DAQ-2025-001136

DAQE-AN104140016-25

{{$d1 }}

Bryan Mansell
Central Valley Water Reclamation Facility
800 West Central Valley Road
Salt Lake City, UT 84119-3379
[e-mail]

Dear Mr. Mansell:

Re: Approval Order: Modification to Approval Order DAQE-AN104140015-21 to Update Engines
Project Number: N104140016

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on May 4,
2023. Central Valley Water Reclamation Facility must comply with the requirements of this AO, all
applicable state requirements (R307), and Federal Standards.

The project engineer for this action is John Persons, who can be contacted at [phone] or
[e-mail]. Future correspondence on this AO should include the engineer's name as well as the
DAQE number shown on the upper right-hand corner of this letter. No public comments were received on
this action.

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:JP:jg

cc: Salt Lake County Health Department
EPA Region 8

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

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

February 21, 2025

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

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

APPROVAL ORDER
DAQE-AN104140016-25
Modification to Approval Order DAQE-AN104140015-21
to Update Engines

Prepared By
John Persons, Engineer
[phone]
[e-mail]

Issued to
Central Valley Water Reclamation Facility - Wastewater Treatment Plant

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

February 21, 2025
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ................................................................................................................... 11
ACRONYMS ............................................................................................................................... 12

DAQE-AN104140016-25
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Central Valley Water Reclamation Facility Central Valley Water Reclamation Facility - Wastewater Treatment Plant

Mailing Address Physical Address
800 West Central Valley Road 800 West Central Valley Road
Salt Lake City, UT 84119-3379 Salt Lake City, UT 84119-3379

Source Contact UTM Coordinates
Name: Bryan Mansell 422600 m Easting
Phone: [phone] 4506500 m Northing
Email: [e-mail] Datum NAD27
UTM Zone 12
SIC code 4952 (Sewerage Systems)

SOURCE INFORMATION
General Description
Central Valley Water Reclamation Facility (CVWRF) employs primary sedimentation tanks, trickling
filters, aeration tanks, secondary sedimentation tanks, and ultraviolet light disinfection. The treated water
is then discharged into Mill Creek. CVWRF also treats the waste materials removed from the water using
anaerobic digesters, which reduces the solids by converting them to water, methane gas, and a residual
called bio-solids. The water is pressed out of the biosolids and returned to the liquid portion of the plant
for treatment. The biosolids are taken and applied to the ground for beneficial agricultural use or
composting. The methane gas is used to fuel engine generators to power the plant. Equipment at the site
consists of digester gas/natural gas-fired engines, emergency generator engines, digester gas flares, small
boilers, and waste oil heaters.

NSR Classification
Minor Modification at Major Source

Source Classification
Located in Northern Wasatch Front O3 NAA, Salt Lake City UT PM2.5 NAA, Salt Lake County SO2
NAA
Salt Lake County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
DAQE-AN104140016-25
Page 4

Combustion Engines
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
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

Project Description
CVWRF requested a modification for:

1- The addition of three (3) 2-MW diesel-fired emergency engines to ensure adequate back-up power in
the event of a power outage.
2- The removal of Waukesha 5 engine, off-site since 2021.
3- Addition of previously permitted Waste Oil Heater emissions.

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)
Ammonia 0 0.17
CO2 Equivalent 621.82 50831.13
Carbon Monoxide -1.81 248.65
Nitrogen Oxides 4.47 68.29
Particulate Matter - PM10 0.20 3.68
Particulate Matter - PM2.5 0.20 2.71
Sulfur Oxides 0.20 0.42
Volatile Organic Compounds -4.49 30.06

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 5140
Acrolein (CAS #107028) 0 3160
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 280
Formaldehyde (CAS #50000) 0 32500
Generic HAPs (CAS #GHAPS) 60 1200
Hexane (CAS #110543) 0 880
Methanol (CAS #67561) 0 1540
Change (TPY) Total (TPY)
Total HAPs 0.03 22.35

DAQE-AN104140016-25
Page 5

SECTION I: GENERAL PROVISIONS

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the five-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of five (5) years. [R307-401-8]
I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]
I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150] I.8 The owner/operator shall submit documentation of the status of construction or modification of Emergency Engines #9-#11 to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO, if construction is discontinued for 18 months or more, or if construction extends beyond the anticipated schedule. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT
II.A THE APPROVED EQUIPMENT
II.A.1 CVWRF Source Wide

II.A.2 JMS Engines #1 and #2 Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines Rating: 2,509 hp (each) Fuel Type: Natural Gas/Digester Gas NSPS Applicability: 40 CFR 60 Subpart JJJJ MACT Applicability: 40 CFR 63 Subpart ZZZZ
DAQE-AN104140016-25
Page 6

II.A.3 JMS Engines #3 and #4 Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines Rating: 2,509 hp (each) Fuel Type: Natural Gas/Digester Gas NSPS Applicability: 40 CFR 60 Subpart JJJJ MACT Applicability: 40 CFR 63 Subpart ZZZZ II.A.4 H2S Removal Vessel
H2S removal vessel upstream of the engines used to treat digester gas.
II.A.5 Emergency Generator Engines #2 and #3 Rating: 896 hp each Quantity: 2 Fuel: Diesel NSPS Applicability: None MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.6 Emergency Generator Engine #4
Rating: 349 hp Quantity: 1
Fuel: Diesel
NSPS Applicability: None MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.7 Emergency Generator Engines #5 and #6 Rating: 800 hp each Quantity: 2 Fuel: Diesel Manufacture Date: 2016 NSPS Applicability: 40 CFR 60 Subpart IIII MACT Applicability: 40 CFR 63 Subpart ZZZZ II.A.8 Emergency Generator Engines #7 and #8
Rating: 1,341 hp each
Quantity: 2 Fuel: Diesel
Manufacture Date: 2015
NSPS Applicability: 40 CFR 60 Subpart IIII MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.9 Three (3) Waste Oil Heaters Rating: 0.28, 0.33, and 0.35 MMBtu/hr each Fuel: Used Oil
II.A.10 Two (2) Digester Gas Flares
Fuel Type: Digester Gas

II.A.11 Boiler #1 Rating: 6.05 MMBtu/hr Fuel: Natural Gas NSPS Applicability: None MACT Applicability: None
DAQE-AN104140016-25
Page 7

II.A.12 Boiler #2 Rating: 6.28 MMBtu/hr Fuel: Natural Gas NSPS Applicability: None MACT Applicability: None II.A.13 Emergency Engines #9, #10, and #11 (NEW) Fuel: Diesel
Rating: 2,680 hp or 6,000 kW Each NSPS Applicability: Subpart IIII
MACT Applicability: Subpart ZZZZ

SECTION II: SPECIAL PROVISIONS
II.B REQUIREMENTS AND LIMITATIONS
II.B.1 Site Wide Requirements
II.B.1.a Visible emissions from the following emission points shall not exceed the following values:

A. Digester Gas/Natural Gas Engines - 10% opacity
B. Diesel Generators - 20% opacity
C. Boilers - 10% opacity

D. Fugitive Emissions - 15% opacity
E. Digester Gas Flare - 10% opacity.
[R307-401-8]

II.B.1.a.1 Opacity observations of emissions shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8]
II.B.1.b The owner/operator shall not allow the NOx emissions from the operation of all non-emergency
engines at the plant to exceed 0.648 tons per day. [R307-401-8, SIP Section IX.H.2]
II.B.1.b.1 The owner/operator shall demonstrate compliance with the emission limitation by summing the emissions from all the non-emergency engines. [R307-401-8, SIP Section IX.H.2]
II.B.2 Waukesha Digester Gas/Natural Gas Engines Requirements
II.B.2.a The owner/operator shall use only natural gas and/or digester gas as fuel in all Waukesha and JMS generator engines. [R307-401-8]
II.B.2.b The owner/operator shall limit emissions from all Waukesha and JMS generator engines to 53
tons of NOx per rolling 12-month period. [R307-401-8]
DAQE-AN104140016-25
Page 8

II.B.2.b.1 The owner/operator shall determine compliance with a rolling 12-month total by calculating a new 12-month total using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month. The owner/operator shall demonstrate compliance with the rolling 12-month limit by using the following equation for each engine and the appropriate conversion factors: NOx = [Emission rate of engine] x [Hours of operation of engine] [R307-401-8] II.B.2.b.2 Records of hours of operation shall be kept for all periods when the engines are in operation.
Continuous recording is required. Records shall be kept on a daily basis. [R307-401-8]
II.B.2.b.3 The owner/operator shall use the most recent stack test data as the emission rates for the rolling 12-month total calculations. Emission rates for the JMS engines shall be measured as required in II.B.3.a. The most recent stack test data shall be used to determine compliance with the rolling 12-month NOx limit. For the period between installation and the initial stack test, the NOx emission limit in II.B.3.a shall be used. A stack test of the Waukesha engine shall be conducted on an annual basis for as long as the engine remains in operation. Testing shall be performed in accordance with the requirements in II.B.3.a.2 through II.B.3.a.5 and II.B.3.a.8 through II.B.3.a.11 of this AO. The source may be tested at any time if directed by the Director. [R307-401-8] II.B.3 JMS Digester Gas/Natural Gas Engines Requirements
II.B.3.a Emissions to the atmosphere from each of the natural gas/digester gas fired engines shall not exceed the following rates: Source: Digester Gas/Natural Gas Engines (Each Stack) Pollutant Limit (g/bhp-hr) NOx 0.55 CO 2.50 VOCs (NMHC) 0.3 [R307-401-8]
DAQE-AN104140016-25
Page 9

II.B.3.a.1 Frequency Emission Point Pollutant Status Test Frequency JMS Engine #1 NOx * + CO * + VOC * + JMS Engine #2 NOx * + CO * + VOC * + JMS Engine #3 NOx * + CO * + VOC * + JMS Engine #4 NOx * + CO * + VOC * + * Initial compliance testing was required and completed. + Test every three (3) years. The Director may require testing at any time. [R307-401-8] II.B.3.a.2 Notification
The Director shall be notified at least 30 days prior to conducting any required emission testing.
A source test protocol shall be submitted to DAQ when the testing notification is submitted to the Director. The source test protocol shall be approved by the Director prior to performing the
test(s). The source test protocol shall outline the proposed test methodologies, stack(s) to be
tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. [R307-401-8]

II.B.3.a.3 Sample Location The sampling location shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other methods as approved by EPA and acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. [R307-401-8]
II.B.3.a.4 Volumetric Flow Rate Test Methods
40 CFR 60, Appendix A, Method 2, or other EPA-approved testing methods acceptable to the Director. [R307-401-8]

II.B.3.a.5 NOx Test Methods 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D, 7E, or other EPA-approved testing methods acceptable to the Director. [R307-401-8]
II.B.3.a.6 CO Test Methods
40 CFR 60, Appendix A, Method 10, or other EPA-approved testing methods acceptable to the
Director. [R307-401-8]

II.B.3.a.7 VOC Test Method 40 CFR 60, Appendix A, Method 18, or other EPA-approved testing methods acceptable to the Director. [R307-401-8]
DAQE-AN104140016-25
Page 10

II.B.3.a.8 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. [R307-401-8] II.B.3.a.9 New Source Operation For a new source/emission point, the production rate during all compliance testing shall be no
less than 90% of the production rate listed in this AO. If the maximum AO allowable production rate has not been achieved at the time of the test, the following procedure shall be followed:
1) Testing shall be at no less than 90% of the production rate achieved to date 2) If the test is passed, the new maximum allowable production rate shall be 110% of the tested
achieved rate, but not more than the maximum allowable production rate. This new allowable maximum production rate shall remain in effect until successfully tested at a higher rate

3) The owner/operator shall request a higher production rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum production rate (110% of the
new rate) will then be allowed if the test is successful. This process may be repeated until the
maximum AO production rate is achieved.
[R307-401-8]

II.B.3.a.10 Existing Source Operation For an existing source/emission point, the production rate during all compliance testing shall be no less than 90% of the maximum production achieved in the previous three (3) years. [R307-401-8]
II.B.3.a.11 The results of stack testing shall be submitted to the Director within 60 days of completion of the
testing. Reports shall clearly identify results as compared to permit limits and indicate compliance status. [R307-401-8]

II.B.4 Emergency Generator Engines Requirements
II.B.4.a The owner/operator shall not test Emergency #9 - #11 concurrently or when any other emergency engine is being tested. [R307-401-8, R307-410-4]

II.B.4.b The owner/operator shall not exceed 52 tests per engine for Emergency Engines #9 - #11 per rolling 12-month period. [R307-401-8, R307-410-4]
II.B.4.c Each emergency generator engine shall not exceed 100 hours of operation for testing and
maintenance per rolling 12-month period. The 100 hours of operation for testing and maintenance purposes may include up to 50 hours per calendar year for operation in
nonemergency situations as provided in 40 CFR 60.4211(f). [R307-401-8]

II.B.4.c.1 Compliance with the limit of the hours of operation shall be determined by installation of an hour meter on the emergency generator engine. Records documenting the operation of the emergency generator engine shall be kept in a log and shall include the following: A. The date the emergency generator engine was used; B. The duration of operation each day in hours; and C. The reason for the emergency generator engine usage. [R307-401-8]
DAQE-AN104140016-25
Page 11

II.B.4.c.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. [R307-401-8] II.B.4.c.3 Records of hours of operation shall be determined by installing a non-resettable hour meter for
the emergency generator engine. [40 CFR 63 Subpart ZZZZ]
II.B.5 Fuel Requirements II.B.5.a The owner/operator shall only use diesel fuel (fuel oil #1, #2, or diesel fuel oil additives) in the
emergency generator engines. All diesel burned shall meet the definition of ultra-low sulfur diesel (ULSD), and contain no more than 15 ppm sulfur. [R307-401-8]
II.B.5.a.1 To demonstrate compliance with the diesel fuel requirements for any diesel fuel purchased, the owner/operator shall keep and maintain fuel purchase invoices. The fuel purchase invoices shall indicate that the diesel fuel meets the ULSD requirements, or the owner/operator shall obtain certification of sulfur content from the fuel supplier. [R307-401-8]
PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN104140015-21 dated July 2, 2021 Is Derived From NOI dated May 4, 2023 Incorporates Additional Information dated July 7, 2023 Incorporates Additional Information dated January 4, 2024 Incorporates Additional Information dated June 13, 2024

DAQE-AN104140016-25
Page 12

ACRONYMS

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

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

DAQE-IN104140016-24

January 9, 2025

Bryan Mansell
Central Valley Water Reclamation Facility
800 West Central Valley Road
Salt Lake City, UT 84119-3379
[e-mail]

Dear Mr. Mansell:

Re: Intent to Approve: Modification to Approval Order DAQE-AN104140015-21 to Update Engines
Project Number: N104140016

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

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

Sincerely,

{{$s }}

Jon L. Black, Manager
New Source Review Section

JLB:JP:jg

cc: Salt Lake County Health Department
EPA Region 8

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

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

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

INTENT TO APPROVE
DAQE-IN104140016-24
Modification to Approval Order DAQE-AN104140015-21
to Update Engines

Prepared By
John Persons, Engineer
[phone]
[e-mail]

Issued to
Central Valley Water Reclamation Facility - Wastewater Treatment Plant

Issued On
January 9, 2025

{{$s }}

New Source Review Section Manager
Jon L. Black
{{#s=Sig_es_:signer1:signature}}
* ) ' & — ) F v A ? A D @ C w D E ˜

TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
PUBLIC NOTICE STATEMENT............................................................................................... 5
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 8
PERMIT HISTORY ................................................................................................................... 12
ACRONYMS ............................................................................................................................... 13

DAQE-IN104140016-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Central Valley Water Reclamation Facility Central Valley Water Reclamation Facility - Wastewater Treatment Plant

Mailing Address Physical Address
800 West Central Valley Road 800 W Central Valley Road
Salt Lake City, UT 84119-3379 Salt Lake City, UT 84119-3379

Source Contact UTM Coordinates
Name: Bryan Mansell 422600 m Easting
Phone: [phone] 4506500 m Northing
Email: [e-mail] Datum NAD27
UTM Zone 12
SIC code 4952 (Sewerage Systems)

SOURCE INFORMATION
General Description
The Central Valley Water Reclamation Facility (CVWRF) employs primary sedimentation tanks,
trickling filters, aeration tanks, secondary sedimentation tanks, and ultraviolet light disinfection. The
treated water is then discharged into Mill Creek. CVWRF also treats the waste materials removed from
the water using anaerobic digesters, which reduces the solids by converting them to water, methane gas,
and a residual called bio-solids. The water is pressed out of the bio-solids and returned to the liquid
portion of the plant for treatment. The bio-solids are taken and applied to the ground for beneficial
agricultural use or composting. The methane gas is used to fuel engine generators to power the plant.
Equipment at the site consists of digester gas/natural gas-fired engines, emergency generator engines,
digester gas flares, small boilers, and waste oil heaters.
NSR Classification
Minor Modification at Major Source

Source Classification
Located in Northern Wasatch Front O3 NAA, Salt Lake City UT PM2.5 NAA, Salt Lake County SO2
NAA
Salt Lake County
Airs Source Size: A

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal
Combustion Engines
DAQE-IN104140016-24
Page 4

NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
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

Project Description
CVWRF requested a modification for:

1- The addition of three (3) 2-MW diesel-fired emergency engines to ensure adequate backup power in
the event of a power outage.
2- The removal of the Waukesha 5 engine, off-site since 2021.
3- Addition of previously permitted Waste Oil Heater emissions.

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)
Ammonia 0 0.17
CO2 Equivalent 621.82 50831.13
Carbon Monoxide -1.81 248.65
Nitrogen Oxides 4.47 68.29
Particulate Matter - PM10 0.20 3.68
Particulate Matter - PM2.5 0.20 2.71
Sulfur Oxides 0.20 0.42
Volatile Organic Compounds -4.49 30.06

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 5140
Acrolein (CAS #107028) 0 3160
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 280
Formaldehyde (CAS #50000) 0 32500
Generic HAPs (CAS #GHAPS) 60 1200
Hexane (CAS #110543) 0 880
Methanol (CAS #67561) 0 1540
Change (TPY) Total (TPY)
Total HAPs 0.03 22.35

DAQE-IN104140016-24
Page 5

PUBLIC NOTICE STATEMENT
The NOI for the above-referenced project has been evaluated and has been found to be consistent with the requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be constructed, installed, established, or modified prior to the issuance of an AO by the Director. A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the intent to approve will be published in the Salt Lake Tribune and Deseret News on January 12, 2025. During the public comment period the proposal and the evaluation of its impact on air quality will be available for the public to review and provide comment. If anyone so requests a public hearing within 15 days of publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as close as practicable to the location of the source. Any comments received during the public comment period and the hearing will be evaluated. The proposed conditions of the AO may be changed as a result of the comments received.

SECTION I: GENERAL PROVISIONS

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

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401]
I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the five-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of five (5) years. [R307-401-8]
I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]
I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]
DAQE-IN104140016-24
Page 6

I.8 The owner/operator shall submit documentation of the status of construction or modification of Emergency Engines #9-#11 to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO, if construction is discontinued for 18 months or more, or if construction extends beyond the anticipated schedule. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO.
II.A THE APPROVED EQUIPMENT II.A.1 Wastewater Treatment Plant Source Wide
II.A.2 JMS Engines #1 & #2 Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines Rating: 2,509 hp (each) Fuel Type: Natural Gas/Digester Gas NSPS Applicability: 40 CFR 60 Subpart JJJJ MACT Applicability: 40 CFR 63 Subpart ZZZZ II.A.3 JMS Engines #3 & #4 Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines Rating: 2,509 hp (each) Fuel Type: Natural Gas/Digester Gas NSPS Applicability: 40 CFR 60 Subpart JJJJ MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.4 H2S Removal Vessel H2S removal vessel upstream of the engines used to treat digester gas. II.A.5 Emergency Generator Engines #2 & #3 Rating: 896 hp each Quantity: Two (2) Fuel: Diesel NSPS Applicability: None MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.6 Emergency Generator Engines #4 Rating: 349 hp Quantity: 1 Fuel: Diesel NSPS Applicability: None MACT Applicability: 40 CFR 63 Subpart ZZZZ
DAQE-IN104140016-24
Page 7

II.A.7 Emergency Generator Engines #5 and #6 Rating: 800 hp each Quantity: 2 Fuel: Diesel Manufacture Date: 2016 NSPS Applicability: 40 CFR 60 Subpart IIII MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.8 Emergency Generator Engines #7 and #8 Rating: 1,341 hp each Quantity: 2
Fuel: Diesel Manufacture Date: 2015 NSPS Applicability: 40 CFR 60 Subpart IIII
MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.9 Three (3) Waste Oil Heaters Rating: 0.28, 0.33, and 0.35 MMBtu/hr each Fuel: Used Oil
II.A.10 Two (2) Digester Gas Flares
Fuel Type: Digester Gas
II.A.11 Boiler #1 Rating: 6.05 MMBtu/hr Fuel: Natural Gas NSPS Applicability: None MACT Applicability: None II.A.12 Boiler #2
Rating: 6.28 MMBtu/hr
Fuel: Natural Gas NSPS Applicability: None
MACT Applicability: None

II.A.13 Emergency Engines #9-#11 (NEW) Fuel: Diesel Rating: 2,680 hp or 6,000 kW each NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ

DAQE-IN104140016-24
Page 8

SECTION II: SPECIAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO. II.B REQUIREMENTS AND LIMITATIONS II.B.1 Site Wide Requirements
II.B.1.a Visible emissions from the following emission points shall not exceed the following values: A. Digester Gas/Natural Gas Engines - 10% opacity B. Diesel Generators - 20% opacity C. Boilers - 10% opacity D. Fugitive Emissions - 15% opacity E. Digester Gas Flare - 10% opacity. [R307-401-8] II.B.1.a.1 Opacity observations of emissions shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8]
II.B.1.b The owner/operator shall not allow the NOx emissions from the operation of all non-emergency engines at the plant to exceed 0.648 tons per day. [R307-401-8, SIP Section IX.H.2] II.B.1.b.1 The owner/operator shall demonstrate compliance with the emission limitation by summing the emissions from all the non-emergency engines. [R307-401-8, SIP Section IX.H.2]
II.B.2 Waukesha Digester Gas/Natural Gas Engines Requirements II.B.2.a The owner/operator shall use only natural gas and/or digester gas as fuel in all Waukesha and JMS generator engines. [R307-401-8]
II.B.2.b The owner/operator shall limit emissions from all Waukesha and JMS generator engines to 53 tons of NOx per rolling 12-month period. [R307-401-8] II.B.2.b.1 The owner/operator shall determine compliance with a rolling 12-month total by calculating a new 12-month total using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month. The owner/operator shall demonstrate compliance with the rolling 12-month limit by using the following equation for each engine and the appropriate conversion factors: NOx = [Emission rate of engine] x [Hours of operation of engine]. [R307-401-8]
II.B.2.b.2 Records of hours of operation shall be kept for all periods when the engines are in operation. Continuous recording is required. Records shall be kept on a daily basis. [R307-401-8]
DAQE-IN104140016-24
Page 9

II.B.2.b.3 The owner/operator shall use the most recent stack test data as the emission rates for the rolling 12-month total calculations. Emission rates for the JMS engines shall be measured as required in II.B.3.a. The most recent stack test data shall be used to determine compliance with the rolling 12-month NOx limit. For the period between installation and the initial stack test, the NOx emission limit in II.B.3.a shall be used. A stack test of the Waukesha engine shall be conducted on an annual basis for as long as the engine remains in operation. Testing shall be performed in accordance with the requirements in II.B.3.a.2 through II.B.3.a.5 and II.B.3.a.8 through II.B.3.a.11 of this AO. The source may be tested at any time if directed by the Director. [R307-401-8] II.B.3 JMS Digester Gas/Natural Gas Engines Requirements
II.B.3.a Emissions to the atmosphere from each of the natural gas/digester gas-fired engines shall not exceed the following rates: Source: Digester Gas/Natural Gas Engines (Each Stack) Pollutant Limit (g/bhp-hr) NOx 0.55 CO 2.50 VOCs (NMHC) 0.3 [R307-401-8] II.B.3.a.1 Frequency
Emission Point Pollutant Status Test Frequency
JMS Engine #1 NOx * + CO * +
VOC * +
JMS Engine #2 NOx * +
CO * +
VOC * +
JMS Engine #3 NOx * +
CO * + VOC * +

JMS Engine #4 NOx * + CO * +
VOC * +

* Initial compliance testing was required and completed.
+ Test every three (3) years. The Director may require testing at any time.

[R307-401-8]

DAQE-IN104140016-24
Page 10

II.B.3.a.2 Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ when the testing notification is submitted to the Director. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack(s) to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. [R307-401-8]
II.B.3.a.3 Sample Location The sampling location shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other methods as approved by EPA and acceptable to the Director. An
Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. [R307-401-8]
II.B.3.a.4 Volumetric Flow Rate Test Methods 40 CFR 60, Appendix A, Method 2, or other EPA-approved testing methods acceptable to the Director. [R307-401-8]
II.B.3.a.5 NOx Test Methods 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D, 7E, or other EPA-approved testing methods
acceptable to the Director. [R307-401-8]

II.B.3.a.6 CO Test Methods 40 CFR 60, Appendix A, Method 10, or other EPA-approved testing methods acceptable to the Director. [R307-401-8] II.B.3.a.7 VOC Test Method
40 CFR 60, Appendix A, Method 18, or other EPA-approved testing methods acceptable to the
Director. [R307-401-8]
II.B.3.a.8 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. [R307-401-8] II.B.3.a.9 New Source Operation
For a new source/emission point, the production rate during all compliance testing shall be no
less than 90% of the production rate listed in this AO. If the maximum AO allowable production rate has not been achieved at the time of the test, the following procedure shall be followed:

1) Testing shall be at no less than 90% of the production rate achieved to date.
2) If the test is passed, the new maximum allowable production rate shall be 110% of the tested
achieved rate, but not more than the maximum allowable production rate. This new allowable
maximum production rate shall remain in effect until successfully tested at a higher rate.

3) The owner/operator shall request a higher production rate when necessary. Testing at no less
than 90% of the higher rate shall be conducted. A new maximum production rate (110% of the
new rate) will then be allowed if the test is successful. This process may be repeated until the
maximum AO production rate is achieved.

[R307-401-8]

DAQE-IN104140016-24
Page 11

II.B.3.a.10 Existing Source Operation For an existing source/emission point, the production rate during all compliance testing shall be no less than 90% of the maximum production achieved in the previous three (3) years. [R307-401-8]
II.B.3.a.11 The results of stack testing shall be submitted to the Director within 60 days of completion of the testing. Reports shall clearly identify results as compared to permit limits and indicate compliance status. [R307-401-8]

II.B.4 Emergency Generator Engines Requirements II.B.4.a The owner/operator shall not test Emergency #9-#11 concurrently or when any other emergency engine is being tested. [R307-401-8, R307-410-4]

II.B.4.b The owner/operator shall not exceed 52 tests per engine for emergency engines #9-#11 per rolling 12-month period. [R307-401-8, R307-410-4]
II.B.4.c Each emergency generator engine shall not exceed 100 hours of operation for testing and maintenance per rolling 12-month period. The 100 hours of operation for testing and
maintenance purposes may include up to 50 hours per calendar year for operation in
nonemergency situations as provided in 40 CFR 60.4211(f). [R307-401-8]
II.B.4.c.1 Compliance with the limit of the hours of operation shall be determined by installation of an hour meter on the emergency generator engine. Records documenting the operation of the emergency generator engine shall be kept in a log and shall include the following: A. The date the emergency generator engine was used; B. The duration of operation each day in hours; and C. The reason for the emergency generator engine usage. [R307-401-8] II.B.4.c.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the twentieth day of each month using data from the previous 12 months.
[R307-401-8]
II.B.4.c.3 Records of hours of operation shall be determined by installing a non-resettable hour meter for the emergency generator engine. [40 CFR 63 Subpart ZZZZ] II.B.5 Fuel Requirements
II.B.5.a The owner/operator shall only use diesel fuel (fuel oil #1, #2, or diesel fuel oil additives) in the emergency generator engines. All diesel burned shall meet the definition of ultra-low sulfur diesel (ULSD) and contain no more than 15 ppm sulfur. [R307-401-8]
II.B.5.a.1 To demonstrate compliance with the diesel fuel requirements for any diesel fuel purchased, the
owner/operator shall keep and maintain fuel purchase invoices. The fuel purchase invoices shall
indicate that the diesel fuel meets the ULSD requirements, or the owner/operator shall obtain
certification of sulfur content from the fuel supplier. [R307-401-8]

DAQE-IN104140016-24
Page 12

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN104140015-21 dated July 2, 2021 Is Derived From NOI dated May 4, 2023 Incorporates Additional Information dated July 7, 2023 Incorporates Additional Information dated January 4, 2024 Incorporates Additional Information dated June 13, 2024

DAQE-IN104140016-24
Page 13

ACRONYMS

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

40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by 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

The Salt Lake Tribune
Publication Name:
The Salt Lake Tribune
Publication URL:
Publication City and State:
Salt Lake City, UT
Publication County:
Salt Lake
Notice Popular Keyword Category:
Notice Keywords:
Water Reclamation Facility
Notice Authentication Number:
202501131013507313680
2892905420
Notice URL:
Back
Notice Publish Date:
Sunday, January 12, 2025
Notice Content
NOTICE A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been
received for consideration by the Director: Company Name: Central Valley Water Reclamation Facility Location: Central Valley Water
Reclamation Facility - Wastewater Treatment Plant – 800 West Central Valley Road, Salt Lake City, UT Project Description: The Central Valley
Water Reclamation Facility (CVWRF) employs primary sedimentation tanks, trickling filters, aeration tanks, secondary sedimentation tanks,
and ultraviolet light disinfection to treat wastewater. CVWRF has requested a modification for the addition of new diesel-fired emergency
generators, which will result in an increased potential to emit of combustion pollutants. Emission reductions will result from improvements to
decrease phosphorus effluent and the removal of an old engine. The completed engineering evaluation and air quality impact analysis showed
the proposed project meets the requirements of federal air quality regulations and the State air quality rules. The Director intends to issue an
Approval Order pending a 30-day public comment period. The project proposal, estimate of the effect on local air quality and draft Approval
Order are available for public inspection and comment at the Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116.
Written comments received by the Division at this same address on or before February 11, 2025, will be considered in making the final
decision on the approval/disapproval of the proposed project. Email comments will also be accepted at [e-mail]. If anyone so
requests to the Director in writing within 15 days of publication of this notice, a hearing will be held in accordance with R307-401-7, UAC.
Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or argument during an adjudicatory
proceeding that was raised during the public comment period and was supported with sufficient information or documentation to enable the
Director to fully consider the substance and significance of the issue. Date of Notice: January 12, 2025 SLT0031045
Back

DAQE-NN104140016-24

January 9, 2025

Salt Lake Tribune and Deseret News
Legal Advertising Dept.
P.O. Box 704055
West Valley City, UT 84170
Acct #9001399880

RE: Legal Notice of Intent to Approve

This letter will confirm the authorization to publish the attached NOTICE in the Salt Lake Tribune and
Deseret News on January 12, 2025.

