DAQ-2025-000844

DAQE-AN102100011-25

{{$d1 }}

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

Dear Mr. Ayala:

Re: Approval Order: Administrative Amendment to Approval Order DAQE-AN102100007-16 to
Update Equipment and Emissions
Project Number: N102100011

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on June 20,
2024. 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.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:TA:jg

cc: TriCounty Health Department
EPA Region 8

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

February 10, 2025

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

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APPROVAL ORDER
DAQE-AN102100011-25
Administrative Amendment to Approval Order
DAQE-AN102100007-16 to Update Equipment
and Emissions

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

Issued to
Kinder Morgan Altamont LLC - Altamont West Compressor Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

February 10, 2025
TABLE OF CONTENTS

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

DAQE-AN102100011-25
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

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

Mailing Address Physical Address
1001 Louisiana Street, Suite 1000 PO Box 587
Houston, TX 77002 Altamont, UT 84001

Source Contact UTM Coordinates
Name: Rich Ayala 551,427 m Easting
Phone: [phone],463,055 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) South Compressor Station receives and compresses
natural gas from the Altamont field. The station is located approximately ten (10) miles west of Altamont.
The equipment at this source consists of two (2) inlet gas compressors, a dehydration unit with a BTEX
condenser, a flare, a loading rack, and various tanks with line heaters.

NSR Classification
Administrative Amendment

Source Classification
Located in
Duchesne County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
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
Title V (Part 70) Major Source
DAQE-AN102100011-25
Page 4

Project Description
Kinder Morgan has requested to replace CE-2 (natural gas-fired reciprocating internal combustion engine,
inlet gas compressor) with a unit with the same capacity (1,030 hp), but the new unit will also include a
non-selective catalytic reduction catalyst and air-fuel-ratio controller on the engine. The replaced
compressor engine (CE-2) is being conducted as a "Reduction in Air Pollutants" UAC R307-401-12 since
all emissions are being reduced.

This permit change qualifies as a reduction in air pollutants (UAC R307-401-12) and does not require a
public review.

SUMMARY OF EMISSIONS

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

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent 0 16005.00
Carbon Monoxide 0 13.90
Nitrogen Oxides -159.13 180.04
Particulate Matter - PM10 0 0.78
Particulate Matter - PM2.5 0 0.78
Sulfur Oxides 0 0.05
Volatile Organic Compounds -0.09 27.93

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
1,3-Butadiene (CAS #106990) 0 182
Acetaldehyde (CAS #75070) 0 1212
Acrolein (CAS #107028) 0 1192
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 3220
Ethyl Benzene (CAS #100414) 0 20
Formaldehyde (CAS #50000) 0 3000
Generic HAPs (CAS #GHAPS) 0 480
Hexane (CAS #110543) 0 4080
Methanol (CAS #67561) 0 704
Toluene (CAS #108883) 0 440
Xylenes (Isomers And Mixture) (CAS #1330207) 0 100
Change (TPY) Total (TPY)
Total HAPs 0 7.32

DAQE-AN102100011-25
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 five-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 five (5) 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]

SECTION II: PERMITTED EQUIPMENT

II.A THE APPROVED EQUIPMENT

II.A.1 Altamont West Compressor Station Source-wide
II.A.2 CE-2 (NEW)
One (1) Natural Gas-Fired Reciprocating Internal Combustion Engine Capacity: 1,030 hp
Control: Non-selective catalytic reduction catalyst, air-fuel-ratio controller
Federal Applicable: 40 CFR 60 Subpart JJJJ
II.A.3 F Flare Flare with knock out and natural gas pilot
II.A.4 BCU
BTEX Condenser Unit
DAQE-AN102100011-25
Page 6

II.A.5 T-1 Pit tank Approximate volume: 16,800 gallons non-NSPS (below 19,813 gallons threshold for 40 CFR Part 60, Subpart Kb)
II.A.6 T-2 and 3 Two (2) 400-barrel Condensate Tank Approximate volume: 16,800 gallons (each)
non-NSPS (below 19,813-gallon threshold for 40 CFR Part 60, Subpart Kb)
II.A.7 CE-3 One (1) Natural Gas Fired Reciprocating Internal Combustion Engine Powers an inlet gas compressor Approximately 1030 hp Construction during a period of exemption for natural gas burning equipment. (Code of Air Conservation Regulations, 1972, 1.3.7) non-NSPS (constructed prior to applicability date)
II.A.8 TEG Triethylene glycol reboiler burner exhaust vent
Natural gas burner
Approximately 500,000 BTU/h Construction during a period of exemption for natural gas burning equipment. (Code of Air
Conservation Regulations, 1972, 1.3.7)

II.A.9 LH Natural Gas Fired Line Heater: Approximately 2,000,000 BTU/hr Construction during a period of exemption for natural gas burning equipment. (Code of Air Conservation Regulations, 1972, 1.3.7)
II.A.10 Truck Loading Rack Submerged loading of condensate

II.A.11 Fugitives Equipment leaks of VOC

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 Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401]
DAQE-AN102100011-25
Page 7

II.B.1.b The owner/operator shall use only pipeline-quality natural gas as a primary fuel. If any other fuel is to be used, an AO shall be required. [R307-401] II.B.1.c The flare shall be used for emergencies and planned station blowdowns for repair and maintenance activities. [R307-401]

II.B.1.d The following items are recognized to be at the West Compressor Station. A permit is not necessary for their operation due to construction during a period of exemption (Code of Air Conservation Regulations, 1972, 1.3.7) for natural gas burning equipment: A. Reciprocating internal combustion engine: Powers an inlet gas compressor, approximately 1030 hp, natural gas fired B. Triethylene glycol reboiler burner exhaust vent: Natural gas burner, approximately 500,000 BTU/hr C. Line heater: Approximately 2,000,000 BTU/hr, natural gas fired. [R307-401]
II.B.2 Requirements on Compressor Engine (CE-2)
II.B.2.a The owner/operator shall not emit more than the following rates and concentrations from the indicated emissions unit(s): ***EMISSIONS UNIT CE-2*** Pollutant g/bhp-hr NOx 1.00 CO 0.65 VOC 0.10 [R307-401-8] II.B.2.a.1 Standard Conditions and 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 for CE-2 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. [40 CFR 60 Subpart JJJJ, R307-401-8]

DAQE-AN102100011-25
Page 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. [R307-165]
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 Requirements on Condensate
II.B.3.a The following production limits shall not be exceeded:
4,250,000 gallons of condensate produced per rolling 12-month total.

