DAQ-2025-001469

DAQE-AN106270013-25

{{$d1 }}

Cecilia Diaz
Northwest Pipeline LLC
PO Box 58900
Salt Lake City, UT 84158-0900
[e-mail]

Dear Ms. Diaz:

Re: Approval Order: Administrative Amendment to Approval Order DAQE-AN0106270010-10 to
Update Equipment Designation, Classification, and Conditions
Project Number: N106270013

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on
November 18, 2024. Northwest Pipeline 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: Southeastern Utah District Health Department

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

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Tim Davis
Interim Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

March 17, 2025

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

{{#s=Sig_es_:signer1:signature}}
{{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}}
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APPROVAL ORDER
DAQE-AN106270013-25
Administrative Amendment to Approval Order
DAQE-AN0106270010-10 to Update Equipment Designation,
Classification, and Conditions

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

Issued to
Northwest Pipeline LLC - Moab Compressor Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

March 17, 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 ..................................................................................... 7
PERMIT HISTORY ..................................................................................................................... 8
ACRONYMS ................................................................................................................................. 9

DAQE-AN106270013-25
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Northwest Pipeline LLC Northwest Pipeline LLC - Moab Compressor Station

Mailing Address Physical Address
PO Box 58900
Salt Lake City, UT 84158-0900
23 Miles south of Moab on Highway 191 La Sal
Route
Moab, UT 84532

Source Contact UTM Coordinates
Name: Cecilia Diaz 637,500 m Easting
Phone: [phone],243,000 m Northing
Email: [e-mail] Datum NAD27
UTM Zone 12
SIC code 4922 (Natural Gas Transmission)

SOURCE INFORMATION
General Description
Northwest Pipeline LLC (Northwest Pipeline), Moab Compressor Station, is a natural gas pipeline
compression facility in east-central Utah. The Moab Compressor Station consists of four (4) reciprocating
engines, one (1) natural gas-fired turbine, and associated equipment that are operated to meet the demand
of the natural gas pipeline system.

NSR Classification
Administrative Amendment

Source Classification
Located in Attainment Area
San Juan County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), GG: Standards of Performance for Stationary Gas Turbines
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines
Title V (Part 70) Major Source
DAQE-AN106270013-25
Page 4

Project Description
Northwest Pipeline has requested an administrative amendment to update equipment designation,
emergency generator conditions, and update the HAP source classification. The equipment designation in
the AO needs to be updated to match the issued Title V operating permit. The equipment is not being
modified or altered. The emergency generator conditions are being updated to clarify the hours of
operations for the emergency backup generator’s engine. The AO was issued with an hour of operation
condition, which was not clarified as operational hours or testing and maintenance hours. The emergency
generator engine conditions will be updated to reflect equipment subject to 40 CFR 63.6640(f)(2) 100
hours of operation annually for testing and maintenance with no limits for emergencies. The HAP
emissions that are listed in the existing AO are only accounting for permitted equipment but not the
grandfathered engines (Reciprocating IC Engine #1-4). The added grandfathered HAP emissions are not
considered new emissions, since they are accounted for in the Title V and emissions inventory. The
addition of the grandfathered HAP emissions to the AO will clarify the Title V Major HAP source
classification discrepancy.

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 * 68074.00
Carbon Monoxide 0 177.05
Nitrogen Oxides 0 1066.51
Particulate Matter - PM10 0 4.48
Particulate Matter - PM2.5 0 4.48
Sulfur Oxides 0 1.96
Volatile Organic Compounds 0 49.08

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
1,3-Butadiene (CAS #106990) ** 640
2,2,4-Trimethylpentane (CAS #540841) ** 660
Acetaldehyde (CAS #75070) ** 6020
Acrolein (CAS #107028) ** 6020
Benzene (Including Benzene From Gasoline) (CAS #71432) ** 1520
Ethyl Benzene (CAS #100414) ** 100
Formaldehyde (CAS #50000) ** 42980
Generic HAPs (CAS #GHAPS) ** 520
Hexane (CAS #110543) ** 500
Methanol (CAS #67561) ** 1920
Polycyclic aromatic hydrocarbons (CAS #65996932) ** 240
Toluene (CAS #108883) ** 780
Xylenes (Isomers And Mixture) (CAS #1330207) ** 220
Change (TPY) Total (TPY)
Total HAPs ** 31.06

Note: Change in emissions indicates the difference between previous AO and proposed modification.
*CO2 emissions were never considered and are now being added.
**HAP emissions are coming from grandfathered equipment and are now being added.
DAQE-AN106270013-25
Page 5

SECTION I: GENERAL PROVISIONS

I.1 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. [R307-415-6a] I.2 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]
I.3 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.4 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.5 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.6 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.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 Moab Compressor Station Source Wide II.A.2 Reciprocating IC Engine #1 (Unit #P001) Installed 1956 - Grandfathered Fired on pipeline-quality natural gas only
II.A.3 Reciprocating IC Engine #2 (Unit #P002) Installed 1956 - Grandfathered Fired on pipeline-quality natural gas only
DAQE-AN106270013-25
Page 6

II.A.4 Reciprocating IC Engine #3 (Unit #P003) Installed 1956 - Grandfathered Fired on pipeline-quality natural gas only II.A.5 Reciprocating IC Engine #4 (Unit #P004)
Installed 1956 - Grandfathered Fired on pipeline-quality natural gas only
II.A.6 Turbine (Unit #P005) 4,354 hp Compressor Turbine (4680 hp Nameplate) Fired on pipeline-quality natural gas only Installed 2003 II.A.7 Boiler #1 (Unit #B001) 5.23 MMBtu/hr boiler for comfort heating
Fired on pipeline-quality natural gas only Installed 1992

II.A.8 Boiler #2 (Unit #B002) 2.5 MMBtu/hr boiler (installed 2001) Fired on pipeline quality natural gas only Installed 1992 II.A.9 Backup Generator #1 (Unit #G001)
292 hp emergency backup generator
Fired on pipeline-quality natural gas only Installed 1992

II.A.10 Backup Generator #2 (Unit #G002) 565 hp emergency backup generator Fired on pipeline-quality natural gas only Installed 1992 II.A.11 Salt Bath Heater (Unit SB001)
0.25 MMBtu/hr heater (installed 2001)
Fired on pipeline-quality natural gas only
II.A.12 Miscellaneous Emission Points (Unit #F001) Fugitive VOC emissions from miscellaneous points, including the blowdown vent stack

DAQE-AN106270013-25
Page 7

SECTION II: SPECIAL PROVISIONS
II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Moab Compressor Station
II.B.1.a Visible emissions from the following emission points shall not exceed the following values:

Turbine Unit #P005 - 10%

Backup Generator Unit G001 - 10%

Backup Generator Unit G002 - 10%

Boiler Unit #B001 - 10%

Salt Bath Heater Unit SB001 - 10%

Fugitive Emissions - 10%

All other points - 20%

Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Appendix A, Method 9.

[R307-201]

II.B.1.b The owner/operator shall use only pipeline-quality natural gas as fuel. If any other fuel is to be used, an AO shall be required. [R307-401]
II.B.2 Requirements on Turbine Unit #P005
II.B.2.a Emissions of NOx from the Turbine Unit #P005 shall be no greater than 6.28 lbs/hour. [R307-401]
II.B.2.b Emissions of CO from the Turbine Unit #P005 shall be no greater than 4.55 lbs/hour.
[R307-401]

II.B.2.c Sulfur content of the fuel combusted shall be no greater than 0.8 percent by weight. [40 CFR 60 Subpart GG]
II.B.3 Emergency Backup Generators
II.B.3.a The owner/operator shall not operate each emergency engine on site for more than 100 hours per rolling 12-month period during non-emergency situations. There is no time limit on the use of the engines during emergencies. [40 CFR 63 Subpart ZZZZ]
II.B.3.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the 20th day of each month using data from the previous 12 months. Records
documenting the operation of each emergency engine shall be kept in a log and shall include the following:

A. The date the emergency engine was used
B. The duration of operation in hours
C. The reason for the emergency engine usage.

[40 CFR 63 Subpart ZZZZ]
DAQE-AN106270013-25
Page 8

II.B.3.a.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour meter on each emergency engine. [40 CFR 63 Subpart ZZZZ]
PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN0106270010-10 dated August 3, 2010 Is Derived From NOI dated November 18, 2024 Incorporates Additional Information dated February 12, 2025

DAQE-AN106270013-25
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

10627
Title V Operating Permit
PERMIT NUMBER: 3700029005
DATE OF PERMIT: September 25, 2020
Date of Last Revision: September 25, 2020
This Operating Permit is issued to, and applies to the following:
Name of Permittee:
Northwest Pipeline LLC
295 Chipeta Way
Salt Lake City, UT 84108
Permitted Location:
Moab Compressor Station
23 Miles south of Moab on Highway 191 La Sal
Route
Moab, UT 84532
UTM coordinates: 637,500 m Easting, 4,243,000 m Northing
SIC code: 4922 (Natural Gas Transmission)
By: Prepared By:
Scott Hanks
_________________________________ [e-mail]
Bryce C. Bird, Director 385-306-6504
Governor
Lieutenant Governor
Executive Director
Director
Project OPP0106270009 Page 2 Title V Operating Permit #3700029005
The following dates or timeframes are referenced in
Section I: General Provisions of this permit.
Annual Certification Due: June 1 and on that date of every calendar year that this permit is
in force.
Renewal application due: March 25, 2025
Permit expiration date: September 25, 2025
written notification within 14 days.
Northwest Pipeline's Moab Compressor Station is a natural gas pipeline compression facility in east-central
Utah. Four reciprocating engines, one natural gas-fired turbine, and associated equipment are operated to meet
the demand of the pipeline system. Operations are controlled from Northwest Pipeline's headquarters in Salt
Lake City. There is no air pollution control equipment at this source. All equipment is fired on natural gas
from the pipeline. This source is subject to 40 CFR 60, Subpart GG, Standards of Performance for Stationary
Gas Turbines; 40 CFR 63, Subpart DDDDD, National Emission Standards for Hazardous Air Pollutants for
Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters, and 40 CFR 63, Subpart
ZZZZ, National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal
Combustion Engines. This source is a major source of nitrogen oxides, carbon monoxide, and HAPs
(Formaldehyde).
Project OPP0106270009 Page 3 Title V Operating Permit #3700029005
Permit/Activity Date Issued Recorded Changes
Title V renewal application
(Project #OPP0106270009)
09/25/2020 -Renew Title V Permit.
-Update applicable requirements for R307-501-4.
-Update conditions for 40 CFR 60 Subpart GG. The
permittee has accepted an F-value of zero in accordance
with 40 CFR 60.332(a)(3).
-Remove condition regarding one-time energy assessment
for Emission Units B001, B002, and SB001. Requirement
was met in October of 2015.
-Clarify applicable requirements for 40 CFR 63 Subpart
DDDDD for Emission Units B001, B002, and SB001.
-Update and clarify requirements for 40 CFR 63 Subpart
ZZZZ for Emission Unit G001.
Title V renewal application
(Project #OPP0106270008)
09/28/2015 Update applicable requirements.
Title V renewal application
(Project #OPP0106270007)
12/16/2010 Added source-wide conditions for startup, shutdown, and
malfunction; for motor vehicle CFC; for recycling and
emission reduction for CFC, added regulatory reference
regarding 0 wt. % fuel-bound nitrogen; modified sulfur
content monitoring/recordkeeping; modified to reflect
replacement engine; added site as major for HAPs; added
40 CFR 63, Subpart ZZZZ.
Title V administrative
amendment by DAQ
(Project #OPP0106270005)
11/10/2003 To replace the existing turbine with a retrofitted unit of
higher capacity; to reduce the NOx and CO limits on the
turbine; to allow Method 19 for CO testing; and to remove
the 5000 hours/yr limit on the turbine as authorized in
DAQE-AN0627004-03 (5/27/03).
Title V renewal application
(Project #OPP0106270004)
12/04/2002
Title V administrative
amendment by DAQ
(Project #OPP0106270003)
02/06/2002 To administratively incorporate the new requirements for
the salt bath heater and replacement boiler B002 as issued
in DAQE-825-01, 10/16/01, and to incorporate minor
changes to H2S monitoring for turbine per EPA approval
letter.
Title V reopening for cause
by DAQ (Project
#OPP0106270002)
07/17/1998 To modify Provision I.U.1 of the permit to reference the
inventory rule directly. Also, in response to EPA
comments, monitoring language for natural gas
combustion opacity was revised to reflect current language
(fuel use monitoring), and PM justification was added.
Project OPP0106270009 Page 4 Title V Operating Permit #3700029005

Title V initial application
(Project #OPP0106270001)
10/22/1997

Project OPP0106270009 Page 5 Title V Operating Permit #3700029005

ENFORCEABLE DATES AND TIMELINES ........................................................................................... 2
ABSTRACT ................................................................................................................................................... 2
OPERATING PERMIT HISTORY ............................................................................................................. 3
SECTION I: GENERAL PROVISIONS ..................................................................................................... 6
Federal Enforcement. .............................................................................................................................................. 6
Permitted Activity(ies). ........................................................................................................................................... 6
Duty to Comply. ..................................................................................................................................................... 6
Permit Expiration and Renewal. ............................................................................................................................. 6
Application Shield. ................................................................................................................................................. 7
Severability. ............................................................................................................................................................ 7
Permit Fee. .............................................................................................................................................................. 7
No Property Rights. ................................................................................................................................................ 7
Revision Exception. ................................................................................................................................................ 7
Inspection and Entry. .............................................................................................................................................. 7
Certification. ........................................................................................................................................................... 8
Compliance Certification. ....................................................................................................................................... 8
Permit Shield. .......................................................................................................................................................... 9
Emergency Provision. ............................................................................................................................................. 9
Operational Flexibility. ......................................................................................................................................... 10
Off-permit Changes. ............................................................................................................................................. 10
Administrative Permit Amendments. .................................................................................................................... 10
Permit Modifications. ........................................................................................................................................... 10
Records and Reporting. ......................................................................................................................................... 10
Reopening for Cause. ............................................................................................................................................ 12
Inventory Requirements. ....................................................................................................................................... 12
Title IV and Other, More Stringent Requirements. ............................................................................................... 13
SECTION II: SPECIAL PROVISIONS .................................................................................................... 14
Emission Unit(s) Permitted to Discharge Air Contaminants. ................................................................... 14
Requirements and Limitations. ............................................................................................................................. 15
Conditions on permitted source (Source-wide). .................................................................................................... 15
Conditions on Turbine. ......................................................................................................................................... 17
Conditions for Boiler #1. ...................................................................................................................................... 21
Conditions for Boiler #2. ...................................................................................................................................... 24
Condition on Backup Generator #1....................................................................................................................... 27
Condition on Backup Generator #2....................................................................................................................... 31
Condition for Salt Bath Heater. ............................................................................................................................. 31
Emissions Trading ..................................................................................................................................... 35
Alternative Operating Scenarios ............................................................................................................... 35
SECTION III: PERMIT SHIELD ............................................................................................................. 36
SECTION IV: ACID RAIN PROVISIONS .............................................................................................. 37
This source is not subject to Title IV. This section is not applicable. ................................................................... 37
REVIEWER COMMENTS ........................................................................................................................ 38

Project OPP0106270009 Page 6 Title V Operating Permit #3700029005

Issued under authority of Utah Code Ann. Section 19-2-104 and 19-2-109.1, and in accordance with
Utah Administrative Code R307-415 Operating Permit Requirements.

All definitions, terms and abbreviations used in this permit conform to those used in Utah Administrative
Code R307-101 and R307-415 (Rules), and 40 Code of Federal Regulations (CFR), except as otherwise
defined in this permit. Unless noted otherwise, references cited in the permit conditions refer to the Rules.

Where a permit condition in Section I, General Provisions, partially recites or summarizes an applicable
rule, the full text of the applicable portion of the rule shall govern interpretations of the requirements of the
rule. In the case of a conflict between the Rules and the permit terms and conditions of Section II, Special
Provisions, the permit terms and conditions of Section II shall govern except as noted in Provision I.M,
Permit Shield.

I.A Federal Enforcement.

All terms and conditions in this permit, including those provisions designed to limit the
potential to emit, are enforceable by the EPA and citizens under the Clean Air Act of 1990
(CAA) except those terms and conditions that are specifically designated as "State
Requirements". (R307-415-6b)

I.B Permitted Activity(ies).

Except as provided in R307-415-7b(1), the permittee may not operate except in compliance
with this permit. (See also Provision I.E, Application Shield)

I.C Duty to Comply.

I.C.1 The permittee must comply with all conditions of the operating permit. Any permit
noncompliance constitutes a violation of the Air Conservation Act and is grounds for any of
the following: enforcement action; permit termination; revocation and reissuance;
modification; or denial of a permit renewal application. (R307-415-6a(6)(a))

I.C.2 It shall not be a defense for a permittee in an enforcement action that it would have been
necessary to halt or reduce the permitted activity in order to maintain compliance with the
conditions of this permit. (R307-415-6a(6)(b))

I.C.3 The permittee shall furnish to the Director, within a reasonable time, any information that
the Director may request in writing to determine whether cause exists for modifying,
revoking and reissuing, or terminating this permit or to determine compliance with this
permit. Upon request, the permittee shall also furnish to the Director copies of records
required to be kept by this permit or, for information claimed to be confidential, the
permittee may furnish such records directly to the EPA along with a claim of
confidentiality. (R307-415-6a(6)(e))

I.C.4 This permit may be modified, revoked, reopened, and reissued, or terminated for cause.
The filing of a request by the permittee for a permit modification, revocation and
reissuance, or termination, or of a notification of planned changes or anticipated
noncompliance shall not stay any permit condition, except as provided under R307-415-
7f(1) for minor permit modifications. (R307-415-6a(6)(c))

I.D Permit Expiration and Renewal.

Project OPP0106270009 Page 7 Title V Operating Permit #3700029005

I.D.1 This permit is issued for a fixed term of five years and expires on the date shown under
"Enforceable Dates and Timelines" at the front of this permit. (R307-415-6a(2))

I.D.2 Application for renewal of this permit is due on or before the date shown under
"Enforceable Dates and Timelines" at the front of this permit. An application may be
submitted early for any reason. (R307-415-5a(1)(c))

I.D.3 An application for renewal submitted after the due date listed in I.D.2 above shall be
accepted for processing, but shall not be considered a timely application and shall not
relieve the permittee of any enforcement actions resulting from submitting a late
application. (R307-415-5a(5))

I.D.4 Permit expiration terminates the permittee's right to operate unless a timely and complete
renewal application is submitted consistent with R307-415-7b (see also Provision I.E,
Application Shield) and R307-415-5a(1)(c) (see also Provision I.D.2). (R307-415-7c(2))

I.E Application Shield.

If the permittee submits a timely and complete application for renewal, the permittee's
failure to have an operating permit will not be a violation of R307-415, until the Director
takes final action on the permit renewal application. In such case, the terms and conditions
of this permit shall remain in force until permit renewal or denial. This protection shall
cease to apply if, subsequent to the completeness determination required pursuant to R307-
415-7a(3), and as required by R307-415-5a(2), the applicant fails to submit by the deadline
specified in writing by the Director any additional information identified as being needed to
process the application. (R307-415-7b(2))

I.F Severability.

In the event of a challenge to any portion of this permit, or if any portion of this permit is
held invalid, the remaining permit conditions remain valid and in force. (R307-415-6a(5))

I.G Permit Fee.

I.G.1 The permittee shall pay an annual emission fee to the Director consistent with R307-415-9.
(R307-415-6a(7))

I.G.2 The emission fee shall be due on October 1 of each calendar year or 45 days after the source
receives notice of the amount of the fee, whichever is later. (R307-415-9(4)(a))

I.H No Property Rights.

This permit does not convey any property rights of any sort, or any exclusive privilege.
(R307-415-6a(6)(d))

I.I Revision Exception.

No permit revision shall be required, under any approved economic incentives, marketable
permits, emissions trading and other similar programs or processes for changes that are
provided for in this permit. (R307-415-6a(8))

I.J Inspection and Entry.

Project OPP0106270009 Page 8 Title V Operating Permit #3700029005

I.J.1 Upon presentation of credentials and other documents as may be required by law, the
permittee shall allow the Director or an authorized representative to perform any of the
following:

I.J.1.a Enter upon the permittee's premises where the source is located or emissions related
activity is conducted, or where records are kept under the conditions of this permit.
(R307-415-6c(2)(a))

I.J.1.b Have access to and copy, at reasonable times, any records that must be kept under
the conditions of this permit. (R307-415-6c(2)(b))

I.J.1.c Inspect at reasonable times any facilities, equipment (including monitoring and air
pollution control equipment), practice, or operation regulated or required under this
permit. (R307-415-6c(2)(c))

I.J.1.d Sample or monitor at reasonable times substances or parameters for the purpose of
assuring compliance with this permit or applicable requirements. (R307-415-
6c(2)(d))

I.J.2 Any claims of confidentiality made on the information obtained during an inspection shall
be made pursuant to Utah Code Ann. Section 19-1-306. (R307-415-6c(2)(e))

I.K Certification.