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

Sincerely,

{{$s }}

Jeree Greenwood
Office Technician

Enclosure

cc: Salt Lake County
cc: Wasatch Front Regional Council

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

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

DAQE-NN104140016-24
Page 2
NOTICE

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

Company Name: Central Valley Water Reclamation Facility
Location: Central Valley Water Reclamation Facility - Wastewater Treatment Plant – 800
West Central Valley Road, Salt Lake City, UT
Project Description: The Central Valley Water Reclamation Facility (CVWRF) employs primary
sedimentation tanks, trickling filters, aeration tanks, secondary sedimentation
tanks, and ultraviolet light disinfection to treat wastewater. CVWRF has
requested a modification for the addition of new diesel-fired emergency
generators, which will result in an increased potential to emit of combustion
pollutants. Emission reductions will result from improvements to decrease
phosphorus effluent and the removal of an old engine.

The completed engineering evaluation and air quality impact analysis showed the proposed project meets
the requirements of federal air quality regulations and the State air quality rules. The Director intends to
issue an Approval Order pending a 30-day public comment period. The project proposal, estimate of the
effect on local air quality and draft Approval Order are available for public inspection and comment at the
Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments
received by the Division at this same address on or before February 11, 2025, will be considered in
making the final decision on the approval/disapproval of the proposed project. Email comments will also
be accepted at [e-mail]. If anyone so requests to the Director in writing within 15 days of
publication of this notice, a hearing will be held in accordance with R307-401-7, UAC.

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

Date of Notice: January 12, 2025

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

DAQE-

RN104140016 November 4, 2024 Bryan Mansell
Central Valley Water Reclamation Fac. 800 West Central Valley Road Salt Lake City, UT 841193379
[e-mail] Dear Bryan Mansell,
Re: Engineer Review: Modification to Approval Order DAQE-AN104140015-21 to Update Engines Project Number: N104140016 Please review and sign this letter and attached Engineer Review (ER) within 10 business days. For this document to be considered as the application for a Title V administrative amendment, a Title V Responsible Official must sign the next page. Please contact John Persons at [phone] if you have any questions or concerns about the ER. If you accept the contents of this ER, please email this signed cover letter to John Persons at [e-mail]. After receipt of the signed cover letter, the DAQ will prepare an Intent to Approve (ITA) for a 30-day public comment period. When the public comment period ends, the DAQ will consider any comments received and will issue the Approval Order. If you do not respond to this letter within 10 business days, the project will move forward without your approval. If you have concerns that we cannot resolve, the DAQ Director may issue an Order prohibiting
construction. Approval Signature _____________________________________________________________
(Signature & Date)
195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
Department of Environmental Quality
Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director
State of Utah
SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor

Engineer Review N104140016: Central Valley Water Reclamation Fac.- Wastewater Treatment Plant November 4, 2024 Page 1
OPTIONAL: In order for this Engineer Review and associated Approval Order conditions to be considered as an application to administratively amend your Title V Permit, the Responsible Official, as
defined in R307-415-3, must sign the statement below. THIS IS STRICTLY OPTIONAL. If you do not want the Engineer Review to be considered as an application to administratively amend your Operating Permit only the approval signature above is required. Failure to have the Responsible Official sign below will not delay the Approval Order, but will require submittal of a separate Operating Permit Application to revise the Title V permit in accordance with R307-415-5a through 5e and R307-415-7a through 7i. A guidance document: Title V Operating Permit Application Due Dates clarifies the required due dates for Title V operating permit applications and can be viewed at:
https://deq.utah.gov/air-quality/permitting-guidance-and-guidelines-air-quality “Based on information and belief formed after reasonable inquiry, I certify that the statements and information provided for this Approval Order are true, accurate and complete and request that this Approval Order be considered as an application to administratively amend the Operating Permit.” Responsible Official _________________________________________________ (Signature & Date) Print Name of Responsible Official _____________________________________

Engineer Review N104140016: Central Valley Water Reclamation Fac.- Wastewater Treatment Plant November 4, 2024 Page 2
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION
Project Number N104140016 Owner Name Central Valley Water Reclamation Fac.
Mailing Address 800 West Central Valley Road Salt Lake City, UT, 841193379
Source Name Central Valley Water Reclamation Fac.- Wastewater Treatment Plant Source Location 800 W Central Valley Road
Salt Lake City, UT 84119-3379 UTM Projection 422600 m Easting, 4506500 m Northing UTM Datum NAD27 UTM Zone UTM Zone 12 SIC Code 4952 (Sewerage Systems) Source Contact Bryan Mansell Phone Number [phone] Email [e-mail]
Billing Contact Bryan Mansell Phone Number 801.973.9100 Email [e-mail]
Project Engineer John Persons, Engineer Phone Number [phone]
Email [e-mail] Notice of Intent (NOI) Submitted May 4, 2023 Date of Accepted Application June 13, 2024

Engineer Review N104140016: Central Valley Water Reclamation Fac.- Wastewater Treatment Plant November 4, 2024 Page 3
SOURCE DESCRIPTION General Description
Central Valley Water Reclamation Facility (CVWRF) employs primary sedimentation tanks, trickling filters, aeration tanks, secondary sedimentation tanks and ultraviolet light disinfection. The treated water is then discharged into Mill Creek. CVWRF also treats the waste materials
removed from the water using anaerobic digesters which reduces the solids by converting them to water, methane gas and a residual called bio-solids. The water is pressed out of the bio-solids and returned to the liquid portion of the plant for treatment. The bio-solids are taken and applied to the ground for beneficial agricultural use or composting. The methane gas is used to fuel engine generators to power the plant. Equipment at the site consists of digester gas/natural gas-fired engines, emergency generator engines, digester gas flares, small boilers, and waste oil heaters. NSR Classification: Minor Modification at Major Source Source Classification
Located in the Northern Wasatch Front O3 NAA, Salt Lake City UT PM2.5 NAA, and Salt Lake County SO2 NAA Salt Lake County
Airs Source Size: A Applicable Federal Standards
NSPS (Part 60), A: General Provisions NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion Engines NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines 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 Project Proposal Modification to Approval Order DAQE-AN104140015-21 to Update Engines Project Description
CVWRF requested a modification for: The addition of three 2-MW diesel-fired emergency engines to ensure adequate back-up power in
the event of a power outage. The removal of Waukesha 5 engine, off-site since 2021. Addition of previously permitted Waste Oil Heater emissions.
EMISSION IMPACT ANALYSIS One-hour NOx modeling was required for this modification and was completed under DAQE-MN104140016-23. Conditions II.B.4.a and II.B.4.b were added as a result of the model. [Last updated January 2, 2024]

Engineer Review N104140016: Central Valley Water Reclamation Fac.- Wastewater Treatment Plant November 4, 2024 Page 4
SUMMARY OF EMISSIONS
The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible.
Criteria Pollutant Change (TPY) Total (TPY) Ammonia 0 0.17 CO2 Equivalent 532 50741.31
Carbon Monoxide 0.41 250.87
Nitrogen Oxides 4.83 68.65
Particulate Matter - PM10 0.17 3.65
Particulate Matter - PM2.5 0.17 2.68
Sulfur Oxides 0.20 0.42 Volatile Organic Compounds 0.54 35.09 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 0 5140
Acrolein (CAS #107028) 0 3160
Benzene (Including Benzene From Gasoline) (CAS #71432) 0 280
Formaldehyde (CAS #50000) 0 32500 Generic HAPs (CAS #GHAPS) 0 1140 Hexane (CAS #110543) 0 880
Methanol (CAS #67561) 0 1540
Change (TPY) Total (TPY)
Total HAPs 0 22.32
Note: Change in emissions indicates the difference between previous AO and proposed modification.

Engineer Review N104140016: Central Valley Water Reclamation Fac.- Wastewater Treatment Plant November 4, 2024 Page 5
Review of BACT for New/Modified Emission Units 1. BACT review regarding New Emergency Engines
The addition of the three new diesel fired engines will result in an increase in criteria emissions. The source completed a RACT/BACT Clearinghouse search for similar engines and determined that BACT for the engines is adherence to Tier II Standard and compliance with NSPS Subpart
JJJJ and MACT Subpart ZZZZ. The engines will be certified to meet Tier II standards with emissions at or below 5.38 g/hp-hr NOx, 0.45 g/hp-hr CO, and 0.04 g/hp-hr PM (PM10 and PM2.5). This, along with use of low sulfur fuels, maintenance and operation according to manufacturer recommendations, and visible at or below 20% opacity is BACT for the new engines. [Last updated January 2, 2024]
SECTION I: GENERAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101]
I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1]

I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by
the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the five-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of five (5) years. [R307-401-8] I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO,
including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4]
I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107]

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I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]
I.8 The owner/operator shall submit documentation of the status of construction or modification of Emergency Engines #9-#11 to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO, if construction is discontinued for 18 months or more, or if construction extends beyond the anticipated schedule. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]
SECTION II: PERMITTED EQUIPMENT
The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.A THE APPROVED EQUIPMENT II.A.1 CVWRF Source Wide

II.A.2 JMS Engines #1 & #2 Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines Rating: 2,509 hp (each) Fuel Type: Natural Gas/Digester Gas NSPS Applicability: 40 CFR 60 Subpart JJJJ MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.3 JMS Engines #3 & #4 Two (2) GE Jenbacher Model JMS 612-F28F02 generator engines
Rating: 2,509 hp (each) Fuel Type: Natural Gas/Digester Gas NSPS Applicability: 40 CFR 60 Subpart JJJJ MACT Applicability: 40 CFR 63 Subpart ZZZZ
II.A.4 H2S Removal Vessel H2S removal vessel upstream of the engines used to treat digester gas. II.A.5 Emergency Generator Engines #2 & #3 Rating: 896 hp each Quantity: 2 Fuel: Diesel NSPS Applicability: None
MACT Applicability: 40 CFR 63 Subpart ZZZZ II.A.6 Emergency Generator Engines #4 Rating: 349 hp Quantity: 1 Fuel: Diesel NSPS Applicability: None
MACT Applicability: 40 CFR 63 Subpart ZZZZ

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II.A.7 Emergency Generator Engines #5 and #6 Rating: 800 hp each Quantity: 2
Fuel: Diesel Manufacture Date: 2016 NSPS Applicability: 40 CFR 60 Subpart IIII
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.8 Emergency Generator Engines #7 and #8
Rating: 1,341 hp each Quantity: 2 Fuel: Diesel Manufacture Date: 2015 NSPS Applicability: 40 CFR 60 Subpart IIII MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.9 Paint Booth Water-wash paint booth
II.A.10 Three (3) Waste Oil Heaters Rating: 0.28, 0.33, and 0.35 MMBtu/hr each Fuel: Used Oil
II.A.11 Two (2) Digester Gas Flares
Fuel Type: Digester Gas II.A.12 Boiler #1 Rating: 6.05 MMBtu/hr Fuel: Natural Gas NSPS Applicability: None MACT Applicability: None
II.A.13 Boiler #2 Rating: 6.28 MMBtu/hr Fuel: Natural Gas NSPS Applicability: None MACT Applicability: None
II.A.14
NEW
Emergency Engines #9-#11 (NEW)
Fuel: Diesel Rating: 2,680 hp or 6,000 kW Each NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ
SECTION II: SPECIAL PROVISIONS
The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label):

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II.B REQUIREMENTS AND LIMITATIONS
II.B.1 Site Wide Requirements
II.B.1.a Visible emissions from the following emission points shall not exceed the following values: A. Digester Gas/Natural Gas Engines - 10% opacity B. Diesel Generators - 20% opacity C. Boilers - 10% opacity D. Fugitive Emissions - 15% opacity E. Digester Gas Flare - 10% opacity F. Spray Booth Exhaust - 10% opacity. [R307-401-8]
II.B.1.a.1 Opacity observations of emissions from all engines, boilers, fugitive emissions, and the spray booth exhaust shall be conducted according to 40 CFR 60, Appendix A, Method 9; opacity observations of emissions from the digester gas flares shall be conducted according to 40 CFR 60, Appendix A, Method 22. [R307-401-8]
II.B.1.b NEW The owner/operator shall not allow the NOx emissions from the operation of all engines at the plant to exceed 0.648 tons per day. [R307-401-8, SIP Section IX.H.2]
II.B.1.b.1
NEW
The owner/operator shall demonstrate compliance with the emission limitation by summing
the emissions from all the engines. [R307-401-8, SIP Section IX.H.2]
II.B.2 Waukesha Digester Gas/Natural Gas Engines Requirements
II.B.2.a The owner/operator shall use only natural gas and/or digester gas as fuel in all Waukesha and JMS generator engines. [R307-401-8]
II.B.2.b The owner/operator shall limit emissions from all Waukesha and JMS generator engines to 53 tons of NOx per rolling 12-month period. [R307-401-8]
II.B.2.b.1 The owner/operator shall determine compliance with a rolling 12-month total by calculating a new 12-month total using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month. The owner/operator shall demonstrate compliance with the rolling 12-month limit by using the following equation for each engine and the appropriate conversion factors: NOx = [Emission rate of engine] x [Hours of operation of engine]. [R307-401-8]
II.B.2.b.2 Records of hours of operation shall be kept for all periods when the engines are in operation. Continuous recording is required. Records shall be kept on a daily basis. [R307-401-8]

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II.B.2.b.3 The owner/operator shall use the most recent stack test data as the emission rates for the rolling 12-month total calculations. Emission rates for the JMS engines shall be measured as required in II.B.3.a. The most recent stack test data shall be used to determine compliance with the rolling 12-month NOx limit. For the period between installation and the initial stack test, the NOx emission limit in II.B.3.a shall be used. A stack test of the Waukesha engine shall be conducted on an annual basis for as long as the engine remains in operation. Testing shall be performed in accordance with the requirements in II.B.3.a.2 through II.B.3.a.5 and II.B.3.a.8 through II.B.3.a.11 of this AO. The source may be tested at any time if directed by the Director. [R307-401-8] II.B.3 JMS Digester Gas/Natural Gas Engines Requirements II.B.3.a Emissions to the atmosphere from each of the natural gas/digester gas fired engines shall not exceed the following rates: Source: Digester Gas/Natural Gas Engines (Each Stack) Pollutant Limit (g/bhp-hr)
NOx 0.55 CO 2.50 VOCs (NMHC) 0.3. [R307-401-8]

II.B.3.a.1 NEW Frequency Emission Point Pollutant Status Test Frequency JMS Engine #1 NOx * +
CO * +
VOC * + JMS Engine #2 NOx * +
CO * +
VOC * + JMS Engine #3 NOx ** +
CO ** +
VOC ** + JMS Engine #4 NOx ** +
CO ** +
VOC ** +
* Initial compliance testing was required and completed. ** Initial compliance testing is required. The initial test date shall be performed as soon as possible and in no case later than 180 days after the startup of a new emission source, an
existing source without an AO, or the granting of an AO to an existing emission source that has not had an initial compliance test performed. If an existing source is modified, a compliance test is required on the modified emission point that has an emission rate limit. + Test every three (3) years. The Director may require testing at any time. [R307-401-8]

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II.B.3.a.2 Notification
The Director shall be notified at least 30 days prior to conducting any required emission
testing. A source test protocol shall be submitted to DAQ when the testing notification is submitted to the Director. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack(s) to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. [R307-401-8]
II.B.3.a.3 Sample Location
The sampling location shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other methods as approved by EPA and acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. [R307-401-8]

II.B.3.a.4 Volumetric Flow Rate Test Methods
40 CFR 60, Appendix A, Method 2 or other EPA approved testing methods acceptable to the
Director. [R307-401-8] II.B.3.a.5 NOx Test Methods 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D, 7E or other EPA approved testing methods acceptable to the Director. [R307-401-8]
II.B.3.a.6 CO Test Methods
40 CFR 60, Appendix A, Method 10, or other EPA approved testing methods acceptable to the Director. [R307-401-8]
II.B.3.a.7 VOC Test Method
40 CFR 60, Appendix A, Method 18, or other EPA approved testing methods acceptable to the Director. [R307-401-8] II.B.3.a.8 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. [R307-401-8]

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II.B.3.a.9 New Source Operation
For a new source/emission point, the production rate during all compliance testing shall be no
less than 90% of the production rate listed in this AO. If the maximum AO allowable production rate has not been achieved at the time of the test, the following procedure shall be followed:

1) Testing shall be at no less than 90% of the production rate achieved to date.

2) If the test is passed, the new maximum allowable production rate shall be
110% of the tested achieved rate, but not more than the maximum allowable
production rate. This new allowable maximum production rate shall remain
in effect until successfully tested at a higher rate.

3) The owner/operator shall request a higher production rate when necessary.
Testing at no less than 90% of the higher rate shall be conducted. A new
maximum production rate (110% of the new rate) will then be allowed if the
test is successful. This process may be repeated until the maximum AO
production rate is achieved. [R307-401-8]
II.B.3.a.10 Existing Source Operation For an existing source/emission point, the production rate during all compliance testing shall be no less than 90% of the maximum production achieved in the previous three (3) years. [R307-401-8]

II.B.3.a.11 The results of stack testing shall be submitted to the Director within 60 days of completion of
the testing. Reports shall clearly identify results as compared to permit limits and indicate compliance status. [R307-401-8]
II.B.4 Emergency Generator Engines Requirements

II.B.4.a NEW The owner/operator shall not test Emergency #9 - #11 concurrently or when any other emergency engine is being tested. [R307-401-8, R307-410-4] II.B.4.b NEW The owner/operator shall not exceed 52 tests per engine for Emergency Engines #9-#11 per rolling 12-month period. [R307-401-8, R307-410-4]
II.B.4.c Each emergency generator engine shall not exceed 100 hours of operation for testing and maintenance per rolling 12-month period. The 100 hours of operation for testing and maintenance purposes may include up to 50 hours per calendar year for operation in
nonemergency situations as provided in 40 CFR 60.4211(f). [R307-401-8]

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II.B.4.c.1 Compliance with the limit of the hours of operation shall be determined by installation of an hour meter on the emergency generator engine. Records documenting the operation of the emergency generator engine shall be kept in a log and shall include the following:
A. The date the emergency generator engine was used; B. The duration of operation each day in hours; and C. The reason for the emergency generator engine usage. [R307-401-8] II.B.4.c.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. [R307-401-8] II.B.4.c.3 Records of hours of operation shall be determined by installing a non-resettable hour meter for the emergency generator engine. [40 CFR 63 Subpart ZZZZ]

II.B.5 Fuel Requirements
II.B.5.a The owner/operator shall only use diesel fuel (fuel oil #1, #2 or diesel fuel oil additives) in the
emergency generator engines. All diesel burned shall meet the definition of ultra-low sulfur diesel (ULSD), and contain no more than 15 ppm sulfur. [R307-401-8]
II.B.5.a.1 To demonstrate compliance with the diesel fuel requirements for any diesel fuel purchased,
the owner/operator shall keep and maintain fuel purchase invoices. The fuel purchase invoices shall indicate that the diesel fuel meets the ULSD requirements, or the owner/operator shall obtain certification of sulfur content from the fuel supplier. [R307-401-8]

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PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the
following documents: Supersedes DAQE-AN104140015-21 dated July 2, 2021
Is Derived From NOI dated May 5, 2023 Incorporates Additional Information dated July 7, 2023 Incorporates Additional Information dated January 4, 2024
REVIEWER COMMENTS
1. Comment regarding Permit Changes : During this minor modification several changes were made to AO DAQE-AN104140015-21. Theses changes included the following: Three (3) 2,680 hp (6,000 kW) diesel-fired emergency generator engines were added to the site. The Waukesha #5 diesel-fired engine was removed. This engine had been removed from the site in 2021 and the emissions were no longer included in the PTE's for the site but the engine was still
incorrectly listed in the equipment list.
The emissions for the three (3) waste oil heaters (equipment that was already in the permit) was not calculated and included in the PTE previously. Therefore, these emissions were estimated and
included in this permit. [Last updated June 24, 2024]
2. Comment regarding Emission Estimates and NOx Limit: The new engine emissions were calculated using emission factors from the manufacturer guaranteed Tier 2 standards (NOx : 5.38 g/hp-hr, CO: 0.45 g/hp-hr, PM10 and PM2.5: 0.04 g/hp-hr), and emission
factors from AP-42 Table 3.3-1 & Table 3.4-1 AP-42 Table 3.4-1. 100 hours of operation per year per engine was assumed. Waste Oil Burner emissions were added in this modification through the equipment was included in previous AO equipment lists. Emission factors from AP-42 Section 1.11 were used assuming 1,200
hours of operation per year.
Flare emissions were updated with 2018 usage data. [Last updated June 24, 2024]
3. Comment regarding Engine NSPS/MACT Applicability: The three new diesel fired emergency engines rated at 2,680 hp (name plate rating) will be subject to the following subparts. 40 CFR 63 MACT Subpart ZZZZ applies to owners and operators of stationary RICE at a major or area source of HAP emissions. Since this source will have stationary RICEs at an area source of HAP emissions, MACT Subpart ZZZZ will apply to this facility. A new or reconstructed stationary RICE located at an area source must meet the requirements of 40 CFR 63 Subpart ZZZZ by meeting the requirements of 40 CFR part 60 subpart IIII. No further requirements apply for such engines

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under MACT Subpart ZZZZ. 40 CFR 60 NSPS Subpart IIII applies to stationary compression ignition (CI) internal combustion engines (ICE) manufactured after 2007. The new engiens are subject to Subpart IIII. Engines greater than 3,000 kW manufactured after 2011 must meet Tier 2 emission standards as described in 40 CFR part 1039, appendix I, for all pollutants and the smoke standards as specified in 40 CFR 1039.105. [Last updated November 4, 2024]
4. Comment regarding SIP Info: Central Valley Water Reclamation Facility is a major source for Carbon Monoxide (250.87 tpy), Formaldehyde (16.25 tpy) and now NOx (68.65 tpy). This facility surpasses the secondary pollutant threshold for NOx (50 tpy) for major source classification as a result of the Northern Wasatch Front Ozone Nonattainment area being reclassified as serious by the EPA. The facility is not a major
source for VOCs as it only emits 35 tpy of VOCs which falls below the 50 tpy secondary pollutant threshold. Central Valley Water Reclamation Facility's Wastewater Treatment Plant is a PM10 SIP listed source and is a subject to SIP requirements under Section IX Part H.2. The details of these requirements are
described in more detail in the following NSR review comment. The emissions increase as a result of this modification will have no effect on the SIP requirements of this source. The emissions increase from these permitted changes result in the following emissions increases:
CO2 Equivalent532 tpy
Carbon Monoxide0.41 tpy Nitrogen Oxides4.83 tpy Particulate Matter - PM10 0.17 tpy
Particulate Matter - PM2.5 0.17 tpy Sulfur Oxides0.20 tpy Volatile Organic Compounds 0.54 tpy
All of these emissions increases are below the "major modification" thresholds listed in R307-101. As a result of this no offsets are required.
Section IX Part H.2 of the PM10 Moderate SIP includes an emission limit for CVWRF. Under Part
H.2, all engines at CVWRF are limited to 0.648 tons per day of NOx. To demonstrate compliance with this limit, CVWRF is required to calculate emissions based on power production (kW-hr/day) and an emission factor (g/kW-hr). The emission factor is based on stack tests, which are required to be performed every three years. This limit was developed based on the 2015 RACT analysis when the five Waukesha engines were in operation. In addition, the generator engines at CVWRF can meet this limit at 100% operation. The Part H.2 limit of 0.648 tons/day is equivalent to 263.52 tpy of NOx. This current AO limits all digester gas
engines at CVWRF to 53 tons of NOx per year. Emergency generators have the potential to contribute an additional 9.55 tpy, for a total NOx PTE of 62.55 from the engines. In terms of daily emissions, the JMS engines have the potential to emit 0.0365 tons/day of NOx. The remaining
emergency generator engines are not expected to significantly contribute to the daily emissions since they typically only operate for a 1-4 hours a day. In the worst case scenario, if each emergency generator engines operated for four hours on the same day and all four JMS engines operated at 100% load for 24 hours, daily NOx would be 0.240 tons/day. This is significantly below the Part H.2 limit of 0.648 tons/day.

