DAQ-2024-004610

1
DAQC-CI160040001-23
Site ID 16004 (B1)

MEMORANDUM

TO: FILE – DOMINION ENERGY UTAH – Magna LNG Facility

THROUGH: Rik Ombach, Minor Source Oil and Gas Compliance Section Manager

FROM: Paul Bushman, Environmental Scientist

DATE: November 9, 2023

SUBJECT: FULL COMPLIANCE EVALUATION, Minor, Salt Lake County

INSPECTION DATE: November 2, 2023

SOURCE LOCATION: 1731 South 8000 West
Magna, UT
SOURCE CONTACTS: Brian Nosich, Sr. Environmental Compliance Coordinator
307-371-9321 [e-mail]
Tommy Flynn, Environmental - Records
804-337-2099 [e-mail]

OPERATING STATUS: Operating.

PROCESS DESCRIPTION: Dominion energy receives natural gas from a pipeline to be
liquified and stored in a 15 million gallon tank. The liquified
natural gas is kept in storage to act as a reservoir during periods
of high natural gas usage and is re-gasified and reintroduced into
the pipeline during peak demand periods. The liquification
process involves a pretreatment system that uses an amine-based
acid gas removal system. Recovered waste streams from the
pretreatment is controlled with a 1.65 MMBtu/hr thermal
oxidizer. After pretreatment the natural gas is liquefied using a
nitrogen cycle liquefaction system. Excess "heavy" hydrocarbons
created by this process are controlled with a 34.3 MMBtu/hr
flare. This process also utilizes three 78.31 MMBtu/hr glycol
water heaters. On-site are two 1000 kW emergency generator
engines and one 300 hp diesel fire pump engine.

APPLICABLE REGULATIONS: Approval Order (AO) DAQE-AN160040002-21 dated August
19, 2021
NSPS (Part 60) -Dc : Standards of Performance for Small
Industrial-Commercial-Institutional Steam Generating Units,
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) -ZZZZ: National Emissions Standards for
2
Hazardous Air Pollutants for Stationary Reciprocating Internal
Combustion Engines

SOURCE EVALUATION:

Name of Permittee: Permitted Location:

Dominion Energy Utah- Magna LNG Facility
1140 West 200 South PO Box 45360 1731 South 8000 West
Salt Lake City, UT 84145 Magna, UT

SIC Code: 4922 (Natural Gas Transmission)

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]

Status: In Compliance. No limits appear to have been exceeded.

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]

Status: In Compliance. No modifications to the equipment or processes were observed
during the inspection.

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

Status: In Compliance. Records were both reviewed on site and after the inspection via
email. See attached.

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]

Status: In Compliance. The equipment appears to be operated and maintained in a manner
consistent with good air pollution control practices for minimizing emissions.

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

Status: In Compliance. No breakdowns have been reported.

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

Status: In Compliance. The source submitted an emission inventory for the 2022 operating
year.

I.8 The owner/operator shall submit documentation of the status of construction or modification of
equipment modified in this AO to the Director within 18 months of the issuance of this AO. The
owner/operator shall submit documentation of the status of construction or modification of
equipment modified in this AO to the Director within 18 months of the issuance of this AO. This
AO may become invalid if construction is not commenced by January 18, 2022 or if construction
is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send
the documentation to the Director, attn.: NSR Section. [R307-401-18]

Status: In Compliance. The source submitted a notice of construction on February 10,
2023, stating that the facility became operational on November 23, 2022. See attachments.

Section II: SPECIAL PROVISIONS

II.A The approved installations shall consist of the following equipment:

II.A.1 Dominion Energy
LNG Storage Facility

II.A.2 Three (3) Glycol Water Heaters
Rating: 78.31 MMBtu/hr (each)
Fuel: Natural Gas
Control: Low NOx Burner with FGR

II.A.3 Two (2) Tube and Shell Heat Vaporizers
*Process equipment associated with Glycol Water Heaters. Listed for informational purposes only.

II.A.4 One (1) Control Flare
Rating: 34.3 MMBtu/hr
controls hydrocarbons from liquefaction process

II.A.5 Two (2) Emergency Generators
Rating: 1000 kW (each)
Fuel: Natural Gas
Federal Applicability: NSPS JJJJ, MACT ZZZZ
Stack Height: 10 feet each, measured from base of stack

II.A.6 One (1) Fire Pump Engine
Rating: 300 hp
Fuel: Diesel
Federal Applicability: NSPS IIII and MACT ZZZZ
Stack Height: 10 feet, measured from base of stack

II.A.7 Miscellaneous Heaters and Boilers
Rating: <5 MMBtu/hr each
Fuel: Natural Gas
*listed for informational purposes only

II.A.8 One (1) Amine Gas Pre-treatment system
Associated Equipment: 2.8 MMBtu/hr amine reboiler, 1.81 MMBtu/hr Dehydration Regen Gas
Heater
Control: 1.65 MMBtu/hr thermal oxidizer (burner rating)

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II.A.9 One (1) Emergency Flare
Controls: Storage and Process equipment
Associated Equipment: Two (2) attached pilot lights
Intended for use in emergency, maintenance and shutdown situations.

II.A.10 One (1) Liquid Natural Gas Storage Tank
Capacity: 15 Million Gallons/ 1,230 MMscf

II.A.11 One (1) Electric Compressor System
Used to liquefy and de-liquefy gas from storage tank,
NSPS Applicability: Subpart OOOOa

Status: In Compliance. The above equipment was observed on site with the exception of
II.A.9 - One (1) Emergency Flare. The emergency flare was not on site. Mr. Flynn
stated that the emergency flare is brought on site when needed during emergency
and maintenance uses only and is not a permanent installation.

II.B Requirements and Limitations

II.B.1 Combustion Sources Requirements

II.B.1.a The following visible emission limits shall not be exceeded:

A. Any stationary point: 10% opacity

B. The diesel-fired fire pump engine: 20% opacity

C. Any natural gas-fired generator and glycol water heater: 10% opacity. [R307-401-8]

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

Status: In Compliance. No emissions were observed from any point during the inspection.

II.B.1.b The owner/operator shall not combust more than 741 MMscf of natural gas per rolling 12-month
period. This fuel consumption limit does not apply to fuel combusted by the emergency engines
or emergency flare for both emergency and non-emergency use situations. [R307-401-8]

II.B.1.b.1 To determine compliance with a rolling 12-month total the owner/operator shall calculate a new
12-month total by the 20th day of each month using data from the previous 12 months. Records
of consumption shall be kept for all periods when the plant is in operation. Natural gas
consumption shall be determined using company records or purchase receipts. [R307-401-8]

Status: In Compliance. According to the reviewed records, the site combusted 28.4046
MMscf of natural gas for the previous rolling 12-month period. See Attachments.

II.B.1.c The owner/operator shall install burners for the 78.3 MMBtu/hr glycol water heaters that are
certified to meet a NOx emission rate of 30 ppm. [R307-401-8]

II.B.1.c.1 The owner/operator shall keep a record of the manufacturer's certification of the emission rate.
The record shall be kept for the life of the equipment. [R307-401-8]

Status: In Compliance. The owner has installed burners that are certified to meet a NOx
emission rate of 30 ppm. See attachments.

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II.B.1.d The owner/operator shall not operate the Glycol Water Heaters at the same time the Regen Gas
Heater, Amine Reboiler, and Thermal Oxidizer are operating. [R307-401-8]

Status: In Compliance. According to the source that due to the processes, the Glycol Water
Heaters are not operated at the same time as the Regen Gas Heater, Amine Reboiler, and
Thermal Oxidizer.

II.B.2 Emergency Engine Requirements

II.B.2.a The owner/operator shall install natural gas emergency engines that are certified to meet a NOx
emission rate of 2.0 g/hp-hr or less. The owner/operator will install a fire pump engine that is
certified to meet a NOx emission rate of 3.0 g/hp-hr or less. [40 CFR 60 Subpart IIII, 40 CFR 60
Subpart JJJJ, R307-401-8]

II.B.2.a.1 The owner/operator shall keep a record of the manufacturer's certification of the emission rate.
The record shall be kept for the life of the equipment. If the engine is non-certified, the
owner/operator shall keep a maintenance plan and records of conducted maintenance, and shall
conduct an initial performance test and conduct subsequent performance testing according to 40
CFR 60.4243. [40 CFR 60 Subpart JJJJ, R307-401-8]

Status: In Compliance. The emergency engines are certified to meet a NOx emission rate of
1.0 g/hp-hr. The fire pump engine is tier 3 emissions certified to meet a NOx emission rate
of 2.69 g/hp-hr. The manufacturer’s certifications are attached.

II.B.2.b The owner/operator shall not operate each emergency engine or fire pump engine on site for
more than 100 hours per rolling 12-month period during non-emergency situations. There is no
time limit on the use of the engines during emergencies. [40 CFR 60 Subpart ZZZZ,
R307-401-8]

II.B.2.b.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the 20th day of each month using data from the previous 12 months. Records
documenting the operation of each emergency engine shall be kept in a log and shall include the
following:

A. The date the emergency engine was used

B. The duration of operation in hours

C. The reason for the emergency engine usage. [40 CFR 60 Subpart ZZZZ, R307-401-8]

Status: In Compliance. The source keeps log with the above requirements. For the most
recent rolling 12-month period Emergency Generator 1 operated for 14.3 hours.
Emergency Generator 2 operated for 13.3 hours. The fire pump operated for 14.1 hours.
See attachments.

II.B.2.b.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [R307-401-8, 40 CFR 63 Subpart ZZZZ]

Status: In Compliance. The emergency engines are equipped with non-resettable hour
meters.

II.B.2.c The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as
fuel in the fire pump engine. [R307-401-8]

II.B.2.c.1 The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur
diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8]

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II.B.2.c.2 To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain
records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel
fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the ULSD
requirements. [R307-401-8]

Status: In Compliance. The source uses only ULSD fuel in the fire pump engine. See
attached fuel purchase invoice.

