 PSI BMEP and 1200 RPM. Refer to the engine specification
section of Waukesha's standard technical data for more information.
17. Cooling system design flow is based on minimum allowable cooling system flow. Cooling system maximum external restriction is defined as the allowable
restriction at the minimum cooling system flow.
5. Emission levels for engines with Waukesha supplied 3-way catalyst are given at catalyst outlet flange. For all other engine models, emission levels are given
at engine exhaust outlet flange prior to any after treatment. Values are based on a new engine operating at indicated site conditions, and adjusted to the
specified timing and air/fuel ratio at rated load. Catalyst out emission levels represent emission levels the catalyst is sized to achieve. Manual adjustment may
be necessary to achieve compliance as catalyst/engine age. Catalyst-out emission levels are valid for the duration of the engine warranty. Emissions are at
an absolute humidity of 75 grains H2O/lb (10.71 g H2O/kg) of dry air. Emission levels may vary subject to instrumentation, measurement, ambient conditions,
fuel quality, and engine variation. Engine may require adjustment on-site to meet emission values, which may affect engine performance and heat output.
NOx, CO, THC, and NMHC emission levels are listed as a not to exceed limit, all other emission levels are estimated. CO2 emissions based on EPA Federal
Register/Vol. 74, No. 209/Friday, October 30, 2009 Rules and Regulations 56398, 56399 (3) Tier 3 Calculation Methodology, Equation C-5.
4. Heat rejection tolerances are ± 30% for radiation, and ± 8% for jacket water, lube oil, intercooler, and exhaust energy.
7. Exhaust temperature given at engine exhaust outlet flange with a tolerance of ± 50°F (28°C).
8. Exhaust gas mass flow value is based on a "wet basis" with a tolerance of ± 7%.
14. Fuel volume flow calculation in metric units is based on 100% relative humidity of the fuel gas at a combustion temperature of 25°C and metering
conditions of 0°C and 101.325 kPa (14.696 psia; 29.92 inches of mercury). This is expressed as [25, V(0;101.325)].
11. Fuel must conform to Waukesha's "Gaseous Fuel Specification" S7884-7 or most current version. Fuel may require treatment to meet current fuel
specification.
2. Power rating is adjusted for fuel, site altitude, and site air inlet temperature, in accordance with ISO 3046/1 with tolerance of ± 3%.
13. Fuel volume flow calculation in english units is based on 100% relative humidity of the fuel gas at standard conditions of 60°F and 14.696 psia (29.92
inches of mercury; 101.325 kPa).
21. Available Turndown Speed Range refers to the constant torque speed range available. Reduced power may be available at speeds outside of this range.
Contact application engineering.
All data provided per the condtions listed in the notes section on page three.
Data Generated by EngCalc Program Version 4.0 INNIO Waukesha Gas Engines, Inc.
10/17/2019 12:56 PM Page 3 of 3
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 (MMscfd): 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 (MMscfh):
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
24
7
52
25 25
25 25
1.875 1.875
16,425 MMscf/year
wet gas moisture removal 45 MMscf/day
DEHY
Kinder Morgan Altamont LLC
Hideout Compressor Station
December 6, 2023
TEG Dehydrator (DEHY) Dry natural gas
Contact Tower andRegenerator TBD
TBD TBD
2024
45
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.
Condenser Combustor
TBD - New Cimarron
98%>80%
DEHY
n/a to condenser/combustor
n/a to condenser/combustor
0.45 1.98
Not Emitted
Not Emitted
0.028
Not Emitted
Not Emitted
Not Emitted
3.861
Not Emitted
0.13 0.59
2024 2024
TBD - New TBD - New
VOC VOC
1.98 tpy
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: ___________________________________________________________________________
2. Model Number: ______________________________3. Serial Number: _______________________________
4. Boiler Rating: _________________(10
6 Btu per Hour)
5. Operating Schedule: __________ hours per day __________ days per week ___________ weeks per year
6. Use: □ steam: psig □hot water □other hot liquid: ________________________________
□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
TBD
TBD TBD
1.5
24 7 52
TEG
TBD
1
TBD
Heater/Reboiler (H-1)
N/A
N/A
Kinder Morgan Altamont LLC
Hideout Compressor Station
December 6, 2023
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 ____________
Stack height above the ground ________________
Stack height above the building ________________
32. Gas exit temperature: ___________
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: _________________ acfm Vertically restricted? □ Yes □No
Emissions Calculations (PTE)
35. 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_________ Lbs/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
N/A
N/A
N/A
N/A
20'
None
0.01 0.04
0.12 0.51
0.1 0.43
769
0.001
0.01 0.04
0.006 0.03
0.01
0.0022 0.01
7.03E-4 3.08E-3
345
10" 600
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: ___________________________________________________________________________
2. Model Number: ______________________________3. Serial Number: _______________________________
4. Boiler Rating: _________________(10
6 Btu per Hour)
5. Operating Schedule: __________ hours per day __________ days per week ___________ weeks per year
6. Use: □ steam: psig □hot water □other hot liquid: ________________________________
□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
TBD
TBD TBD
1.5
24 7 52
TEG
TBD
1
TBD
Stabilizer Heater (H-2)
N/A
N/A
Kinder Morgan Altamont LLC
Hideout Compressor Station
December 6, 2023
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 ____________
Stack height above the ground ________________
Stack height above the building ________________
32. Gas exit temperature: ___________
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: _________________ acfm Vertically restricted? □ Yes □No
Emissions Calculations (PTE)
35. 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_________ Lbs/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.
N/A
N/A
N/A
N/A
20'
None
0.01 0.04
0.12 0.51
0.10 0.43
769
0.001
0.01 0.04
7.03E-4 3.08E-3
0.006 0.03
0.01
0.0022 0.01
345
10" 600
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: ____________ psi
9. Outside color of tank: __________________________10. Maximum storage temperature: __________ FO
11. Average throughput: ____________ gallons per year 12. Turnovers/yearly ____ Monthly ____ Weekly ___
13. Average liquid height (feet): _____________________ 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
Deck Fitting Category: ________________________
18. T
______________________________________
hell Characteristics:
Condition: _________________________________
Breather Vent Settings: ________________________
Tank Construction: ___________________________
Roof Type: __________________________________
Deck Construction: ___________________________
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: ________________________________
Kinder Morgan Altamont LLC
QD
7%'$PELHQW



1$

*RRG
R]
&DUERQ6WHHO
&RQH
&DUERQ6WHHO
ZHOGHG
0HWKDQRO
0HWKDQRO6WRUDJH7DQN077DQN

59.411°F
1.4156 psia
32.04 lb/lbmol
TBD
Hideout Compressor Station
December 6, 2023
TBD
New ()168
2
Page 2 of 2
Form 20 - Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Vapor Pressure: ________________________________ Vapor Pressure: ________________________________
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Emissions Calculations (PTE)
22. C
Submit calculations as an appendix. Provide Material Safety Data Sheets for products being stored.
alculated emissions for this device:
VOC _________Lbs/hr_____ Tons/yr
HAPs_________Lbs/hr (speciate)______Tons/yr (speciate)
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
0HWKDQRO6WRUDJH7DQN077DQN
Methanol Only0.03 0.13
0.03 0.13

Page 1 of 2
New Source Review Section
Utah Division of Air Quality
Company: _________________________
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: ____________ psi
9. Outside color of tank: __________________________
11. Average throughput: ____________ gallons per year 12. Turnovers/yearly ____ Monthly ____ Weekly ___
13. Average liquid height (feet): _____________________ 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:_________________________________
18. T
______________________________________
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: ________________________________
Kinder Morgan Altamont LLC
1
6aleV 2il
10.78 psia
TBD
Gunbarrel (T-1) & Condensate Tanks
(T-2, T-3, T-4, T-5, T-6)
Site/Source:________________________
Date: December 6, 2023_____________________________
17. S
Deck Fitting Category: ________________________
hell Characteristics:
GoodCondition: _________________________________
Breather Vent Settings: _____________________
Carbon SteelTank Construction: _________________
Roof Type: ______________________________
Deck Construction: _________________
welded
10. Maximum storage temperature: __________
OFAmbient
N/A
4 oz
cone
carbon steel
TBD
New (2024)16,800 each
12 20
16.89
TBD
4,600,000
18 1
55
12.91
62.1°F
85.14 lb/lbmol
Hideout Compressor Station
Page 2 of 2
Form 20 - Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Vapor Pressure: ________________________________ Vapor Pressure: ________________________________
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Emissions Calculations (PTE)
22. C
Submit calculations as an appendix. Provide Material Safety Data Sheets for products being stored.
alculated emissions for this device:
VOC _________Lbs/hr_____ Tons/yr
HAPs_________Lbs/hr (speciate)______Tons/yr (speciate)
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
*XQEDUUHO7 &RQGHQVDWH
7DQNV77777
Emissions shown are controlled1.69 7.39
0.820.19
Page 1 of 2
New Source Review Section
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: ____________ psi
9. Outside color of tank: __________________________10. Maximum storage temperature: __________ FO
11. Average throughput: ____________ gallons per year 12. Turnovers/yearly ____ Monthly ____ Weekly ___
13. Average liquid height (feet): _____________________ 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:_________________________________
18. T
______________________________________
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: ________________________________
Kinder Morgan Altamont LLC
4
1
TBD
Used Lube Oil Tank (ULO-Tank)
Date: December 6, 2023_____________________________
17. S
Deck Fitting Category: ________________________
hell Characteristics:
GoodCondition: _________________________________
Breather Vent Settings: _____________________
Carbon SteelTank Construction: _________________
Roof Type: ______________________________
Deck Construction: _________________
welded
Ambient
n/a
N/A
4 oz
cone
carbon steel
Used Motor Oil
Hideout Compressor Station
TBD
New (2024)8,400
12 10
1.28
TBD
30,457
6 1
Page 2 of 2
Form 20 - Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Vapor Pressure: ________________________________ Vapor Pressure: ________________________________
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Emissions Calculations (PTE)
22. C
Submit calculations as an appendix. Provide Material Safety Data Sheets for products being stored.
alculated emissions for this device:
VOC _________Lbs/hr_____ Tons/yr
HAPs_________Lbs/hr (speciate)______Tons/yr (speciate)
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
Used Lube Oil Tank (ULO-Tank)
0.04 0.19
Page 1 of 2
New Source Review Section
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: ____________ psi
9. Outside color of tank: __________________________10. Maximum storage temperature: __________ FO
11. Average throughput: ____________ gallons per year 12. Turnovers/yearly ____ Monthly ____ Weekly ___
13. Average liquid height (feet): _____________________ 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:_________________________________
18. T
______________________________________
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: ________________________________
Kinder Morgan Altamont LLC
4
1
TBD
Ambient
n/a
N/A
4 oz
cone
carbon steel
Fresh Motor Oil
Fresh Lube Oil Tank (LO-Tank)
Date: December 6, 2023_____________________________
17. S
Deck Fitting Category: ________________________
hell Characteristics:
GoodCondition: _________________________________
Breather Vent Settings: _____________________
Carbon SteelTank Construction: _________________
Roof Type: ______________________________
Deck Construction: _________________
welded
Hideout Compressor Station
TBD
New (2024)8,400
12 10
1.28
TBD
30,457
6 1
Page 2 of 2
Form 20 - Organic Liquid Storage Tank
(Continued)
21.Chemical Components Information
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Vapor Pressure: ________________________________ Vapor Pressure: ________________________________
Chemical Name: ________________________________
Percent of Total Liquid Weight: _____________________
Molecular Weight: _______________________________
Avg. Liquid Temperature: _________________________
Emissions Calculations (PTE)
22. C
Submit calculations as an appendix. Provide Material Safety Data Sheets for products being stored.
alculated emissions for this device:
VOC _________Lbs/hr_____ Tons/yr
HAPs_________Lbs/hr (speciate)______Tons/yr (speciate)
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
Fresh Lube Oil Tank (LO-Tank)
0.04 0.19
Appendix B 
Site Location Map 
Simplified Process Flow Diagram 
Kinder Morgan
Process Flow Diagram
Hideout Compressor Station
Field Gas Streams
Inlet Slug Catcher 3-Stage
Compression
Gas
Non-condensable reboiler vapors
(5) 400-bbl
Conensate
Tank
Tank Vapors (including S&W, Flashing)
(1) 400-bbl
Gunbarrel
Tank
Dehydrator Treatment
Gas
Liquids
Water Truck Loading Condensate Loadout
Gas from Farm CS
Discharge
Dry Gas to
Pipeline
High Pressure
Slug Catcher
1-Stage
Compression
Gas Treated Gas
HP Drains to Slug Catcher
Glycol
Flash Tank BTEX
Condenser
BTEX Tank Liquids to Pit Tank
Flash Tank EmissionsDropout Liquids Circle Back
Combustor
Stream color coding:
Black - liquids
Red – process gas
Green – waste gas
Appendix C  
Emission Calculations 
Table C-1: Source and Emission Inventory Proposed Equipment for Hideout Compressor Station
Emission
Unit ID EU Description Make/Model
BSFC, HHV
(Btu/bhp-hr)
Heat Input
(MMBtu/hr)
Enforceable
(Hrs/yr)Fuel
HHV
(Btu/scf)
Fuel
(MMscf/yr)
Add-On
Controls
C-1
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-2
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-3
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-4
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-5
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-6
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-7
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-8
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-9
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
C-10
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 1,900 bhp 8,131 15.4 8,760 NG 1,281 105.7 NSCR
H-1 Heater / Reboiler n/a 1.5 MMbtu/hr n/a 1.5 8,760 NG 1,281 10.3 None
H-2 Gas Fired Stabilizer Heater n/a 1.5 MMbtu/hr n/a 1.5 8,760 NG 1,281 10.3 None
DEHY
TEG Dehydration Unit Process
Vents (Still Vent & Flash Tank)n/a 45.00 MMscfd n/a n/a 8,760 n/a n/a n/a
Combustor
(COM-2)
COM-1 Tank & TLO Combustor TBD 121 scfh (pilot)n/a 0.2 8,760 NG 1,281 1.1 None
COM-2 BTEX Combustor TBD 121 scfh (pilot)n/a 0.2 8,760 NG 1,281 1.1 None
FL-1 Facility Flare TBD 71 scfh (pilot)n/a 0.1 8,760 NG 1,281 200.0 None
T-1 - T-6
(1)Gunbarrel & (5)Condensate
Tanks n/a 400 bbl n/a n/a 8,760 n/a n/a n/a
Combustor
(COM-1)
TRK-1 Truck Loading n/a 257 bbl/day n/a n/a 8,760 n/a n/a n/a
Combustor
(COM-1)
LO-Tank Lube Oil Tank n/a 200 bbl n/a n/a 8,760 n/a n/a n/a None
ULO-Tank Used Lube Oil Tank n/a 200 bbl n/a n/a 8,760 n/a n/a n/a None
MT-Tank Methanol Storage Tank n/a 400 bbl n/a n/a 8,760 n/a n/a n/a None
50/50-Tank Antifreeze Tank (50/50)n/a 100 bbl n/a n/a 8,760 n/a n/a n/a None
FAB
Ultra-fab H2S Removal System
(closed loop)n/a n/a n/a
FAB-Tank H2S Removal n/a 400 bbl None
PIG
Pigging Emissions
(Launcher/Receiver)n/a n/a n/a n/a n/a n/a n/a n/a FL-1
BLW DWN Compressor Blow Down Events n/a n/a n/a n/a n/a n/a n/a n/a FL-1
FUG-1 Fugitive - Component Leaks n/a n/a n/a n/a 8,760 n/a n/a n/a n/a
Hideout CS Facility-wide Emissions
Capacity
(Site Rating)
Page 1 of 4 12/19/2023
Table C-1: Source and Emission Inventory Proposed Equipment for Hideout Compressor Station
Emission
Unit ID EU Description Make/Model
C-1
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-2
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-3
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-4
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-5
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-6
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-7
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-8
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-9
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-10
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
H-1 Heater / Reboiler n/a
H-2 Gas Fired Stabilizer Heater n/a
DEHY
TEG Dehydration Unit Process
Vents (Still Vent & Flash Tank)n/a
COM-1 Tank & TLO Combustor TBD
COM-2 BTEX Combustor TBD
FL-1 Facility Flare TBD
T-1 - T-6
(1)Gunbarrel & (5)Condensate
Tanks n/a
TRK-1 Truck Loading n/a
LO-Tank Lube Oil Tank n/a
ULO-Tank Used Lube Oil Tank n/a
MT-Tank Methanol Storage Tank n/a
50/50-Tank Antifreeze Tank (50/50)n/a
FAB
Ultra-fab H2S Removal System
(closed loop)n/a
FAB-Tank H2S Removal n/a
PIG
Pigging Emissions
(Launcher/Receiver)n/a
BLW DWN Compressor Blow Down Events n/a
FUG-1 Fugitive - Component Leaks n/a
Hideout CS Facility-wide Emissions
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
1.26 5.50 1.27 5.57 1.47E-01 6.43E-01 1.47E-01 6.43E-01 0.01 0.04 1.26 5.50 0.10 0.45
0.12 0.51 0.10 0.43 8.90E-03 3.90E-02 8.90E-03 3.90E-02 7.03E-04 3.08E-03 0.01 0.03 2.20E-03 9.66E-03
0.12 0.51 0.10 0.43 8.90E-03 3.90E-02 8.90E-03 3.90E-02 7.03E-04 3.08E-03 6.44E-03 2.82E-02 2.20E-03 9.66E-03
Not emitted Not emitted Not emitted Not emitted Not emitted
See
COM-2
See
COM-2
0.39 1.70 0.10 0.43 0.04 0.17 0.04 0.17 Negligible 1.84 8.05 1.98E-01 8.68E-01
0.11 0.47 0.03 0.12 0.01 0.05 0.01 0.05 Negligible 0.52 2.28 1.37E-01 6.01E-01
1.99 8.74 9.09 39.82 0.61 2.65 0.61 2.65 Negligible 6.33 27.72 0.18 0.79
Not emitted Not emitted Not emitted Not emitted Not emitted See COM-1 See COM-1
Not emitted Not emitted Not emitted Not emitted Not emitted See COM-1 See COM-1
Not emitted Not emitted Not emitted Not emitted Not emitted 0.04 0.19 Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted 0.04 0.19 Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted 0.03 0.13 0.03 0.13
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
See
FL-1
See
FL-1
Not emitted Not emitted Not emitted Not emitted Not emitted
See
FL-1
See
FL-1
Not emitted Not emitted Not emitted Not emitted Not emitted 0.10 0.44 0.01 0.05
15.28 66.93 22.13 96.93 2.14 9.38 2.14 9.38 0.09 0.40 21.48 94.10 1.58 6.94
Total HAPVOCNOXSO2PM2.5PM10CO
Page 2 of 4 12/19/2023
Table C-1: Source and Emission Inventory Proposed Equipment for Hideout Compressor Station
Emission
Unit ID EU Description Make/Model
C-1
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-2
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-3
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-4
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-5
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-6
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-7
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-8
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-9
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-10
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
H-1 Heater / Reboiler n/a
H-2 Gas Fired Stabilizer Heater n/a
DEHY
TEG Dehydration Unit Process
Vents (Still Vent & Flash Tank)n/a
COM-1 Tank & TLO Combustor TBD
COM-2 BTEX Combustor TBD
FL-1 Facility Flare TBD
T-1 - T-6
(1)Gunbarrel & (5)Condensate
Tanks n/a
TRK-1 Truck Loading n/a
LO-Tank Lube Oil Tank n/a
ULO-Tank Used Lube Oil Tank n/a
MT-Tank Methanol Storage Tank n/a
50/50-Tank Antifreeze Tank (50/50)n/a
FAB
Ultra-fab H2S Removal System
(closed loop)n/a
FAB-Tank H2S Removal n/a
PIG
Pigging Emissions
(Launcher/Receiver)n/a
BLW DWN Compressor Blow Down Events n/a
FUG-1 Fugitive - Component Leaks n/a
Hideout CS Facility-wide Emissions
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
0.08 0.37 No factor No factor 2.44E-03 0.01 8.62E-04 3.78E-03 3.83E-05 1.68E-04 3.01E-04 1.32E-03
8.79E-05 3.85E-04 2.11E-03 9.23E-03 No factor 2.46E-06 0.00 3.98E-06 1.74E-05 No factor No factor
8.79E-05 3.85E-04 2.11E-03 9.23E-03 No factor 2.46E-06 1.08E-05 3.98E-06 1.74E-05 No factor No factor
See
COM-2
See
COM-2
See
COM-2
See
COM-2
See
COM-2 Not emitted
See
COM-2
1.74E-03 7.60E-03 1.84E-01 8.05E-01 2.47E-03 1.08E-02 8.46E-03 3.71E-02 3.28E-03 1.44E-02 No factor 1.70E-04 7.45E-04
4.94E-04 2.16E-03 5.11E-02 2.24E-01 3.36E-04 1.47E-03 7.30E-02 3.20E-01 1.27E-02 5.57E-02 No factor 1.36E-04 5.97E-04
0.03 0.12 0.17 0.73 3.17E-03 1.39E-02 0.01 0.03 0.00 0.01 No factor 6.64E-04 2.91E-03
Not emitted See COM-1 See COM-1 See COM-1 See COM-1 Not emitted See COM-1
Not emitted See COM-1 See COM-1 See COM-1 See COM-1 Not emitted See COM-1
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted
See
FL-1
See
FL-1
See
FL-1
See
FL-1
See
FL-1 Not emitted
See
FL-1
See
FL-1
See
FL-1
See
FL-1
See
FL-1
See
FL-1 Not emitted
See
FL-1
Not emitted 0.01 0.05 Not emitted 4.75E-04 2.08E-03 5.82E-04 2.55E-03 1.08E-05 4.74E-05 1.33E-04 5.83E-04
0.87 3.80 0.42 1.83 5.98E-03 2.62E-02 0.11 0.50 2.75E-02 1.21E-01 3.94E-04 1.73E-03 4.12E-03 1.80E-02
Benzene2,2,4-Trimethylpentanen-HexaneFormaldehyde XylenesEthylbenzeneToluene
Page 3 of 4 12/19/2023
Table C-1: Source and Emission Inventory Proposed Equipment for Hideout Compressor Station
Emission
Unit ID EU Description Make/Model
C-1
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-2
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-3
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-4
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-5
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-6
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-7
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-8
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-9
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
C-10
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5
H-1 Heater / Reboiler n/a
H-2 Gas Fired Stabilizer Heater n/a
DEHY
TEG Dehydration Unit Process
Vents (Still Vent & Flash Tank)n/a
COM-1 Tank & TLO Combustor TBD
COM-2 BTEX Combustor TBD
FL-1 Facility Flare TBD
T-1 - T-6
(1)Gunbarrel & (5)Condensate
Tanks n/a
TRK-1 Truck Loading n/a
LO-Tank Lube Oil Tank n/a
ULO-Tank Used Lube Oil Tank n/a
MT-Tank Methanol Storage Tank n/a
50/50-Tank Antifreeze Tank (50/50)n/a
FAB
Ultra-fab H2S Removal System
(closed loop)n/a
FAB-Tank H2S Removal n/a
PIG
Pigging Emissions
(Launcher/Receiver)n/a
BLW DWN Compressor Blow Down Events n/a
FUG-1 Fugitive - Component Leaks n/a
Hideout CS Facility-wide Emissions
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
4.06E-03 0.02 4.73E-03 2.07E-02 1,918.47 8,402.91 4.21 18.45 0.00 0.01 2,024.8 8,868.7
No factor No factor 175.46 768.53 0.00 0.01 0.00 0.00 175.6 769.3
No factor No factor 175.46 768.53 0.00 0.01 0.00 0.00 175.6 769.3
Not emitted Not emitted
See
COM-2
See
COM-2
See
COM-2
No factor No factor 324.65 1,421.98 0.22 0.95 6.12E-04 2.68E-03 330.2 1,446.5
No factor No factor 90.48 396.32 0.01 0.03 1.71E-04 7.47E-04 90.7 397.4
No factor No factor 3,430.74 15,026.63 0.15 0.66 6.47E-03 2.83E-02 3,436.4 15,051.5
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted 0.03 0.13 Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted Not emitted Not emitted Not emitted
Not emitted Not emitted
See
FL-1
See
FL-1
See
FL-1
Not emitted Not emitted
See
FL-1
See
FL-1
See
FL-1
Not emitted Not emitted Not emitted Not emitted Not emitted
0.04 0.18 7.68E-02 2.07E-01 102,411.1 186.20 0.18 107,120.8
Acrolein CO2eN2OMethaneCarbon DioxideMethanol
Page 4 of 4 12/19/2023