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[Last updated November 4, 2024]

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ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document:
40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology
CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by EPA to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1 COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal UDAQ use EPA Environmental Protection Agency
FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i) GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/HR Pounds per hour
LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units
NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit
R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year
UAC Utah Administrative Code VOC Volatile organic compounds
Assumptions atomizing, waste oil
Hours 1200 my numbers assumed this many hours per year, as those heaters only operate in winter and only when building
MMbtu/gal 10^3 0.00013 this doesn't seem correct. Should be closer to 0.138 MMBtu/gal (see https://www.epa.gov/system/files/docume
0.28 0.33 0.35 MMBtu/hr
PM10 6.85E-02 8.08E-02 8.57E-02 0.24
PM2.5 6.85E-02 8.08E-02 8.57E-02 0.24
NOx 2.55E-02 3.01E-02 3.19E-02 0.09
CO 6.72E-03 7.92E-03 8.40E-03 0.02
SO2 2.96E-02 3.49E-02 3.70E-02 0.10
VOC 1.34E-03 1.58E-03 1.68E-03 0.00
CO2 7.24E+00 8.53E+00 9.05E+00 2.48E+01
1.11 EFs lb/10^3 gal lb/MMBtu
PM10 51 0.408
NOx 19 0.152
SO2 22.05 0.1764
CO 5 0.04
VOC 1 0.008
cO2 22000 176
ents/2022-10/Default%20Heat%20Content%20Ratios%20for%20Help%20and%20User%20Guide%20%281%29.pdf), which equates to 138 MM
MBtu/ 10^3gal), which is closer to the data provided in my calculations (MMBtu/hr divided by gal/hr)
Emission Unit PM10 PM2.5 NOx CO SO2 VOC
Emergency Engines 2*4 0.075 0.075 2.57 0.59 0.0013 0.07
Emergency 5,6 0.056 0.056 0.74 0.03 0.001 0.01
Emergency 7,8 0.044 0.044 1.41 0.77 0.0016 0.09
Emergency 9-11 0.035 0.035 4.77 0.4 0.0049 0.26
Natural Gas/Digester 2.91 1.94 53.3 242.27 0.181 29.07
Flare**0 0 0.52 2.36 0 5.03
Boiler 6 MMBtu 0.2 0.2 2.6 2.18 0.016 0.14
Boiler 150 hp 0.2 0.2 2.7 2.26 0.016 0.15
Waste Oil 0.93 0.93 0.07 0.02 0.269 0.004
Total*4.45 3.48 68.68 250.88 0.4908 34.824
DAQE-AN104140015-21 3.48 2.51 63.82 250.46 0.22 34.55
Change in 0.97 0.97 4.86 0.42 0.2708 0.274
Emission Unit PM10 PM2.5 NOx CO SO2 VOC
Emergency Engines 2*4 0.075 0.075 2.57 0.59 0.0013 0.07
Emergency 5,6 0.056 0.056 0.74 0.03 0.001 0.01
Emergency 7,8 0.044 0.044 1.41 0.77 0.0016 0.09
Emergency 9-11 0.035 0.035 4.77 0.4 0.0049 0.26
Natural Gas/Digester 2.91 1.94 53.3 242.27 0.181 29.07
Flare**0 0 0.52 2.36 0 5.03
Boiler 6 MMBtu 0.2 0.2 2.6 2.18 0.016 0.14
Boiler 150 hp 0.2 0.2 2.7 2.26 0.016 0.15
Waste Oil 0.24 0.24 0.09 0.02 0.10 0.00
Total*3.755008 2.785008 68.697552 250.88304 0.3234064 34.824608
DAQE-AN104140015-21 3.48 2.51 63.82 250.46 0.22 34.55
Change in 0.275008 0.275008 4.877552 0.42304 0.1034064 0.274608
HAPs CO2e
0.001 124
0.001 93
0.001 156
0.012 467
22.21 43,463
0.049 3,136
0.051 3,254
0.003 73
22.328 50766
22.32 50209.31
0.008 556.69
HAPs CO2e
0.001 124
0.001 93
0.001 156
0.012 467
22.21 43,463
0.049 3,136
0.051 3,254
0.003 24.82
22.328 50717.81684
22.32 50209.31
0.008 508.5068448
new emergency gens waste oil previous permit Change New totals
NOx 0.06 63.82 0.06 63.88
CO 0.40 0.01 250.46 0.41 250.87
PM10 0.04 0.14 3.48 0.17 3.65
PM2.5 0.04 0.14 2.51 0.17 2.68
VOC 0.26 0.00 34.82 0.26 35.09
SO2 0.01 0.20 0.22 0.20 0.42
HAP 0.01 0.02 22.32 0.03 22.35
CO2e 467.00 65.00 50,209.31 532.00 50,741.31
Equipment Details
Model CB3500 0.35 MMBtu/hr*157.3770492 btu/hr
Model CB 3250 0.33 MMBtu/hr*
Model CB2800 0.28 MMBtu/hr*Truck Barn
Total Rating 0.96 MMBtu/hour mm
Model CB3500 2.3 gal/hr 0.154761905
Model CB 3250 2.1 gal/hr
Model CB2800 1.7 gal/hr
el Consumption 6.1 gal/hr
Operational Ho 1,200 hours/year
Criteria Pollutan Factor (lb/10^ sion Rate (lbs/hon Total (tons/y Reference
NOX 16 9.76E-02 5.86E-02 AP-42 Table 1.11-2
CO 2.1 1.28E-02 7.69E-03 AP-42 Table 1.11-2
PM10 37.05 2.26E-01 1.36E-01 AP-42 Table 1.10.65% Ash assumed
PM2.5 37.05 2.26E-01 1.36E-01 AP-42 Table 1.1conservative assumption
VOC 1 6.10E-03 3.66E-03 AP-42 Table 1.11-3
SO2 53.5 3.26E-01 1.96E-01 AP-42 Table 1.10.5% Sulfur assumed
Lead 5.5 3.36E-02 2.01E-02 AP-42 Table 1.10.11% Lead assumed
HAPs 3.64E-02 2.18E-02
Green House G al Warming Poton Factor (lb/10^ on Total (tons/y Reference
CO2 (mass basi 1 22,000 409
Methane (mass 25 0.475 0.01
N2O (mass basi 298 0.53 0.01
CO2e 65
Hazardous Air n Factor (lb/10^ sion Rate (lbs/hon Total (tons/y Reference
Phenol 2.80E-03 1.71E-05 1.02E-05
Dichlorobenzen 0.00E+00 0.00E+00 0.00E+00
1.3-3,8 & Tabl

Waste Oil Burners
Maintenance Barn *nominal rating
of the burner,
but based on
No 2 fuel oil,
actual BTU/hr
with waste oil
Equipment Barn
<-- Assuming 10 hour shifts, 5 days per week, 6
Naphthalene 9.20E-05 5.61E-07 3.37E-07
Phenanthrene/a 1.00E-04 6.10E-07 3.66E-07
Dibutylphthalate 3.40E-05 2.07E-07 1.24E-07
Butylbenzylphth 0.00E+00 0.00E+00 0.00E+00
Bis(2-ethylhexy 0.00E+00 0.00E+00 0.00E+00
Pyrene 8.30E-06 5.06E-08 3.04E-08
Benz(a)anthrac 0.00E+00 0.00E+00 0.00E+00
Benzo(a)pyrene 0.00E+00 0.00E+00 0.00E+00
Trichloroethylen 0.00E+00 0.00E+00 0.00E+00
Arsenic 6.00E-02 3.66E-04 2.20E-04
Beryllium 1.80E-03 1.10E-05 6.59E-06
Cadmium 1.20E-02 7.32E-05 4.39E-05
Chromium 1.80E-01 1.10E-03 6.59E-04
Lead 0.00E+00 0.00E+00 0.00E+00
Mercury 0.00E+00 0.00E+00 0.00E+00
Manganese 5.00E-02 3.05E-04 1.83E-04
Nickel 1.60E-01 9.76E-04 5.86E-04
Selenium 0.00E+00 0.00E+00 0.00E+00
0.002847689 1.71E-03
Table 1.11-5 and

TEST REPORT SUMMARY

Client Information / Test Location Source Information
Central Valley Water Reclamation Facility Engine/Unit ID: Jenbacher #4
Wastewater Treatment Plant Engine Make/Model: GE JMS 612-F28F02
800 W Central Valley Road
Salt Lake City, UT 84119-3379
Engine Serial Number: 1322446
Engine Type: Compression Ignition
Engine Date of Manufacture: 2018
Engine Rating: 2,509 HP
Regulatory Applicability AST Project No.
40 CFR 60, Subpart JJJJ AST-2022-0470
DAQE-AN104140015-21

Run No. Run 1 Run 2 Run 3 Average
Date 3/2/22 3/2/22 3/2/22 --
Engine Load, % * 100 100 100 100
Nitrogen Oxides Data
Emission Factor, g/bHP-hr 0.44 0.43 0.42 0.43
Emission Limit, g/bHP-hr -- -- -- 0.55
Percent of Limit, % -- -- -- 78
Carbon Monoxide Data
Emission Factor, g/bHP-hr 1.3 1.3 1.3 1.3
Emission Limit, g/bHP-hr -- -- -- 2.0
Percent of Limit, % -- -- -- 63
Volatile Organic Compounds Data
Emission Factor, g/bHP-hr 0.054 0.053 0.058 0.055
Emission Limit, g/bHP-hr -- -- -- 1.0
Percent of Limit, % -- -- -- 6
Non-Methane Hydrocarbons Data
Emission Factor, g/bHP-hr 0.095 0.094 0.10 0.097
Emission Limit, g/bHP-hr -- -- -- 0.3
Percent of Limit, % -- -- -- 32
Methane Data
Emission Factor, g/bHP-hr 2.8 2.8 2.9 2.8
Formaldehyde Data
Emission Factor, g/bHP-hr 0.16 0.17 0.17 0.17
* Performance testing was conducted while the engine was operating at the highest achievable load at current site conditions.

Central Valley Water Reclamation Facility 
800 W Central Valley Road 
Salt Lake City, UT 84119‐3379 
Source Tested: Jenbacher Engine #4 
Test Date: March 2, 2022 
AST Project No. AST‐2022‐0470 
Prepared By 
Alliance Source Testing, LLC 
3683 W 2270 S, Suite E 
West Valley City, UT 84120 
Engine Test Report 
.
Source Test Report
Source & Contact Information
AST-2022-0470 Central Valley –Salt Lake City, UT Page i

Regulatory Information

Permit No. DAQE-AN104140015-21
Regulatory Citation 40 CFR 60, Subpart JJJJ

Source Information

Source Name Source ID Target Parameters
GE Jenbacher Model JMS 612-
F28F02 Generator Engine Jenbacher #4 NOx, CO, VOC

Contact Information

Test Location Test Company
Central Valley Water Reclamation Facility
Wastewater Treatment Plant
800 W Central Valley Road
Salt Lake City, UT 84119-3379

Bryan Mansell
[e-mail]
[phone]

Alliance Source Testing, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120

Project Manager
Kyle Vaughan
[e-mail]
[phone]

Field Team Leader
Andrew Bellard
[e-mail]
[phone]

QA/QC Manager
Heather Morgan
[e-mail]
[phone]

Report Coordinator
Sarah Perry
[e-mail]
[phone]

2 of 76
Source Test Report
Certification Statement
AST-2022-0470 Central Valley –Salt Lake City, UT Page ii
Alliance Source Testing, LLC (AST) has completed the source testing as described in this report. Results apply
only to the source(s) tested and operating condition(s) for the specific test date(s) and time(s) identified within this
report. All results are intended to be considered in their entirety, and AST is not responsible for use of less than the
complete test report without written consent. This report shall not be reproduced in full or in part without written
approval from the customer.
To the best of my knowledge and abilities, all information, facts and test data are correct. Data presented in this
report has been checked for completeness and is accurate, error-free and legible. Onsite testing was conducted in
accordance with approved internal Standard Operating Procedures. Any deviations or test program notes are
detailed in the relevant sections on the test report.
This report is only considered valid once an authorized representative of AST has signed in the space provided
below; any other version is considered draft. This document was prepared in portable document format (.pdf) and
contains pages as identified in the bottom footer of this document.
Kyle Vaughan, QSTI
Alliance Source Testing, LLC
Date
3 of 76
4/5/2022

Source Test Report
Table of Contents

AST-2022-0470 Central Valley –Salt Lake City, UT Page iii

TABLE OF CONTENTS

1.0 Introduction .................................................................................................................................................. 1-1 
1.1 Process/Control System Descriptions ...................................................................................................... 1-1 
1.2 Project Team ............................................................................................................................................ 1-1 
1.3 Instrument Information ............................................................................................................................ 1-1 
1.4 Test Protocol and Notification ................................................................................................................. 1-1 
2.0 Testing Methodology .................................................................................................................................... 2-1 
2.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate ..... 2-1 
2.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide ........................................................... 2-1 
2.3 U.S. EPA Reference Test Method 320 – H2O, NOx, CO, VOC, NMHC, CH4 and H2CO ...................... 2-1 
2.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification ........................................... 2-2 
2.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A .......................................... 2-2 
2.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320 ................................................. 2-3 

LIST OF TABLES

Table 1-1 Project Team ........................................................................................................................................ 1-1 
Table 1-2 Instrument Information ........................................................................................................................ 1-1 
Table 2-1 Source Testing Methodology ............................................................................................................... 2-1 

APPENDICES

Appendix A Sample Calculations
Appendix B Field Data
Appendix C Quality Assurance/Quality Control Data
Appendix D Engine Operating Data
Appendix E SSTP and Associated Documentation

4 of 76

Introduction

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Source Test Report
Introduction

AST-2022-0470 Central Valley –Salt Lake City, UT Page 1-1

1.0 Introduction
Alliance Source Testing, LLC (AST) was retained by Central Valley Wastewater Reclamation Facility (Central
Valley) to conduct compliance testing at the Wastewater Treatment Plant in Salt Lake City, Utah. Portions of the
facility are subject to provisions of the 40 CFR 60, Subpart JJJJ and the Utah Department of Environmental Quality,
Division of Air Quality (UDAQ) Approval Order (AO) DAQE-AN104140015-21. Testing was conducted on the
exhaust of the new GE Jenbacher Model JSM 612-F28F02 engine designated as Jenbacher #4 to demonstrate
compliance with emission limits detailed in the facility’s permit and 40 CFR 60, Subpart JJJJ.

Compliance testing was conducted to determine the emission rates of nitrogen oxides (NOx), carbon monoxide (CO)
and volatile organic compounds (VOC) and non-methane hydrocarbons (NMHC). The VOC emissions do not
include formaldehyde (H2CO). Testing consisted of three (3) 60-minute test runs for the source. Performance
testing was conducted while the engine was operating at the highest achievable load at current site conditions. The
Test Report Summary (TRS) provides the results from the compliance testing, including the three (3) run average,
with comparisons to the applicable limits. Any difference between the summary results listed in the TRS and the
detailed results contained in the appendices is due to rounding for presentation.
1.1 Process/Control System Descriptions
Central Valley operates two (2) GE Jenbacher Model JMS 612-F28F02 generator engines. Each engine is rated at
2,509 horsepower (hp) each. The engines can be fired on natural gas or digester gas. Jenbacher #4 is the subject of
this test program and was fired on a mixed gas of blended digester gas and natural gas.

1.2 Project Team
Personnel involved in this project are identified in the following table.

Table 1-1
Project Team
Central Valley Personnel Bryan Mansell
Zack VanWormer
AST Personnel Andrew Bellard
Gabriel Tor

1.3 Instrument Information
The instruments used to conduct the compliance testing are summarized in the following table.

Table 1-2
Instrument Information
Pollutant Manufacturer Model Serial Number
O2 / CO2 Servomex 4900 0410403-2409
H2O / NOx / CO / VOC / CH4 / H2CO MKS 8 017778272

1.4 Test Protocol and Notification
Testing was conducted in accordance with the test protocol submitted to UDAQ by Central Valley.
6 of 76

Testing Methodology

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Testing Methodology

AST-2022-0470 Central Valley –Salt Lake City, UT Page 2-1

2.0 Testing Methodology
The emissions testing program was conducted in accordance with the U.S. EPA Reference Test Methods listed in
Table 2-1. Method descriptions are provided below while quality assurance/quality control data is provided in
Appendix C.

Table 2-1
Source Testing Methodology
Parameter U.S. EPA Reference
Test Methods Notes/Remarks
Volumetric Flow Rate 1 & 2 Full Velocity Traverses
Oxygen / Carbon Dioxide 3A Instrumental Analysis
Moisture Content / Nitrogen Oxides / Carbon
Monoxide / Volatile Organic Compounds / Methane /
Formaldehyde
320 FTIR
Gas Dilution System Certification 205 --
2.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate
The sampling location and number of traverse (sampling) points were selected in accordance with U.S. EPA
Reference Test Method 1. To determine the minimum number of traverse points, the upstream and downstream
distances were equated into equivalent diameters and compared to Figure 1-2 in U.S. EPA Reference Test Method 1.

Full velocity traverses were conducted in accordance with U.S. EPA Reference Test Method 2 to determine the
average stack gas velocity pressure, static pressure and temperature. The velocity and static pressure measurement
system consisted of a pitot tube and inclined manometer. The stack gas temperature was measured with a K-type
thermocouple and pyrometer.

Stack gas velocity pressure and temperature readings were recorded during each test run. The data collected was
utilized to calculate the volumetric flow rate in accordance with U.S. EPA Reference Test Method 2.

2.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide
The oxygen (O2) and carbon dioxide (CO2) testing was conducted in accordance with U.S. EPA Reference Test
Method 3A. Data was collected online and reported in one-minute averages. The sampling system consisted of a
stainless-steel probe, Teflon sample line(s), gas conditioning system and the identified gas analyzer. The gas
conditioning system was a non-contact condenser used to remove moisture from the stack gas. If an unheated
Teflon sample line was used, then a portable non-contact condenser was placed in the system directly after the
probe. Otherwise, a heated Teflon sample line was used. The quality control measures are described in Section 2.5.

2.3 U.S. EPA Reference Test Method 320 – H2O, NOx, CO, VOC, NMHC, CH4 and H2CO
The concentrations of moisture content (H2O), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic
compounds (VOC), non-methane hydrocarbons (NMHC), methane (CH4) and formaldehyde (H2CO) were determined in
accordance with U.S. EPA Reference Test Method 320. Each source gas stream was extracted at a constant rate through
a heated probe, heated filter and heated sample line and analyzed with a MKS MultiGas 2030 FTIR operated by a
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portable computer. The computer has FTIR spectra of calibration gases stored on the hard drive. These single component
calibration spectra are used to analyze the measured sample spectra. The gas components to be measured were selected
from the spectra library and incorporated into the analytical method. The signal amplitude, linearity, and signal to noise
ratio were measured and recorded to document analyzer performance. A leak check was performed on the sample cell.
The instrument path length was verified using ethylene as the Calibration Transfer Standard. Dynamic spiking was
performed using a certified standard of the target compound or appropriate surrogate in nitrogen with sulfur hexafluoride
blended as a tracer to calculate the dilution factor. All test spectra, interferograms, and analytical method information are
recorded and stored with the calculated analytical results. The quality control measures are described in Section 2.6.
2.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification
A calibration gas dilution system field check was conducted in accordance with U.S. EPA Reference Method 205.
Multiple dilution rates and total gas flow rates were utilized to force the dilution system to perform two dilutions on
each mass flow controller. The diluted calibration gases were sent directly to the analyzer, and the analyzer response
recorded in an electronic field data sheet. The analyzer response agreed within 2% of the actual diluted gas
concentration. A second Protocol 1 calibration gas, with a cylinder concentration within 10% of one of the gas
divider settings described above, was introduced directly to the analyzer, and the analyzer response recorded in an
electronic field data sheet. The cylinder concentration and the analyzer response agreed within 2%. These steps
were repeated three (3) times. Copies of the Method 205 data can be found in the Quality Assurance/Quality
Control Appendix.
2.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A
Cylinder calibration gases used met EPA Protocol 1 (+/- 2%) standards. Copies of all calibration gas certificates can
be found in the Quality Assurance/Quality Control Appendix.

Low Level gas was introduced directly to the analyzer. After adjusting the analyzer to the Low-Level gas
concentration and once the analyzer reading was stable, the analyzer value was recorded. This process was repeated
for the High-Level gas. For the Calibration Error Test, Low, Mid, and High Level calibration gases were
sequentially introduced directly to the analyzer. All values were within 2.0 percent of the Calibration Span or 0.5%
absolute difference.

High or Mid Level gas (whichever was closer to the stack gas concentration) was introduced at the probe and the
time required for the analyzer reading to reach 95 percent or 0.5% (whichever was less restrictive) of the gas
concentration was recorded. The analyzer reading was observed until it reached a stable value, and this value was
recorded. Next, Low Level gas was introduced at the probe and the time required for the analyzer reading to
decrease to a value within 5.0 percent or 0.5% (whichever was less restrictive) was recorded. If the Low-Level gas
was zero gas, the response was 0.5% or 5.0 percent of the upscale gas concentration (whichever was less restrictive).
The analyzer reading was observed until it reached a stable value and this value was recorded. The measurement
system response time and initial system bias were determined from these data. The System Bias was within 5.0
percent of the Calibration Span or 0.5% absolute difference.

High or Mid Level gas (whichever was closer to the stack gas concentration) was introduced at the probe. After the
analyzer response was stable, the value was recorded. Next, Low Level gas was introduced at the probe, and the
analyzer value recorded once it reached a stable response. The System Bias was within 5.0 percent of the
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Calibration Span or 0.5% absolute difference or the data was invalidated and the Calibration Error Test and System
Bias were repeated.

Drift between pre- and post-run System Bias was within 3 percent of the Calibration Span or 0.5% absolute
difference. If the drift exceeded 3 percent or 0.5%, the Calibration Error Test and System Bias were repeated.

To determine the number of sampling points, a gas stratification check was conducted prior to initiating testing. The
pollutant concentrations were measured at three points (16.7, 50.0 and 83.3 percent of the measurement line). Each
traverse point was sampled for a minimum of twice the system response time.

If the pollutant concentration at each traverse point did not differ more than 5 percent or 0.3% (whichever was less
restrictive) of the average pollutant concentration, then single point sampling was conducted during the test runs. If
the pollutant concentration did not meet these specifications but differed less than 10 percent or 0.5% from the
average concentration, then three (3) point sampling was conducted (stacks less than 7.8 feet in diameter - 16.7, 50.0
and 83.3 percent of the measurement line; stacks greater than 7.8 feet in diameter – 0.4, 1.0, and 2.0 meters from the
stack wall). If the pollutant concentration differed by more than 10 percent or 0.5% from the average concentration,
then sampling was conducted at a minimum of twelve (12) traverse points. Copies of stratification check data can
be found in the Quality Assurance/Quality Control Appendix.

A Data Acquisition System with battery backup was used to record the instrument response in one (1) minute
averages. The data was continuously stored as a *.CSV file in Excel format on the hard drive of a computer. At the
completion of testing, the data was also saved to the AST server. All data was reviewed by the Field Team Leader
before leaving the facility. Once arriving at AST’s office, all written and electronic data was relinquished to the
report coordinator and then a final review was performed by the Project Manager.
2.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320
EPA Protocol 1 Calibration Gases – Cylinder calibration gases used met EPA Protocol 1 (+/- 2%) standards. Copies
of all calibration gas certificates can be found in the Quality Assurance/Quality Control Appendix.

After providing ample time for the FTIR to reach the desired temperature and to stabilize, zero gas (nitrogen) was
introduced directly to the instrument sample port. While flowing nitrogen the signal amplitude was recorded, a
background spectra was taken, a linearity check was performed and recorded, the peak to peak noise and the root
mean square in the spectral region of interest was measured and a screenshot was recorded.

Following the zero gas checks, room air was pulled through the sample chamber and the line width and resolution
was verified to be at 1879 cm-1, the peak position was entered and the FWHH was recorded (screenshot).
Following these checks, another background spectra was recorded and the calibration transfer standard (CTS) was
introduced directly to the instrument sample port. The CTS instrument recovery was recorded and the instrument
mechanical response time was measured.

Next, stack gas was introduced to the FTIR through the sampling system and several scans were taken until a stable
reading was achieved. The native concentration of our surrogate spiking analyte (acetaldehyde) was recorded.
Spike gas was introduced to the sampling system at a constant flow rate ≤ 10% of the total sample flow rate and a
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corresponding dilution ratio was calculated along with a system response time. Matrix spike recovery spectra were
recorded and were within the ± 30% of the calculated value of the spike concentration that the method requires.

The matrix spike recovery was conducted once at the beginning of the testing and the CTS recovery procedures
were repeated following each test run. The corresponding values were recorded.
11 of 76
Appendix A

12 of 76
Appendix A
Example Calculations
Location
Source
Project No.
Run No.
Parameter(s)
Absolute Stack Gas Pressure (Ps), in. Hg
where,
Pb 26.02 = barometric pressure, in. Hg
Pg 2.40 = static pressure, in. H2O
Ps 26.20 = in. Hg
Moisture Fraction (BWSsat), dimensionless (theoretical at saturated conditions)
where,
Ts 356.3 = stack temperature, °F
Ps 26.2 = absolute stack gas pressure, in. Hg
BWSsat 10.7 = dimensionless
Moisture Fraction (BWS), dimensionless
where,
BWSsat 10.702 = moisture fraction (theoretical at saturated conditions)
BWSmsd -- = moisture fraction (measured)
BWS 0.091
Molecular Weight (DRY) (Md), lb/lb-mole
where,
CO2 9.1 = carbon dioxide concentration, %
O2 10.3 = oxygen concentration, %
Md 29.87 = lb/lb mol
Molecular Weight (WET) (Ms), lb/lb-mole
where,
Md 29.87 = molecular weight (DRY), lb/lb mol
BWS 0.091 = moisture fraction, dimensionless
Ms 28.79 = lb/lb mol
Average Velocity (Vs), ft/sec
where,
Cp 0.84 = pitot tube coefficient
Δ P1/2 1.013 = average pre/post test velocity head of stack gas, (in. H2O)1/2
Ts 816.0 = average pre/post test absolute stack temperature, °R
Ps 26.20 = absolute stack gas pressure, in. Hg
Ms 28.79 = molecular weight of stack gas, lb/lb mol
Vs 75.7 = ft/sec
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
1
VFR
Ms ൌ Md ሺ1 െ BWSሻ ൅ 18.015 ሺBWSሻ
13 of 76
Appendix A
Example Calculations
Location
Source
Project No.
Run No.
Parameter(s)
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
1
VFR
Average Stack Gas Flow at Stack Conditions (Qa), acfm
where,
Vs 75.7 = stack gas velocity, ft/sec
As 2.18 = cross-sectional area of stack, ft2
Qa 9,909 = acfm
Average Stack Gas Flow at Standard Conditions (Qs), dscfm
Ps
Ts
where,
Qa 9,909 = average stack gas flow at stack conditions, acfm
BWS 0.091 = moisture fraction, dimensionless
Ps 26.20 = absolute stack gas pressure, in. Hg
Ts 816.0 = average pre/post test absolute stack temperature, °R
Qs 5,100 = dscfm
Qsd = 17.636 x Qa x (1 - BWS) x
14 of 76
Appendix A
Example Calculations
Location:
Source:
Project No.:
Run No. /Method
Run No.1
Methane - Outlet Concentration (as C3H8) (CCH4), ppmvd
CCH4w
1 - BWS
where,
CCH4w 1,105.5 = Methane - Outlet Concentration (as C3H8), ppmvw
BWS 0.091 = moisture fraction, unitless
CCH4 1,216.2 = ppmvd
Methane - Outlet Concentration (as C3H8) (CCH4w), ppmvw
where,
CCH4 1,216.2 = Methane - Outlet Concentration (as C3H8), ppmvd
BWS 0.091 = moisture fraction, unitless
CCH4w 1,105.5 = ppmvw
Methane - Outlet Concentration (as C3H8) (CCH4c15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CCH4 1,216.2 = Methane - Outlet Concentration (as C3H8), ppmvd
CO₂10.3 = oxygen concentration, %
CCH4c15 677.4 = ppmvd @15% O₂
Methane - Outlet Emission Rate (as C3H8) (ERCH4), lb/hr
where,
CCH4 1,216.2 = Methane - Outlet Concentration (as C3H8), ppmvd
MW 16.04 = CH4 molecular weight, g/g-mole
Qs 5,100 = stack gas volumetric flow rate at standard conditions, dscfm
ERCH4 15.5 = lb/hr
Methane - Outlet Emission Rate (as C3H8) (ERCH4TPY), ton/yr
ERCH4 x 8,760
2,000
where,
ERCH4 15.5 = Methane - Outlet Emission Rate (as C3H8), lb/hr
ERCH4TPY 67.8 = ton/yr
ERCH4 =CCH4 x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 454
CCH4w = CMethane x (1 - BWS)
CCH4c15 = CCH4 x
CCH4 =
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
Run 1 / Method 320
ERCH4TPY =

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
15 of 76
Appendix A
Example Calculations
Methane - Outlet Emission Factor (as C3H8) (EFCH4), g/bhp-hr
ERCH4 x 454
EBW
where,
ERCH4 15.5 = Methane - Outlet Emission Rate (as C3H8), lb/hr
EBW 2,509 = engine brake work, HP
EFCH4 2.8 = g/bhp-hr
EFCH4 =
𝑔
𝑙𝑏
16 of 76
Appendix A
Example Calculations
Location:
Source:
Project No.:
Run No./Method
Formaldehyde Concentration (CH2CO), ppmvd
where,
CH2COw 33.2 = H2CO concentration, ppmvw
BWS 0.091 = moisture fraction, unitless
CH2CO 36.5 = H2CO Concentration, ppmvd
Formaldehyde - Outlet Concentration (as C3H8) (CH2COw), ppmvw
where,
CH2CO 36.5 = Methane - Outlet Concentration (as C3H8), ppmvd
BWS 0.091 = moisture fraction, unitless
CH2COw 33.2 = ppmvw
Formaldehyde Concentration @ 15% Oxygen (CH2COc15), ppmvd @ 15% O2
where,
CH2CO 36.5 = H2CO Concentration, ppmvd
CO2 10.3 = O2 Concentration, %
CH2COc15 20.4 = ppmvd @ 15% O2
Formaldehyde Emission Rate (ERH2CO), lb/hr
where,
CH2CO 36.5 = H2CO Concentration, ppmvd
MW 30.026 = H2CO molecular weight, g/g-mole
Qs 5,100 = stack gas volumetric flow rate at standard conditions, dscfm
ERH2CO 0.87 = lb/hr
Formaldehyde Emission Rate (ERH2COTPY), ton/yr
where,
ERH2CO 0.87 = H2CO emission rate, lb/hr
ERH2COTPY 3.8 = ton/yr
Formaldehyde Emission Factor (EFH2CO), g/bhp-hr
where,
ERH2CO 0.87 = H2CO emission rate, lb/hr
EBW 2,509 = engine brake work, HP
EFH2CO 0.16 = g/bHP-hr
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
Run 1 Outlet/ Method 320
CH2COw = CH2CO x (1 - BWS)
17 of 76
Appendix A
Example Calculations
Location:
Source:
Project No.:
Run No. /Method
Run No.1
CO - Outlet Concentration (CCO), ppmvd
CCOw
1 - BWS
where,
CCOw 283.7 = CO - Outlet Concentration, ppmvw
BWS 0.091 = moisture fraction, unitless
CCO 312.1 = ppmvd
CO - Outlet Concentration (CCOc15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CCO 312.1 = CO - Outlet Concentration, ppmvd
CO₂10.3 = oxygen concentration, %
CCOc15 173.8 = ppmvd @15% O₂
CO - Outlet Emission Rate (ERCO), lb/hr
where,
CCO 312.1 = CO - Outlet Concentration, ppmvd
MW 28.01 = CO molecular weight, g/g-mole
Qs 5,100 = stack gas volumetric flow rate at standard conditions, dscfm
ERCO 6.9 = lb/hr
CO - Outlet Emission Rate (ERCOTPY), ton/yr
ERCO x 8,760
2,000
where,
ERCO 6.9 = CO - Outlet Emission Rate, lb/hr
ERCOTPY 30.4 = ton/yr
CO - Outlet Emission Factor (EFCO), g/bhp-hr
ERCO x 454
EBW
where,
ERCO 6.9 = CO - Outlet Emission Rate, lb/hr
EBW 2,509 = engine brake work, HP
EFCO 1.3 = g/bhp-hr
ERCO =CCO x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 454
ERCOTPY =
EFCO =
CCOc15 = CCO x
CCO =
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
Run 1 / Method 320

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
𝑔
𝑙𝑏
18 of 76
Appendix A
Example Calculations
Location:
Source:
Project No.:
Run No. /Method
Run No.1
NOx - Outlet Concentration (CNOx), ppmvd
CNOxw
1 - BWS
where,
CNOxw 60.4 = NOx - Outlet Concentration, ppmvw
BWS 0.091 = moisture fraction, unitless
CNOx 66.5 = ppmvd
NOx - Outlet Concentration (CNOxc15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CNOx 66.5 = NOx - Outlet Concentration, ppmvd
CO₂10.3 = oxygen concentration, %
CNOxc15 37.0 = ppmvd @15% O₂
NOx - Outlet Emission Rate (ERNOx), lb/hr
where,
CNOx 66.5 = NOx - Outlet Concentration, ppmvd
MW 46.0055 = NOx molecular weight, g/g-mole
Qs 5,100 = stack gas volumetric flow rate at standard conditions, dscfm
ERNOx 2.4 = lb/hr
NOx - Outlet Emission Rate (ERNOxTPY), ton/yr
ERNOx x 8,760
2,000
where,
ERNOx 2.4 = NOx - Outlet Emission Rate, lb/hr
ERNOxTPY 10.6 = ton/yr
NOx - Outlet Emission Factor (EFNOx), g/bhp-hr
ERNOx x 454
EBW
where,
ERNOx 2.4 = NOx - Outlet Emission Rate, lb/hr
EBW 2,509 = engine brake work, HP
EFNOx 0.44 = g/bhp-hr
ERNOx =CNOx x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 454
ERNOxTPY =
EFNOx =
CNOxc15 = CNOx x
CNOx =
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
Run 1 / Method 320