Any application form, report, or compliance certification submitted pursuant to this permit
shall contain certification as to its truth, accuracy, and completeness, by a responsible
official as defined in R307-415-3. This certification shall state that, based on information
and belief formed after reasonable inquiry, the statements and information in the document
are true, accurate, and complete. (R307-415-5d)

I.L Compliance Certification.

I.L.1 Permittee shall submit to the Director an annual compliance certification, certifying
compliance with the terms and conditions contained in this permit, including emission
limitations, standards, or work practices. This certification shall be submitted no later than
the date shown under "Enforceable Dates and Timelines" at the front of this permit, and that
date each year following until this permit expires. The certification shall include all the
following (permittee may cross-reference this permit or previous reports): (R307-415-6c(5))

I.L.1.a The identification of each term or condition of this permit that is the basis of the
certification;

I.L.1.b The identification of the methods or other means used by the permittee for
determining the compliance status with each term and condition during the
certification period. Such methods and other means shall include, at a minimum, the
monitoring and related recordkeeping and reporting requirements in this permit. If
necessary, the permittee also shall identify any other material information that must
be included in the certification to comply with section 113(c)(2) of the Act, which
prohibits knowingly making a false certification or omitting material information;

I.L.1.c The status of compliance with the terms and conditions of the permit for the period
covered by the certification, including whether compliance during the period was
continuous or intermittent. The certification shall be based on the method or means
designated in Provision I.L.1.b. The certification shall identify each deviation and
Project OPP0106270009 Page 9 Title V Operating Permit #3700029005

take it into account in the compliance certification. The certification shall also
identify as possible exceptions to compliance any periods during which compliance
is required and in which an excursion or exceedance as defined under 40 CFR Part
64 occurred; and

I.L.1.d Such other facts as the Director may require to determine the compliance status.

I.L.2 The permittee shall also submit all compliance certifications to the EPA, Region VIII, at the
following address or to such other address as may be required by the Director: (R307-415-
6c(5)(d))

Environmental Protection Agency, Region VIII
Office of Enforcement, Compliance and Environmental Justice
(mail code 8ENF)
1595 Wynkoop Street
Denver, CO 80202-1129

I.M Permit Shield.

I.M.1 Compliance with the provisions of this permit shall be deemed compliance with any
applicable requirements as of the date of this permit, provided that:

I.M.1.a Such applicable requirements are included and are specifically identified in this
permit, or (R307-415-6f(1)(a))

I.M.1.b Those requirements not applicable to the source are specifically identified and listed
in this permit. (R307-415-6f(1)(b))

I.M.2 Nothing in this permit shall alter or affect any of the following:

I.M.2.a The emergency provisions of Utah Code Ann. Section 19-1-202 and Section 19-2-
112, and the provisions of the CAA Section 303. (R307-415-6f(3)(a))

I.M.2.b The liability of the owner or operator of the source for any violation of applicable
requirements under Utah Code Ann. Section 19-2-107(2)(g) and Section 19-2-110
prior to or at the time of issuance of this permit. (R307-415-6f(3)(b)

I.M.2.c The applicable requirements of the Acid Rain Program, consistent with the CAA
Section 408(a). (R307-415-6f(3)(c))

I.M.2.d The ability of the Director to obtain information from the source under Utah Code
Ann. Section 19-2-120, and the ability of the EPA to obtain information from the
source under the CAA Section 114. (R307-415-6f(3)(d))

I.N Emergency Provision.

I.N.1 An "emergency" is any situation arising from sudden and reasonably unforeseeable events
beyond the control of the source, including acts of God, which situation requires immediate
corrective action to restore normal operation, and that causes the source to exceed a
technology-based emission limitation under this permit, due to unavoidable increases in
emissions attributable to the emergency. An emergency shall not include noncompliance to
the extent caused by improperly designed equipment, lack of preventive maintenance,
careless or improper operation, or operator error. (R307-415-6g(1))

Project OPP0106270009 Page 10 Title V Operating Permit #3700029005

I.N.2 An emergency constitutes an affirmative defense to an action brought for noncompliance
with such technology-based emission limitations if the affirmative defense is demonstrated
through properly signed, contemporaneous operating logs, or other relevant evidence that:

I.N.2.a An emergency occurred and the permittee can identify the causes of the emergency.
(R307-415-6g(3)(a))

I.N.2.b The permitted facility was at the time being properly operated. (R307-415-
6g(3)(b))

I.N.2.c During the period of the emergency the permittee took all reasonable steps to
minimize levels of emissions that exceeded the emission standards, or other
requirements in this permit. (R307-415-6g(3)(c))

I.N.2.d The permittee submitted notice of the emergency to the Director within two
working days of the time when emission limitations were exceeded due to the
emergency. This notice must contain a description of the emergency, any steps
taken to mitigate emissions, and corrective actions taken. This notice fulfills the
requirement of Provision I.S.2.c below. (R307-415-6g(3)(d))

I.N.3 In any enforcement proceeding, the permittee seeking to establish the occurrence of an
emergency has the burden of proof. (R307-415-6g(4))

I.N.4 This emergency provision is in addition to any emergency or upset provision contained in
any other section of this permit. (R307-415-6g(5))

I.O Operational Flexibility.

Operational flexibility is governed by R307-415-7d(1).

I.P Off-permit Changes.

Off-permit changes are governed by R307-415-7d(2).

I.Q Administrative Permit Amendments.

Administrative permit amendments are governed by R307-415-7e.

I.R Permit Modifications.

Permit modifications are governed by R307-415-7f.

I.S Records and Reporting.

I.S.1 Records.

I.S.1.a The records of all required monitoring data and support information shall be
retained by the permittee for a period of at least five years from the date of the
monitoring sample, measurement, report, or application. Support information
includes all calibration and maintenance records, all original strip-charts or
appropriate recordings for continuous monitoring instrumentation, and copies of all
reports required by this permit. (R307-415-6a(3)(b)(ii))

Project OPP0106270009 Page 11 Title V Operating Permit #3700029005

I.S.1.b For all monitoring requirements described in Section II, Special Provisions, the
source shall record the following information, where applicable: (R307-415-
6a(3)(b)(i))

I.S.1.b.1 The date, place as defined in this permit, and time of sampling or
measurement.

I.S.1.b.2 The date analyses were performed.

I.S.1.b.3 The company or entity that performed the analyses.

I.S.1.b.4 The analytical techniques or methods used.

I.S.1.b.5 The results of such analyses.

I.S.1.b.6 The operating conditions as existing at the time of sampling or
measurement.

I.S.1.c Additional record keeping requirements, if any, are described in Section II, Special
Provisions.

I.S.2 Reports.

I.S.2.a Monitoring reports shall be submitted to the Director every six months, or more
frequently if specified in Section II. All instances of deviation from permit
requirements shall be clearly identified in the reports. (R307-415-6a(3)(c)(i))

I.S.2.b All reports submitted pursuant to Provision I.S.2.a shall be certified by a
responsible official in accordance with Provision I.K of this permit. (R307-415-
6a(3)(c)(i)

I.S.2.c The Director shall be notified promptly of any deviations from permit requirements
including those attributable to upset conditions as defined in this permit, the
probable cause of such deviations, and any corrective actions or preventative
measures taken. Prompt, as used in this condition, shall be defined as written
notification within the number of days shown under "Enforceable Dates and
Timelines" at the front of this permit. Deviations from permit requirements due to
breakdowns shall be reported in accordance with the provisions of R307-107.
(R307-415-6a(3)(c)(ii))

I.S.3 Notification Addresses.

I.S.3.a All reports, notifications, or other submissions required by this permit to be
submitted to the Director are to be sent to the following address or to such other
address as may be required by the Director:

Utah Division of Air Quality
P.O. Box 144820
Salt Lake City, UT 84114-4820
Phone: [phone]

I.S.3.b All reports, notifications or other submissions required by this permit to be
submitted to the EPA should be sent to one of the following addresses or to such
other address as may be required by the Director:
Project OPP0106270009 Page 12 Title V Operating Permit #3700029005

For annual compliance certifications:

Environmental Protection Agency, Region VIII
Office of Enforcement, Compliance and Environmental Justice
(mail code 8ENF)
1595 Wynkoop Street
Denver, CO 80202-1129

For reports, notifications, or other correspondence related to permit modifications,
applications, etc.:

Environmental Protection Agency, Region VIII
Office of Partnerships and Regulatory Assistance Air and Radiation
Program (mail code 8P-AR)
1595 Wynkoop Street
Denver, CO 80202-1129
Phone: [phone]

I.T Reopening for Cause.

I.T.1 A permit shall be reopened and revised under any of the following circumstances:

I.T.1.a New applicable requirements become applicable to the permittee and there is a
remaining permit term of three or more years. No such reopening is required if the
effective date of the requirement is later than the date on which this permit is due to
expire, unless the terms and conditions of this permit have been extended pursuant
to R307-415-7c(3), application shield. (R307-415-7g(1)(a))

I.T.1.b The Director or EPA determines that this permit contains a material mistake or that
inaccurate statements were made in establishing the emissions standards or other
terms or conditions of this permit. (R307-415-7g(1)(c))

I.T.1.c EPA or the Director determines that this permit must be revised or revoked to
assure compliance with applicable requirements. (R307-415-7g(1)(d))

I.T.1.d Additional applicable requirements are to become effective before the renewal date
of this permit and are in conflict with existing permit conditions. (R307-415-
7g(1)(e))

I.T.2 Additional requirements, including excess emissions requirements, become applicable to a
Title IV affected source under the Acid Rain Program. Upon approval by EPA, excess
emissions offset plans shall be deemed to be incorporated into this permit. (R307-415-
7g(1)(b))

I.T.3 Proceedings to reopen and issue a permit shall follow the same procedures as apply to initial
permit issuance and shall affect only those parts of this permit for which cause to reopen
exists. (R307-415-7g(2))

I.U Inventory Requirements.

An emission inventory shall be submitted in accordance with the procedures of R307-150,
Emission Inventories. (R307-150)

Project OPP0106270009 Page 13 Title V Operating Permit #3700029005

I.V Title IV and Other, More Stringent Requirements
Where an applicable requirement is more stringent than an applicable requirement of
regulations promulgated under Title IV of the Act, Acid Deposition Control, both
provisions shall be incorporated into this permit. (R307-415-6a(1)(b))

Project OPP0106270009 Page 14 Title V Operating Permit #3700029005

II.A Emission Unit(s) Permitted to Discharge Air Contaminants.
(R307-415-4(3)(a) and R307-415-4(4))

II.A.1 Permitted source
Source-wide

II.A.2 P001: Reciprocating IC Engine #1
Two stroke lean burn (2SLB) Spark Ignition Reciprocating Internal Combustion Engine (SI RICE)
compressor engine installed in 1956, fired on pipeline-quality natural gas only. Approximately 2000 hp.
No unit specific applicable requirements.

II.A.3 P002: Reciprocating IC Engine #2
2SLB SI RICE compressor engine installed in 1956, fired on pipeline-quality natural gas only.
Approximately 2000 hp. No unit specific applicable requirements.

II.A.4 P003: Reciprocating IC Engine #3
2SLB SI RICE compressor engine installed in 1956, fired on pipeline-quality natural gas only.
Approximately 2000 hp. No unit specific applicable requirements.

II.A.5 P004: Reciprocating IC Engine #4
2SLB SI RICE compressor engine installed in 1956, fired on pipeline-quality natural gas only.
Approximately 2000 hp. No unit specific applicable regulations.

II.A.6 P005: Turbine
4680 hp compressor turbine (nameplate ISO rating) fired on pipeline-quality natural gas only, equipped
with SoLoNOx technology. Construction commenced in 2003.

II.A.7 B001: Boiler #1 in A Plant
5.231 MMBtu/hr boiler (installed in 2001), fired on pipeline-quality natural gas only.

II.A.8 B002: Boiler #2 in B Plant
2.5 MMBtu/hr boiler (installed in 1992), used for comfort heating, fired on pipeline-quality natural gas
only.

II.A.9 G001: Backup Generator #1 in A Plant
Approximately 292 hp four stroke rich burn (4SRB) SI RICE emergency backup generator installed in
1992, fired on pipeline-quality natural gas only.

II.A.10 G002: Backup Generator #2 in B Plant
Approximately 565 hp four stroke rich burn (4SRB) SI RICE emergency backup generator installed in
1992, fired on pipeline-quality natural gas only.

II.A.11 F001: Miscellaneous Emission Points
Fugitive VOC emissions from miscellaneous points, including small tanks and blowdown vent stack. No
unit specific applicable requirements.

II.A.12 SB001: Salt Bath Heater
Site terminology is Fuel Gas Heater. 0.25 MMBtu/hr heater (installed in 2001), fired on pipeline-quality
natural gas only.

Project OPP0106270009 Page 15 Title V Operating Permit #3700029005

II.B Requirements and Limitations
The following emission limitations, standards, and operational limitations apply to the permitted facility
as indicated:

II.B.1 Conditions on permitted source (Source-wide).

II.B.1.a Condition:

At all times, including periods of startup, shutdown, and malfunction, the permittee shall, to the extent
practicable, maintain and operate any permitted plant equipment, 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. [Origin: DAQE-AN0106270010-10]. [40 CFR 60.11(d), R307-401-8]

II.B.1.a.1 Monitoring:

Records required for this permit condition will serve as monitoring.

II.B.1.a.2 Recordkeeping:

Permittee shall document activities performed to assure proper operation and maintenance.
Records shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.1.a.3 Reporting:

There are no reporting requirements for this provision except those specified in Section I of this
permit.

II.B.1.b Condition:

The permittee shall comply with the applicable requirements for servicing of motor vehicle air
conditioners pursuant to 40 CFR 82, Subpart B - Servicing of Motor Vehicle Air Conditioners. [Origin:
40 CFR 82, Subpart B]. [40 CFR 82.30(b)]

II.B.1.b.1 Monitoring:

The permittee shall certify, in the annual compliance statement required in Section I of this
permit, its compliance status with the requirements of 40 CFR 82, Subpart B.

II.B.1.b.2 Recordkeeping:

All records required in 40 CFR 82, Subpart B shall be maintained consistent with the
requirements of Provision S.1 in Section I of this permit.

II.B.1.b.3 Reporting:

All reports required in 40 CFR 82, Subpart B shall be submitted as required. There are no
additional reporting requirements except as outlined in Section I of this permit.

Project OPP0106270009 Page 16 Title V Operating Permit #3700029005

II.B.1.c Condition:
The permittee shall comply with the applicable requirements for recycling and emission reduction for
class I and class II refrigerants pursuant to 40 CFR 82, Subpart F - Recycling and Emissions Reduction.
[Origin: 40 CFR 82, Subpart F]. [40 CFR 82.150(b)]

II.B.1.c.1 Monitoring:

The permittee shall certify, in the annual compliance statement required in Section I of this
permit, its compliance status with the requirements of 40 CFR 82, Subpart F.

II.B.1.c.2 Recordkeeping:

All records required in 40 CFR 82, Subpart F shall be maintained consistent with the
requirements of Provision S.1 in Section I of this permit.

II.B.1.c.3 Reporting:

All reports required in 40 CFR 82, Subpart F shall be submitted as required. There are no
additional reporting requirements except as outlined in Section I of this permit.

II.B.1.d Condition:

1) General requirements for prevention of emissions and use of good air pollution control practices.

(a) All crude oil, condensate, and intermediate hydrocarbon liquids collection, storage, processing
and handling operations, regardless of size, shall be designed, operated and maintained so as to
minimize emission of volatile organic compounds to the atmosphere to the extent reasonably
practicable.

(b) At all times, including periods of start-up, shutdown, and malfunction, the installation and air
pollution control equipment shall be maintained and operated in a manner consistent with good
air pollution control practices for minimizing emissions.

(c) Determination of whether or not 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, infrared camera images, opacity observations, review of operating and
maintenance procedures, and inspection of the source.
[Origin: R307-501-4]. [R307-501-4]

II.B.1.d.1 Monitoring:

Records required for this permit condition will serve as monitoring.

II.B.1.d.2 Recordkeeping:

The permittee shall keep manufacturer specifications or equivalent on file and shall document
activities performed to assure proper operation and maintenance. Records shall be maintained in
accordance with Provision I.S.1 of this permit.

II.B.1.d.3 Reporting

There are no reporting requirements for this provision except those specified in Section I of this
permit.
Project OPP0106270009 Page 17 Title V Operating Permit #3700029005

II.B.2 Conditions on Turbine.

II.B.2.a Condition:

Emissions of NOx from each stationary gas turbine shall not be greater than the concentration calculated
by the equation:

STD = 0.0150 (14.4/Y) + F

where:

STD = allowable ISO corrected NOx emission concentration (percent by volume, at 15 percent oxygen
and on a dry basis);

Y = manufacturer's rated heat rate at manufacturer's rated peak load (kilojoules per watt hour), or
actual measured heat rate based on lower heating value of fuel as measured at actual peak load for
the facility. The value of Y shall not exceed 14.4 kilojoules per watt hour; and

F = NOx emission allowance for fuel-bound nitrogen as defined in 40 CFR 60.332(a)(4). The
permittee has accepted an F-value of zero in accordance with 40 CFR 60.332(a)(3).

[Origin: 40 CFR 60 Subpart GG]. [40 CFR 60.332(a)(2), 40 CFR 60.332(c)]

II.B.2.a.1 Monitoring:

Stack testing shall be performed as specified here:

(a) Frequency. The source shall be tested at least once every five years based on the date of the
most recent stack test, or at any other time if directed by the Director. If a turbine covered
by this condition is replaced, the new turbine shall be tested within 60 days of reaching
maximum capacity, but not later than 180 days after initial startup.

(b) Notification. At least 30 days before the test, the source shall notify the Director of the date,
time, and place of testing and provide a copy of the test protocol. The source shall attend a
pretest conference if determined necessary by the Director.

(c) Sample Point. The emission sample point shall conform to the requirements of 40 CFR 60,
Appendix A, Method 1 and 40 CFR 60.335(a). In addition, Occupational Safety and Health
Administration (OSHA) approved access shall be provided to the test location.

(d) Methods

(1) 40 CFR 60, Appendix A, Method 20, or other EPA-approved testing method, as
acceptable to the Director, shall be used to determine the nitrogen oxides.

(2) 40 CFR 60, Appendix A, Method 2, or other EPA-approved testing method, as
acceptable to the Director, shall be used to determine stack gas velocity and volumetric
flow rate. Method 19 may be used in place of Method 2 if the unit is equipped with a
calibrated fuel meter and fuel analysis is available.

(e) Calculations. For each run of the performance test, the mean nitrogen oxides emission
concentration (NOxo) corrected to 15 percent O2 shall be corrected to ISO standard
conditions using the following equation.
Project OPP0106270009 Page 18 Title V Operating Permit #3700029005

NOx = (NOxo)(Pr/Po)0.5e19(Ho-0.00633)(288 K/Ta)1.53

where:

NOx = emission concentration of NOx at 15 percent O2 and ISO standard ambient
conditions, ppm by volume, dry basis,

NOxo = mean observed NOx concentration, ppm by volume, dry basis, at 15 percent O2,

Pr = reference combustor inlet absolute pressure at 101.3 kilopascals ambient pressure.
Alternatively, 760 mm Hg (29.92 in Hg) may be used,

Po = observed combustor inlet absolute pressure at test, mm Hg. Alternatively, the
barometric pressure for the date of the test may be used,

Ho = observed humidity of ambient air, g H2O/g air,

e = transcendental constant, 2.718, and

Ta = ambient temperature, K.

The 3-run performance test shall be performed within +/- 5 percent at four evenly-spaced
load points in the normal operating range of the gas turbine, including the minimum point in
the operating range and 90-to-100 percent of peak load.

To determine mass emission rates (lb/hr, etc.), the pollutant concentration as determined by
the appropriate methods above shall be multiplied by the volumetric flow rate and any
necessary conversion factors determined by the Director to give the results in the specified
units of the emission limitation.

(f) Production Rate During Testing. The operational rate during all compliance testing shall be
no less than 90% of the maximum rate achieved in the previous three (3) years.

II.B.2.a.2 Recordkeeping:

Results of all stack testing shall be recorded and maintained in accordance with the associated test
method and Provision S.1 in Section I of this permit.

II.B.2.a.3 Reporting:

Results of required stack testing shall be submitted to the Director within 60 days of completion
of the testing. The submittal shall clearly identify results and indicate compliance status. The
annual compliance certification required by Provision L in Section I of this permit shall use the
most recent test results as a basis for stating compliance status for this limitation.