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, records of tank throughput 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]

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:
Supersedes AO DAQE-AN102100007-16 dated December 28, 2016 Is Derived From NOI dated June 20, 2024
DAQE-AN102100011-25
Page 9

ACRONYMS

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

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

DAQE-

RN102100011 January 22, 2025 Rich Ayala
Kinder Morgan Altamont LLC 1001 Louisiana St. Suite 1000
Houston, TX 77002 [e-mail]
Dear Rich Ayala, Re: Engineer Review: Administrative Amendment to Approval Order to DAQE-AN102100007-16, to Update Equipment and Emissions Project Number: N102100011 Please review and sign this letter and attached Engineer Review (ER) within 10 business days. For this document to be considered as the application for a Title V administrative amendment, a Title V Responsible Official must sign the next page.
Please contact Tad Anderson at [phone] if you have any questions or concerns about the ER. If you accept the contents of this ER, please email this signed cover letter to Tad Anderson at [e-mail]. After receipt of the signed cover letter, the DAQ 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 your approval. If you have concerns that we cannot resolve, 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 N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 1
OPTIONAL: In order for this Engineer Review and associated Approval Order conditions to be considered as an application to administratively amend your Title V Permit, the Responsible Official, as
defined in R307-415-3, must sign the statement below. THIS IS STRICTLY OPTIONAL. If you do not want the Engineer Review to be considered as an application to administratively amend your Operating Permit only the approval signature above is required. Failure to have the Responsible Official sign below will not delay the Approval Order, but will require submittal of a separate Operating Permit Application to revise the Title V permit in accordance with R307-415-5a through 5e and R307-415-7a through 7i. A guidance document: Title V Operating Permit Application Due Dates clarifies the required due dates for Title V operating permit applications and can be viewed at:
https://deq.utah.gov/air-quality/permitting-guidance-and-guidelines-air-quality “Based on information and belief formed after reasonable inquiry, I certify that the statements and information provided for this Approval Order are true, accurate and complete and request that this Approval Order be considered as an application to administratively amend the Operating Permit.” Responsible Official _________________________________________________ (Signature & Date) Print Name of Responsible Official _____________________________________

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 2
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION
Project Number N102100011 Owner Name Kinder Morgan Altamont LLC
Mailing Address 1001 Louisiana St. Suite 1000 Houston, TX, 77002
Source Name Kinder Morgan Altamont LLC.- Altamont West Compressor Station Source Location: PO Box 587 Altamont, UT 84001 UTM Projection 551,427 m Easting, 4,463,055 m Northing UTM Datum NAD27 UTM Zone UTM Zone 12 SIC Code 1311 (Crude Petroleum & Natural Gas) Source Contact Rich Ayala Phone Number [phone]
Email [e-mail] Billing Contact Rich Ayala
Phone Number 303-914-4932 Email [e-mail]
Project Engineer Tad Anderson, Engineer Phone Number [phone] Email [e-mail] Notice of Intent (NOI) Submitted June 20, 2024 Date of Accepted Application December 10, 2024

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 3
SOURCE DESCRIPTION General Description
The Kinder Morgan, South Compressor Station receives and compresses natural gas from the Altamont field. The station is located approximately ten miles west of Altamont. The equipment at this source consists of two inlet gas compressors, a dehydration unit with BTEX condenser,
flare, loading rack, and various tanks with line heaters. NSR Classification: Administrative Amendment Source Classification Located in Duchesne County Airs Source Size: A Applicable Federal Standards NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines 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
Title V (Part 70) Major Source Project Proposal Administrative Amendment to Approval Order to DAQE-AN102100007-16, to Update Equipment and Emissions
Project Description Kinder Morgan has requested to replace CE-2 (Natural gas-fired reciprocating internal combustion engine, inlet gas compressor) with a unit with the same capacity (1,030 hp) but the new unit will also include a non-selective catalytic reductions catalyst and air-fuel-ratio controller on the engine. The replaced compressor engine (CE-2) is being conducted as a "Reduction in Air Pollutants" UAC R307-401-12, since all emissions are being reduced. This permit change qualifies as a reduction in air pollutants (UAC R307-401-12) and does not
require a public review EMISSION IMPACT ANALYSIS
Modeling is not required as per R307-410-4 and R307-410-5. [Last updated December 4, 2024]