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
𝑔
𝑙𝑏
19 of 76
Appendix A
Example Calculations
Location:
Source:
Project No.:
Run No. /Method
VOC - Outlet Concentration (as C3H8) (CVOC), ppmvd
CVOCw
1 - BWS
where,
CVOCw 7.8 = VOC - Outlet Concentration (as C3H8), ppmvw
BWS 0.091 = moisture fraction, unitless
CVOC 8.6 = ppmvd
VOC - Outlet Concentration (as C3H8) (CVOCw), ppmvw
where,
CVOC 8.6 = VOC - Outlet Concentration (as C3H8), ppmvd
BWS 0.091 = moisture fraction, unitless
CVOCw 7.8 = ppmvw
VOC - Outlet Concentration (as C3H8) (CVOCc15), ppmvd @ 15% O₂
20.9 - 15
20.9 - O₂
where,
CVOC 8.6 = VOC - Outlet Concentration (as C3H8), ppmvd
CO₂10.3 = oxygen concentration, %
CVOCc15 4.8 = ppmvd @15% O₂
VOC - Outlet Emission Rate (as C3H8) (ERVOC), lb/hr
where,
CVOC 8.6 = VOC - Outlet Concentration (as C3H8), ppmvd
MW 44.1 = VOC molecular weight, g/g-mole
Qs 5,100 = stack gas volumetric flow rate at standard conditions, dscfm
ERVOC 0.30 = lb/hr
VOC - Outlet Emission Rate (as C3H8) (ERVOCTPY), ton/yr
ERVOC x 8,760
2,000
where,
ERVOC 0.30 = VOC - Outlet Emission Rate (as C3H8), lb/hr
ERVOCTPY 1.3 = ton/yr
ERVOCTPY =
ERVOC =CVOC x MW x Qs x 60 x 28.32
24.04 x 1.0E06 x 454
CVOCc15 = CVOC x
CVOC =
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
Run 1 / Method 320
CVOCw = CVOC x (1 - BWS)

𝑚𝑖𝑛
ℎ𝑟
𝐿
𝑓𝑡ଷ
𝐿
𝑔െ𝑚𝑜𝑙𝑒
𝑔
𝑙𝑏
𝑙𝑏
𝑡𝑜𝑛
ℎ𝑟
𝑦𝑟
20 of 76
Appendix A
Example Calculations
VOC - Outlet Emission Factor (as C3H8) (EFVOC), g/bhp-hr
ERVOC x 454
EBW
where,
ERVOC 0.30 = VOC - Outlet Emission Rate (as C3H8), lb/hr
EBW 2,509 = engine brake work, HP
EFVOC 0.054 = g/bhp-hr
EFVOC =
𝑔
𝑙𝑏
21 of 76

Appendix B

22 of 76
Emissions Calculations
Location
Source
Project No.
Run Number Run 1 Run 2 Run 3 Average
Date 3/2/22 3/2/22 3/2/22 --
Start Time 9:22 11:06 12:42 --
Stop Time 10:22 12:06 13:42 --
Engine Data
Engine Manufacturer
Engine Model
Engine Serial Number
Engine Type
Engine Date of Manufacturer DOM
Engine Hour Meter Reading EMR
Engine Brake Work, HP EBW 2,509 2,509 2,509 2,509
Maximum Engine Brake Work, HP MaxEBW 2,509 2,509 2,509 2,509
Engine Load, % EL 100 100 100 100
Fuel Heating Value, Btu/scf FHV 1,040 1,040 1,040 1,040
Fuel Factor (O2 dry), dscf/MMBtu Fd 8,710 8,710 8,710 8,710
Ambient Temperature TAmb 52 57 57 55
Relative Humidity, % RH 35 35 35 35
Barometric Pressure, in. Hg Pb 26.02 25.98 25.98 25.99
Moisture Fraction, dimensionless BWS 0.091 0.096 0.099 0.095
Volumetric Flow Rate (M1-4), dscfm Qs 5,100 5,134 5,150 5,128
O₂ Concentration, % dry CO₂10.31 10.30 10.29 10.30
CO₂ Concentration, % dry CCO₂9.09 9.14 9.21 9.15
Methane - Outlet Concentration, ppmvd CCH4 1,216.2 1,204.8 1,251.4 1,224.1
Methane - Outlet Concentration, ppmvw CCH4w 1,105.5 1,089.5 1,128.0 1,107.7
Methane - Outlet Concentration, ppmvd @ 15 % O₂CCH4c15 677.4 670.4 695.6 681.1
Methane - Outlet Emission Rate, lb/hr ERCH4 15.5 15.4 16.1 15.7
Methane - Outlet Emission Rate, ton/yr ERCH4TPY 67.8 67.7 70.5 68.7
Methane - Outlet Emission Factor, g/bHP-hr EFCH4 2.8 2.8 2.9 2.8
Formaldehyde - Outlet Concentration, ppmvd CCHOH 36.5 38.5 39.3 38.1
Formaldehyde - Outlet Concentration, ppmvw CCHOHw 33.2 34.8 35.4 34.5
Formaldehyde - Outlet Concentration, ppmvd @ 15 % O₂CCHOHc15 20.4 21.4 21.8 21.2
Formaldehyde - Outlet Emission Rate, lb/hr ERCHOH 0.87 0.92 0.95 0.91
Formaldehyde - Outlet Emission Rate, ton/yr ERCHOHTPY 3.8 4.0 4.1 4.0
Formaldehyde - Outlet Emission Factor, g/bHP-hr EFCHOH 0.16 0.17 0.17 0.17
CO - Outlet Concentration, ppmvd CCO 312.1 309.6 317.1 312.9
CO - Outlet Concentration, ppmvd @ 15 % O₂CCOc15 173.8 172.3 176.3 174.1
CO - Outlet Emission Rate, lb/hr ERCO 6.9 6.9 7.1 7.0
CO - Outlet Emission Rate, ton/yr ERCOTPY 30.4 30.4 31.2 30.7
CO - Outlet Emission Factor, g/bHP-hr EFCO 1.3 1.3 1.3 1.3
NOx - Outlet Concentration, ppmvd CNOx 66.5 65.4 62.9 64.9
NOx - Outlet Concentration, ppmvd @ 15 % O₂CNOxc15 37.0 36.4 35.0 36.1
NOx - Outlet Emission Rate, lb/hr ERNOx 2.4 2.4 2.3 2.4
NOx - Outlet Emission Rate, ton/yr ERNOxTPY 10.6 10.5 10.2 10.4
NOx - Outlet Emission Factor, g/bHP-hr EFNOx 0.44 0.43 0.42 0.43
VOC - Outlet Concentration, ppmvd CVOC 8.6 8.4 9.0 8.7
VOC - Outlet Concentration, ppmvw CVOCw 7.8 7.6 8.1 7.8
VOC - Outlet Concentration, ppmvd @ 15 % O₂CVOCc15 4.8 4.7 5.0 4.8
VOC - Outlet Emission Rate, lb/hr ERVOC 0.30 0.30 0.32 0.30
VOC - Outlet Emission Rate, ton/yr ERVOCTPY 1.3 1.3 1.4 1.3
VOC - Outlet Emission Factor, g/bHP-hr EFVOC 0.054 0.053 0.058 0.055
NMHC - Outlet Concentration, ppmvd CNMHC (as C3H8)15.0 14.8 15.9 15.2
NMHC - Outlet Concentration, ppmvw CNMHC (as C3H8)w 13.6 13.4 14.4 13.8
NMHC - Outlet Concentration, ppmvd @ 15 % O₂CNMHC (as C3H8)c15 8.4 8.2 8.9 8.5
NMHC - Outlet Emission Rate, lb/hr ERNMHC (as C3H8)0.53 0.52 0.56 0.54
NMHC - Outlet Emission Rate, ton/yr ERNMHC (as C3H8)TPY 2.3 2.3 2.5 2.3
NMHC - Outlet Emission Factor, g/bHP-hr EFNMHC (as C3H8)0.095 0.094 0.10 0.097
298
Input Data - Outlet
Calculated Data - Outlet
FTIR Calculated Data
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
GE
JMS 612-F28F02
1322446
Compression Ignition
2018
23 of 76
Run 1 - CEMS Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
9:22 10.30 9.27
9:23 10.28 9.23
9:24 10.32 9.20
9:25 10.31 9.25
9:26 10.29 9.28
9:27 10.30 9.24
9:28 10.32 9.26
9:29 10.34 9.21
9:30 10.38 9.25
9:31 10.31 9.21
9:32 10.37 9.22
9:33 10.34 9.19
9:34 10.39 9.21
9:35 10.32 9.23
9:36 10.35 9.20
9:37 10.31 9.21
9:38 10.34 9.24
9:39 10.36 9.20
9:40 10.32 9.27
9:41 10.31 9.19
9:42 10.30 9.24
9:43 10.34 9.22
9:44 10.36 9.21
9:45 10.33 9.20
9:46 10.34 9.16
9:47 10.36 9.22
9:48 10.37 9.17
9:49 10.33 9.22
9:50 10.34 9.13
9:51 10.38 9.14
9:52 10.39 9.21
9:53 10.39 9.18
9:54 10.38 9.13
9:55 10.40 9.13
9:56 10.42 9.18
9:57 10.37 9.15
9:58 10.39 9.17
9:59 10.39 9.13
10:00 10.40 9.16
10:01 10.40 9.12
10:02 10.44 9.11
10:03 10.41 9.17
10:04 10.36 9.17
10:05 10.39 9.18
10:06 10.41 9.16
10:07 10.36 9.14
10:08 10.37 9.22
10:09 10.39 9.16
10:10 10.37 9.16
10:11 10.38 9.16
10:12 10.37 9.18
10:13 10.34 9.17
10:14 10.39 9.15
10:15 10.33 9.15
10:16 10.36 9.15
10:17 10.37 9.17
10:18 10.36 9.16
10:19 10.38 9.15
10:20 10.40 9.15
10:21 10.40 9.13
Parameter O₂ - Outlet CO₂ - Outlet
Uncorrected Run Average (Cobs)10.4 9.2
Cal Gas Concentration (CMA)11.0 11.0
Pretest System Zero Response 0.08 0.09
Posttest System Zero Response 0.08 0.09
Average Zero Response (Co)0.1 0.1
Pretest System Cal Response 11.04 11.09
Posttest System Cal Response 11.06 11.10
Average Cal Response (CM)11.1 11.1
Corrected Run Average (Corr)10.3 9.1
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
24 of 76
Run 1 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet NMHC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvd ppmvw ppmvw ppmvw % (wet)
MDL ----0.38 0.25 0.63 2.68 ------
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
9:22 192.7 1.003 1,059.3 35.7 306.3 63.2 7.7 13.3 9.2
9:23 192.7 1.003 1,052.9 33.3 304.0 64.4 7.2 12.9 8.9
9:24 192.8 1.000 1,040.3 38.6 299.4 64.4 7.4 13.0 9.3
9:25 192.8 1.002 1,051.4 35.0 301.7 64.1 7.5 12.9 9.5
9:26 192.8 1.003 1,041.0 34.8 299.7 64.7 7.4 12.9 9.4
9:27 192.7 1.002 1,036.0 38.4 299.4 63.7 7.5 12.9 9.5
9:28 192.8 1.002 1,057.0 34.9 303.6 63.1 7.6 13.2 9.6
9:29 192.8 1.002 1,066.7 34.5 305.4 62.9 7.5 13.1 9.4
9:30 192.9 1.002 1,073.2 32.4 306.9 62.7 7.4 13.1 9.2
9:31 193.0 1.002 1,061.0 31.9 306.3 62.7 7.8 13.5 9.0
9:32 193.0 1.002 1,079.1 31.7 307.0 63.1 7.1 12.9 8.7
9:33 193.0 1.001 1,104.6 31.3 311.2 61.8 7.4 13.3 8.5
9:34 193.0 1.004 1,095.0 30.9 310.8 62.1 7.3 13.1 8.3
9:35 193.0 1.003 1,103.3 31.2 311.9 61.5 7.7 13.4 8.2
9:36 193.0 1.001 1,078.7 34.9 307.4 62.4 7.7 13.5 8.6
9:37 193.0 1.002 1,081.9 32.5 308.6 62.0 7.7 13.6 8.7
9:38 193.0 1.001 1,092.9 32.2 310.4 61.9 7.9 13.8 8.7
9:39 193.0 1.001 1,083.0 34.3 308.2 61.8 7.7 13.5 8.8
9:40 193.0 1.002 1,082.5 33.8 307.6 61.7 7.7 13.6 9.1
9:41 193.0 1.002 1,088.1 32.7 308.5 62.2 7.9 13.9 9.0
9:42 193.0 1.002 1,085.4 31.3 306.9 62.8 7.3 13.1 8.9
9:44 192.9 1.003 1,102.0 31.3 311.4 61.7 7.5 13.3 8.8
9:45 192.9 1.004 1,106.0 31.3 314.1 61.3 7.7 13.6 8.7
9:46 192.9 1.000 1,116.6 34.5 313.9 61.0 7.7 13.6 8.7
9:47 192.8 1.003 1,101.3 35.0 309.8 60.7 7.7 13.5 9.1
9:48 192.8 1.003 1,081.0 34.5 306.6 62.0 7.4 13.2 9.1
9:49 192.8 1.004 1,111.9 32.5 312.9 60.4 8.1 14.1 8.9
9:50 192.8 1.003 1,105.7 31.9 312.3 61.0 7.5 13.3 8.9
9:51 192.7 1.003 1,108.3 32.5 312.2 60.7 7.8 13.7 8.8
9:52 192.7 1.004 1,113.2 35.0 313.5 59.4 8.1 14.0 9.0
9:53 192.7 1.003 1,136.3 35.2 318.2 58.2 7.8 13.8 9.1
9:54 192.7 1.003 1,168.3 34.0 325.0 56.5 8.1 14.4 9.1
9:55 192.7 1.003 1,153.9 32.6 322.5 57.8 7.6 13.7 9.0
9:56 192.7 1.001 1,142.1 35.0 319.3 58.0 7.7 13.8 9.0
9:57 192.7 0.999 1,148.8 36.2 320.1 57.4 8.4 14.5 9.4
9:58 192.7 1.001 1,118.5 35.8 314.9 58.5 8.0 13.8 9.5
9:59 192.7 1.002 1,125.1 35.6 315.7 58.1 8.4 14.3 9.5
10:00 192.7 1.001 1,128.5 34.2 316.6 57.6 7.9 13.8 9.6
10:01 192.7 0.998 1,158.5 35.0 320.1 56.5 8.3 14.4 9.8
10:02 192.8 1.001 1,162.4 34.1 322.2 56.2 7.9 14.1 9.6
10:03 192.9 1.003 1,126.0 33.9 315.4 58.2 7.8 13.7 9.5
10:04 192.9 1.000 1,099.9 33.2 309.8 59.8 7.6 13.4 9.5
10:05 193.0 1.000 1,109.6 32.6 312.7 59.3 8.1 13.9 9.4
10:07 193.0 1.003 1,101.6 32.0 310.6 59.4 8.1 13.8 9.3
10:08 193.0 1.003 1,111.8 32.2 313.9 59.0 7.3 13.2 9.3
10:09 193.0 1.001 1,117.8 32.1 313.7 59.0 8.2 14.0 9.3
10:10 193.0 1.001 1,111.5 32.0 312.2 59.7 7.7 13.5 9.3
10:11 193.0 1.002 1,125.6 32.2 315.0 58.9 8.1 13.9 9.3
10:12 193.0 1.002 1,125.2 32.0 314.8 59.2 8.0 13.9 9.2
10:13 193.0 1.001 1,144.9 31.6 318.5 58.3 8.2 14.2 9.2
10:14 192.9 1.002 1,124.4 31.6 314.6 59.3 8.2 14.2 9.2
10:15 192.9 1.001 1,117.6 31.4 313.8 59.8 7.7 13.7 9.1
10:16 192.9 1.002 1,089.2 31.2 309.4 61.2 7.8 13.7 9.1
10:17 192.9 1.002 1,116.1 31.2 314.4 59.6 7.8 13.7 9.0
10:18 192.8 1.001 1,131.4 31.3 315.8 59.5 8.2 14.2 9.1
10:19 192.8 1.003 1,134.8 31.4 317.6 58.6 7.8 14.0 9.1
10:20 192.7 1.002 1,130.7 31.5 316.2 58.5 7.7 13.7 9.1
10:21 192.7 1.001 1,147.2 32.0 320.6 57.7 8.3 14.4 9.1
10:22 192.7 1.001 1,155.1 31.5 321.9 57.4 8.2 14.3 9.1
Parameter Temperature Pressure Methane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet NMHC - Outlet BWS - Outlet
Run Average 192.9 1.002 1105.5 33.2 312.1 60.4 7.8 13.6 9.1
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
25 of 76
Run 2 - CEMS Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
11:06 10.38 9.19
11:07 10.36 9.23
11:08 10.37 9.20
11:09 10.38 9.21
11:10 10.39 9.17
11:11 10.37 9.23
11:12 10.38 9.20
11:13 10.39 9.21
11:14 10.41 9.21
11:15 10.43 9.13
11:16 10.41 9.16
11:17 10.42 9.22
11:18 10.43 9.18
11:19 10.41 9.18
11:20 10.41 9.19
11:21 10.42 9.19
11:22 10.43 9.21
11:23 10.44 9.14
11:24 10.39 9.18
11:25 10.44 9.18
11:26 10.42 9.20
11:27 10.43 9.15
11:28 10.41 9.22
11:29 10.41 9.16
11:30 10.39 9.17
11:31 10.38 9.23
11:32 10.39 9.21
11:33 10.40 9.22
11:34 10.35 9.25
11:35 10.35 9.21
11:36 10.35 9.23
11:37 10.31 9.25
11:38 10.33 9.28
11:39 10.34 9.21
11:40 10.33 9.21
11:41 10.32 9.24
11:42 10.33 9.22
11:43 10.35 9.25
11:44 10.36 9.22
11:45 10.32 9.28
11:46 10.34 9.22
11:47 10.33 9.27
11:48 10.31 9.26
11:49 10.34 9.27
11:50 10.34 9.24
11:51 10.32 9.23
11:52 10.31 9.24
11:53 10.37 9.18
11:54 10.33 9.23
11:55 10.32 9.25
11:56 10.34 9.26
11:57 10.32 9.26
11:58 10.33 9.24
11:59 10.35 9.23
12:00 10.34 9.24
12:01 10.32 9.28
12:02 10.37 9.23
12:03 10.37 9.27
12:04 10.36 9.20
12:05 10.39 9.21
Parameter O₂ - Outlet CO₂ - Outlet
Uncorrected Run Average (Cobs)10.4 9.2
Cal Gas Concentration (CMA)11.0 11.0
Pretest System Zero Response 0.08 0.09
Posttest System Zero Response 0.12 0.14
Average Zero Response (Co)0.1 0.1
Pretest System Cal Response 11.06 11.10
Posttest System Cal Response 11.08 11.04
Average Cal Response (CM)11.1 11.1
Corrected Run Average (Corr)10.3 9.1
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
26 of 76
Run 2 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet NMHC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvd ppmvw ppmvw ppmvw % (wet)
MDL ----0.38 0.25 0.63 2.68 ------
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
11:06 192.6 1.008 1,142.3 37.6 317.8 53.4 8.1 14.1 10.4
11:07 192.6 1.007 1,125.4 37.0 317.1 54.6 7.8 13.8 10.3
11:08 192.7 1.008 1,138.7 37.3 318.6 54.9 8.2 14.2 10.2
11:09 192.6 1.007 1,129.4 36.6 315.7 55.6 8.0 13.9 10.0
11:10 192.6 1.007 1,139.2 36.5 318.4 55.5 8.2 14.2 9.9
11:11 192.6 1.008 1,129.1 36.7 316.4 55.6 8.3 14.2 9.9
11:12 192.6 1.009 1,114.8 36.3 314.0 56.4 8.1 13.9 9.7
11:13 192.6 1.007 1,136.4 35.9 318.3 55.3 7.8 13.9 9.7
11:14 192.6 1.010 1,108.5 35.9 313.6 56.4 7.5 13.2 9.7
11:15 192.6 1.008 1,136.8 36.1 318.3 56.0 8.0 13.9 9.9
11:16 192.6 1.009 1,128.7 35.9 318.1 56.2 8.0 14.0 9.9
11:17 192.6 1.009 1,137.8 36.1 320.6 55.3 8.3 14.3 9.8
11:18 192.6 1.008 1,137.8 36.1 321.1 55.5 8.1 14.2 9.8
11:19 192.7 1.008 1,158.1 35.8 323.5 55.5 7.7 13.9 9.7
11:20 192.8 1.008 1,138.1 35.5 320.5 55.9 7.9 13.9 9.6
11:21 192.8 1.008 1,137.1 35.3 320.9 55.9 8.0 14.0 9.5
11:22 192.8 1.008 1,141.6 34.9 319.5 55.8 7.6 13.6 9.4
11:24 192.8 1.008 1,144.9 34.9 320.8 55.3 7.8 13.8 9.4
11:25 192.9 1.006 1,145.2 35.0 321.2 55.8 7.7 13.7 9.4
11:26 193.0 1.008 1,149.4 35.0 322.9 55.6 7.9 13.9 9.4
11:27 192.9 1.006 1,161.1 34.9 324.6 54.6 8.0 14.2 9.5
11:28 193.0 1.007 1,133.3 35.0 319.7 55.5 7.9 13.9 9.5
11:29 193.0 1.007 1,145.0 35.8 320.6 55.3 7.9 13.9 9.6
11:30 193.0 1.007 1,123.8 35.4 315.6 56.6 7.7 13.6 9.7
11:31 193.0 1.006 1,098.4 35.3 312.2 57.1 8.3 14.1 9.8
11:32 193.0 1.007 1,093.0 35.6 310.3 57.8 7.6 13.3 9.8
11:33 193.0 1.007 1,090.5 35.4 310.1 58.7 7.7 13.3 9.7
11:34 192.9 1.006 1,068.5 35.4 306.8 59.5 7.6 13.4 9.7
11:35 192.9 1.006 1,059.7 35.3 304.8 60.0 7.6 13.3 9.7
11:36 192.9 1.007 1,051.0 35.5 301.4 60.7 7.3 12.9 9.8
11:37 192.8 1.006 1,046.7 35.2 300.6 62.0 7.3 13.0 9.8
11:38 192.8 1.005 1,042.5 34.7 299.9 63.0 7.0 12.5 9.8
11:39 192.8 1.007 1,044.5 34.1 300.2 63.1 6.9 12.4 9.6
11:40 192.7 1.008 1,038.5 34.1 299.4 63.4 7.1 12.6 9.5
11:41 192.7 1.009 1,036.6 34.0 298.0 63.6 7.2 12.7 9.4
11:42 192.7 1.009 1,033.6 33.9 297.6 63.1 7.1 12.6 9.3
11:43 192.7 1.009 1,038.1 33.3 300.1 62.7 7.5 12.9 9.2
11:44 192.6 1.009 1,049.2 33.2 301.8 63.0 7.1 12.7 9.2
11:45 192.6 1.009 1,046.0 33.2 300.8 62.9 7.3 13.0 9.2
11:47 192.6 1.006 1,042.0 34.1 300.0 63.2 7.2 12.8 9.3
11:48 192.6 1.006 1,024.3 34.7 297.9 62.8 7.0 12.5 9.6
11:49 192.6 1.006 1,043.5 35.0 300.6 62.0 7.4 12.9 9.8
11:50 192.6 1.007 1,050.8 35.5 300.1 61.0 7.3 13.0 9.9
11:51 192.6 1.006 1,046.0 35.8 298.7 60.9 7.0 12.7 10.0
11:52 192.7 1.006 1,037.8 36.2 297.0 61.2 7.3 12.8 10.1
11:53 192.7 1.005 1,038.4 36.6 298.8 61.4 7.1 12.5 10.2
11:54 192.8 1.005 1,029.7 36.6 297.4 62.2 7.2 12.6 10.3
11:55 192.8 1.005 1,029.2 36.8 297.6 62.2 7.2 12.7 10.3
11:56 192.9 1.006 1,044.0 35.8 299.4 61.5 7.2 12.8 10.2
11:57 192.9 1.006 1,038.1 34.4 299.1 62.6 7.5 13.0 9.8
11:58 193.0 1.007 1,055.3 33.6 302.0 61.9 7.5 13.2 9.6
11:59 193.0 1.008 1,058.1 32.9 302.3 62.3 7.1 12.7 9.3
12:00 193.0 1.010 1,053.6 32.4 303.3 62.3 7.7 13.3 9.1
12:01 193.0 1.011 1,053.6 30.9 303.3 63.0 7.5 13.2 8.7
12:02 193.0 1.009 1,081.2 30.0 309.7 62.0 7.4 13.3 8.4
12:03 193.0 1.009 1,113.8 29.8 315.7 60.6 7.3 13.1 8.1
12:04 193.0 1.010 1,118.2 30.3 316.6 59.9 7.4 13.3 8.0
12:05 193.0 1.008 1,115.0 31.6 315.1 60.0 7.4 13.2 8.2
12:06 193.0 1.007 1,088.6 31.6 310.8 61.7 7.7 13.5 8.4
Parameter Temperature Pressure Methane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet NMHC - Outlet BWS - Outlet
Run Average 192.8 1.007 1089.5 34.8 309.6 59.1 7.6 13.4 9.6
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
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Run 3 - CEMS Data
Location:
Source:
Project No.:
Date:
Time O₂ - Outlet CO₂ - Outlet
Unit % dry % dry
Status Valid Valid
12:42 10.34 9.17
12:43 10.34 9.14
12:44 10.37 9.21
12:45 10.35 9.16
12:46 10.35 9.17
12:47 10.35 9.19
12:48 10.35 9.14
12:49 10.36 9.16
12:50 10.32 9.15
12:51 10.34 9.19
12:52 10.33 9.18
12:53 10.34 9.19
12:54 10.33 9.18
12:55 10.32 9.19
12:56 10.29 9.22
12:57 10.33 9.20
12:58 10.32 9.23
12:59 10.31 9.21
13:00 10.33 9.25
13:01 10.31 9.19
13:02 10.29 9.18
13:03 10.28 9.26
13:04 10.30 9.24
13:05 10.31 9.21
13:06 10.34 9.14
13:07 10.35 9.19
13:08 10.35 9.16
13:09 10.33 9.19
13:10 10.27 9.21
13:11 10.32 9.23
13:12 10.28 9.20
13:13 10.28 9.22
13:14 10.30 9.22
13:15 10.24 9.26
13:16 10.30 9.25
13:17 10.31 9.19
13:18 10.25 9.19
13:19 10.26 9.20
13:20 10.27 9.22
13:21 10.28 9.27
13:22 10.25 9.23
13:23 10.27 9.23
13:24 10.29 9.21
13:25 10.31 9.22
13:26 10.28 9.22
13:27 10.27 9.27
13:28 10.29 9.25
13:29 10.29 9.22
13:30 10.28 9.18
13:31 10.28 9.22
13:32 10.37 9.21
13:33 10.29 9.24
13:34 10.33 9.21
13:35 10.30 9.23
13:36 10.34 9.19
13:37 10.35 9.19
13:38 10.31 9.20
13:39 10.36 9.27
13:40 10.35 9.16
13:41 10.34 9.14
Parameter O₂ - Outlet CO₂ - Outlet
Uncorrected Run Average (Cobs)10.3 9.2
Cal Gas Concentration (CMA)11.0 11.0
Pretest System Zero Response 0.12 0.14
Posttest System Zero Response 0.10 0.14
Average Zero Response (Co)0.1 0.1
Pretest System Cal Response 11.08 11.04
Posttest System Cal Response 10.96 10.90
Average Cal Response (CM)11.0 11.0
Corrected Run Average (Corr)10.3 9.2
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
28 of 76
Run 3 - FTIR Data
Location:
Source:
Project No.:
Date:
Time Temperature Pressure Methane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet NMHC - Outlet BWS - Outlet
Unit ° C atm ppmvw ppmvw ppmvd ppmvw ppmvw ppmvw % (wet)
MDL ----0.38 0.25 0.63 2.68 ------
Status Valid Valid Valid Valid Valid Valid Valid Valid Valid
12:42 193.0 1.006 1,155.7 35.6 321.5 52.8 8.5 15.0 10.4
12:43 193.0 1.007 1,156.0 36.4 320.8 53.4 8.2 14.6 10.3
12:44 193.0 1.008 1,155.9 37.5 321.4 53.3 8.3 14.8 10.3
12:45 193.0 1.009 1,173.8 37.3 324.0 52.6 8.4 15.0 10.1
12:46 193.0 1.007 1,157.6 36.9 322.6 53.4 8.5 14.9 10.1
12:47 193.0 1.007 1,149.5 36.4 322.9 54.1 8.2 14.7 10.0
12:48 193.0 1.007 1,177.4 36.0 326.1 53.6 8.2 14.8 9.9
12:49 193.0 1.008 1,172.8 35.9 324.9 53.4 8.0 14.6 9.7
12:50 193.0 1.008 1,176.8 35.6 326.0 53.8 8.6 15.2 9.6
12:51 193.0 1.007 1,181.1 34.6 327.5 53.7 8.5 15.2 9.6
12:52 193.0 1.007 1,183.4 34.9 327.7 54.2 8.4 15.1 9.7
12:53 193.0 1.006 1,174.4 35.8 325.6 54.2 8.4 14.9 9.9
12:55 193.0 1.007 1,137.2 35.5 318.8 55.3 8.1 14.5 9.9
12:56 193.0 1.006 1,160.1 35.6 323.7 54.8 8.2 14.6 9.9
12:57 193.0 1.007 1,117.7 35.7 315.4 57.4 8.6 14.8 9.9
12:58 193.0 1.006 1,142.9 35.7 319.5 56.2 8.0 14.4 9.9
12:59 193.0 1.007 1,125.8 35.9 317.8 57.4 8.3 14.5 9.8
13:00 193.0 1.007 1,099.5 35.6 312.7 57.7 8.1 14.2 9.7
13:01 193.0 1.007 1,120.7 35.6 316.2 57.5 7.8 14.1 9.6
13:02 193.0 1.007 1,129.7 35.6 318.4 57.3 8.2 14.6 9.6
13:03 193.0 1.007 1,102.7 35.3 311.8 58.0 8.0 14.1 9.6
13:04 193.0 1.006 1,107.3 35.5 312.8 58.4 7.9 14.0 9.7
13:05 193.0 1.009 1,090.8 35.0 307.9 58.7 7.7 13.7 9.7
13:06 193.0 1.009 1,110.6 34.2 313.6 57.6 7.7 13.8 9.6
13:07 193.0 1.006 1,140.9 34.4 321.0 56.2 8.6 15.0 9.7
13:08 193.0 1.008 1,139.0 34.4 319.2 57.2 8.1 14.4 9.7
13:09 192.9 1.007 1,156.1 34.0 322.2 56.7 8.2 14.7 9.7
13:10 193.0 1.009 1,120.2 33.5 315.7 57.8 7.6 13.8 9.6
13:11 193.0 1.008 1,143.2 33.5 318.8 57.4 8.1 14.5 9.5
13:12 193.0 1.008 1,140.9 33.9 319.1 57.3 8.1 14.5 9.6
13:13 192.9 1.008 1,111.2 34.2 314.2 59.0 8.2 14.4 9.7
13:14 192.9 1.007 1,125.5 34.6 316.8 58.0 8.6 14.8 9.8
13:15 192.9 1.006 1,089.0 35.5 307.9 60.4 8.1 14.1 9.9
13:16 192.9 1.006 1,106.2 36.2 312.3 57.9 7.9 14.1 10.1
13:18 192.9 1.007 1,115.2 36.3 313.6 57.6 8.2 14.4 10.2
13:19 192.9 1.006 1,098.2 36.7 310.1 59.3 7.9 14.0 10.3
13:20 192.9 1.006 1,059.9 36.4 303.0 61.1 7.9 14.1 10.2
13:21 192.9 1.006 1,084.9 36.6 310.1 58.8 7.7 13.9 10.2
13:22 192.9 1.007 1,084.5 36.4 307.3 59.4 7.7 13.9 10.2
13:23 192.9 1.006 1,067.5 36.5 304.4 60.8 7.7 13.8 10.3
13:24 192.9 1.005 1,074.6 36.9 307.0 59.6 7.7 13.9 10.3
13:25 192.9 1.006 1,098.6 36.8 310.9 57.8 7.9 14.0 10.2
13:26 192.8 1.006 1,110.3 36.2 314.3 57.2 8.4 14.7 10.2
13:27 192.8 1.007 1,103.4 36.0 311.7 59.5 8.0 14.1 10.0
13:28 192.8 1.008 1,099.6 35.8 312.5 59.6 8.1 14.2 9.9
13:29 192.8 1.009 1,105.5 35.4 313.1 58.7 7.9 14.2 9.7
13:30 192.8 1.008 1,105.0 34.0 313.4 59.2 8.2 14.4 9.6
13:31 192.8 1.007 1,103.4 33.4 313.4 58.8 8.4 14.5 9.6
13:32 192.9 1.008 1,147.6 33.2 321.6 56.2 8.0 14.4 9.5
13:33 192.8 1.008 1,127.9 32.9 318.3 57.0 8.1 14.5 9.4
13:34 192.8 1.009 1,118.4 32.6 317.0 56.9 8.0 14.4 9.3
13:35 192.8 1.007 1,120.9 33.0 317.5 56.7 7.9 14.2 9.3
13:36 192.8 1.008 1,141.1 34.0 320.7 55.6 8.2 14.7 9.5
13:37 192.8 1.006 1,139.8 34.5 320.4 56.8 7.7 14.3 9.6
13:38 192.8 1.005 1,146.0 36.3 320.2 56.1 8.0 14.5 9.8
13:39 192.8 1.006 1,142.6 36.6 321.2 55.3 8.5 15.1 9.9
13:41 192.8 1.007 1,157.6 36.9 322.0 54.3 8.5 15.2 10.0
13:42 192.8 1.005 1,141.6 37.5 320.8 54.7 8.2 14.7 10.2
13:43 192.8 1.005 319.1 54.4 8.6 8.6 10.3
Parameter Temperature Pressure Methane - Outlet Formaldehyde - Outlet CO - Outlet NOx - Outlet VOC - Outlet NMHC - Outlet BWS - Outlet
Run Average 192.9 1.007 1128.0 35.4 317.1 56.7 8.1 14.4 9.9
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
29 of 76
Method 1 Data
Location
Source
Project No.
Date:
Vertical
Circular
26.00 in
6.00 in
20.00 in
2.18 ft2
2
1
1.1 ft
0.7 (must be > 0.5)
4.1 ft
2.5 (must be > 2)
16
16
Measurer (Initial and Date):ABB 3/1/22
Reviewer (Initial and Date):GMT 3/1/22
2345 6 789101112
1 14.6 -- 6.7 -- 4.4 -- 3.2 -- 2.6 -- 2.1 1 3.2 0.64 6.64
2 85.4 -- 25.0 -- 14.6 -- 10.5 -- 8.2 -- 6.7 2 10.52.108.10
3 -- -- 75.0 -- 29.6 -- 19.4 -- 14.6 -- 11.8 3 19.43.889.88
4 -- -- 93.3 -- 70.4 -- 32.3 -- 22.6 -- 17.7 4 32.3 6.46 12.46
5 -- -- -- -- 85.4 -- 67.7 -- 34.2 -- 25.0 5 67.7 13.54 19.54
6 -- -- -- -- 95.6 -- 80.6 -- 65.8 -- 35.6 6 80.6 16.12 22.12
7 -- -- -- -- -- -- 89.5 -- 77.4 -- 64.4 7 89.5 17.90 23.90
8 -- -- -- -- -- -- 96.8 -- 85.4 -- 75.0 8 96.8 19.36 25.36
9 -- -- -- -- -- -- -- -- 91.8 -- 82.3 9 -- -- --
10 -- -- -- -- -- -- -- -- 97.4 -- 88.2 10 -- -- --
11 -- -- -- -- -- -- -- -- -- -- 93.3 11 -- -- --
12 -- -- -- -- -- -- -- -- -- -- 97.9 12 -- -- --
*Percent of stack diameter from inside wall to traverse point.
A = 1.1 ft.
B = 4.1 ft.
Depth of Duct = 20 in.
Cross Sectional Area of Duct:
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
03/01/22
Stack Parameters
Duct Orientation:
Duct Design:
Distance from Far Wall to Outside of Port:
Nipple Length:
Depth of Duct:
No. of Test Ports:
Number of Readings per Point:
Distance A:
Distance A Duct Diameters:
Distance B:
Distance B Duct Diameters:
Minimum Number of Traverse Points:
Actual Number of Traverse Points:
CIRCULAR DUCT
Number of traverse points on a diameter
Stack Diagram
Cross Sectional Area
LOCATION OF TRAVERSE POINTS Traverse
Point
% of
Diameter
Distance
from inside
wall
Distance
from
outside of
port
Upstream 
Disturbance
Downstream 
Disturbance
B
A
30 of 76
Cyclonic Flow Check
Location
Source
Project No.
Date
Sample Point Angle (ΔP=0)
1 -5
2 -3
3 -7
4 -6
5 -6
6 -10
7 -10
8 -5
9 0
10 5
11 5
12 8
13 15
14 15
15 10
16 5
Average 7.2
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/22
31 of 76
Field Data
Method 2 Data
Location
Source
Project No.
Δ P
(in. WC)
Ts
(°F)
Δ P
(in. WC)
Ts
(°F)
Δ P
(in. WC)
Ts
(°F)
0.95 359 0.98 360 1.00 361
1.00 360 1.00 360 0.99 361
1.00 360 1.10 361 1.00 362
1.10 361 1.20 361 1.10 363
1.10 362 1.10 362 1.20 363
1.00 362 1.00 362 1.20 363
1.00 363 1.00 362 1.00 363
0.98 363 1.00 362 1.00 362
0.99 361 0.99 362 0.98 362
0.99 363 0.99 362 1.00 363
1.00 363 1.00 363 1.10 363
1.10 364 1.10 363 1.10 363
1.20 365 1.30 364 1.20 363
1.10 365 1.20 364 1.20 364
0.99 365 1.00 364 1.10 363
0.95 365 1.00 364 1.00 363
Average
Square Root of ΔP, (in. WC)1/2 (ΔP)1/2 1.026
Average ΔP, in. WC (ΔP)1.05
Pitot Tube Coefficient (Cp)0.840
Barometric Pressure, in. Hg (Pb)26.02
Static Pressure, in. WC (Pg)2.40
Stack Pressure, in. Hg (Ps)26.20
Average Temperature, °F (Ts)360.4
Average Temperature, °R (Ts)820.1
Measured Moisture Fraction (BWSmsd)0.095
Moisture Fraction @ Saturation (BWSsat)11.269
Moisture Fraction (BWS)0.095
O2 Concentration, % (O2)10.3
CO2 Concentration, % (CO2)9.1
Molecuar Weight, lb/lb-mole (dry) (Md)29.88
Molecuar Weight, lb/lb-mole (wet) (Ms)28.74
Velocity, ft/sec (Vs)76.9
VFR at stack conditions, acfm (Qa)10,062
VFR at standard conditions, scfh (Qsw)340,118
VFR at standard conditions, scfm (Qsw)5,669
VFR at standard conditions, dscfm (Qsd)5,128
8
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
Run No. 1 2 3
Status VALID VALID VALID
Date 3/2/22 3/2/22 3/2/22
Stop Time 9:40 11:20 13:00
Start Time 9:30 11:10 12:50
Traverse Point
A-1
2
3
4
Leak Check Pass Pass Pass
3
4
5
6
7
5
6
7
8
B-1
2
0.840 0.840 0.840
1.03 1.06 1.07
1.013 1.029 1.035
2.40 2.40 2.40
26.02 26.02 26.02
356.3 362.3 362.6
26.20 26.20 26.20
0.091 0.096 0.099
816.0 821.9 822.3
29.87 29.87 29.89
10.3 10.3 10.3
9.1 9.1 9.2
75.7 77.2 77.7
28.79 28.74 28.71
9,909 10,103 10,174
5,611 5,679 5,716
336,637 340,738 342,978
5,100 5,134 5,150
11.57911.52610.702
0.0990.0960.091
32 of 76