Table C-2: Calculations of Emissions from engine for inlet compressor C-1 through C-10
Engine Make and Model:Waukesha 7044 GSI S5 Engine Type:4SRB
Fuel:Pipeline quality natural gas Fuel LHV:1,015 btu/scf Fuel HHV:1,281 btu/scf
Site Rated Power (bhp):1,900 from manufacturer*Operating RPM:1,200
Fuel Consumption (LHV):7,350 btu/bhp-hr from manufacturer*Site Elevation:5,090 feet ASL
Fuel Consumption (HHV):8,131 btu/bhp-hr from manufacturer*
Maximum Heat Input:15.4 MMbtu/hr calculated w/HHV 12,064 scf/hr
Annual Operation:8,760 hrs 105.68 MMscf/yr 12/19/2023
Pollutant Emission
Factor Units Factor Source
Emissions
(lb/hr)
Emissions
(tpy)
Control
Type
Control
Efficiency
(%)
Emission
Factor Units Factor Source
Emission
Rate (lb/hr)
Emissions
(tpy)
PM 1.94E-02 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.30 1.31 none 0 0.30 1.31
PM10 9.50E-03 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.47E-01 6.43E-01 none 0 1.47E-01 6.43E-01
PM2.5 9.50E-03 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.47E-01 6.43E-01 none 0 1.47E-01 6.43E-01
SO2 5.88E-04 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.01 0.04 none 0 9.08E-03 3.98E-02
NOX 10.90 g/bhp-hr Manufacturer 45.66 199.98 NSCR 97.3 0.30 g/bhp-hr Client Experience 1.26 5.50
CO 9.20 g/bhp-hr Manufacturer 38.54 168.79 NSCR 96.7 0.30 g/bhp-hr Manufacturer Plus 1.27 5.57
VOC**0.30 g/bhp-hr Client Eng. Experience 1.26 5.50 NSCR 0.0 0.30 g/bhp-hr Client Experience 1.26 5.50
HCHO 0.05 g/bhp-hr Manufacturer 0.21 0.92 NSCR 60.0 0.020 g/bhp-hr Manufacturer 8.38E-02 0.37
Total HAPs (exc. HCHO)0.01 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.18 0.81 NSCR 90.0 0.001 lb/Mmbtu AP-42 Table 3.2-3 0.02 0.08
CO2 458.00 g/bhp-hr Manufacturer 1,918 8402.91 none 0 1918.47 8402.91
CH4 0.26 g/bhp-hr Manufacturer 4 18.45 none 0 4.21 18.45
N2O 2.20E-04 lb/MMBtu 40CFR98 Table C-2 0.00 0.01 none 0 0.00 0.01
2,024.81 8,868.68 2,024.81 8,868.68
*Maximum rated horsepower from manufacturer
**NM, NEHC from manufacturer specifications
Note: See Sheet 2 for sample calculations and footnotes.
Hideout Compressor Station
Uncontrolled Emissions Information Controlled Emissions Information Projected Emissions
calculated w/HHVMaximum Fuel Input:
Total Uncontrolled GHGs (CO2e) --> Total Projected GHGs (CO2e) -->
WAUK 7044GSI
Table C-2: Calculations of Emissions from engine for inlet compressor C-1 through C-10
Extended HAP Emissions Jul-23
Constituent
Emissions
Factor
Factor
Units Factor Source4,5,6
Emissions
(lb/hr)
Emissions
(tpy)3
Control
Efficiency
(%)7
Emissions
(lb/hr)
Emissions
(tpy)3
1,1,2,2-Tetrachloroethane 2.53E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)3.91E-04 1.71E-03 90 3.91E-05 1.71E-04
1,1,2-Trichloroethane 1.53E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)2.36E-04 1.04E-03 90 2.36E-05 1.04E-04
1.3-Butadiene 6.63E-04 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.02E-02 4.49E-02 90 1.02E-03 4.49E-03
1,3-Dichloropropene 1.27E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.96E-04 8.59E-04 90 1.96E-05 8.59E-05
2-Methylnaphthalene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
2,2,4-Trimethylpentane 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Acenaphthene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Acenaphthylene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Acetaldehyde 2.79E-03 lb/MMBtu AP-42 Table 3.2-3 (7/00)4.31E-02 1.89E-01 90 4.31E-03 1.89E-02
Acrolein 2.63E-03 lb/MMBtu AP-42 Table 3.2-3 (7/00)4.06E-02 1.78E-01 90 4.06E-03 1.78E-02
Benzene 1.58E-03 lb/MMBtu AP-42 Table 3.2-3 (7/00)2.44E-02 1.07E-01 90 2.44E-03 1.07E-02
Benzo(b)fluoranthene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Benzo(e)pyrene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Benzo(g,h,i)perylene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Biphenyl 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Carbon Tetrachloride 1.77E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)2.73E-04 1.20E-03 90 2.73E-05 1.20E-04
Chlorobenzene 1.29E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.99E-04 8.73E-04 90 1.99E-05 8.73E-05
Chloroform 1.37E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)2.12E-04 9.27E-04 90 2.12E-05 9.27E-05
Chrysene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Ethylbenzene 2.48E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)3.83E-04 1.68E-03 90 3.83E-05 1.68E-04
Ethylene Dibromide 2.13E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)3.29E-04 1.44E-03 90 3.29E-05 1.44E-04
Fluoranthene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Fluorene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Formaldehyde 5.00E-02 g/hp-hr Manufacturer 2.09E-01 9.17E-01 60 8.38E-02 3.67E-01
Methanol 3.06E-03 lb/MMBtu AP-42 Table 3.2-3 (7/00)4.73E-02 2.07E-01 90 4.73E-03 2.07E-02
Methylene Chloride 4.12E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)6.36E-04 2.79E-03 90 6.36E-05 2.79E-04
n-Hexane 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Naphthalene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
PAH 1.41E-04 lb/MMBtu AP-42 Table 3.2-3 (7/00)2.18E-03 9.54E-03 90 2.18E-04 9.54E-04
Phenanthrene 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Phenol 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
POM 9.71E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.50E-03 6.57E-03 90 1.50E-04 6.57E-04
Styrene 1.19E-05 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.84E-04 8.05E-04 90 1.84E-05 8.05E-05
Tetrachloroethane 0.00E+00 lb/MMBtu AP-42 Table 3.2-3 (7/00)0.00E+00 0.00E+00 90 0.00E+00 0.00E+00
Toluene 5.58E-04 lb/MMBtu AP-42 Table 3.2-3 (7/00)8.62E-03 3.78E-02 90 8.62E-04 3.78E-03
Vinyl Chloride 7.18E-06 lb/MMBtu AP-42 Table 3.2-3 (7/00)1.11E-04 4.86E-04 90 1.11E-05 4.86E-05
Xylene 1.95E-04 lb/MMBtu AP-42 Table 3.2-3 (7/00)3.01E-03 1.32E-02 90 3.01E-04 1.32E-03
Totals:0.39 1.72 0.10 0.45
Uncontrolled1 Controlled2Waukesha 7044 GSI S5
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WAUK 7044GSI
Table C-3: Hideout Compressor Station - TEG Reboiler H-1
Emission Source: Indirect Heater
Source Type: Natural Gas-Fired Heater
Heat Input:
Natural Gas Higher Heating Value (HHV):
Fuel Consumption (HHV):
Fuel Consumption (HHV):
Operating Hours per Year:
Sulfur Content of Fuel:
Exhaust Stack Temp:
Exhaust Gas Flow:
Number of Units: 1
Emission Short-term Annual
Pollutant Factors 1 lb/hr 2 g/sec tpy 3 g/sec
NOx 100.0 lb/MMscf 0.12 0.0148 0.51 0.0148
CO 84.0 lb/MMscf 0.10 0.0124 0.43 0.0124
VOC 5.5 lb/MMscf 0.006 0.0008 0.03 0.0008
SO2 0.6 lb/MMscf 7.03E-04 0.0001 3.08E-03 0.0001
PM10 7.6 lb/MMscf 0.01 0.0011 0.04 0.0011
PM2.5 7.6 lb/MMscf 0.01 0.0011 0.04 0.0011
CO2 53.06 kg/MMBtu 175.5 22.11 768.5 22.11
CH4 0.001 kg/MMBtu 0.003 0.0004 0.014 0.0004
N2O 0.0001 kg/MMBtu 0.000 0.0000 0.001 0.0000
Notes:
1 Emission factors (lb/MMscf) based on USEPA AP-42, Section 1.4, Table 1.4-2, dated July 1998
2 Hourly Emission Rate (lb/hr) = (lb/MMscf) * (MMscf/hr); or (kg/MMBtu) (MMBtu/hr) (2.2046 lb/kg)
3 Annual Emission Rate (tpy) = (lb/hr) (hrs/yr) (ton/2000 lb)
Natural Gas-Fired Indirect Heater Criteria Pollutant Emissions
Calculations
AP42 Table 1.4-2 indicates that all PM (total, condensible, and filterable) is assumed to be less than 1.0
micrometer in diameter. Therefore, the PM emission factors presented here may be used to estimate PM10,
PM2.5 or PM1 emissions.
1.50 MMBtu/hr
1,281 Btu/scf
0.0012 MMscf/hr
10.26 MMscf/yr
8,760 hr/yr
0.0020 gr/scf
600 F
345 acfm
One Heater
CO2e 769.3 tpy
Table C-3a: Hideout Compressor Station - TEG Reboiler H-1
Emission Emission Rates
Factor One Heater
Pollutant Type 1 (lb/MMscf) 2 (lb/hr) 3 (lbs/yr) (tpy) 4
2-Methylnaphthalene HAP 2.4E-05 2.81E-08 2.46E-04 1.23E-07
3-Methylchloranthrene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
7,12-Dimethylbenz(a)anthracene HAP 1.6E-05 1.87E-08 1.64E-04 8.21E-08
Acenaphthene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Acenaphthylene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Anthracene HAP 2.4E-06 2.81E-09 2.46E-05 1.23E-08
Benz(a)anthracene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Benzene HAP 2.1E-03 2.46E-06 2.15E-02 1.08E-05
Benzo(a)pyrene HAP 1.2E-06 1.41E-09 1.23E-05 6.16E-09
Benzo(b)fluoranthene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Benzo(g,h,i)perylene HAP 1.2E-06 1.41E-09 1.23E-05 6.16E-09
Benzo(k)fluoranthene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Chrysene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Dibenzo(a,h)anthracene HAP 1.2E-06 1.41E-09 1.23E-05 6.16E-09
Dichlorobenzene HAP 1.2E-03 1.41E-06 1.23E-02 6.16E-06
Fluoranthene HAP 3.0E-06 3.51E-09 3.08E-05 1.54E-08
Fluorene HAP 2.8E-06 3.28E-09 2.87E-05 1.44E-08
Formaldehyde HAP 7.5E-02 8.79E-05 7.70E-01 3.85E-04
n-Hexane* HAP 1.8E+00 2.11E-03 1.85E+01 9.23E-03
Indeno(1,2,3-cd)pyrene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Naphthalene HAP 6.1E-04 7.15E-07 6.26E-03 3.13E-06
Phenanathrene HAP 1.7E-05 1.99E-08 1.74E-04 8.72E-08
Pyrene HAP 5.0E-06 5.86E-09 5.13E-05 2.57E-08
Toluene HAP 3.4E-03 3.98E-06 3.49E-02 1.74E-05
Totals: HAP 2.20E-03 1.93E+01 9.66E-03
*Largest HAP
Natural Gas-Fired Heater 8,760 hr/yr Total HAPs 9.66E-03
Maximum Heat Input Max HAP 9.23E-03
Natural Gas Heating Value
Fuel Consumption (LHV)
Fuel Consumption (LHV)
Number of Heaters 1
Notes:
1 Type = HAP for Hazardous Air Pollutant.
2 Emission factors from AP-42, Section 1.4, Table 1.4-3 (7/98).
3 Hourly Emission Rate (lb/hr) = [(MMBtu/Hr) * (lb/MMscf)] / [(BTU/scf)]
4 Annual Emission Rate (tpy) = (lb/hr) * (8760 hr/yr) / (2,000 lb/ton)
1.50 MMBtu/hr
1,281 Btu/scf
0.0012 MMscf/hr
10.26 MMscf/yr
Natural Gas-Fired Indirect Heater Criteria Pollutant Emissions
Calculations
Table C-4: Hideout Compressor Station - Stabilizer Heater H-2
Emission Source:Indirect Heater
Source Type:Natural Gas-Fired Heater
Heat Input:
Natural Gas Higher Heating Value (HHV):
Fuel Consumption (HHV):
Fuel Consumption (HHV):
Operating Hours per Year:
Sulfur Content of Fuel:
Exhaust Stack Temp:
Exhaust Gas Flow:
Number of Units:1
Emission Short-term Annual
Pollutant Factors 1 lb/hr 2 g/sec tpy 3 g/sec
NOx 100.0 lb/MMscf 0.12 0.0148 0.51 0.0148
CO 84.0 lb/MMscf 0.10 0.0124 0.43 0.0124
VOC 5.5 lb/MMscf 0.006 0.0008 0.03 0.0008
SO2 0.6 lb/MMscf 7.03E-04 0.0001 3.08E-03 0.0001
PM10 7.6 lb/MMscf 0.01 0.0011 0.04 0.0011
PM2.5 7.6 lb/MMscf 0.01 0.0011 0.04 0.0011
CO2 53.06 kg/MMBtu 175.5 22.11 768.5 22.11
CH4 0.001 kg/MMBtu 0.003 0.0004 0.014 0.0004
N2O 0.0001 kg/MMBtu 0.000 0.0000 0.001 0.0000
Notes:
1 Emission factors (lb/MMscf) based on USEPA AP-42, Section 1.4, Table 1.4-2, dated July 1998
2 Hourly Emission Rate (lb/hr) = (lb/MMscf) * (MMscf/hr); or (kg/MMBtu) (MMBtu/hr) (2.2046 lb/kg)
3 Annual Emission Rate (tpy) = (lb/hr) (hrs/yr) (ton/2000 lb)
AP42 Table 1.4-2 indicates that all PM (total, condensible, and filterable) is assumed to be less than 1.0 micrometer
in diameter. Therefore, the PM emission factors presented here may be used to estimate PM10, PM2.5 or PM1
emissions.
0.0020 gr/scf
600 F
345 acfm
One Heater
CO2e 769.3 tpy
8,760 hr/yr
Natural Gas-Fired Indirect Heater Criteria Pollutant Emissions
Calculations
1.50 MMBtu/hr
1,281 Btu/scf
0.0012 MMscf/hr
10.26 MMscf/yr
Table C-4a:Hideout Compressor Station - Stabilizer Heater H-2
Emission Emission Rates
Factor One Heater
Pollutant Type 1 (lb/MMscf)2 (lb/hr)3 (lbs/yr) (tpy)4
2-Methylnaphthalene HAP 2.4E-05 2.81E-08 2.46E-04 1.23E-07
3-Methylchloranthrene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
7,12-Dimethylbenz(a)anthracene HAP 1.6E-05 1.87E-08 1.64E-04 8.21E-08
Acenaphthene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Acenaphthylene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Anthracene HAP 2.4E-06 2.81E-09 2.46E-05 1.23E-08
Benz(a)anthracene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Benzene HAP 2.1E-03 2.46E-06 2.15E-02 1.08E-05
Benzo(a)pyrene HAP 1.2E-06 1.41E-09 1.23E-05 6.16E-09
Benzo(b)fluoranthene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Benzo(g,h,i)perylene HAP 1.2E-06 1.41E-09 1.23E-05 6.16E-09
Benzo(k)fluoranthene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Chrysene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Dibenzo(a,h)anthracene HAP 1.2E-06 1.41E-09 1.23E-05 6.16E-09
Dichlorobenzene HAP 1.2E-03 1.41E-06 1.23E-02 6.16E-06
Fluoranthene HAP 3.0E-06 3.51E-09 3.08E-05 1.54E-08
Fluorene HAP 2.8E-06 3.28E-09 2.87E-05 1.44E-08
Formaldehyde HAP 7.5E-02 8.79E-05 7.70E-01 3.85E-04
n-Hexane*HAP 1.8E+00 2.11E-03 1.85E+01 9.23E-03
Indeno(1,2,3-cd)pyrene HAP 1.8E-06 2.11E-09 1.85E-05 9.23E-09
Naphthalene HAP 6.1E-04 7.15E-07 6.26E-03 3.13E-06
Phenanathrene HAP 1.7E-05 1.99E-08 1.74E-04 8.72E-08
Pyrene HAP 5.0E-06 5.86E-09 5.13E-05 2.57E-08
Toluene HAP 3.4E-03 3.98E-06 3.49E-02 1.74E-05
Totals: HAP 2.20E-03 1.93E+01 9.66E-03
*Largest HAP
Natural Gas-Fired Heater 8,760 hr/yr Total HAPs 9.66E-03
Maximum Heat Input Max HAP 9.23E-03
Natural Gas Heating Value
Fuel Consumption (HHV)
Fuel Consumption (HHV)
Number of Heaters 1
Notes:
1 Type = HAP for Hazardous Air Pollutant.
2 Emission factors from AP-42, Section 1.4, Table 1.4-3 (7/98).
3 Hourly Emission Rate (lb/hr) = [(MMBtu/Hr) * (lb/MMscf)] / [(BTU/scf)]
4 Annual Emission Rate (tpy) = (lb/hr) * (8760 hr/yr) / (2,000 lb/ton)
Natural Gas-Fired Indirect Heater Criteria Pollutant Emissions
Calculations
1.50 MMBtu/hr
1,281 Btu/scf
0.0012 MMscf/hr
10.26 MMscf/yr
Hideout Compressor Station
Table C-5: Facility Flare Emissions Calculations Updated: 7/20/2023
Make/Model:Annual hours operated:8,760 Destruction Efficiency (%):98
Pilot & Purge Stream
Flow Rate
(scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+
HHV
(btu/scf)
Pilot & Purge Gas 71 0.843 0.314 77.760 11.189 5.579 0.798 1.998 0.431 0.668 0.247
1,280.59
Predicted Gas Streams to
Flare7
Flow Rate
(scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+
HHV
(btu/scf)
Flared Waste Gas 22,831.05 0.84 0.31 77.76 11.19 5.58 0.80 2.00 0.43 0.67 0.25 1,280.59
Pig Launch/Receive Included with Flared Waste Gas volume.
Blowdowns (SSM)Included with Flared Waste Gas volume.
Maintenance Flaring Included with Flared Waste Gas volume.
22,831.05 1,280.59
Continuent EF Units (lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)
NOX1 0.068 lb/MMBtu 0.006 0.027 1.988 8.708 1.994 8.735
CO2 0.310 lb/MMBtu 0.028 0.123 9.064 39.698 9.092 39.822
Uncontrolled VOC3 1.006 4.408 315.446 1381.653 316.452 1386.061
Controlled VOC4 0.020 0.088 6.309 27.633 6.329 27.721
PM10 or PM2.5
6 40 µg/L 0.002 0.008 0.604 2.645 0.606 2.654
Benzene 4.21E-05 1.84E-04 7.71E-03 3.38E-02 0.008 0.034
Toluene 9.54E-06 4.18E-05 2.33E-03 1.02E-02 2.34E-03 1.02E-02
n-Hexane 7.85E-04 3.44E-03 1.66E-01 7.29E-01 0.167 0.732
2,2,4-Trimethylpentane 7.42E-06 3.25E-05 3.16E-03 1.39E-02 3.17E-03 1.39E-02
Controlled HAP5 8.45E-04 3.70E-03 1.80E-01 0.787 0.180 0.790
Formadehyde8 1.169 lb/MMscf 8.30E-05 3.64E-04 0.027 0.117 0.027 0.117
Xylenes8 0.029 lb/MMscf 2.06E-06 9.02E-06 6.62E-04 2.90E-03 6.64E-04 0.003
CO29 116.978 lb/MMBtu 10.64 46.58 3,420.10 14,980.05 3,430.74 15,026.63
CH4 0.000 0.002 0.150 0.656 0.150 0.658
N2O9 0.0002 lb/MMBtu 2.00E-05 8.78E-05 0.006 0.028 0.006 0.028
Equations:
TBD
Stream Composition (% by volume)
Total Stream
Calculated Criteria Emissions
Emission Factor Pilot & Purge Flared Waste Gas Total
Note: Values in the blue-shaded cells in table above were derived from Bryan Research & Engineering, Inc. ProMax™ 5.0 simulation software program (see Table C-7).
see Equations
see Equations
see Equations
see Equations
see Equations
see Equations
see Equations
see Equations
𝑁𝑂𝑥,𝐶𝑂,𝐶𝑂2,𝐶𝐻4 & 𝑁2𝑂 𝑙𝑏
ℎ𝑟= 𝐸𝐹
𝑙𝑏
𝑀𝑀𝑏𝑡𝑢 𝑥 𝐹𝑙𝑜𝑤 𝑅𝑎𝑡𝑒 𝑠𝑐𝑓
ℎ𝑟𝑥 𝐻𝐻𝑉 𝑏𝑡𝑢
𝑠𝑐𝑓 𝑥1 𝑀𝑀𝑏𝑡𝑢
1000000 𝑏𝑡𝑢
1. NOX EF from USEPA AP-42, Chapter 13, Section5, Tables 13.5-1
2. CO EF from USEPA AP-42, Chapter 13, Section 5, Table 13.5-2
3. Uncontrolled VOC calculated based on the VOC fraction of each individual stream (see Uncontrolled VOC calculation equation below).
4. Controlled VOC represents the VOC fraction of each individual stream with a 98% destruction efficiency applied. (see Controlled VOC equation below).
5. Controlled HAPs calculated based on the HAP weight fraction of the predictable waste gas streams. A 98% destruction efficiency rating is applied to calculate controlled emissions.
6. PM10 or PM2.5 factors are identical. From AP-42 Tables 13.5-1 & 2 (lightly smoking)
7. Stream compositions are representative based on measurements and facility knowledge. Estimated to be 60 MMscf/yr split equally between Inlet and Residue compositions.
8. EF from Ventura County Air Pollution Control District AB2588 Combustion Emissions Factors (May 17, 2001).
9. CO2 EF from Table C-1 of 40 CFR 98 and N2O EF from Table C-2 of 40 CFR 98.
𝑃𝑀10 𝑙𝑏
ℎ𝑟= 𝐸𝐹
µ
𝐿 𝑥 𝐹𝑙𝑜𝑤 𝑠𝑐𝑓
ℎ𝑟𝑥 10.6 𝑠𝑐𝑓
𝑠𝑐𝑓 𝐶𝐻4 𝑥 0.0283 𝑚ଷ
𝑠𝑐𝑓 𝑥 1000 𝐿
𝑚ଷ 𝑥1𝑔
10଺ µ𝑔 𝑥𝑙𝑏
453.59𝑔
𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑜𝑟𝑔𝑙𝑏
ℎ𝑟= 𝑇𝑜𝑡𝑎𝑙 𝑆𝑡𝑟𝑒𝑎𝑚 𝑅𝑎𝑡𝑒
𝑠𝑐𝑓௧
ℎ𝑟𝑥 𝑆𝑡𝑟𝑒𝑎𝑚 𝑚𝑜𝑙𝑒𝑐𝑢𝑙𝑎𝑟 𝑤𝑒𝑖𝑔ℎ𝑡𝑙𝑏௢௥௚
𝑙𝑏𝑚𝑜𝑙௢௥௚
𝑥1 𝑚𝑜𝑙௢௥௚
379.1𝑠𝑐𝑓௢௥௚
𝑥 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑤𝑒𝑖𝑔ℎ𝑡 𝑓𝑟𝑎𝑐𝑡𝑖𝑜𝑛
𝐶𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏
ℎ𝑟= 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐
𝑙𝑏
ℎ𝑟𝑥 1 − 𝑑𝑒𝑠𝑡𝑟𝑢𝑐𝑡𝑖𝑜𝑛 𝑒𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦
Hideout Compressor Station
Table C-6a: Tank Combustor (COM-1) - Emissions Calculations 7/20/2023
Make/Model:Annual hours operated:8,760 Destruction Efficiency (%):98
Pilot/Purge Gas Stream
Flow Rate
(scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+
HHV
(btu/scf)
Inlet HP Gas 221 0.843 0.314 77.760 11.189 5.579 0.798 1.998 0.431 0.668 0.247 1,280.59
Streams to Combustor7
Flow Rate
(scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+
HHV
(btu/scf)
GB & CND Tank Vapor 1,201.8 0.76 0.02 24.25 19.40 18.92 3.88 11.53 3.96 7.24 7.79 1,974.8
PW Loading Vapor 0.05 1.20 0.00 1.69 1.53 0.23 0.01 0.04 0.00 0.00 0.01 82.5
CND Loading Vapor 61.48 0.78 0.01 25.82 19.81 18.87 3.79 11.18 3.78 6.85 7.14 1,936.1
1,263.3 1,972.9
Total
Continuent EF Units (lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)
NOX1 0.140 lb/MMBtu 0.040 0.174 0.332 1.455 5.79E-07 2.54E-06 0.017 0.073 0.389 1.702
CO2 0.035 lb/MMBtu 0.010 0.043 0.083 0.364 1.45E-07 6.34E-07 0.004 0.018 0.097 0.425
Uncontrolled VOC3 3.396 14.876 84.399 369.670 1.49E-05 6.52E-05 4.148 18.168 91.944 402.715
Controlled VOC4 0.068 0.298 1.688 7.393 2.98E-07 1.30E-06 0.083 0.363 1.839 8.054
PM10 or PM2.5
6 40 µg/L 0.006 0.026 0.032 0.139 1.33E-06 5.81E-06 0.002 0.007 0.039 0.172
Benzene 1.31E-04 5.74E-04 7.95E-03 3.48E-02 6.23E-09 2.73E-08 3.77E-04 1.65E-03 0.008 0.037
Toluene 2.97E-05 1.30E-04 3.11E-03 1.36E-02 5.86E-10 2.57E-09 1.43E-04 6.28E-04 0.003 0.014
n-Hexane 2.44E-03 1.07E-02 1.73E-01 7.59E-01 4.22E-10 1.85E-09 8.16E-03 3.57E-02 0.184 0.805
2,2,4-Trimethylpentane 2.31E-05 1.01E-04 2.34E-03 1.02E-02 2.06E-12 9.02E-12 1.08E-04 4.74E-04 0.002 0.011
Controlled HAP5 2.63E-03 1.15E-02 1.87E-01 0.818 7.25E-09 3.18E-08 0.009 0.039 0.198 0.868
Formaldehyde8 1.169 lb/MMscf 2.58E-04 1.13E-03 1.40E-03 6.15E-03 5.86E-08 2.57E-07 7.19E-05 3.15E-04 0.002 0.008
Xylenes8 0.029 lb/MMscf 6.41E-06 2.81E-05 1.57E-04 6.86E-04 8.81E-12 3.86E-11 7.01E-06 3.07E-05 1.70E-04 7.45E-04
CO2
9 116.978 lb/MMBtu 33.11 145.00 277.62 1,215.99 4.84E-04 2.12E-03 13.92 60.99 324.654 1421.983
CH4 0.001 0.006 0.204 0.892 5.93E-07 2.60E-06 1.11E-02 4.86E-02 0.216 0.947
N2O9 0.0002 lb/MMBtu 6.24E-05 2.73E-04 5.23E-04 2.29E-03 9.12E-10 3.99E-09 2.62E-05 1.15E-04 6.12E-04 2.68E-03
Equations:
see Equations
see Equations
see Equations
see Equations
see Equations
see Equations
see Equations
see Equations
TBD
Stream Composition (% by volume)
Total Stream
Calculated Criteria Emissions
Emission Factor Pilot GB & CND Tank Vapor CND Loading Vapor
← Note: Values in the blue-shaded
cells to the left were derived from
Bryan Research & Engineering, Inc.
ProMax™ 5.0 simulation software
program (see Table C-7).
PW Loading Vapor
𝑁𝑂𝑥,𝐶𝑂,𝐶𝑂2,𝐶𝐻4 & 𝑁2𝑂 𝑙𝑏
ℎ𝑟= 𝐸𝐹
𝑙𝑏
𝑀𝑀𝑏𝑡𝑢 𝑥 𝐹𝑙𝑜𝑤 𝑅𝑎𝑡𝑒 𝑠𝑐𝑓
ℎ𝑟𝑥 𝐻𝐻𝑉 𝑏𝑡𝑢
𝑠𝑐𝑓 𝑥1 𝑀𝑀𝑏𝑡𝑢
1000000 𝑏𝑡𝑢
1. EF from Wyoming Chapter 6, Section 2 Oil and Gas Production Facilities Permitting Guidance.
2. EF from Wyoming Chapter 6, Section 2 Oil and Gas Production Facilities Permitting Guidance.
3. Uncontrolled VOC emissions for Pilot derived from Uncontrolled VOC calculation equation below. Tank Vapor and Loading Vapor emissions were developed from ProMax Simulation Model (Hideout
CS Process_20230719.XLSX).
4. Controlled VOC represents the VOC fraction of each individual stream with a 98% destruction efficiency applied. (see Controlled VOC equation below).
5. Controlled HAPs for Pilot derived from the HAP weight fraction of the Inlet and Residue gas streams. Tank Vapor and Loading Vapor emissions were developed from ProMax Simulation Model
(Hideout CS Process_20230719.XLSX).
6. PM10 or PM2.5 factors are identical. From AP-42 Tables 13.5-1 & 2 (lightly smoking)
7. Stream compositions and flow rates were developed from ProMax Simulation Model (Hideout CS Process_20230719.XLSX)
8. EF from Ventura County Air Pollution Control District AB2588 Combustion Emissions Factors (May 17, 2001).
9. CO2 EF from Table C-1 of 40 CFR 98 and N2O EF from Table C-2 of 40 CFR 98.
𝑃𝑀10 𝑙𝑏
ℎ𝑟= 𝐸𝐹
µ
𝐿 𝑥 𝐹𝑙𝑜𝑤 𝑠𝑐𝑓
ℎ𝑟𝑥 10.6 𝑠𝑐𝑓
𝑠𝑐𝑓 𝐶𝐻4 𝑥 0.0283 𝑚ଷ
𝑠𝑐𝑓 𝑥 1000 𝐿
𝑚ଷ 𝑥1𝑔
10଺ µ𝑔 𝑥𝑙𝑏
453.59𝑔
𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑜𝑟𝑔𝑙𝑏
ℎ𝑟= 𝑇𝑜𝑡𝑎𝑙 𝑆𝑡𝑟𝑒𝑎𝑚 𝑅𝑎𝑡𝑒
𝑠𝑐𝑓௧
ℎ𝑟𝑥 𝑆𝑡𝑟𝑒𝑎𝑚 𝑚𝑜𝑙𝑒𝑐𝑢𝑙𝑎𝑟 𝑤𝑒𝑖𝑔ℎ𝑡𝑙𝑏௢௥௚
𝑙𝑏𝑚𝑜𝑙௢௥௚
𝑥1 𝑚𝑜𝑙௢௥௚
379.1𝑠𝑐𝑓௢௥௚
𝑥 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑤𝑒𝑖𝑔ℎ𝑡 𝑓𝑟𝑎𝑐𝑡𝑖𝑜𝑛
𝐶𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏
ℎ𝑟= 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐
𝑙𝑏
ℎ𝑟𝑥 1 − 𝑑𝑒𝑠𝑡𝑟𝑢𝑐𝑡𝑖𝑜𝑛 𝑒𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦
Hideout Compressor Station
Table C-6b: BTEX Combustor (COM-2) - Emissions Calculations 7/20/2023
Make/Model:Annual hours operated:8,760 Destruction Efficiency (%):98
Pilot/Purge Gas Stream
Flow Rate
(scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+
HHV
(btu/scf)
Inlet HP Gas 221 0.843 0.314 77.760 11.189 5.579 0.798 1.998 0.431 0.668 0.247 1,280.59
Streams to Combustor7
Flow Rate
(scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+
HHV
(btu/scf)
BTEX Vapor 201.7 4.558 0.001 4.590 6.810 9.944 2.166 11.339 5.363 11.226 32.606 2,432.0
201.7 2,432.0
Continuent EF Units (lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)
NOx1 0.140 lb/MMBtu 0.040 0.174 0.069 0.301 0.108 0.474
CO2 0.035 lb/MMBtu 0.010 0.043 0.017 0.075 0.027 0.119
Uncontrolled VOC3 3.396 14.876 22.623 99.088 26.019 113.964
Controlled VOC4 0.068 0.298 0.452 1.982 0.520 2.279
PM10 or PM2.5
6 40 µg/L 0.006 0.026 0.005 0.023 0.011 0.049
Benzene 1.31E-04 5.74E-04 7.29E-02 3.19E-01 0.073 0.320
Toluene 2.97E-05 1.30E-04 1.27E-02 5.56E-02 0.013 0.056
n-Hexane 2.44E-03 1.07E-02 4.87E-02 2.13E-01 0.051 0.224
2,2,4-Trimethylpentane 2.31E-05 1.01E-04 3.13E-04 1.37E-03 3.36E-04 1.47E-03
Controlled HAP5 2.63E-03 1.15E-02 1.35E-01 0.590 0.137 0.601
Formaldehyde8 1.169 lb/MMscf 2.58E-04 1.13E-03 2.36E-04 1.03E-03 4.94E-04 2.16E-03
Xylenes8 0.029 lb/MMscf 6.41E-06 2.81E-05 1.30E-04 5.69E-04 1.36E-04 5.97E-04
CO29 116.978 lb/MMBtu 33.11 145.00 57.38 251.32 90.485 396.324
CH4 0.001 0.006 0.006 0.028 0.008 0.035
N2O9 0.0002 lb/MMBtu 6.24E-05 2.73E-04 1.08E-04 4.74E-04 1.71E-04 7.47E-04
Equations:
Emission Factor Pilot BTEX Vapor Total
TBD
Stream Composition (% by volume)
Total Stream
Calculated Criteria Emissions
see Equations
see Equations
see Equations
see Equations ← Note: Values in the blue-
shaded cells to the left were
derived from Bryan
Research & Engineering, Inc.
ProMax™ 5.0 simulation
software program (see Table
C-7).
see Equations
see Equations
see Equations
see Equations
𝑁𝑂𝑥,𝐶𝑂,𝐶𝑂2,𝐶𝐻4 & 𝑁2𝑂 𝑙𝑏
ℎ𝑟= 𝐸𝐹
𝑙𝑏
𝑀𝑀𝑏𝑡𝑢 𝑥 𝐹𝑙𝑜𝑤 𝑅𝑎𝑡𝑒 𝑠𝑐𝑓
ℎ𝑟𝑥 𝐻𝐻𝑉 𝑏𝑡𝑢
𝑠𝑐𝑓 𝑥1 𝑀𝑀𝑏𝑡𝑢
1000000 𝑏𝑡𝑢
1. EF from Wyoming Chapter 6, Section 2 Oil and Gas Production Facilities Permitting Guidance.
2. EF from Wyoming Chapter 6, Section 2 Oil and Gas Production Facilities Permitting Guidance.
3. Uncontrolled VOC emissions for Pilot derived from Uncontrolled VOC calculation equation below. Tank Vapor and Loading Vapor emissions were developed from ProMax Simulation Model (Hideout
CS Process_20230719.XLSX).
4. Controlled VOC represents the VOC fraction of each individual stream with a 98% destruction efficiency applied. (see Controlled VOC equation below).
5. Controlled HAPs for Pilot derived from the HAP weight fraction of the Inlet and Residue gas streams. Tank Vapor and Loading Vapor emissions were developed from ProMax Simulation Model
(Hideout CS Process_20230719.XLSX).
6. PM10 or PM2.5 factors are identical. From AP-42 Tables 13.5-1 & 2 (lightly smoking)
7. Stream compositions and flow rates were developed from ProMax Simulation Model (Hideout CS Process_20230719.XLSX)
8. EF from Ventura County Air Pollution Control District AB2588 Combustion Emissions Factors (May 17, 2001).
𝑃𝑀10 𝑙𝑏
ℎ𝑟= 𝐸𝐹
µ
𝐿 𝑥 𝐹𝑙𝑜𝑤 𝑠𝑐𝑓
ℎ𝑟𝑥 10.6 𝑠𝑐𝑓
𝑠𝑐𝑓 𝐶𝐻4 𝑥 0.0283 𝑚ଷ
𝑠𝑐𝑓 𝑥 1000 𝐿
𝑚ଷ 𝑥1𝑔
10଺ µ𝑔 𝑥𝑙𝑏
453.59𝑔
𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑜𝑟𝑔𝑙𝑏
ℎ𝑟= 𝑇𝑜𝑡𝑎𝑙 𝑆𝑡𝑟𝑒𝑎𝑚 𝑅𝑎𝑡𝑒
𝑠𝑐𝑓௧
ℎ𝑟𝑥 𝑆𝑡𝑟𝑒𝑎𝑚 𝑚𝑜𝑙𝑒𝑐𝑢𝑙𝑎𝑟 𝑤𝑒𝑖𝑔ℎ𝑡𝑙𝑏௢௥௚
𝑙𝑏𝑚𝑜𝑙௢௥௚
𝑥1 𝑚𝑜𝑙௢௥௚
379.1𝑠𝑐𝑓௢௥௚
𝑥 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑤𝑒𝑖𝑔ℎ𝑡 𝑓𝑟𝑎𝑐𝑡𝑖𝑜𝑛
𝐶𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏
ℎ𝑟= 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐
𝑙𝑏
ℎ𝑟𝑥 1 − 𝑑𝑒𝑠𝑡𝑟𝑢𝑐𝑡𝑖𝑜𝑛 𝑒𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦
Hideout Compressor Station
Table C-6: Stream Compositions - Gunbarrel (T-1), Condensate Tanks (T-2 - T-6), Truck Loadout, TEG Dehydration
Total
(to combustor)
Post
Combustor
(98% DE)
Total
(to combustor)
Post
Combustor
(98% DE)
Total
(to combustor)
Post
Combustor
(98% DE)
Total
(to combustor)
Post
Combustor
(98% DE)
CO2 3.820 3.820 2.52E-04 2.52E-04 0.202 0.202 3.861 3.861
N2 0.072 0.072 7.73E-08 7.73E-08 1.64E-03 0.002 0.001 0.001
C1 44.610 0.892 1.30E-04 2.60E-06 2.431 0.049 1.417 0.028
C2 66.898 1.338 2.20E-04 4.40E-06 3.495 0.070 3.941 0.079
C3 95.671 1.913 4.76E-05 9.53E-07 4.882 0.098 8.439 0.169
iC4 25.846 0.517 3.75E-06 7.50E-08 1.292 0.026 2.423 0.048
nC4 76.838 1.537 1.01E-05 2.02E-07 3.812 0.076 12.684 0.254
iC5 32.775 0.655 1.05E-06 2.09E-08 1.598 0.032 7.446 0.149
nC5 59.896 1.198 5.45E-07 1.09E-08 2.899 0.058 15.588 0.312
nC6 37.942 0.759 9.24E-08 1.85E-09 1.787 0.036 10.656 0.213
nC7 12.529 0.251 6.29E-09 1.26E-10 0.576 0.012 1.796 0.036
Benzene 1.742 0.035 1.36E-06 2.73E-08 8.25E-02 1.65E-03 15.957 0.319
o-Xylene 0.034 0.001 1.93E-09 3.86E-11 1.54E-03 3.07E-05 0.028 0.001
Ethylbenzene 0.004 0.000 1.96E-10 3.92E-12 1.59E-04 3.18E-06 0.003 0.000
Toluene 0.681 0.014 1.28E-07 2.57E-09 0.031 6.28E-04 2.779 0.056
Cyclohexane 22.333 0.447 4.93E-07 9.87E-09 1.051 2.10E-02 20.335 0.407
C8 0.487 0.010 2.25E-11 4.51E-13 0.022 4.36E-04 0.020 0.000
Methylcyclohexane 2.383 0.048 1.04E-08 2.08E-10 0.110 2.20E-03 0.865 0.017
2,2,4-Trimethylpentane 0.512 0.010 4.51E-10 9.02E-12 0.024 4.74E-04 0.068 0.001
C10+0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00 0.00E+00
Total VOC 369.67 7.39 6.52E-05 1.30E-06 18.17 0.36 99.09 1.98
Total HAP 40.91 0.82 1.59E-06 3.18E-08 1.93 0.04 29.49 0.59
HHV (Btu/scf)1974.8 82.5 1936.1 2432.0
MW (lb/lb-mole)42.70 18.56 41.77 58.33
Std. Vapor Flow MMscfd 2.88E-02 1.20E-06 1.48E-03 4.84E-03
Sales Oil RVP 12.907 psi
TVP at Average Temp 16.89 psia
Component
TEG Dehydrator Emissions (tpy)Produced Water Loadout (tpy)
Gun Barrel (T-1) & Condensate
Tanks (T-2 - T-6)
Emissions (tpy) Condensate Loadout (tpy)
NOTE: All stream compositions and emissions shown in these tables are from Bryan Research & Engineering, Inc. ProMax™ 5.0 simulation software program for Hideout CSProcess_20230719.xlsx.
Names
Water Content
Units
lbm/MMSCF
Compressed Wet Gas to Dehy
61.3
Dry Gas
1.82
Names
Mass Flow Sum
Units
ton/yr
Compressed Wet Gas to Dehy
449.4
Overheads
47.76
BTEX Emissions to Dehy Combustor
18.77
Temperature
Pressure
Std Vapor Volumetric Flow
120
1452.2
44.999
°F
psia
MMSCFD
Pressure
Temperature
Std Vapor Volumetric Flow
Gross Ideal Gas Heating Value
25*
120
982.7
1523.8
psig
°F
scf/hr
Btu/ft^3
Temperature
Pressure
100*
25*
°F
psia
Temperature 120*°F
Temperature 300*°F
Pressure 1062*psia
Std Liquid Volumetric Flow 7.5*sgpm
Names
Benzene(Mass Flow)
Ethylbenzene(Mass Flow)
Toluene(Mass Flow)
o-Xylene(Mass Flow)
n-Hexane(Mass Flow)
2,2,4-Trimethylpentane(Mass Flow)
Units
ton/yr
ton/yr
ton/yr
ton/yr
ton/yr
ton/yr
Flash Gas to Fuel System
1.4539
0.00043098
0.25737
0.0034909
13.141
0.094271
BTEX Emissions to Dehy Combustor
15.957
0.0025168
2.7788
0.028444
10.656
0.068441
Std Vapor Volumetric Flow
Gross Ideal Gas Heating Value
Temperature
201.69
2432
120*
scfh
Btu/ft^3
°F
Process Streams BTEX Emissions to Dehy Combustor
Composition Status: Solved
Phase: Total From Block: BTEX Tank
To Block:--
%
4.58953
6.80960
9.94444
2.16588
11.3390
5.36253
11.2261
6.42519
0.931154
10.6143
0.0139211
0.00123178
1.56704
11.3979
3.92021E-06
0.00124963
0
0
4.55817
0
12.5546
0.00912371
0.457902
0.0311319
0
0
lbmol/h
0.0201666
0.0299217
0.0436963
0.00951697
0.0498241
0.0235632
0.0493278
0.0282325
0.00409153
0.0466395
6.11698E-05
5.41250E-06
0.00688565
0.0500829
1.72256E-08
5.49092E-06
0
0
0.0200288
0
0.0551656
4.00900E-05
0.00201204
0.000136795
0
0
i-Pentane
n-Pentane
n-Hexane
n-Heptane
Benzene
o-Xylene
Mole Fraction
Methane
Ethane
Propane
i-Butane
n-Butane
Argon
Carbon Dioxide
Carbon Monoxide
Cyclohexane
C8
Methylcyclohexane
Ethylbenzene
Toluene
Water
Triethylene Glycol
Nitrogen
Oxygen
Propane
i-Butane
n-Butane
i-Pentane
n-Pentane
n-Hexane
2,2,4-Trimethylpentane
C10+
C9
Molar Flow
Methane
Ethane
Triethylene Glycol
Nitrogen
Oxygen
Argon
Carbon Dioxide
Carbon Monoxide
n-Heptane
Benzene
o-Xylene
Ethylbenzene
Toluene
Water
Cyclohexane
C8
Methylcyclohexane
2,2,4-Trimethylpentane
C10+
C9
%
1.26228
3.51041
7.51783
2.15821
11.2988
6.63308
13.8859
9.49260
1.59961
14.2142
0.0253379
0.00224198
2.47536
3.52032
1.00929E-05
0.000600155
0
0
3.43917
0
18.1144
0.0178675
0.770795
0.0609672
0
0
lb/h
0.323522
0.899716
1.92682
0.553147
2.89588
1.70005
3.55894
2.43295
0.409979
3.64310
0.00649409
0.000574618
0.634433
0.902257
2.58681E-06
0.000153819
0
0
0.881457
0
4.64271
0.00457942
0.197554
0.0156259
0
0
Mass Fraction
Methane
Ethane
Propane
i-Butane
n-Butane
Ethylbenzene
Toluene
Water
Triethylene Glycol
Nitrogen
Oxygen
i-Pentane
n-Pentane
n-Hexane
n-Heptane
Benzene
o-Xylene
2,2,4-Trimethylpentane
C10+
C9
Mass Flow
Methane
Ethane
Argon
Carbon Dioxide
Carbon Monoxide
Cyclohexane
C8
Methylcyclohexane
n-Heptane
Benzene
o-Xylene
Ethylbenzene
Toluene
Water
Propane
i-Butane
n-Butane
i-Pentane
n-Pentane
n-Hexane
Cyclohexane
C8
Methylcyclohexane
2,2,4-Trimethylpentane
C10+
C9
Triethylene Glycol
Nitrogen
Oxygen
Argon