II.B.2.b Condition:

Emissions of CO shall be no greater than 4.55 lbs/hour. [Origin: DAQE-AN0106270010-10]. [R307-
401-8]

II.B.2.b.1 Monitoring:

Stack testing shall be performed as specified here:
Project OPP0106270009 Page 19 Title V Operating Permit #3700029005

a) The source shall be tested at least once every five years based on the date of the most recent
stack test, or at any other time if directed by the Director. If a turbine covered by this
condition is replaced, the new turbine shall be tested within 60 days of reaching maximum
capacity, but not later than 180 days after initial startup.

b) Notification. At least 30 days before the test, the source shall notify the Director of the date,
time, and place of testing and provide a copy of the test protocol. The source shall attend a
pretest conference if determined necessary by the Director.

c) Sample Point. The emission sample point shall conform to the requirements of 40 CFR 60,
Appendix A, Method 1. In addition, Occupational Safety and Health Administration (OSHA)
approved access shall be provided to the test location.

d) Methods.

(1) 40 CFR 60, Appendix A, Method 10, or other EPA approved testing method, as
acceptable to the Director, shall be used to determine CO emissions;

(2) 40 CFR 60, Appendix A, Method 2, or other EPA approved testing method, as acceptable
to the Director, shall be used to determine stack gas velocity and volumetric flow rate.
Method 19 may be used in place of Method 2 if the unit is equipped with a calibrated fuel
meter and fuel analysis is available.

e) Calculations. To determine mass emission rates (lb/hr, etc.) the pollutant concentration as
determined by the appropriate methods above shall be multiplied by the volumetric flow rate
and any necessary conversion factors determined by the Director to give the results in the
specified units of the emission limitation.

f) Production Rate During Testing. The operational rate during all compliance testing shall be
no less than 90% of the maximum rate achieved in the previous three (3) years.

II.B.2.b.2 Recordkeeping:

Results of all stack testing shall be recorded and maintained in accordance with the associated test
method and Provision I.S.1 of this permit.

II.B.2.b.3 Reporting:

Results of required stack testing shall be submitted to the Director within 60 days of completion
of the testing. The submittal shall clearly identify results and indicate compliance status. The
annual compliance certification required by Provision L in Section I of this permit shall use the
most recent test results as a basis for stating compliance status for this limitation.

II.B.2.c Condition:

Emissions of NOx shall be no greater than 6.28 lbs/hour. [Origin: DAQE-AN0106270010-10]. [R307-
401-8]

II.B.2.c.1 Monitoring:

Compliance with the limitation shall be demonstrated by calculating an average NOx emission
rate based on the total Btu value of the fuel combusted and the hours of operation for each
affected turbine as follows:

Project OPP0106270009 Page 20 Title V Operating Permit #3700029005

The quantity of natural gas combusted in the turbine shall be monitored. Each month, the total
amount of natural gas combusted in the turbine shall be calculated and multiplied by the average
Btu value of the fuel. The resulting Btu total shall be multiplied by the appropriate emission
factor to estimate the NOx emissions for that month.

The emission total shall be divided by the hours of operation for the turbine during the month to
calculate an average lb/hr emission rate. The emission factor used in this calculation shall be
determined by dividing the average NOx emission rate (lb/hr) at peak load calculated from the
most recent stack test by the fuel flow rate (Btu/hr) corresponding to peak load for each affected
turbine. The average NOx emission rate (lb/hr) calculated from the most recent stack test shall
also be used for demonstrating compliance with this limitation.

II.B.2.c.2 Recordkeeping:

The following information will be calculated and recorded within 15 days of the end of each
month:

a) The total amount of fuel combusted in the unit by volume (scf/month) and by heating value
(Btu/month).

b) The average heating value of the fuel (Btu/scf) combusted during the month.

c) The total hours of operation of the unit for the month.

d) The total NOx emissions calculated using the emissions factor.

e) The average NOx emissions (lb/hr) for the month.

The records shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.2.c.3 Reporting:

There are no reporting requirements for this provision except those specified in Section I of this
permit.

II.B.2.d Condition:

Sulfur content of the fuel combusted shall be no greater than 0.8 percent by weight (8000 ppmw).
[Origin: 40 CFR 60.333 (Subpart GG)]. [40 CFR 60.333(b)]

II.B.2.d.1 Monitoring:

In lieu of monitoring the total sulfur content of gaseous fuel combusted in the turbines, the
permittee shall demonstrate that the gaseous fuel meets the definition of natural gas in 40 CFR
60.331(u). To make the required demonstration, the permittee shall use the gas quality
characteristics in a current tariff sheet for the gaseous fuel, specifying that the maximum total
sulfur content of the fuel is 20.0 grains/100 scf or less. (40 CFR 60.334(h)(3))

II.B.2.d.2 Recordkeeping:

The total sulfur limit in the gas tariff sheet shall be recorded and converted to percent sulfur by
weight to determine sulfur content. Results of monitoring shall be maintained in accordance with
Provision I.S.1 of this permit.

Project OPP0106270009 Page 21 Title V Operating Permit #3700029005

II.B.2.d.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.

II.B.2.e Condition:

Visible emissions shall be no greater than 10 percent opacity. [Origin: DAQE-AN0106270010-10].
[R307-401-8]

II.B.2.e.1 Monitoring:

In lieu of monitoring via visible emission observations, fuel usage shall be monitored to
demonstrate that only pipeline-quality natural gas is used as fuel.

II.B.2.e.2 Recordkeeping:

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.2.e.3 Reporting:

In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certify in each annual certification report that only pipeline-quality natural gas is used as fuel.

II.B.3 Conditions on Boiler #1.

II.B.3.a Condition:

Visible emissions shall be no greater than 10 percent opacity. [Origin: DAQE-AN0106270010-10].
[R307-401-8]

II.B.3.a.1 Monitoring:

In lieu of monitoring via visible emission observations, fuel usage shall be monitored to
demonstrate that only pipeline-quality natural gas is used as fuel.

II.B.3.a.2 Recordkeeping:

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.3.a.3 Reporting:

In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certify in each annual certification report that only pipeline-quality natural gas is used as fuel.

II.B.3.b Condition:

The permittee shall conduct tune-ups as specified in the monitoring for this condition for each existing
affected emission unit with a heat input capacity of less than 10 million Btu per hour, but greater than 5
million Btu per hour, in the gas 1 subcategory. [Origin: 40 CFR 63 Subpart DDDDD]. [40 CFR 63
Subpart DDDDD (Table 3), 40 CFR 63.7495(b), 40 CFR 63.7500(a), 40 CFR 63.7500(e), 40 CFR
63.7510(e)]

Project OPP0106270009 Page 22 Title V Operating Permit #3700029005

II.B.3.b.1 Monitoring:
Tune-ups shall be conducted as specified in (a) through (e) below.

(a) As applicable, inspect the burner, and clean or replace any components of the burner as
necessary. Burner inspection may be performed prior to the tune-up or be delayed until the
next scheduled unit shutdown. At units where entry into a piece of process equipment or into
a storage vessel is required to complete the tune-up inspections, inspections are required only
during planned entries into the storage vessel or process equipment;

(b) Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the
flame pattern. The adjustment should be consistent with the manufacturer's specifications, if
available;

(c) Inspect the system controlling the air-to-fuel ratio, as applicable, and ensure that it is
correctly calibrated and functioning properly. The permittee may delay the inspection until
the next scheduled unit shutdown;

(d) Optimize total emissions of CO. This optimization should be consistent with the
manufacturer's specifications, if available, and with any NOx requirement to which the unit is
subject;

(e) Measure the concentrations in the effluent stream of CO in parts per million, by volume, and
oxygen in volume percent, before and after the adjustments are made (measurements may be
either on a dry or wet basis, as long as it is the same basis before and after the adjustments are
made). Measurements may be taken using a portable CO analyzer.

Following the initial tune-up, the permittee shall conduct a tune-up of each affected emission unit
every 2 years to demonstrate continuous compliance. Each biennial tune-up shall be conducted no
more than 25 months after the previous tune-up. If the unit is not operating on the required date
for a tune-up, the tune-up shall be conducted within 30 calendar days of startup.

(40 CFR 63.7500(e), 40 CFR 63.7515(d), 40 CFR 63.7515(g), 40 CFR 63.7540(a)(10)(i)-(v), 40
CFR 63.7540(a)(11), 40 CFR 63.7540(a)(13))

II.B.3.b.2 Recordkeeping:

The permittee shall maintain on-site, a report containing the following information.

(a) The concentrations of CO in the effluent stream in parts per million by volume, and oxygen
in volume percent, measured at high fire or typical operating load, before and after the tune-
up of the boiler or process heater;

(b) A description of any corrective actions taken as a part of the tune-up; and

(c) The type and amount of fuel used over the 12 months prior to the tune-up, but only if the unit
was physically and legally capable of using more than one type of fuel during that period.
Units sharing a fuel meter may estimate the fuel used by each unit.

(40 CFR 63.7540(a)(10)(vi))

The permittee shall keep a copy of each notification and report submitted to demonstrate
compliance, including all documentation supporting any Initial Notification or Notification of
Compliance Status or compliance report. (40 CFR 63.7555(a)(1))

Project OPP0106270009 Page 23 Title V Operating Permit #3700029005

Records demonstrating compliance with this condition shall be maintained in accordance with 40
CFR 63.7560 and Provision I.S.1 of this permit.

II.B.3.b.3 Reporting:

The permittee shall submit the tune-up report if requested. (40 CFR 63.7540(a)(10)(vi))

The permittee shall submit a compliance report every 2 years.

(a) The first compliance report shall cover the period beginning January 31, 2016 and ending on
December 31, 2018.

(b) The first 2-year compliance report shall be postmarked or submitted no later than January 31.

(c) Each subsequent 2-year compliance report shall cover the applicable 2-year period from
January 1 to December 31.

(d) Each subsequent 2-year compliance report shall be postmarked or submitted no later than
January 31.

The compliance report shall contain the following information.

(a) Company and Facility name and address.

(b) Process unit information.

(c) Date of report and beginning and ending dates of the reporting period.

(d) The date of the most recent tune-up for each unit.

(e) The date of the most recent burner inspection if it was not done biennially and was delayed
until the next scheduled or unscheduled unit shutdown.

(f) Statement by a responsible official with that official's name, title, and signature, certifying the
truth, accuracy, and completeness of the content of the report.

(g) If there are no deviations from the requirements for work practice standards for periods of
startup and shutdown, the report shall contain a statement that there were no deviations from
the work practice standards during the reporting period.

(h) If the permittee has a deviation from a work practice standard for periods of startup and
shutdown during the reporting period, the report shall contain a description of the deviation,
including which work practice standard was deviated from, and information on the number,
duration, and cause of deviations (including unknown cause), as applicable, and the
corrective action taken.

(40 CFR 63.7550(a), (b), (c), 40 CFR 63 Subpart DDDDD Table 9)

The permittee shall submit the reports according to the procedures specified in 40 CFR
63.7550(h)(3).

There are no additional reporting requirements for this provision except those specified in Section
I of this permit.

Project OPP0106270009 Page 24 Title V Operating Permit #3700029005

II.B.3.c Condition:
Unless otherwise specified in this permit, the permittee shall at all times, except during periods of startup
and shutdown, operate and maintain the affected emission unit, including associated air pollution control
equipment and monitoring equipment, in a manner consistent with safety and good air pollution control
practices for minimizing emissions. Determination of whether such operation and maintenance
procedures are being used will be based on information available to the Director that may include, but is
not limited to, monitoring results, review of operation and maintenance procedures, review of operation
and maintenance records, and inspection of the source. [Origin: 40 CFR 63 Subpart DDDDD]. [40 CFR
63.7495(b), 40 CFR 63.7500(a)(3), 40 CFR 63.7500(f)]

II.B.3.c.1 Monitoring:

Records required for this permit condition will serve as monitoring.

II.B.3.c.2 Recordkeeping:

Permittee shall document activities performed to assure proper operation and maintenance.
Records shall be kept as specified in 40 CFR 63.7555 and maintained in accordance with 40 CFR
63.7560 and Provision I.S.1 of this permit.

II.B.3.c.3 Reporting:

In addition to the reporting requirements of Section I of this permit, the permittee shall comply
with the reporting requirements specified in 40 CFR 63.7550.

II.B.4 Conditions for Boiler #2.

II.B.4.a Condition:

Visible emissions shall be no greater than 20 percent opacity. [Origin: DAQE-AN0106270010-10].
[R307-401-8]

II.B.4.a.1 Monitoring:

In lieu of monitoring via visible emission observations, fuel usage shall be monitored to
demonstrate that only pipeline-quality natural gas is used as fuel.

II.B.4.a.2 Recordkeeping:

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.4.a.3 Reporting:

In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certify in each annual certification report that only pipeline-quality natural gas is used as fuel.

II.B.4.b Condition:

The permittee shall conduct tune-ups as specified in the monitoring for this condition for each existing
affected emission unit with (1) a continuous oxygen trim system that maintains an optimum air to fuel
ratio, or (2) a heat input capacity of less than or equal to 5 million Btu per hour in the gas 1 subcategory.
[Origin: 40 CFR 63 Subpart DDDDD]. [40 CFR 63 Subpart DDDDD (Table 3), 40 CFR 63.7495(b), 40
CFR 63.7500(a), 40 CFR 63.7500(e), 40 CFR 63.7510(e)]
Project OPP0106270009 Page 25 Title V Operating Permit #3700029005

II.B.4.b.1 Monitoring:

Tune-ups shall be conducted as specified in (a) through (e) below.

(a) As applicable, inspect the burner, and clean or replace any components of the burner as
necessary. Burner inspection may be performed prior to the tune-up or be delayed until the
next scheduled or unscheduled unit shutdown but the permittee shall inspect each burner at
least once every 72 months. At units where entry into a piece of process equipment or into a
storage vessel is required to complete the tune-up inspections, inspections are required only
during planned entries into the storage vessel or process equipment;

(b) Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the
flame pattern. The adjustment should be consistent with the manufacturer's specifications, if
available;

(c) Inspect the system controlling the air-to-fuel ratio, as applicable, and ensure that it is
correctly calibrated and functioning properly. The permittee may delay the inspection until
the next scheduled unit shutdown;

(d) Optimize total emissions of CO. This optimization should be consistent with the
manufacturer's specifications, if available, and with any NOx requirement to which the unit is
subject;

(e) Measure the concentrations in the effluent stream of CO in parts per million, by volume, and
oxygen in volume percent, before and after the adjustments are made (measurements may be
either on a dry or wet basis, as long as it is the same basis before and after the adjustments are
made). Measurements may be taken using a portable CO analyzer.

Following the initial tune-up, the permittee shall conduct a tune-up of each affected emission unit
every 5 years to demonstrate continuous compliance. Each 5-year tune-up shall be conducted no
more than 61 months after the previous tune-up. If an oxygen trim system is utilized on an
affected emission unit, the permittee shall set the oxygen level no lower than the oxygen
concentration measured during the most recent tune-up. If the unit is not operating on the
required date for a tune-up, the tune-up shall be conducted within 30 calendar days of startup.

(40 CFR 63.7500(e), 40 CFR 63.7515(d), 40 CFR 63.7515(g), 40 CFR 63.7540(a)(10)(i)-(v), 40
CFR 63.7540(a)(12), 40 CFR 63.7540(a)(13))

II.B.4.b.2 Recordkeeping:

The permittee shall maintain on-site, a report containing the following information.

(a) The concentrations of CO in the effluent stream in parts per million by volume, and oxygen
in volume percent, measured at high fire or typical operating load, before and after the tune-
up of the boiler or process heater;

(b) A description of any corrective actions taken as a part of the tune-up; and

(c) The type and amount of fuel used over the 12 months prior to the tune-up, but only if the unit
was physically and legally capable of using more than one type of fuel during that period.
Units sharing a fuel meter may estimate the fuel used by each unit.

(40 CFR 63.7540(a)(10)(vi))
Project OPP0106270009 Page 26 Title V Operating Permit #3700029005

The permittee shall keep a copy of each notification and report submitted to demonstrate
compliance, including all documentation supporting any Initial Notification or Notification of
Compliance Status or compliance report. (40 CFR 63.7555(a)(1))

Records demonstrating compliance with this condition shall be maintained in accordance with 40
CFR 63.7560 and Provision I.S.1 of this permit.

II.B.4.b.3 Reporting:

The permittee shall submit the tune-up report if requested. (40 CFR 63.7540(a)(10)(vi))

The permittee shall submit a compliance report every 5 years.

(a) The first compliance report shall cover the period beginning January 31, 2016 and ending on
December 31, 2021.

(b) The first 5-year compliance report shall be postmarked or submitted no later than January 31.

(c) Each subsequent 5-year compliance report shall cover the applicable 5-year period from
January 1 to December 31.

(d) Each subsequent 5-year compliance report shall be postmarked or submitted no later than
January 31.

The compliance report shall contain the following information.

(a) Company and Facility name and address.

(b) Process unit information.

(c) Date of report and beginning and ending dates of the reporting period.

(d) The date of the most recent tune-up for each unit.

(e) The date of the most recent burner inspection if it was not done on a 5-year period and was
delayed until the next scheduled or unscheduled unit shutdown.

(f) Statement by a responsible official with that official's name, title, and signature, certifying the
truth, accuracy, and completeness of the content of the report.

(g) If there are no deviations from the requirements for work practice standards for periods of
startup and shutdown, the report shall contain a statement that there were no deviations from
the work practice standards during the reporting period.

(h) If the permittee has a deviation from a work practice standard for periods of startup and
shutdown during the reporting period, the report shall contain a description of the deviation,
including which work practice standard was deviated from, and information on the number,
duration, and cause of deviations (including unknown cause), as applicable, and the
corrective action taken.

(40 CFR 63.7550(a), (b), (c), 40 CFR 63 Subpart DDDDD Table 9)

Project OPP0106270009 Page 27 Title V Operating Permit #3700029005

The permittee shall submit the reports according to the procedures specified in 40 CFR
63.7550(h)(3).

There are no additional reporting requirements for this provision except those specified in Section
I of this permit.

II.B.4.c Condition:

Unless otherwise specified in this permit, the permittee shall at all times, except during periods of startup
and shutdown, operate and maintain the affected emission unit, including associated air pollution control
equipment and monitoring equipment, in a manner consistent with safety and good air pollution control
practices for minimizing emissions. Determination of whether such operation and maintenance
procedures are being used will be based on information available to the Director that may include, but is
not limited to, monitoring results, review of operation and maintenance procedures, review of operation
and maintenance records, and inspection of the source. [Origin: 40 CFR 63 Subpart DDDDD]. [40 CFR
63.7495(b), 40 CFR 63.7500(a)(3), 40 CFR 63.7500(f)]

II.B.4.c.1 Monitoring:

Records required for this permit condition will serve as monitoring.

II.B.4.c.2 Recordkeeping:

Permittee shall document activities performed to assure proper operation and maintenance.
Records shall be kept as specified in 40 CFR 63.7555 and maintained in accordance with 40 CFR
63.7560 and Provision I.S.1 of this permit.

II.B.4.c.3 Reporting:

In addition to the reporting requirements of Section I of this permit, the permittee shall comply
with the reporting requirements specified in 40 CFR 63.7550.

II.B.5 Conditions on Backup Generator #1.

II.B.5.a Condition:

Visible emissions shall be no greater than 10 percent opacity. [Origin: DAQE-AN0106270010-10].
[R307-401-8]

II.B.5.a.1 Monitoring:

In lieu of monitoring via visible emission observations, fuel usage shall be monitored to
demonstrate that only pipeline-quality natural gas is used as fuel.

II.B.5.a.2 Recordkeeping:

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.5.a.3 Reporting:

In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certify in each annual certification report that only pipeline-quality natural gas is used as fuel.

Project OPP0106270009 Page 28 Title V Operating Permit #3700029005

II.B.5.b Condition:
Hours of operation shall be no greater than 500 hours per 12-month period. [Origin: DAQE-
AN0106270010-10]. [R307-401-8]

II.B.5.b.1 Monitoring:

An hour meter shall be used to continuously monitor the hours of operation for the affected
equipment. Readings shall be taken monthly to determine the total operating hours for that
month. The permittee shall calculate a rolling 12-month total. By the 20th day of each month, a
new 12-month total shall be calculated using data from the previous 12 months.

II.B.5.b.2 Recordkeeping:

Records of each monthly check will be maintained in accordance with Provision I.S.1 of this
permit. Additionally, the record shall include the reading for each hour meter and the calculated
total hours of operation for the previous 12 months.

II.B.5.b.3 Reporting:

There are no reporting requirements for this provision except those specified in Section I of this
permit.