Appendix C

33 of 76
QA Data
Location
Source
Project No.
O₂ - Outlet CO₂ - Outlet
Make Servomex Servomex
Model 4900 4900
S/N 0410403-2409 0410403-2409
Operating Range 0-100 0-100
Cylinder ID
Zero NA NA
Low NA NA
Mid EB0104764 EB0104764
High EB0104764 EB0104764
Cylinder Certifed Values
Low NA NA
Mid 24.0 23.9
High 24.0 23.9
Cylinder Expiration Date
Zero NA NA
Low NA NA
Mid 4/27/29 4/27/29
High 4/27/29 4/27/29
Parameter
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
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Calibration Data
Location:
Source:
Project No.:
Date:
O₂ - Outlet CO₂ - Outlet
Expected Average Concentration 12.0 12.0
Span Between
Low 12.0 12.0
High 60.0 60.0
Desired Span 24.0 23.9
Low Range Gas
Low NA NA
High NA NA
Mid Range Gas
Low 9.6 9.6
High 14.4 14.3
High Range Gas
Low NA NA
High NA NA
Actual Concentration (% or ppm)
Zero 0.0 0.0
Low NA NA
Mid 11.0 11.0
High 24.0 23.9
Response Time (seconds)45.0 45.0
Upscale Calibration Gas (CMA)Mid Mid
Instrument Response (% or ppm)
Zero 0.0 0.0
Low NA NA
Mid 11.1 11.4
High 24.0 24.0
Performance (% of Span or Cal. Gas Conc.)
Zero 0.0 0.0
Low NA NA
Mid 0.3 1.5
High 0.0 0.2
Status
Zero PASS PASS
Low NA NA
Mid PASS PASS
High PASS PASS
Parameter
3/2/22
AST-2022-0470
Jenbacher #4
Central Valley Water Reclamation - CVWR
35 of 76
Bias/Drift Determinations
Location:
Source:
Project No.:
O₂ - Outlet CO₂ - Outlet
Run 1 Date 3/2/22
Span Value 24.0 23.9
Initial Instrument Zero Cal Response 0.0 0.0
Initial Instrument Upscale Cal Response 11.1 11.4
Pretest System Zero Response 0.1 0.1
Posttest System Zero Response 0.1 0.1
Pretest System Upscale Response 11.0 11.1
Posttest System Upscale Response 11.1 11.1
Bias (%)
Pretest Zero 0.3 0.4
Posttest Zero 0.3 0.4
Pretest Span -0.1 -1.1
Posttest Span 0.0 -1.0
Drift (%)
Zero 0.0 0.0
Mid 0.1 0.0
Run 2 Date 3/2/22
Span Value 24.0 23.9
Instrument Zero Cal Response 0.0 0.0
Instrument Upscale Cal Response 11.1 11.4
Pretest System Zero Response 0.1 0.1
Posttest System Zero Response 0.1 0.1
Pretest System Upscale Response 11.1 11.1
Posttest System Upscale Response 11.1 11.0
Bias (%)
Pretest Zero 0.3 0.4
Posttest Zero 0.5 0.6
Pretest Span 0.0 -1.0
Posttest Span 0.0 -1.3
Drift (%)
Zero 0.2 0.2
Mid 0.1 -0.3
Run 3 Date 3/2/22
Span Value 24.0 23.9
Instrument Zero Cal Response 0.0 0.0
Instrument Upscale Cal Response 11.1 11.4
Pretest System Zero Response 0.1 0.1
Posttest System Zero Response 0.1 0.1
Pretest System Upscale Response 11.1 11.0
Posttest System Upscale Response 11.0 10.9
Bias (%)
Pretest Zero 0.5 0.6
Posttest Zero 0.4 0.6
Pretest Span 0.0 -1.3
Posttest Span -0.5 -1.9
Drift (%)
Zero -0.1 0.0
Mid -0.5 -0.6
Parameter
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
36 of 76
37 of 76
Location
Source(s)
Project No.
Date(s)
Ethylene Cylinder ID
Concentration (ppmv)
Instrument Outlet
CTS 1 94.54 CTS 7 93.36 AVERAGE 93.48 Greatest Deviation from average
CTS 2 93.18 CTS 8 93.64 MAX 94.54 1.13%
CTS 3 93.18 CTS 9 ‐‐ deviation 1.05
CTS 4 93.65 CTS 10 ‐‐ MIN 93.07 Agreement with Assumed Pathlength
CTS 5 93.07 CTS 11 ‐‐ deviation 0.42 96.87%
CTS 6 93.26 CTS 12 ‐‐within 5% no correction required
CTS 1 CTS 7
Date Time File Temperature (CPressure Ethylene Date Time File Temperature (CPressure Ethylene
2/28/22 14:51:40 N2_0834.LAB 192.4 1.002 94.26 3/2/22 12:32:30 CTS 7_1934.LAB 193.0 1.007 92.92
2/28/22 14:51:44 N2_0835.LAB 192.4 1.002 94.72 3/2/22 12:33:33 CTS 7_1935.LAB 193.1 1.006 93.22
2/28/22 14:51:48 N2_0836.LAB 192.4 1.002 94.64 3/2/22 12:34:36 CTS 7_1936.LAB 193.1 1.006 93.95
CTS 2 CTS 8
Date Time File Temperature (CPressure Ethylene Date Time File Temperature (CPressure Ethylene
2/28/22 16:53:42 CTS2_0928.LAB 192.9 1.009 92.94 3/2/22 14:04:25 CTS 8_2004.LAB 193.0 1.002 93.83
2/28/22 16:54:44 CTS2_0929.LAB 192.9 0.913 93.33 3/2/22 14:05:28 CTS 8_2005.LAB 192.9 1.002 93.64
2/28/22 16:55:47 CTS2_0930.LAB 192.9 0.899 93.27 3/2/22 14:06:31 CTS 8_2006.LAB 192.9 1.002 93.47
CTS 3 CTS 9
Date Time File Temperature (CPressure Ethylene Date Time File Temperature (CPressure Ethylene
3/1/22 7:59:36 CTS3_0948.LAB 193.0 1.002 93.31
3/1/22 8:00:39 CTS3_0949.LAB 193.0 1.002 93.00
3/1/22 8:01:42 CTS3_0950.LAB 193.0 1.002 93.21
CTS 4 CTS 10
Date Time File Temperature (CPressure Ethylene Date Time File Temperature (CPressure Ethylene
3/1/22 10:02:55 CTS4_1028.LAB 192.9 1.002 93.53
3/1/22 10:03:58 CTS4_1029.LAB 192.9 1.001 93.45
3/1/22 10:05:01 CTS4_1030.LAB 192.9 1.001 93.97
CTS 5 CTS 11
Date Time File Temperature (CPressure Ethylene Date Time File Temperature (CPressure Ethylene
3/2/22 8:00:08 CTS5_1734.LAB 192.9 1.003 93.32
3/2/22 8:01:10 CTS5_1735.LAB 192.8 1.003 93.25
3/2/22 8:02:13 CTS5_1736.LAB 192.8 1.003 92.62
CTS 6 CTS 12
Date Time File Temperature (CPressure Ethylene Date Time File Temperature (CPressure Ethylene
3/2/22 10:57:44 CTS 6_1864.LAB 192.8 1.007 93.36
3/2/22 10:58:47 CTS 6_1865.LAB 192.8 1.007 93.26
3/2/22 10:59:49 CTS 6_1866.LAB 192.8 1.007 93.15
MKS 8 (Serial #017778272)
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28-3/2/22
96.5
EB0072307
38 of 76
Location
Source
Project No.
Date
EB0096620 Component
96.6 Acetaldehyde
EB0096620 Component
5.12 SF6
Instrument ID Outlet
Direct Spike Values
Date Time File Temperature (C) Pressure Spike (ppm) Tracer (ppm)
02/28/22 15:21:12 ACETALDEHYDE S 193.0 0.900 94.12 5.248
02/28/22 15:22:14 ACETALDEHYDE S 193.0 0.900 93.57 5.241
02/28/22 15:23:17 ACETALDEHYDE S 192.9 0.900 93.32 5.226
02/28/22 15:24:20 ACETALDEHYDE S 192.9 0.900 92.83 5.202
02/28/22 15:25:23 ACETALDEHYDE S 193.0 0.900 92.44 5.216
02/28/22 15:26:25 ACETALDEHYDE S 192.9 0.900 92.47 5.193
02/28/22 15:27:28 ACETALDEHYDE S 193.0 0.900 92.31 5.192
Average 93.01 5.217
Native Values
Date Time File Temperature (C) Pressure Spike (ppm) Tracer (ppm)
02/28/22 15:56:06 NATIVE_0886.LAB 192.8 1.007 0.29 0.036
02/28/22 15:57:09 NATIVE_0887.LAB 192.7 1.002 0.69 0.028
02/28/22 15:58:11 NATIVE_0888.LAB 192.7 1.000 0.80 0.030
02/28/22 15:59:14 NATIVE_0889.LAB 192.7 1.006 0.49 0.032
02/28/22 16:00:17 NATIVE_0890.LAB 192.7 1.004 0.55 0.029
02/28/22 16:01:20 NATIVE_0891.LAB 192.7 1.004 0.60 0.030
02/28/22 16:02:22 NATIVE_0892.LAB 192.7 0.999 0.75 0.029
Average 0.59 0.031
Spiked values
Date Time File Temperature (C) Pressure Spike (ppm) Tracer (ppm)
02/28/22 16:16:21 SPIKE_0903.LAB 192.8 1.001 8.09 0.470
02/28/22 16:17:24 SPIKE_0904.LAB 192.8 1.000 8.04 0.470
02/28/22 16:18:27 SPIKE_0905.LAB 192.8 1.003 8.07 0.467
02/28/22 16:19:30 SPIKE_0906.LAB 192.8 0.994 9.01 0.490
02/28/22 16:20:32 SPIKE_0907.LAB 192.8 0.997 8.49 0.481
02/28/22 16:21:35 SPIKE_0908.LAB 192.8 1.000 8.28 0.466
02/28/22 16:22:38 SPIKE_0909.LAB 192.8 1.001 8.36 0.462
Average 8.33 0.472
Dilution Factor
8.5%
Calculated Spike
8.42
Spike Recovery
98.99%
MKS 8 (Serial #017778272)
Tracer Cylinder ID
Tracer Gas concentration
Spike Gas concentration
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28/2022
Spike Cylinder ID
39 of 76
Location
Project No.
Instrument
Source Jenbacher #4
Date 2/28/22
Time 16:16
Analyte Acetaldehyde
Direct 93.01
Native 0.59
Spiked 8.33
Dilution  8.5%
Recovery 99%
Result PASS
Summary of Spikes
Central Valley Water Reclamation - CVWR
AST-2022-0470
MKS 8 (Serial #017778272)
40 of 76
This is to certify the gases referenced have been calibrated/tested, and verified to meet the defined specifications. This
calibration/test was performed using Gases or Scales that are traceable through National Institute of Standards and
Technology (NIST) to the International System of Units (SI). The basis of compliance stated is a comparison of the
measurement parameters to the specified or required calibration/testing process. The expanded uncertainties use a
coverage factor of k=2 to approximate the 95% confidence level of the measurement, unless otherwise noted. This
calibration certificate applies only to the item described and shall not be reproduced other than in full, without written approval
from Red Ball Technical Gas Services. If not included, the uncertainty of calibrations are available upon request and were
taken into account when determining pass or fail.
Anthony Cyr
Assistant Operations Manager
Assay Laboratory: Red Ball TGS
Version 02-G, Revised on 2017-07-02
MPC Date
C2H4 FTIR MKS MKS 2031DJG2EKVS13T 017146467
Analytical Instrumentation SMART-CERT
Component Principle Make Model Serial
97.8 PPM 2 191064EB0004963EB000496306/22/2021 PS N2 C2H4
Reference Standard(s)
Serial Number Lot Expiration Type Balance Component Concentration Uncertainty(%)NIST Reference
Nitrogen
Analytical Measurement Data Available Online.
Balance
Ethylene
Certified Concentration(s)
Component Concentration Uncertainty Analytical Principle
96.5 PPM ± 2% NIST FTIR
Customer:Previous Certification Dates:
Do Not Use This Cylinder Below 100 psig (0.7 Megapascal).
This mixture is for laboratory use only, not for drug, household or other use.
This mixture is certified in Mole % to be within ±2% of the actual number reported with a confidence of 95%.
This mixture was manufactured by scale; weights traceable to N.I.S.T. Certificate #822/266926-02.
COA #EB0072307.20200909-0 Lot Number:EB0072307.20200909
Customer PO. NO.:Tracking Number:084248576
Product ID Number:124838 Expiration Date:09/11/2022
Cylinder Pressure:1900 PSIG MFG Facility: - Shreveport - LA
CERTIFIED GAS CERTIFICATE OF ANALYSIS
Cylinder Number:EB0072307 Certification Date:09/11/2020
Red Ball Technical Gas Service
555 Craig Kennedy Way
Shreveport, LA 71107
800-551-8150
Accreditation #62754 PGVP Vendor ID # G12020
41 of 76
5.12 PPM ± 2% NIST FTIR
This is to certify the gases referenced have been calibrated/tested, and verified to meet the defined specifications. This
calibration/test was performed using Gases or Scales that are traceable through National Institute of Standards and
Technology (NIST) to the International System of Units (SI). The basis of compliance stated is a comparison of the
measurement parameters to the specified or required calibration/testing process. The expanded uncertainties use a
coverage factor of k=2 to approximate the 95% confidence level of the measurement, unless otherwise noted. This
calibration certificate applies only to the item described and shall not be reproduced other than in full, without written approval
from Red Ball Technical Gas Services. If not included, the uncertainty of calibrations are available upon request and were
taken into account when determining pass or fail.
Anthony Cyr
Assistant Operations Manager
Assay Laboratory: Red Ball TGS
Version 02-G, Revised on 2017-07-02
MKS MKS 2031DJG2EKVS13T 017146467
MPC Date
SF6 FTIR MKS MKS 2031DJG2EKVS13T 017146467
C2H4O FTIR
Analytical Instrumentation SMART-CERT
Component Principle Make Model Serial
5 191064
98.2 PPM 2 191064
EB0003113 EB0003113 06/22/2021 PS N2 SF6 5.04 PPM
EB0003113 EB0003113 06/22/2021 PS N2 C2H4O
Reference Standard(s)
Serial Number Lot Expiration Type Balance Component Concentration Uncertainty(%)NIST Reference
Nitrogen
Analytical Measurement Data Available Online.
Balance
Acetaldehyde
Sulfur Hexafluoride
Certified Concentration(s)
Component Concentration Uncertainty Analytical Principle
96.6 PPM ± 2% NIST FTIR
Customer:Previous Certification Dates:
Do Not Use This Cylinder Below 100 psig (0.7 Megapascal).
This mixture is for laboratory use only, not for drug, household or other use.
This mixture is certified in Mole % to be within ±2% of the actual number reported with a confidence of 95%.
This mixture was manufactured by scale; weights traceable to N.I.S.T. Certificate #822/266926-02.
COA #EB0096620.20210105-0 Lot Number:EB0096620.20210105
Customer PO. NO.:Tracking Number:095690988
Product ID Number:125303 Expiration Date:01/20/2023
Cylinder Pressure:1900 PSIG MFG Facility: - Shreveport - LA
CERTIFIED GAS CERTIFICATE OF ANALYSIS
Cylinder Number:EB0096620 Certification Date:01/20/2021
Red Ball Technical Gas Service
555 Craig Kennedy Way
Shreveport, LA 71107
800-551-8150
Accreditation #62754 PGVP Vendor ID # G12021
42 of 76
Location
Source(s)
Project No.
Health Check Parameter MKS - Single Beam (Pre-Test)
Instrument ID MKS 8 (Serial #017778272)
Date
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28/2022
43 of 76
Location
Source(s)
Project No.
Health Check Parameter MKS - Single Beam (Post-Test)
Instrument ID MKS 8 (Serial #017778272)
Date
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/2022
44 of 76
Location
Source(s)
Project No.
Health Check Parameter MKS - Detector Linearity
Instrument ID MKS 8 (Serial #017778272)
Date
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28/2022
45 of 76
Location
Source(s)
Project No.
Health Check Parameter MKS - Peak Analysis
Instrument ID MKS 8 (Serial #017778272)
Date
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28/2022
46 of 76
Location
Source(s)
Project No.
Health Check Parameter MKS - Signal to Noise Ratio
Instrument ID MKS 8 (Serial #017778272)
Date
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28/2022
47 of 76
Location
Source(s)
Project No.
Health Check Parameter MKS - Analysis Validation Utility
Instrument ID MKS 8 (Serial #017778272)
Date
Analysis Validation Report
Sample Filename: C:\2022\22‐0470 CVWR\NATIVE_0884.LAB
Filename for noise: C:\2022\22‐0470 CVWR\N2_0749.LAB
Interferences Filenames: C:\OLT\Support Spectra 1min 191C LN2\Carbon Dioxide (19.03%, 5.11m, 191c).lab
Recipe path: C:\OLT\RECIPES\NG Engines R3.MGRCP
Gas calibration Name Conc MDC3 MDC2 MDC1 MAU FMU*R OCU ~ DL
NO (350,3000) 191C 43.78 1.99 2.68 1.17 1.59 2.71 2.71 3.37
NO2 (150) 191C (1OF2) 25.25 0.45 0.27 0.14 0.15 0.48 0.48 0.36
NO2 (2000) 191C (2OF2) 21.7 9.17 4.59 4.07 5.19 11.7 11.7 5.57
N2O (100,200,300) 191C 0.54 0.15 0.1 0.25 0.29 0.17 0.29 0.1
CH4 (250) 191C (1OF2) 816.84 79.88 0.38 1.17 3.11 186.38 186.38 0.48
CH4 (3000) 191C (2OF2) 904.01 14.68 1.51 5.36 8.83 21.9 21.9 2.09
NH3 (300) 191C (1OF2) 0.15 0.83 0.74 0.59 0.99 1.4 1.4 0.93
NH3 (3000) 191C (2OF2) 0.17 4.91 2.84 6.4 12.09 9.26 12.09 3.78
H2O% (20) 191C 5.71 0.07 ‐0.04 0.08 0.14 0.14 ‐
CO2% (20) 191C 6.6 0.18 ‐0.06 0.08 0.25 0.25 ‐
CO (500) 191C (1OF2) 275.43 19.78 0.63 0.97 2.1 39.39 39.39 0.78
CO% (1) 191C (2OF2) 0.03 0 0 00000
ETHANE (500) 191C 14.6 2.08 0.34 0.9 1 2.31 2.31 0.45
ETHYLENE (100,3000) 191C 11.24 1.2 0.73 0.82 1.42 2.08 2.08 0.99
ACETYLENE (1000) 191C 0.27 3.4 0.17 1.9 2.55 4.56 4.56 0.17
PROPANE (200) 191C ‐1.87 1.12 0.72 0.47 0.51 1.2 1.2 0.94
PROPYLENE (200,1000) 191 0.29 2.75 1.78 2.15 2.52 3.22 3.22 2.24
BUTANE (200) 191C 2.16 1.03 0.29 0.46 0.54 1.21 1.21 0.31
ACETALDEHYDE (500) 191C 0.53 5.73 1.73 2.22 2.86 7.38 7.38 2.21
FORMIC ACID (10) 191C 1.07 0.38 0.81 0.3 0.36 0.46 0.46 1.03
MEOH (10) 191C 0.99 0.45 0.41 0.78 0.9 0.52 0.9 0.51
SF6 (28) 8.76 0.89 ‐0.3 0.34 0.99 0.99 ‐
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
2/28/2022
48 of 76
Location
Source(s)
Project No.
Spectra (CTS)
Date
Time 14:51
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
N2_0834.LAB
2/28/2022
49 of 76
Location
Source(s)
Project No.
Spectra (Analyte Direct)
Date
Time 15:21
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
ACETALDEHYDE SF6_0859.LAB
2/28/2022
50 of 76
Location
Source(s)
Project No.
Spectra (Native)
Date
Time 15:56
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
NATIVE_0886.LAB
2/28/2022
51 of 76
Location
Source(s)
Project No.
Spectra (Spike)
Date
Time 16:16
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
SPIKE_0903.LAB
2/28/2022
52 of 76
EPA Method 205
Field Calibration of Dilution System
Location:
Project No.:
Date
(%) lpm (%) (%) (%) (%) (%) (%) (%)( ± 2 %)
10L/5L 80.0 5.0 19.2 19.2 19.3 19.2 19.2 19.25 0.05 0.3%
10L/5L 50.0 5.0 12.0 12.0 12.1 12.1 12.1 12.10 0.10 0.8%
10L/1L 20.0 4.0 4.8 4.8 4.8 4.8 4.9 4.82 0.02 0.4%
10L/1L 10.0 4.0 2.4 2.4 2.5 2.4 2.4 2.42 0.02 1.0%
(%)( ± 2 %)( ± 2 %)( ± 2 %)
19.25 0.4% -0.2% -0.3%
12.10 0.0% 0.1% -0.1%
4.82 -0.2% -0.4% 0.6%
2.42 1.9% -1.4% -0.6%
Mid-Level Supply Gas Calibration Direct to Analyzer
Calibration Injection 1 Injection 2 Injection 3 Average
Gas Analyzer Analyzer Analyzer Analyzer
Concentration Concentration Concentration Concentration Concentration
(%)(%)(%)(%)(%)(%)( ± 2 %)
11.18 11.2 11.2 11.2 11.20 0.02 0.2%
Average
Analyzer
Concentration
Injection 1
Error
Injection 2
Error
Injection 3
Error
Difference
Average
Error
*Not all AST Environics Units have 2-10L Mass Flow Controllers. For these units the 90% @ 7lpm and 80% @ 7lpm injections will not be conducted.
Cylinder Gas ID (Mid-Level): EB0081895
Cylinder Gas Concentration (Mid-Level), %: 11.18
Target Mass Flow
Contollers
Target
Dilution
Target Flow
Rate
Target
Concentration
Actual
Concentration
Injection 1
Analyzer
Concentration
Injection 2
Analyzer
Concentration
Injection 3
Analyzer
Concentration
Average
Analyzer
Concentration Difference Average Error
Component/Balance Gas: O2/N2
Cylinder Gas ID (Dilution): EB0104764
Cylinder Gas Concentration (Dilution), %: 24.0
Analyzer Model: 4900
Analyzer SN: 0410403-2409
Environics ID: 8029
Analyzer Make: Servomex
Central Valley Water Reclamation - CVWR
AST-2022-0470
3/2/22
53 of 76
Dilution System Make:
Dilution System Model:
Dilution System S/N:
Calibration Equipment Make:
Calibration Equipment Model:
Calibration Equipment S/N:
Flow Cell S/N:
Flow Cell S/N:
Calibration Gas:
Barometric Pressure, mmHg:
Ambient Temperature, °F:
Mass Flow Controller ID
Size, ccm:
Make:
Model:
S/N:
Set Flow True Flow Difference Set Flow True Flow Difference Set Flow True Flow Difference
cc/min cc/min cc/min cc/min cc/min cc/min
5%500 510 2.0% 500 513 2.6% 50 51 2.0%
10%1,000 1,018 1.8% 1,000 1,027 2.7% 100 101 1.0%
20%2,000 2,041 2.1% 2,000 2,045 2.3% 200 202 1.0%
30%3,000 3,058 1.9% 3,000 3,059 2.0% 300 303 1.0%
40%4,000 4,074 1.9% 4,000 4,070 1.8% 400 404 1.0%
50%5,000 5,084 1.7% 5,000 5,094 1.9% 500 504 0.8%
60%6,000 6,097 1.6% 6,000 6,099 1.7% 600 605 0.8%
70%7,000 7,119 1.7% 7,000 7,136 1.9% 700 707 1.0%
80%8,000 8,150 1.9% 8,000 8,160 2.0% 800 811 1.4%
90%9,000 9,179 2.0% 9,000 9,193 2.1% 900 915 1.7%
100%10,000 10,214 2.1% 10,000 10,225 2.3% 1,000 1,022 2.2%
Date
EFC 202 EFC 202
65.8
Environics
8029
#1
10,000
Environics
4040
Alicat Scientific
197206, 197208
197206
197208
Nitrogen
25.79
Calibration Performed By Kyle Vaughan 
3/18/21
0455242003
Mass Flow Controller Calibration
Note:  The mass flow controller's calibration values are used by the dilution system's operating software to improve accuracy.  These calibrations are not 
necessarily indicative of the systems overall performance.  Performance is verified by conducting a Method 205 prior to each field use.
M‐10SLPD/5MM‐D/5M, M‐1SLPM‐D/5M
EFC 202
10,000
# 2# 3
Environics
0455242004
1,000
Environics
0455238002
54 of 76
CERTIFICATE OF ANALYSIS
Grade of Product: EPA Protocol
Part Number:E03NI78E15A0225 Reference Number:153-124603219-1
Cylinder Number:EB0081895 Cylinder Volume:151.7 CF
Laboratory:124 - Tooele (SAP) - UT Cylinder Pressure:2015 PSIG
PGVP Number:B72017 Valve Outlet:590
Gas Code:CO2,O2,BALN Certification Date:Feb 14, 2017
Expiration Date:Feb 14, 2025
Certification performed in accordance with “EPA Traceability Protocol for Assay and Certification of Gaseous Calibration Standards (May 2012)” document EPA
600/R-12/531, using the assay procedures listed. Analytical Methodology does not require correction for analytical interference. This cylinder has a total analytical
uncertainty as stated below with a confidence level of 95%. There are no significant impurities which affect the use of this calibration mixture. All concentrations are on a
mole/mole basis unless otherwise noted.
Do Not Use This Cylinder below 100 psig, i.e. 0.7 megapascals.
ANALYTICAL RESULTS
Component Requested Actual Protocol Total Relative Assay
Concentration Concentration Method Uncertainty Dates
CARBON DIOXIDE 11.00 %10.80 %G1 +/- 0.7% NIST Traceable 02/14/2017
OXYGEN 11.00 %11.18 %G1 +/- 0.7% NIST Traceable 02/14/2017
NITROGEN Balance -
CALIBRATION STANDARDS
Type Lot ID Cylinder No Concentration Uncertainty Expiration Date
NTRM 1 CC413742 16.939 % CARBON DIOXIDE/NITROGEN 0.60 May 08, 2019
NTRM 98051014 SG9162888BAL 12.05 % OXYGEN/NITROGEN 0.7%Dec 02, 2017
ANALYTICAL EQUIPMENT
Instrument/Make/Model Analytical Principle Last Multipoint Calibration
Horiba VIA-510 SV4MEUTJ CO2 CO2 NDIR (Dixon)Feb 13, 2017
Horiba MPA-510 X9A4UGL8 O2 O2 Paramagnetic (Dixon)Jan 19, 2017
Triad Data Available Upon Request
Airgas Specialty GasesAirgas USA, LLC
525 North Industrial Loop Road
Tooele, UT 84074
Airgas.com
Signature on file
Approved for Release Page 1 of 153-124603219-1
55 of 76
QA Data
Stratification Check
Location:
Source:
Project No.:
Date:
Time O2 CO2
(%)(%)
A-1 9:00 10.3 9.2
2 9:02 10.3 9.2
3 9:04 10.2 9.3
10.3 9.2
Single Point Single Point
Average
Criteria Met
Traverse Point
Sampling Method Single Point Sampling
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
3/2/2022
56 of 76
Location
Source
Project No.
Parameter(s):
3/2/22 P-867 no no no
Date Probe or
Thermocouple ID
Reference
Temp. (°F)
Indicated
Temp. (°F)Difference Criteria
3/2/22 P-867 250.0 250.0 0.0%
3/2/22 Weather Station NA NA NA
Date Pitot ID
Evidence of
damage?
Evidence of
mis-alignment?
Calibration or
Repair required?
Central Valley Water Reclamation - CVWR
Jenbacher #4
AST-2022-0470
VFR
± 1.5 % (absolute)
Date Barometric
Pressure
Evidence of
damage?
Reading
Verified
Calibration or
Repair required?Weather Station Location
Salt Lake City, UT
57 of 76