Carbon Dioxide
Carbon Monoxide
Process Streams BTEX Emissions to Dehy Combustor
Properties Status: Solved
Phase: Total From Block: BTEX Tank
To Block:--
Property Units
Temperature °F 120*
Pressure psia 14.7
Mole Fraction Vapor % 100
Mole Fraction Light Liquid % 0
Mole Fraction Heavy Liquid % 0
Phase Mole Fraction % 100
Molecular Weight lb/lbmol 58.3289
Mass Density lb/ft^3 0.140681
Molar Flow lbmol/h 0.439404
Mass Flow lb/h 25.6299
Vapor Volumetric Flow ft^3/h 182.185
Liquid Volumetric Flow gpm 22.7139
Std Vapor Volumetric Flow MMSCFD 0.00484050
Std Liquid Volumetric Flow sgpm 0.0779824
Compressibility 0.979762
Specific Gravity 2.01394
API Gravity
Enthalpy Btu/h -23451.9
Mass Enthalpy Btu/lb -915.020
Mass Cp Btu/(lb*°F) 0.380568
Ideal Gas CpCv Ratio 1.09911
Dynamic Viscosity cP 0.00875479
Kinematic Viscosity cSt 3.88498
Thermal Conductivity Btu/(h*ft*°F) 0.0100966
Surface Tension lbf/ft
Net Ideal Gas Heating Value Btu/ft^3 2258.54
Net Liquid Heating Value Btu/lb 17580.4
Gross Ideal Gas Heating Value Btu/ft^3 2432.04
Gross Liquid Heating Value Btu/lb 18946.2
Std Liquid Volumetric Flow
API Gravity 60F/60F
Specific Gravity 60F/60F
572.81
72.778
0.69268
bbl/d
Temperature
Pressure
50
25
°F
psig
Temperature
Pressure
62.096*
0*
°F
psig
Temperature
Pressure
Std Liquid Volumetric Flow
50
25*
601.43
°F
psig
bbl/day
Temperature
Pressure
Std Vapor Volumetric Flow
80*
25*
46.754
°F
psig
MMSCFD
Names
Benzene(Mass Flow)
Toluene(Mass Flow )
Ethylbenzene(Mass Flow )
o-Xylene(Mass Flow)
n-Hexane(Mass Flow)
2,2,4-Trimethylpentane(Mass Flow )
Units
ton/yr
ton/yr
ton/yr
ton/yr
ton/yr
ton/yr
Total CND Tank Emissions
0.10804
0.041109
0.00020832
0.00201
2.3392
0.031041
CND Tank Loadout Em
0.082519
0.031399
0.00015911
0.0015352
1.7866
0.023709
Pit Tank Loadout Em
1.3646e-06*
1.2827e-07*
1.9624e-10*
1.9294e-09*
9.2394e-08*
4.5081e-10*
GB Overhead Gas
1.6335
0.63944
0.0033348
0.032294
35.603
0.4811
Std Liquid Volumetric Flow
True Vapor Pressure
Reid Vapor Pressure
22.996
18.871
1.0799
bbl/d
psia
psi
Names
Std Liquid Volumetric Flow
Units
bbl/d
8
1002.6
1
1050.9
6
1000.1
Process Streams CND Tank Loadout Em GB Overhead Gas Gunbarrel and CND Tank Emissions Pit Tank Loadout Em Total CND Tank Emissions
Composition Status: Solved Solved Solved Solved Solved
Phase: Total From Block:(5) 400-bbl Condensate Tanks (1) 400-bbl Gunbarrel (Pit) Tank MIX-101 --MIX-102
To Block: MIX-105 MIX-101 MIX-105 MIX-105 MIX-101
%%%%%
25.8244 24.1351 24.2483 1.69123* 25.8244
19.8135 19.3710 19.4007 1.53007* 19.8135
18.8717 18.9230 18.9196 0.225808* 18.8717
3.79010 3.88397 3.87768 0.0134891* 3.79010
11.1787 11.5531 11.5281 0.0362870* 11.1787
3.77589 3.97456 3.96125 0.00303177* 3.77589
6.84792 7.26728 7.23919 0.00158053* 6.84792
3.53379 3.86131 3.83938 0.000224148* 3.53379
0.980204 1.09823 1.09032 1.31227E-05* 0.980204
0.180062 0.195449 0.194418 0.00365231* 0.180062
0.00246474 0.00284295 0.00281762 3.79951E-06* 0.00246474
0.000255444 0.000293574 0.000291020 3.86438E-07* 0.000255444
0.0580837 0.0648621 0.0644081 0.000291038* 0.0580837
1.96269 2.27354 2.25271 95.2946* 1.96269
5.71930E-09 1.33521E-08 1.28408E-08 2.73967E-06* 5.71930E-09
0.00999703 0.0231690 0.0222867 0.000576855* 0.00999703
0 0 0 0* 0
0 0 0 0* 0
0.783303 0.754956 0.756854 1.19787* 0.783303
0 0 0 0* 0
2.12828 2.32734 2.31400 0.00122587* 2.12828
0.0325579 0.0374746 0.0371452 4.12412E-08* 0.0325579
0.190697 0.213116 0.211614 2.21668E-05* 0.190697
0.0353770 0.0393640 0.0390970 8.25079E-07* 0.0353770
0 0 0 0* 0
0 0 0 0* 0
lbmol/h lbmol/h lbmol/h lbmol/h lbmol/h
0.0345916 0.589576 0.634866 1.84694E-06* 0.0452899
0.0265401 0.473198 0.507946 1.67094E-06* 0.0347483
0.0252785 0.462254 0.495351 2.46598E-07* 0.0330965
0.00507681 0.0948782 0.101525 1.47311E-08* 0.00664694
0.0149738 0.282222 0.301827 3.96279E-08* 0.0196048
0.00505779 0.0970911 0.103713 3.31091E-09* 0.00662204
0.00917274 0.177526 0.189536 1.72605E-09* 0.0120096
0.00473349 0.0943248 0.100522 2.44786E-10* 0.00619743
0.00131298 0.0268276 0.0285467 1.43309E-11* 0.00171905
0.000241192 0.00477446 0.00509025 3.98857E-09* 0.000315786
3.30151E-06 6.94481E-05 7.37706E-05 4.14932E-12* 4.32258E-06
3.42165E-07 7.17148E-06 7.61947E-06 4.22017E-13* 4.47988E-07
7.78027E-05 0.00158446 0.00168633 3.17834E-10* 0.000101865
0.00262901 0.0555383 0.0589804 0.000104068* 0.00344210
7.66096E-12 3.26167E-10 3.36197E-10 2.99191E-12* 1.00303E-11
1.33910E-05 0.000565977 0.000583510 6.29965E-10* 1.75325E-05
0 0 0 0* 0
0 0 0 0* 0
0.00104923 0.0184422 0.0198159 1.30816E-06* 0.00137373
0 0 0 0* 0
0.00285082 0.0568525 0.0605850 1.33874E-09* 0.00373251
4.36111E-05 0.000915435 0.000972534 4.50383E-14* 5.70989E-05
0.000255437 0.00520603 0.00554046 2.42076E-11* 0.000334437
4.73872E-05 0.000961591 0.00102363 9.01044E-13* 6.20429E-05
0 0 0 0* 0
0 0 0 0* 0
%%%%%
9.91854 9.05240 9.10914 1.46163 9.91854
14.2636 13.6181 13.6603 2.47852 14.2636
19.9229 19.5087 19.5359 0.536412 19.9229
5.27398 5.27790 5.27764 0.0422365 5.27398
15.5554 15.6995 15.6900 0.113620 15.5554
6.52222 6.70442 6.69248 0.0117839 6.52222
11.8286 12.2587 12.2305 0.00614319 11.8286
7.29071 7.77968 7.74764 0.00104059 7.29071
2.35147 2.57283 2.55833 7.08373E-05 2.35147
0.336732 0.356939 0.355615 0.0153690 0.336732
0.00626469 0.00705658 0.00700469 2.17306E-05 0.00626469
0.000649266 0.000728690 0.000723487 2.21016E-06 0.000649266
0.128127 0.139725 0.138965 0.00144462 0.128127
0.846525 0.957605 0.950327 92.4851 0.846525
2.05627E-08 4.68797E-08 4.51555E-08 2.21642E-05 2.05627E-08
0.00670476 0.0151746 0.0146197 0.000870552 0.00670476
0 0 0 0 0
0 0 0 0 0
0.825320 0.776804 0.779982 2.84001 0.825320
0 0 0 0 0
4.28823 4.57937 4.56029 0.00555791 4.28823
0.0890384 0.100082 0.0993582 2.53787E-07 0.0890384
0.448270 0.489225 0.486542 0.000117250 0.448270
0.0967479 0.105128 0.104579 5.07730E-06 0.0967479
0 0 0 0 0
0 0 0 0 0
2,2,4-Trimethylpentane
C10+
C9
Argon
Carbon Dioxide
Carbon Monoxide
Cyclohexane
C8
Methylcyclohexane
Ethylbenzene
Toluene
Water
Triethylene Glycol
Nitrogen
Oxygen
i-Pentane
n-Pentane
n-Hexane
n-Heptane
Benzene
o-Xylene
Mass Fraction
Methane
Ethane
Propane
i-Butane
n-Butane
Cyclohexane
C8
Methylcyclohexane
2,2,4-Trimethylpentane
C10+
C9
Triethylene Glycol
Nitrogen
Oxygen
Argon
Carbon Dioxide
Carbon Monoxide
n-Heptane
Benzene
o-Xylene
Ethylbenzene
Toluene
Water
Propane
i-Butane
n-Butane
i-Pentane
n-Pentane
n-Hexane
2,2,4-Trimethylpentane
C10+
C9
Molar Flow
Methane
Ethane
Argon
Carbon Dioxide
Carbon Monoxide
Cyclohexane
C8
Methylcyclohexane
Ethylbenzene
Toluene
Water
Triethylene Glycol
Nitrogen
Oxygen
i-Pentane
n-Pentane
n-Hexane
n-Heptane
Benzene
o-Xylene
Mole Fraction
Methane
Ethane
Propane
i-Butane
n-Butane
lb/h lb/h lb/h lb/h lb/h
0.554935 9.45826 10.1848 2.96295E-05* 0.726562
0.798036 14.2286 15.2735 5.02435E-05* 1.04485
1.11467 20.3834 21.8428 1.08739E-05* 1.45941
0.295076 5.51453 5.90086 8.56201E-07* 0.386335
0.870311 16.4034 17.5428 2.30326E-06* 1.13948
0.364913 7.00501 7.48278 2.38878E-07* 0.477772
0.661802 12.8083 13.6748 1.24532E-07* 0.866481
0.407910 8.12847 8.66254 2.10945E-08* 0.534066
0.131563 2.68818 2.86043 1.43598E-09* 0.172252
0.0188399 0.372942 0.397608 3.11555E-07* 0.0246666
0.000350505 0.00737295 0.00783186 4.40513E-10* 0.000458907
3.63260E-05 0.000761361 0.000808921 4.48035E-11* 4.75607E-05
0.00716862 0.145990 0.155376 2.92847E-08* 0.00938569
0.0473624 1.00054 1.06255 0.00187482* 0.0620104
1.15047E-09 4.89815E-08 5.04878E-08 4.49304E-10* 1.50628E-09
0.000375127 0.0158549 0.0163461 1.76475E-08* 0.000491144
0 0 0 0* 0
0 0 0 0* 0
0.0461761 0.811631 0.872088 5.75715E-05* 0.0604572
0 0 0 0* 0
0.239924 4.78468 5.09880 1.12668E-07* 0.314126
0.00498163 0.104569 0.111091 5.14465E-12* 0.00652233
0.0250804 0.511159 0.543996 2.37685E-09* 0.0328371
0.00541297 0.109841 0.116928 1.02925E-10* 0.00708707
0 0 0 0* 0
0 0 0 0*0
Process Streams CND Tank Loadout Em GB Overhead Gas Gunbarrel and CND Tank Emissions Pit Tank Loadout Em Total CND Tank Emissions
Properties Status: Solved Solved Solved Solved Solved
Phase: Total From Block: (5) 400-bbl Condensate Tanks (1) 400-bbl Gunbarrel (Pit) Tank MIX-101 -- MIX-102
To Block: MIX-105 MIX-101 MIX-105 MIX-105 MIX-101
Property Units
Temperature °F 62.0960 62.096* 62.0937 61.5564 62.0960
Pressure psia 12.34 12.15* 12.15 0.281670 12.34
Mole Fraction Vapor % 100 100 100 100 100
Mole Fraction Light Liquid % 0 0 0 0 0
Mole Fraction Heavy Liquid % 0 0 0 0 0
Phase Mole Fraction % 100 100 100 100 100
Molecular Weight lb/lbmol 41.7689 42.7717 42.7045 18.5625 41.7689
Mass Density lb/ft^3 0.0931864 0.0939920 0.0938410 0.000935002 0.0931864
Molar Flow lbmol/h 0.133949 2.44282 2.61819 0.000109207 0.175377
Mass Flow lb/h 5.59493 104.483 111.809 0.00202716 7.32530
Vapor Volumetric Flow ft^3/h 60.0401 1111.62 1191.47 2.16808 78.6090
Liquid Volumetric Flow gpm 7.48552 138.592 148.547 0.270306 9.80061
Std Vapor Volumetric Flow MMSCFD 0.00147559 0.0269102 0.0288422 1.20303E-06 0.00193196
Std Liquid Volumetric Flow sgpm 0.0224465 0.413582 0.442970 4.42430E-06 0.0293886
Compressibility 0.987817 0.987422 0.987462 0.999713 0.987817
Specific Gravity 1.44217 1.47680 1.47448 0.640917 1.44217
API Gravity
Enthalpy Btu/h -6324.25 -117063 -125343 -11.1887 -8280.18
Mass Enthalpy Btu/lb -1130.35 -1120.40 -1121.05 -5519.39 -1130.35
Mass Cp Btu/(lb*°F) 0.402529 0.400983 0.401080 0.437765 0.402529
Ideal Gas CpCv Ratio 1.13490 1.13190 1.13210 1.32353 1.13490
Dynamic Viscosity cP 0.00845169 0.00838505 0.00838941 0.00989650 0.00845169
Kinematic Viscosity cSt 5.66200 5.56922 5.58108 660.767 5.66200
Thermal Conductivity Btu/(h*ft*°F) 0.0112749 0.0110902 0.0111023 0.0115721 0.0112749
Surface Tension lbf/ft
Net Ideal Gas Heating Value Btu/ft^3 1780.16 1818.91 1816.32 39.0677 1780.16
Net Liquid Heating Value Btu/lb 19412.1 19366.9 19369.9 -21.1499 19412.1
Gross Ideal Gas Heating Value Btu/ft^3 1936.13 1977.63 1974.85 82.5171 1936.13
Gross Liquid Heating Value Btu/lb 21126.7 21070.8 21074.4 1053.29 21126.7
Cyclohexane
C8
Methylcyclohexane
2,2,4-Trimethylpentane
C10+
C9
Triethylene Glycol
Nitrogen
Oxygen
Argon
Carbon Dioxide
Carbon Monoxide
n-Heptane
Benzene
o-Xylene
Ethylbenzene
Toluene
Water
Propane
i-Butane
n-Butane
i-Pentane
n-Pentane
n-Hexane
Mass Flow
Methane
Ethane
Hideout Compressor Station Emission Source: Fugitives
Table C-8:Fugitive Equipment Leaks Emissions Calculations Operating Hours:
Emission
Equipment Factors (a)
Service Type kg/hr/source
Count (b)wt %lb/hr (c)tpy (d)wt %lb/hr (c)tpy (d)wt %lb/hr (c)tpy (d)wt %lb/hr (c)tpy (d)wt %lb/hr (c)tpy (d)wt %lb/hr (c)tpy (d)wt %lb/hr (c)tpy (d)
Valves 2.50E-05 297 0.00 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.04
Pump Seals 3.50E-04 140 0.03 0.12 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.06 0.27
Others 1.20E-04 378 0.02 0.11 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.06 0.25
Connectors 1.00E-05 665 0.00 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.04
Flanges 5.70E-06 1245 0.00 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.04
Open-Ended 1.50E-05 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Valves 1.90E-05 178 0.01 0.03 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Pump Seals 5.10E-04 5 0.01 0.02 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Others 1.10E-04 68 0.02 0.07 0.00 0.02 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Connectors 9.70E-06 317 0.01 0.03 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Flanges 2.40E-06 477 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Open-Ended 1.40E-05 3 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Valves 9.70E-06 432 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Pump Seals 2.40E-05 70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Others 5.90E-05 420 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Connectors 1.00E-05 1108 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Flanges 2.90E-06 70 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Open-Ended 3.50E-06 0 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
5873 0.10 0.44 1.07E-02 4.67E-02 4.75E-04 2.08E-03 5.82E-04 2.55E-03 1.08E-05 4.74E-05 1.33E-04 5.83E-04 0.15 0.65
Notes:
(a) Emission factors are from Table 2-8 of the "Protocol for Equipment Leak Emission Estimates". EPA-453/R-95-017.
(b) Based on scaled equipment count from Farm Compression Station.
(c) Hourly Emission Rate (lb/hr) = (Emission Factor, kg/hour/source) * (count) * (1000 kg/g) / (453.59 g/lb) * (wt %)
(d) Annual Emission Rate (tpy) = (Hourly Emission Rate, lb/hr) * (hr/yr) / (2,000 lb/ton)
(e) Weight Percents of Hydrocarbons taken from Farm CS discharge to be representative inlet gas composition for Hideout CS.
(f) Weight Percents of Hydrocarbons taken from condensate stream from Bryan Research & Engineering, Inc. ProMax™ 5.0 simulation software program for Hideout CS Process_20230719.xlsx. *Available upon request*
7/1/2023
8,760 hr/yr
VOC n-Hexane Benzene Toluene Ethylbenzene Xylene
Emissions
1.43% 0.03%
CH4
Gas (e)24.37% 0.64% 0.0298% 0.0090% 0.0000% 0.0000% 57.88%
Total
0.34% 0.02%
Water/Oil
Light Oil (f)99.76% 23.16% 1.03%
Natural Gas Composition- Inlet Gas (Single Stage)
Company
Division
District
State
Field
Facility
1280.59
Sales/Fuel Gas Mole PercentP = true vapor pressure of liquid loaded (psia). TVP derived from stream compositions in Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program for Farm CS Process_20191126 20psig.pmx.xlsx.Weight Weight
Fraction
Carbon
Weight HHV
Nitrogen N2 0.31 28.00 0.088 0.004 0.00 0.00
Hydrogen Sulfide H2S 0.00 34.08 0.000 0.000 0.00 0.00
Carbonyl Sulfide COS 0.00 60.08 0.000 0.000 0.00 0.00
Carbon Disulfide CS2 0.00 76.14 0.000 0.000 0.00 0.00
Carbon Dioxide CO2 0.843 44.00 0.371 0.017 0.10 0.00
Methane CH4 77.7599 16.00 12.442 0.579 9.33 78424.65
Ethane C2H6 11.1886 30.00 3.357 0.156 2.69 19838.36
Propane C3H8 5.5791 44.00 2.455 0.114 2.01 14055.21
isoButane C4H10 0.7975 58.00 0.463 0.022 0.38 2594.73
n-Butane C4H10 1.9979 58.00 1.159 0.054 0.96 6515.91
isoPentane C5H12 0.4311 72.00 0.310 0.014 0.26 1724.36
n-Pentane C5H12 0.668 72.00 0.481 0.022 0.40 2876.63
Hexane C6H14 (w/o n-Hexane)0.1859 86.00 0.160 0.007 0.13 883.46
n-Hexane C6H14 0.1606 86.00 0.138 0.006 0.12 757.41
Benzene C6H6 0.008 78.11 0.006 0.000 0.01 30.77
C7+0.06 100.00 0.061 0.003 0.04 334.98
Toluene 0.002 92.14 0.002 0.000 0.00 9.42
Ethylbenzene 0.00 106.17 0.000 0.000 0.00 0.00
Xylenes 0.00 106.17 0.000 0.000 0.00 0.00
2,2,4-Trimethylpentane 0.00 114.22 0.003 0.000 0.00 12.93
100.00 21.495 1.000 0.764 1280.59
Calculated Gas Properties
Gas Molecular Weight 21.495 g/gmol, lb/lbmol
Carbon Weight Fraction 0.764
Calculated Gas HHV 1280.588 Btu/scf
VOC Weight Fraction 0.24
HAP Weight Fraction 0.01
Kinder Morgan
Midstream
Utah
Altamont
Fuel Composition Applicability Hideout single stage inlet post slug catcher
Fuel Higher Heating Value (Btu/scf)
Hideout CS
Composition Identification Number Farm CS Discharge Gas
Data Source/Reference and Contact Person Farm CS Discharge Gas
Natural Gas Composition- Inlet Gas (3-Stage)
Company
Division
District
State
Field
Facility
1358.32
Sales/Fuel Gas Mole PercentP = true vapor pressure of liquid loaded (psia). TVP derived from stream compositions in Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program for Farm CS Process_20191126 20psig.pmx.xlsx.Weight Weight
Fraction
Carbon
Weight HHV
Nitrogen N2 0.27 28.00 0.075 0.003 0.00 0.00
Hydrogen Sulfide H2S 0.00 34.08 0.000 0.000 0.00 0.00
Carbonyl Sulfide COS 0.00 60.08 0.000 0.000 0.00 0.00
Carbon Disulfide CS2 0.00 76.14 0.000 0.000 0.00 0.00
Carbon Dioxide CO2 0.8741 44.00 0.385 0.017 0.10 0.00
Methane CH4 74.7713 16.00 11.963 0.522 8.97 75410.51
Ethane C2H6 11.9154 30.00 3.575 0.156 2.86 21127.04
Propane C3H8 5.9551 44.00 2.620 0.114 2.14 15002.45
isoButane C4H10 0.853 58.00 0.495 0.022 0.41 2775.30
n-Butane C4H10 2.2058 58.00 1.279 0.056 1.06 7193.95
isoPentane C5H12 0.5975 72.00 0.430 0.019 0.36 2389.94
n-Pentane C5H12 1.0338 72.00 0.744 0.032 0.62 4451.89
Hexane C6H14 (w/o n-Hexane)0.5504 86.00 0.473 0.021 0.40 2615.68
n-Hexane C6H14 0.5167 86.00 0.444 0.019 0.37 2436.81
Benzene C6H6 0.030 78.11 0.023 0.001 0.02 111.82
C7+0.39 100.00 0.387 0.017 0.28 2110.83
Toluene 0.024 92.14 0.022 0.001 0.02 106.26
Ethylbenzene 0.00 106.17 0.000 0.000 0.00 2.07
Xylenes 0.00 106.17 0.005 0.000 0.00 25.60
2,2,4-Trimethylpentane 0.01 114.22 0.015 0.001 0.01 71.39
100.00 22.937 1.000 0.768 1358.32
Calculated Gas Properties
Gas Molecular Weight 22.937 g/gmol, lb/lbmol
Carbon Weight Fraction 0.768
Calculated Gas HHV 1358.315 Btu/scf
VOC Weight Fraction 0.30
HAP Weight Fraction 0.02
Fuel Higher Heating Value (Btu/scf)
Composition Identification Number
Data Source/Reference and Contact Person Harvest Inlet Ravolla CS. October 9, 2019
Fuel Composition Applicability Hideout Station inlet post slug catcher
Hideout Compressor Station
Kinder Morgan
Midstream
Utah
Altamont
TANKS 4.0.9d
Emissions Report - Detail Format
Tank Indentification and Physical Characteristics
Identification
User Identification:LO Tank
City:Salt Lake City
State:Utah
Company:
Type of Tank:Vertical Fixed Roof Tank
Description:200 bbl Lube Oil Tank at Hideout Compressor Station
Tank Dimensions
Shell Height (ft):10.00
Diameter (ft):12.00
Liquid Height (ft) :9.00
Avg. Liquid Height (ft):6.00
Volume (gallons):7,614.27
Turnovers:4.00
Net Throughput(gal/yr):30,457.07
Is Tank Heated (y/n):N
Paint Characteristics
Shell Color/Shade:Gray/Light
Shell Condition Good
Roof Color/Shade:Gray/Light
Roof Condition:Good
Roof Characteristics
Type:Cone
Height (ft)0.50
Slope (ft/ft) (Cone Roof)0.10
Breather Vent Settings
Vacuum Settings (psig):-0.03
Pressure Settings (psig)0.03
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure = 12.64 psia)
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LO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Liquid Contents of Storage Tank
LO Tank - Vertical Fixed Roof Tank
Salt Lake City, Utah
Daily Liquid Surf.
Temperature (deg F)
Liquid
Bulk
Temp Vapor Pressure (psia)
Vapor
Mol.
Liquid
Mass
Vapor
Mass Mol. Basis for Vapor Pressure
Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract. Fract. Weight Calculations
Jet naphtha (JP-4)All 59.41 49.72 69.11 54.20 1.2823 0.9944 1.5732 80.0000 120.00 Option 1: VP50 = 1 VP60 = 1.3
Page 2 of 6TANKS 4.0 Report
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LO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Detail Calculations (AP-42)
LO Tank - Vertical Fixed Roof Tank
Salt Lake City, Utah
Annual Emission Calcaulations
Standing Losses (lb):297.1280
Vapor Space Volume (cu ft):471.2389
Vapor Density (lb/cu ft):0.0184
Vapor Space Expansion Factor:0.1204
Vented Vapor Saturation Factor:0.7793
Tank Vapor Space Volume:
Vapor Space Volume (cu ft):471.2389
Tank Diameter (ft):12.0000
Vapor Space Outage (ft):4.1667
Tank Shell Height (ft):10.0000
Average Liquid Height (ft):6.0000
Roof Outage (ft):0.1667
Roof Outage (Cone Roof)
Roof Outage (ft):0.1667
Roof Height (ft):0.5000
Roof Slope (ft/ft):0.1000
Shell Radius (ft):6.0000
Vapor Density
Vapor Density (lb/cu ft):0.0184
Vapor Molecular Weight (lb/lb-mole):80.0000
Vapor Pressure at Daily Average Liquid
Surface Temperature (psia):1.2823
Daily Avg. Liquid Surface Temp. (deg. R):519.0816
Daily Average Ambient Temp. (deg. F):51.9625
Ideal Gas Constant R
(psia cuft / (lb-mol-deg R)):10.731
Liquid Bulk Temperature (deg. R):513.8725
Tank Paint Solar Absorptance (Shell):0.5400
Tank Paint Solar Absorptance (Roof):0.5400
Daily Total Solar Insulation
Factor (Btu/sqft day):1,452.1184
Vapor Space Expansion Factor
Vapor Space Expansion Factor:0.1204
Daily Vapor Temperature Range (deg. R):38.7740
Daily Vapor Pressure Range (psia):0.5788
Breather Vent Press. Setting Range(psia):0.0600
Vapor Pressure at Daily Average Liquid
Surface Temperature (psia):1.2823
Vapor Pressure at Daily Minimum Liquid
Surface Temperature (psia):0.9944
Vapor Pressure at Daily Maximum Liquid
Surface Temperature (psia):1.5732
Daily Avg. Liquid Surface Temp. (deg R):519.0816
Daily Min. Liquid Surface Temp. (deg R):509.3881
Daily Max. Liquid Surface Temp. (deg R):528.7751
Daily Ambient Temp. Range (deg. R):23.3583
Vented Vapor Saturation Factor
Vented Vapor Saturation Factor:0.7793
Vapor Pressure at Daily Average Liquid:
Surface Temperature (psia):1.2823
Vapor Space Outage (ft):4.1667
Working Losses (lb):74.3935
Vapor Molecular Weight (lb/lb-mole):80.0000
Vapor Pressure at Daily Average Liquid
Surface Temperature (psia):1.2823
Annual Net Throughput (gal/yr.):30,457.0664
Annual Turnovers:4.0000
Turnover Factor:1.0000
Maximum Liquid Volume (gal):7,614.2666
Maximum Liquid Height (ft):9.0000
Tank Diameter (ft):12.0000
Working Loss Product Factor:1.0000
Total Losses (lb):371.5215
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LO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Individual Tank Emission Totals
Emissions Report for: Annual
LO Tank - Vertical Fixed Roof Tank
Salt Lake City, Utah
Losses(lbs)
Components Working Loss Breathing Loss Total Emissions
Jet naphtha (JP-4) 74.39 297.13 371.52
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LO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Tank Indentification and Physical Characteristics
Identification
User Identification:ULO Tank
City:Salt Lake City
State:Utah
Company:
Type of Tank:Vertical Fixed Roof Tank
Description:200 bbl Lube Oil Tank at Hideout Compressor Station
Tank Dimensions
Shell Height (ft):10.00
Diameter (ft):12.00
Liquid Height (ft) :9.00
Avg. Liquid Height (ft):6.00
Volume (gallons):7,614.27
Turnovers:4.00
Net Throughput(gal/yr):30,457.07
Is Tank Heated (y/n):N
Paint Characteristics
Shell Color/Shade:Gray/Light
Shell Condition Good
Roof Color/Shade:Gray/Light
Roof Condition:Good
Roof Characteristics
Type:Cone
Height (ft)0.50
Slope (ft/ft) (Cone Roof)0.10
Breather Vent Settings
Vacuum Settings (psig):-0.03
Pressure Settings (psig)0.03
Meterological Data used in Emissions Calculations: Salt Lake City, Utah (Avg Atmospheric Pressure = 12.64 psia)
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ULO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Liquid Contents of Storage Tank
ULO Tank - Vertical Fixed Roof Tank
Salt Lake City, Utah
Daily Liquid Surf.
Temperature (deg F)
Liquid
Bulk
Temp Vapor Pressure (psia)
Vapor
Mol.
Liquid
Mass
Vapor
Mass Mol. Basis for Vapor Pressure
Mixture/Component Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract. Fract. Weight Calculations
Jet naphtha (JP-4)All 59.41 49.72 69.11 54.20 1.2823 0.9944 1.5732 80.0000 120.00 Option 1: VP50 = 1 VP60 = 1.3
Page 2 of 6TANKS 4.0 Report
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ULO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Detail Calculations (AP-42)
ULO Tank - Vertical Fixed Roof Tank
Salt Lake City, Utah
Annual Emission Calcaulations
Standing Losses (lb):297.1280
Vapor Space Volume (cu ft):471.2389
Vapor Density (lb/cu ft):0.0184
Vapor Space Expansion Factor:0.1204
Vented Vapor Saturation Factor:0.7793
Tank Vapor Space Volume:
Vapor Space Volume (cu ft):471.2389
Tank Diameter (ft):12.0000
Vapor Space Outage (ft):4.1667
Tank Shell Height (ft):10.0000
Average Liquid Height (ft):6.0000
Roof Outage (ft):0.1667
Roof Outage (Cone Roof)
Roof Outage (ft):0.1667
Roof Height (ft):0.5000
Roof Slope (ft/ft):0.1000
Shell Radius (ft):6.0000
Vapor Density
Vapor Density (lb/cu ft):0.0184
Vapor Molecular Weight (lb/lb-mole):80.0000
Vapor Pressure at Daily Average Liquid
Surface Temperature (psia):1.2823
Daily Avg. Liquid Surface Temp. (deg. R):519.0816
Daily Average Ambient Temp. (deg. F):51.9625
Ideal Gas Constant R
(psia cuft / (lb-mol-deg R)):10.731
Liquid Bulk Temperature (deg. R):513.8725
Tank Paint Solar Absorptance (Shell):0.5400
Tank Paint Solar Absorptance (Roof):0.5400
Daily Total Solar Insulation
Factor (Btu/sqft day):1,452.1184
Vapor Space Expansion Factor
Vapor Space Expansion Factor:0.1204
Daily Vapor Temperature Range (deg. R):38.7740
Daily Vapor Pressure Range (psia):0.5788
Breather Vent Press. Setting Range(psia):0.0600
Vapor Pressure at Daily Average Liquid
Surface Temperature (psia):1.2823
Vapor Pressure at Daily Minimum Liquid
Surface Temperature (psia):0.9944
Vapor Pressure at Daily Maximum Liquid
Surface Temperature (psia):1.5732
Daily Avg. Liquid Surface Temp. (deg R):519.0816
Daily Min. Liquid Surface Temp. (deg R):509.3881
Daily Max. Liquid Surface Temp. (deg R):528.7751
Daily Ambient Temp. Range (deg. R):23.3583
Vented Vapor Saturation Factor
Vented Vapor Saturation Factor:0.7793
Vapor Pressure at Daily Average Liquid:
Surface Temperature (psia):1.2823
Vapor Space Outage (ft):4.1667
Working Losses (lb):74.3935
Vapor Molecular Weight (lb/lb-mole):80.0000
Vapor Pressure at Daily Average Liquid
Surface Temperature (psia):1.2823
Annual Net Throughput (gal/yr.):30,457.0664
Annual Turnovers:4.0000
Turnover Factor:1.0000
Maximum Liquid Volume (gal):7,614.2666
Maximum Liquid Height (ft):9.0000
Tank Diameter (ft):12.0000
Working Loss Product Factor:1.0000
Total Losses (lb):371.5215
Page 3 of 6TANKS 4.0 Report
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ULO-Tank
TANKS 4.0.9d
Emissions Report - Detail Format
Individual Tank Emission Totals
Emissions Report for: Annual
ULO Tank - Vertical Fixed Roof Tank
Salt Lake City, Utah
Losses(lbs)
Components Working Loss Breathing Loss Total Emissions
Jet naphtha (JP-4) 74.39 297.13 371.52
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ULO-Tank
Appendix D
Facility Emission Forms
1.Form 5 - Table D-1
2.Form 5 - Table D-1a
Form 5 Company
Emissions Information Site
Criteria /GHGs/HAP's Date
Utah Division of Air Quality
New Source Review Section
Criteria Pollutants
PM10
PM10 Fugitive
PM2.5
NOx
SO2
CO
VOC
VOC Fugitive
NH3
Greenhouse Gases
CO2
CH4
N2O
HFCs
PFCs
SF6
Total CO2e
Hazardous Air Pollutant**
Formaldehyde
n-Hexane
2,2,4-Trimethylpentane
Benzene
Toluene
Ethylbenzene
Xylenes
Acrolein
Methanol
Other HAPs***
Total Facility HAPs
**Use additional sheets for pollutants if needed
Page 1 of 1
0.00 107,120.81 107,120.81
0.00 1.73E-03 1.73E-03
0.00 0.03 0.03
0.00 0.50 0.50
0.00 0.44 0.44
CO2e
102,411.11
4,655.02
54.69
0.00
0.00
0.00 0.00
0.00
0.00
0.00
0.00 0.18 0.18
0.00 0.21 0.21
*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)
0.00 1.83 1.83
0.00
0.00
0.00 0.02 0.02
Permitted Emissions
(tons/year)
Emissions Increase
(tons/year)
Proposed Emissions
(tons/year)
0.00 0.12 0.12
Permitted Emissions
(tons/yr)
Emissions Increase
(tons/yr)
Proposed Emissions
(tons/yr)
Kinder Morgan Altamont LLC
Hideout Compressor Station
December 19, 2023
Table D-1: Proposed Emissions
0.00 9.38 9.38
Potential to Emit* Criteria Pollutants & GHGs
0.00 0.00 0.00
0.00 9.38 9.38
0.00 66.93 66.93
0.00 0.40 0.40
0.00 96.93 96.93
0.26
0.00 94.10 94.10
0.00 3.80 3.80
0.00 0.26
CO2e
0.00
0.00
0.00
0.00
CO2e
102,411.11
4,655.02
54.69
0.00 6.94 6.94
***See individual calculation sheets for additional HAPs.
Hazardous Air Pollutants (list individually)Maximum emissions rate (lbs/hour)
1,1,2,2-Tetrachloroethane 3.91E-04
1,1,2-Trichloroethane 2.36E-04
1.3-Butadiene 1.02E-02
1,3-Dichloropropene 1.96E-04
2-Methylnaphthalene 4.69E-08
3-Methylchloranthrene 3.51E-09
7,12-Dimethylbenz(a)anthracene 3.12E-08
2,2,4-Trimethylpentane 5.98E-03
Acenaphthene 3.51E-09
Acenaphthylene 3.51E-09
Acetaldehyde 4.31E-02
Anthracene 4.69E-09
Acrolein 4.06E-02
Benz(a)anthracene 3.51E-09
Benzo(a)pyrene 0.00E+00
Benzene 1.14E-01
Benzo(b)fluoranthene 0.00E+00
Benzo(e)pyrene 2.34E-09
Benzo(b)fluoranthene 3.51E-09
Benzo(g,h,i)perylene 2.34E-09
Benzo(k)fluoranthene 3.51E-09
Biphenyl 0.00E+00
Carbon Tetrachloride 2.73E-04
Chlorobenzene 1.99E-04
Chloroform 2.12E-04
Chrysene 3.51E-09
Dibenzo(a,h)anthracene 2.34E-09
Dichlorobenzene 2.34E-06
Ethylbenzene 3.94E-04
Ethylene Dibromide 3.29E-04
Fluoranthene 5.86E-09
Fluorene 5.47E-09
Formaldehyde 8.67E-01
Methanol 7.68E-02
Methylene Chloride 6.36E-04
n-Hexane 4.16E-01
Indeno(1,2,3-cd)pyrene 3.51E-09
Naphthalene 1.19E-06
PAH 2.18E-03
Phenanthrene 3.32E-08
Phenol 0.00E+00
POM 1.50E-03
Pyrene 9.76E-09
Styrene 1.84E-04
Tetrachloroethane 0.00E+00
Toluene 2.75E-02
Vinyl Chloride 1.11E-04
Xylene 4.12E-03
Highest Single HAP: Formaldehyde 8.67E-01
App. D, Table D-1a
Utah Division of Air Quality
Project Hourly HAP Emissions
HAP Emissions Information (Continued)
Form 5 Table D-1a
Approval Order Application
Appendix E
Source Size Determination
Kinder Morgan - Hideout Compressor Station
Appendix E: Source Size Determination
Narrative:
Criteria Pollutants
PM10
PM10 Fugitive
PM2.5
NOx
SO2
CO
VOC
VOC Fugitive
Greenhouse Gases
CO2
CH4
N2O
HFCs
PFCs
SF6
Hazardous Air Pollutant
Total HAPs
Formaldehyde
UAC R307-415-3
The Hideout Compressor Station is a new natural gas compressor facility located in Duchesne County, Utah in the Ozone
Non-attainment area. This facility will be classified as an Area Source, as defined in R307-415-3, for all criteria air pollutants.
0.00 6.94 6.94
Page 1 of 1
0.00 3.80 3.80
0.00 107,120.81 107,120.81
Hazardous Air Pollutants (As defined in Section 12(b) of the Clean Air Act)
Permitted Emissions
(tons/year)
Emissions Increase
(tons/year)
Proposed Emissions
(tons/year)
0.00 0.00 0.00
0.00 0.00 0.00
0.00 4,655.02 4,655.02
0.00 54.69 54.69
CO2e CO2e CO2e
0.00 102,411.11 102,411.11
0.00 94.10 94.10
0.00 0.44 0.44
0.00 0.40 0.40
0.00 96.93 96.93
0.00 9.38 9.38
0.00 66.93 66.93
0.00 9.38 9.38
0.00 0.00 0.00
Permitted Emissions
(tons/year)
Emissions Increase
(tons/year)
Proposed Emissions
(tons/year)
December 19, 2023
Table E-1: Source Size Determination
Potential to Emit Criteria Pollutants & GHGs
Appendix F 
Offset Requirements 
Appendix F
Hideout Compressor Station – Emission Offset Requirements
Requirement:Utah Administrative Code R307-420 establishes offset and maintenance requirements for
owners and operators of new or modified facilities emitting Nitrogen Oxides (NOx) or Volatile Organic
Compounds (VOC) in Davis and Salt Lake counties.
Applicability:Not applicable – The Hideout Compressor Station will not be located in the
counties of Utah or Salt Lake. It will be constructed in the Ozone non-attainment area of
Duchesne County, Utah which currently has no emissions offset requirements for area sources.
Requirement:Utah Administrative Code R307-421 establishes offset and maintenance requirements for
owners and operators of new or modified facilities emitting NOx or Sulfur Dioxide (SO2) in Utah and Salt
Lake counties.
Applicability:Not applicable – The Hideout Compressor Station is a new natural gas compressor
facility located in Duchesne County, Utah in the Ozone Non-attainment area. This facility will be
classified as an Area Source, as defined in R307-415-3, for all criteria air pollutants.
Appendix G 
BACT Discussion 
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-1