II.B.5.c Condition:

The permittee shall comply with the following operating limitations at all times for each emergency
affected emission unit:

1) The permittee shall operate the affected emission unit according to the requirements in 40 CFR
63.6640(f). Any operation other than emergency operation, maintenance and testing, and operation in
non-emergency situations for 50 hours per year, as described in 40 CFR 63.6640(f), is prohibited. If
the engine is not operated in accordance with 40 CFR 63.6640(f), it will not be considered an
emergency engine and shall meet all requirements for non-emergency engines.

(a) There is no time limit on the use of emergency stationary RICE in emergency situations.

(b) The permittee may operate the affected unit for maintenance checks and readiness testing for a
maximum of 100 hours per calendar year. Any operation for non-emergency situations as
allowed by paragraph 40 CFR 63.6640(f)(3) counts as part of the 100 hours per calendar year
allowed in paragraph 40 CFR 63.6640(f)(2).

(c) The permittee may operate the affected emission unit up to 50 hours per calendar year in non-
emergency situations. The 50 hours of operation in non-emergency situations are counted as part
of the 100 hours per year for maintenance and testing and shall meet the requirements in 40 CFR
63.6640(f).

2) The permittee shall meet the following requirements at all times, except during periods of startup:

(a) Change oil and filter every 500 hours of operation or annually, whichever comes first.

(b) Inspect spark plugs every 1,000 hours of operation or annually, whichever comes first and replace
as necessary.

Project OPP0106270009 Page 29 Title V Operating Permit #3700029005

(c) Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and
replace as necessary.

During periods of startup, the permittee shall minimize the engine's time spent at idle and minimize
the engine's startup time to a period needed for appropriate and safe loading of the engine, not to
exceed 30 minutes, after which time the non-startup emission limitations apply.

3) The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as identified in
Table 8 of 40 CFR 63 Subpart ZZZZ.

[Origin: 40 CFR 63 Subpart ZZZZ]. [40 CFR 63 Subpart ZZZZ (Table 2c), 40 CFR 63 Subpart ZZZZ
(Table 8), 40 CFR 63.6602, 40 CFR 63.6605, 40 CFR 63.6625(h), 40 CFR 63.6640(f), 40 CFR 63.6665]

II.B.5.c.1 Monitoring:

The permittee shall install a non-resettable hour meter if one is not already installed. (40 CFR
63.6625(f))

If an emergency engine is operating during an emergency and it is not possible to shut down the
engine in order to perform the work practice requirements on the schedule required in Table 2c,
or if performing the work practice on the required schedule would otherwise pose an
unacceptable risk under Federal, State, or local law, the work practice can be delayed until the
emergency is over or the unacceptable risk under Federal, State, or local law has abated. The
work practice shall be performed as soon as practicable after the emergency has ended or the
unacceptable risk under Federal, State, or local law has abated. (40 CFR 63 Subpart ZZZZ Table
2c Footnote 1)

The permittee shall demonstrate continuous compliance by operating and maintaining the
stationary RICE and after-treatment control device (if any) according to the manufacturer's
emission-related written operation and maintenance instructions or develop and follow their own
maintenance plan which must provide to the extent practicable for the maintenance and operation
of the engine in a manner consistent with good air pollution control practice for minimizing
emissions. (40 CFR 63.6625(e), 40 CFR 63 Subpart ZZZZ Table 6(9))

The permittee has the option of utilizing an oil analysis program in order to extend the specified
oil change requirement in accordance with 40 CFR 63.6625(j). The oil analysis must be
performed at the same frequency specified for changing the oil in 40 CFR 63 Subpart
ZZZZ Table 2c.

The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as
identified in Table 8 of 40 CFR 63 Subpart ZZZZ. (40 CFR 63.6665)

II.B.5.c.2 Recordkeeping:

The permittee shall keep the records described in 40 CFR 63.6655(a)(1)-(5) as applicable. (40
CFR 63.6655(a))

The permittee shall keep records that demonstrate continuous compliance with each applicable
operating limitation (including, but not limited to, the manufacturer's emission-related operation
and maintenance instructions or the permittee-developed maintenance plan). (40 CFR
63.6655(d), 40 CFR 63 Subpart ZZZZ Table 6)

Records of the maintenance conducted shall be kept in order to demonstrate that the permittee
Project OPP0106270009 Page 30 Title V Operating Permit #3700029005

operated and maintained the affected emission unit and after-treatment control device (if any)
according to their own maintenance plan. (40 CFR 63.6655(e))

For each affected emission unit that does not meet the standards applicable to non-emergency
engines, the permittee shall keep records of the hours of operation of the engine that are recorded
through the non-resettable hour meter. The permittee shall document how many hours are spent
for emergency operation, including what classified the operation as emergency and how many
hours are spent for non-emergency operation. (40 CFR 63.6655(f)).

If additional hours are to be used for maintenance checks and readiness testing, the permittee
shall maintain records indicating that Federal, State, or local standards require maintenance and
testing of emergency RICE beyond 100 hours per calendar year. (40 CFR 63.6640(f)(2)(i))

The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as
identified in Table 8 of 40 CFR 63 Subpart ZZZZ. (40 CFR 63.6665)

Records shall be maintained in accordance with Provisions of I.S.1 of this permit and 40 CFR
63.6660.

II.B.5.c.3 Reporting:

In addition to reporting requirements specified in Section I of this permit, the permittee shall
report any failure to perform the work practice on the schedule required and the Federal, State or
local law under which the risk was deemed unacceptable. (40 CFR 63 Subpart ZZZZ Table 2c
Footnote 1)

The permittee shall comply with the applicable general provisions in 40 CFR 63.1-15 as
identified in 40 CFR 63 Subpart ZZZZ Table 8. (40 CFR 63.6640(e) and 40 CFR 63.6665)

II.B.5.d Condition:

At all times the permittee shall operate and maintain any affected source, including associated air
pollution control equipment and monitoring equipment, in a manner consistent with safety and good air
pollution control practices for minimizing emissions. The general duty to minimize emissions does not
require the permittee to make any further efforts to reduce emissions if levels required by this standard
have been achieved. Determination of whether such operation 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, review of operation and maintenance procedures, review of operation and
maintenance records, and inspection of the source. [Origin: 40 CFR 63 Subpart ZZZZ]. [40 CFR
63.6595(a)(1), 40 CFR 63.6605(b)]

II.B.5.d.1 Monitoring:

Records required for this permit condition will serve as monitoring.

II.B.5.d.2 Recordkeeping:

The permittee shall keep the records described in 40 CFR 63.6655(a)(1)-(5) as applicable. [40
CFR 63.6655(a)] The permittee shall document activities performed to assure proper operation
and maintenance. Records shall be maintained in accordance with 40 CFR 63.6660 and Provision
I.S.1 of this permit.

Project OPP0106270009 Page 31 Title V Operating Permit #3700029005

II.B.5.d.3 Reporting:
There are no reporting requirements for this provision except those specified in Section I of this
permit.

II.B.6 Conditions on Backup Generator #2.

II.B.6.a Condition:

Visible emissions shall be no greater than 10 percent opacity. [Origin: DAQE-AN0106270010-10].
[R307-401-8]

II.B.6.a.1 Monitoring:

In lieu of monitoring via visible emission observations, fuel usage shall be monitored to
demonstrate that only pipeline-quality natural gas is used as fuel.

II.B.6.a.2 Recordkeeping:

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.6.a.3 Reporting:

In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certify in each annual certification report that only pipeline-quality natural gas is used as fuel.

II.B.6.b Condition:

Hours of operation shall be no greater than 200 hours per 12-month period. [Origin: DAQE-
AN0106270010-10]. [R307-401-8]

II.B.6.b.1 Monitoring:

An hour meter shall be used to continuously monitor the hours of operation for the affected
equipment. Readings shall be taken monthly to determine the total operating hours for that
month. The permittee shall calculate a rolling 12-month total. By the 20th day of each month, a
new 12-month total shall be calculated using data from the previous 12 months.

II.B.6.b.2 Recordkeeping:

Records of each monthly check will be maintained in accordance with Provision I.S.1 of this
permit. Additionally, the record shall include the reading for each hour meter and the calculated
total hours of operation for the previous 12 months.

II.B.6.b.3 Reporting:

There are no reporting requirements for this provision except those specified in Section I of this
permit.

II.B.7 Conditions on Salt Bath Heater.

II.B.7.a Condition:

Visible emission shall be no greater than 10 percent opacity. [Origin: DAQE-AN0106270010-10].
[R307-401-8]
Project OPP0106270009 Page 32 Title V Operating Permit #3700029005

II.B.7.a.1 Monitoring:
In lieu of monitoring via visible emission observations, fuel usage shall be monitored to
demonstrate that only pipeline-quality natural gas is used as fuel.

II.B.7.a.2 Recordkeeping:

Results of monitoring shall be maintained in accordance with Provision I.S.1 of this permit.

II.B.7.a.3 Reporting:

In addition to the reporting requirements specified in Section I of this permit, the permittee shall
certify in each annual certification report that only pipeline-quality natural gas is used as fuel.

II.B.7.b Condition:

The permittee shall conduct tune-ups as specified in the monitoring for this condition for each existing
affected emission unit with (1) a continuous oxygen trim system that maintains an optimum air to fuel
ratio, or (2) a heat input capacity of less than or equal to 5 million Btu per hour in the gas 1 subcategory.
[Origin: 40 CFR 63 Subpart DDDDD]. [40 CFR 63 Subpart DDDDD (Table 3), 40 CFR 63.7495(b), 40
CFR 63.7500(a), 40 CFR 63.7500(e), 40 CFR 63.7510(e)]

II.B.7.b.1 Monitoring:

Tune-ups shall be conducted as specified in (a) through (e) below.

(a) As applicable, inspect the burner, and clean or replace any components of the burner as
necessary. Burner inspection may be performed prior to the tune-up or be delayed until the
next scheduled or unscheduled unit shutdown but the permittee shall inspect each burner at
least once every 72 months. At units where entry into a piece of process equipment or into a
storage vessel is required to complete the tune-up inspections, inspections are required only
during planned entries into the storage vessel or process equipment;

(b) Inspect the flame pattern, as applicable, and adjust the burner as necessary to optimize the
flame pattern. The adjustment should be consistent with the manufacturer's specifications, if
available;

(c) Inspect the system controlling the air-to-fuel ratio, as applicable, and ensure that it is
correctly calibrated and functioning properly. The permittee may delay the inspection until
the next scheduled unit shutdown;

(d) Optimize total emissions of CO. This optimization should be consistent with the
manufacturer's specifications, if available, and with any NOx requirement to which the unit is
subject;

(e) Measure the concentrations in the effluent stream of CO in parts per million, by volume, and
oxygen in volume percent, before and after the adjustments are made (measurements may be
either on a dry or wet basis, as long as it is the same basis before and after the adjustments are
made). Measurements may be taken using a portable CO analyzer.

Following the initial tune-up, the permittee shall conduct a tune-up of each affected emission unit
every 5 years to demonstrate continuous compliance. Each 5-year tune-up shall be conducted no
more than 61 months after the previous tune-up. If an oxygen trim system is utilized on an
affected emission unit, the permittee shall set the oxygen level no lower than the oxygen
Project OPP0106270009 Page 33 Title V Operating Permit #3700029005

concentration measured during the most recent tune-up. If the unit is not operating on the
required date for a tune-up, the tune-up shall be conducted within 30 calendar days of startup.

[40 CFR 63.7500(e), 40 CFR 63.7515(d), 40 CFR 63.7515(g), 40 CFR 63.7540(a)(10)(i)-(v), 40
CFR 63.7540(a)(12), 40 CFR 63.7540(a)(13)]

II.B.7.b.2 Recordkeeping:

The permittee shall maintain on-site, a report containing the following information.

(a) The concentrations of CO in the effluent stream in parts per million by volume, and oxygen
in volume percent, measured at high fire or typical operating load, before and after the tune-
up of the boiler or process heater;

(b) A description of any corrective actions taken as a part of the tune-up; and

(c) The type and amount of fuel used over the 12 months prior to the tune-up, but only if the unit
was physically and legally capable of using more than one type of fuel during that period.
Units sharing a fuel meter may estimate the fuel used by each unit.

(40 CFR 63.7540(a)(10)(vi))

The permittee shall keep a copy of each notification and report submitted to demonstrate
compliance, including all documentation supporting any Initial Notification or Notification of
Compliance Status or compliance report. (40 CFR 63.7555(a)(1))

II.B.7.b.3 Reporting:

The permittee shall submit the tune-up report if requested. (40 CFR 63.7540(a)(10)(vi))

The permittee shall submit a compliance report every 5 years.

(a) The first compliance report shall cover the period beginning January 31, 2016 and ending on
December 31, 2021.

(b) The first 5-year compliance report shall be postmarked or submitted no later than January 31.

(c) Each subsequent 5-year compliance report shall cover the applicable 5-year period from
January 1 to December 31.

(d) Each subsequent 5-year compliance report shall be postmarked or submitted no later than
January 31.

The compliance report shall contain the following information.

(a) Company and Facility name and address.

(b) Process unit information.

(c) Date of report and beginning and ending dates of the reporting period.

(d) The date of the most recent tune-up for each unit.

Project OPP0106270009 Page 34 Title V Operating Permit #3700029005

(e) The date of the most recent burner inspection if it was not done on a 5-year period and was
delayed until the next scheduled or unscheduled unit shutdown.

(f) Statement by a responsible official with that official's name, title, and signature, certifying the
truth, accuracy, and completeness of the content of the report.

(g) If there are no deviations from the requirements for work practice standards for periods of
startup and shutdown, the report shall contain a statement that there were no deviations from
the work practice standards during the reporting period.

(h) If the permittee has a deviation from a work practice standard for periods of startup and
shutdown during the reporting period, the report shall contain a description of the deviation,
including which work practice standard was deviated from, and information on the number,
duration, and cause of deviations (including unknown cause), as applicable, and the
corrective action taken.

(40 CFR 63.7550(a), (b), (c), 40 CFR 63 Subpart DDDDD Table 9)

The permittee shall submit the reports according to the procedures specified in 40 CFR
63.7550(h)(3).

There are no additional reporting requirements for this provision except those specified in Section
I of this permit.

II.B.7.c Condition:

Unless otherwise specified in this permit, the permittee shall at all times, except during periods of startup
and shutdown, operate and maintain the affected emission unit, including associated air pollution control
equipment and monitoring equipment, in a manner consistent with safety and good air pollution control
practices for minimizing emissions. Determination of whether such operation and maintenance
procedures are being used will be based on information available to the Director that may include, but is
not limited to, monitoring results, review of operation and maintenance procedures, review of operation
and maintenance records, and inspection of the source. [Origin: 40 CFR 63 Subpart DDDDD]. [40 CFR
63.7495(b), 40 CFR 63.7500(a)(3), 40 CFR 63.7500(f)]

II.B.7.c.1 Monitoring:

Records required for this permit condition will serve as monitoring.

II.B.7.c.2 Recordkeeping:
Permittee shall document activities performed to assure proper operation and maintenance.
Records shall be kept as specified in 40 CFR 63.7555 and maintained in accordance with 40 CFR
63.7560 and Provision I.S.1 of this permit.

II.B.7.c.3 Reporting:

In addition to the reporting requirements of Section I of this permit, the permittee shall comply
with the reporting requirements specified in 40 CFR 63.7550.

Project OPP0106270009 Page 35 Title V Operating Permit #3700029005

II.C Emissions Trading
(R307-415-6a(10))

Not applicable to this source.

II.D Alternative Operating Scenarios.
(R307-415-6a(9))

Not applicable to this source.

Project OPP0106270009 Page 36 Title V Operating Permit #3700029005

The following requirements have been determined to be not applicable to this source in accordance with
Provision I.M, Permit Shield:

III.A. 40 CFR 68 (Chemical Accident Prevention Provisions)

This regulation is not applicable to the Permitted source for the following reason(s): because no
listed substance is now stored at this source at levels above the threshold quantity; also, the pipeline
and associated compression equipment are regulated under 49 CFR Part 192 and so do not meet the
definition of "stationary source" for this part [Last updated April 24, 2020]

III.B. 40 CFR 61 Subpart A (General Provisions)

This regulation is not applicable to the Permitted source for the following reason(s): this source
does not handle any of the listed substances [Last updated April 24, 2020]

III.C. 40 CFR 61 Subpart V (National Emission Standard for Equipment Leaks (Fugitive Emission
Sources))

This regulation is not applicable to the Permitted source for the following reason(s): this source has
no equipment in volatile hazardous air pollutant (VHAP) service [Last updated April 24, 2020]

III.D. 40 CFR 63 Subpart H (National Emission Standards for Organic HAPs for Equipment Leaks)

This regulation is not applicable to the Permitted source for the following reason(s): this source has
no equipment in organic hazardous air pollutant (OHAP) service and is not subject to any subpart
that references this regulation [Last updated April 24, 2020]

Project OPP0106270009 Page 37 Title V Operating Permit #3700029005

IV.A This source is not subject to Title IV. This section is not applicable.

Project OPP0106270009 Page 38 Title V Operating Permit #3700029005

This operating permit incorporates all applicable requirements contained in the following documents:

Incorporates AN106270010-10 dated August 3, 2010

1. Comment on an item originating in 40 CFR 64 regarding Permitted source
CAM applicability: CAM applicability has been evaluated. There are no CAM
requirements in this permit. [Last updated April 24, 2020]

2. Comment on an item originating in EPA comment regarding Permitted source
Justification of monitoring: The turbine at the source is subject to the NOx concentration
limits in Subpart GG, NOx BACT limits (in lb/hr), and CO BACT limits (also in lb/hr).
The NOx concentration limit and CO BACT limit have five-year (minimum) stack test
requirements. However, the NOx BACT limit uses an emission factor (derived from the
stack test) in conjunction with fuel quality and consumption monitoring on a monthly basis
to demonstrate compliance.

Additionally, no controls are used to meet these limits, the emissions are not typically
variable, and the sites are remote, which makes frequent stack testing infeasible.
[10/07/2003] [Last updated April 24, 2020]

3. Comment on an item originating in 40 CFR 60 Subpart GG regarding Permitted source
Requirement to monitor water-fuel ratio at turbine (40 CFR 60.334(a)): The turbine at this
source does not employ water injection, so the requirement is not included in this permit.
[1/27/1997] [Last updated April 24, 2020]

4. Comment on an item originating in 40 CFR 51 regarding Permitted source
Requirements for Preparation of Implementation Plans: Source requested a shield term for
40 CFR 51. This part includes many requirements for the state which do not directly affect
the source; however, Subpart I is the regulatory authority for all new source review,
including PSD. This shield item was declined. Portions of 40 CFR 51 may be included in
future shield terms if more explicit justification is provided. [1/15/1997] [Last updated
April 24, 2020]

5. Comment on an item originating in 40 CFR 63 Subpart ZZZZ & 40 CFR 60 Subpart JJJJ regarding
Permitted source
SI RICE: Due to manufacture dates emission units P001-P004, G001, and G002 are not
subject to 40 CFR 60 Subpart JJJJ. Emission units P001- P004, G001, and G002 are
subject to 40 CFR 63 Subpart ZZZZ. However, emissions units P001-P004 do not
currently have any operation or emission limitations under Subpart ZZZZ. [Last updated
April 24, 2020]

6. Comment on an item originating in 40 CFR 52 regarding Permitted source
State Implementation Plans: Source requested a shield term for 40 CFR 52. This part
includes many requirements for the state which do not directly affect the source; however,
Subpart TT is the federal approval of the Utah SIP, which does contain requirements for
sources in attainment areas. This shield item was declined. Portions of 40 CFR 52 not
including Subpart TT may be included in future shield terms if more explicit justification
is provided. [1/15/1997] [Last updated April 24, 2020]

Project OPP0106270009 Page 39 Title V Operating Permit #3700029005

7. Comment on an item originating in DAQE-AN06270010-10 regarding F001: Miscellaneous
emission points
Use of term fugitive: In discussion with NSR engineers, this item is to refer to equipment
with small point source emissions such as blowdown stacks or vent stacks on tanks. The
term fugitive was in the original permit, but has never been changed as the meaning of the
term fugitive changed. [Last updated April 24, 2020]

8. Comment on an item originating in 40 CFR 60 Subpart GG regarding P005: Turbine
Definition of ISO standard day conditions: The standards prescribed in this subpart
reference ISO standard day conditions. These are defined in the subpart as 288 K, 60%
relative humidity, and 101.3 kPa (58.7 °F, 14.7 psia, 60% relative humidity). [4/30/1997]
[Last updated April 24, 2020]

9. Comment on an item originating in EPA Technical Enforcement Program memo regarding P005:
Turbine
H2S Monitoring approval: The sulfur content monitoring described above was modified by
NWP request and approved in an EPA memo dated 8/18/2000 to include chromatography
and station location. This change was incorporated with the 1/2002 admin amendment.