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 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 0 16005.00 Carbon Monoxide 0 13.90
Nitrogen Oxides -159.13 180.04
Particulate Matter - PM10 0 0.78
Particulate Matter - PM2.5 0 0.78
Sulfur Oxides 0 0.05
Volatile Organic Compounds -0.09 27.93 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
1,3-Butadiene (CAS #106990) 0 182
Acetaldehyde (CAS #75070) 0 1212
Acrolein (CAS #107028) 0 1192
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 3220
Ethyl Benzene (CAS #100414) 0 20 Formaldehyde (CAS #50000) 0 3000 Generic HAPs (CAS #GHAPS) 0 480
Hexane (CAS #110543) 0 4080
Methanol (CAS #67561) 0 704
Toluene (CAS #108883) 0 440
Xylenes (Isomers And Mixture) (CAS #1330207) 0 100 Change (TPY) Total (TPY) Total HAPs 0 7.32
Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 5
Review of BACT for New/Modified Emission Units 1. BACT review regarding Project
The BACT analysis took into consideration the following control technologies to control NOx
emissions from the new SI-RICE: 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 four-stroke rich burn (4SRB).
The CE-2 engine is classified as 4SRB engines and has the maximum rated power of 1,030 bhp.
Exhaust stacks for the units will be equipped with an NSCR catalyst to reduce the NOx emissions
rate by more than 95% to achieve 1 g/bhp-hr. The NSCR combustion control technology is considered BACT for the CE-2 natural gas-fired 4SRB engine with a 1 g/bhp-hr (2.27 lb/hr) NOx
limit. A 10% opacity is also considered BACT for the CE-2c4SRB engine. [Last updated December 10, 2024]
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 Executive Secretary or Executive Secretary's representative upon request, and the records shall include the five-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 five (5) years. [R307-401-8]

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 6
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]

SECTION II: PERMITTED EQUIPMENT The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the
AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.A THE APPROVED EQUIPMENT
II.A.1 Altamont West Compressor Station Source-wide
II.A.2 NEW CE-2 (NEW) Natural Gas Fired Reciprocating Internal Combustion Engine
Capacity: 1,030 hp Control: Non-selective catalytic reduction catalyst, Air-fuel-ratio controller Federal Applicable: 40 CFR 60 Subpart JJJJ
II.A.3 F Flare Flare with knock out and natural gas pilot

II.A.4 BCU BTEX Condenser Unit
II.A.5 T-1 Pit tank Approximate volume 16,800 gallons non NSPS (below 19,813 gallons threshold for 40 CFR Part 60, Subpart Kb)
II.A.6 T-2,3 Two 400 barrel Condensate Tank Approximate volume 16,800 gallons (each) non NSPS (below 19,813 gallon threshold for 40 CFR Part 60, Subpart Kb)

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 7
II.A.7 CE-3 One (1) Natural Gas Fired Reciprocating Internal Combustion Engines Powers an inlet gas compressor
approximately 1030 hp (each) Construction during a period of exemption for natural gas burning equipment. (Code of Air Conservation Regulations, 1972, 1.3.7)
non NSPS (constructed prior to applicability date) II.A.8 TEG Triethylene glycol reboiler burner exhaust vent Natural gas burner approximately 500,000 BTU/h Construction during a period of exemption for natural gas burning equipment. (Code of Air
Conservation Regulations, 1972, 1.3.7) II.A.9 LH Natural Gas Fired Line heater: Approximately 2,000,000 BTU/hr Construction during a period of exemption for natural gas burning equipment. (Code of Air Conservation Regulations, 1972, 1.3.7)

II.A.10 Truck Loading Rack
Submerged loading of condensate II.A.11 Fugitives Equipment leaks of VOC

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

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 8
II.B.1.b The owner/operator shall use only pipeline quality natural gas as a primary fuel. If any other fuel is to be used, an AO shall be required. . [R307-401]

II.B.1.c The flare shall be used for emergencies and planned station blow downs for repair and maintenance activities. [R307-401] II.B.1.d NEW The following items are recognized to be at the West Compressor Station. A permit is not necessary for their operation due to construction during a period of exemption (Code of Air
Conservation Regulations, 1972, 1.3.7) for natural gas burning equipment: A. Reciprocating internal combustion engine: Powers an inlet gas compressor,
approximately 1030 hp, natural gas fired. B. Triethylene glycol reboiler burner exhaust vent: Natural gas burner, approximately
500,000 BTU/hr. C. Line heater: Approximately 2,000,000 BTU/hr, natural gas fired. [R307-401]
II.B.2 NEW Requirements on Compressor Engine (CE-2)
II.B.2.a
NEW
The owner/operator shall not emit more than the following rates and concentrations from the
indicated emissions unit(s): ***EMISSIONS UNIT CE-2*** Pollutant g/bhp-hr NOx 1.00
CO 0.65 VOC 0.10. [R307-401-8]
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 for CE-2 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. [40 CFR 60 Subpart JJJJ, R307-401-8]

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 9
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. [R307-165]
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 Requirements on Condensate
II.B.3.a
NEW
The following production limits shall not be exceeded:
4,250,000 gallons of condensate produced per rolling 12-month total 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, records of tank throughput 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]

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 10
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 June 20, 2024
Supersedes DAQE-AN102100007-16 dated December 28, 2016
REVIEWER COMMENTS

1. Comment regarding Permit Action: Kinder Morgan has requested an Administrative Amendment to AO DAQE-AN0102100007-16, the Altamont West compressor station, to replace CE-2 1030 hp compressor engine from the permit with a unit of same capacity but with NSCR and air-fuel-ratio controller on the engine. This permit action is being conducted so the change will be incorporated into the Title V permit. [Last updated December 4, 2024] 2. Comment regarding Estimated Emissions: The CE-2 Compressor engine emissions 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. [Last updated December 4, 2024]
3. Comment regarding PSD Source: The permit action is decreasing the emissions of NOx from 339.17 TPY to 180.04 TPY. This reduction in emissions will lower the source classification from a Major PSD source (250 TPY) to a
Major source (<100 TPY) for NOx. [Last updated December 4, 2024] 4. Comment regarding Existing Grandfathered Equipment: This permit contains equipment (CE-3 and LH) that were installed after the 1970 Clean Air Act. Compressor Engine CE-3 and line heater were installed during a period of exemption (Code of Air Conservation Regulations, 1972, 1.3.7) for natural gas burning equipment. The CE-3 and line heater are listed in the permit, but no regulations are associated with the equipment. The PTE emissions for CE-3 and the line heater are accounted for in the permits PTEs and have included in the emissions inventories. [Last updated December 4, 2024] 5. Comment regarding Permit Format Update: The previous permit was permitted in 2016. UDAQ has changed the permit format since 2016 and this permit has been updated to reflect. [Last updated December 4, 2024]