Appendix G Hideout BACT Discussion
1.0 Best Available Control Technology
1.1 R307-401-5(2)(d) Best Available Control Technology
The notice of intent shall include an analysis of best available control technology (BACT) for
the proposed source or modification. BACT is defined in R307-401-2 as:
“an emissions limitation (including a visible emissions standard) based on the
maximum degree of reduction for each air contaminant which would be emitted from
any proposed stationary source or modification which the executive secretary, 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 executive
secretary 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.”
BACT requirements are intended to ensure that a proposed facility will incorporate control
systems that reflect the latest demonstrated practical techniques for a particular type of
emission unit. The top-down BACT evaluation requires documentation and ranking of
performance levels achievable for each technically feasible pollutant control technology
applicable to the Hideout Compressor Station emission sources.
The top-down approach to the BACT review process involves determining the most stringent
control technology available. If it can be shown that the most stringent control technology is
technically, environmentally, or economically impractical on a case-by-case basis for the
particular source under evaluation, then the next most stringent level of control is determined
and similarly evaluated. This process continues until a control technology and associated
emission level is determined that cannot be eliminated by any technical, environmental, or
economic objections. The top-down BACT evaluation process is described in the USEPA
draft document "New Source Review Workshop Manual.” The five steps involved in a top-
down BACT evaluation are:
1 Identify all available control options with practical potential for application to the
specific emission unit for the regulated pollutant under evaluation;
2 Eliminate technically infeasible technology options;
3 Rank remaining control technologies by control effectiveness;
4 Evaluate the most effective control alternative and document results; if the top option
is not selected as BACT, evaluate the next most effective control option; and
5 Select BACT, which will be the most effective practical option not rejected based on
energy, environmental, or economic impacts.
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-2