II.B.2.d The owner/operator shall comply with the following testing/maintenance restrictions:

A. The owner/operator shall not test more than one (1) engine at a time,

B. The owner/operator shall not conduct more than one (1) test per week for each engine,
and;

C. The owner/operator shall not test the emergency generators or fire pump engine before
8:00 am or after 5:00 pm. [R307-410]

II.B.2.d.1 Records for engine testing shall be kept in a log and shall include the date, the start time and end
time of any test. [R307-410]

Status: In Compliance. Records reviewed on site show that the emergency engines and fire
pump engines are tested for 15 minutes per week on Wednesdays. The log for each engine
shows the start and stop times, and no engines were noted to have been tested during the
same time frame. All tests observed in the logbook occurred between 8:00 am and 5:00 pm.

II.B.3 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair)

II.B.3.a The owner/operator shall develop a fugitive emissions monitoring plan. At a minimum, the plan
shall include:

A. Monitoring frequency

B. Monitoring technique and equipment

C. Procedures and timeframes for identifying and repairing leaks

D. Recordkeeping practices

E. Calibration and maintenance procedures
[R307-401-8]

II.B.3.a.1 The plan shall address monitoring for "difficult-to-monitor" and "unsafe-to-monitor"
components. [R307-401-8]

Status: In Compliance. The source has developed a fugitive emissions monitoring plan. The
plan contains the above requirements. See attachments.

II.B.3.b The owner/operator shall conduct monitoring surveys on site to observe each "fugitive emissions
component" for "fugitive emissions."

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

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

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II.B.3.b.1 Monitoring surveys shall be conducted according to the following schedule:

A. No later than 60 days after startup of production of Liquified Natural Gas after the
completion of commissioning activities.

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

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

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

[R307-401-8]

II.B.3.b.2 Monitoring surveys shall be conducted using one or both of the following to detect fugitive
emissions:

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

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

[R307-401-8]

Status: In Compliance. The source conducts the required monitoring surveys according to
the required schedule using OGI equipment that meet the requirements above. Resurveys
are conducted using monitoring equipment that meets U.S. EPA Method 21. See attached
monitoring survey.

II.B.3.c If fugitive emissions are detected at any time, the owner/operator shall repair the fugitive
emissions component as soon as possible but no later than 15 calendar days after detection.

If the repair or replacement is technically infeasible, would require a vent blowdown, a well
shutdown or well shut-in, or would be unsafe to repair during operation of the unit, the repair or
replacement must be completed during the next well shutdown, well shut-in, after an
unscheduled, planned or emergency vent blowdown or within 24 months, whichever is earlier.
[R307-401-8]

II.B.3.c.1 The owner/operator shall resurvey the repaired or replaced fugitive emissions component no later
than 30 calendar days after the fugitive emissions component was repaired. [R307-401-8]

Status: In Compliance. The source repairs detected leaks within 15 calendar days after
detection unless technically infeasible. The source conducts resurveys using Method 21
equipment. See attached monitoring survey.

II.B.3.d The owner/operator shall maintain records of the fugitive emissions monitoring plan, monitoring
surveys, repairs, and resurveys. [R307-401-8]

Status: In Compliance. The owner/operator maintains records of the fugitive emissions
monitoring plan, monitoring surveys, repairs, and resurveys. See attachments.

II.B.4 Flare and Thermal Oxidizer Requirements

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II.B.4.a The owner/operator shall control emissions from the amine gas pre-treatment system with a
thermal oxidizer. The owner/operator shall control emissions generated from the liquefaction and
storage process with the emergency flare. The owner/operator shall control emissions from the
heavies waste stream during the liquification process with the control flare. [R307-401-8]

Status: In Compliance. The source controls the emissions from the amine gas pre-treatment
system with a thermal oxidizer. The source controls the emissions from the heavies waste
stream with a control flare.

II.B.4.b The owner/operator shall operate the emergency flare, control flare, and thermal oxidizer with a
continuous pilot flame and shall equip each device with an auto-igniter. [R307-503-4]

Status: In Compliance. The control flare and the thermal oxidizer is operated with a
continuous pilot flame and each device is equipped with an auto-igniter.

II.B.4.c The emergency flare, control flare, and thermal oxidizer shall operate with no visible emissions.
[R307-401-8]

II.B.4.c.1 The owner/operator shall conduct visual determination of emissions from the emergency flare,
control flare, and thermal oxidizer quarterly. Visual determination of emissions shall be
conducted for a 6-minute period while the unit(s) are operating according to 40 CFR 60,
Appendix A, Method 22. [R307-401-8]

II.B.4.c.2 To determine compliance with the emergency flare, control flare, and thermal oxidizer opacity
requirements, the owner/operator shall keep a record of the following:

A. The date and time of the day the observations were made

B. Which unit(s) the observation was conducted for

C. Whether or not visible emissions were observed (the owner/operator may note if the
equipment did not operate during any given calendar quarter period)

D. Any corrective actions taken, if any. [R307-401-8]

Status: In Compliance. The source keeps records of the Method 22 observations. Records
reviewed on site show that the source performs the observations quarterly, with the most
recent observations occurring on October 23, 2023.

Section III: APPLICABLE FEDERAL REQUIREMENTS

In addition to the requirements of this AO, all applicable provisions of the following federal programs
have been found to apply to this installation. This AO in no way releases the owner or operator from any
liability for compliance with all other applicable federal, state, and local regulations including UAC
R307.

NSPS (Part 60) -Dc : Standards of Performance for Small Industrial-Commercial-Institutional Steam
Generating Units

Status: In Compliance. The boilers combust only natural gas. Each Glycol Water heater has a gas
flowmeter installed. Records of the amount of natural gas combusted is kept monthly. See attachments.

9
NSPS (Part 60) IIII : Standards of Performance for Stationary Compression Ignition Internal Combustion
Engines

Status: In Compliance. The diesel fire pump was manufactured in September of 2021, and is tier 3
certified. The diesel fire pump engine operates less than 100 hours per year for maintenance, testing,
and training purposes. It is equipped with a non-resettable hour meter. According to the source,
maintenance is performed according to the manufacturer's specifications.

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

Status: In Compliance. The two emergency generators were manufactured in July of 2021, and are EPA
certified. They are equipped with non-resettable hour meters. They operate less than 100 hours per year
for maintenance, testing, and training purposes. Cat Wheeler is contracted to perform the maintenance
for these generators.

NSPS (Part 60) OOOOa : Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015

Status: Not Observed. NSPS Part 60 Subpart OOOOa applies to sources located within the Crude Oil
and Natural Gas Production source category, which for natural gas production includes the well and
extends to, but does not include, the point of custody transfer to the natural gas transmission and
storage segment. This facility is a liquid natural gas storage facility in the natural gas transmission and
storage segment. The natural gas at this facility has already been processed and is ready for delivery to
a final end user.

MACT (Part 63) -ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary
Reciprocating Internal Combustion Engines

Status: In Compliance. The fire pump meets the requirements of 40 CFR 60, Subpart IIII for
compression engines. The emergency generators meet the requirements of 40 CFR 60, Subpart JJJJ for
spark ignition engines. No further requirements under Subpart ZZZZ apply.

AREA SOURCE RULES EVALUATION:

The following Area Source Rules were evaluated during this inspection:

Nonattainment and Maintenance Areas for PM10: Emission Standards [R307-305]

Status: In Compliance. The requirements of this area source rule are satisfied by compliance with
AO condition II.B.1.a.

Nonattainment and Maintenance Areas for PM10:Emissions and Fugitive Emissions and Fugitive Dust
[R307-309]

Status: In Compliance. No fugitive emissions or fugitive dust was observed during the inspection.

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EMISSION INVENTORY:

Listed before are the Actual Emissions Inventory provided from Dominion Energy Utah - Magna LNG
Facility. A comparison of the estimated total potential emissions (PTE) on AO: DAQE-AN160040002-21
dated August 19, 2021, is provided.
(PTE) are supplied for supplemental purposes only.

Criteria Pollutant PTE tons/yr Actuals tons/yr
CO2 Equivalent 54956.00
Carbon Monoxide 30.10
Nitrogen Oxides 20.20 0.01354
Particulate Matter - PM10 3.10
Particulate Matter - PM2.5 3.10
Sulfur Dioxide 0.30
Volatile Organic Compounds 36.40 0.00857

Hazardous Air Pollutant PTE lbs/yr Actuals lbs/yr
Formaldehyde (CAS #50000) 178
Generic HAPs (CAS #GHAPS) 70
Hexane (CAS #110543) 1464

PREVIOUS ENFORCEMENT
ACTIONS: No enforcement actions within the past five years.

COMPLIANCE STATUS &
RECOMMENDATIONS: In regards to Approval Order (AO) DAQE-AN160040002-21
dated August 19, 2021: In compliance at the time of inspection.
The facility appears to be well maintained and operated.
Required records were current and made available both during
the inspection and afterwards via email.

HPV STATUS: Not Applicable.

RECOMMENDATION FOR
NEXT INSPECTION: FR clothing, hard hat, safety boots, safety glasses, and hearing
protection are required to tour the site.