Engineer Review N102100011: Kinder Morgan Altamont LLC.- Altamont West Compressor Station January 22, 2025 Page 11
ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document:
40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology
CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by EPA to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1 COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal UDAQ use EPA Environmental Protection Agency
FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i) GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/HR Pounds per hour
LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units
NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit
R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year
UAC Utah Administrative Code VOC Volatile organic compounds
Source:Kinder Morgan
Site:West
Project #:N10210-0011
AN102100007-19 permit new
change AO
TPY TPY TPY
PM10 Total 0.78 0.00 0.78
PM10 point 0.78 0.00 0.78
PM10 fugtive 0.00 0.00 0.00
PM2.5 Total 0.78 0.00 0.78
NOx 339.17 -159.13 180.04
CO 13.90 0.00 13.90
SOx 0.05 0.00 0.05 HAP Summary Sheet
VOC Total 28.02 -0.09 27.93 Existing Change New
VOC point 28.02 -0.09 27.93 TPY TPY TPYVOC Fugtive 0.00 0.00 0.00 7.32 0 7.32
HAPs 7.32 0.00 7.32
GHGs 16005.00 0.00 16005.00
Emissions breakout
PM10 PM2.5 SOx NOx VOC CO
Equipment Capaicty TPY TPY TPY TPY TPY TPY
CE-4 RICE 1,680 HP 0.554 0.554 0.02 1.14 0.285 0.285
TEG-2 w/still vent
VRU
Flare
Pit Tank 1 16,800 gal
2 Condensate Tanks 16,800 gal each
Methanol Tank 4,200 gal
2 Con. Tanks 16,800 gal each
Fugtive VOC
CE-1 RICE 1,030 HP
CE-2 RICE 1,030 HP
CE-3 RICE 1,030 HP
TEG-1 w/condenser 1 MMBtu/hr
Line Heater 2 MMBtu/hr
Condensate Loadout
Combustor
HAP GHG Inv
TPY TPY ID
180551
177480
174304
177150 ?
178012
17013
11889
180552
180553
11850
5598
5599
5600
178010
5602
178010
Source:Kinder Morgan
Site:West
Project #:N10210-0011
Existing Change New
TPY TPY TPY
HAPs Totals 7.32000 2.66480 0.00000
Existing Change New Existing ChangeHAPTPYTPYTPYlb/yr lb/yrAcetaldehyde0.771 0.02480 1542.00
Acrolein 0.680 1360.00Benzene1.200 2.64000 2400.00
1,3-Butadiene 0.001 2.65
Ethyl Benzene 0.020 40.00Formaldehyde3.800 7600.00
Methanol 0.617 1234.00
Hexane 1.140 2280.002,2,4-Trimethylpentane 0.030 60.00
Toluene 0.440 880.00
Xylene 0.160 320.00Generic0.076 151.00Total8.93483 2.66480
HAP's Modeling Existing Increase NewSourceSourceSourceHAPlb/hr lb/hr lb/hr <20m 20-50 50-100
2,2,4-Trimethylpentane
Acetaldehyde 0.00000 1.71155 2.29709 4.14376
Acrolein 0.00000 0.00871 0.01169 0.02109
Benzene 0.00000 0.02720 0.03510 0.06550Cobalt0.00000 0.00100 0.00130 0.00250
Ethylbenzene 0.00000 22.14000 28.66000 53.41000
Formaldehyde 0.00000 0.01400 0.01880 0.03390Hex. Chromium 0.00000 0.00020 0.00020 0.00040
n-Hexane 0.00000 8.98810 11.63166 21.67718
Methanol 0.00000 14.20074 18.37742 34.24883Naphthalene0.00000 2.67000 3.46000 6.45000
Nickel 0.00000 0.00170 0.00220 0.00410Toluene0.00000 3.84000 4.97000 9.27000
Xylene 0.00000 22.14000 28.66000 53.41000
Vert. Restricted (lb/hr)
New Change hr/yr=lb/yr lb/hr
Modeling
>100 <50 50-100 >100 Required
8.10736 6.93630 10.08916 13.96268
0.04127 0.03531 0.05136 0.07108
0.14380 0.10540 0.12940 0.19650
0.00540 0.00400 0.00450 0.00740
116.80000 85.97000 97.26000 159.78000
0.06630 0.05670 0.08250 0.11420
0.00090 0.00070 0.00080 0.00120
47.40781 34.89497 39.47714 64.85530
74.90192 55.13227 62.37186 102.46806
14.10000 10.38000 11.74000 19.29000
0.00900 0.00660 0.00810 0.01230
20.27000 14.92000 16.88000 27.73000
116.80000 85.97000 97.26000 159.78000
Vert. Unrestricted (lb/hr)

FedEx 2761 6792 8581

June 20, 2024

Mr. Harold Burge, Manager Major NSR
Utah Division of Air Quality (UDAQ)
Utah Department of Environmental Quality
195 North 1950 West
Salt Lake City, Utah 84116

Re: Kinder Morgan Altamont LLC – Altamont West Compressor Station
Approval Order DAQE-AN102100007-16 &
Title V Operating Permit # 1300040005
R307-401-12 Notification for Replacement of Compressor Engine