This BACT analysis focuses on the ten (10) four-stroke rich burn (4SRB) Spark-Ignited
Reciprocating Internal Combustion Engines (SI-RICE) proposed for the project. The SI-
RICE, as a group, are the largest contributors of air emissions at the Hideout Compressor
Station. The other emission sources are addressed briefly, only to describe the control
technologies being employed, which currently reflect BACT for each respective source type.
The following table summarizes the proposed controls and emission levels for NOx, CO and
VOCs.
Table G.1: Emission Unit Table

There are ten (10) 4SRB natural gas fired SI-RICE proposed to drive compressors within the
facility. For this project, each of the SI-RICE will be purchased new from the manufacturer.
Emission Unit
ID EU Description Make/Model
Add-On
Controls
NOX
(tpy)
CO
(tpy)
PM10
(tpy)
PM2.5
(tpy)
SO2
(tpy)
VOC
(tpy)
C-1
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-2
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-3
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-4
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-5
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-6
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-7
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-8
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-9
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
C-10
Inlet Compressor
4SRB SI-RICE Waukesha 7044 GSI S5 NSCR 5.50 5.57 6.43E-01 6.43E-01 0.04 5.50
H-1 Heater / Reboiler n/a None 0.51 0.43 3.90E-02 3.90E-02 0.00 0.03
H-2 Gas Fired Stabilizer Heater n/a None 0.51 0.43 3.90E-02 3.90E-02 0.00 0.03
DEHY
TEG Dehydration Unit Process
Vents (Still Vent & Flash Tank) n/a
Combustor
(COM-2)- See COM-2 See COM-2 See COM-2 - See COM-2
COM-1 Tank & TLO Combustor TBD None 1.70 0.43 1.72E-01 1.72E-01 - 8.05
COM-2 BTEX Combustor TBD None 0.47 0.12 4.90E-02 4.90E-02 - 2.28
FL-1 Facility Flare TBD None 8.74 39.82 2.65E+00 2.65E+00 - 27.72
T-1 - T-6
(1) Gunbarrel & (5) Condensate
Tanks n/a
Combustor
(COM-1)- See COM-1 See COM-1 See COM-1 - See COM-1
TRK-1 Truck Loading n/a
Combustor
(COM-1)- See COM-1 See COM-1 See COM-1 - See COM-1
LO-Tank Lube Oil Tank n/a None - - - - - 0.19
ULO-Tank Used Lube Oil Tank n/a None - - - - - 0.19
MT-Tank Methanol Storage Tank n/a None - - - - - 0.13
50/50-Tank Antifreeze Tank (50/50) n/a None - - - - - 0.00
FAB
Ultra-fab H2S Removal System
(closed loop) n/a n/a - - - - - 0.00
FAB-Tank H2S Removal n/a None - - - - - 0.00
PIG
Pigging Emissions
(Launcher/Receiver) n/a FL-1 - See FL-1 See FL-1 See FL-1 - See FL-1
BLW DWN Compressor Blow Down Events n/a FL-1 - See FL-1 See FL-1 See FL-1 - See FL-1
FUG-1 Fugitive - Component Leaks n/a n/a - - - - - 0.44
66.93 96.93 9.38 9.38 0.40 94.10 Hideout Compressor Station Facility-wide Emissions
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-3