ATTACHMENTS: Applicable Supporting Documentation Included
Dominion Energy SeMces, lnc.
120 Tredegar Street
Richmond, VA 23219
DominionEnergy.com
February L0,2023
BY: CERTIFIED MAIL
Director
Attn: NSR Section
Utah Division of Air Quality
MultiAgency State Office Building
195 North 1950 West
Salt Lake City, Utah 84116
RE: Dominion Enerqv Utah
Maqna LNG Facilitv (DAQE-AN160040002-21 )
Status Notification of Construction/Modifi cation
To whom it may concern:
THiuile"
UTAH DEPARTI{ENT OF
ENVIRONMEN-TAL QUAUTY
FEB 2',2C2.?
DIVISION OF AtR OUALITY
REVIEWED
Iniriats: @o^,,, 7/r jf z,
ComplianceSt"tug ngCre.F&n* l(&Lt
Dominion Energy Utah (DEU) is submitting this notification in accordance with condition
1.8 of the approval order referenced above. Construction of the emission units at the
facility started in July 2021. Construction of the facility continued until commissioning
activities were completed and the plant was put into commercial operations on
November 23,2022.
lf you have any questions, please contact Tommy Flynn at [phone] or via email
at thomas.j.flyn n@dom inionenergy. com.
Sincerely,
Molly A. Parker
Director, Environmental Services
Emergency Generator
UNIT =
YEAR MONTH
Non-
Emergency
Hours
Emergency
Hours
Calendar Year Non-
Emergency Hours
12-Month Rolling
Non-Emergency
Hours
2022 JUN 0.00 0.00 0.0 0.0 0.0 0.0
2022 JUL 0.00 0.00 0.0 0.0 0.0 0.0
2022 AUG 0.00 0.00 0.0 0.0 0.0 0.0
2022 SEPT 0.00 0.00 0.0 0.0 0.0 0.0
2022 OCT 0.80 0.80 0.8 0.0 0.8 0.8
2022 NOV 2.10 1.30 1.3 0.0 2.1 2.1
2022 DEC 3.10 1.00 1.0 0.0 3.1 3.1
2023 JAN 4.10 1.00 1.0 0.0 4.1 4.1
2023 FEB 7.50 3.40 3.4 0.0 7.5 7.5
2023 MAR 8.30 0.80
0.8 0.0 8.3 8.3
2023 APR 9.30 1.00 1.0 0.0 9.3 9.3
2023 MAY 10.30 1.00 1.0 0.0 10.3 10.3
2023 JUN 11.30 1.00 1.0 0.0 11.3 11.3
2023 JUL 12.60 1.30 1.3 0.0 12.6 12.6
2023 AUG 14.10 1.50 1.5 0.0 14.1 14.1
2023 SEPT 14.10 0.00 0.0 0.0 14.1 14.1
2023 OCT 15.10 1.00 1.0 0.0 14.3 14.3
2023 NOV 15.40 0.30 0.3 0.0 13.3 13.3
2023 DEC 15.40 0.00 0.0 0.0 12.3 12.3
Total 12-Month Rolling
Operating Hours
3.1
12.3
Emergency Auxiliary Generator Magna LNGStation Name:
Operating Hours Data
1468-hp Gen 1
Emergency Generator hour tracking per NESHAP ZZZZ or NSPS JJJJ
Reason for Emergency
Operation
LIMIT = 100 Non-
Emergency Hours in
any 12-Month
Rolling PeriodTotal Hours on Non-Reset
Hour Meter
Hours Operated Since Last
Reading
NESHAP/NSPS Requirement LIMIT = 100 Non-Emergency
Hours in a Calendar Year
Emergency Generator
UNIT =
YEAR MONTH
Non-
Emergency
Hours
Emergency
Hours
Calendar Year Non-
Emergency Hours
12-Month Rolling
Non-Emergency
Hours
2022 JUN 0.00 0.00 0.0 0.0 0.0 0.0
JUL 0.00 0.00 0.0 0.0 0.0 0.0
AUG 0.00 0.00 0.0 0.0 0.0 0.0
SEPT 0.00 0.00 0.0 0.0 0.0 0.0
OCT 0.80 0.80 0.8 0.0 0.8 0.8
NOV 1.80 1.00 1.0 0.0 1.8 1.8
DEC 2.80 1.00 1.0 0.0 2.8 2.8
2023 JAN 3.80 1.00 1.0 0.0 3.8 3.8
FEB 4.60 0.80 0.8 0.0 4.6 4.6
MAR 5.90 1.30
1.3 0.0 5.9 5.9
APR 8.50 2.60 2.6 0.0 8.5 8.5
MAY 16.10 7.60 0.8 6.8 Loss of Purchased Power 16.1 9.3
JUN 17.10 1.00 1.0 0.0 17.1 10.3
JUL 18.40 1.30 1.3 0.0 18.4 11.6
AUG 19.90 1.50 1.5 0.0 19.9 13.1
SEPT 19.90 0.00 0.0 0.0 19.9 13.1
OCT 20.90 1.00 1.0 0.0 20.1 13.3
NOV 21.20 0.30 0.3 0.0 19.4 12.6
DEC 21.20 0.00 0.0 0.0 18.4 11.6
1468-hp Gen 2
2.8
11.6
Operating Hours Data
Total Hours on Non-Reset
Hour Meter
Hours Operated Since Last
Reading
NESHAP/NSPS Requirement
Reason for Emergency
Operation
Total 12-Month Rolling
Operating Hours
LIMIT = 100 Non-Emergency
Hours in a Calendar Year
LIMIT = 100 Non-
Emergency Hours in
any 12-Month
Rolling Period
Station Name:Magna LNG Emergency Auxiliary Generator
Emergency Generator hour tracking per NESHAP ZZZZ or NSPS JJJJ
Emergency Generator
UNIT =
YEAR MONTH
Non-
Emergency
Hours
Emergency
Hours
Calendar Year Non-
Emergency Hours
12-Month Rolling
Non-Emergency
Hours
2022 JUN 0.00 0.00 0.0 0.0 0.0 0.0
JUL 0.00 0.00 0.0 0.0 0.0 0.0
AUG 3.80 3.80 3.8 0.0 3.8 3.8
SEPT 3.80 0.00 0.0 0.0 3.8 3.8
OCT 4.60 0.80 0.8 0.0 4.6 4.6
NOV 5.60 1.00 1.0 0.0 5.6 5.6
DEC 6.60 1.00 1.0 0.0 6.6 6.6
2023 JAN 7.60 1.00 1.0 0.0 7.6 7.6
FEB 8.60 1.00 1.0 0.0 8.6 8.6
MAR 9.90 1.30
1.3 0.0 9.9 9.9
APR 10.90 1.00 1.0 0.0 10.9 10.9
MAY 11.90 1.00 1.0 0.0 11.9 11.9
JUN 12.90 1.00 1.0 0.0 12.9 12.9
JUL 14.20 1.30 1.3 0.0 14.2 14.2
AUG 16.70 2.50 2.5 0.0 12.9 12.9
SEPT 16.70 0.00 0.0 0.0 12.9 12.9
OCT 18.70 2.00 2.0 0.0 14.1 14.1
NOV 19.20 0.50 0.5 0.0 13.6 13.6
DEC 19.20 0.00 0.0 0.0 12.6 12.6
Fire Pump
Engine
6.6
12.6
Operating Hours Data
Total Hours on Non-Reset
Hour Meter
Hours Operated Since Last
Reading
NESHAP/NSPS Requirement
Reason for Emergency
Operation
Total 12-Month Rolling
Operating Hours
LIMIT = 100 Non-Emergency
Hours in a Calendar Year
LIMIT = 100 Non-
Emergency Hours in
any 12-Month
Rolling Period
Station Name:Magna LNG Emergency Auxiliary Generator
Emergency Generator hour tracking per NESHAP ZZZZ or NSPS JJJJ
Date
Emergency
Generator (G-
1880 & G-1885)
Fuel Meter
Reading (SCF)
Glycol Heater FH-
4120 Fuel Meter
Reading (SCF)
Glycol Heater FH-
4140 Fuel Meter
Reading (SCF)
Glycol Heater FH-
4160 Fuel Meter
Reading (SCF)
Flare Fuel Meter
Reading (SCF)
Regen Heater
Fuel Meter
Reading (SCF)
Amine Reboiler
and Flash Tank
Fuel Meter
Reading (SCF)
Thermal Oxidizer
Fuel Meter
Reading (SCF)
MONTHLY
TOTAL (NON-
EMERGENCY)
(SCF)
ROLLING 12-
MONTH TOTAL
NON-
EMERGENCY
(SCF)
MONTHLY
TOTAL (NON-
EMERGENCY)
(MMSCF)
ROLLING 12-
MONTH TOTAL
NON-
EMERGENCY
(MMSCF)
1/5/2023 7570 5140 4920 267310 3790 5720 6000 5290 298170 298170 0.29817 0.29817
2/1/2023 78530 1860 2284480 118280 35810 39080 -2900 494610 2971220 3269390 2.97122 3.26939
3/1/2023 19100 41300 0 0 404000 398800 14000 4279600 5137700 8407090 5.1377 8.40709
4/1/2023 9700 0 0 3470310 168100 49300 0 302100 3989810 12396900 3.98981 12.3969
5/1/2023 5900 0 100 100 93900 240600 0 584200 918900 13315800 0.9189 13.3158
6/1/2023 33100 0 0 100 101800 0 0 0 101900 13417700 0.1019 13.4177
7/1/2023 26900 300 100 100 96700 200 2400 6900 106700 13524400 0.1067 13.5244
8/1/2023 40600 300 1300 1400 212500 464000 1896200 1390300 3966000 17490400 3.966 17.4904
9/1/2023 27800 0 100 200 100600 380200 1234700 962600 2678400 20168800 2.6784 20.1688
10/1/2023 33200 0 0 0 835800 468300 2133300 1317100 4754500 24923300 4.7545 24.9233
11/1/2023 35100 2300 44300 900 611000 353800 1508800 960200 3481300 28404600 3.4813 28.4046
12/1/2023 0 28404600 0 28.4046
Date
Emergency
Generator (G-
1880 & G-1885)
Fuel Meter
Reading (SCF)
Glycol Heater FH-
4120 Fuel Meter
Reading (SCF)
Glycol Heater FH-
4140 Fuel Meter
Reading (SCF)
Glycol Heater FH-
4160 Fuel Meter
Reading (SCF)
Flare Fuel Meter
Reading (SCF)
Regen Heater
Fuel Meter
Reading (SCF)
Amine Reboiler
and Flash Tank
Fuel Meter
Reading (SCF)
Thermal Oxidizer
Fuel Meter
Reading (SCF)
MONTHLY
TOTAL (NON-
EMERGENCY)
(SCF)
ROLLING 12-
MONTH TOTAL
NON-
EMERGENCY
(SCF)
MONTHLY
TOTAL (NON-
EMERGENCY)
(MMSCF)
ROLLING 12-
MONTH TOTAL
NON-
EMERGENCY
(MMSCF)
1/1/2024 0 28106430 0 28.10643
2/1/2024 0 25135210 0 25.13521
3/1/2024 0 19997510 0 19.99751
4/1/2024 0 16007700 0 16.0077
5/1/2024 0 15088800 0 15.0888
6/1/2024 0 14880200 0 14.8802
7/1/2024 0 14880200 0 14.8802
8/1/2024 0 10914200 0 10.9142
9/1/2024 0 8235800 0 8.2358
10/1/2024 0 3481300 0 3.4813
11/1/2024 0 0 0 0
12/1/2024 0 0 0 0
CUSTOMER:
PO NUMBER:
COMPANY:
VENDOR NUMBER:
DOCUMENT TITLE :
1
0
Emissions Compliance Guarantee
REV. DATE
20208-ECG
Issued for Information (including opacity)
Issued for Information
DESCRIPTION
March 26, 2021
January 29, 2021
VDDR # 68
DOMINION ENERGY
50147884
300143898