Dear Mr. Burge:

Kinder Morgan Altamont LLC (Kinder Morgan) operates the Altamont West Compressor Station, which is
currently permitted to operate under Approval Order DAQE-AN102100007-16 (dated December 28, 2016)
and Title V Operating Permit #1300040005 (dated November 30, 2022). Kinder Morgan is proposing to
replace one existing compressor engine identified as CE-2 at the station with a like-kind unit, which will
have additional emission controls. The replacement four-stroke rich-burn (4SRB) engine will have a
maximum site and nameplate rating of 1,030 bhp, which is consistent with the rating of the existing
engine. In addition, the engine will be configured with non-selective catalytic reduction catalyst (NSCR)
and an air-fuel-ratio controller (AFRC). Kinder Morgan plans to operate the existing CE-2 engine until the
replacement unit is installed. At no time will the replacement engine and the engine it replaces both
operate simultaneously. The compressor will not be replaced as part of the project.

This replacement will result in a significant reduction in NOx emissions and will not increase the potential
to emit (PTE) of any air pollutant nor cause emissions of any new air pollutant. Utah Rule R307-401-12
provides an exemption from the requirement to submit a Notice of Intent (NOI) as follows:

R307-401-12. Reduction in Air Contaminants.

(1) Applicability. The owner or operator of a stationary source of air contaminants that reduces or
eliminates air contaminants is exempt from the requirement to submit a notice of intent and obtain
an approval order prior to construction if:

(a) the project does not increase the potential to emit of any air contaminant or cause
emissions of any new air contaminant, and

(b) the director is notified of the change and the reduction of air contaminants is made
enforceable through an approval order in accordance with (2) below.

(2) Notification. The owner or operator shall submit a written description of the project to the
director no later than 60 days after the changes are made. The director will update the source's
approval order or issue a new approval order to include the project and to make the emission
reductions enforceable. Public review under R307-401-7 is not required for the update to the
approval order.

This project meets the Reduction in Air Contaminants exemption because:

(a) The project does not increase the PTE of any air contaminant or cause emissions of any new air
contaminant, and
(b) With this letter, notification of the change is being provided in accordance with paragraph (b).
The project is expected to commence in June 2024.

The project triggers applicability to 40 CFR 60 Subpart JJJJ for “new” (as defined in the rule) non-
emergency 4SRB engines ≥500 hp. The replacement engine will be subject to emissions limits for nitrogen
oxides (NOx) (1.0 g/HP-hr), carbon monoxide (CO) (2.0 g/HP-hr), and volatile organic compounds (VOC)
(0.7 g/HP-hr) from Table 1 in 40 CFR 60.4233(c) for engines manufactured after January 1, 2011. The
replacement engine will be considered a “non-certified” engine for purposes of this rule. Per 40 CFR
60.4243(a)(2)(iii), Kinder Morgan will be required to complete performance testing initially (within 180
days of initial startup) and every 8,760 hours or 3 years thereafter, whichever comes first. 60.4243(a)(2)(iii)
also requires Kinder Morgan to keep a maintenance plan and records of conducted maintenance and will
be required to, to the extent practicable, maintain and operate the engine in a manner consistent with
good air pollution control practice for minimizing emissions. Per 40 CFR 60.4243(g), for each engine
configured with an AFRC, the controller must be maintained and operated appropriately in order to
ensure proper operation of the engine and control device to minimize emissions at all times.

The project does not include any modifications or changes to the compressor. Therefore, the project does
not trigger applicability to 40 CFR 60 Subpart OOOOb at 60.5385b (reciprocating compressor
requirements) for CE-2, nor does it trigger requirements of 60.5397b for fugitive emissions.

For purposes of 40 CFR 63 Subpart ZZZZ, per 40 CFR 63.6590(c)(1), a “new” (as defined in the rule)
stationary reciprocating internal combustion engine (RICE) located at an area source of HAP is required to
meet the requirements of 40 CFR 60 Subpart JJJJ for a spark ignition engine. The replacement engine
meets these criteria; no further requirements under 40 CFR 63 Subpart ZZZZ will apply for this engine.

The project also triggers applicability to Utah Rule R307-501 which 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. The facility meets these criteria, and the project is
subject to R307-501. The project is not subject to other requirements within R307-502 through R307-511
generally because the replacement equipment will be regulated by an Approval Order, is not located at a
well site, and the compressor is not impacted by the project.

Under the provisions of R307-401-12, a BACT evaluation is not formally required. Note that a previous
BACT determination that Kinder Morgan performed for installation of a similar engine at another Utah
facility concluded that new compressor engines equipped with NSCR catalyst for NOx, CO, and VOC
control would be lower than the generally-accepted BACT. No add-on controls are expected to be feasible
for sulfide dioxide (SO2) and particulate matter (PM10 and PM2.5) from internal combustion engines firing
pipeline quality natural gas.

The estimated change in potential emissions from the engine is summarized in the table below. The “Pre-
Project PTE” includes total potential emissions from the existing engine that is being replaced (the engine
within CE-2, excluding compressor) and “Post-Project PTE” includes total potential emissions from the
replacement engine (excluding compressor). Detailed emission calculations are provided in Attachment A,
and the engine specifications are attached as Attachment B to this notification.

Table 1. Estimated Change in Potential Emissions (tpy)
Contaminant Pre-Project PTE Post-Project PTE Difference
NOx 169.08 9.95 -159.13
CO 6.46 6.46 0.00
VOC 1.08 0.99 -0.09
SO2 0.02 0.02 0.00
PM / PM10 / PM2.5 0.71 0.71 0.00
Total 177.36 36.27 -159.22

Kinder Morgan requests concurrence from the Utah Division of Air Quality (UDAQ) that this project meets
the R307-401-12 Reduction in Air Contaminants exemption.