Appendix D

58 of 76
Location Central Valley Water Reclamation - CVWR
Source Jenbacher #4
Project No.AST-2022-0470
Run Number Run 1 Run 2 Run 3
Date 3/2/22 3/2/22 3/2/22
Start Time 9:22 11:06 12:42
Stop Time 10:22 12:06 13:42
Engine Brake Work, HP (EBW)
Time, 0 min 2,509 2,509 2,509
Time, 15 min 2,509 2,509 2,509
Time, 30 min 2,509 2,509 2,509
Time, 45 min 2,509 2,509 2,509
Time, 60 min 2,509 2,509 2,509
Average 2,509 2,509 2,509
Engine Load, % (EL)
Time, 0 min 100 100 100
Time, 15 min 100 100 100
Time, 30 min 100 100 100
Time, 45 min 100 100 100
Time, 60 min 100 100 100
Average 100 100 100
Engine Operational Data
59 of 76

Appendix E

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62 of 76
Central Valley Water Reclamation Facility 
800 W Central Valley Road 
Salt Lake City, UT 84119‐3379 

Source to be Tested: Jenbacher Engine #4 
Proposed Test Date: March 1, 2022 

AST Project No. 2022‐0470 

Prepared By 
Alliance Source Testing, LLC 
3683 W 2270 S, Suite E 
West Valley City, UT 84120 
Site Specific Test Plan 
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Site Specific Test Plan
Test Program Summary

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Regulatory Information

Permit No. DAQE-AN104140015-21
Regulatory Citation 40 CFR 60, Subpart JJJJ

Source Information

Source Name Source ID Target Parameters
GE Jenbacher Model JMS 612-
F28F02 Generator Engine Jenbacher #4 NOx, CO, VOC, NMHC

Contact Information

Test Location Test Company
Central Valley Water Reclamation Facility
Wastewater Treatment Plant
800 W Central Valley Road
Salt Lake City, UT 84119-3379

Bryan Mansell
[e-mail]
[phone]

Alliance Source Testing, LLC
3683 W 2270 S, Suite E
West Valley City, UT 84120

Project Manager
Kyle Vaughan
[e-mail]
[phone]

Field Team Leader
Guy Grebe
[e-mail]
[phone]
(subject to change)

QA/QC Manager
Heather Morgan
[e-mail]
[phone]

Test Plan/Report Coordinator
Sarah Perry
[e-mail]
[phone]

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Site Specific Test Plan
Table of Contents

AST-2022-0470 Central Valley –Salt Lake City, UT Page ii

TABLE OF CONTENTS

1.0 Introduction .................................................................................................................................................. 1-1 
1.1 Process/Control System Descriptions ...................................................................................................... 1-1 
1.2 Project Team ............................................................................................................................................ 1-1 
1.3 Safety Requirements ................................................................................................................................ 1-1 
2.0 Summary of Test Program ............................................................................................................................ 2-1 
2.1 General Description ................................................................................................................................. 2-1 
2.2 Process/Control System Parameters to be Monitored and Recorded ....................................................... 2-1 
2.3 Proposed Test Schedule ........................................................................................................................... 2-1 
2.4 Emission Limits ....................................................................................................................................... 2-2 
2.5 Test Report ............................................................................................................................................... 2-3 
3.0 Testing Methodology .................................................................................................................................... 3-1 
3.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate ..... 3-1 
3.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide ........................................................... 3-1 
3.3 U.S. EPA Reference Test Method 320 – H2O, NOx, CO, VOC, and NMHC .......................................... 3-2 
3.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification ........................................... 3-2 
3.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A .......................................... 3-2 
3.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320 ................................................. 3-3 
4.0 Quality Assurance Program .......................................................................................................................... 4-1 
4.1 Equipment ................................................................................................................................................ 4-1 
4.2 Field Sampling ......................................................................................................................................... 4-2 

LIST OF TABLES

Table 1-1 Project Team ........................................................................................................................................ 1-1 
Table 2-1 Program Outline and Tentative Test Schedule..................................................................................... 2-2 
Table 2-2 Emission Limits ................................................................................................................................... 2-2 
Table 3-1 Source Testing Methodology ............................................................................................................... 3-1 

LIST OF APPENDICES
Appendix A Method 1 Data
Appendix B Example Field Data Sheets

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Site Specific Test Plan
Introduction

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1.0 Introduction
Alliance Source Testing, LLC (AST) was retained by Central Valley Wastewater Reclamation Facility (Central
Valley) to conduct compliance testing at the Wastewater Treatment Plant in Salt Lake City, Utah. Portions of the
facility are subject to provisions of the 40 CFR 60, Subpart JJJJ and the Utah Department of Environmental Quality,
Division of Air Quality (UDAQ) Approval Order (AO) DAQE-AN104140015-21. Testing will be conducted to
determine the emission rates of nitrogen oxides (NOx), carbon monoxide (CO), volatile organic compounds (VOC)
and non-methane hydrocarbons (NMHC) from the exhaust of the new GE Jenbacher Model JSM 612-F28F02
engine designated as Jenbacher #4. The VOC emissions will not include formaldehyde.

This site-specific test plan (SSTP) has been prepared to address the notification and testing requirements of the
UDAQ permit and the NSPS.
1.1 Process/Control System Descriptions
Central Valley operates two (2) GE Jenbacher Model JMS 612-F28F02 generator engines. Each engine is rates at
2,509 horsepower (hp) each. The engines can be fired on natural gas or digester gas. Jenbacher #4 is the subject of
this test program and will be fired on a mixed gas of blended digester gas and natural gas.

1.2 Project Team
Personnel planned to be involved in this project are identified in the following table.

Table 1-1
Project Team
Central Valley Personnel Bryan Mansell
Regulatory Agency UDAQ
AST Personnel Guy Grebe
other field personnel assigned at time of testing event

1.3 Safety Requirements
Testing personnel will undergo site-specific safety training for all applicable areas upon arrival at the site. AST
personnel will have current OSHA or MSHA safety training and be equipped with hard hats, safety glasses with side
shields, steel-toed safety shoes, hearing protection, fire resistant clothing, and fall protection (including shock
corded lanyards and full-body harnesses). AST personnel will conduct themselves in a manner consistent with
Client and AST’s safety policies.

A Job Safety Analysis (JSA) will be completed daily by the AST Field Team Leader.

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Site Specific Test Plan
Summary of Test Programs

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2.0 Summary of Test Program
To satisfy the requirements of the UDAQ permit and the NSPS, the facility will conduct a performance test program
to determine the compliance status of the Jenbacher #4.
2.1 General Description
All testing will be performed in accordance with specifications stipulated in U.S. EPA Reference Test Methods 1, 2,
3A and 320. Table 2-1 presents an outline and tentative schedule for the emissions testing program. The following
is a summary of the test objectives.

 Testing will be performed to demonstrate compliance with the UDAQ permit and 40 CFR 60, Subpart JJJJ.
 Emissions testing will be conducted on the exhaust of Jenbacher #4.
 Performance testing will be conducted at no less than 90% of the production rate achieved to date.
 Each of the three (3) test runs will be approximately 60 minutes in duration.
 Concurrent oxygen (O2), carbon dioxide (CO2) and moisture content (H2O) will be collected during each
test run and combined with facility data to calculate emission rates in grams per break horsepower hour
(g/bhp-hr).
2.2 Process/Control System Parameters to be Monitored and Recorded
Plant personnel will collect operational and parametric data at least once every 15 minutes during the testing. The
following list identifies the measurements, observations and records that will be collected during the testing
program:

 Ambient Temperature (°F)
 Barometric Pressure (“HgA)
 Relative Humidity (%)
 Compressor Process Conditions
 Engine Operating Load
 Fuel Consumption
2.3 Proposed Test Schedule
Table 2-1 presents an outline and tentative schedule for the emissions testing program.

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Table 2-1
Program Outline and Tentative Test Schedule

Testing Location Parameter US EPA Method No. of Runs Run Duration Est. Onsite
Time
DAY 1 – February 28, 2022
Equipment Setup & Pretest QA/QC Checks 6 hr
DAY 2 – March 1, 2022
Jenbacher #4
VFR 1-2
3 60 min 10 hr
O2/CO2 3A
BWS

320
NOx
CO
VOC 1
NMHC
DAY 3 – March 2, 2022
Contingency Day (if needed)
1 VOC measurements will not include formaldehyde
2.4 Emission Limits
Emission limits for each pollutant are below.

Table 2-2
Emission Limits

Source Pollutant Citation
Jenbacher #4
(Digester Gas Mode)
NOx – 0.55 g/bhp-hr
Permit
CO – 2.5 g/bhp-hr
VOC – 1.0 g/bhp-hr
NMHC – 0.3 g/bhp-hr
Jenbacher #4
(Natural Gas Mode)
NOx – 0.55 g/bhp-hr
CO – 2.0 g/bhp-hr
VOC – 0.7 g/bhp-hr
NMHC – 0.3 g/bhp-hr
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2.5 Test Report
The final test report must be submitted within 60 days of the completion of the performance test and will include the
following information
 Introduction – Brief discussion of project scope of work and activities.
 Results and Discussion – A summary of test results and process/control system operational data with
comparison to regulatory requirements or vendor guarantees along with a description of process conditions
and/or testing deviations that may have affected the testing results.
 Methodology – A description of the sampling and analytical methodologies.
 Sample Calculations – Example calculations for each target parameter.
 Field Data – Copies of actual handwritten or electronic field data sheets.
 Quality Control Data – Copies of all instrument calibration data and/or calibration gas certificates.
 Process Operating/Control System Data – Process operating and control system data (as provided by
Central Valley) to support the test results.
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Site Specific Test Plan
Testing Methodology

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3.0 Testing Methodology
This section provides a description of the sampling and analytical procedures for each test method that will be
employed during the test program. All equipment, procedures and quality assurance measures necessary for the
completion of the test program meet or exceed the specifications of each relevant test method. The emission testing
program will be conducted in accordance with the test methods listed in Table 3-1.

Table 3-1
Source Testing Methodology
Parameter U.S. EPA Reference
Test Methods Notes/Remarks
Volumetric Flow Rate 1 & 2 Full Velocity Traverses
Oxygen / Carbon Dioxide 3A Instrumental Analysis
Moisture Content / Nitrogen Oxides / Carbon
Monoxide / Volatile Organic Compounds /
Non-Methane Hydrocarbons
320 FTIR
Gas Dilution System Certification 205 --

All stack diameters, depths, widths, upstream and downstream disturbance distances and nipple lengths will be
measured on site with a verification measurement provided by the Field Team Leader.

3.1 U.S. EPA Reference Test Methods 1 and 2 – Sampling/Traverse Points and Volumetric Flow Rate
The sampling location and number of traverse (sampling) points will be selected in accordance with U.S. EPA
Reference Test Method 1. To determine the minimum number of traverse points, the upstream and downstream
distances will be equated into equivalent diameters and compared to Figure 1-2 in U.S. EPA Reference Test Method
1.

Full velocity traverses will be conducted in accordance with U.S. EPA Reference Test Method 2 to determine the
average stack gas velocity pressure, static pressure and temperature. The velocity and static pressure measurement
system will consist of a pitot tube and inclined manometer. The stack gas temperature will be measured with a K-
type thermocouple and pyrometer.

Stack gas velocity pressure and temperature readings will be recorded during each test run. The data collected will
be utilized to calculate the volumetric flow rate in accordance with U.S. EPA Reference Test Method 2.
3.2 U.S. EPA Reference Test Method 3A – Oxygen/Carbon Dioxide
The oxygen (O2) and carbon dioxide (CO2) testing will be conducted in accordance with U.S. EPA Reference Test
Method 3A. Data will be collected online and reported in one-minute averages. The sampling system will consist
of a stainless steel probe, Teflon sample line(s), gas conditioning system and the identified gas analyzer. The gas
conditioning system will be a non-contact condenser used to remove moisture from the stack gas. If an unheated
Teflon sample line is used, then a portable non-contact condenser will be placed in the system directly after the
probe. Otherwise, a heated Teflon sample line will be used. The quality control measures are described in Section
3.5.
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3.3 U.S. EPA Reference Test Method 320 – H2O, NOx, CO, VOC, and NMHC
The concentrations of moisture content (H2O), nitrogen oxides (NOx), carbon monoxide (CO), volatile organic
compounds (VOC) and non-methane hydrocarbons (NMHC) will be determined in accordance with U.S. EPA
Reference Test Method 320. Each source gas stream will be extracted at a constant rate through a heated probe,
heated filter and heated sample line and analyzed with a MKS MultiGas 2030 FTIR operated by a portable
computer. The computer has FTIR spectra of calibration gases stored on the hard drive. These single component
calibration spectra are used to analyze the measured sample spectra. The gas components to be measured will be
selected from the spectra library and incorporated into the analytical method. The signal amplitude, linearity, and
signal to noise ratio will be measured and recorded to document analyzer performance. A leak check will be
performed on the sample cell. The instrument path length will be verified using ethylene as the Calibration Transfer
Standard. Dynamic spiking will be performed using a certified standard of the target compound or appropriate
surrogate in nitrogen with sulfur hexafluoride blended as a tracer to calculate the dilution factor. All test spectra,
interferograms, and analytical method information are recorded and stored with the calculated analytical results. The
quality control measures are described in Section 3.6.
3.4 U.S. EPA Reference Test Method 205 – Gas Dilution System Certification
A calibration gas dilution system field check will be conducted in accordance with U.S. EPA Reference Method
205. Multiple dilution rates and total gas flow rates will be utilized to force the dilution system to perform two
dilutions on each mass flow controller. The diluted calibration gases will be sent directly to the analyzer, and the
analyzer response recorded in an electronic field data sheet. The analyzer response must agree within 2% of the
actual diluted gas concentration. A second Protocol 1 calibration gas, with a cylinder concentration within 10% of
one of the gas divider settings described above, will be introduced directly to the analyzer, and the analyzer response
recorded in an electronic field data sheet. The cylinder concentration and the analyzer response must agree within
2%. These steps will be repeated three (3) times.
3.5 Quality Assurance/Quality Control – U.S. EPA Reference Test Method 3A
Cylinder calibration gases will meet EPA Protocol 1 (+/- 2%) standards. Copies of all calibration gas certificates
will be included in the Quality Assurance/Quality Control Appendix of the report.

Low Level gas will be introduced directly to the analyzer. After adjusting the analyzer to the Low Level gas
concentration and once the analyzer reading is stable, the analyzer value will be recorded. This process will be
repeated for the High Level gas. For the Calibration Error Test, Low, Mid, and High Level calibration gases will be
sequentially introduced directly to the analyzer. The Calibration Error for each gas must be within 2.0 percent of the
Calibration Span or 0.5 ppmv/% absolute difference.

High or Mid Level gas (whichever is closer to the stack gas concentration) will be introduced at the probe and the
time required for the analyzer reading to reach 95 percent or 0.5 ppm/% (whichever was less restrictive) of the gas
concentration will be recorded. The analyzer reading will be observed until it reaches a stable value, and this value
will be recorded. Next, Low Level gas will be introduced at the probe and the time required for the analyzer reading
to decrease to a value within 5.0 percent or 0.5 ppm//% (whichever was less restrictive) will be recorded. If the Low
Level gas is zero gas, the acceptable response must be 5.0 percent of the upscale gas concentration or 0.5 ppm/%
(whichever was less restrictive). The analyzer reading will be observed until it reaches a stable value and this value
will be recorded. The measurement system response time and initial system bias will be determined from these data.
The System Bias for each gas must be within 5.0 percent of the Calibration Span or 0.5 ppmv/% absolute difference.

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High or Mid Level gas (whichever is closer to the stack gas concentration) will be introduced at the probe. After the
analyzer response is stable, the value will be recorded. Next, Low Level gas will be introduced at the probe, and the
analyzer value will be recorded once it reaches a stable response. The System Bias for each gas must be within 5.0
percent of the Calibration Span or 0.5 ppmv/% absolute difference or the data is invalidated and the Calibration
Error Test and System Bias must be repeated.

The Drift between pre- and post-run System Bias must be within 3 percent of the Calibration Span or 0.5 ppmv/%
absolute difference or the Calibration Error Test and System Bias must be repeated.

To determine the number of sampling points, a gas stratification check will be conducted prior to initiating testing.
The pollutant concentrations will be measured at twelve traverse points (as described in Method 1) or three points
(16.7, 50.0 and 83.3 percent of the measurement line). Each traverse point will be sampled for a minimum of twice
the system response time.

If the pollutant concentration at each traverse point do not differ more than 5% or 0.5 ppm/0.3% (whichever is less
restrictive) of the average pollutant concentration, then single point sampling will be conducted during the test runs.
If the pollutant concentration does not meet these specifications but differs less than 10% or 1.0 ppm/0.5% from the
average concentration, then three (3) point sampling will be conducted (stacks less than 7.8 feet in diameter - 16.7,
50.0 and 83.3 percent of the measurement line; stacks greater than 7.8 feet in diameter – 0.4, 1.0, and 2.0 meters
from the stack wall). If the pollutant concentration differs by more than 10% or 1.0 ppm/0.5% from the average
concentration, then sampling will be conducted at a minimum of twelve (12) traverse points. Copies of stratification
check data will be included in the Quality Assurance/Quality Control Appendix of the report.

A Data Acquisition System with battery backup will be used to record the instrument response in one (1) minute
averages. The data will be continuously stored as a *.CSV file in Excel format on the hard drive of a computer. At
the completion of testing, the data will also be saved to the AST server. All data will be reviewed by the Field Team
Leader before leaving the facility. Once arriving at AST’s office, all written and electronic data will be relinquished
to the report coordinator and then a final review will be performed by the Project Manager.

3.6 Quality Assurance/Quality Control – U.S. EPA Reference Method 320
EPA Protocol 1 Calibration Gases – Cylinder calibration gases used will meet EPA Protocol 1 (+/- 2%) standards or
will be certified standards.

After providing ample time for the FTIR to reach the desired temperature and to stabilize, zero gas (nitrogen) will be
introduced directly to the instrument sample port. While flowing nitrogen the signal amplitude will be recorded, a
background spectra will be taken, a linearity check will be performed and recorded, the peak to peak noise and the
root mean square in the spectral region of interest will be measured and a screenshot will be recorded.

Following the zero gas checks, room air will be pulled through the sample chamber and the line width and resolution
will be verified to be at 1879 cm-1, the peak position will be entered and the FWHH will be recorded (screenshot).
Following these checks, another background spectra will be recorded and the calibration transfer standard (CTS)
will be introduced directly to the instrument sample port. The CTS instrument recovery will be recorded and the
instrument mechanical response time will be measured.

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Next, stack gas will be introduced to the FTIR through the sampling system and several scans will be taken until a
stable reading will be achieved. The native concentration of our surrogate or target spiking analyte will be recorded.
Spike gas will be introduced to the sampling system at a constant flow rate ≤ 10% of the total sample flow rate and a
corresponding dilution ratio will be calculated along with a system response time. Matrix spike recovery spectra
will be recorded and will be within the ± 30% of the calculated value of the spike concentration that the method
requires.

The matrix spike recovery will be conducted once at the beginning of the testing and the CTS recovery procedures
will be repeated following each test run. The corresponding values will be recorded.

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Quality Assurance Program

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4.0 Quality Assurance Program
AST follows the procedures outlined in the Quality Assurance/Quality Control Management Plan to ensure the
continuous production of useful and valid data throughout the course of this test program. The QC checks and
procedures described in this section represent an integral part of the overall sampling and analytical scheme.
Adherence to prescribed procedures is quite often the most applicable QC check.
4.1 Equipment
Field test equipment is assigned a unique, permanent identification number. Prior to mobilizing for the test
program, equipment is inspected before being packed to detect equipment problems prior to arriving on site. This
minimizes lost time on the job site due to equipment failure. Occasional equipment failure in the field is
unavoidable despite the most rigorous inspection and maintenance procedures. Therefore, replacements for critical
equipment or components are brought to the job site. Equipment returning from the field is inspected before it is
returned to storage. During the course of these inspections, items are cleaned, repaired, reconditioned and
recalibrated where necessary.