Power Flame Incorporated
2001 South 21st Street, Parsons, Kansas 67357
Telephone [phone], Fax [phone]
Web Site: www.powerflame.com
E-Mail: tsd@ powerflame.com

February 26, 2021

Heatec, Inc.
5200 Wilson Road
Chattanooga, TN 37410
Attn: Lori Manzolillo

Subject: LNICM14-G-40 burner emissions

Dear Lori,

Our standard LNICMax burner is designed to meet 30 PPM NOx when firing natural
gas. This burner will maintain these NOx levels under normal use and with standard
maintenance.

As with all Power Flame products, we will guarantee the emission performance of the
burner, in this case 30 PPM NOx and 50 PPM CO, Corrected to 3% O2 when
commissioned by a qualified service technician and installed in the heater. Power
Flame can also guarantee a maximum opacity of 20%.

We will offer our standard product warranty relative to defects in workmanship or
component failures that extends 15 months from the date of shipment or 12 months
from the date of start-up, whichever occurs sooner.

We appreciate your interest in Power Flame products and trust we will have the
opportunity to provide the burners for your project. Please feel free to contact us if
you have any additional questions or concerns.

Sincerely,

POWER FLAME INCORPORATED

Marty Kelly
Marty Kelly
Inside Sales Engineer

FIRE PUMP ENGINES
MODELS
JU6H-UFADMG JU6H-UFADP0 JU6H-UFADR0 JU6H-UFADT0
JU6H-UFAD58 JU6H-UFADP8 JU6H-UFADR8 JU6H-UFADW8
JU6H-UFADNG JU6H-UFADQ0 JU6H-UFADS8 JU6H-UFADX8
JU6H-UFADN0 JU6H-UFAD88 JU6H-UFADS0 JU6H-UFAD98
JU6H
MODEL

RATED SPEED US-EPA
(NSPS)
Available
Until

1760 2100 2350 2400
UFADMG 175 131 175 131 No Expiration
UFAD58 183 137 No Expiration
UFADNG 190 142 181 135 183 137 183 137 No Expiration
UFADN0 197 147 197 147 200 149 200 149 No Expiration
UFADP0 209 156 211 157 211 157 No Expiration
UFADP8 220 164 No Expiration
UFADQ0 224 167 226 169 226 169 No Expiration
UFAD88 237 177 No Expiration
UFADR0 238 177.5 240 179 240 179 No Expiration
UFADR8 250 187 No Expiration
UFADS8 260 194 No Expiration
UFADS0 260 194 268 200 268 200 No Expiration
UFADT0 274 204 275 205 275 205 No Expiration
UFADW8 282 211 No Expiration
UFADX8 305 227.5 No Expiration
UFAD98 315 235 No Expiration
ITEM
JU6H MODELS
MG 58 NG N0 P8 88 P0 Q0 R0 S0 T0 R8 S8 W8 X8 98
Number of Cylinders 6
Aspiration TRWA
Rotation*CW
Overall Dimensions – in. (mm) 59.8 (1519) H x 56.7 (1414) L x 36.7 (933) W 60.9 (1547) H x 58.6 (1488) L x 40.0 (1015) W
Crankshaft Centerline Height – in. (mm)14 (356)
Weight – lb (kg)1747 (791)
Compression Ratio 19.0:1 17.0:1
Displacement – cu. in. (L)415 (6.8)
Engine Type 4 Stroke Cycle – Inline Construction
Bore & Stroke – in. (mm)4.19 x 5.00 (106 x 127)
Installation Drawing D628
Wiring Diagram AC C07651
Wiring Diagram DC C071367, C072146, C071361 C071368, C072146, C071761
Engine Series John Deere 6068 Series Power Tech E John Deere 6068 Series Power Tech Plus
Speed Interpolation N/A
SPECIFICATIONS
Abbreviations: CW – Clockwise TRWA – Turbocharged with Raw Water Aftercooling N/A - Not Available L – Length W – Width H - Height
*Rotation viewed from Heat Exchanger / Front of engine
FM
®
FM-UL-cUL APPROVED RATINGS BHP/KW
CERTIFIED POWER RATING
• Each engine is factory tested to verify power and performance.
• FM-UL power ratings are shown at specific speeds, Clarke engines can be
applied at a single rated RPM setting ± 50 RPM.
Picture represents JU6H-TRWA Power Tech Plus Engine Series
USA EPA (NSPS) Tier 3 Emissions Certified Off-Road (40 CFR Part 89) and NSPS Stationary (40 CFR Part 60 Sub Part llll). Meet EU Stage IIIA emission levels.
All Models available for Export
ENGINE RATINGS BASELINES
• Engines are to be used for stationary emergency standby fire pump service only. Engines
are to be tested in accordance with NFPA 25.
• Engines are rated at standard SAE conditions of 29.61 in. (752.1 mm) Hg barometer and
77°F (25°C) inlet air temperature [approximates 300 ft. (91.4 m) above sea level] by the
testing laboratory (see SAE Standard J 1349).
• A deduction of 3 percent from engine horsepower rating at standard SAE conditions shall
be made for diesel engines for each 1000 ft. (305 m) altitude above 300 ft. (91.4 m)
• A deduction of 1 percent from engine horsepower rating as corrected to standard SAE
conditions shall be made for diesel engines for every 10°F (5.6°C) above 77°F (25°C)
ambient temperature.PES Doc.# 9927172256-ENG rev 00
ENGINE EQUIPMENT
EQUIPMENT STANDARD OPTIONAL
Air Cleaner Direct Mounted, Washable, Indoor Service with Drip Shield Disposable, Drip Proof, Indoor Service Outdoor Type, Single or
Two Stage (Cyclonic)
Alarms Overspeed Alarm & Shutdown, Low Oil Pressure, Low & High
Coolant Temperature, Low Raw Water Flow, High Raw Water
Temperature, Alternate ECM Warning, Fuel Injection Malfunction,
ECM Warning and Failure with Automatic Switching
Low Coolant Level, Low Oil Level, Oil Filter Differential Pressure,
Fuel Filter Differential Pressure, Air Filter Restriction
Alternator 12V-DC, 42 Amps with Poly-Vee Belt and Guard 24V-DC, 40 Amps with Poly-Vee Belt and Guard
Coupling Bare Flywheel UL Listed Driveshaft and Guard, JU6H-
UFAD58/NG/ADMG/ADM8/K0/N0/Q0/R0-CDS30-S1; JU6H-
UFADP8/P0/T0/88/R8/S8/S0/W8/X8/98- CDS50-SC at 1760/2100
RPM only
Electronic Control Module 12V-DC, Energized to Stop, Primary ECM always Powered on 24V-DC, Energized to Stop, Primary ECM always Powered on
Engine Heater 115V-AC, 1360 Watt 230V-AC, 1360 Watt
Exhaust Flex Connection SS Flex, 150# ANSI Flanged Connection, 5” for JU6H-
UFAD58/MG/NG/N0/P8/88;
SS Flex, 150# ANSI Flanged Connection, 6” for JU6H-
UFADP0/Q0/R0/S0/T0/R8/S8/W8/X8/98 (w/ orifice plate)
SS Flex, 150# ANSI Flanged Connection, 6” for JU6H-
UFAD58/MG/NG/N0/P8/88;
SS Flex, 150# ANSI Flanged Connection, 8” for JU6H-
UFADP0/Q0/R0/S0/T0/R8/S8/W8/X8/98 (w/ orifice plate)
Exhaust Protection Metal Guards on Manifolds and Turbocharger
Flywheel Housing SAE #3
Flywheel Power Take Off 11.5” SAE Industrial Flywheel Connection
Fuel Connections Fire Resistant, Flexible, USA Coast Guard Approved, Supply and
Return Lines
SS, Braided, cUL Listed, Supply and Return Lines
Fuel Filter Primary Filter with Priming Pump
Fuel Injection System High Pressure Common Rail
Governor, Speed Dual Electronic Control Modules
Heat Exchanger Tube and Shell Type, 60 PSI (4 BAR), NPT(F) Connections – Sea
Water Compatible
Instrument Panel Multimeter to Display English and Metric, Tachometer, Hourmeter,
Water Temperature, Oil Pressure and One (1) Voltmeter with
Toggle Switch, Front Opening
Junction Box Integral with Instrument Panel; For DC Wiring Interconnection to
Engine Controller
Lube Oil Cooler Engine Water Cooled, Plate Type
Lube Oil Filter Full Flow with By-Pass Valve
Lube Oil Pump Gear Driven, Gear Type
Manual Start Control On Instrument Panel with Control Position Warning Light
Overspeed Control Electronic, Factory Set, Not Field Adjustable
Raw Water Cooling Loop
w/Alarms
Galvanized Seawater, All 316SS, High Pressure
Raw Water Cooling Loop
Solenoid Operation
Automatic from Fire Pump Controller and from Engine Instrument
Panel (for Horizontal Fire Pump Applications)
Not Supplied (for Vertical Turbine Fire Pump Applications)
Run – Stop Control On Instrument Panel with Control Position Warning Light
Starters Two (2) 12V-DC Two (2) 24V-DC
Throttle Control Adjustable Speed Control by Increase/Decrease Button, Tamper
Proof in Instrument Panel
Water Pump Centrifugal Type, Poly-Vee Belt Drive with Guard
C133421 revR
19JUN15
Specifications and information contained in this brochure subject to change without notice.
FIRE PUMP ENGINES
Fire Protection Products, Inc.
100 Progress Place, Cincinnati, Ohio 45246
United States of America
Tel [phone]-FIRE(3473) Fax [phone]
www.clarkefire.com
UK, Ltd.
Grange Works, Lomond Rd., Coatbridge, ML5-2NN
United Kingdom
Tel [phone] Fax [phone]
www.clarkefire.com
®
®
Abbreviations: DC – Direct Current, AC – Alternating Current, SAE – Society of Automotive Engineers, NPT(F) – National
Pipe Tapered Thread (Female), ANSI – American National Standards Institute, SS – Stainless Steel
MODELS
JU6H-UFADMG JU6H-UFADP0 JU6H-UFADR0 JU6H-UFADT0
JU6H-UFAD58 JU6H-UFADP8 JU6H-UFADR8 JU6H-UFADW8
JU6H-UFADNG JU6H-UFADQ0 JU6H-UFADS8 JU6H-UFADX8
JU6H-UFADN0 JU6H-UFAD88 JU6H-UFADS0 JU6H-UFAD98
JU6H - UFADR0
John Deere Base Engine
350 Series
6 Cylinders
Heat Exchanger Cooled
Power Curve Number
EPA Tier 3 Certified
Built in USA
FM Approved
UL Listed
MODEL NOMENCLATURE: (10 Digit Models)
ENGINE PERFOR MANCE:
STA NDA R D CO NDI T I ONS: (SA E J1349, ISO 3046)
77°F (25°C ) A I R I NLET TEMPER A TURE
29.61 I N. (751.1MM) HG B A RO MET R IC P RESSURE
#2 DIESEL FUEL (SEE C 13940)
Ke vin Ku nkle r 1 7MAY0 8
NAME PLATE BHP (MAXIMU M PUMP L OAD)
THIS DRAWING AND THE INFORMATION
HEREIN ARE OUR PROPERTY AND MAY
BE USED BY OTHERS ONLY AS
AUTHORIZED BY US. UNPUBLISHED --
ALL RIGHTS RESERVED UNDER THE
COPYRIGHT LAWS.
C RE A T E D DA T E C RE A T E D
05 /1 7/0 8
ENGINE MODEL JU6H-UFAD98
DRA WI N G N O .
C 13 2 61 8
RE V
A
FIR E P U M P M O D E L : J U 6H-U FAD 98
H e a t E x cha ng e r C o o le d
R a w W a te r C ha r ge C o o ling
T ie r 3 E missio ns C e rtif ie d
B
ra
ke