Also, EPA requested a change in the origin for the monitoring condition to show the EPA
letters of approval. Due to space constraints, the full list will not fit in the permit. EPA
issued letters on 1/20/93, 2/5/93, 7/22/93, and 8/18/2000 approving this monitoring
approach. The letters are on file at DAQ. [7/19/2002]
[Last updated April 24, 2020]

10. Comment on an item originating in 40 CFR 60 Subpart GG regarding P005: Turbine
Requirement to monitor fuel-bound nitrogen content: This requirement was not included in
this permit as the source combusts only pipeline quality natural gas, which typically has no
fuel-bound nitrogen. This requirement is apparently intended for coal- or oil-derived fuels.
Also, EMTIC guidance document GD-009 indicates that there is no good test at this time,
so the F-factor should be zero. A letter from EPA Region 8 dated 1/20/93 to NWP agrees
that no nitrogen monitoring is needed for natural gas. [6/09/1997] [Last updated April 24,
2020]

11. Comment on an item originating in 40 CFR 60 Subpart GG regarding P005: Turbine
Requirement to monitor sulfur content of turbine fuel [40 CFR 60.334(h)(3)]: EPA's July
22, 1993 approval of a custom fuel monitoring schedule has been superseded by later
revisions to NSPS subpart GG, at 60.334(h)(3) and (4). Under 60.334(h)(4), sources have
the option of continuing to follow an EPA-approved custom fuel monitoring schedule, but
are now allowed to alternative operation under 60.334(h)(3) of demonstrating compliance
with the sulfur content limit of 60.333 via a current, valid gas tariff sheet, provided that the
tariff sheet specifies that the maximum total sulfur content of the fuel is 20.0 grains/100
scf or less, and provided that the gaseous fuel is demonstrated to meet the definition of
natural gas at 60.331(u). Since all combustion at this source uses pipeline gas, use of a
tariff sheet satisfies NSPS Subpart GG monitoring. [Last updated April 24, 2020]

12. Comment on an item originating in 40 CFR 63, Subpart YYYY regarding P005: Turbine
Turbine: In 2004 EPA issued a stay to suspend the obligation of sources in the lean premix
gas-fired turbines and diffusion flame gas-fired turbines subcategories to comply with the
emissions limitations and operating limitations set forth in 40 CFR part 63, subpart
YYYY. On March 9, 2020 EPA published an update to 40 CFR part 63, subpart YYYY.
However, EPA did not finalize the proposed removal of the stay and are still reviewing the
comments on lifting the stay and will respond to them in any subsequent action. Upon
Project OPP0106270009 Page 40 Title V Operating Permit #3700029005

resolution of this matter re-evaluation of the applicability of 40 CFR part 63, subpart
YYYY will be necessary. [Last updated June 9, 2020]

13. Comment on an item originating in 40 CFR 60 Subpart GG regarding P005 Turbine
Fuel bound nitrogen: According to Reviewer Comment 10, pipeline quality natural gas
typically has no fuel-bound nitrogen so the F-factor should be zero. Therefore, the
permittee has accepted an F-value of zero in accordance with 40 CFR 60.332(a) and the
condition for the emissions of NOx was rewritten and streamlined accordingly. [Last
updated June 9, 2020]

14. Comment on an item originating in 40 CFR 60 Subpart GG regarding P005 Turbine
Requirement to submit stack testing results to the Director within 30 days [DAQE-
AN0106270010-10]: Utah Administrative Code rule R307-165 - Stack Testing was
updated and became effective on 8/10/2020. The updated rule requires sources to submit
stack test results to the director no later than 60 days after completion of the testing.
Therefore, Title V Permit was updated from within 30 days to within 60 days for results of
required stack testing of the Turbine to be submitted to the Director. [Last updated
September 16, 2020]

15. Comment on an item originating in 40 CFR 63 Subpart DDDDD regarding Permitted source
Requirement for emission units B001, B002, and SB001 to perform a one-time energy
assessment by January 31, 2016 [40 CFR 63 Subpart DDDDD (Table 3), 40 CFR
63.7495(b), 40 CFR 63.7500(a)]: This requirement was met when one-time energy
assessment for emission units B001, B002, and SB001 was conducted in October 2015.
Therefore, this requirement is being removed from the Title V Permit for emission units
B001, B002, and SB001. [Last updated June 9, 2020]

16. Comment on an item originating in 40 CFR 60 Subpart GG regarding P005 Turbine
Turbine combustor exchanged: The turbine combustor was exchanged and placed into
service on April 4, 2014. The turbine combustor exchange did not meet the definition of
Modification 40 CFR 60.14(a), or Reconstruction 40 CFR 60.15(b). [Last updated June 9,
2020]

17. Comment on an item originating in 40 CFR 63 Subpart ZZZZ regarding G001
Requirements with regard to demand response: Due to the U.S. Court of Appeals for the
District of Columbia Circuit vacating paragraphs 40 CFR 63.6640(f)(ii) - (iii),
requirements with regard to demand response was removed from Recordkeeping in
II.B.5.c.2. [Last updated June 16, 2020]

18. Comment on an item originating in 40 CFR 63 Subpart ZZZZ regarding G001
Hours limitation: The permittee must comply with the requirements specified in 40 CFR
63.6640(f) as well as the limitation of 500 hours per 12-month period specified in
Condition II.B.5.b. The requirements specified in 40 CFR 63.6640(f) include operating
the emergency generator for a maximum of 100 hours per calendar year for any
combination of the purposes specified in paragraphs (f)(2)(i). Therefore, up to 100 of the
500 hours granted in Condition II.B.5.b may be used for the purposes specified in
paragraphs (f)(2)(i), with any remaining hours being used for emergency use. [Last
updated June 10, 2020]

19. Comment on an item originating in 40 CFR 63 Subpart ZZZZ regarding G002
Hours limitation: Backup Generator #2 meets the definition of an Emergency Generator
given in 40 CFR 63 Subpart ZZZZ. Therefore, the permittee must comply with the
requirements specified in 40 CFR 63.6640(f) as well as the limitation of 200 hours per 12-
month period specified in Condition II.B.5.b. These requirements include operating the
Project OPP0106270009 Page 41 Title V Operating Permit #3700029005

emergency generator for a maximum of 100 hours per calendar year for any combination
of the purposes specified in paragraphs (f)(2)(i). Therefore, up to 100 of the 200 hours per
12-month period granted in Condition II.B.5.a may be used for the purposes specified in
paragraphs (f)(2)(i), with any remaining hours being used for emergency use. [Last
updated June 10, 2020]

20. Comment on an item originating in this permit regarding Permitted source
Emission unit terminology: The site terminology for emission units B001, B002, G001,
and G002 was updated to clarify location of equipment at the site. According to the
permittee, B001 and G001 are located in A Plant, and B002 and G002 are located in B
Plant. The 5.231 MMBtu/hr boiler and 292 hp generator are located in A Plant, and should
be labeled as B001 and G001 respectively. The 2.5 MMBtu/hr boiler and 565 hp generator
are located in B Plant, and should be labeled as B002 and G002 respectively. The
equipment has not been moved or changed. This is simply an update to the site
terminology clarifying where the equipment is actually located. [Last updated June 16,
2020]

Source:Northwest Pipeline
Site:Moab CS
Date:
Project #:N10627-0013
AN106270010-10 permit new
change AO
TPY TPY TPY Formaldehy
PM10 4.48 0 4.48 P001 1.76
PM2.5 4.48 0 4.48 P002 1.76
NOx 1066.51 0 1066.51 P003 1.76
CO 177.05 0 177.05 P004 1.76
SOx 1.96 0 1.96 P005 0.12
VOC 49.08 0 49.08 7.16
HAPs 0.06 0 0.06
GHGs 68047.00 68,047 68,047
HAP Title V App 2019 Old AO Total
Acetaldehyde 1.16 0.00 1.16
Acrolein 0.52 0.00 0.52
Benzene 0.28 0.00 0.28
Ethyl Benzene 0.00 0.00 0.00
Formaldehyde 7.16 0.00 7.16
Hexane 0.00 0.00 0.00
Toluene 1.90 0.00 1.90
Xylene 0.09 0.00 0.09
Generic 0.00 0.06 0.06Total11.11 0.06 11.17
HAP's Modeling Existing Increase NewSourceSourceSource
HAP lb/hr lb/hr lb/hr <20m 20-50 50-100 >100 <50 50-100
2,2,4-Trimethylpentane
Vert. Restricted (lb/hr)Vert. Unrestricted
Acetaldehyde 0 1.711554192 2.29709 4.14376 8.10736 6.9363 10.0891616
Acrolein 0 0.008712802 0.01169 0.02109 0.04127 0.03531 0.05135967
Benzene 0 0.0272 0.0351 0.0655 0.1438 0.1054 0.1294
Cobalt 0 0.001 0.0013 0.0025 0.0054 0.004 0.0045
Ethylbenzene 0 22.14 28.66 53.41 116.8 85.97 97.26
Formaldehyde 0 0.014 0.0188 0.0339 0.0663 0.0567 0.0825
Hex. Chromium 0 0.0002 0.0002 0.0004 0.0009 0.0007 0.0008
n-Hexane 0 8.98809816 11.6317 21.6772 47.4078 34.895 39.477137
Methanol 0 14.2007362 18.3774 34.2488 74.9019 55.1323 62.3718609
Naphthalene 0 2.67 3.46 6.45 14.1 10.38 11.74
Nickel 0 0.0017 0.0022 0.0041 0.009 0.0066 0.0081
Toluene 0 3.84 4.97 9.27 20.27 14.92 16.88
Xylene 0 22.14 28.66 53.41 116.8 85.97 97.26
Acetaldehyd Acroline Benzene Toluene Xylenes
0.29 0.13 0.07 0.47 0.02
0.29 0.13 0.07 0.47 0.02
0.29 0.13 0.07 0.47 0.02
0.29 0.13 0.07 0.47 0.02
0 0 0 0.02 0.01
1.16 0.52 0.28 1.9 0.09
Modeling
>100 Required
d (lb/hr)
13.9626789
0.07107812
0.1965
0.0074
159.78
0.1142
0.0012
64.8552965
102.468057
19.29
0.0123
27.73
159.78
Source:Northwest Pipeline
Site:Moab CS
Date:
Project #:N10627-0013
AN106270010-10 new permit
AN AO change
TPY TPY TPY
CO 177.05 0 177.05
N0x 1,066.51 0 1066.51
PM10 4.48 0 4.48
PM2.5 4.48 0 4.48
SOx 1.96 0 1.96
VOC 49.08 0 49.08
HAPs 0.06 0 31.06
GHGs 0 68,074 68074
Grandfathered Existing
HAP TPY TPY
Acetaldehyde 3.01
Acrolein 3.01
Benzene 0.76
Butadiene 0.32
Ethylbenzene 0.05
Formaldahyde 21.49
Hexane 0.25
Methanol 0.96
POM 0.12
Toluene 0.39
2,2,4-TMP 0.33
Xylenes 0.11
Generic 0.26 0.06
Total 31.06 0.06
Total Single
Grandfathered Emissions TPY TPY
Acetaldehyde 3 0.75
Acrolein 3 0.75
Benzene 0.76 0.19
Butadiene 0.32 0.08
Ethylbenzene 0.04 0.01
Formaldahyde 21.36 5.34
Hexane 0.16 0.04
Methanol 0.96 0.24
POM 0.12 0.03
Toluene 0.36 0.09
2,2,4-TMP 0.32 0.08
Xylenes 0.12 0.03
Generic 0.24 0.06
Tad Anderson <[e-mail]>
Moab CS Approval Order
Forsberg, Derek <[e-mail]>Wed, Feb 12, 2025 at 1:59 PM
To: Tad Anderson <[e-mail]>, Jared Crosby <[e-mail]>
Cc: Walter Konkel <[e-mail]>, "Diaz, Cecilia" <[e-mail]>
Hello Tad, I had Walter review. Looks like it’s a rounding issue. Below are the Moab HAP emission rates not considering
rounding. It should be 31.06. Please feel free to reach out to me, Cecilia or Walter with any further questions.

Thanks,
Derek

Derek Forsberg | Williams | Environmental Manager | Salt Lake City Division
Cell: 801-673-1334
[e-mail]

From: Tad Anderson <[e-mail]>
Sent: Wednesday, February 12, 2025 10:58 AM
To: Forsberg, Derek <[e-mail]>; Jared Crosby <[e-mail]>
Subject: [EXTERNAL] Re: Moab CS Approval Order

***CAUTION! EXTERNAL SENDER*** STOP. ASSESS. VERIFY!! If suspicious, STOP and click the Phish Alert Buon
Derek,
[Quoted text hidden]
[Quoted text hidden]
Northwest Pipeline, LLC
650 S. Main Street, Suite 300
Salt Lake City, UT 84101

November 18, 2024

Tad Anderson
Environmental Engineer
Utah Department of Environmental Quality
195 North 1950 West
Salt Lake City, UT 84116

Subject: Request for Administrative Update
Northwest Pipeline LLC
Moab Compressor Station
Approval Order DAQE-AN0106270010-10

Dear Mr. Anderson:
Northwest Pipeline LLC is submitting this letter to request an administrative update to
Approval Order (AO) DAQE-AN0106270010-10 for the Moab Compressor Station in San
Juan County, Utah. The AO has incorrect descriptions for the boilers and generators and
needs updating to match information in Title V Operating Permit #3700029005.
Furthermore, the AO limits operation of each emergency generator engine to a specified
number of hours per rolling 12-month period; however, in accordance with NESHAP
Subpart ZZZZ at §63.6640(f)(1), there is no time limit on the use of emergency stationary
RICE in emergency situations.
Requested changes to the AO shown below are consistent with information in the current
Title V Operating Permit:

II.A.7 Boiler #1 (Unit #B001) 2.5 5.23 MMBtu/hr boiler for comfort heating Fired on pipeline quality natural gas only
II.A.8 Boiler #2 (Unit #B002) 5.23 2.5 MMBtu/hr boiler for comfort heating Fired on pipeline quality natural gas only
II.A.9 Backup Generator #1 (Unit #G001) 565 292 hp emergency backup generator Fired on pipeline quality natural gas only
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
Tad Anderson
Utah Department of Environmental Quality
November 18, 2024
Page 02 of 03

II.A.10 Backup Generator #2 (Unit #G002) New 292 565 hp emergency backup generator Fired on pipeline quality natural gas only
II.B.3 Limits on Backup Generator (Unit #G001) II.B.3.a Hours of operation shall be no greater than 200 500 hours per rolling 12-month period. Records documenting generator usage shall be kept in a monthly log and
they shall show the duration in hours of the generator usage and the reason for the usage. Compliance with the limitation shall be determined on a rolling 12 month total. Based on the first day of each month, a new 12-month total shall be calculated using data from the previous 12 months. Monthly
calculations shall be made no later than 20 days after the end of each calendar month. There is no time limit on the use of emergency stationary RICE in emergency situations.
[R307-401] II.B.4 Limits on Backup Generator (Unit #G002) II.B.4.a Hours of operation shall be no greater than 500 200 hours per rolling 12-
month period. Records documenting generator usage shall be kept in a monthly log and they shall show the duration in hours of the generator usage and the reason
for the usage. Compliance with the limitation shall be determined on a rolling 12 month total. Based on the first day of each month, a new 12-month total shall be calculated using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month.
There is no time limit on the use of emergency stationary RICE in emergency situations. [R307-401]
Additionally, the current AO shows the Moab Compressor Station as an existing minor HAP
source. Again, to be consistent with Title V Operating Permit #3700029005, the revised AO
should reflect the facility as a major HAP source. Detailed potential to emit calculations for
the facility emission sources are attached.

Finally, the source contact listed in the AO should be changed from Matt Armstrong,
Environmental Specialist to Derek Forsberg, Environmental Manager.

Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
Tad Anderson
Utah Department of Environmental Quality
November 18, 2024
Page 03 of 03
If you have any questions concerning this submittal, or need additional information, please
contact me at [phone] or by email at [e-mail]. Thank you for
your assistance in this matter.
Sincerely,
Derek Forsberg
Environmental Manager
Attachments
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
Application for
Approval Order Modification

For the:
Northwest Pipeline, LLC
Moab Compressor Station
Approval Order DAQE-AN0627004-03
San Juan County, Utah

Submitted to:
Utah Department of Environmental Quality
Division of Air Quality
195 North 1950 West
Salt Lake City, UT 84116

Submitted by:
Northwest Pipeline LLC 650 S. Main Street, Suite 300
Salt Lake City, UT 84101

Prepared by:
EcoLogic Environmental Consultants, LLC
864 Windsor Court
Santa Barbara, CA 93111-1037

November 2024

Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13

Northwest Pipeline LLC
Moab Compressor Station
Application for Approval Order Modification
Application for
Approval Order Modification

Northwest Pipeline LLC
Moab Compressor Station

Table of Contents
Cover Letter
Title Page / Table of Contents
Company Information/Notice of Intent (NOI) – Form 2
Potential to Emit Calculations

Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13

Northwest Pipeline LLC
Moab Compressor Station
Application for Approval Order Modification
Company Information/Notice of Intent (NOI) – Form 2

Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
1of 1
Form 2 Date ____________
Company Information/Notice of Intent (NOI)
Utah Division of Air Quality
New Source Review Section
Application for: Ƒ Initial Approval Order Ƒ Approval Order Modification
General Owner and Source Information
1.Company name and mailing address:
____________________________
____________________________
Phone No.: ( )
Fax No.: ( )
2. Company** contact for environmental matters:
____________________________
Phone no.: ( )
Email:_______________________
** Company contact only; consultant or independent contractor contact
information can be provided in a cover letter
3. Source name and physical address (if different from
above):____________________________
____________________________
____________________________
Phone no.: ( )
Fax no.: ( )
4. Source Property Universal Transverse Mercator
coordinates (UTM), including System and Datum:
UTM:_________________________
X:____________________________
Y:____________________________
5. The Source is located in:__________________ County 6.Standard Industrial Classification Code (SIC)
__ __ __ __
7. If request for modification, AO# to be modified: DAQE #__________________ DATED: ____/____/____
8. Brief (50 words or less) description of process.
Electronic NOI
9. A complete and accurate electronic NOI submitted to DAQ Permitting Mangers Jon Black ([e-mail]) or Alan
Humpherys ([e-mail]) can expedite review process. Please mark application type.
Hard Copy Submittal Electronic Copy Submittal Ƒ %RWK
Authorization/Signature
I hereby certify that the information and data submitted in and with this application is completely true, accurate and
complete, based on reasonable inquiry made by me and to the best of my knowledge and belief.
Signature: Title:
_______________________________________
Name (Type or print)
Telephone Number:
( )
Email:
Date:
November 2024
✔
Northwest Pipeline LLC
650 South Main Street, Suite 300
Salt Lake City, UT 84101
[phone]
Derek Forsberg
[phone]
derek.forsberg@williams
Moab Compressor Station
23 miles south of Moab
Highway 191 La Sal Route
San Juan
12
637,160m
4,243,250m
4922
DAQE-AN0106270010-10 08 03 2010
Natural gas transmission compressor station
✔
VP / GM - Northwest Pipeline
Camilo Amezquita
[phone]
[e-mail]
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
11/18/2024 | 6:03 PM CST

Northwest Pipeline LLC
Moab Compressor Station
Application for Approval Order Modification
Potential to Emit Calculations

Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy
P001 na Compressor Engine 01 - Clark TLA-6 1,770 bhp 8,760 61.39 268.89 9.05 39.65 2.65 11.60 0.01 0.06 1.07 4.67
P002 na Compressor Engine 02 - Clark TLA-6 1,770 bhp 8,760 61.39 268.89 9.05 39.65 2.65 11.60 0.01 0.06 1.07 4.67
P003 na Compressor Engine 03 - Clark TLA-6 1,770 bhp 8,760 61.39 268.89 9.05 39.65 2.65 11.60 0.01 0.06 1.07 4.67
P004 na Compressor Engine 04 - Clark TLA-6 1,770 bhp 8,760 61.39 268.89 9.05 39.65 2.65 11.60 0.01 0.06 1.07 4.67
P005 na Compressor Turbine 01 - Solar Centaur 40-4700S 4,354 bhp 8,760 6.28 27.49 4.55 19.93 1.30 5.71 0.16 0.70 0.25 1.08
G001 na Backup Generator - Cummins GTA855 292 bhp 500 4.90 1.23 8.04 2.01 0.07 0.02 1E-03 3E-04 0.02 5E-03
G002 na Backup Generator - CAT G3412 565 bhp 200 10.08 1.01 16.52 1.65 0.14 0.01 3E-03 3E-04 0.09 0.01
B001 na Boiler 01 5.23 MMBtu/hr 8,760 0.51 2.25 0.43 1.89 0.03 0.12 3E-03 0.01 0.04 0.17
B002 na Boiler 02 2.50 MMBtu/hr 8,760 0.25 1.07 0.21 0.90 0.01 0.06 1E-03 0.01 0.02 0.08
SB001 na Salt Bath Heater 0.25 MMBtu/hr 8,760 0.02 0.11 0.02 0.09 1E-03 0.01 1E-04 6E-04 2E-03 0.01
F001 na Process Piping Fugitives 1,600 Units 8,760 ------------0.17 0.76 ------------
267.61 1,109 65.98 185.08 12.33 53.11 0.22 0.95 4.68 20.04
Northwest Pipeline LLC
Moab Compressor Station
Potential to Emit (PTE) - Criteria - Controlled
Potential to Emit (PTE) - Criteria - Controlled
Emission Estimates - Page 01 of 14
VOC (w/HCHO)CONOxhr/yr
Total:
Moab Compressor Station
Site Rating PM10/2.5SO2SourceIDAPCEDescription
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy
P001 na Compressor Engine 01 - Clark TLA-6 1,770 bhp 8,760 0.17 0.75 0.17 0.75 0.04 0.19 0.02 0.08 2E-03 0.01 1.22 5.34 0.01 0.04
P002 na Compressor Engine 02 - Clark TLA-6 1,770 bhp 8,760 0.17 0.75 0.17 0.75 0.04 0.19 0.02 0.08 2E-03 0.01 1.22 5.34 0.01 0.04
P003 na Compressor Engine 03 - Clark TLA-6 1,770 bhp 8,760 0.17 0.75 0.17 0.75 0.04 0.19 0.02 0.08 2E-03 0.01 1.22 5.34 0.01 0.04
P004 na Compressor Engine 04 - Clark TLA-6 1,770 bhp 8,760 0.17 0.75 0.17 0.75 0.04 0.19 0.02 0.08 2E-03 0.01 1.22 5.34 0.01 0.04
P005 na Compressor Turbine 01 - Solar Centaur 40-4700S 4,354 bhp 8,760 1E-03 0.01 2E-04 1E-03 4E-04 2E-03 2E-05 7E-05 1E-03 0.01 0.03 0.12 --- ---
G001 na Backup Generator - Cummins GTA855 292 bhp 500 0.01 2E-03 0.01 1E-03 3E-03 9E-04 1E-03 4E-04 5E-05 1E-05 0.04 0.01 ------
G002 na Backup Generator - CAT G3412 565 bhp 200 0.01 1E-03 0.01 1E-03 0.01 7E-04 3E-03 3E-04 1E-04 1E-05 0.09 0.01 ------
B001 na Boiler 01 5.23 MMBtu/hr 8,760 --- --- --- ---1E-05 5E-05 --- --- --- ---4E-04 2E-03 0.01 0.04
B002 na Boiler 02 2.50 MMBtu/hr 8,760 --- --- --- ---5E-06 2E-05 --- --- --- ---2E-04 8E-04 4E-03 0.02
SB001 na Salt Bath Heater 0.25 MMBtu/hr 8,760 --- --- --- ---5E-07 2E-06 --- --- --- ---2E-05 8E-05 4E-04 2E-03
F001 na Process Piping Fugitives 1,600 Units 8,760 ------------3E-04 1E-03 ------3E-04 1E-03 ------3E-03 0.01
0.71 3.01 0.70 3.01 0.18 0.76 0.08 0.32 0.01 0.05 5.04 21.49 0.06 0.25
lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy lb/hr*tpy
P001 na Compressor Engine 01 - Clark TLA-6 1,770 bhp 8,760 0.05 0.24 0.01 0.03 0.02 0.09 0.02 0.08 0.01 0.03 0.01 0.06 1.76 7.69
P002 na Compressor Engine 02 - Clark TLA-6 1,770 bhp 8,760 0.05 0.24 0.01 0.03 0.02 0.09 0.02 0.08 0.01 0.03 0.01 0.06 1.76 7.69
P003 na Compressor Engine 03 - Clark TLA-6 1,770 bhp 8,760 0.05 0.24 0.01 0.03 0.02 0.09 0.02 0.08 0.01 0.03 0.01 0.06 1.76 7.69
P004 na Compressor Engine 04 - Clark TLA-6 1,770 bhp 8,760 0.05 0.24 0.01 0.03 0.02 0.09 0.02 0.08 0.01 0.03 0.01 0.06 1.76 7.69
P005 na Compressor Turbine 01 - Solar Centaur 40-4700S 4,354 bhp 8,760 --- ---1E-03 0.01 5E-03 0.02 2E-05 7E-05 2E-03 0.01 1E-03 5E-03 0.04 0.17
G001 na Backup Generator - Cummins GTA855 292 bhp 500 0.01 2E-03 5E-04 1E-04 1E-03 3E-04 ------4E-04 1E-04 4E-04 1E-04 0.07 0.02
G002 na Backup Generator - CAT G3412 565 bhp 200 0.01 1E-03 1E-03 1E-04 2E-03 2E-04 ------9E-04 9E-05 8E-04 8E-05 0.14 0.01
B001 na Boiler 01 5.23 MMBtu/hr 8,760 --- ---9E-04 4E-03 2E-05 8E-05 --- --- --- ---6E-06 3E-05 0.01 0.05
B002 na Boiler 02 2.50 MMBtu/hr 8,760 --- ---4E-04 2E-03 8E-06 4E-05 --- --- --- ---3E-06 1E-05 0.01 0.02
SB001 na Salt Bath Heater 0.25 MMBtu/hr 8,760 --- ---4E-05 2E-04 8E-07 4E-06 --- --- --- ---3E-07 1E-06 5E-04 2E-03
F001 na Process Piping Fugitives 1,600 Units 8,760 3E-04 1E-03 ------3E-04 1E-03 3E-04 1E-03 3E-04 1E-03 ------5E-03 0.02
0.24 0.96 0.03 0.12 0.09 0.40 0.08 0.33 0.03 0.12 0.06 0.26 7.30 31.06
Ethylbenzene
Total:
Acetaldehyde AcroleinSourceIDAPCEDescription
Potential to Emit (PTE) - Hazardous Air Pollutants (HAP) - Controlled
Emission Estimates - Page 02 of 14
Xylenes Trace/Other Total HAPPOM/PAH 2,2,4-TMP
Moab Compressor Station
Methanol Toluene
Northwest Pipeline LLC
Moab Compressor Station
Potential to Emit (PTE) - Hazardous Air Pollutants (HAP) - Controlled
Total:
Source
ID APCE Description Site Rating hr/yr*
n-HexaneHCHOSite Rating Butadienehr/yr*Benzene
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
CO2 CO2e CH4 CO2e N2O CO2e
GWP:1 GWP:28 GWP:265
MMBtu/hr tpy tpy tpy tpy tpy tpy lb/hr*tpy
P001 na Compressor Engine 01 - Clark TLA-6 1,770 bhp 8,760 22.08 11,311 11,311 0.21 5.97 0.02 5.65 2,585 11,323
P002 na Compressor Engine 02 - Clark TLA-6 1,770 bhp 8,760 22.08 11,311 11,311 0.21 5.97 0.02 5.65 2,585 11,323
P003 na Compressor Engine 03 - Clark TLA-6 1,770 bhp 8,760 22.08 11,311 11,311 0.21 5.97 0.02 5.65 2,585 11,323
P004 na Compressor Engine 04 - Clark TLA-6 1,770 bhp 8,760 22.08 11,311 11,311 0.21 5.97 0.02 5.65 2,585 11,323
P005 na Compressor Turbine 01 - Solar Centaur 40-4700S 4,354 bhp 8,760 37.28 17,961 17,961 1.41 39.50 0.49 129.81 4,139 18,130
G001 na Backup Generator - Cummins GTA855 292 bhp 500 2.16 74.35 74.35 0.74 20.82 1E-04 0.03 380.81 95.20
G002 na Backup Generator - CAT G3412 565 bhp 200 4.44 51.95 51.95 1E-03 0.03 1E-04 0.03 520.02 52.00
B001 na Boiler 01 5.23 MMBtu/hr 8,760 5.23 2,695 2,695 0.05 1.45 0.05 13.09 618.61 2,710
B002 na Boiler 02 2.50 MMBtu/hr 8,760 2.50 1,288 1,288 0.02 0.69 0.02 6.26 295.70 1,295
SB001 na Salt Bath Heater 0.25 MMBtu/hr 8,760 0.25 128.82 128.82 2E-03 0.07 2E-03 0.63 29.57 129.52
F001 na Process Piping Fugitives 1,600 Units 8,760 ---0.49 0.49 13.19 369.35 --- ---84.44 369.84
140.17 67,446 67,446 16.28 455.78 0.65 172.44 16,409 68,074
Moab Compressor Station
Total:
Northwest Pipeline LLC
Moab Compressor Station
Potential to Emit (PTE) - Greenhouse Gases (GHG) - Controlled
Emission Estimates - Page 03 of 14
Potential to Emit (PTE) - Greenhouse Gases (GHG) - Controlled
Description Site Rating hr/yrSource
ID
TOTALCO2eHeat Input (HHV)APCE
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
Stack Test NOx 15.73 2.78 61.39 268.89 ---15.73 61.39 268.89
Stack Test CO 2.32 0.41 9.05 39.65 ---2.32 9.05 39.65
AP-42 Table 3.2-1 VOC 0.68 0.12 2.65 11.60 ---0.68 2.65 11.60
AP-42 Table 3.2-1 SO2 3.33E-03 5.88E-04 0.01 0.06 ---3E-03 0.01 0.06
AP-42 Table 3.2-1 PM10/2.5 2.73E-01 4.83E-02 1.07 4.67 ---0.27 1.07 4.67
1,770 bhp AP-42 Table 3.2-1 Acetaldehyde 4.39E-02 7.76E-03 0.17 0.75 ---0.04 0.17 0.75
8,760 hr/yr AP-42 Table 3.2-1 Acrolein 4.40E-02 7.78E-03 0.17 0.75 ---0.04 0.17 0.75
AP-42 Table 3.2-1 Benzene 1.10E-02 1.94E-03 0.04 0.19 ---0.01 0.04 0.19
AP-42 Table 3.2-1 Butadiene, 1,3-4.64E-03 8.20E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Ethylbenzene 6.11E-04 1.08E-04 2E-03 0.01 ---6E-04 2E-03 0.01
AP-42 Table 3.2-1 Formaldehyde 3.12E-01 5.52E-02 1.22 5.34 ---0.31 1.22 5.34
745 Exhaust Temp (oF)AP-42 Table 3.2-1 n-Hexane 2.52E-03 4.45E-04 0.01 0.04 ---0.00 0.01 0.04
19,238 Exhaust Flow (acfm)AP-42 Table 3.2-1 Methanol 1.40E-02 2.48E-03 0.05 0.24 ---0.01 0.05 0.24
AP-42 Table 3.2-1 POM/PAH 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
AP-42 Table 3.2-1 Toluene 5.45E-03 9.63E-04 0.02 0.09 ---0.01 0.02 0.09
AP-42 Table 3.2-1 TMP, 2,2,4-4.79E-03 8.46E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Xylenes 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
12,473 Btu/bhp-hr (HHV)AP-42 Table 3.2-1 Other/Trace HAP 3.72E-03 6.57E-04 0.01 0.06 ---4E-03 0.01 0.06
22.08 MMBtu/hr (HHV)Sum Total HAP 0.45 0.08 1.76 7.69 ---0.45 1.76 7.69
21,228 scf/hr 40CFR98 - Table C1 CO2 (GWP=1)661.82 116.98 2,583 11,311 ---661.82 2,583 11,311
185.96 MMscf/yr 40CFR98 - Table C2 CH4 (GWP=28)0.01 2.20E-03 0.05 0.21 ---0.01 0.05 0.21
1,040 Btu/scf (HHV)40CFR98 - Table C2 N2O (GWP=265)1.25E-03 2.20E-04 5E-03 0.02 ---1E-03 5E-03 0.02
Weighted Sum CO2e 662.50 117.10 2,585 11,323 ---662.50 2,585 11,323
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
4 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate. (It does NOT impact the emission estimates.)
Northwest Pipeline LLC
Moab Compressor Station
Compressor Engine (P001) Emissions
Source
ID Description Reference Pollutant
Pre-ControlledEmissions Control
Efficiency
ControlledEmissions
P001
Compressor Engine 01
Dresser-Rand
Clark TLA-6 (2SLB)
Manufactured 1956
NESHAP ZZZZ Affected
3 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Compressor Engine (P001) Emissions
Emission Estimates - Page 04 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
Stack Test NOx 15.73 2.78 61.39 268.89 ---15.73 61.39 268.89
Stack Test CO 2.32 0.41 9.05 39.65 ---2.32 9.05 39.65
AP-42 Table 3.2-1 VOC 0.68 0.12 2.65 11.60 ---0.68 2.65 11.60
AP-42 Table 3.2-1 SO2 3.33E-03 5.88E-04 0.01 0.06 ---3E-03 0.01 0.06
AP-42 Table 3.2-1 PM10/2.5 2.73E-01 4.83E-02 1.07 4.67 ---0.27 1.07 4.67
1,770 bhp AP-42 Table 3.2-1 Acetaldehyde 4.39E-02 7.76E-03 0.17 0.75 ---0.04 0.17 0.75
8,760 hr/yr AP-42 Table 3.2-1 Acrolein 4.40E-02 7.78E-03 0.17 0.75 ---0.04 0.17 0.75
AP-42 Table 3.2-1 Benzene 1.10E-02 1.94E-03 0.04 0.19 ---0.01 0.04 0.19
AP-42 Table 3.2-1 Butadiene, 1,3-4.64E-03 8.20E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Ethylbenzene 6.11E-04 1.08E-04 2E-03 0.01 ---6E-04 2E-03 0.01
AP-42 Table 3.2-1 Formaldehyde 3.12E-01 5.52E-02 1.22 5.34 ---0.31 1.22 5.34
745 Exhaust Temp (oF)AP-42 Table 3.2-1 n-Hexane 2.52E-03 4.45E-04 0.01 0.04 ---0.00 0.01 0.04
19,238 Exhaust Flow (acfm)AP-42 Table 3.2-1 Methanol 1.40E-02 2.48E-03 0.05 0.24 ---0.01 0.05 0.24
AP-42 Table 3.2-1 POM/PAH 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
AP-42 Table 3.2-1 Toluene 5.45E-03 9.63E-04 0.02 0.09 ---0.01 0.02 0.09
AP-42 Table 3.2-1 TMP, 2,2,4-4.79E-03 8.46E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Xylenes 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
12,473 Btu/bhp-hr (HHV)AP-42 Table 3.2-1 Other/Trace HAP 3.72E-03 6.57E-04 0.01 0.06 ---4E-03 0.01 0.06
22.08 MMBtu/hr (HHV)Sum Total HAP 0.45 0.08 1.76 7.69 ---0.45 1.76 7.69
21,228 scf/hr 40CFR98 - Table C1 CO2 (GWP=1)661.82 116.98 2,583 11,311 ---661.82 2,583 11,311
185.96 MMscf/yr 40CFR98 - Table C2 CH4 (GWP=28)0.01 2.20E-03 0.05 0.21 ---0.01 0.05 0.21
1,040 Btu/scf (HHV)40CFR98 - Table C2 N2O (GWP=265)1.25E-03 2.20E-04 5E-03 0.02 ---1E-03 5E-03 0.02
Weighted Sum CO2e 662.50 117.10 2,585 11,323 ---662.50 2,585 11,323
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
4 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate. (It does NOT impact the emission estimates.)
Northwest Pipeline LLC
Moab Compressor Station
Compressor Engine (P002) Emissions
Source
ID Description Reference Pollutant
Pre-ControlledEmissions Control
Efficiency
ControlledEmissions
P002
Compressor Engine 02
Dresser-Rand
Clark TLA-6 (2SLB)
Manufactured 1956
NESHAP ZZZZ Affected
3 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Compressor Engine (P002) Emissions
Emission Estimates - Page 05 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
Stack Test NOx 15.73 2.78 61.39 268.89 ---15.73 61.39 268.89
Stack Test CO 2.32 0.41 9.05 39.65 ---2.32 9.05 39.65
AP-42 Table 3.2-1 VOC 0.68 0.12 2.65 11.60 ---0.68 2.65 11.60
AP-42 Table 3.2-1 SO2 3.33E-03 5.88E-04 0.01 0.06 ---3E-03 0.01 0.06
AP-42 Table 3.2-1 PM10/2.5 2.73E-01 4.83E-02 1.07 4.67 ---0.27 1.07 4.67
1,770 bhp AP-42 Table 3.2-1 Acetaldehyde 4.39E-02 7.76E-03 0.17 0.75 ---0.04 0.17 0.75
8,760 hr/yr AP-42 Table 3.2-1 Acrolein 4.40E-02 7.78E-03 0.17 0.75 ---0.04 0.17 0.75
AP-42 Table 3.2-1 Benzene 1.10E-02 1.94E-03 0.04 0.19 ---0.01 0.04 0.19
AP-42 Table 3.2-1 Butadiene, 1,3-4.64E-03 8.20E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Ethylbenzene 6.11E-04 1.08E-04 2E-03 0.01 ---6E-04 2E-03 0.01
AP-42 Table 3.2-1 Formaldehyde 3.12E-01 5.52E-02 1.22 5.34 ---0.31 1.22 5.34
745 Exhaust Temp (oF)AP-42 Table 3.2-1 n-Hexane 2.52E-03 4.45E-04 0.01 0.04 ---0.00 0.01 0.04
19,238 Exhaust Flow (acfm)AP-42 Table 3.2-1 Methanol 1.40E-02 2.48E-03 0.05 0.24 ---0.01 0.05 0.24
AP-42 Table 3.2-1 POM/PAH 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
AP-42 Table 3.2-1 Toluene 5.45E-03 9.63E-04 0.02 0.09 ---0.01 0.02 0.09
AP-42 Table 3.2-1 TMP, 2,2,4-4.79E-03 8.46E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Xylenes 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
12,473 Btu/bhp-hr (HHV)AP-42 Table 3.2-1 Other/Trace HAP 3.72E-03 6.57E-04 0.01 0.06 ---4E-03 0.01 0.06
22.08 MMBtu/hr (HHV)Sum Total HAP 0.45 0.08 1.76 7.69 ---0.45 1.76 7.69
21,228 scf/hr 40CFR98 - Table C1 CO2 (GWP=1)661.82 116.98 2,583 11,311 ---661.82 2,583 11,311
185.96 MMscf/yr 40CFR98 - Table C2 CH4 (GWP=28)0.01 2.20E-03 0.05 0.21 ---0.01 0.05 0.21
1,040 Btu/scf (HHV)40CFR98 - Table C2 N2O (GWP=265)1.25E-03 2.20E-04 5E-03 0.02 ---1E-03 5E-03 0.02
Weighted Sum CO2e 662.50 117.10 2,585 11,323 ---662.50 2,585 11,323
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
4 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate. (It does NOT impact the emission estimates.)
Northwest Pipeline LLC
Moab Compressor Station
Compressor Engine (P003) Emissions
Source
ID Description Reference Pollutant
Pre-ControlledEmissions Control
Efficiency
ControlledEmissions
P003
Compressor Engine 03
Dresser-Rand
Clark TLA-6 (2SLB)
Manufactured 1956
NESHAP ZZZZ Affected
3 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Compressor Engine (P003) Emissions
Emission Estimates - Page 06 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
Stack Test NOx 15.73 2.78 61.39 268.89 ---15.73 61.39 268.89
Stack Test CO 2.32 0.41 9.05 39.65 ---2.32 9.05 39.65
AP-42 Table 3.2-1 VOC 0.68 0.12 2.65 11.60 ---0.68 2.65 11.60
AP-42 Table 3.2-1 SO2 3.33E-03 5.88E-04 0.01 0.06 ---3E-03 0.01 0.06