1.2 SI-RICE BACT Analysis for NOx
1.2.1 Formation of NOx
Nitrogen oxides (NOx) are formed in combustion processes primarily by either: 1) oxidation
of nitrogen in the combustion air at high temperatures (thermal NOx), or 2) reduction and
subsequent oxidation of nitrogen chemically bound in the fuel at slightly lower temperatures
(fuel NOx). Virtually all NOx emissions originate as nitric oxide (NO) since both nitrogen and
oxygen dissociate to atomic form at the high temperatures within the combustion flame. A
minor fraction of the NO (1-5%) is further oxidized in the exhaust gas to nitrogen dioxide
(NO2).
Fuel NOx formation is affected by numerous factors, including the amount of chemically
bound nitrogen in the fuel, the mixing rate of the fuel and combustion air, the flame
temperature, the air to fuel ratio (AFR), and the residence time in the high temperature
zones. However, since the nitrogen is not chemically bound, no fuel NOx is expected. The
presence of nitrogen in the fuel may reduce the rate of thermal NOx formation by acting as
an inert diluent and reduce peak flame temperatures, although it is not possible to quantify
this impact. Therefore, fuel NOx is expected to contribute little, if any, to the total NOx
emissions from these IC engines.
Virtually all thermal NOx is formed in the region of the flame at the highest temperature.
Maximum thermal NOx production occurs at a slightly lean fuel-to-air ratio due to the excess
availability of oxygen for reaction within the hot flame zone. Thermal NOx formation is a
function of combustion air preheat, residence time, free oxygen availability, and peak flame
temperature. Preheating combustion air tends to increase the formation of thermal NOx.
1.2.2 Availability of NOx Control Technologies
U.S. EPA has published several documents that identify NOx control techniques available for
use on combustion sources. Information contained in two of these U.S. EPA documents was
used to assist in the identification of available and technically feasible control technology
options for natural gas-fired IC engines (USEPA 1992 and USEPA 1999).
Available NOx control techniques for the IC engines can be classified as either combustion
control methods (including inherently designed low emission equipment, processes, or fuels)
aimed at reducing the formation of NOx in the various combustion processes by minimizing
those factors which foster NOx formation, or flue gas controls which reduce the NOx present
in the exhaust gases to elemental nitrogen.
Table G.2: NOx Combustion Control Technology and Technical Feasibility
Control
Technology
Combustion Control Technology
Description
Technically Feasible?
AFR Controller An air-fuel ratio (AFR) controller monitors the
oxygen content in the exhaust and provides
feedback control to the fuel gas such that the
combustion zone can be consistently
maintained in an operating region which
minimizes the formation of NOx.
Feasible for units C-1 through C-
10. All ten engines will employ an
electronic AFR to optimize
combustion and reduce emissions.
Pre-Stratified
Charge (PSC)
The concept of PSC is to introduce controlled
amounts of air into the intake manifold in a
specified sequence and quantity to create
fuel-rich and fuel-lean combustion zones.
The fuel-rich zone is adjacent to the igniter to
Not Feasible on units C-1 through
C-10. These units are new 4SRB
SI-RICE. Retrofitting a new engine
with PSC is technically infeasible
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-4

Control
Technology
Combustion Control Technology
Description
Technically Feasible?
insure stable operation of the engine. The fuel
lean zone rapidly quenches the flame
reducing the NOx formation rate.
and not as effective as available
flue gas treatment options.
Lean Burn
Technology
In a lean burn engine, a large volume of air is
introduced into the chamber to lower the
flame temperature and reduce NOx formation
rates. To maintain stable engine operation at
extremely lean main chamber conditions, a
fuel rich mixture is introduced into a small pre-
chamber containing an igniter plug. Once
ignited, the flame passes from the pre-
chamber into the main cylinder to provide an
effective ignition source for the extremely lean
fuel air mixture.
Not Feasible for units C-1 through
C-10. These units are four stroke
rich burn (4SRB) engines. As
such, they cannot be retrofitted to
employ lean-burn technology.
Ultra Lean
Burn
Technology
(ULB)
A SI-RICE engine that uses ULB technology
employs Lean Burn technology and
improvements of several combustion and
control systems to achieve the lowest engine
NOx emissions, and increased fuel efficiency.
Advanced combustion controls, turbo
matching and air/fuel mixing are all optimized
in a ULB system.
Not Feasible for units C-1 through
C-10. These units are four stroke
rich burn (4SRB) engines. As
such, they cannot be retrofitted to
employ ULB technology.
1.2.3 General Description of NOx Flue Gas Treatment Controls and
Technical Feasibility
Unlike combustion controls which seek to minimize the formation of NOx, flue gas controls,
selective non-catalytic reduction (SNCR), non-selective catalytic reduction (NSCR), and
selective catalytic reduction (SCR), are designed to reduce the NOx which has already been
formed to molecular nitrogen. SCR and SNCR processes inject a reducing agent into the
flue gas of a combustion unit which reduces NO to molecular nitrogen. Reducing agents are
injected into the flue gas either in the presence or absence of a catalyst. NSCR utilizes
reducing compounds in the flue gas to convert NO to molecular nitrogen. Each of these flue
gas treatment control options is described below.
Table G.3: NOx Flue Gas Treatment Controls and Technical Feasibility
Control
Technology
Control Technology Description Technically Feasible?
Selective Non-
catalytic
Reduction
(SNCR)
The non-catalytic process, SNCR, involves
the non-catalytic decomposition of NOx in the
flue gas to nitrogen and water using either
urea or ammonia as a reducing agent. The
ammonia process is based on a gas phase
homogeneous reaction between NH3 and NOx
within a specific temperature range (1,600 to
2,200°F). Ammonia must be injected into the
flue gas by means of a carrier gas (air or
steam).
Not Feasible for units C-1 through
C-10. This control technology
requires exhaust temperatures
above 1,300°F. The rich burn IC
engines will operate between 950
and 1,150°F In addition, SNCR
requires a residence time longer
than feasible in an IC engine
source.
Non Selective
Catalytic
Reduction
(NSCR)
NSCR has been used to control NOx
emissions from rich-burn engines for many
years. In the presence of CO and NMHC in
the engine exhaust, the catalyst converts NOx
Feasible for units C-1 through C-
10. These units are rich-burn
engines and as such can employ
NSCR for effective NOx reduction.
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-5

Control
Technology
Control Technology Description Technically Feasible?
to nitrogen and oxygen. A stack temperature
between 800 and 1,200°F is needed for peak
reduction performance of 80 to 90%.
Selective
Catalytic
Reduction
(SCR)
SCR utilizes a metal-based catalyst and the
injection of an ammonia reducing agent
upstream of the catalyst. In a typical ammonia
injection system, anhydrous ammonia is
drawn from a storage tank and evaporated
using a steam or electric-heated vaporizer.
The vapor is mixed with a pressurized carrier
gas to provide both sufficient momentum
through the injection nozzles and effective
mixing of the ammonia with the exhaust
gases
Not Feasible for units C-1 through
C-10. These units are 4SRB SI-
RICE and SCR is not an
appropriate control technology for
rich burn engines.
1.2.4 Summary of Selected SI-RICE NOx BACT (Units C-1 through C-10)
The Waukesha 7044 GSI S5 engine is classified as a four-stroke rich burn (4SRB) engine
and is considered to have a maximum rated power of 1,900 bhp. Each engine will be
purchased new as a driver for ten natural gas compressors. Exhaust stacks for each of the
units will be equipped with a NSCR (3-way) catalyst to reduce the NOx emissions rates by
more than 97% to achieve 0.30 g/bhp-hr. This combustion control technology is lower than
the generally accepted BACT level of 1.0 g NOx/bhp-hr for new natural gas-fired 4SRB
engines and constitutes BACT. Table G.4 summarizes the proposed emission rates for each
engine. These values can be achieved with no adverse operational, environmental or energy
impacts.
Table G.4: Summary of NOx BACT Emission Rates
Engine Emission Rates Control Technology
Waukesha 7044 GSI S5 0.3 g/bhp-hr 1.26 lb/hr 5.50 tpy NSCR
1.3 SI-RICE BACT Analysis for CO and VOC
1.3.1 Formation of CO and VOC
CO and VOC emissions are a product of incomplete combustion in a combustion source.
Complete combustion of a hydrocarbon fuel would theoretically result in water vapor and
carbon dioxide as exhaust products. However, due to less-than-ideal conditions, combustion
is incomplete, and a small fraction of CO and VOC are present in the exhaust. The rate of
CO and VOC emissions are dependent upon the parameters that affect the combustion
efficiency. These include proper mixing of the fuel and combustion air and adequate
residence time at temperature to complete the oxidation process.
1.3.2 Four-Stroke Rich Burn Engines – Technically Feasible and Selected
CO/VOC Control Technologies
Units C-1 through C-10 are natural gas-fired, four-stroke rich burn (4SRB) engines.
Technically feasible, and widely used CO/VOC control techniques for 4SRB engines has
been Non-selective Catalytic Reduction (NSCR), and combustion tuning and operation per
the manufacturer's recommendations. All proposed 4SRB engines will be equipped with an
NSCR to reduce NOx, CO, and VOC emissions in the exhaust stack. This level of control
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-6

technology is considered BACT and the emission rates are lower than the current
standards, as applicable, in 40 CFR 60 Subpart JJJJ for control of CO and VOC.
Table G.5: CO and VOC - Standards and Proposed Emissions
Constituent JJJJ Limit
(g/hp-hr)
Proposed Emissions
(g/hp-hr)
CO 2.0 0.3
VOC 0.7 0.3
Table G.6 summarizes the proposed emission limits for each engine. These values can be
achieved with no adverse operational, environmental or energy impacts.
Table G.6: Summary of CO and VOC BACT Emission Rates
Pollutant Emission Limit Control Technology
CO 0.3 g/bhp-hr 1.27 lb/hr 5.57 tpy NSCR
VOC 0.3 g/bhp-hr 1.26 lb/hr 5.50 tpy NSCR
1.4 SI-RICE BACT Analysis for SO2 and PM10
Emissions of SO2 are generated in fossil fuel-fired sources from the oxidation of sulfur
present in the fuel. Emissions of PM10 are a function of ash content, firing configuration, and
operational practices. Uncontrolled emissions of SO2 are thus affected by fuel sulfur content
alone, and not by source category, mechanism, size, or operation. Uncontrolled emissions of
PM10 are affected by the non-combustible inert matter and condensable substances such as
acid gases, which for natural gas combustion are negligible.
No add-on SO2 or PM10 controls have ever been applied to IC engines firing pipeline-quality
natural gas. Each IC engine at the Hideout Compressor Station will fire pipeline-quality
natural gas and, as such, none of the proposed IC engines will be equipped with SO2 or
PM10 controls. Potential emissions of SO2 and PM10 from the engines are extremely small,
less than 1 tpy each. As such, BACT is determined to be the use of pipeline-quality natural
gas as fuel and proper operation and maintenance of each IC engine according to the
manufacturer’s recommendations.
1.5 Other Emission Units - BACT Analysis for VOCs
1.5.1 Triethylene Glycol (TEG) Dehydrator Vents
The still vent for the TEG regeneration processes at the Hideout Compressor Station will be
routed through a condenser with all non-condensable vapors from the condenser vent being
directed to an enclosed combustor (COM-2). The combustor will be purchased new for
service at the facility and will achieve a destruction efficiency of 95% or greater. The TEG
dehydrator flash tank vapors will be collected and used in the fuel system at the station. This
control configuration for this type of source constitutes BACT.
1.5.2 Organic Liquid Storage Tank Vents
The proposed organic liquid storage tanks for the Hideout Compressor Station include the
following:
Kinder Morgan
Hideout Compressor Station Air Application
December 19, 2023
SLR Project No.: 132.01110.0010

G-7

Table G.7: Organic Liquid Storage Tanks
Emission Unit # Description Material Stored
Uncontrolled
VOC PTE
(tpy) Proposed Control
LO-Tank New Motor Oil Tank New motor oil 0.19 None
ULO-Tank Used Motor Oil Tank Used motor oil 0.19 None
MT-Tank Methanol Tank New methanol 0.13 None
Tanks T-1
through T-6
Gun Barrel and
Condensate Tanks
(five)
Produced Water and
Pipeline Condensate
904.74 Enclosed
combustor (COM-
1)
The organic liquids storage tanks with the largest VOC emissions are Tanks T-1 through T-6
(Gunbarrel and Condensate Storage Tanks). The vapors for these tanks will be collected with
an enclosed vapor collection system and directed to an enclosed combustor (COM-1) with a
VOC destruction efficiency of 95% or greater. The vapor collection system and enclosed
combustor arrangement for this type of source constitutes BACT.
The logistics and the expense associated with piping the vents of the remaining tanks to
control device do not justify the cost to control the very low VOC emissions from tanks LO-
Tank, ULO-Tank and MT-Tank. The process area round these tanks tend to be complex with
little space. These tanks represent a very small portion of the VOC emissions, and as such
will not need any additional controls. In addition, the applicability in R307-506-3 explicitly
states the requirements for storage vessels only applies to those vessels located at a well
site as defined in OOOOa. The atmospheric venting of tanks for lubricating oils and
methanol is generally accepted industry practice. Additionally, the installation of a vapor
collection system and installation of an enclosed combustor would not be economically
feasible to control 0.5 tons per year of VOC emissions.
1.5.3 Tank Truck Loading
Current truck loading requirements in R307-504 establish specific control requirements for the
loading and unloading of liquids containing volatile organic compounds (VOCs) at oil or gas
well sites. These control requirements include the use of bottom fill or submerged fill pipe as
well as a “Vapor Capture Line” from the truck.
The Hideout Compressor Station is not co-located with or directly associated with one or more
oil wells or gas wells and therefore is not considered a “well production facility” or a “well site”
as described in R307-504, R307-506 or 40 CFR 60.5430a, Subpart OOOOa.
Liquids will be removed from the Used Motor Oil Tank ULO-Tank, Gun Barrel (T-1) and
Condensate Tanks (T-2 through T-6) using a tanker truck that utilizes bottom filling or
submerged fill pipe techniques. The load-out of motor lubricating oils (LO-Tanks and ULO-
Tank) is not expected to generate VOC emissions, therefore a vapor capture line will not be
installed to collect and control from these sources. Venting any vapors generated during truck
load out of motor lubricating oil is accepted as BACT.
Uncontrolled truck Load-out VOC emissions for the Gun Barrel (T-1) and Condensate Tanks
(T-2 through T-6) are expected to be significant (> 40 tpy) so a vapor capture line for the
truck load-out activities at these tanks will be installed. All collected vapors from condensate
load out activities will be directed to an enclosed combustor (COM-1) for destruction. The
configuration of a vapor collection system and destruction using an enclosed combustor
meets the requirements of R307-594 and constitutes BACT.

Appendix H 
Emission Controls 

Utah Division of Air Quality
New Source Review Section Company___________________________
Site/Source__________________________
Form 4 Date_______________________________
Flare Systems

Equipment Information

1. Manufacturer:
_________________________
Model no.:
_________________________
(if available)

2. Design and operation shall be in accordance with 40CFR63.11. In addition
to the information listed in this form, provide the following: an assembly
drawing with dimensions, interior dimensions and features, flare’s
maximum capacity in BTU/hr.
3.Characteristics of Waste Gas Stream Input
Components Min. Value Expected
(scfm @ 68 oF, 14.7 psia)
Ave. Value Expected
(scfm @ 68oF, 14.7 psia)
Design Max.
(scfm @ 68oF, 14.7 psia)
a.

b.

c.

d.

e.

f.

g.

h.