H
o
rs
e
p
o
w
e
r
-
B
H
P

(kw
)
ENGINE SPE ED - RPM
REST R ICT ED:
Us e on ly for Stan d-By Fire Pum p Applications

J U6H -UF AD9 8
IN STALLATIO N & O PERATIO N DATA (I&O)
U SA Pro d uced
Ba s ic E ng ine De s cr iptio n
Engine Manufa cture r ......................................................................................................................................................Jo hn D e er e C o .
I gnition Ty pe ......................................................................................................................................................C om pre ss io n (D iese l)
Numbe r o f C y linde rs ......................................................................................................................................................6
B o re and S tro ke - in (mm ) ......................................................................................................................................................4.19 (106) X 5 (127)
D ispla cem e nt - in³ (L) ......................................................................................................................................................415 (6.8)
C om pr essio n Ratio ......................................................................................................................................................17.0:1
V a lv e s pe r cy linde r
Intake ......................................................................................................................................................2
Ex haust ......................................................................................................................................................2
C om bustio n S yste m ......................................................................................................................................................D ir ect Inje ction
Engine Ty pe ......................................................................................................................................................I n-Line , 4 S trok e C y cle
Fue l Manage ment C ontro l ......................................................................................................................................................Ele ctro nic, High P r essure C o mm o n Rail
Firing O rde r (C W R otatio n) ......................................................................................................................................................1-5-3-6-2-4
A spiration ......................................................................................................................................................Turbochar ged
C ha rge A ir C ooling Ty pe ......................................................................................................................................................R a w W a te r
R o tation, v iewe d from front of engine , C lock wise (C W) ......................................................................................................................................................S tandard
Engine C r a nkca se V e nt System ......................................................................................................................................................Ope n
I nstalla tio n D ra wing ......................................................................................................................................................D 628
We ight - lb (k g) ......................................................................................................................................................1747 (792)
Po we r Ra ting 1760
Na me plate Powe r - HP (k W ) ¹ ......................................................................................................................................................315 (235)
Co o ling Sy s te m - [C05138 6]1760
Engine C oola nt He a t - B tu/sec (kW) ......................................................................................................................................................101.5 (107)
Engine Radiate d Heat - B tu/se c (k W) ......................................................................................................................................................21.2 (22.4)
He a t Ex cha nge r Minim um Flo w
60°F (15°C ) Raw H2O - ga l/m in (L/m in) ......................................................................................................................................................28 (106)
100°F (37°C ) Raw H2O - ga l/m in (L/m in) ......................................................................................................................................................38 (144)
He a t Ex cha nge r Ma x im um C ooling R aw Wate r
Inle t Pres sure - psi (ba r ) ......................................................................................................................................................60 (4.1)
Flow - gal/min (L/min) ......................................................................................................................................................40 (151)
Typica l Engine H2O O perating T em p - °F (°C ) ......................................................................................................................................................180 (82.2) - 195 (90.6)
Therm o sta t
S ta rt to O pe n - °F (°C ) ......................................................................................................................................................180 (82.2)
Fully O pe ne d - °F (°C ) ......................................................................................................................................................203 (95)
Engine C oola nt C apac ity - qt (L) ......................................................................................................................................................21.6 (20.4)
C oolant Pressure C ap - lb/in² (k P a ) ......................................................................................................................................................15 (103)
Max im um Engine C oo la nt Te mperature - °F (°C ) ......................................................................................................................................................230 (110)
Minim um Engine C oolant Tem pe ra ture - °F (°C ) ......................................................................................................................................................160 (71.1)
High C oolant Te m p A la rm S witch - °F (°C ) ......................................................................................................................................................235 (113) - 241 (116)
Ele c tr ic Sy ste m - DC Sta nd a r d Optiona l
S y ste m V olta ge (No minal) ......................................................................................................................................................12 24
B a tte ry C apa city for Am bie nts A bo v e 32°F (0°C )
V olta ge (No minal) ......................................................................................................................................................12 {C 07633}12 {C 07633}
Q ty . Per Battery Bank ......................................................................................................................................................1 2
S AE s ize pe r J537 ......................................................................................................................................................8D 8D
C C A @ 0°F (-18°C ) per J537 ......................................................................................................................................................1400 1400
Re s er ve C a pacity - Minutes per J537 ......................................................................................................................................................430 430
B a tte ry C able C ircuit, Max R e sista nce - ohm ......................................................................................................................................................0.0012 0.0012
B a tte ry C able Minimum S ize
0-120 in. C ircuit Le ngth ² ......................................................................................................................................................00 00
121-160 in. C ircuit Le ngth ² ......................................................................................................................................................000 000
161-200 in. C ircuit Le ngth ² ......................................................................................................................................................0000 0000
C ha rging A lte rna tor Ma ximum O utput - A mp, ......................................................................................................................................................40 {C 071363}55 {C 071365}
S tarte r C rank ing A m ps, R o lling - @60°F (15°C ) ......................................................................................................................................................440 {R E69704/RE70404}250 {C 07819/C 07820}
* A ll fo otnotes a r e at the bottom o f P a ge 2
Page 1 of 2
C 132911 Rev L
D S P 15MA Y19
J U6H -UF AD9 8
IN STALLATIO N & O PERATIO N DATA (I&O)
U SA Pro d uced
Ex ha ust S y s te m (S in g le E x ha us t Outle t)1760
Exhaust Flow - ft.³/m in (m ³/m in) ......................................................................................................................................................1400 (39.6)
Exhaust Te m pe ra ture - °F (°C ) ......................................................................................................................................................961 (516)
Max im um A llo wable B ac k Pre ssure - in H2O (k P a ) ......................................................................................................................................................30 (7.5)
Minim um Ex ha ust Pipe D ia . - in (mm ) ³ ......................................................................................................................................................6 (152)
F ue l S y s te m 1760
Fue l C ons um ptio n - ga l/hr (L/hr) ......................................................................................................................................................15 (56.8)
Fue l R e turn - ga l/hr (L/hr) ......................................................................................................................................................21.3 (80.6)
Fue l S upply - ga l/hr (L/hr) ......................................................................................................................................................36.3 (137)
Fue l P r essure - lb/in² (k Pa ) ......................................................................................................................................................3 (20.7) - 6 (41.4)
Minim um Line S ize - S upply - in. .......................................................................................................................................................50 S chedule 40 S te e l P ipe
P ipe Oute r D iam e ter - in (m m ) ......................................................................................................................................................0.848 (21.5)
Minim um Line S ize - Re tur n - in. .......................................................................................................................................................375 S che dule 40 Ste e l P ipe
P ipe Oute r D iam e ter - in (m m ) ......................................................................................................................................................0.675 (17.1)
Max im um A llo wable Fuel P ump S uction Lift
with c le a n Filte r - in H2O (mH2O) ......................................................................................................................................................80 (2)