AP-42 Table 3.2-1 PM10/2.5 2.73E-01 4.83E-02 1.07 4.67 ---0.27 1.07 4.67
1,770 bhp AP-42 Table 3.2-1 Acetaldehyde 4.39E-02 7.76E-03 0.17 0.75 ---0.04 0.17 0.75
8,760 hr/yr AP-42 Table 3.2-1 Acrolein 4.40E-02 7.78E-03 0.17 0.75 ---0.04 0.17 0.75
AP-42 Table 3.2-1 Benzene 1.10E-02 1.94E-03 0.04 0.19 ---0.01 0.04 0.19
AP-42 Table 3.2-1 Butadiene, 1,3-4.64E-03 8.20E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Ethylbenzene 6.11E-04 1.08E-04 2E-03 0.01 ---6E-04 2E-03 0.01
AP-42 Table 3.2-1 Formaldehyde 3.12E-01 5.52E-02 1.22 5.34 ---0.31 1.22 5.34
745 Exhaust Temp (oF)AP-42 Table 3.2-1 n-Hexane 2.52E-03 4.45E-04 0.01 0.04 ---0.00 0.01 0.04
19,238 Exhaust Flow (acfm)AP-42 Table 3.2-1 Methanol 1.40E-02 2.48E-03 0.05 0.24 ---0.01 0.05 0.24
AP-42 Table 3.2-1 POM/PAH 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
AP-42 Table 3.2-1 Toluene 5.45E-03 9.63E-04 0.02 0.09 ---0.01 0.02 0.09
AP-42 Table 3.2-1 TMP, 2,2,4-4.79E-03 8.46E-04 0.02 0.08 ---5E-03 0.02 0.08
AP-42 Table 3.2-1 Xylenes 1.52E-03 2.68E-04 0.01 0.03 ---2E-03 0.01 0.03
12,473 Btu/bhp-hr (HHV)AP-42 Table 3.2-1 Other/Trace HAP 3.72E-03 6.57E-04 0.01 0.06 ---4E-03 0.01 0.06
22.08 MMBtu/hr (HHV)Sum Total HAP 0.45 0.08 1.76 7.69 ---0.45 1.76 7.69
21,228 scf/hr 40CFR98 - Table C1 CO2 (GWP=1)661.82 116.98 2,583 11,311 ---661.82 2,583 11,311
185.96 MMscf/yr 40CFR98 - Table C2 CH4 (GWP=28)0.01 2.20E-03 0.05 0.21 ---0.01 0.05 0.21
1,040 Btu/scf (HHV)40CFR98 - Table C2 N2O (GWP=265)1.25E-03 2.20E-04 5E-03 0.02 ---1E-03 5E-03 0.02
Weighted Sum CO2e 662.50 117.10 2,585 11,323 ---662.50 2,585 11,323
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
4 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate. (It does NOT impact the emission estimates.)
Northwest Pipeline LLC
Moab Compressor Station
Compressor Engine (P004) Emissions
Source
ID Description Reference Pollutant
Pre-ControlledEmissions Control
Efficiency
ControlledEmissions
P004
Compressor Engine 04
Dresser-Rand
Clark TLA-6 (2SLB)
Manufactured 1956
NESHAP ZZZZ Affected
3 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Compressor Engine (P004) Emissions
Emission Estimates - Page 07 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
Vendor Data NOX 6.28 27.49 ---6.28 27.49
Permit CO 0.47 0.12 4.55 19.93 ---0.47 4.55 19.93
Vendor Data VOC 0.14 0.03 1.30 5.71 ---0.14 1.30 5.71
Vendor Data SO2 0.02 4E-03 0.16 0.70 ---0.02 0.16 0.70
AP-42 Table 3.1-2a PM10/2.5 0.03 0.0066 0.25 1.08 ---0.03 0.25 1.08
4,700 bhp (design)AP-42 Table 3.1-3 *Acetaldehyde 1.55E-04 4.00E-05 1E-03 0.01 ---2E-04 1E-03 0.01
4,354 bhp (site-rating)AP-42 Table 3.1-3 *Acrolein 2.49E-05 6.40E-06 2E-04 1E-03 ---2E-05 2E-04 1E-03
8,760 hr/yr AP-42 Table 3.1-3 Benzene 4.66E-05 1.20E-05 4E-04 2E-03 ---5E-05 4E-04 2E-03
AP-42 Table 3.1-3 Butadiene, 1,3-1.67E-06 4.30E-07 2E-05 7E-05 ---2E-06 2E-05 7E-05
AP-42 Table 3.1-3 Ethylbenzene 1.24E-04 3.20E-05 1E-03 0.01 ---1E-04 1E-03 5E-03
AP-42 Table 3.1-3 *Formaldehyde 2.76E-03 7.10E-04 0.03 0.12 ---3E-03 0.03 0.12
AP-42 Table 3.1-3 n-Hexane --- --- --- --- --- --- --- ---
AP-42 Table 3.1-3 Methanol --- --- --- --- --- --- --- ---
AP-42 Table 3.1-3 POM/PAH 1.35E-04 3.47E-05 1E-03 0.01 ---1E-04 1E-03 0.01
AP-42 Table 3.1-3 Toluene 5.05E-04 1.30E-04 5E-03 0.02 ---5E-04 5E-03 0.02
AP-42 Table 3.1-3 TMP, 2,2,4-1.67E-06 4.30E-07 2E-05 7E-05 ---2E-06 2E-05 7E-05
AP-42 Table 3.1-3 Xylenes 2.49E-04 6.40E-05 2E-03 0.01 ---2E-04 2E-03 0.01
8,562 Btu/bhp-hr (HHV)AP-42 Table 3.1-3 Other/Trace HAP 1.13E-04 2.90E-05 1E-03 5E-03 ---1E-04 1E-03 5E-03
37.28 MMBtu/hr (HHV)Sum Total HAP 4.11E-03 1.06E-03 0.04 0.17 ---4E-03 0.04 0.17
35,880 scf/hr AP-42 Table 3.1-2a CO2 (GWP=1)427.20 110.00 4,101 17,961 ---427.20 4,101 17,961
314.31 MMscf/yr AP-42 Table 3.1-2a CH4 (GWP=28)3.36E-02 8.64E-03 0.32 1.41 ---0.03 0.32 1.41
1,039 Btu/scf (HHV)AP-42 Table 3.1-2a N2O (GWP=265)1.17E-02 3.00E-03 0.11 0.49 ---0.01 0.11 0.49
Weighted Sum CO2e 431.23 111.04 4,139 18,130 ---431.23 4,139 18,130
* = Aldehyde
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr. Actual load and operating hours will be less.
2 - As per vendor specifications, NMNEHC (non-methane/non-ethane hydrocarbons) do NOT include aldehydes. VOC is the sum of NMNEHC, Acetaldehyde, Acrolein, and Formaldehyde.
3 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
Northwest Pipeline LLC
Moab Compressor Station
Compressor Turbine 01 (P005) Emissions
Source
ID Description Reference Pollutant
Pre-ControlledEmissions Control Efficiency
ControlledEmissions
P005
Compressor Turbine 01
Solar Centaur T-4700S
Constructed: 1993
NSPS GG: Affected
4 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene,
1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Compressor Turbine 01 (P005) Emissions
Emission Estimates - Page 08 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
AP-42 Table 3.2-3 NOx 7.62 2.27 4.90 21.48 ---7.62 4.90 1.23
AP-42 Table 3.2-3 CO 12.49 3.72 8.04 35.21 ---12.49 8.04 2.01
AP-42 Table 3.2-3 VOC (w/Aldehydes)0.11 0.03 0.07 0.31 ---0.11 0.07 0.02
AP-42 Table 3.2-3 SO2 1.97E-03 5.88E-04 1E-03 0.01 ---2E-03 1E-03 3E-04
AP-42 Table 3.2-3 PM10/2.5 3.35E-02 9.99E-03 0.02 0.09 ---0.03 0.02 0.01
292 bhp AP-42 Table 3.2-3 Acetaldehyde*9.36E-03 2.79E-03 0.01 0.03 ---0.01 0.01 2E-03
500 hr/yr AP-42 Table 3.2-3 Acrolein*8.83E-03 2.63E-03 0.01 0.02 ---0.01 0.01 1E-03
AP-42 Table 3.2-3 Benzene 5.30E-03 1.58E-03 3E-03 0.01 ---5E-03 3E-03 9E-04
AP-42 Table 3.2-3 Butadiene, 1,3-2.23E-03 6.63E-04 1E-03 0.01 ---2E-03 1E-03 4E-04
AP-42 Table 3.2-3 Ethylbenzene 8.32E-05 2.48E-05 5E-05 2E-04 ---8E-05 5E-05 1E-05
AP-42 Table 3.2-3 Formaldehyde*0.07 2.05E-02 0.04 0.19 ---0.07 0.04 0.01
1,304 Exhaust Temp (oF)AP-42 Table 3.2-3 n-Hexane --- ---------------------
2,700 Exhaust Flow (acfm)AP-42 Table 3.2-3 Methanol 1.03E-02 3.06E-03 0.01 0.03 ---0.01 0.01 2E-03
AP-42 Table 3.2-3 POM/PAH 7.99E-04 2.38E-04 5E-04 2E-03 ---8E-04 5E-04 1E-04
AP-42 Table 3.2-3 Toluene 1.87E-03 5.58E-04 0.00 0.01 ---2E-03 1E-03 3E-04
AP-42 Table 3.2-3 TMP, 2,2,4---- ---------------------
AP-42 Table 3.2-3 Xylenes 6.55E-04 1.95E-04 4E-04 2E-03 ---7E-04 4E-04 1E-04
7,400 Btu/bhp-hr (HHV)AP-42 Table 3.2-3 Other/Trace HAP 6.01E-04 1.79E-04 4E-04 2E-03 ---6E-04 4E-04 1E-04
2.16 MMBtu/hr (HHV)Sum Total HAP 0.11 0.03 0.07 0.31 ---0.11 0.07 0.02
2,118 scf/hr Vendor Data CO2 (GWP=1)462.00 137.64 297 1,303 ---462.00 297 74
1.06 MMscf/yr Vendor Data CH4 (GWP=28)4.62 1.38 2.97 13.03 ---4.62 2.97 0.74
1,020 Btu/scf (HHV)40CFR98 - Table C2 N2O (GWP=265)7.40E-04 2.20E-04 5E-04 2E-03 ---7E-04 5E-04 1E-04
Weighted Sum CO2e 591.56 176.24 381 1,668 ---591.56 381 95
* = Aldehyde
Notes:1 - The Pre-controlled emissions shown are based on operation at 100% of rated load for 8,760 hr/yr. Controlled emissions are based on operation at 100% load for 500 hr/yr.
2 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
4 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate. (It does NOT impact the emission estimates.)
Northwest Pipeline LLC
Moab Compressor Station
Backup Generator Engine (G001) Emissions
Source
ID Description Reference Pollutant
Pre-Controlled
Emissions Control
Efficiency
Controlled
Emissions
G001
Backup Generator Engine 01
Cummins GTA855(4SRB)
Manufactured 1992
NESHAP ZZZZ Affected
3 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene,
1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Backup Generator Engine (G001) Emissions
Emission Estimates - Page 09 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
g/bhp-hr lb/MMBtu lb/hr tpy g/bhp-hr lb/hr tpy
AP-42 Table 3.2-3 NOx 8.09 2.27 10.08 44.15 ---8.09 10.08 1.01
AP-42 Table 3.2-3 CO 13.26 3.72 16.52 72.36 ---13.26 16.52 1.65
AP-42 Table 3.2-3 VOC (w/Aldehydes)0.12 0.03 0.14 0.63 ---0.12 0.14 0.01
AP-42 Table 3.2-3 SO2 2.10E-03 5.88E-04 0.00 0.01 ---2E-03 3E-03 3E-04
AP-42 Table 3.2-3 PM10/2.5 6.92E-02 1.94E-02 0.09 0.38 ---0.07 0.09 0.01
565 bhp AP-42 Table 3.2-3 Acetaldehyde*9.95E-03 2.79E-03 0.01 0.05 ---0.01 0.01 1E-03
200 hr/yr AP-42 Table 3.2-3 Acrolein*9.38E-03 2.63E-03 0.01 0.05 ---0.01 0.01 1E-03
AP-42 Table 3.2-3 Benzene 5.63E-03 1.58E-03 0.01 0.03 ---0.01 0.01 7E-04
AP-42 Table 3.2-3 Butadiene, 1,3-2.36E-03 6.63E-04 3E-03 0.01 ---2E-03 3E-03 3E-04
AP-42 Table 3.2-3 Ethylbenzene 8.84E-05 2.48E-05 1E-04 0.00 ---9E-05 1E-04 1E-05
AP-42 Table 3.2-3 Formaldehyde*7.31E-02 2.05E-02 0.09 0.40 ---0.07 0.09 0.01
936 Exhaust Temp (oF)AP-42 Table 3.2-3 n-Hexane --- ---------------------
3,124 Exhaust Flow (acfm)AP-42 Table 3.2-3 Methanol 1.09E-02 3.06E-03 0.01 0.06 ---0.01 0.01 1E-03
AP-42 Table 3.2-3 POM/PAH 8.49E-04 2.38E-04 1E-03 5E-03 ---8E-04 1E-03 1E-04
AP-42 Table 3.2-3 Toluene 1.99E-03 5.58E-04 2E-03 0.01 ---2E-03 2E-03 2E-04
AP-42 Table 3.2-3 TMP, 2,2,4---- ---------------------
AP-42 Table 3.2-3 Xylenes 6.95E-04 1.95E-04 9E-04 4E-03 ---7E-04 9E-04 9E-05
7,860 Btu/bhp-hr (HHV)AP-42 Table 3.2-3 Other/Trace HAP 6.39E-04 1.79E-04 8E-04 3E-03 ---6E-04 8E-04 8E-05
4.44 MMBtu/hr (HHV)Sum Total HAP 0.12 0.03 0.14 0.63 ---0.12 0.14 0.01
4,270 scf/hr 40CFR98 - Table C1 CO2 (GWP=1)417.05 116.98 519 2,275 ---417.05 519 52
0.85 MMscf/yr 40CFR98 - Table C2 CH4 (GWP=28)0.01 2.20E-03 0.01 0.04 ---0.01 0.01 1E-03
1,040 Btu/scf (HHV)40CFR98 - Table C2 N2O (GWP=265)7.86E-04 2.20E-04 1E-03 4E-03 ---8E-04 1E-03 1E-04
Weighted Sum CO2e 417.48 117.10 520 2,278 ---417.48 520 52
* = Aldehyde
Notes:1 - The Pre-controlled emissions shown are based on operation at 100% of rated load for 8,760 hr/yr. Controlled emissions are based on operation at 100% load for 500 hr/yr.
2 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
4 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate. (It does NOT impact the emission estimates.)
Moab Compressor Station Emission Estimates - Page 10 of 14
Back-up Generator Engine (G002) Emissions
Moab Compressor Station
Northwest Pipeline LLC
ControlledEmissionsSource
ID Description Reference Control
Efficiency
Back-up Generator Engine (G002) Emissions
Pollutant
Pre-ControlledEmissions
3 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
G002
Backup Generator Engine
Caterpillar G3412
(4SRB)
Manufactured 1993
NESHAP ZZZZ Affected
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
lb/MMscf lb/MMBtu lb/hr tpy
NOx 101.96 9.80E-02 0.51 2.25
CO 85.65 8.24E-02 0.43 1.89
NMNEHC 5.61 5.39E-03 0.03 0.12
VOC 5.61 5.39E-03 0.03 0.12
SO2 0.61 5.88E-04 3E-03 0.01
PM10/2.5 7.75 7.45E-03 0.04 0.17
Acetaldehyde --- --- --- ---
Acrolein --- --- --- ---
Benzene 2.14E-03 2.06E-06 1E-05 5E-05
1,3-Butadiene --- --- --- ---
Ethylbenzene --- --- --- ---
5.23 MMBtu/hr (HHV)Formaldehyde 7.65E-02 7.35E-05 4E-04 2E-03
n-Hexane 1.84 1.76E-03 0.01 0.04
Methanol --- --- --- ---
POM/PAH 1.75E-01 1.69E-04 9E-04 4E-03
Toluene 3.47E-03 3.33E-06 2E-05 8E-05
2,2,4-TMP --- --- --- ---
1,040 Btu/scf (HHV)Xylenes --- --- --- ---
Other/Trace HAP 1.22E-03 1.18E-06 6E-06 3E-05
8,760 hr/yr Total HAP 2.09 2.01E-03 0.01 0.05
5,029 scf/hr CO2 (GWP=1)122,353 117.65 615.29 2,695
44.05 MMscf/yr CH4 (GWP=28)2.35 2.25E-03 0.01 0.05
45,815 MMBtu/yr N2O (GWP=265)2.24 2.16E-03 0.01 0.05
CO2e 123,013 118.28 618.61 2,710
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate.
3 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
EPA AP-42 Table 1.4-2
Weighted Sum
4 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Boiler (B001) Emissions
Emission Estimates - Page 11 of 14
B001
Boiler
EPA AP-42 Table 1.4-1
EPA AP-42 Table 1.4-1
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Capacity:
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-4
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Sum
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Northwest Pipeline LLC
Moab Compressor Station
Boiler (B001) Emissions
Source
ID Description Reference Pollutant
EmissionFactor Emissions
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
lb/MMscf lb/MMBtu lb/hr tpy
NOx 101.96 9.80E-02 0.25 1.07
CO 85.65 8.24E-02 0.21 0.90
NMNEHC 5.61 5.39E-03 0.01 0.06
VOC 5.61 5.39E-03 0.01 0.06
SO2 0.61 5.88E-04 1E-03 0.01
PM10/2.5 7.75 7.45E-03 0.02 0.08
Acetaldehyde --- --- --- ---
Acrolein --- --- --- ---
Benzene 2.14E-03 2.06E-06 5E-06 2E-05
1,3-Butadiene --- --- --- ---
Ethylbenzene --- --- --- ---
2.50 MMBtu/hr (HHV)Formaldehyde 7.65E-02 7.35E-05 2E-04 8E-04
n-Hexane 1.84 1.76E-03 0.00 0.02
Methanol --- --- --- ---
POM/PAH 1.75E-01 1.69E-04 4E-04 2E-03
Toluene 3.47E-03 3.33E-06 8E-06 4E-05
2,2,4-TMP --- --- --- ---
1,040 Btu/scf (HHV)Xylenes --- --- --- ---
Other/Trace HAP 1.22E-03 1.18E-06 3E-06 1E-05
8,760 hr/yr Total HAP 2.09 2.01E-03 0.01 0.02
2,404 scf/hr CO2 (GWP=1)122,353 117.65 294.12 1,288
21.06 MMscf/yr CH4 (GWP=28)2.35 2.25E-03 0.01 0.02
21,900 MMBtu/yr N2O (GWP=265)2.24 2.16E-03 0.01 0.02
CO2e 123,013 118.28 295.70 1,295
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate.
3 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
Northwest Pipeline LLC
Moab Compressor Station
Boiler (B002) Emissions
Source
ID Description Reference Pollutant
EmissionFactor Emissions
Capacity:EPA AP-42 Table 1.4-3
B002
Boiler
EPA AP-42 Table 1.4-1
EPA AP-42 Table 1.4-1
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-4
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Sum
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
Weighted Sum
4 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Boiler (B002) Emissions
Emission Estimates - Page 12 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
lb/MMscf lb/MMBtu lb/hr tpy
NOx 101.96 9.80E-02 0.02 0.11
CO 85.65 8.24E-02 0.02 0.09
NMNEHC 5.61 5.39E-03 1E-03 0.01
VOC 5.61 5.39E-03 1E-03 0.01
SO2 0.61 5.88E-04 1E-04 6E-04
PM10/2.5 7.75 7.45E-03 0.00 0.01
Acetaldehyde --- --- --- ---
Acrolein --- --- --- ---
Benzene 2.14E-03 2.06E-06 5E-07 2E-06
1,3-Butadiene --- --- --- ---
Ethylbenzene --- --- --- ---
0.25 MMBtu/hr (HHV)Formaldehyde 7.65E-02 7.35E-05 2E-05 8E-05
n-Hexane 1.84 1.76E-03 4E-04 2E-03
Methanol --- --- --- ---
POM/PAH 1.75E-01 1.69E-04 4E-05 2E-04
Toluene 3.47E-03 3.33E-06 8E-07 4E-06
2,2,4-TMP --- --- --- ---
1,040 Btu/scf (HHV)Xylenes --- --- --- ---
Other/Trace HAP 1.22E-03 1.18E-06 3E-07 1E-06
8,760 hr/yr Total HAP 2.09 2.01E-03 5E-04 2E-03
240 scf/hr CO2 (GWP=1)122,353 117.65 29.41 129
2.11 MMscf/yr CH4 (GWP=28)2.35 2.25E-03 6E-04 2E-03
2,190 MMBtu/yr N2O (GWP=265)2.24 2.16E-03 5E-04 2E-03