4. Percent of time this
condition occurs

5. Flow rate: Minimum Expected Design Maximum Temp oF Pressure (psig)

Waste Gas Stream _______________ _______________ _______ ____________
Fuel Added to Gas Stream _______________ _______________ _______ ____________
Heat content of the gas to be flared ______________ BTU/ft3

6. Number of pilots

7. Type of fuel

8. Fuel Flow Rate (scfm @ 68oF & 14.7 psia) per pilot

Page 1 of 3
Kinder Morgan Altamont LLC
Hideout Compressor Station
July 28, 2023
TBD
TBD
ESD, Blowdowns,
Pressure Relief, Pigging 0 380.5 (200 MMscf/yr)
380.5 scfm (200 MMscf/yr)0
1,000 - 1,500
Pipeline NG1
50 scfh (0.438 MMscf/yr)
20.8 scfh (0.182 MMscf/yr)
Page 2 of 3
Flare Systems
Form 4
(Continued)

Steam Injection

9. Steam pressure (psig)

Minimum Expected __________________
Design Maximum __________________

10. Total steam flow Rate (lb/hr)

11. Temperature (oF)

12. Velocity (ft/sec)

13. Number of jet streams

14. Diameter of steam jets (inches)

15. Design basis for steam injected (lb steam/lb hydrocarbon)
Water Injection

16. Water pressure (psig)

Minimum Expected __________________
Design Maximum __________________

17. Total Water Flow Rate (gpm)

Minimum Expected __________________
Design Maximum __________________

18. Number of water jets

19. Diameter of Water jets (inches)

20. Flare height (ft)

21. Flare tip inside diameter (ft)
Emissions Calculations (PTE)

22. 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_________Lbs/hr (speciate)__________Tons/yr (speciate)
Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix.

N/A
N/A
0.61 2.65 0.61 2.65
1.99 8.74 --
9.09 39.82 6.33 27.72
15,027 0.66
0.03
0.790.18
Appendix I 
Federal and State Rule Applicability 
APPENDIX I - Applicable Federal Clean Air Act Rules
Facility:Kinder Morgan - Hideout Compressor Station December 2023
Program
Identifier
Program
Citation
Secondary
Identifier Rule Citation
Target
Pollutants Rule Summary & Applicability Notes Ap
p
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No
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Ap
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Determination Notes
NSPS 40CFR60 Subpart A §§60.1-60.19 General Provisions X
Several subparts of 40 CFR Part 60 apply to this facility. Portions of the general provisions
apply, as referenced in applicable subparts.
A flare used as a control device for a referencing NSPS subpart will conform to the
requirements of §60.18, as applicable and as required by that referencing subpart.
NSPS 40CFR60 Subpart Db §§60.40b-60.49b NOX, SO2,
PM
Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units with a
heat input capacity >100 MMBtu/hr for which construction, modification, or reconstruction
commenced after June 19, 1984
X Permittee does not operate any affected facilities
NSPS 40CFR60 Subpart Dc §§60.40c-60.48c NOX, SO2,
PM
Standards of Performance for Small Industrial-Commercial-Institutional 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 100 MMBtu/h or less, but greater than or equal to
10 MMBtu/h
X Permittee does not operate any affected facilities
NSPS 40CFR60 Subpart K §§60.110-60.113 VOC
Standards of Performance for certain storage vessels for petroleum liquids for which construction,
reconstruction, or modification commenced after June 11, 1973, and prior to May 19, 1978 and
with a storage capacity >40,000 gallons.
X Permittee does not operate any affected facilities
NSPS 40CFR60 Subpart Ka §§60.110a-60.115a VOC
Standards of Performance for certain storage vessels for petroleum liquids for which construction,
reconstruction, or modification commenced after May 18, 1978 and prior to July 23, 1984 and with
a storage capacity >40,000 gallons.
X Permittee does not operate any affected facilities
NSPS 40CFR60 Subpart Kb §§60.110b-60.116b VOC
Standards of Performance for certain Volatile Organic Liquid (VOL) Storage Vessels (Including
Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification
Commenced After July 23, 1984 and with a design storage capacity greater than or equal to 75
cubic meters (471.7 bbls).
X Permittee does not operate any affected facilities
NSPS 40CFR60 Subpart GG §§60.330-60.335 NOX, SO2
Standards of performance for stationary gas turbines with a heat input at peak load equal to or
greater than 10 MMBtu/h (based on the lower heating value of the fuel fired) and for which
construction, modification, or reconstruction commenced after October 3, 1977 and on or before
February 18, 2005
X Permittee does not operate any stationary combustion turbine affected facilities
NSPS 40CFR60 Subpart KKK §§60.630-60.636 VOC
Subpart KKK—Standards of Performance for Equipment Leaks of VOC From Onshore Natural
Gas Processing Plants for Which Construction, Reconstruction, or Modification Commenced After
January 20, 1984, and on or Before August 23, 2011
X Facility is not a natural gas processing plant.
NSPS 40CFR60 Subpart LLL §§60.640-60.648 SO2
Subpart LLL—Standards of Performance for SO2 Emissions From Onshore Natural Gas
Processing for Which Construction, Reconstruction, or Modification Commenced After January
20, 1984, and on or Before August 23, 2011
X Facility is not a natural gas processing plant. Subpart LLL is not a relevant standard.
NSPS 40CFR60 Subpart CCCC §§60.2000-60.2265
D/F, Cd, Pb,
Hg, PM, HCl,
NOX, SO2,
CO,
Fug.Ash,
opacity
Standards that are applicable to Commercial and Industrial Solid Waste Incinerator (CISWI) Units.X Permittee does not operate any affected facilities
NSPS 40CFR60 Subpart IIII §§60.4200-60.4219 NOX, NMHC,
HC, CO, PM
Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (CI-
ICE) for which construction, reconstruction or modification occurred after July 11, 2005 and where
the stationary CI ICE was manufactured after April 1, 2006 (CI-ICE that are not fire pump engines)
or manufactured as a certified National Fire Protection Association (NFPA) fire pump engine after
July 1, 2006.
X Permittee does not operate any stationary CI-ICE
Applicability Determination
Kinder Morgan
Appendix I - FCAA Applicability Review Hideout Compressor Station SLR Project No.: 132.01110.0010
Page 1
Program
Identifier
Program
Citation
Secondary
Identifier Rule Citation
Target
Pollutants Rule Summary & Applicability Notes Ap
p
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No
t

Ap
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Determination Notes
Applicability Determination
NSPS 40CFR60 Subpart JJJJ §§60.4230-60.4248 NOX, CO,
VOC
Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (SI-ICE) for
which construction, reconstruction or modification occurred after June 12, 2006 and where the
stationary SI-ICE was manufactured:
(i) On or after July 1, 2007, for engines with a maximum engine power greater than or equal to
500 HP (except lean burn engines with a maximum engine power greater than or equal to 500 HP
and less than 1,350 HP);
(ii) on or after January 1, 2008, for lean burn engines with a maximum engine power greater than
or equal to 500 HP and less than 1,350 HP;
(iii) on or after July 1, 2008, for engines with a maximum engine power <500 HP; or
(iv) on or after January 1, 2009, for emergency engines with a maximum engine power>25 HP
X
The proposed natural gas compressor drivers are 1,900 hp each. All are new SI-4SRB and
will be considered an "affected facility" for purposes of NSPS Subpart JJJJ.
Each affected SI-ICE will meet standards and requirements as applicable.
NSPS 40CFR60 Subpart KKKK §§60.4300-60.4420 NOX, SO2
Standards of Performance for stationary combustion turbines that commenced construction,
modification, or reconstruction after February 18, 2005.X Permittee does not operate any stationary combustion turbine affected facilities
NSPS 40CFR60 Subpart OOOO §§60.5360-60.5430 VOC, SO2
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 on or before September 18, 2015
X Permittee does not operate any affected facility for which construction, reconstruction or
modification occurred after August 23, 2011, and on or before September 18, 2015
NSPS 40CFR60 Subpart OOOOa §60.5375a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Wells X Permittee does not operate any well affected facility
NSPS 40CFR60 Subpart OOOOa §60.5380a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Centrifugal
Compressors with Wet Seal Degassing Systems
X Permittee does not operate any centrifugal compressor affected facility
NSPS 40CFR60 Subpart OOOOa §60.5385a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015:
Reciprocating Compressors
X
The natural gas compressor drivers will be constructed after September 18, 2015 making
them reciprocating compressor affected facilities subject to work practice standards
prescribed in §60.5385. A notification is not required. Maintain records prescribed by
§60.5420(c)(3) and submit annual reports as required by §60.5420(b)(1) and (4).
NSPS 40CFR60 Subpart OOOOa §60.5390a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Continuous
Bleed Natural Gas-Driven Pneumatic Controllers
X Permittee does not operate any natural gas pneumatic controller affected facility. All
controllers are operated by instrument air.
NSPS 40CFR60 Subpart OOOOa §60.5393a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Pneumatic
Pumps at Natural Gas Processing Plants and Well Sites
X Facility is not a natural gas processing plant or well site. Permittee does not operate a
pneumatic pump affected facility
NSPS 40CFR60 Subpart OOOOa §60.5395a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Storage
Vessels
X
The new gunbarrel tank will be a single storage vessel with potential VOC emissions
greater than 6 tpy (6.92 tpy) and is therefore considered an affected facility. The
condensate tanks (five) will have combined potential VOC emissions less than 6 tpy and
will not be storage vessel affected facilities, as provided by §60.5365a(e).
NSPS 40CFR60 Subpart OOOOa §60.5397a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Collection
of Fugitive Emissions Components at a Well Site or Compressor Station
X Facility is a compressor station as defined in §60.5430a. The Hideout Compressor Station
will be an affected facility and will be subject the requirements in this section.
NSPS 40CFR60 Subpart OOOOa §60.5398a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Alternative
Means of Emission Limitations
X Permittee has not requested an alternative means of emission limitations
NSPS 40CFR60 Subpart OOOOa
§§60.5400a through
60.5402a VOC, GHG
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015: Equipment
Leaks at Onshore Natural Gas Processing Plants
X Facility is not a natural gas processing plant as defined in §60.5430a.
NSPS 40CFR60 Subpart OOOOa
§§60.5405a through
60.5407a SO2
Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015:
Sweetening units located at onshore natural gas processing plants that commenced
construction, modification, or reconstruction after September 18, 2015, and on or before
November 16, 2020, and sweetening units that commence construction, modification, or
reconstruction after November 16, 2020.
X
The H2S treating unit is a scavenger-based process that does not generate acid gas. The
unit meets the definition of a "sweetening unit" in Subpart OOOOa (§60.5430a) and the
construction of the unit will commence after November 16, 2020, but the unit does not
emit sulfur compounds.
NSPS 40CFR60 Subpart OOOOb Proposed VOC, CH4
In November 2022 the EPA proposed rules to reduce methane emissions from new and existing
sources in the oil and natural gas industry. These rules have not been promulgated into law, but
can affect certain affected facilities constructed, reconstructed or modified after November 16,
2021.
NSPS OOOOb will apply to certain affected facilities constructed, reconstructed or
modified after Nov. 16, 2021. This could apply to equipment at this facility. Of particular
concern in NSPS OOOOb is the criteria for enforceability of VOC controls for tanks. It may
be beneficial to ensure permit language issued by UDAQ includes criteria equivalent to the
standards outlined in the proposed rule.
Kinder Morgan
Appendix I - FCAA Applicability Review Hideout Compressor Station SLR Project No.: 132.01110.0010
Page 2
Program
Identifier
Program
Citation
Secondary
Identifier Rule Citation
Target
Pollutants Rule Summary & Applicability Notes Ap
p
l
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a
b
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No
t

Ap
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Determination Notes
Applicability Determination
NESHAP 40CFR61 Subpart A §§61.01-19 General Provisions X Facility is not subject to a subpart of 40 CFR 61.
NESHAP 40CFR61 Subpart J §§61.110-61.112 Benzene
National emission standard for fugitive equipment leaks of benzene. Applicable to pumps,
compressors, pressure relief valves, connectors, surge control vessels, bottoms receivers and
control devices that operate in benzene service. Benzene services means that the equipment
contacts or contains a fluid (liquid or gas) that is 10% benzene by weight.
X Facility does not process or produce any streams (liquid or gas) with more than 10%
benzene by weight.
NESHAP 40CFR61 Subpart M §§61.140-61.157 Asbestos
National emissions standard pertaining to asbestos during milling, manufacturing,
demolition/renovation or disposal.X
Currently the facility is not engaging in any of these activities involving asbestos, however
any demolition and/or renovation activities could be potentially subject to Subpart M,
Standards for Demolition and Renovation.
NESHAP 40CFR61 Subpart V §§61.240-61.247 HAP Applies to various sources that operate in volatile hazardous air pollutant (VHAP) service.X The facility does not operate the identified sources in VHAP service.
NESHAP 40CFR63 Subpart A §§63.1-63.16 HAP General Provisions X Permittee operates certain affected facilities. Subpart A applies as referenced by an
underlying subpart.
NESHAP 40CFR63 Subpart HH §§63.760-63.777 HAP
National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production
Facilities X
The compressor station will be an area source of HAP (defined in 63.761). The actual
average emissions of benzene from the TEG dehydration unit process vent to the
atmosphere are less than 0.90 megagram per year (1 tpy), as determined by the
procedures specified in § 63.772(b)(2). The TEG unit meets the exception threshold
criteria listed in 63.760(e)(1)(ii) and is not subject to standards, except that the records of
the determination of these criteria must be maintained as required in § 63.774(d)(1).
NESHAP 40CFR63 Subpart HHH §§63.1270-63.1289 HAP
National Emission Standards for Hazardous Air Pollutants From Natural Gas Transmission and
Storage Facilities (Major Sources)X The facility is not in the natural gas transmission source category, but is in the oil and
natural gas production source category. Rule is not a relevant standard.
NESHAP 40CFR63 Subpart EEEE §§63.2330-63.2406 HAP
National Emission Standards for Hazardous Air Pollutants: Organic Liquids Distribution (Non-
Gasoline). This subpart establishes national emission limitations, operating limits, and work
practice standards for organic hazardous air pollutants (HAP) emitted from organic liquids
distribution (OLD) (non-gasoline) operations at major sources of HAP emissions.
X The facility is an area source of HAP emissions. This rule only applies to major sources of
HAP emissions. [40 CFR §63.2334(a) and (c)(1)]
NESHAP 40CFR63 Subpart YYYY §§63.6080-63.6175 HAP
Establishes emissions limitations and operating limitations that apply to stationary combustion
turbines located at major sources of HAP.X Permittee does not operate any stationary combustion turbine
NESHAP 40CFR63 Subpart ZZZZ §§63.6580-63.6675 HAP
National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal
Combustion Engines (RICE) Located at Major and Area Sources of HAP X
New or reconstructed stationary RICE located at an area source of HAP must meet the
requirements of Subpart ZZZZ by meeting the requirements of 40 CFR part 60 subpart
JJJJ for spark ignition engines. No further requirements apply for such engines under
Subpart ZZZZ - see §63.6590(c).
NESHAP 40CFR63 Subpart DDDDD §§63.7480-63.7575 HAP
National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial,
Commercial, and Institutional Boilers and Process Heaters X Facility is an area source of HAP. Rule does not apply to area sources.
Kinder Morgan
Appendix I - FCAA Applicability Review Hideout Compressor Station SLR Project No.: 132.01110.0010
Page 3
Program
Identifier
Program
Citation
Secondary
Identifier Rule Citation
Target
Pollutants Rule Summary & Applicability Notes Ap
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a
b
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No
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Ap
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Determination Notes
Applicability Determination
NESHAP 40CFR63 Subpart GGGGG §§63.7880-63.7957 HAP National Emission Standards for Hazardous Air Pollutants: Site Remediation (Major Sources)X Facility is an area source of HAP. Rule does not apply to area sources.
NESHAP 40CFR63 Subpart JJJJJJ §§63.11193-63.11237 HAP
National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and
Institutional Boilers at Area Sources X Permittee does not operate any boilers (defined in §63.11237)
CAM 40CFR64 §§64.1-64.10
Regulated
air pollutants
(defined in
Part 70 or
71)
Compliance Assurance Monitoring X
There is no pollutant-specific emission unit (PSEU) that uses a control device and has
potential pre-control device emissions of a applicable regulated air pollutant equal to or
greater than 100 percent of the amount, in tons per year, required for a source to be
classified as a major source [40 CFR §64.2].
RMP 40CFR68 §§68.1-68.220 Chemical Accident Prevention Provisions X Facility does not store more than a threshold quantity of listed Flammable Substances as
defined in §68.130 Table 3.
Acid Rain 40CFR72 - 40
CFR78 Acid Rain Program X Acid rain permits are required only for facilities that generate electricity and serve a
generator with a nameplate of 25 MW or more.
OzDS 40CFR82 Subpart B §§82.30-82.42
Ozone
depleting
substances
Applies to any person performing service on motor vehicle equipment involving the refrigerant in
the motor vehicle air conditioner.X Facility does not perform service on motor vehicle air conditioner units.
OzDS 40CFR82 Subpart F §§82.150-82.169
Ozone
depleting
substances
Establishes work practices to recapture and recycle refrigerants and applies to any person
servicing, maintaining, or repairing appliances.X Facility does not perform service on any appliances.
OzDS 40CFR82 Subpart H §§82.250-82.270 Halon Reduction of emissions of Halons from on-site equipment.X The facility does not operate a halon fire suppression system or any other equipment
containing halon.
GHG 40CFR98 Subpart C §§98.30-98.38 CO2, CH4,
N2O
Subpart C applies to combustion sources that exceed an annual CO2e emissions of 25,000 metric
tons.X Combustion emissions for this facility will be reported under Subpart W of 40 CFR part 98.
GHG 40CFR98 Subpart W §§98.230-98.238 CO2, CH4,
N2O
Subpart W applies to all identified industry segments that will exceed an annual CO2e emissions of
25,000 metric tons. Source categories include Offshore petroleum and natural gas production,
Onshore petroleum and natural gas production, Onshore natural gas processing, Onshore natural
gas transmission, Underground natural gas storage, Liquefied natural gas (LNG) storage, LNG
import and export equipment, Natural gas distribution, Onshore petroleum and natural gas
gathering and boosting, and Onshore natural gas transmission.
X The annual CO2e emissions are estimated to be more than 25,000 metric tons. The facility
is considered a natural gas gathering and boosting facility applicable under Subpart W.
Note: The subpart of each of the programs listed above were reviewed for applicability. Those subparts within each program that are categorically not relevant are not listed in above.
Kinder Morgan
Appendix I - FCAA Applicability Review Hideout Compressor Station SLR Project No.: 132.01110.0010
Page 4
APPENDIX I - Utah Administrative Code (UAC) Applicability
Facility: Kinder Morgan - Hideout Compressor Station
December 2023
Program
Identifier Rule Citation Rule Summary & Applicability Notes Ap
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No
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Ap
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Determination Notes
UAC R307-101 General Requirements X
UAC R307-102 General Requirements: Broadly Applicable Requirements.X
UAC R307-103 Administrative Procedures.X Administrative proceedings under Utah Air Quality Act are governed
by Rule R305-7
UAC R307-104 Conflict of Interest X
Rule establishes procedures that are necessary for promulgating
federally approvable air quality standards as permitted by
subsection 19-2-104(1)(b).
UAC R307-105 General Requirements: Emergency Controls X Applies to the Director
UAC R307-107 General Requirements: Unavoidable Breakdown X
UAC R307-110 General Requirements: State Implementation Plan.X
UAC R307-115 General Conformity.X Incorporation by reference
UAC R307-120 General Requirements: Tax Exemption for Air Pollution Control Equipment X
UAC R307-121 General Requirements: Clean Air and Efficient Vehicle Tax Credit X
UAC R307-122 General Requirements: Heavy Duty Vehicle Tax Credit X
UAC R307-123 General Requirements: Clean Fuels and Vehicle Technology Grant and Loan Program X
UAC R307-124 General Requirements: Conversion to Alternative Fuel Grant Program X
UAC R307-125 Clean Air Retrofit, Replacement, and Off-Road Technology Program X
UAC R307-130 General Penalty Policy X
UAC R307-135 Enforcement Response Policy for Asbestos Hazard Emergency Response Act.X
UAC R307-150 Emission Inventories X
UAC R307-150-1 Purpose and General Requirements X
UAC 150-1(3)
Periodic Emission Inventories. Emission inventories shall be submitted on or before April
15 of each year following the calendar year for which an inventory is required. X
UAC 150-1(5)
Recordkeeping. Maintain a copy of the emission inventory submitted to the Division and
make records available for inspection indicating how the information submitted in the
inventory was determined, including any calculations, data, measurements, and estimates
used. Records shall be kept for a period of at least five years from the due date of each
inventory.
X
UAC R307-150-2 Definitions X
UAC R307-150-3 Applicability X
UAC R307-150-4 Sulfur Dioxide Milestone Inventory Requirements X
R307-150-4 applies to all stationary sources with actual emissions
of 100 tons or more per year of sulfur dioxide in calendar year 2000
or any subsequent year unless exempted in (a) below - see R307-
150-3(1). Facility does not have actual annual emissions of more
than 100 TPY of sulfur dioxide.
Applicability Determination
Kinder Morgan
Appendix I - UAC Applicability Review Hideout Compressor Station
SLR Project No. 132.01110.0010
Page 1
Program
Identifier Rule Citation Rule Summary & Applicability Notes Ap
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Ap
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Determination Notes
Applicability Determination
UAC R307-150-5 Sources Identified in R307-150-3(2), Large Major Source Inventory Requirements X R307-150-5 applies to large major sources - see R307-150-3(2).
Facility is not a "Large Major Source" as defined in R307-150-2.
UAC R307-150-6
R307-150-6 applies to:
(a) each major source that is not a large major source;
(b) each source with the potential to emit 5 tons or more per year of lead; and
(c) each source not included in (2) or (3)(a) or (3)(b) above that is located in Davis, Salt
Lake, Utah, or Weber Counties and that has the potential to emit 25 tons or more per year
of any combination of oxides of nitrogen, oxides of sulfur and PM10, or the potential to
emit 10 tons or more per year of volatile organic compounds.
- Sources identified in 150-3(3)
X
Facility is not a major source, and is not a large major source.
Triennial emission inventories of PM10, PM2.5, SOx, NOx, CO,
VOC and HAP are not required to be submtited to the UDAQ.
UAC R307-150-7 Sources Identified in R307-150-3(4), Other Part 70 Sources X R307-150-7 Applies to Part 70 sources not included in R307-150-
3(2) or (3) - see R307-150-3(4).
UAC R307-150-8 Exempted Hazardous Air Pollutants X
UAC R307-165 Emission testing X
Establishes the emission testing requirements and frequency for all
areas of Utah. Emissions testing requirements will be set out in
Approval Order.
UAC R307-170 Continuous Emission Monitoring Program X
Source is not required to install a continuous monitoring system to
determine emissions to the atmosphere or to measure control
equipment efficiency
UAC R307-201 Emission Standards: General Emission Standards X
UAC R307-201-3 Visible Emission Standards X Opacity standards apply to any installation
UAC R307-202 Emission Standards: General Burning X Permittee does not engage in regulated activity
UAC R307-203 Emission Standards: Sulfur Content of Fuels X
All of the new/modified combustion sources will be fired with
pipeline quality natural gas; therefore, the sulfur content limits of this
section (fuel oil and coal only) do not apply.
UAC R307-204 Emission Standards: Smoke Management X Permittee does not engage in regulated activity
UAC R307-205 Fugitive Emissions and Fugitive Dust X
Kinder Morgan
Appendix I - UAC Applicability Review Hideout Compressor Station
SLR Project No. 132.01110.0010
Page 2
Program
Identifier Rule Citation Rule Summary & Applicability Notes Ap
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Determination Notes
Applicability Determination
UAC R307-206 Emission Standards: Abrasive Blasting X Permittee does not engage in regulated activity
UAC R307-207 Residential Fireplaces and Solid Fuel Burning Devices X Permittee does not engage in regulated activity
UAC R307-208 Outdoor Wood Boilers X Permittee does not engage in regulated activity
UAC R307-210 Standards of Performance for New Stationary Sources X
The provisions of 40 CFR Part 60, effective on July 1, 2016, except
for Subparts Cb, Cc, Cd, Ce, BBBB, DDDD, and HHHH, are
incorporated by reference. Permittee owns and operates "affected
facilities" subject to certain NSPS subparts.
UAC R307-214 National Emission Standards for Hazardous Air Pollutants X
The provisions of Title 40 of the Code of Federal Regulations (40
CFR) Part 61, National Emission Standards for Hazardous Air
Pollutants, effective as of July 1, 2016, are incorporated into these
rules by reference. No Part 61 rule applies.
UAC R307-220 Emission Standards: Plan for Designated Facilities X Permittee does not engage in regulated activity
UAC R307-221 Emission Standards: Emission Controls for Existing Municipal Solid Waste Landfills X Permittee does not engage in regulated activity
UAC R307-222 Emission Standards: Existing Incinerators for Hospital, Medical, Infectious Waste X Permittee does not engage in regulated activity
UAC R307-223 Emission Standards: Existing Small Municipal Waste Combustion Units X Permittee does not engage in regulated activity
UAC R307-224 Mercury Emission Standards: Coal-Fired Electric Generating Units X Permittee does not engage in regulated activity
UAC R307-250 Western Backstop Sulfur Dioxide Trading Program X
Facility does not have the potential to emit 100 tons or more of
sulfur dioxide per year and does not otherwise operate affected
facilities
UAC R307-301 Utah and Weber Counties: Oxygenated Gasoline Program As a Contingency Measure X Permittee does not engage in regulated activity
UAC R307-302 Solid Fuel Burning Devices X Permittee does not engage in regulated activity
UAC R307-303 Commercial Cooking X Permittee does not engage in regulated activity
UAC R307-305 Nonattainment and Maintenance Areas for PM10: Emission Standards X Permittee does not engage in regulated activity
UAC R307-306 PM10 Nonattainment and Maintenance Areas: Abrasive Blasting X Permittee does not engage in regulated activity
UAC R307-307 Road Salting and Sanding X Permittee does not engage in regulated activity
UAC R307-309
Nonattainment and Maintenance Areas for PM10 and PM2.5: Fugitive Emissions and
Fugitive Dust. R307-309 applies to all sources of fugitive dust and fugitive emissions
located in PM10 and PM2.5 nonattainment and maintenance plan areas as defined in 40
CFR 81.345 (July 1, 2011), except as specified in R307-309-3(2).
X Facility is not located in PM10 and PM2.5 nonattainment and
maintenance plan areas.
Kinder Morgan
Appendix I - UAC Applicability Review Hideout Compressor Station
SLR Project No. 132.01110.0010
Page 3
Program
Identifier Rule Citation Rule Summary & Applicability Notes Ap
p
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a
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No
t