Max im um A llo wable Fuel Head a bove Fue l pump, S upply or Return - ft (m ) ......................................................................................................................................................6.6 (2)
Fuel Filte r Micro n S ize ......................................................................................................................................................2 (Seco ndar y)
He a te r Sy ste m Sta nd a r d Optiona l
Engine C oola nt He a ter
Watta ge (Nom ina l) ......................................................................................................................................................1360 1360
V olta ge - AC , 1 P ha se ......................................................................................................................................................115 (+5% -10%)230 (+5%, -10%)
P a rt Num be r ......................................................................................................................................................{C 123640}{C 123644}
A ir Sy s te m 1760
C om bustio n A ir Flow - ft.³/min (m ³/m in) ......................................................................................................................................................547 (15.5)
A ir C le aner ......................................................................................................................................................Sta nd a r d Optiona l
P a rt Num be r ......................................................................................................................................................{C 03244}{C 03327}
Ty pe ......................................................................................................................................................I ndoor S e rv ice Only ,C anister,
with Shield S ingle -S ta ge
C le a ning m e thod ......................................................................................................................................................Wa sha ble D ispo sable
A ir Intak e Re strictio n Ma x im um Lim it
D irty Air C leane r - in H2O (k P a ) ......................................................................................................................................................14 (3.5)14 (3.5)
C le a n A ir C leane r - in H2O (k P a ) ......................................................................................................................................................7 (1.7)5 (1.2)
Max im um A llo wable Te mpe ra tur e (A ir To Engine Inlet) - °F (°C ) ......................................................................................................................................................130 (54.4)
Lub r ic a tio n Sy ste m
Oil Pressure - norm a l - lb/in² (k P a ) ......................................................................................................................................................40 (276) - 60 (414)
Low O il Pre ssure A la rm Switc h - lb/in² (kPa) to ......................................................................................................................................................30 (207) - 35 (241)
I n Pa n Oil Te m per ature - °F (°C ) ......................................................................................................................................................220 (104) - 245 (118)
Tota l Oil C apa city with Filte r - qt (L) ......................................................................................................................................................31.7 (30)
Lub e Oil He a te r Op tio na l Optiona l
Wa ttage (Nominal) ......................................................................................................................................................150 150
V o ltage ......................................................................................................................................................120V (+5%, -10%)240V (+5%, -10%)
Part Number ......................................................................................................................................................{C 04430}{C 04431}
Pe r fo r m a nce 1760
B MEP - lb/in² (k Pa ) ......................................................................................................................................................342 (2360)
Pisto n Speed - ft/min (m /min) ......................................................................................................................................................1467 (447)
Me c hanica l Noise - dB (A ) @ 1m ......................................................................................................................................................C 133381
Powe r C urv e ......................................................................................................................................................C 132618
NOTE: T his e ngine is intende d for indo o r insta lla tio n or in a we a therproof enc lo sure . ¹ Derate 3% pe r ev e ry 1000 ft. 304.8m a bo v e 300 ft. 91.4m a nd de ra te 1%
fo r ev e ry 10°F 5.55 °C abov e 77°F 25°C . ² Positiv e and Ne ga tive Cables C o mbine d Le ngth. ³ Minim um Ex ha ust Pipe Diam e ter is base d on: 15 fe e t o f pipe , one
90° e lbo w, and one Indus trial silenc er . A B a ck-pressure flo w a na ly sis mus t be perfo rmed o n the actual fie ld insta lled e x haust s yste m to a ssure engine max im um
allowable ba ck pr essure is not ex ce eded. See Ex haust Sizing C a lculator o n www.cla r k efire.com . { } indica te s com ponent refe re nce pa rt numbe r.
Page 2 of 2
C 132911 Rev L
D S P 15MA Y19
Air Cleaner Cylinder Head
Type…………..………….. .. Indoor Usage Only Type…….. …………………Slab 2 Valve
Oiled Fabric Pleats Material…………………….Annealed Gray Iron
Material……..…..…….………Surgical Cotton
Aluminum Mesh Cylinder Liners
Type…….. …………………Centrifugal Cast, Wet Liner
Air Cleaner - Optional Material………………..….…Alloy Iron Plateau, Honed
Type………………………….Canister
Material………………………Pleated Paper Fuel Pump
Housing………………..…… Enclosed Type…………………………Diaphragm
Drive…………………………Cam Lobe
Camshaft
Material………….…………..Cast Iron Heat Exchanger (USA) - JU4H & JU6H Only
Chill Hardened Type…………………………Tube & Shell
Location…………...….……. In Block Materials
Drive……………….………..…Gear, Spur Tube & Headers……………Copper
Type of Cam…………..…....Ground Shell…………………………Copper
Electrode……………………Zinc
Type……….. ..…………….Raw Water Cooled Heat Exchanger (UK) - JU4H & JU6H Only
Materials (in contact with raw water)Type…………………………Tube & Bundle
Tubes……………………………90/10 CU/NI
Headers ……………………36500 Muntz Materials
Covers ……………………83600 Red Brass Tube & Headers……………Copper
Plumbing ……………………316 Stainless Steel/ Brass Shell………..……………. Aluminum
90/10 Silicone
Injection Pump
Type……………………….. Rotary
Drive…………………………Gear
Type…...……………………Air to Air Cooled
Materials Lubrication Cooler
Core…………………………Aluminum Type…………………………Plate
Coolant Pump Lubrication Pump
Type……….…………………Centrifugal Type…………………………Gear
Drive……………………………Poly Vee Belt Drive…………………………Gear
Coolant Thermostat Main Bearings
Type……………………………Non Blocking Type…………………………Precision Half Shells
Qty……………………………1 Material………………………Steel Backed-Aluminum
Lined
Cooling Loop (Galvanized)
Tees, Elbows, Pipe…………Galvanized Steel Piston
Ball Valves……………………Brass ASTM B 124, Type and Material…………Aluminum Alloy with
Solenoid Valve………………Brass Reinforced Top Ring Groove
Pressure Regulator…………Bronze Cooling………………………Oil Jet Spray
Strainer………………………Cast Iron (1/2" - 1" loops) or
Bronze (1.25" - 2" loops)Piston Pin
Type…………………………Full Floating - Offset
Cooling Loop (Sea Water)Piston Rings
Tees, Elbows, Pipe…………316 Stainless Steel Number/Piston…………… 3
Ball Valves……………………316 Stainless Steel Top………………………… Keystone Barrel Faced -
Solenoid Valve………………316 Stainless Steel Plasma Coated
Pressure Regulator/StrainerCast Brass ASTM B176 Second………………………Tapered Cast Iron
C87800 Third…………………………Double Rail Type
w/Expander Spring
Cooling Loop (316SS)
Tees, Elbows, Pipe…………316 Stainless Steel Radiator - JU4R & JU6R Only
Ball Valves……………………316 Stainless Steel Type……………………… Plate Fin
Solenoid Valve………………316 Stainless Steel Materials
Pressure Regulator/Strainer316 Stainless Steel Core……………………… Copper & Brass
Tank & Structure……….. Steel
Connecting Rod
Type……………………………I-Beam Taper Optional
Material………………………Forged Steel Alloy Marine Coating……………Baked Phenolic
Crank Pin Bearings Valves
Type……………………………Precision Half Shell Type…….. …………………Poppet
Number………………………1 Pair Per Cylinder Arrangement………… ……Overhead Valve
Material………………………Wear-Guard Number/Cylinder……………1 intake
1 exhaust
Crankshaft Operating Mechanism……Mechanical Rocker Arm
Material………………………Forged Steel Type of Lifter…………….. Large Head
Type of Balance…………… Dynamic Valve Seat Insert……………Replaceable
Cylinder Block
Type……………………………One Piece with
Non-Siamese Cylinders
Material………………………Annealed Gray Iron
Charge Air Cooler (JU6R-AA67, 59, 61, PF, Q7, RF,
S9, 83 only)
JU4H, JU4R & JU6H, JU6R ENGINE MODELS
ENGINE MATERIALS AND CONSTRUCTION
Charge Air Cooler (JU6H-60,62,68,74,84, 94, T8, T0,
T2, ADK0, AD58, ADNG, ADN0, ADQ0, ADR0, AAQ8,
AARG, ADP8, ADP0, ADT0, AD88, ADR8, AD98,
ADS0, ADW8, ADX8, AD98 only)
C13615 14NOV18

Rating Specific Emissions Data

Nameplate Rating Information

Clarke Model JU6H-UFAD98
Power Rating (BHP/kW) 315/235
Certified Speed (RPM) 1760

Refer to Rating Data section on page 2 for emissions output values

Rating Specific Emissions Data - John Deere Power Systems
Rating Data
Rating 6068HFC48A
Certified Power(kW)235
Rated Speed 1760
Vehicle Model Number OEM (Clarke Fire Pump-
Emergency)
Units g/kW-hr g/hp-hr
NOx 3.61 2.69
HC 0.08 0.06
NOx + HC N/A N/A
Pm 0.07 0.06
CO 0.6 0.4
Certificate Data
Engine Model Year 2019
EPA Family Name KJDXL13.5103
EPA JD Name 650HAA
EPA Certificate Number KJDXL13.5103-007
CARB Executive Order
Parent of Family 6135HF485A
Units g/kW-hr
NOx 3.31
HC 0.11
NOx + HC N/A
Pm 0.10
CO 0.6
* The emission data listed is measured from a laboratory test engine according to the test
procedures of 40 CFR 89 or 40 CFR 1039, as applicable. The test engine is intended to represent
nominal production hardware, and we do not guarantee that every production engine will have
identical test results. The family parent data represents multiple ratings and this data may have
been collected at a different engine speed and load. Emission results may vary due to engine
manufacturing tolerances, engine operating conditions, fuels used, or other conditions beyond
our control.
This information is property of Deere & Company. It is provided solely for the purpose of
obtaining certification or permits of Deere powered equipment. Unauthorized distribution of this
information is prohibited.
Emissions Results by Rating run on Feb-18-2019
Octave Band
Octave Band
JU6H-UFAD98
FIRE PUMP DRIVER
NOISE DATA
Mechanical Engine Noise *
RPM BHP OVERALL
dB(A)
31.5 Hz
dB(A)
63 Hz
dB(A)
125 Hz
dB(A)
250 Hz
dB(A)
500 Hz
dB(A)
1k Hz
dB(A)
2k Hz
dB(A)
4k Hz
dB(A)
8k Hz
dB(A)
16k Hz
dB(A)
1760 315 109.20 67.00 69.20 82.60 89.20 97.10 99.70 104.90 103.40 101.70 101.70
Raw Exhaust Engine Noise **
RPM BHP OVERALL
dB(A)
31.5 Hz
dB(A)
63 Hz
dB(A)
125 Hz
dB(A)
250 Hz
dB(A)
500 Hz
dB(A)
1k Hz
dB(A)
2k Hz
dB(A)
4k Hz
dB(A)
8k Hz
dB(A)
16k Hz
dB(A)
1760 315 113.00 0.00 102.70 107.10 101.80 104.00 103.60 106.30 103.50 93.20 86.80
* Values above are provided at 3.3ft (1m) from engine block and do not include the raw exhaust noise.
** Values above are provided at 23ft (7m), 90° horizontal, from a vertical exhaust outlet and does not include noise created mechanically by the engine.
The above data reflects nominal values for a typical engine of this model, speed and power in a free-field environment, tested at a no-load condition.
Installation specifics such as background noise level and amplification of noise levels from reflecting off of surrounding objects, will affect the overall noise
levels observed. As a result of this, Clarke makes no guarantees to the above levels in an actual installation.
C133381 Rev E 23Jan18 DSP