Furthermore, as a follow-up action to make this project enforceable, Kinder Morgan requests UDAQ issues
an update to the facility’s Approval Order. Kinder Morgan is requesting addition of the following permit
changes within the AO:

1. Addition of permit condition limiting the emissions of NOx, CO, and VOC from each engine
associated with CE-2 to 1.00 g/bhp-hr, 0.65 g/bhp-hr, and 0.10 g/bhp-hr, respectively.

Kinder Morgan also requests that the facility’s Title V Operating Permit (#1300040005 (dated November
30, 2022) incorporate these changes.

Please do not hesitate to contact me at 303.914.7605 or [e-mail] if you have
questions as you process this request.

Sincerely,

Erin Dunman
EHS Engineer

Enclosures: Attachment A: Emission Calculations
Attachment B: Engine Specifications

Attachment A:
Emissions Calculations

Attachment A - Detailed Air Emissions Calculations
Kinder Morgan Altamont LLC
West Compressor Station
R307-401-12 Notification
Parameter Value Unit of Measure
Emission Source ID:CE-2 -
Make:Waukesha -
Model:L7042GSI S4 -
Engine Type:4SRB -
Engine Horsepower:1,030 bhp
BSFC:8,100 Btu/bhp-hr
Fuel Flowrate: 8.34 MMBtu/hr
Fuel Heating Value:1,120 Btu/scf
Annual Operating Hours:8,760 hours
Pollutant Emission
Factor
Emission
Factor
Units
Source
Emission
Rate
(lb/hr)
Emission
Rate
(tpy)
NOX 1.00 g/bhp-hr Proposed Permit Limit 2.27 9.95
CO 0.65 g/bhp-hr Proposed Permit Limit 1.48 6.46
VOC 1.00E-01 g/bhp-hr Proposed Permit Limit 0.23 0.99
SO2 5.88E-04 lb/MMBtu AP-42, Table 3.2-3 4.91E-03 0.02
PM Total 1.94E-02 lb/MMBtu AP-42, Table 3.2-3 0.16 0.71
PM10 1.94E-02 lb/MMBtu AP-42, Table 3.2-3 0.16 0.71
PM2.5 1.94E-02 lb/MMBtu AP-42, Table 3.2-3 0.16 0.71
1,1,2,2-Tetrachloroethane 2.53E-05 lb/MMBtu AP-42, Table 3.2-3 2.11E-04 9.25E-04
1,1,2-Trichloroethane 1.53E-05 lb/MMBtu AP-42, Table 3.2-3 1.28E-04 5.59E-04
1,3-Butadiene 6.63E-04 lb/MMBtu AP-42, Table 3.2-3 0.01 0.02
1,3-Dichloropropene 1.27E-05 lb/MMBtu AP-42, Table 3.2-3 1.06E-04 4.64E-04
Acetaldehyde 2.79E-03 lb/MMBtu AP-42, Table 3.2-3 0.02 0.10
Acrolein 2.63E-03 lb/MMBtu AP-42, Table 3.2-3 0.02 0.10
Benzene 1.58E-03 lb/MMBtu AP-42, Table 3.2-3 0.01 0.06
Carbon Tetrachloride 1.77E-05 lb/MMBtu AP-42, Table 3.2-3 1.48E-04 6.47E-04
Chlorobenzene 1.29E-05 lb/MMBtu AP-42, Table 3.2-3 1.08E-04 4.71E-04
Chloroform 1.37E-05 lb/MMBtu AP-42, Table 3.2-3 1.14E-04 5.01E-04
Ethylbenzene 2.48E-05 lb/MMBtu AP-42, Table 3.2-3 2.07E-04 9.06E-04
Ethylene Dibromide 2.13E-05 lb/MMBtu AP-42, Table 3.2-3 1.78E-04 7.78E-04
Formaldehyde 2.05E-02 lb/MMBtu AP-42, Table 3.2-3 0.17 0.75
Methanol 3.06E-03 lb/MMBtu AP-42, Table 3.2-3 0.03 0.11
Methylene Chloride 4.12E-05 lb/MMBtu AP-42, Table 3.2-3 3.44E-04 1.51E-03
Naphthalene 9.71E-05 lb/MMBtu AP-42, Table 3.2-3 8.10E-04 3.55E-03
PAH 1.41E-04 lb/MMBtu AP-42, Table 3.2-3 1.18E-03 0.01
Styrene 1.19E-05 lb/MMBtu AP-42, Table 3.2-3 9.93E-05 4.35E-04
Toluene 5.58E-04 lb/MMBtu AP-42, Table 3.2-3 4.66E-03 0.02
Vinyl Chloride 7.18E-06 lb/MMBtu AP-42, Table 3.2-3 5.99E-05 2.62E-04
Xylene 1.95E-04 lb/MMBtu AP-42, Table 3.2-3 1.63E-03 0.01
Total HAP 3.24E-02 lb/MMBtu AP-42, Table 3.2-3 0.27 1.18