Ap
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Determination Notes
Applicability Determination
UAC R307-310 Salt Lake County: Trading of Emission Budgets for Transportation Conformity X Permittee does not engage in regulated activity
UAC R307-311 Utah County: Trading of Emission Budgets for Transportation Conformity X Permittee does not engage in regulated activity
UAC R307-312 Aggregate Processing Operations for PM2.5 Nonattainment Areas X Permittee does not engage in regulated activity
UAC R307-320 Ozone Maintenance Areas and Ogden City: Employer-Based Trip Reduction Program X Permittee does not engage in regulated activity
UAC R307-325
Ozone Nonattainment and Maintenance Areas: General Requirements.
No person shall allow or cause volatile organic compounds (VOCs) to be spilled,
discarded, stored in open containers, or handled in any other manner that would result in
greater evaporation of VOCs than would have if reasonably available control technology
(RACT) had been applied.
X
R307-325 applies to all sources located in any nonattainment or
maintenance area for ozone. Facility is located in an ozone
nonattainment area. All storage tanks are controlled with a vapor
collection system and combustion.
UAC R307-326
Ozone Nonattainment and Maintenance Areas: Control of Hydrocarbon Emissions in
Petroleum Refineries X Permittee does not engage in regulated activity
UAC R307-327
Ozone Nonattainment and Maintenance Areas: Petroleum Liquid Storage. R307-327
applies to the owner or operator of any petroleum refinery or petroleum liquid storage
facility located in any ozone nonattainment or maintenance area.
X The facility is not a petroleum refinery or petroleum liquid storage
facility.
UAC R307-328 Gasoline Transfer and Storage X Permittee does not engage in regulated activity
UAC R307-335 Degreasing and Solvent Cleaning Operations X Permittee does not engage in regulated activity
UAC R307-341 Ozone Nonattainment and Maintenance Areas: Cutback Asphalt X Permittee does not engage in regulated activity
UAC R307-342 Adhesives and Sealants X Permittee does not engage in regulated activity
UAC R307-343 Emissions Standards for Wood Furniture Manufacturing Operations X Permittee does not engage in regulated activity
UAC R307-344 Paper, Film, and Foil Coatings X Permittee does not engage in regulated activity
UAC R307-345 Fabric and Vinyl Coatings X Permittee does not engage in regulated activity
UAC R307-346 Metal Furniture Surface Coatings X Permittee does not engage in regulated activity
UAC R307-347 Large Appliance Surface Coatings X Permittee does not engage in regulated activity
UAC R307-348 Magnet Wire Coatings X Permittee does not engage in regulated activity
UAC R307-349 Flat Wood Panel Coatings X Permittee does not engage in regulated activity
UAC R307-350 Miscellaneous Metal Parts and Products Coatings X Permittee does not engage in regulated activity
UAC R307-351 Graphic Arts X Permittee does not engage in regulated activity
UAC R307-352 Metal Container, Closure, and Coil Coatings X Permittee does not engage in regulated activity
UAC R307-353 Plastic Parts Coatings X Permittee does not engage in regulated activity
UAC R307-354 Automotive Refinishing Coatings X Permittee does not engage in regulated activity
UAC R307-355 Control of Emissions from Aerospace Manufacture and Rework Facilities X Permittee does not engage in regulated activity
UAC R307-356 Appliance Pilot Light X Permittee does not engage in regulated activity
UAC R307-357 Consumer Products X Permittee does not engage in regulated activity
UAC R307-361 Architectural Coatings X Permittee does not engage in regulated activity
UAC R307-401 Permit: New and Modified Sources X
Kinder Morgan
Appendix I - UAC Applicability Review Hideout Compressor Station
SLR Project No. 132.01110.0010
Page 4
Program
Identifier Rule Citation Rule Summary & Applicability Notes Ap
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a
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No
t

Ap
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Determination Notes
Applicability Determination
UAC R307-403
New and Modified sources in Nonattainment Areas and Maintenance Areas. R307-403
applies to any new major stationary source or major modification that is major for the
pollutant for which the area is designated nonattainment
X
The facility will not be major stationary source for the pollutants for
which the area is designated nonattainment. Therefore provisions of
R307-403 do not apply.
UAC R307-405 Permits: Major Sources in Attainment or Unclassified Areas X Facility will not be classified as a "major source" for any criteria
pollutants.
UAC R307-406 Visibility X
UAC R307-410 Permits: Emissions Impact Analysis X Included with NOI
UAC R307-414
Permits: Fees for Approval Orders. The owner and operator of each new major source or
major modification is required to pay a fee to the Department sufficient to cover the
reasonable costs of reviewing and acting upon the notice of intent.
X Facility will not be classified as a "major source" for any criteria
pollutants.
UAC R307-415 Permits: Operating Permit Requirements X
Facility will not be classified as a "major source" for any criteria
pollutants.
UAC R307-417 Permits: Acid Rain Sources X Facility is not an acid rain source
UAC R307-420 Permits: Ozone Offset Requirements in Davis and Salt Lake Counties X Facility is not located in in Salt Lake County or Utah County
UAC R307-421 Permits: PM10 Offset Requirements in Salt Lake County and Utah County X Facility is not located in in Salt Lake County or Utah County
UAC R307-424 Permits: Mercury Requirements for Electric Generating Units X Permittee does not operate EGUs
UAC R307-501 Oil and Gas Industry: General Provisions X
R307-501 applies to all oil and natural gas exploration, production,
and transmission operations; well production facilities; natural gas
compressor stations; and natural gas processing plants in Utah.
UAC R307-501-4
General Provisions. Includes general requirements for air pollution control equipment, the
prevention of emissions and the use of good air pollution control practices.X
UAC R307-502 Oil and Gas Industry: Pneumatic Controllers X All pneumatic devices at the facility are driven by air and therefore
are not subject to these requirements.
UAC R307-503
Oil and Gas Industry: Flares
All open flares and all enclosed flares installed on or after January 1, 2015 shall be
equipped with an operational auto-igniter upon installation of the flare.
X Facility is a natural gas compressor station equipped with an open-
flame flare. Flare to be installed with an auto-ignitor.
UAC R307-504
Oil and Gas Industry: Tank Truck Loading. R307-504 establishes control requirements for
the loading of liquids containing volatile organic compounds at oil or gas well sites. X Facility is not a well site.
UAC R307-801 Utah Asbestos Rule X Facility is new with all new equipment and is not constructed with
asbestos containing materials.
UAC R307-840 Lead-Based Paint Program Purpose, Applicability, and Definitions X Permittee is not engaged in lead-based paint activities and
renovations
UAC R307-841 Residential Property and Child-Occupied Facility Renovation X Permittee does not engage in regulated activity
UAC R307-842 Lead-Based Paint Activities X Permittee does not engage in regulated activity
Notes: All subtitles to R307 were reviewed for applicability. Those subtitles that were categorically not applicable were not included in the table above.
Kinder Morgan
Appendix I - UAC Applicability Review Hideout Compressor Station
SLR Project No. 132.01110.0010
Page 5
Appendix J 
Emissions Impact Analysis 

Hideout Compressor Station
Modeled Emissions Impact Analysis
Kinder Morgan Altamont LLC

Prepared by:
SLR International Corporation
1612 Specht Point Road, Suite 119, Fort Collins, Colorado, 80525

SLR Project No.: 132.01110.00109

December 21, 2023

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

ii

Table of Contents
1.0 Emissions Impact Analysis ............................................................................................. 1
1.1 General Modeling Approach ............................................................................................... 1
1.2 Emission Unit Descriptions and Locations .......................................................................... 2
1.3 Building Downwash Analysis .............................................................................................. 2
1.4 Model Receptors and Terrain ............................................................................................. 2
1.5 AERMET Meteorological Data Analysis .............................................................................. 2
1.6 NO2 Modeling Approach ..................................................................................................... 3
1.7 Background Air Quality Data .............................................................................................. 3
1.8 Offsite Emission Sources ................................................................................................... 3
2.0 Modeling Results - Cumulative Impact Analysis – NO2 ................................................. 4

Tables
Table 1 Modeled Emission Rates and Exhaust Parameters ....................................................... 3
Table 2 Background Concentrations for used for the Cumulative Impact Analysis ..................... 4
Table 3 Cumulative Impact Analysis Summary .......................................................................... 4

Figures
Figure 1 Diagram of Modeled Buildings and Sources ............................................................. 6
Figure 2 3-Dimensional Modeled Site Layout ......................................................................... 7

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

iii

Hideout Compressor Station
Modeled Emissions Impact Analysis

Prepared for:
Kinder Morgan Altamont LLC

This document has been prepared by SLR International Corporation (SLR). The material in this
report was prepared under the supervision and direction of the undersigned.

Abigail Stewart
Project Scientist

Tom Damiana
Principal Engineer

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

1

1.0 Emissions Impact Analysis
The construction of new facilities or modifications to existing sources that result in total
controlled emission increase levels greater than those listed in the Utah Administrative Code
(UAC) Section R307-410-4 are required to submit a dispersion modeling analysis as part of a
complete Notice of Intent (NOI) application package. Additionally, UAC Section R307-410-5
requires applicant sources proposing any increase of hazardous air pollutant (HAP) emissions
to submit all HAP emission levels and pollutant release information for their facility.
Potential criteria pollutant and HAP emissions from the proposed construction and installation of
the Hideout Compressor Station have been evaluated and supporting information regarding the
facility process and calculated emissions are provided in Appendices A and C of the permit
application package. Appendix J of the permit application package demonstrates that the
potential project emissions for oxides of nitrogen (NOx) were found to exceed the emissions
thresholds listed in UAC Section R307-410-4. As a result, air dispersion modeling was
conducted to demonstrate that the proposed project will not cause or contribute to an
exceedance of the annual and 1-hour average NO2 National Ambient Air Quality Standards
(NAAQS).
Additionally, a HAPs analysis was conducted according to UAC Section R307-410-5 and is
presented in Table J-1 of Appendix J of the permit application package. As described in
Appendix J, formaldehyde from the large 4-Stroke Rich Burn Spark Ignition compressor engines
was the only significant HAP that exceeded the emissions threshold value (ETV). However,
these emissions units are subject to an emission standard promulgated under 42 U.S.C. 7412
(NESHAP Subpart ZZZZ) and are exempt from the requirements of UAC Sections R307-410-
5(c)(i)(A) through (C) which is a comparison of the emission unit emissions to ETVs. Thus,
formaldehyde emissions from these compressor engines does not require a dispersion
modeling analysis.
The air quality analysis was conducted based on the approaches documented in the Minor
Source Modeling Protocol Form that was approved by Dave Prey at the Utah Department of
Environmental Quality1. These approaches are described in more detail in the subsections that
follow.
1.1 General Modeling Approach
This modeling analysis consists of the following:
 The latest version of AERMOD (v23132);
 Model-ready meteorological input surface and upper air data consisting of surface data
from Vernal, Utah (2016-2020) and upper air data from Grand Junction, Colorado was
downloaded from UDAQ’s website2;

1 Approved on November 29, 2023 via email.
2 https://deq.utah.gov/air-quality/emissions-impact-assessment-guideline-preface
Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

2

 Terrain elevations from the National Elevation Dataset files acquired from the U.S.
Geological Survey were processed in the latest version of AERMAP (v18081) to develop
the receptor terrain elevations and corresponding hill height scale required by AERMOD;
and
 The most recent version of BPIP (04/21/2004) was used to produce the inputs needed
for AERMOD to simulate the effects of building downwash on source plumes.
1.2 Emission Unit Descriptions and Locations
Table 1 provides the modeled emission unit (EU) physical parameters and emission rates. All
EUs were modeled as vertical, uncapped point sources and all EU locations were referenced to
the Universal Transverse Mercator (UTM) Zone 12 North American Datum 1983 (NAD83)
coordinate system. The actual stack diameter and release height for the flare (FL-1) were used
for modeling.
1.3 Building Downwash Analysis
The modeling analysis follows the guidance provided in the EPA Guidelines for Determination of
Good Engineering Practice Stack Height (EPA-450/4-80-023R, June 1985). Direction-specific
building downwash dimensions for use as modeling inputs were calculated using BPIP. Building
coordinates and heights for each structure that could influence a modeled EU were entered into
BPIP and the output dimensions were used to ensure that no stack exceeds good engineering
practice stack height and to provide the direction-specific downwash dimensions to the
AERMOD model.
1.4 Model Receptors and Terrain
Terrain elevations from the National Elevation Dataset (NED) files acquired from the United
States Geological Survey (USGS) were processed in the latest version of AERMAP to develop
receptor terrain elevations and corresponding hill height scales input into AERMOD. The near
grid receptor field consists of:
 Fence-line receptors spaced apart by no more than 25 meters;
 Receptors spaced at 25 meters out to 100 meters;
 Receptors spaced at 100 meters out to 1,000 meters;
 Receptors spaced at 250 meters out to 5,000 meters;
 Receptors spaced at 500 meters out to 10,000 meters;
 Receptors spaced at 1,000 meters out to 20,000 meters.
1.5 AERMET Meteorological Data Analysis
A five-year meteorological dataset provided by UDAQ was used to estimate the pollutant
impacts from the proposed project. The meteorological data were collected at the Vernal, UT
National Weather Service (NWS) Automated Surface Observation System (ASOS) from
January 1, 2016 through December 31, 2020. This dataset was processed with the “adjust u*”
option to adjust the surface friction velocity to address issues with the AERMOD model
tendency to overpredict from some sources under stable, low wind speed conditions.
Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

3

1.6 NO2 Modeling Approach
For modeling purposes, ARM2 and the default upper and lower equilibrium ratios of 0.9 and 0.5,
respectively were used for NO2 modeling.
1.7 Background Air Quality Data
Background ambient air quality data are required for a cumulative impact analysis to represent
the contribution of ambient air pollutant levels from non-modeled sources. Ambient NO 2
concentrations based on the most recent 3-years (2020 to 2022) of ambient air data collected at
Roosevelt, UT were used to represent the ambient air background levels at the project location.
The monitoring station in Roosevelt, UT is located 8 kilometers north-northeast of the project
and is exposed to impacts from the same sources that impact the project location. Therefore,
this data is representative of non-modeled sources in the project impact area. Table 2 provides
background air quality data from Roosevelt for all measured pollutants and used to support this
analysis.
1.8 Offsite Emission Sources
Following UDAQ guidance, offsite sources that are either not expected to produce a significant
concentration gradient in the impact area or are included in the background concentration
estimates are not explicitly modeled, per 40 CFR Part 51, Appendix W, Sections 8.2 and 8.3. As
a result, only project sources were explicitly modeled.

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

4

2.0 Modeling Results - Cumulative Impact Analysis – NO2
The impacts from project sources were predicted using the simulation described in Sections 1.1
through 1.5. Ambient NO2 background concentrations were added to the modeled NO 2 impacts
as shown in Table 3 for comparison to the annual and 1-hour NO 2 NAAQS. The results in
Table 3 show that the modeled impacts, when added to background ambient air levels, are less
than the NO2 NAAQS.

Tables
Hideout Compressor Station
Modeled Emissions Impact Analysis
Kinder Morgan Altamont LLC
SLR Project No.: 132.01110.00109
December 21, 2023

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

Table 1 Modeled Emission Rates and Exhaust Parameters
Emission Unit Modeled Emission
Rates (g/s) Modeled Exhaust Parameters
EU ID Model ID Description NOx Height (m) Temperature (K) Velocity (m/s) Diameter (m)
C-1 C_1
Inlet Compressor 4 Stroke Rich
Burn Spark Ignition-RICE 0.1582 12.19 866.48 38.20 0.356
C-2 C_2
C-3 C_3
C-4 C_4
C-5 C_5
C-6 C_6
C-7 C_7
C-8 C_8
C-9 C_9
C-10 C_10
H-1 H_1 Heater / Reboiler
0.01480
6.096
588.71 3.24 0.253
H-2 H_2 Gas Fired Stabilizer Heater 6.100
FL-1 FL_1 Facility Flare 0.2513 18.29 1273 20 0.357
COM-1 COM_1 Tank & Tank Loadout
Combustor 0.04900 3.66
1255.37
4.41
0.508
COM-2 COM_2 BTEX Combustor 0.01360 3.66 0.9158

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

Table 2 Background Concentrations for used for the Cumulative Impact Analysis
Primary Pollutant Averaging Period Design Value Background
Concentration 1
Monitor Information
NO2
1-Hour 31.07 ppb (58.47 μg/m3)
Roosevelt, Utah
Annual 10.45 ppb (19.66 μg/m3)
SO2 1-Hour 2.00 ppb
PM10 24-Hour 146.33 μg/m3
PM2.5
24-Hour 23.77 μg/m3
Annual 6.28 μg/m3
CO
1-Hour 0.50 ppm
8-Hour 0.40 ppm
O3 1-Hour 0.06 ppm
1 Based on measurements collected from 2020 through 2022.

Table 3 Cumulative Impact Analysis Summary
Pollutant Averaging
Period
Background
Level
(μg/m3)
Model-Predicted Design Value (μg/m3) Maximum
Modeled
Impact
(μg/m3)
Cumulative
Impact
(μg/m3)
NAAQS
(μg/m3) 2016 2017 2018 2019 2020
NO2
1-Hour 1 58.47 82.52 82.52 141 188
Annual 19.66 4.011 3.947 3.780 3.934 3.938 4.011 23.7 100
1 The modeled 5-year average of the 98th percentile of the annual distribution of 1-hour daily maximum NO2 concentrations is compared against the
level of the 1-hour NO2 NAAQS per EPA guidance.

Figures/Drawings
Hideout Compressor Station
Modeled Emissions Impact Analysis
Kinder Morgan Altamont LLC
SLR Project No.: 132.01110.00109
December 21, 2023

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

Figure 1 Diagram of Modeled Buildings and Sources

Kinder Morgan Altamont LLC
Hideout Compressor Station
December 21, 2023
SLR Project No.: 132.01110.00109

Figure 2 3-Dimensional Modeled Site Layout