CORPORATE FUGITIVE EMISSIONS MONITORING PLAN

Dominion Energy Services, Inc.
120 Tredegar Street
Richmond, VA 23059

Revision 0 (November 2022)
Corporate Fugitive Emissions Monitoring Plan i
TABLE OF CONTENTS
1 INTRODUCTION ........................................................................................................... 1
2 IDENTIFICATION OF AFFECTED COMPONENTS & FREQUENCY OF
MONITORING ................................................................................................................ 2
2.1 IDENTIFICATION OF AFFECTED COMPONENTS......................................... 2
2.2 FREQUENCY OF MONITORING ....................................................................... 2
3 FUGITIVE EMISSION MONITORING METHODS .................................................... 3
3.1 OPTICAL GAS IMAGING CAMERA ................................................................. 3
3.1.1 OGIC Instrument Specifications .............................................................. 3
3.1.2 OGIC Monitoring Procedures .................................................................. 3
3.1.3 OGIC Daily Verification Check .............................................................. 4
3.1.4 OGIC Use in Adverse Conditions ........................................................... 6
3.1.5 Thermal Background ............................................................................... 7
3.1.6 Handling Interferences ............................................................................. 7
3.1.7 OGIC Operator Training and Experience ................................................ 7
3.1.8 OGIC Calibration and Maintenance ........................................................ 8
3.2 METHOD 21 (RESURVEY ONLY) ..................................................................... 8
3.2.1 Method 21 Instrument Specifications (Gas Analyzer) ............................. 8
3.2.2 Method 21 Instrument Monitoring Procedure ......................................... 8
3.2.3 Method 21 Instrument Performance Evaluation ...................................... 9
3.2.4 Method 21 Instrument Calibration ........................................................... 9
3.2.5 Method 21 Soap Bubble Test (Alternate to Method 21 Instrument Test)
(Re-Survey Only) ................................................................................... 10
4 DIFFICULT-TO-MONITOR (DTM) AND UNSAFE-TO-MONITOR (UTM)
LOCATIONS ................................................................................................................. 11
4.1 DIFFICULT-TO-MONITOR ............................................................................... 11
4.2 UNSAFE-TO-MONITOR .................................................................................... 11
5 FUGITIVE EMISSIONS IDENTIFICATION, REPAIR AND RESURVEY .............. 12
5.1 FUGITIVE EMISSION IDENTIFICATION ....................................................... 12
5.2 FUGITIVE EMISSION REPAIR ........................................................................ 12
5.3 RESURVEY ......................................................................................................... 12
5.4 DELAY OF REPAIR ........................................................................................... 12
6 RECORDKEEPING ...................................................................................................... 13

TABLE OF CONTENTS (Continued)
Dominion Corporate FEM Plan ii Rev. 5
APPENDICES

Appendix A: Site-Specific FEM Plans
Appendix B: NSPS OOOOa Compliance Verification
Appendix C: Method 21 Compliance Verification
Appendix E: FEM Plan Revision Log

Dominion Corporate FEM Plan 1 Rev. 5
1 INTRODUCTION
Dominion Energy (Dominion), through its various subsidiaries, owns and operates interstate
natural gas transmission and storage systems across the United States, including liquified
natural gas (LNG) stations. The Dominion LNG stations covered by this corporate fugitive
emissions monitoring plan (Plan) are subject to fugitive emissions monitoring (FEM)
requirements pursuant to state and/or federal 1 air quality regulations.
This Plan addresses the FEM requirements applicable to all Dominion LNG stations subject to
FEM. Site-specific FEM requirements are provided in the site-specific FEM plans included in
Appendix A. If there is a discrepancy between the requirements in this corporate FEM plan and
those in the site-specific FEM plan, requirements in the site-specific plan will take precedence.

1 The only federal air quality FEM regulation applicable to the facilities covered hereunder is 40 CFR Part 60, Subpart OOOOa:
Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification, or Reconstruction
Commenced After September 18, 2015.

Dominion Corporate FEM Plan 2 Rev. 5
2 IDENTIFICATION OF AFFECTED COMPONENTS & FREQUENCY OF MONITORING
2.1 IDENTIFICATION OF AFFECTED COMPONENTS
This Plan applies to the fugitive emission components (FECs) at LNG stations that are within
the fence line of the facility. A FEC is defined as follows:
Any component that has the potential to emit fugitive emissions of methane or VOC,
including but not limited to valves, connectors, pressure relief devices, open-ended
lines, flanges, covers, closed vent systems, thief hatches or other openings on storage
vessels, compressors, instruments, and meters. Devices that vent as part of normal
operations are not considered FECs.2

Open-ended lines associated with safety systems, such as site blowdown vents, are not
sources of fugitive emissions but are vents, and therefore are not subject to the regulatory FEM
requirements of this Plan.3 Additionally, emissions from devices that are intended to vent as a
part of normal operation are not subject to regulatory FEM requirements if they: 1) exit through a
vent and 2) occur as a result of normal operation. Such emissions include, but are not limited to:
• Emissions from vents on non-pressurized (atmospheric) storage vessels.
• Emissions from pneumatic device vents. Emissions from components associated with a
pneumatic device that are not intended to vent during normal operation would be
considered FECs and subject to regulatory FEM requirements.
• Emissions from pressure relief devices during a pressure release. Emissions from a
pressure relief device that has not been activated are subject to regulatory FEM
requirements.4
2.2 FREQUENCY OF MONITORING
The monitoring frequency varies depending on the applicable regulatory requirements.
Facilities subject to NSPS OOOOa are required to conduct initial monitoring within 60 days of
startup of a new or modified LNG station or by June 3, 2017, whichever is later
(§60.5397a(f)(2)). Subsequent monitoring must be performed on a quarterly basis, with
consecutive quarterly monitoring surveys conducted at least 60 days apart (§60.5397a(g)(2)).
Monitoring required pursuant to state regulations will follow the frequency defined in the state-
specific regulation. The monitoring frequencies for each facility are outlined in the site-specific
FEM plans in Appendix A.

2 FEC definition from 40 CFR §60.5430a.
3 The EPA did not intend for such vents to be subject to the FEM requirements of NSPS OOOOa as summarized at 81 FR 35861..
4 EPA’s position on when emissions from a pressure relief device are subject to FEM requirements under NSPS OOOOa is clarified
on Page 4-214 in Chapter 4 of the NSPS OOOOa Response to Comment document.

Dominion Corporate FEM Plan 3 Rev. 5
3 FUGITIVE EMISSION MONITORING METHODS
FEM will be performed using an optical gas imaging camera (OGIC) to identify sources of
fugitive emissions within each facility. Sources of fugitive emissions identified during a FEM
survey will be resurveyed to verify the success of repairs using either an OGIC or the Method 21
soap bubble test (Snoop Method) pursuant to Section 5.3 of this FEM Plan. Procedures to be
followed for FEM surveys and re-surveys are discussed below. Records of each FEM survey
and re-survey will be maintained in accordance with Section 6 of this Plan.

3.1 OPTICAL GAS IMAGING CAMERA
The OGIC will comply with the following minimum specifications as required in
§60.5397a.(c)(7)(i)(A) and (B):
• The OGIC will be capable of imaging gases in the spectral range for the compound of
highest concentration in the potential fugitive emissions. Methane is the compound of
highest concentration in natural gas.
• The OGIC will be capable of imaging a gas that is half methane and half propane at a
concentration of 10,000 ppmv or 1 percent, and a flow rate of ≤ 60 grams per hour (g/hr)
from a quarter inch diameter orifice.
Dominion will utilize an OGIC that is compliant with the aforementioned specifications. In
accordance with §60.5397a.(c)(3), the specific manufacturer(s) and model number(s) of the
OGIC instrument(s) and the required information verifying that the OGIC(s) is(are) compliant
with the specifications is provided in Appendix B.

FEM surveys will be performed by appropriately trained personnel in accordance with the
procedures summarized below.
• On a daily basis, prior to beginning each OGIC FEM survey, monitoring personnel will
complete an OGIC daily verification check in accordance with Section 3.1.3 of this Plan.

• The FEM survey will follow the defined observation path. Figures illustrating the defined
observation path at each LNG station, as appropriate, are contained within the site-
specific FEM plans (Appendix A).

• FECs subject to FEM will be surveyed with the OGIC. FECs that are considered difficult
to monitor or unsafe to monitor will be surveyed as described in Section 4.