CO2 116.98 lb/MMBtu 40 CFR 98, Subpart C, Table C-1 975.94 4,274.62
CH4 2.20E-03 lb/MMBtu 40 CFR 98, Subpart C, Table C-2 0.02 0.08
N2O 2.20E-04 lb/MMBtu 40 CFR 98, Subpart C, Table C-2 1.84E-03 0.01
CO2e --40 CFR 98, Subpart A, Table A-1 976.95 4,279.03
Emission Source Information
Emissions Data
Compressor Engine (CE-2) Emissions Calculations - Replacement Unit
West Compressor Station Title V Renewal Application Page 1 of 1
Attachment A - Detailed Air Emissions Calculations
Kinder Morgan Altamont LLC
West Compressor Station
R307-401-12 Notification
Parameter Value Unit of Measure
Emission Source ID:CE-2 -
Make:Waukesha -
Model:L7042GSI -
Engine Type:4SRB -
Engine Horsepower:1,030 bhp
BSFC:8,100 Btu/bhp-hr
Fuel Flowrate: 8.34 MMBtu/hr
Fuel Heating Value:1,120 Btu/scf
Annual Operating Hours:8,760 hours
Pollutant Emission
Factor
Emission
Factor
Units
Source
Emission
Rate
(lb/hr)
Emission
Rate
(tpy)
NOX 17.00 g/bhp-hr November 2008 Source Testing 38.60 169.08
CO 0.65 g/bhp-hr November 2008 Source Testing 1.48 6.46
VOC 2.96E-02 lb/MMBtu AP-42, Table 3.2-3 0.25 1.08
SO2 5.88E-04 lb/MMBtu AP-42, Table 3.2-3 4.91E-03 0.02
PM Total 1.94E-02 lb/MMBtu AP-42, Table 3.2-3 0.16 0.71
PM10 1.94E-02 lb/MMBtu AP-42, Table 3.2-3 0.16 0.71
PM2.5 1.94E-02 lb/MMBtu AP-42, Table 3.2-3 0.16 0.71
1,1,2,2-Tetrachloroethane 2.53E-05 lb/MMBtu AP-42, Table 3.2-3 2.11E-04 9.25E-04
1,1,2-Trichloroethane 1.53E-05 lb/MMBtu AP-42, Table 3.2-3 1.28E-04 5.59E-04
1,3-Butadiene 6.63E-04 lb/MMBtu AP-42, Table 3.2-3 0.01 0.02
1,3-Dichloropropene 1.27E-05 lb/MMBtu AP-42, Table 3.2-3 1.06E-04 4.64E-04
Acetaldehyde 2.79E-03 lb/MMBtu AP-42, Table 3.2-3 0.02 0.10
Acrolein 2.63E-03 lb/MMBtu AP-42, Table 3.2-3 0.02 0.10
Benzene 1.58E-03 lb/MMBtu AP-42, Table 3.2-3 0.01 0.06
Carbon Tetrachloride 1.77E-05 lb/MMBtu AP-42, Table 3.2-3 1.48E-04 6.47E-04
Chlorobenzene 1.29E-05 lb/MMBtu AP-42, Table 3.2-3 1.08E-04 4.71E-04
Chloroform 1.37E-05 lb/MMBtu AP-42, Table 3.2-3 1.14E-04 5.01E-04
Ethylbenzene 2.48E-05 lb/MMBtu AP-42, Table 3.2-3 2.07E-04 9.06E-04
Ethylene Dibromide 2.13E-05 lb/MMBtu AP-42, Table 3.2-3 1.78E-04 7.78E-04
Formaldehyde 2.05E-02 lb/MMBtu AP-42, Table 3.2-3 0.17 0.75
Methanol 3.06E-03 lb/MMBtu AP-42, Table 3.2-3 0.03 0.11
Methylene Chloride 4.12E-05 lb/MMBtu AP-42, Table 3.2-3 3.44E-04 1.51E-03
Naphthalene 9.71E-05 lb/MMBtu AP-42, Table 3.2-3 8.10E-04 3.55E-03
PAH 1.41E-04 lb/MMBtu AP-42, Table 3.2-3 1.18E-03 0.01
Styrene 1.19E-05 lb/MMBtu AP-42, Table 3.2-3 9.93E-05 4.35E-04
Toluene 5.58E-04 lb/MMBtu AP-42, Table 3.2-3 4.66E-03 0.02
Vinyl Chloride 7.18E-06 lb/MMBtu AP-42, Table 3.2-3 5.99E-05 2.62E-04
Xylene 1.95E-04 lb/MMBtu AP-42, Table 3.2-3 1.63E-03 0.01
Total HAP 3.24E-02 lb/MMBtu AP-42, Table 3.2-3 0.27 1.18
CO2 116.98 lb/MMBtu 40 CFR 98, Subpart C, Table C-1 975.94 4,274.62
CH4 2.20E-03 lb/MMBtu 40 CFR 98, Subpart C, Table C-2 0.02 0.08
N2O 2.20E-04 lb/MMBtu 40 CFR 98, Subpart C, Table C-2 1.84E-03 0.01
CO2e --40 CFR 98, Subpart A, Table A-1 976.95 4,279.03
Compressor Engine (CE-2) Emissions Calculations - Replaced
Emission Source Information
Emissions Data