Calibrations are conducted in a manner, and at a frequency, which meets or exceeds U.S. EPA specifications. The
calibration procedures outlined in the U.S. EPA Methods, and those recommended within the Quality Assurance
Handbook for Air Pollution Measurement Systems: Volume III (EPA-600/R-94/038c, September 1994) are utilized.
When these methods are inapplicable, methods such as those prescribed by the American Society for Testing and
Materials (ASTM) or other nationally recognized agency may be used. Data obtained during calibrations is checked
for completeness and accuracy. Copies of calibration forms are included in the report.

The following sections elaborate on the calibration procedures followed by AST for these items of equipment.

 Dry Gas Meter and Orifice. A full meter calibration using critical orifices as the calibration standard is
conducted at least semi-annually, more frequently if required. The meter calibration procedure determines
the meter correction factor (Y) and the meter’s orifice pressure differential (ΔH@). AST uses approved
Alternative Method 009 as a post-test calibration check to ensure that the correction factor has not changed
more than 5% since the last full meter calibration. This check is performed after each test series.
 Pitot Tubes and Manometers. Type-S pitot tubes that meet the geometric criteria required by U.S. EPA
Reference Test Method 2 are assigned a coefficient of 0.84 unless a specific coefficient has been
determined from a wind tunnel calibration. If a specific coefficient from a wind tunnel calibration has been
obtained that coefficient will be used in lieu of 0.84. Standard pitot tubes that meet the geometric criteria
required by U.S. EPA Reference Test Method 2 are assigned a coefficient of 0.99. Any pitot tubes not
meeting the appropriate geometric criteria are discarded and replaced. Manometers are verified to be level
and zeroed prior to each test run and do not require further calibration.
 Temperature Measuring Devices. All thermocouple sensors mounted in Dry Gas Meter Consoles are
calibrated semi-annually with a NIST-traceable thermocouple calibrator (temperature simulator) and
verified during field use using a second NIST-traceable meter. NIST-traceable thermocouple calibrators
are calibrated annually by an outside laboratory.
 Digital Calipers. Calipers are calibrated annually by AST by using gage blocks that are calibrated annually
by an outside laboratory.
 Barometer. The barometric pressure is obtained from a nationally recognized agency or a calibrated
barometer. Calibrated barometers are checked prior to each field trip against a mercury barometer. The
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barometer is acceptable if the values agree within ± 2 percent absolute. Barometers not meeting this
requirement are adjusted or taken out of service.
 Balances and Weights. Balances are calibrated annually by an outside laboratory. A functional check is
conducted on the balance each day it is use in the field using a calibration weight. Weights are re-certified
every two (2) years by an outside laboratory or internally. If conducted internally, they are weighed on a
NIST traceable balance. If the weight does not meet the expected criteria, they are replaced.
 Other Equipment. A mass flow controller calibration is conducted on each Environics system annually
following the procedures in the Manufacturer’s Operation manual. Other equipment such as probes,
umbilical lines, cold boxes, etc. are routinely maintained and inspected to ensure that they are in good
working order. They are repaired or replaced as needed.
4.2 Field Sampling
Field sampling will be done in accordance with the Standard Operating Procedures (SOP) for the applicable test
method(s). General QC measures for the test program include:
 Cleaned glassware and sample train components will be sealed until assembly.
 Sample trains will be leak checked before and after each test run.
 Appropriate probe and impinger temperatures will be maintained.
 The sampling port will be sealed to prevent air from leaking from the port.
 Dry gas meter, ΔP, ΔH, temperature and pump vacuum data will be recorded during each sample point.
 An isokinetic sampling rate of 90-110% will be maintained, as applicable.
 All raw data will be maintained in organized manner.
 All raw data will be reviewed on a daily basis for completeness and acceptability.

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1/2/24, 8:28 PM State of Utah Mail - RACT analysis for CVWRF pertaining to Serious Ozone Nonattainment Area Designation
https://mail.google.com/mail/u/0/?ik=b363bbe9c3&view=pt&search=all&permmsgid=msg-f:1784464783801526358&simpl=msg-f:1784464783801526358 1/2
Sarah Foran <[e-mail]>
RACT analysis for CVWRF pertaining to Serious Ozone Nonattainment Area
Designation
Bryan Mansell <[e-mail]>Tue, Dec 5, 2023 at 10:43 AM
To: Ana Williams <[e-mail]>, Sarah Foran <[e-mail]>
Cc: "Harold Burge ([e-mail])" <[e-mail]>, "[e-mail]" <[e-mail]>, Phil Heck
<[e-mail]>, Brandon Heidelberger <[e-mail]>, Bryan Mansell <[e-mail]>,
Sharon Burton <[e-mail]>, Zackery VanWormer <[e-mail]>
Ana and Sarah,
Please find attached the requested RACT analysis and associated cover letter. A hard copy is being mailed to
the DAQ office today. Please let me know if you have any questions.

Thanks,

Bryan Mansell, P.E.
Central Valley Water Reclamation Facility

Chief Engineer

Phone: [phone] Ext 171
Mobile: [phone]
Email: [e-mail]

800 W Central Valley Rd.
South Salt Lake, UT 84119

https://www.cvwrfut.gov

 Please consider the environment before printing this email 

1/2/24, 8:28 PM State of Utah Mail - RACT analysis for CVWRF pertaining to Serious Ozone Nonattainment Area Designation
https://mail.google.com/mail/u/0/?ik=b363bbe9c3&view=pt&search=all&permmsgid=msg-f:1784464783801526358&simpl=msg-f:1784464783801526358 2/2
2 attachments
RACT Cover Ltr 12052023.pdf
260K
RACT Analysis for NOx - FINAL.pdf
10180K

DAQE-MN104140016-23

M E M O R A N D U M

TO: Sarah Foran, NSR Engineer
FROM: Jason Krebs, Air Quality Modeler

DATE: August 16, 2023
SUBJECT: Modeling Analysis Review for the Notice of Intent for Central Valley Water Reclamation
Facility – Wastewater Treatment Plant, Salt Lake County, Utah
_____________________________________________________________________________________
This is not a Major Prevention of Significant Deterioration (PSD) Source.

I. OBJECTIVE
Central Valley Water Reclamation Facility (Applicant) is seeking an approval order for their
wastewater treatment plant located in Salt Lake County, Utah. The applicant requests removal of
an existing Waukesha engine, and installation of three emergency standby diesel generators.

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

II. APPLICABLE RULE(S)
Utah Air Quality Rules:
R307-401-6 Condition for Issuing an Approval Order
R307-410-3 Use of Dispersion Models
R307-410-4 Modeling of Criteria Pollutants in Attainment Areas

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

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

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

9 ,
JK
DAQE- MN104140016-23
Page 2
B. Assumptions

1. Topography/Terrain

The Plant is at an elevation 4233 feet with terrain features that have an affect on
concentration predictions.

a. Zone: 12
b. Approximate Location:
UTM (NAD83): 422600 meters East
4506500 meters North
2. Urban or Rural Area Designation
After a review of the appropriate 7.5-minute quadrangles, it was concluded the area is “rural” for air modeling purposes.
3. Ambient Air
It was determined the Plant boundary used in the AQIA meets the State’s definition of
ambient air.

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

5. Meteorology

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

Surface – Salt Lake Airport, UT NWS: 2016-2020
Upper Air – Salt Lake Airport, UT NWS: 2016-2020

6. Background
The background concentrations were based on concentrations measured in Salt Lake City,
Utah.

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

DAQE- MN104140016-23
Page 3
8. Model and Options

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

9. Air Pollutant Emission Rates

Central Valley Water Reclamation Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
JMS1 422841 4506514 3.0400 13.315 8760
JMS2 422841 4506510 3.0400 13.315 8760
JMS3 422841 4506505 3.0400 13.315 8760
JMS4 422841 4506501 3.0400 13.315 8760
RSS9 422728 4506657 21.5001 1.075 100
RSS2 422728 4506651 21.5001 1.075 100
ADMNGEN 422834 4506256 8.3800 0.419 100
COGEN6 422860 4506544 7.4000 0.370 100
COGEN7 422864 4506544 7.4000 0.370 100
HW7GEN 422897 4506446 14.1001 0.705 100
HW8GEN 422902 4506446 14.1001 0.705 100
NEWGEN9 422842 4506684 31.7902 1.590 100
NEWGEN10 422848 4506684 31.7902 1.590 100
NEWGEN11 422856 4506684 31.7902 1.590 100
BOIL1 422841 4506477 0.5900 2.584 8760
BOIL2 422841 4506484 0.5900 2.584 8760
FLARE2 422979 4506599 0.0600 0.263 8760
FLARE1 422979 4506595 0.0600 0.263 8760
WSTOIL1 422991 4506702 0.0400 0.175 8760
WSTOIL2 423153 4506557 0.0300 0.131 8760
WSTOIL3 423178 4506536 0.0400 0.175 8760

Total 203.3211 68.9245
Tesoro Refining and Marketing Company LLC
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
TE104 423575 4516094 63.1277 276.499 8760
DAQE- MN104140016-23
Page 4
COGEN_E 423812 4515999 14.3445 62.829 8760
COGEN_W 423802 4515998 13.7070 60.037 8760
TE101 423662 4515862 8.8469 38.749 8760
TE102 423669 4515966 7.0071 30.691 8760
OTHERS2 423865 4515745 38.6289 169.195 8760
Total 145.6621 638.0000 Hexcel Corporation
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
HEX_VOL 410709 4500886 0.6481 2.839 8760
HEX_P10 410663 4500923 47.5341 208.199 8760
HEX_P15 410561 4500938 1.1532 5.051 8760
HEX_P25 410554 4500927 34.4725 150.990 8760
HEX_P45 410393 4500998 0.2411 1.056 8760

Total 84.0490 368.1345
10. Source Location and Parameters
Source Type
Source Parameters
Elev, Ht Temp Flow Dia
(ft) (m) (ft) (K) (m/s) (ft)
JMS1 POINT 4241.4 13.7 45.0 809 21.95 0.51
JMS2 POINT 4241.5 13.7 45.0 809 21.95 0.51
JMS3 POINT 4241.6 13.7 45.0 809 21.95 0.51
JMS4 POINT 4241.7 13.7 45.0 809 21.95 0.51
RSS9 POINT 4238.6 3.7 12.0 753 42.60 0.27
RSS2 POINT 4238.9 3.7 12.0 753 42.60 0.27
ADMNGEN POINT 4239.0 3.7 12.0 753 49.68 0.16
COGEN6 POINT 4241.2 4.9 16.0 753 95.40 0.51
COGEN7 POINT 4241.0 4.9 16.0 753 95.40 0.51
HW7GEN POINT 4241.2 5.2 17.0 753 46.66 0.35
HW8GEN POINT 4241.1 5.2 17.0 753 46.66 0.35
NEWGEN9 POINT 4238.7 4.7 15.3 753 61.63 0.40
NEWGEN10 POINT 4239.2 4.7 15.3 753 61.63 0.40
NEWGEN11 POINT 4239.7 4.7 15.3 753 61.63 0.40
BOIL1 POINT 4241.9 12.8 42.0 478 15.25 0.20
DAQE- MN104140016-23
Page 5
BOIL2 POINT 4241.9 12.8 42.0 478 15.25 0.20
FLARE2 POINT 4240.3 12.8 42.0 1273 20.00 0.62
FLARE1 POINT 4240.3 12.8 42.0 1273 20.00 0.62
WSTOIL1 POINT 4239.8 8.2 27.0 471 64.31 0.20
WSTOIL2 POINT 4240.8 8.5 28.0 463 46.94 0.19
WSTOIL3 POINT 4241.5 8.2 27.0 463 50.53 0.20
HEX_VOL VOLUME 5021.0 9.5 31.2
HEX_P10 POINT 5021.5 7.5 24.7 335 14.26 0.69
HEX_P15 POINT 5020.1 12.1 39.7 338 9.76 0.50
HEX_P25 POINT 5020.2 18.9 62.0 463 18.30 0.37
HEX_P45 POINT 5020.3 39.3 128.9 301 7.86 0.98
TE104 POINT 4236.6 60.4 197.9 544 16.90 2.90
COGEN_E POINT 4261.6 11.9 39.0 433 4.15 1.83
COGEN_W POINT 4259.4 11.9 39.0 433 4.15 1.83
TE101 POINT 4236.4 30.5 100.0 426 6.86 1.22
TE102 POINT 4244.1 30.5 100.0 652 9.98 2.44
OTHERS2 POINT 4249.6 12.2 40.0 499 4.95 0.61

IV. RESULTS AND CONCLUSIONS

A. National Ambient Air Quality Standards

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

Air
Pollutant
Period Prediction Class II
Significant
Impact
Level
Background Nearby
Sources*
Total NAAQS Percent
(μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) NAAQS
NO2
1-
Hour 144.5 7.5 26.6 11.8 182.9 188 97.29%

V. PERMIT CONDITIONS

The following suggested permit language should be included under the Terms and Conditions in the AO:

• Testing of the new emergency standby engines shall occur no more than 52 times per rolling
12-month period.
• Testing of the new emergency standby engines shall not occur while any of the existing
emergency standby engines are being tested.

JK:jg
NOI 2023 CVWRF Permit #3500191001 July 7, 2023 Page 3 of 3

Cc: Harold Burge, Utah Division of Air Quality Joseph Randolph, Utah Division of Air Quality Jon Black, Utah Division of Air Quality Sarah Foran, Utah Division of Air Quality Brandon Heidelberger, CVWRF Assistant General Manager
Bryan Mansell, CVWRF Chief Engineer Sharon Burton, CVWRF Plant Superintendent Zack VanWormer, CVWRF Cogen Supervisor Attachments:
New Emissions Location Map Manufacturer engine specifications, emissions data, and Tier 2 certification Updated PTE Summary BACT Analysis

New Emissions Location Map

Manufacturer engine specifications,
emissions data, and Tier 2 certification
Central Valley Water
Reclamation Facility
South Salt Lake, UT
(3) 2000kW Diesel Generators
JULY 2021
REV-2
Submitted by:
Nick Paolo
Smith Power Products,
Inc.
303-810-1085
[e-mail] SU
B
M
I
T
T
A
L
L
Date: September 14, 2020
Reference: SPP2702.4 CVWRF 3 Salt Lake City - 2000kW QTY 3 4160V
We are pleased to offer the following quote for the above project:
The proposal is per one-line drawing and specifications with clarifications in the notes section of the bill of
materials listed after the quote: please reference previous quote 2702.1
QUANTITY EQUIPMENT DESCRIPTION PRICE EACH TOTAL PRICE
3 MTU 2000kW Generator Set M/N DS2000 Diesel Fuel Derate: 2000kW @ 4300 Feet, 104°F 4160V Volt, 3 Phase, 60 HZ, 1800 RPM Genset OPU Dry Assembly Weight: lbs.
Included Included
3 Generator Enclosure Weather Proof Level 2
85 dBA at 23’ Included Included
3 NGR’s Included Included
*Crane/rigging not included. Fuel not included.
Cat walks not included. If required, we can
provide an adder.
Equipment Description:
Generator:
Application Emergency Standby (3D) 1,
Frequency 60 Hz 1, Generator Voltage 4160 V 1,
Phase 3 Phase 1, Unit Specification Standard Unit 1,
Engine Model 16V4000G74S (24volts) 1, Exhaust Emissions (EPA) EPA Tier 2 1,
Radiator Design Temperature 43°C 1, Temp Rise 130° 1,
Power Output 2000 kW 1, Full Load Amps 346 1,
Generator Frame and Wire Qty LSA 641-VL75-M (6 Wire) 1, Generator Wire Configuration Wye 1,
Custom Generator Enclosure Sound 85dB(A) @ 23ft 1, Fuel Tank UL142 24hr tank 1,
Control panel With Control Panel 1, Circuit Breaker Options Exterior mounted 1,
Breaker Wire Color Scheme Standard Breaker Wire Color Scheme 1, Paralleling Paralleling without MTU Components 1,
Central Valley Water Reclation Facility SEPT2020 REV0 Page 29 of 146
3
3
3 NGR’s
y
Generator Enclosure
MTU 2000kW Generator SetM/N DS2000
2000kW @ 4300 Feet,104°F
4160 V
2000 kW
y
Sound 85dB(A) @ 23ftUL142 24hr tank()@
MTU 16V4000 DS2000 45 °C
Diesel Generator Set
2,000 kWe/60 Hz/Standby/380 - 13,800V
Voltage (L-L)380V † ‡416V † ‡440V † ‡480V † ‡600V ‡
Phase33333
PF 0.8 0.8 0.8 0.8 0.8
Hz 60 60 60 60 60
kW 2,000 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500 2,500
Amps 3,798 3,470 3,280 3,007 2,406
skVA@30%
voltage dip 6,899 6,030 6,745 4,914 4,575
Generator model*841-M70-M 841-M70-M 841-M70-M 641-VL90-M 641-VL85-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
Voltage (L-L)4,160V 12,470V 13,200V 13,800V
Phase3333
PF 0.8 0.8 0.8 0.8
Hz 60 60 60 60
kW 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500
Amps 347 116 109 105
skVA@30%
voltage dip 4,303 3,243 3,633 3,971
Generator model*641-VL75-M 4P6.6-2600-M 4P6.6-2600-M 4P6.6-2600-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 50 of 146
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 51 of 146
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 52 of 146
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 53 of 146
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY2020 MODEL YEARCERTIFICATE OF CONFORMITYWITH THE CLEAN AIR ACT
OFFICE OF TRANSPORTATIONAND AIR QUALITYANN ARBOR, MICHIGAN 48105
Certificate Issued To: MTU America, Inc. (U.S. Manufacturer or Importer)
Certificate Number: LMDDL95.4GTZ-007
Effective Date:01/29/2020
Expiration Date:12/31/2020
_________________________Byron J. Bunker, Division DirectorCompliance Division
Issue Date:01/29/2020
Revision Date:N/A
Model Year: 2020
Manufacturer Type: Original Engine Manufacturer
Engine Family: LMDDL95.4GTZ
Mobile/Stationary Indicator: Stationary
Emissions Power Category: 560<kW<=2237
Fuel Type: Diesel
After Treatment Devices: No After Treatment Devices Installed
Non-after Treatment Devices: Electronic Control, Smoke Puff Limiter
Pursuant to Section 111 and Section 213 of the Clean Air Act (42 U.S.C. sections 7411 and 7547) and 40 CFR Part 60, and subject to the terms and conditions prescribed in those provisions, this certificate of
conformity is hereby issued with respect to the test engines which have been found to conform to applicable requirements and which represent the following engines, by engine family, more fully described in
the documentation required by 40 CFR Part 60 and produced in the stated model year.
This certificate of conformity covers only those new compression-ignition engines which conform in all material respects to the design specifications that applied to those engines described in the
documentation required by 40 CFR Part 60 and which are produced during the model year stated on this certificate of the said manufacturer, as defined in 40 CFR Part 60.
It is a term of this certificate that the manufacturer shall consent to all inspections described in 40 CFR 1068 and authorized in a warrant or court order. Failure to comply with the requirements of such a
warrant or court order may lead to revocation or suspension of this certificate for reasons specified in 40 CFR Part 60. It is also a term of this certificate that this certificate may be revoked or suspended or
rendered void ab initio for other reasons specified in 40 CFR Part 60.
This certificate does not cover engines sold, offered for sale, or introduced, or delivered for introduction, into commerce in the U.S. prior to the effective date of the certificate.
The actual engine power may lie outside the limits of the Emissions Power Category shown above. See the certificate application for details.
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Issued to: MTU America Inc
100 Power Dr
Mankato MN 56001-4790

This certificate confirms that
representative samples of
ENGINE GENERATORS
Stationary engine generator assemblies, Diesel Fueled, for
indoor use, Models 12V4000, 16V4000, 20V4000 followed
by D, followed by S, followed by 1250 thru 3250.

Have been investigated by UL in accordance with the
Standard(s) indicated on this Certificate.

Standard(s) for Safety: UL 2200-Engine Generators
CAN/CSA C22.2 No. 100-14-Motors and Generators
Additional Information: See the UL Online Certifications Directory at
https://iq.ulprospector.com for additional information.
This Certificate of Compliance does not provide authorization to apply the UL Mark. Only the UL Follow-Up Services Procedure provides authorization to apply the UL Mark. Only those products bearing the UL Mark should be considered as being UL Certified and covered under UL’s Follow-Up Services. Look for the UL Certification Mark on the product.
Central Valley Water Reclation Facility SEPT2020 REV0 Page 43 of 146

Accredited Body: DQS GmbH, August-Schanz-Straße 21, 60433 Frankfurt am Main, Germany

CERTIFICATE
This is to certify that

MTU America Inc.
100 Power Drive
Mankato, MN 56001
United States of America
has implemented and maintains a Quality Management System.
Scope:
Development, production, sales and service of decentralized energy systems.
Through an audit, documented in a report, it was verified that the management system
fulfills the requirements of the following standard:

ISO 9001 : 2015

Certificate registration no.
Excerpt from certificate registration no.
Valid from
Valid until
Date of certification
500767 QM15
353331 QM15
2018-08-15
2021-08-14
2018-08-15
DQS GmbH

Stefan Heinloth
Managing Director

Central Valley Water Reclation Facility SEPT2020 REV0 Page 44 of 146

Updated PTE Summary
Equipment Details
Backup Gen 9 2,680 hp
Backup Gen 10 2,680 hp
Backup Gen 11 2,680 hp
Total Rating 8,040 hp = (6000 kw)
Operational Hours 100 hours/year
Sulfur Content 15 ppm or 0.0015%
Criteria Pollutant
Emission
Standards
(g/hp-hr)
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
NOX 5.38 95.36 4.77
CO 0.45 7.98 0.40
PM10 0.04 0.71 0.035
PM2.5 0.04 0.71 0.035
VOC 6.42E-04 5.16 0.26
SO2 1.21E-05 0.10 0.005 AP-42 Table 3.4-1
HAP 0.25 0.01 See Below
Green House Gas Pollutant
Global
Warming
Potential
Emission Factor
(lb/hp-hr)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
CO2 (mass basis)1 1.16 9,326 466
Methane (mass basis)25 6.35E-05 1 0.03
CO2e 467
Hazardous Air Pollutant
Emission Factor
(lb/MMBtu)
Emission
Rate
(lbs/hr)
Emission
Total
(tons/year) Reference
Benzene 7.76E-04 4.37E-02 2.18E-03
Toluene 2.81E-04 1.58E-02 7.91E-04
Xylenes 1.93E-04 1.09E-02 5.43E-04
Propylene 2.79E-03 1.57E-01 7.85E-03
Formaldehyde 7.89E-05 4.44E-03 2.22E-04
Acetaldehyde 2.52E-05 1.42E-03 7.09E-05
Acrolein 7.88E-06 4.43E-04 2.22E-05
Naphthalene 1.30E-04 7.32E-03 3.66E-04
Acenaphthylene 9.23E-06 5.19E-04 2.60E-05
Acenaphthene 4.68E-06 2.63E-04 1.32E-05
Fluorene 1.28E-05 7.20E-04 3.60E-05
Phenanthrene 4.08E-05 2.30E-03 1.15E-04
Anthracene 1.23E-06 6.92E-05 3.46E-06
Fluoranthene 4.03E-06 2.27E-04 1.13E-05
Pyrene 3.71E-06 2.09E-04 1.04E-05
Benz(a)anthracene 6.22E-07 3.50E-05 1.75E-06
Chrysene 1.53E-06 8.61E-05 4.31E-06
Benzo(b)fluoranthene 1.11E-06 6.25E-05 3.12E-06
Benzo(k)fluoranthene 2.18E-07 1.23E-05 6.13E-07
Benzo(a)pyrene 2.57E-07 1.45E-05 7.23E-07
Indeno(1,2,3-cd)pyrene 4.14E-07 2.33E-05 1.16E-06
Dibenz(a,h)anthracene 3.46E-07 1.95E-05 9.74E-07
Benzo(g,h,l)perylene 5.56E-07 3.13E-05 1.56E-06
Emergency Generators 9 - 11 (Blower Bldg)
Tier 2 limits,
AP-42 Table 3.3-1,
& Table 3.4-1
AP-42 Table 3.3-1
& Table 3.4-1
AP-42 Table 3.3-2,
Table 3.4-3, &
Table 3.4-4
Page 1
Emission Unit PM10 PM2.5 NOx CO SO2 VOC HAPs CO2e
Emergency Engines 2-4 0.075 0.075 2.57 0.59 0.0013 0.07 0.001 124
Emergency Engines 5 & 6 0.056 0.056 0.74 0.03 0.0010 0.01 0.001 93
Emergency Engines 7 & 8 0.044 0.044 1.41 0.77 0.0016 0.09 0.001 156
Emergency Engines 9-11*0.035 0.035 4.77 0.40 0.0049 0.26 0.012 467
Natural Gas/Digester Gas Engines 1-4 2.91 1.94 53.30 242.27 0.181 29.07 22.21 43,463
Flare**0.00 0.00 0.52 2.36 0.00 5.03
Boiler (6 MMBtu/hr)0.20 0.20 2.60 2.18 0.016 0.14 0.049 3,136
Boiler (150 hp)0.20 0.20 2.70 2.26 0.016 0.15 0.051 3,254
Waste Oil Burners***0.93 0.93 0.07 0.02 0.269 0.004 0.003 73
Total*4.45 3.48 68.67 250.89 0.49 34.81 22.33 50766.77
DAQE-AN104140015-21 3.48 2.51 63.82 250.46 0.22 34.55 22.32 50209.31
Change in PTE 0.97 0.97 4.85 0.43 0.27 0.26 0.014 557.46
* Proposed to be added in 2023
** Updated with 2018 data
***Inadvertently left out of previous PTE estimate totals

BACT Analysis
Technical Memorandum

Limitations:
This document was prepared solely for Central Valley Water Reclamation Facility (CVWRF) in accordance with professional standards at the time the
services were performed and in accordance with the contract between CVWRF and Brown and Caldwell dated January 3, 2023. This document is
governed by the specific scope of work authorized by CVWRF; it is not intended to be relied upon by any other party except for regulatory authorities
contemplated by the scope of work. We have relied on information or instructions provided by CVWRF and other parties and, unless otherwise
expressly indicated, have made no independent investigation as to the validity, completeness, or accuracy of such information.
.202 Cousteau Place, Suite 175
Davis, CA 95618

T: 530.747.0650

Prepared for: Central Valley Water Reclamation Facility
Project Title: Emergency Diesel Engine Generators Serving Blower Building
Project No.: 159388
Technical Memorandum
Subject: BACT Analysis for Emergency Engine Generators 9, 10, and 11
Date: June 26, 2023
To: Bryan Mansell, Chief Engineer
From: Jason Wiser
Copy to: File