CO2e 123,013 118.28 29.57 130
Notes:1 - The emissions shown are based on operation at 100% of rated load for 8,760 hr/yr.
2 - The fuel heating value will vary, 1,020 Btu/scf (HHV) is at the low end of the range and results in a high (conservative) fuel consumption estimate.
3 - PM10/2.5 is filterable and condensable particulate matter; including PM10 and PM2.5
EPA AP-42 Table 1.4-2
Weighted Sum
4 - "Other/Trace HAPs" includes: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, 1,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Phenol, Propylene Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
Moab Compressor Station Salt Bath Heater (SB001) Emissions
Emission Estimates - Page 13 of 14
SB001
Salt Bath Heater
EPA AP-42 Table 1.4-1
EPA AP-42 Table 1.4-1
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Capacity:
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Sum
EPA AP-42 Table 1.4-2
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
EPA AP-42 Table 1.4-3
Northwest Pipeline LLC
Moab Compressor Station
Salt Bath Heater (SB001) Emissions
Source
ID Description Reference Pollutant
EmissionFactor Emissions
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
4.76 Wgt%3.02 Wgt%82.09 Wgt%
120%lb/hr/Unit lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
200 240 9.92E-03 ---2.38 10.43 0.11 0.50 0.07 0.32 1.95 8.56 54.80 240.03
--- ---5.29E-03 --- --- --- --- --- --- --- --- --- --- ---
20 24 1.94E-02 ---0.47 2.04 0.02 0.10 0.01 0.06 0.38 1.67 10.72 46.94
929 1,115 4.41E-04 ---0.49 2.15 0.02 0.10 0.01 0.07 0.40 1.77 11.31 49.55
151 181 8.60E-04 ---0.16 0.68 7E-03 0.03 5E-03 0.02 0.13 0.56 3.59 15.71
33 40 4.41E-03 ---0.17 0.76 8E-03 0.04 0.01 0.02 0.14 0.63 4.02 17.60
TOTAL:1,333 1,600 TOTAL:3.67 16.07 0.17 0.76 0.11 0.49 3.01 13.19 84.44 369.84
PRE-Controlled:0.17 0.76 0.11 0.49 3.01 13.19 84.44 369.84
0.01 Wgt%0.01 Wgt%0.07 Wgt%0.01 Wgt%0.01 Wgt%0.01 Wgt%0.01 Wgt%0.12 Wgt%
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
2E-04 9E-04 2E-04 9E-04 2E-03 7E-03 2E-04 9E-04 2E-04 9E-04 2E-04 9E-04 2E-04 9E-04 3E-03 1E-02
--- --- --- --- --- --- --- --- --- --- --- --- --- --- --- ---
4E-05 2E-04 4E-05 2E-04 3E-04 1E-03 4E-05 2E-04 4E-05 2E-04 4E-05 2E-04 4E-05 2E-04 6E-04 3E-03
4E-05 2E-04 4E-05 2E-04 3E-04 2E-03 4E-05 2E-04 4E-05 2E-04 4E-05 2E-04 4E-05 2E-04 6E-04 3E-03
1E-05 6E-05 1E-05 6E-05 1E-04 5E-04 1E-05 6E-05 1E-05 6E-05 1E-05 6E-05 1E-05 6E-05 2E-04 8E-04
2E-05 7E-05 2E-05 7E-05 1E-04 5E-04 2E-05 7E-05 2E-05 7E-05 2E-05 7E-05 2E-05 7E-05 2E-04 1E-03
TOTAL:3E-04 1E-03 3E-04 1E-03 3E-03 1E-02 3E-04 1E-03 3E-04 1E-03 3E-04 1E-03 3E-04 1E-03 5E-03 0.02
PRE-Controlled:0 0 0 0 3E-03 0.01 0 0 0 0 0 0 0 0 5E-03 0.02
Notes:1 - Assumed 8,760 hours per year of fugitive emissions.
20%
%Total %VOC
1,416 lb/MMscf 1,699 lb/MMscf 3.02% ---
kg/hr lb/hr/unit kg/hr lb/hr/unit kg/hr lb/hr/unit 38,466 lb/MMscf 46,159 lb/MMscf 82.09% ---
Valves 4.5E-03 9.92E-03 2.5E-03 5.51E-03 9.8E-05 2.16E-04 4,744 lb/MMscf 5,693 lb/MMscf --- ---
Pump Seals 2.4E-03 5.29E-03 1.3E-02 2.87E-02 2.4E-05 5.29E-05 2,230 lb/MMscf 2,676 lb/MMscf 4.76%100.00%
Others 8.8E-03 1.94E-02 7.5E-03 1.65E-02 1.4E-02 3.09E-02 46,856 lb/MMscf 56,227 lb/MMscf 100.00% ---
Connectors 2.0E-04 4.41E-04 2.1E-04 4.63E-04 1.1E-04 2.43E-04 ---lb/MMscf 5.00 lb/MMscf 0.01%0.19%
Flanges 3.9E-04 8.60E-04 1.1E-04 2.43E-04 2.9E-06 6.39E-06 ---lb/MMscf 5.00 lb/MMscf 0.01%0.19%
Open-Ended Lines 2.0E-03 4.41E-03 1.4E-03 3.09E-03 2.5E-04 5.51E-04 33.27 lb/MMscf 39.92 lb/MMscf 0.07%1.49%
---lb/MMscf 5.00 lb/MMscf 0.01%0.19%
3 - "Other” components include pressure relief devices (PRD), compressors, diaphragms, drains, meters, etc. ---lb/MMscf 5.00 lb/MMscf 0.01%0.19%
---lb/MMscf 5.00 lb/MMscf 0.01%0.19%
---lb/MMscf 5.00 lb/MMscf 0.01%0.19%
33.27 lb/MMscf 69.92 lb/MMscf 0.12%2.61%
CO2e
CH4 GWP = 28
Northwest Pipeline LLC
Moab Compressor Station
Process Piping and Equipment Leak (F001) Emissions
Source
ID Description
Component (Unit) Type Unit
Count
Safety Multiplier LeakFactor LDAR
Control
Credit
ControlledLeaks
VOC CO2 CH4
(Gas)
F001
Process Piping and
Equipment Leaks (Gas)
Valves
Pump Seals
Other
Connectors
Flanges
Open-ended Lines
Source
ID
Component
(Unit) Type
Benzene Ethylbenzene n-Hexane
F001
Valves
Pump Seals
Other
Connectors
Flanges
Open-ended Lines
Toluene 2,2,4-TMP Xylenes Total HAP
(Gas)
Methanol
5 - The results of a representative Inlet (Wet) Gas Analysis were used to determine the following
worst-case components (See Section VI.b - Lab Data):
2 - Gas/Vapor emissions calculated using EPA Protocol for Equipment Leak Emission Estimates, EPA-453/R-95-017, Nov 1995; Table 2-4, Oil and Gas Production Operations:Minimum Contingency:
Pollutant Inlet (Wet) Gas Worst Case
n-Hexane
Equipment Type Gas Light Liquid Water/Oil CO2
Methane (CH4)
N2/Water/Ethane/Etc
VOC
TOTAL Gas
Benzene
Ethylbenzene
Methanol
Toluene
2,2,4-TMP
4 - LDAR Control Credit from EPA's "Leak Detection and Repair—A Best Practices Guide", EPA-305-D-07-001, October 2007, Table 4-1-Control effectiveness for an LDAR program at a chemical process unit.Xylenes
Total HAP
Moab Compressor Station Process Piping and Equipment Leak (F001) Emissions
Emission Estimates - Page 14 of 14
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
2SLB 4SLB 4SRB Uncontrolled Lean Pre-Mix#
lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
NOx (<90% Load)3.17E+00 4.08E+00 2.27E+00 3.23E-01 9.91E-02
CO (≥ 90% Load)3.86E-01 3.17E-01 3.72E+00 8.23E-02 1.51E-02
VOC (NMNEHC w/o Aldehydes*)4.93E-02 5.17E-02 6.50E-03 2.06E-03 2.06E-03
VOC (NMNEHC w/ Aldehydes*)1.20E-01 1.18E-01 3.24E-02*2.82E-03 2.13E-03
SO2 (2,000 gr-S/MMscf ≈ 0.0007 W%)5.88E-04 5.88E-04 5.88E-04 5.88E-04 5.88E-04
PM10/2.5 (Condensible and Filterable) 4.83E-02 9.99E-03 1.94E-02 6.63E-03 6.63E-03
Acetaldehyde*7.76E-03 8.36E-03 2.79E-03 4.00E-05 4.00E-05
Acrolein*7.78E-03 5.14E-03 2.63E-03 6.40E-06 6.40E-06
Benzene 1.94E-03 4.40E-04 1.58E-03 1.20E-05 9.10E-07
Butadiene, 1,3-8.20E-04 2.67E-04 6.63E-04 4.30E-07 4.30E-07
Ethylbenzene 1.08E-04 3.97E-05 2.48E-05 3.20E-05 3.20E-05
Formaldehyde (HCHO)*5.52E-02 5.28E-02 2.05E-02 7.10E-04 2.00E-05
n-Hexane 4.45E-04 1.11E-03 --- --- ---
Methanol (MeOH)2.48E-03 2.50E-03 3.06E-03 --- ---
Polycyclic Organic Matter (POM/PAH)2.68E-04 3.74E-04 2.38E-04 3.47E-05 3.47E-05
Toluene 9.63E-04 4.08E-04 5.58E-04 1.30E-04 1.30E-04
Trimethylpentane, 2,2,4- (i-Octane)8.46E-04 2.50E-04 --- --- ---
Xylenes 2.68E-04 1.84E-04 1.95E-04 6.40E-05 6.40E-05
Other/Trace HAP**6.57E-04 3.21E-04 1.79E-04 2.90E-05 2.90E-05
TOTAL HAP 7.95E-02 7.22E-02 3.24E-02*1.06E-03 3.57E-04
CO2 (GWP=1)1.10E+02 1.10E+02 1.10E+02 1.10E+02 1.10E+02
CH4 (GWP=28)1.45E+00 1.25E+00 2.30E-01 8.64E-03 8.64E-03
N2O (GWP=265)Use 40CFR98 Use 40CFR98 Use 40CFR98 3.00E-03 3.00E-03
CO2e Use 40CFR98 Use 40CFR98 Use 40CFR98 Use 40CFR98 Use 40CFR98
Industrial Flares Diesel Engines
13.5-1 06/17 3.3-1; 3.3-2 10/96
Uncontrolled LoNOx Burners Flue Gas Recirc Combustion Uncontrolled
lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu lb/MMBtu
NOx (≥ 90% Load)9.80E-02 4.90E-02 3.14E-02 Use Ext. Comb.4.41E+00
CO (≥ 90% Load)8.24E-02 8.24E-02 8.24E-02 3.10E-01 9.50E-01
VOC (NMNEHC w/o Aldehydes*)5.32E-03 5.32E-03 5.32E-03 3.60E-01
VOC (NMNEHC w/ Aldehydes*)5.39E-03 5.39E-03 5.39E-03 3.62E-01
SO2 (2,000 gr-S/MMscf ≈ 0.0007 W%)5.88E-04 5.88E-04 5.88E-04 2.90E-01
PM10/2.5 (Condensible and Filterable) 7.45E-03 7.45E-03 7.45E-03 3.10E-01
Acetaldehyde* --- --- ---7.67E-04
Acrolein* --- --- ---9.25E-05
Benzene 2.06E-06 2.06E-06 2.06E-06 9.33E-04
Butadiene, 1,3- --- --- ---3.91E-05
Ethylbenzene --- --- --- ---
Formaldehyde (HCHO)*7.35E-05 7.35E-05 7.35E-05 1.18E-03
n-Hexane 1.76E-03 1.76E-03 1.76E-03 ---
Methanol (MeOH) --- --- --- ---
Polycyclic Organic Matter (POM/PAH)1.69E-04 1.69E-04 1.69E-04 1.68E-04
Toluene 3.33E-06 3.33E-06 3.33E-06 4.09E-04
Trimethylpentane, 2,2,4- (i-Octane) --- --- --- ---
Xylenes --- --- ---2.85E-04
Other/Trace HAP**1.18E-06 1.18E-06 1.18E-06 ---
TOTAL HAP 2.01E-03 2.01E-03 2.01E-03 3.87E-03
CO2 (GWP=1)1.18E+02 1.18E+02 1.18E+02 1.64E+02
CH4 (GWP=28)2.25E-03 2.25E-03 2.25E-03
N2O (GWP=265)2.16E-03 6.27E-04 6.27E-04
CO2e Use 40CFR98 Use 40CFR98 Use 40CFR98
Weighted Sum
Carbon Dioxide Methane Nitrous Oxide CO2e
lb CO2/MMBtu lb CH4/MMBtu lb N2O/MMBtu lb CO2e/MMBtu
138,000 Btu/gal 1.63E+02 6.61E-03 1.32E-03 1.64E+02
91,000 Btu/gal 1.39E+02 6.61E-03 1.32E-03 1.39E+02
1,026 Btu/scf 1.17E+02 2.20E-03 2.20E-04 1.17E+02
CO2 CH4 N2O
1 28 265
Revised: 11/04/24
GH
G
Attachment B5 - Emission Factors
Natural Gas
Propane
Fuel Oil No. 2 (Diesel)
Table A-1 to Subpart A of Part 98 (amendment published at 89 FR 31894, Apr. 25, 2024)
Global Warming Potential (100 Yr) (GWP)
CR
I
T
E
R
I
A
HA
P
s
GH
G
HA
P
s
Pollutant
Use Ext. Comb.
Use Ext. Comb.
Potentially Applicable
AP-42 and GHG EMISSION FACTORS(Preferentially use test data or vendor data where available)
Pollutant
Natural Gas-Fired Reciprocating Engines Stationary Gas-Fired Turbines
AP-42 Table 3.2-1; 3.2-2; 3.2-3 07/00 AP-42 Table 3.1-1; 3.1-2a; 3.1-3 04/00
Natural Gas (External) Combustion
Use 40CFR98
AP-42 Table 1.4-1; 1.4-2; 1.4-3 (<100 MMBtu/hr) 07/98
Use Ext. Comb.CR
I
T
E
R
I
A
(*AP-42 shows V-HAP>VOC?)(#Lean Pre-Mix - aka: Dry Low Emissions (DLE or DLN) or SoLoNOx)
** Other/Trace HAPs include: Carbon Tetrachloride, Chlorobenzene, Chloroform, Dichloropropene, ,3-Dichloropropene, Ethylene Dibromide, Methylene Chloride, Naphthalene, Phenol, Propylene, Oxide, Styrene, 1,1,2,2-Tetrachloroethane, 1,1,2-Trichloroethane, and Vinyl Chloride (as per AP-42).
* Aldehyde (not measured in EPA Test Method 25)
Fuel Type
40CFR98 - Default Greenhouse Gas (GHG) Emission Factors
Default HHV
Table C-1 to Subpart C of Part 98 Table C-2 to Subpart C of Part 98
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
Sampled:07/13/21 NWP Moab Chromatograph GPSA-Sec 23
Water 109-86-4 H2O 18.015 --- --- --- --- --- --- --- ---
Oxygen 7782-44-7 O2 31.999 --- --- --- --- --- --- --- ---
Carbon Dioxide 124-38-9 CO2 44.010 1.2211 0.5374 1,416.13 3.0223 --- --- --- ---
Hydrogen Sulfide 2148-87-8 H2S 34.086 --- --- --- --- --- ---637.6 ---
Nitrogen 7727-37-9 N2 28.013 1.1485 0.3217 847.85 1.8095 --- --- --- ---
Methane*75-82-8 CH4 16.042 90.9901 14.5971 38,465.73 82.0939 86.2620 ---1,010.0 919.000
Ethane*74-84-0 C2H6 30.069 4.9173 1.4786 3,896.28 8.3155 8.7377 ---1,769.7 87.021
Propane**74-98-6 C3H8 44.096 1.2171 0.5367 1,414.21 3.0182 3.1715 63.4245 2,516.2 30.623
iso-Butane**75-28-5 i-C4H10 58.122 0.1947 0.1132 298.19 0.6364 0.6687 13.3733 3,252.0 6.331
n-Butane**106-97-8 n-C4H10 58.122 0.2161 0.1256 331.01 0.7065 0.7423 14.8453 3,262.4 7.051
iso-Pentane**78-78-4 i-C5H12 72.149 0.0518 0.0374 98.52 0.2103 0.2209 4.4185 4,000.9 2.073
n-Pentane**109-66-0 n-C5H12 72.149 0.0287 0.0207 54.55 0.1164 0.1223 2.4463 4,008.9 1.150
Cyclopentane**287-92-3 C5H10 70.100 --- --- --- --- --- ---3,763.6 ---
Cyclohexane**110-82-7 C6H12 84.162 --- --- --- --- --- ---4,481.6 ---
Other Hexanes**Various C6H14 86.175 --- --- --- --- --- ---4,750.3 ---
Heptanes**142-82-5 C7H16 100.205 --- --- --- --- --- ---5,502.5 ---
Methylcyclohexane**108-87-2 C7H14 98.186 --- --- --- --- --- ---5,215.9 ---
C8+ Heavies**Various C8+138.00 est. --- --- --- --- --- ---7,000.0 ---
Benzene***71-43-2 C6H6 78.112 --- --- --- --- --- ---3,741.9 ---
Ethylbenzene***100-41-4 C8H10 106.165 --- --- --- --- --- ---5,222.0 ---
n-Hexane***110-54-3 C6H14 86.175 0.0147 0.0126 33.27 0.0710 0.0746 1.4920 4,756.0 0.697
Methanol (MeOH)***67-56-1 CH3OH 32.040 --- --- --- --- --- ---866.9 ---
Toluene***108-88-3 C7H8 92.138 --- --- --- --- --- ---4,474.9 ---
2,2,4-Trimethylpentane***540-84-1 C8H18 114.229 --- --- --- --- --- ---6,213.6 ---
Xylenes***1330-20-7 C8H10 106.165 --- --- --- --- --- ---5,208.7 ---
Totals:100.000 17.7809 46,855.74 100.00 --- ---1,054
THC:97.630 16.9218 44,591.76 95.17 100.00 ---
Total VOC:1.723 0.8461 2,229.75 4.76 5.00 100.00
Total HAP:0.015 0.0126 33.27 0.07 0.07 1.49
20%
Mole %Wgt %lb/MMscf Wgt %lb/MMscf % VOC
1.2211 3.022 1,416.13 3.61%1,700.00 --- ---Margin
90.9901 82.094 38,466 90.71%42,750 ---11.1%Margin
6.0658 10.125 4,744 --- --- --- ---Margin
1.7230 4.759 2,229.75 5.69%2,680.00 100.00%20.2%Margin
100.0000 100.000 46,856 100.00%47,130 ---0.59%Margin
--- --- ---0.002%1.00 0.04% ---Margin
--- --- ---0.002%1.00 0.04% ---Margin
0.0147 0.071 33.27 0.085%40.00 1.49% ---Margin
--- --- ---0.002%1.00 0.04% ---Margin
--- --- ---0.002%1.00 0.04% ---Margin
* = Hydrocarbon (HC) --- --- ---0.002%1.00 0.04% ---Margin
** = also Volatile Organic Compound (VOC) --- --- ---0.002%1.00 0.04% ---Margin
*** = also Hazardous Air Pollutant (HAP)0.0147 0.071 33.27 0.098%46.00 1.72% ---Margin
Xylenes***
Total HAP***
CO2
Other (N2, C2, O2, CO, H2O)
Methane*
TOTAL GAS
VOC**
2,2,4-Trimethylpentane***
Toluene***
n-Hexane***
Methanol (MeOH)***
Note: Actual HAP Content is less than Detection Limits.
Northwest Pipeline LLC
Moab Compressor Station
Inlet Gas - Summary
Component CAS Formula Molecular Weight (MW) Mole %(M% = V%)Wgt Sum(MW*MF)lb/MMscf(WS/UGC#)Weight %Total GasBtu/scf (HHV)
Weight %VOC Component Btu/scf (HHV)
Moab Compressor Station
Weight %THC
lb "X"/scf =(M% of "X") x (MW of "X") / #UGC
#UGC (Universal Gas Constant) = 379.482 scf/lb-mol @ 60 oF and 14.6959 psia.
Minimum VOC/HAP Margin:Margin for Changes
in Future Gas Composition
Representative Inlet Gas Analysis Assumed "Worst-Case"
Component
CalculatedBtu/scf
(HHV):
0.00
Ethylbenzene***
Benzene***
Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13

Northwest Pipeline LLC
Moab Compressor Station
Application for Approval Order Modification

** End of Application for Application for
Approval Order Modification **

Docusign Envelope ID: DD199C2A-F522-435E-B500-98D54FDC1E13
Certificate Of Completion
Envelope Id: DD199C2AF522435EB50098D54FDC1E13 Status: Completed
Subject: Complete with Docusign: 20241118_MoabCS_AO-ModificationApplication.pdf
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One Williams Center
Tulsa, OK 74172
[e-mail]
IP Address: 73.6.189.218
Record Tracking
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11/18/2024 4:50:07 PM
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[e-mail]
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[e-mail]
VP/GM Williams NWP
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