Attachment B:
Engine Specifications

ReUp Altamont - Altamont Gas Plant VHP - L7042GSI S4
Waukesha Gas Engine David Blankenheim 262-225-0031 [e-mail] Gas Compression
ENGINE SPEED (rpm):900 NOx SELECTION (g/bhp-hr):
DISPLACEMENT (in3):7040 COOLING SYSTEM:JW, IC + OC
COMPRESSION RATIO:8:1 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):10
ENGINE SOUND LEVEL (dBA)101 MAX. AIR INLET RESTRICTION (in. H2O):15
IGNITION TIMING:ESM2 Controlled EXHAUST SOUND LEVEL (dBA)104
SITE CONDITIONS:
FUEL:Altamont 3-1-22 ALTITUDE (ft):6430
FUEL PRESSURE RANGE (psig):30 - 60 MAXIMUM INLET AIR TEMPERATURE (°F):90
FUEL HHV (BTU/ft3):1,137.4 FUEL WKI:74.8
FUEL LHV (BTU/ft3):1,028.2
SITE SPECIFIC TECHNICAL DATA 110%
OVERLOAD
UNITS SITE DATA
(See note 18)93%90%75%
CONTINUOUS ENGINE POWER BHP 1133 1110 1030 832 833
OVERLOAD % 2/24 hr Note 18 10 10 --
MECHANICAL EFFICIENCY (LHV)%32.6 32.5 32.4 31.6 31.6
CONTINUOUS POWER AT FLYWHEEL BHP 1133 1110 1030 832 833
based on no auxiliary engine driven equipment
RPM
FUEL CONSUMPTION (LHV)BTU/BHP-hr 7816 7843 7856 8060 8060
FUEL CONSUMPTION (HHV)BTU/BHP-hr 8646 8676 8691 8916 8915
FUEL FLOW based on fuel analysis LHV SCFM 144 141 131 109 109
JACKET WATER (JW)BTU/hr x 1000 2713 2704 2501 2149 2150
LUBE OIL (OC)BTU/hr x 1000 377 377 361 330 330
INTERCOOLER (IC)BTU/hr x 1000 150 163 123 74 74
EXHAUST BTU/hr x 1000 2333 2264 2091 1657 1658
RADIATION BTU/hr x 1000 571 539 552 511 511
NOx (NO + NO2)g/bhp-hr 0.15 0.15 0.15 0.15 0.15
CO g/bhp-hr 0.30 0.30 0.30 0.30 0.30
THC g/bhp-hr 1.50 1.50 1.49 1.49 1.49
NMHC g/bhp-hr 0.201 0.203 0.201 0.202 0.202
NM,NEHC (VOC)g/bhp-hr 0.029 0.030 0.030 0.030 0.030
CO2 g/bhp-hr 502 504 504 517 517
CO2e (Methane GWP: 25)g/bhp-hr 529 531 532 545 545
CH2O g/bhp-hr 0.001 0.001 0.001 0.001 0.001
CH4 g/bhp-hr 1.08 1.09 1.09 1.09 1.09
INDUCTION AIR FLOW SCFM 1622 1594 1482 1229 1229
EXHAUST GAS MASS FLOW lb/hr 7541 7411 6891 5713 5716
EXHAUST GAS FLOW at exhaust temp, 14.5 psia ACFM 5171 5066 4668 3760 3762
EXHAUST TEMPERATURE °F 1083 1078 1064 1021 1021
TOTAL JACKET WATER CIRCUIT (JW)BTU/hr x 1000 3076 3067
TOTAL AUXILIARY WATER CIRCUIT (IC + OC)BTU/hr x 1000 598 613
JACKET WATER PUMP MIN. DESIGN FLOW GPM 343
JACKET WATER PUMP MAX. EXTERNAL RESTRICTION psig 10
AUX WATER PUMP MIN. DESIGN FLOW GPM 60
AUX WATER PUMP MAX. EXTERNAL RESTRICTION psig 24
AIR INTAKE / EXHAUST GAS
HEAT EXCHANGER SIZING12
0.15 NOx 0.30 CO
MAX RATING
AT 100 °F
AIR TEMP
700 - 1200AVAILABLE TURNDOWN SPEED RANGE
SITE RATING AT MAXIMUM INLET AIR
TEMPERATURE OF 90 °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 4.2 INNIO Waukesha Gas Engines, Inc.
3/4/2022 10:12 AM Page 1 of 3
ReUp Altamont - Altamont Gas Plant VHP - L7042GSI S4
Waukesha Gas Engine David Blankenheim 262-225-0031 [e-mail] Gas Compression
FUEL COMPOSITION
HYDROCARBONS:Mole or Volume %FUEL:Altamont 3-1-22
Methane CH4 83.495 FUEL PRESSURE RANGE (psig):30 - 60
Ethane C2H6 13.13 FUEL WKI:74.8
Propane C3H8 1.9226
Iso-Butane I-C4H10 0.106 FUEL SLHV (BTU/ft3):1010.31
Normal Butane N-C4H10 0.1655 FUEL SLHV (MJ/Nm3):39.73
Iso-Pentane I-C5H12 0.0113
Normal Pentane N-C5H12 0.0108 FUEL LHV (BTU/ft3):1028.20
Hexane C6H14 0 FUEL LHV (MJ/Nm3):40.43
Heptane C7H16 0
Ethene C2H4 0 FUEL HHV (BTU/ft3):1137.39
Propene C3H6 0 FUEL HHV (MJ/Nm3):44.73
SUM HYDROCARBONS 98.84 FUEL DENSITY (SG):0.65
NON-HYDROCARBONS:
Nitrogen N2 0.3267
Oxygen O2 0
Helium He 0
Carbon Dioxide CO2 0.8317
Carbon Monoxide CO 0
Hydrogen H2 0
Water Vapor H2O 0
TOTAL FUEL 99.999
FUEL CONTAMINANTS
Total Sulfur Compounds % volume Total Sulfur Compounds 0 µg/BTU
Total Halogen as Chloride % volume Total Halogen as Chloride 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 4.2 INNIO Waukesha Gas Engines, Inc.
3/4/2022 10:12 AM Page 2 of 3
ReUp Altamont - Altamont Gas Plant VHP - L7042GSI S4
Waukesha Gas Engine David Blankenheim 262-225-0031 [e-mail] Gas Compression
NOTES
SPECIAL REQUIREMENTS
Requires option code 1008B/1008SB for 0.15 g/bhp-hr NOx 0.30 g/bhp-hr CO 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. It is permissible to operate the engine at the indicated overload power, for two hours in every
24 hour period.
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 138 PSI BMEP and 900 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 4.2 INNIO Waukesha Gas Engines, Inc.
3/4/2022 10:12 AM Page 3 of 3