Prepared by:
Jennifer Border, Principal Engineer

Reviewed by:
Don Trueblood, Chief Scientist

Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
ii
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
Table of Contents
Section 1: Background..............................................................................................................................................1
1.1 Site History and Permitting Timeline..................................................................................................................1
1.2 Attainment Status................................................................................................................................................1
1.3 Standby Emergency Diesel Engine Generators.................................................................................................2
1.3.1 Engine Emissions and Controls..........................................................................................................2
Section 2: Best Available Control Technology Analysis...........................................................................................3
2.1 Pollutants for Which BACT is Required..............................................................................................................4
2.2 Control Technologies...........................................................................................................................................4
Section 3: Conclusion................................................................................................................................................5
Attachment A: Emergency Engine Data....................................................................................................................A
Attachment B: EPA RBLC Search Results ................................................................................................................B
List of Tables
Table 1. Engine Data .................................................................................................................................................2
Table 2. RBLC BACT Methods of Control..................................................................................................................4
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
1
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
Section 1: Background
The Central Valley Water Reclamation Facility (CVWRF) is located at 800 West Central Valley Road in Salt
Lake City, Salt Lake County, Utah. CVWRF treats wastewater using a combination of processes. Every day,
between 50 and 60 million gallons of wastewater are conveyed into the facility for treatment. Those millions
of gallons of water are processed, impurities are separated and treated, and harmful bacteria, protozoa, and
viruses are eliminated so that only clean water is returned to Mill Creek and the Jordan River.
1.1 Site History and Permitting Timeline
CVWRF is currently permitted under Title V Air Permit 3500191001, issued March 16, 2020, through the
State of Utah, Department of Environmental Quality, Division of Air Quality (DAQ). Emissions at the facility are
primarily associated with electric power generation from the operation of prime-use digester gas/natural
gas-fueled engine generators and standby emergency diesel engine generators.
The facility is currently undergoing construction of a Biological Nutrient Removal (BNR) system to reduce
effluent total phosphorus concentrations as required by the Technology Based Phosphorus Effluent Limit
Rule promulgated by the Utah DWQ in 2015. The new standby emergency diesel engine generators
(hereafter referred to as “engines”) will provide emergency power to the blower building which serves the
BNR system. The generators are on-site but are not commissioned; commissioning is expected to take place
in late 2023.
1.2 Attainment Status
CVWRF is located in Salt Lake County, Utah which is currently designated non-attainment for PM2.5, SO2 and
Ozone; the area is also designated as a PM10 maintenance area. Salt Lake County was designated as
marginal non-attainment for Ozone on June 4, 2018. Since the area was not able to attain the ozone
standard within the three-year period allowed by United States Environmental Protection Agency (USEPA),
the area was re-designated as moderate non-attainment for ozone on November 7, 2022.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
2
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
1.3 Standby Emergency Diesel Engine Generators
Table 1 provides information regarding each of the three identical engines.
Table 1. Engine Data
Manufacturer MTU Rolls Royce
Generator Model 641-VL75-M
Engine Model 16V4000G74S
Displacement 76.3 liters
Number of Cylinders 16
Displacement per cylinder 4.77 liters per cylinder
Generator Power (Electrical)2,000 kW
Engine Power (estimated)2,884 BHP`
Engine Emissions Data:
Certification
NOx + NMHC
CO
PM
Tier II
5.38 g/hp-hr
0.45 g/hp-hr
0.04 g/hp-hr
a. Engine horsepower based on the fuel consumption provided in the manufacturer spec sheet at 100% load
and assumptions from footnotes “a” and “e” of AP-42 Table 3.4 1
CO = Carbon Monoxide
kW = kilowatt(s)
g = gram(s)
hp-hr = horse power per hour
NMHC = Non-methane hydrocarbon
NOx = Nitrogen Oxides
PM = Particulate Matter
1.3.1 Engine Emissions and Controls
Since the engines do not drive fire pumps, were manufactured after 2006, and are being installed after July
11, 2005, they are subject to 40 Code of Federal Regulations (CFR) 60, Subpart IIII, Standards of
Performance for New Stationary Engines [40 CFR 60.4200]. Since the engines are designated for
emergency use, the model year is later than 2006, and the displacement is less than 30 liters per cylinder,
they are subject to the emissions standards provided in 40 CFR 60.4202 [40 CFR 60.4205]. Section 4202
of Subpart IIII further requires that engines rated at 50 HP or more must meet the emissions standards in 40
CFR 1039, Appendix I and the smoke standards in 40 CFR 1039.105. [40 CFR 60.4202(a)]. The emissions
standards in 40 CFR 1039, Appendix I for engines over 560 kW are equal to the emissions standards for
Tier 2 engines.
The section regarding smoke standards, 40 CFR 1039.105, states that the smoke opacity standards
provided do not apply to engines certified to a PM emission standard of 0.07 g/kW-hr (0.05 g/hp-hr) or
lower. Since the engines are certified to a PM emission standard of 0.04 g/hp-hr, the smoke opacity
standards do not apply.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
3
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
CVWRF will be required to comply with the other provisions of Subpart IIII, specifically to:
Operate and maintain the engines according to the manufacturer’s emission-related written instructions;
Change only those emission-related settings that are permitted by the manufacturer;
Install and configure the engine according to the manufacturer’s emission-related specifications;
Limit operation of the engines for non-emergency purposes to a maximum of 100 hours per year (of
which up to 50 hours per year can be for uses not associated with maintenance and testing of the
engines).
The USEPA Certificate of Conformity for the engine family states that the following treatment devices are
integral to the engine (“non-after treatment devices”): electronic control and puff limiter. In addition, the
emissions guarantee provided by the manufacturer exceeds the emissions requirements of 40 CFR 1039,
Appendix I (the emissions standards are less than the Tier 2 emissions limits).
Section 2: Best Available Control Technology Analysis
Following USEPA Guidance, best available control technology (BACT) can be defined as the most stringent of
the following:
The lowest emission rate or most effective emission limitation successfully achieved in practice by the
same type of equipment, operated under similar conditions (rating and capacity), at the same type of
source; or
The lowest emission rate or most effective emission control device determined to be technologically
feasible and cost effective for the equipment being installed; or
The requirements of a State or Federal Performance Standard Regulation.
A BACT analysis is performed on a case-by-case basis and must consider emission rates and/or control
technologies that have been achieved on similar equipment or that are technologically feasible and cost
effective. These requirements have led to development of a standard procedure for case-by-case “top down”
BACT analyses.
Step 1: Identify pollutants for which BACT is required. Utah Department of Environmental Quality (DEQ)
regulations require BACT for all criteria pollutants.
Step 2: Identify emission rates and/or control technologies. Once the pollutants for which the BACT
analysis is required are identified, candidate emission rates and/or control technologies must be
identified.
Step 3: Evaluate technological feasibility of the emission rates and/or control technologies identified in
Step 2. Any emission rates and/or control technologies that are not technologically feasible should be
eliminated at this step.
Step 4: Rank remaining emission rates and/or control technologies by effectiveness. This ranking
should consider, as appropriate, control efficiency, resulting emission rates, energy impacts (fuel use,
etc.), and environmental impacts (secondary air emissions, hazardous waste production, impacts to
other media, etc.).
Step 5: Evaluate cost effectiveness of the most stringent emission rates and/or most effective controls.
Step 6: Select BACT.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
4
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
2.1 Pollutants for Which BACT is Required
This BACT analysis considered emissions of NOx, CO, VOC, PM10, PM2.5, and SO2.
2.2 Control Technologies
Existing sources of information were used to identify emission controls that have been used for similar
projects. The Utah DEQ’s website contains several source-specific BACT analyses that were submitted by
facilities which are major sources of PM2.5 and PM2.5 precursors regarding various types of facilities.
Several of these documents contain an analysis of BACT measures for PM2.5 control from emergency
engines. BC reviewed these analyses and did not find any that provided achieved-in-practice controls that
exceed the PM-related controls already proposed for the engines.
In addition, in response to the area around the facility having been recently designated non-attainment for
ozone, the Utah DEQ website contains area source rules which apply to several specific source categories;
none of the rules apply directly or indirectly to internal combustion engines.
BC conducted an initial BACT determinations search of the following database:
USEPA Reasonable Available Control Technology (RACT)/BACT/Lowest Achievable Emission Rate
Clearinghouse (RBLC) – Category 17.110 – Internal Combustion Engines – Large (>500 hp) – Fuel Oil
(kerosene, aviation, and diesel) with a keyword search for “emergency”
The results from the RBLC initially provided over 6,000 potential determinations. However, the results were
further refined through filtering the information as follows:
Engines fired on fuel other than diesel were removed
Engines driving fire pumps were removed
Smaller engines (roughly under 1,000 hp) were removed
Pollutants were limited to criteria pollutants only and omitted carbon dioxide, hydrogen sulfide, and
visible emissions
The refined RBLC results provided 18 BACT determinations. The remaining control technologies cited are
listed in the Table 2 below.
Table 2. RBLC BACT Methods of Control
Pollutant Methods of Control
Particulate Matter
Minimize hours of operation
Tier II Engine
Good combustion practices
SOx Low sulfur fuel (15 ppm sulfur content)
VOC Minimize hours of operation
Tier II Engine
CO Minimize hours of operation
Tier II Engine
NOx 3.95 g/HP-hr – 4.46 g/HP-hra
a. BC requested verification from the agency which submitted the determination for the NOx
emission limit (PA 0291) and received a response from the Pennsylvania Department of
Environmental Protection stating that the source had never been constructed. Therefore,
this emissions limit was not demonstrated as achieved in practice and was not brought
forward for consideration as BACT.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
5
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
As noted in the footnote for the NOx emission standard in Table 2 above, according to an email from the
Pennsylvania Department of Environmental Protection, the facility subject to the NOx emission limit was
never constructed and the limit was not achieved in practice. Therefore, this BACT determination was not
brought forward.
The remaining Methods of Control cited in the results from the RBLC search will be incorporated by CVWRF
in the operation of the emergency engines.
Section 3: Conclusion
In conclusion, CVWRF purchased MTU emergency engines 9, 10, and 11 and has installed them at the
facility. The engines are not currently operational as the facility which they will serve has not been
constructed yet.
The engines are considered to meet current BACT requirements for the size and type of operation with the
following provisions:
The engines are certified Tier II.
The engines will be operated and maintained according to the manufacturer's emission-related written
instructions;
Only those emission-related settings that are permitted by the manufacturer will be changed;
The engines will be installed and configured according to the manufacturer’s emission-related
specifications;
Operation of the engines for non-emergency purposes will be limited to a maximum of 100 hours per
year (of which up to 50 hours per year can be for uses not associated with maintenance and testing of
the engines).
Only ultra-low sulfur diesel fuel will be used in the engines.
The above provision are considered to satisfy the requirement that good combustion practices are utilized
during the operation of the engines.
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
A
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
Attachment A: Emergency Engine Data
Central Valley Water
Reclamation Facility
South Salt Lake, UT
(3) 2000kW Diesel Generators
JULY 2021
REV-2
Submitted by:
Nick Paolo
Smith Power Products,
Inc.
303-810-1085
[e-mail] SU
B
M
I
T
T
A
L
L
Date: September 14, 2020
Reference: SPP2702.4 CVWRF 3 Salt Lake City - 2000kW QTY 3 4160V
We are pleased to offer the following quote for the above project:
The proposal is per one-line drawing and specifications with clarifications in the notes section of the bill of
materials listed after the quote: please reference previous quote 2702.1
QUANTITY EQUIPMENT DESCRIPTION PRICE EACH TOTAL PRICE
3 MTU 2000kW Generator Set M/N DS2000 Diesel Fuel Derate: 2000kW @ 4300 Feet, 104°F 4160V Volt, 3 Phase, 60 HZ, 1800 RPM Genset OPU Dry Assembly Weight: lbs.
Included Included
3 Generator Enclosure Weather Proof Level 2
85 dBA at 23’ Included Included
3 NGR’s Included Included
*Crane/rigging not included. Fuel not included.
Cat walks not included. If required, we can
provide an adder.
Equipment Description:
Generator:
Application Emergency Standby (3D) 1,
Frequency 60 Hz 1, Generator Voltage 4160 V 1,
Phase 3 Phase 1, Unit Specification Standard Unit 1,
Engine Model 16V4000G74S (24volts) 1, Exhaust Emissions (EPA) EPA Tier 2 1,
Radiator Design Temperature 43°C 1, Temp Rise 130° 1,
Power Output 2000 kW 1, Full Load Amps 346 1,
Generator Frame and Wire Qty LSA 641-VL75-M (6 Wire) 1, Generator Wire Configuration Wye 1,
Custom Generator Enclosure Sound 85dB(A) @ 23ft 1, Fuel Tank UL142 24hr tank 1,
Control panel With Control Panel 1, Circuit Breaker Options Exterior mounted 1,
Breaker Wire Color Scheme Standard Breaker Wire Color Scheme 1, Paralleling Paralleling without MTU Components 1,
Central Valley Water Reclation Facility SEPT2020 REV0 Page 29 of 146
3
3
3 NGR’s
y
Generator Enclosure
MTU 2000kW Generator SetM/N DS2000
2000kW @ 4300 Feet,104°F
4160 V
2000 kW
y
Sound 85dB(A) @ 23ftUL142 24hr tank()@
MTU 16V4000 DS2000 45 °C
Diesel Generator Set
2,000 kWe/60 Hz/Standby/380 - 13,800V
Voltage (L-L)380V † ‡416V † ‡440V † ‡480V † ‡600V ‡
Phase33333
PF 0.8 0.8 0.8 0.8 0.8
Hz 60 60 60 60 60
kW 2,000 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500 2,500
Amps 3,798 3,470 3,280 3,007 2,406
skVA@30%
voltage dip 6,899 6,030 6,745 4,914 4,575
Generator model*841-M70-M 841-M70-M 841-M70-M 641-VL90-M 641-VL85-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
Voltage (L-L)4,160V 12,470V 13,200V 13,800V
Phase3333
PF 0.8 0.8 0.8 0.8
Hz 60 60 60 60
kW 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500
Amps 347 116 109 105
skVA@30%
voltage dip 4,303 3,243 3,633 3,971
Generator model*641-VL75-M 4P6.6-2600-M 4P6.6-2600-M 4P6.6-2600-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 50 of 146
MTU 16V4000 DS2000 45 °C
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 52 of 146
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 53 of 146
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY2020 MODEL YEARCERTIFICATE OF CONFORMITYWITH THE CLEAN AIR ACT
OFFICE OF TRANSPORTATIONAND AIR QUALITYANN ARBOR, MICHIGAN 48105
Certificate Issued To: MTU America, Inc. (U.S. Manufacturer or Importer)
Certificate Number: LMDDL95.4GTZ-007
Effective Date:01/29/2020
Expiration Date:12/31/2020
_________________________Byron J. Bunker, Division DirectorCompliance Division
Issue Date:01/29/2020
Revision Date:N/A
Model Year: 2020
Manufacturer Type: Original Engine Manufacturer
Engine Family: LMDDL95.4GTZ
Mobile/Stationary Indicator: Stationary
Emissions Power Category: 560<kW<=2237
Fuel Type: Diesel
After Treatment Devices: No After Treatment Devices Installed
Non-after Treatment Devices: Electronic Control, Smoke Puff Limiter
Pursuant to Section 111 and Section 213 of the Clean Air Act (42 U.S.C. sections 7411 and 7547) and 40 CFR Part 60, and subject to the terms and conditions prescribed in those provisions, this certificate of
conformity is hereby issued with respect to the test engines which have been found to conform to applicable requirements and which represent the following engines, by engine family, more fully described in
the documentation required by 40 CFR Part 60 and produced in the stated model year.
This certificate of conformity covers only those new compression-ignition engines which conform in all material respects to the design specifications that applied to those engines described in the
documentation required by 40 CFR Part 60 and which are produced during the model year stated on this certificate of the said manufacturer, as defined in 40 CFR Part 60.
It is a term of this certificate that the manufacturer shall consent to all inspections described in 40 CFR 1068 and authorized in a warrant or court order. Failure to comply with the requirements of such a
warrant or court order may lead to revocation or suspension of this certificate for reasons specified in 40 CFR Part 60. It is also a term of this certificate that this certificate may be revoked or suspended or
rendered void ab initio for other reasons specified in 40 CFR Part 60.
This certificate does not cover engines sold, offered for sale, or introduced, or delivered for introduction, into commerce in the U.S. prior to the effective date of the certificate.
The actual engine power may lie outside the limits of the Emissions Power Category shown above. See the certificate application for details.
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Issued to: MTU America Inc
100 Power Dr
Mankato MN 56001-4790

This certificate confirms that
representative samples of
ENGINE GENERATORS
Stationary engine generator assemblies, Diesel Fueled, for
indoor use, Models 12V4000, 16V4000, 20V4000 followed
by D, followed by S, followed by 1250 thru 3250.

Have been investigated by UL in accordance with the
Standard(s) indicated on this Certificate.

Standard(s) for Safety: UL 2200-Engine Generators
CAN/CSA C22.2 No. 100-14-Motors and Generators
Additional Information: See the UL Online Certifications Directory at
https://iq.ulprospector.com for additional information.
This Certificate of Compliance does not provide authorization to apply the UL Mark. Only the UL Follow-Up Services Procedure provides authorization to apply the UL Mark. Only those products bearing the UL Mark should be considered as being UL Certified and covered under UL’s Follow-Up Services. Look for the UL Certification Mark on the product.
Central Valley Water Reclation Facility SEPT2020 REV0 Page 43 of 146

Accredited Body: DQS GmbH, August-Schanz-Straße 21, 60433 Frankfurt am Main, Germany

CERTIFICATE
This is to certify that

MTU America Inc.
100 Power Drive
Mankato, MN 56001
United States of America
has implemented and maintains a Quality Management System.
Scope:
Development, production, sales and service of decentralized energy systems.
Through an audit, documented in a report, it was verified that the management system
fulfills the requirements of the following standard:

ISO 9001 : 2015

Certificate registration no.
Excerpt from certificate registration no.
Valid from
Valid until
Date of certification
500767 QM15
353331 QM15
2018-08-15
2021-08-14
2018-08-15
DQS GmbH

Stefan Heinloth
Managing Director

Central Valley Water Reclation Facility SEPT2020 REV0 Page 44 of 146
Best Available Control Technology Analysis for Emergency Engine Generators 9, 10, and 11
B
Use of contents on this sheet is subject to the limitations specified at the beginning of this document.
BACT Emerg Engines 9, 10, 11.docx
Attachment B: EPA RBLC Search Results
USEPA RBLC Output
Page 1 of 2
Exported on June 15, 2023
Filtered on Fuel (Diesel)
Excludes:
fire pumps
smaller engines
RBLCID Facility Name
Corporate Or
Company Name
Facility
County
Facility
State
EPA
Region Other Agency Contact Info Permit Num SIC Code NAICS Code
Complete
Application
Date
Permit
Issuance
Date
Date Determination
Last Updated
Permit
Type Process Name Primary Fuel Throughput Tput Unit Pollutant Test Method
Control Method
Description
Emission
Limit
Emission Limit
1 Unit
Case-By-Case
Basis
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Carbon
Monoxide Unspecified
Minimized hours
of operations Tier
II engine 0.0126 G/HP HR
OTHER CASE-
BY-CASE
MA-0039
SALEM HARBOR
STATION
REDEVELOPMENT
FOOTPRINT POWER
SALEM HARBOR
DEVELOPMENT LP ESSEX MA 1
Cosmo Buttaro
MassDEP Northeast Regional
Office
205B Lowell Street
Wilmington, MA 01887
[phone]
[e-mail] NE-12-022 4911 221112 9/9/2013 1/30/2014 5/5/2016 A
Emergency
Engine/Generat
or ULSD 7.4 MMBTU/H
Carbon
Monoxide Unspecified 2.6 GM/BHP-H
OTHER CASE-
BY-CASE
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Carbon
Monoxide Unspecified 5.79 LB/H
OTHER CASE-
BY-CASE
*PA-0313
FIRST QUALITY TISSUE
LOCK HAVEN PLT
FIRST QUALITY
TISSUE, LLC CLINTON PA 3 18-00030C 2676 322291 4/14/2015 7/27/2017 3/26/2019 B
Emergency
Generator Diesel 2500 bhp
Carbon
Monoxide Unspecified 3.5 G
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Nitrogen
Oxides (NOx)Unspecified 9.89 LB/H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Particulate
matter,
filterable 10µ
(FPM10)Unspecified
Minimized hours
of operations Tier
II engine 0.15 LB/H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Particulate
matter,
filterable 2.5µ
(FPM2.5)Unspecified
Minimized hours
of operations Tier
II engine 0.15 LB/H
OTHER CASE-
BY-CASE
MI-0447
LBWL--ERICKSON
STATION
LANSING BOARD OF
WATER AND LIGHT EATON MI 5
Please contact the permit
engineer
Melissa Byrnes
517-648-6339
[e-mail] 74-18A 4911 221112 9/22/2020 1/7/2021 9/10/2021 D
EUEMGD--
emergency
engine diesel fuel 4474.2 KW
Particulate
matter,
filterable
(FPM)Unspecified
Good combustion
practices, burn
ultra-low diesel
fuel, and will be
NSPS compliant.0.2 G/KW-H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Particulate
matter,
filterable
(FPM)Unspecified
Minimized hours
of operations Tier
II engine 0.15 LB/H
OTHER CASE-
BY-CASE
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Particulate
matter, total
(TPM)Unspecified 0.02 TPY
OTHER CASE-
BY-CASE
USEPA RBLC Output
Page 2 of 2
*PA-0313
FIRST QUALITY TISSUE
LOCK HAVEN PLT
FIRST QUALITY
TISSUE, LLC CLINTON PA 3 18-00030C 2676 322291 4/14/2015 7/27/2017 3/26/2019 B
Emergency
Generator Diesel 2500 bhp
Particulate
matter, total
(TPM)Unspecified 0.2 G
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Sulfur Dioxide
(SO2)Unspecified
Low sulfur fuel 15
ppmw 0.61 LB/H
OTHER CASE-
BY-CASE
MA-0039
SALEM HARBOR
STATION
REDEVELOPMENT
FOOTPRINT POWER
SALEM HARBOR
DEVELOPMENT LP ESSEX MA 1
Cosmo Buttaro
MassDEP Northeast Regional
Office
205B Lowell Street
Wilmington, MA 01887
[phone]
[e-mail] NE-12-022 4911 221112 9/9/2013 1/30/2014 5/5/2016 A
Emergency
Engine/Generat
or ULSD 7.4 MMBTU/H
Sulfur Dioxide
(SO2)Unspecified 0.011 LB/H
OTHER CASE-
BY-CASE
OH-0352
OREGON CLEAN ENERGY
CENTER ARCADIS, US, INC.LUCAS OH 5 P0110840 4931 221112 4/3/2013 6/18/2013 5/4/2016 A
Emergency
generator diesel 2250 KW
Sulfur Dioxide
(SO2)
EPA/OAR Mthd
6C 0.03 LB/H N/A
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Sulfur Oxides
(SOx)Unspecified 0.01 LB/H
OTHER CASE-
BY-CASE
TX-0728
PEONY CHEMICAL
MANUFACTURING
FACILITY BASF BRAZORIA TX 6
David Infortunio
512-239-1247
<[e-mail]
v>118239, N200 2813 325311 2/11/2015 4/1/2015 1/31/2020 B
Emergency
Diesel
Generator Diesel 1500 hp
Volatile
Organic
Compounds
(VOC)Unspecified
Minimized hours
of operations Tier
II engine 0.7 LB/H
OTHER CASE-
BY-CASE
PA-0291
HICKORY RUN ENERGY
STATION
HICKORY RUN
ENERGY LLC LAWRENCE PA 3
JOHN F. GUTH
NORTHWEST REGION AIR
PROGRAM MANAGER
230 Chestnut Street
Meadville, PA 16335-3481
814-332-6940 37-337A 4911 221112 12/20/2012 4/23/2013 3/2/2020 A
EMERGENCY
GENERATOR
Ultra Low
sulfur
Distillate 7.8 MMBTU/H
Volatile
Organic
Compounds
(VOC)Unspecified 0.7 LB/H
OTHER CASE-
BY-CASE
*PA-0313
FIRST QUALITY TISSUE
LOCK HAVEN PLT
FIRST QUALITY
TISSUE, LLC CLINTON PA 3 18-00030C 2676 322291 4/14/2015 7/27/2017 3/26/2019 B
Emergency
Generator Diesel 2500 bhp
Volatile
Organic
Compounds
(VOC)Unspecified 3.5 G
RBLCID Facility Name
Corporate Or
Company Name
Facility
County
Facility
State
EPA
Region Other Agency Contact Info Permit Num SIC Code NAICS Code
Complete
Application
Date
Permit
Issuance
Date
Date Determination
Last Updated
Permit
Type Process Name Primary Fuel Throughput Tput Unit Pollutant Test Method
Control Method
Description
Emission
Limit
Emission Limit
1 Unit
Case-By-Case
Basis
Central Valley Water
Reclamation Facility
South Salt Lake, UT
(3) 2000kW Diesel Generators
JULY 2021
REV-2
Submitted by:
Nick Paolo
Smith Power Products,
Inc.
303-810-1085
[e-mail] SU
B
M
I
T
T
A
L
L
Date: September 14, 2020
Reference: SPP2702.4 CVWRF 3 Salt Lake City - 2000kW QTY 3 4160V
We are pleased to offer the following quote for the above project:
The proposal is per one-line drawing and specifications with clarifications in the notes section of the bill of
materials listed after the quote: please reference previous quote 2702.1
QUANTITY EQUIPMENT DESCRIPTION PRICE EACH TOTAL PRICE
3 MTU 2000kW Generator Set M/N DS2000 Diesel Fuel Derate: 2000kW @ 4300 Feet, 104°F 4160V Volt, 3 Phase, 60 HZ, 1800 RPM Genset OPU Dry Assembly Weight: lbs.
Included Included
3 Generator Enclosure Weather Proof Level 2
85 dBA at 23’ Included Included
3 NGR’s Included Included
*Crane/rigging not included. Fuel not included.
Cat walks not included. If required, we can
provide an adder.
Equipment Description:
Generator:
Application Emergency Standby (3D) 1,
Frequency 60 Hz 1, Generator Voltage 4160 V 1,
Phase 3 Phase 1, Unit Specification Standard Unit 1,
Engine Model 16V4000G74S (24volts) 1, Exhaust Emissions (EPA) EPA Tier 2 1,
Radiator Design Temperature 43°C 1, Temp Rise 130° 1,
Power Output 2000 kW 1, Full Load Amps 346 1,
Generator Frame and Wire Qty LSA 641-VL75-M (6 Wire) 1, Generator Wire Configuration Wye 1,
Custom Generator Enclosure Sound 85dB(A) @ 23ft 1, Fuel Tank UL142 24hr tank 1,
Control panel With Control Panel 1, Circuit Breaker Options Exterior mounted 1,
Breaker Wire Color Scheme Standard Breaker Wire Color Scheme 1, Paralleling Paralleling without MTU Components 1,
Central Valley Water Reclation Facility SEPT2020 REV0 Page 29 of 146
3
3
3 NGR’s
y
Generator Enclosure
MTU 2000kW Generator SetM/N DS2000
2000kW @ 4300 Feet,104°F
4160 V
2000 kW
y
Sound 85dB(A) @ 23ftUL142 24hr tank()@
MTU 16V4000 DS2000 45 °C
Diesel Generator Set
2,000 kWe/60 Hz/Standby/380 - 13,800V
Voltage (L-L)380V † ‡416V † ‡440V † ‡480V † ‡600V ‡
Phase33333
PF 0.8 0.8 0.8 0.8 0.8
Hz 60 60 60 60 60
kW 2,000 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500 2,500
Amps 3,798 3,470 3,280 3,007 2,406
skVA@30%
voltage dip 6,899 6,030 6,745 4,914 4,575
Generator model*841-M70-M 841-M70-M 841-M70-M 641-VL90-M 641-VL85-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
Voltage (L-L)4,160V 12,470V 13,200V 13,800V
Phase3333
PF 0.8 0.8 0.8 0.8
Hz 60 60 60 60
kW 2,000 2,000 2,000 2,000
kVA 2,500 2,500 2,500 2,500
Amps 347 116 109 105
skVA@30%
voltage dip 4,303 3,243 3,633 3,971
Generator model*641-VL75-M 4P6.6-2600-M 4P6.6-2600-M 4P6.6-2600-M
Q|œ¬
ҋ³|130 °C/40 °C 130 °C/40 °C 130 °C/40 °C 130 °C/40 °C
¢|t֋¢6 LEAD WYE 6 LEAD WYE 6 LEAD WYE 6 LEAD WYE
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 50 of 146
MTU 16V4000 DS2000 45 °C
4,160V
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 51 of 146
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Central Valley Water Reclation Facility SEPT2020 REV0 Page 53 of 146
UNITED STATES ENVIRONMENTAL PROTECTION AGENCY2020 MODEL YEARCERTIFICATE OF CONFORMITYWITH THE CLEAN AIR ACT
OFFICE OF TRANSPORTATIONAND AIR QUALITYANN ARBOR, MICHIGAN 48105
Certificate Issued To: MTU America, Inc. (U.S. Manufacturer or Importer)
Certificate Number: LMDDL95.4GTZ-007
Effective Date:01/29/2020
Expiration Date:12/31/2020
_________________________Byron J. Bunker, Division DirectorCompliance Division
Issue Date:01/29/2020
Revision Date:N/A
Model Year: 2020
Manufacturer Type: Original Engine Manufacturer
Engine Family: LMDDL95.4GTZ
Mobile/Stationary Indicator: Stationary
Emissions Power Category: 560<kW<=2237
Fuel Type: Diesel
After Treatment Devices: No After Treatment Devices Installed
Non-after Treatment Devices: Electronic Control, Smoke Puff Limiter
Pursuant to Section 111 and Section 213 of the Clean Air Act (42 U.S.C. sections 7411 and 7547) and 40 CFR Part 60, and subject to the terms and conditions prescribed in those provisions, this certificate of
conformity is hereby issued with respect to the test engines which have been found to conform to applicable requirements and which represent the following engines, by engine family, more fully described in
the documentation required by 40 CFR Part 60 and produced in the stated model year.
This certificate of conformity covers only those new compression-ignition engines which conform in all material respects to the design specifications that applied to those engines described in the
documentation required by 40 CFR Part 60 and which are produced during the model year stated on this certificate of the said manufacturer, as defined in 40 CFR Part 60.
It is a term of this certificate that the manufacturer shall consent to all inspections described in 40 CFR 1068 and authorized in a warrant or court order. Failure to comply with the requirements of such a
warrant or court order may lead to revocation or suspension of this certificate for reasons specified in 40 CFR Part 60. It is also a term of this certificate that this certificate may be revoked or suspended or
rendered void ab initio for other reasons specified in 40 CFR Part 60.
This certificate does not cover engines sold, offered for sale, or introduced, or delivered for introduction, into commerce in the U.S. prior to the effective date of the certificate.
The actual engine power may lie outside the limits of the Emissions Power Category shown above. See the certificate application for details.
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Issued to: MTU America Inc
100 Power Dr
Mankato MN 56001-4790

This certificate confirms that
representative samples of
ENGINE GENERATORS
Stationary engine generator assemblies, Diesel Fueled, for
indoor use, Models 12V4000, 16V4000, 20V4000 followed
by D, followed by S, followed by 1250 thru 3250.

Have been investigated by UL in accordance with the
Standard(s) indicated on this Certificate.

Standard(s) for Safety: UL 2200-Engine Generators
CAN/CSA C22.2 No. 100-14-Motors and Generators
Additional Information: See the UL Online Certifications Directory at
https://iq.ulprospector.com for additional information.
This Certificate of Compliance does not provide authorization to apply the UL Mark. Only the UL Follow-Up Services Procedure provides authorization to apply the UL Mark. Only those products bearing the UL Mark should be considered as being UL Certified and covered under UL’s Follow-Up Services. Look for the UL Certification Mark on the product.
Central Valley Water Reclation Facility SEPT2020 REV0 Page 43 of 146

Accredited Body: DQS GmbH, August-Schanz-Straße 21, 60433 Frankfurt am Main, Germany

CERTIFICATE
This is to certify that

MTU America Inc.
100 Power Drive
Mankato, MN 56001
United States of America
has implemented and maintains a Quality Management System.
Scope:
Development, production, sales and service of decentralized energy systems.
Through an audit, documented in a report, it was verified that the management system
fulfills the requirements of the following standard:

ISO 9001 : 2015

Certificate registration no.
Excerpt from certificate registration no.
Valid from
Valid until
Date of certification
500767 QM15
353331 QM15
2018-08-15
2021-08-14
2018-08-15
DQS GmbH

Stefan Heinloth
Managing Director

Central Valley Water Reclation Facility SEPT2020 REV0 Page 44 of 146