• The distance between the OGIC and the FECs being surveyed shall not exceed the
maximum distance (D Max ) established during the OGIC daily verification check. The
operator will establish an optimized D Max during the survey taking into account the
following variables:
o Weather conditions
o Thermal background

Dominion Corporate FEM Plan 4 Rev. 5
o Viewing angle of components along observation path
o Distance between component and observation path
Throughout the FEM survey, monitoring personnel will reassess the distance between
the OGIC and the FECs being surveyed to maintain compliance with D Max , based on the
variables listed above, as necessary. Monitoring personnel may perform an additional
OGIC daily verification check to establish a new D Max , as needed.
• A FEC is considered a source of fugitive emissions (i.e., is leaking) if visible emissions
are observed coming from the FEC using the OGIC. Such FECs identified during the
FEM survey are subject to the repair provisions discussed in Section 5.2 of this Plan.

• Monitoring personnel will qualitatively assess monitoring conditions throughout the FEM
survey and will follow the procedures identified in Section 3.1.4 of this Plan if adverse
monitoring conditions are encountered.

• The procedures identified in Section 3.1.5 of this Plan will be followed to ensure that
adequate thermal background exists when viewing each FEC with the OGIC.

• The procedures identified in Section 3.1.6 of this Plan will be followed if interferences are
encountered during the FEM survey.

• Monitoring personnel will meet the qualification and experience criteria outlined in
Section 3.1.7 of this Plan.

• The OGIC will be operated, maintained, and calibrated as outlined in Section 3.1 of this
Plan.

An OGIC daily performance check will be performed prior to OGIC FEM surveys, and at other
times as needed, in accordance with the following procedure.
1) Start the OGIC according to the manufacturer's instructions, ensuring that all
appropriate settings conform to the manufacturer's requirements.
2) After the OGIC start-up process is completed and the OGIC is set to the intended
settings, look at the viewfinder to ensure that the image is clear. If the image is
unclear or grainy, perform a lens assessment and follow proper lens cleaning
procedure, if necessary.
3) Prior to beginning the FEM survey, test the OGIC as follows:
a. Record ambient temperature as measured from an onsite temperature
gauge (e.g. thermometer) or local weather station.
b. Record wind speed from a local weather station. Alternatively, wind speed
may be obtained from a hand-held anemometer, if available.

Dominion Corporate FEM Plan 5 Rev. 5
c. Install a regulator on a 100 percent (+/- 2%) methane gas cylinder (verify
that the cylinder contains gas). The regulator shall be capable of
producing a flow rate of 0.5 liter/minute (L/min). Place the cylinder in the
area where the OGIC FEM survey will take place or where the same
environmental (wind, rain, etc.) conditions exist. The OGIC daily
verification check will be repeated if wind speed is observed to increase
during the FEM survey to an extent that, based on the discretion of the
monitoring technician, may affect the monitoring results.
d. Open the valve on the regulator to set a flow rate of 0.5 L/min while
observing the gas flow through the OGIC viewfinder. Determine the
maximum distance (D Max ) at which the emission is seen through the
viewfinder for a minimum duration of 10 seconds. Once this distance is
determined, the OGIC daily verification check is complete.5

5 The mass flow rate of methane during the daily instrument check will be approximately 22 g/hr based on the density of methane at
standard temperature and pressure using a pure methane gas cylinder and a 0.5 L/min flow regulator. Standard temperature and
pressure are defined as 68 degrees Fahrenheit (F) and 1 atmosphere (atm), respectively.

Dominion Corporate FEM Plan 6 Rev. 5

3.1.4.1 Wind
Wind speed is recorded during the OGIC daily verification check. If the wind speed within the
survey area(s) has a Beaufort number of five or higher, the survey will be postponed in those
areas until the wind speed has decreased. A wind speed chart is presented in Table 3.
Table 3. Wind Speed Chart
Beaufort
number
Wind
(km/h)
Wind
(mph)
Wind
classification Wind effects on land Wind effects on water
0 <1 <1 Calm Smoke rises vertically Water calm, mirror-like
1 1-5 1-3 Light air
Smoke drift indicates
wind direction; still
wind vanes
Scale-like ripples with no foam
crests
2 6-11 4-7 Light breeze
Leaves rustle; wind
felt on face; wind
vanes moved by wind
Small wavelets; crests have a
glassy appearance and do not
break
3 12-19 8-12 Gentle breeze
Leaves and twigs
constantly moving;
light flags extended
Large wavelets; crests begin to
break, scattered whitecaps
4 20-29 13-18 Moderate
breeze
Dust and loose paper
raised; small branches
move
Small waves 1-4’ becoming longer;
many whitecaps
5 30-38 19-24 Fresh breeze Small trees with
leaves begin to sway
Moderate, longer waves 4-8’;
whitecaps common; some spray
6 39-50 25-31 Strong breeze
Larger tree branches
moving; phone lines
whistle
Larger waves 8-13’; whitecaps
common; more spray
7 51-61 32-38 Near gale
Whole trees moving;
difficult to walk against
wind
Sea heaps up; waves 13-20’;
crests break; white foam streaking
off breakers
8 62-74 39-46 Gale
Twigs break off trees;
difficult to walk against
wind
Moderately high waves, 13-20’,
with greater lengths; crests
beginning to break into foam blown
in white streaks
9 75-86 47-54 Strong gale
Slight damage to
buildings; shingles and
slates torn off roofs
High waves of 20’; rolling seas;
dense streaks of foam; spray may
reduce visibility
10 87-101 55-63 Storm
Trees uprooted;
considerable structural
damage to buildings
Very high waves, 20-30‘, with
overhanging crests; sea white with
blown foam
11 102-
115 64-72 Violent storm Widespread damage
Huge waves, 30-45’, foam patches
cover sea; air filled with spray;
visibility reduced
12 >115 >72 Hurricane Widespread damage
Huge waves, over 45’ air filled with
foam; sea all white with driving
spray; little visibility

Dominion Corporate FEM Plan 7 Rev. 5
3.1.4.2 Rain
The OGIC may be used in light rain if the OGIC daily verification check is performed in the same
rain conditions. If conditions change, monitoring personnel will perform an additional OGIC daily
verification check and then resume the survey.
3.1.4.3 Temperature
Monitoring personnel will record the ambient temperature during the OGIC daily verification
check and will confirm that the temperature is within the acceptable operating range of the
OGIC. In the unlikely event that temperature within the survey area falls outside of the
acceptable operating range of the OGIC, the FEM survey will be postponed until acceptable
operating conditions exist.

The ability to easily identify fugitive emissions using an OGIC decreases as the thermal energy
differential between the fugitive emission and background decreases. If necessary, monitoring
personnel may view a FEC using multiple camera angles and select an angle that provides an
adequate thermal background. During the FEM survey, monitoring personnel will continuously
perform a qualitative analysis of the thermal properties of the background to ensure that
adequate thermal background is present. If monitoring personnel identify an area where
questionable thermal background is present that may reduce the detection capabilities of the
OGIC, one or both of the following procedures will be followed.
1) An additional OGIC verification check will be performed in the area of question to
verify that adequate thermal background is present.
2) A temporary background (e.g., a person or other background) will be inserted
into the scene(s) to create an adequate thermal background when feasible to
increase the thermal energy differential between the fugitive emission and the
background.

Monitoring personnel will be knowledgeable of the process streams typically present at the
types of facilities being surveyed and will be able to identify sources of potential interference,
such as steam. If potential interference is identified, monitoring personnel will utilize alternate
viewing angles to differentiate between the FEC and potential interference source. In addition,
monitoring personnel may utilize a secondary confirmation instrument (e.g., handheld gas
detector or soap bubbles) to confirm the presence of a leak.

FEM surveys will be performed by personnel that are trained in the proper operation of the
OGIC to be used in the FEM survey and that have prior experience using OGICs for the
purposes of identifying fugitive emissions. Additionally, monitoring personnel will be familiar with

Dominion Corporate FEM Plan 8 Rev. 5
the types of equipment located at a LNG station. Monitoring personnel will have reviewed the
site-specific FEM Plan prior to performing FEM surveys.

Calibration and maintenance of the OGIC will be performed in accordance with manufacturer’s
recommendations. Records of calibration and maintenance, as applicable, will be maintained by
the OGIC owner/operator.
3.2 METHOD 21 (RESURVEY ONLY)
Dominion may utilize a Method 21 (gas analyzer) from Appendix A-7 of 40 CFR Part 60 (Method
21) or the alternate re-survey Method 21 soap bubble test (Snoop Method) in lieu of the OGIC
to re-survey FECs for the purposes of verifying that repairs are successful. Re-surveys that
utilize Method 21 or the Snoop Method will be performed in accordance with the procedures set
forth in this section.

Dominion will utilize an instrument that meets the requirements specified in Section 6.0 of
Method 21. The manufacturer and model number of gas detector instrument(s) and the required
verification(s) that the instrument(s) meet the requirements specified in Section 6.0 of Method
21 is(are) provided in Appendix C.
The detection capability of the instrument shall be consistent with that of a flame ionization
detector-based instrument. As such, the fugitive emission definition is 500 ppm and the
development of a site-specific fugitive emission definition is not required.

The use of a Method 21 instrument to re-survey a FEC that has been identified as a source of
fugitive emissions will follow the procedures summarized below.
• Prior to initiating a FEC re-survey event, monitoring personnel will review documentation
of Method 21 instrument performance evaluations to verify compliance with the criteria
(Section 3.2.3).

• Prior to utilizing the Method 21 instrument to re-survey a FEC, monitoring personnel will
calibrate the Method 21 instrument each day the instrument is used in accordance with
Section 3.2.4 of this Plan.

• Prior to initiating a FEC re-survey event, monitoring personnel will start the Method 21
instrument and wait for completion of the manufacturer-recommended start-up
sequence/warm-up period.

• Monitoring personnel will measure and note the background methane concentration
(Cbackground ) in the vicinity of the FEC by moving the Method 21 instrument probe
randomly upwind and downwind at a distance of one to two meters from the FEC. If an
interference exists due to a nearby emission, the ambient concentration may be

Dominion Corporate FEM Plan 9 Rev. 5
measured at a distance closer to the FEC, but in no case will the distance be less than
25 centimeters (cm).

• Monitoring personnel will re-survey the FEC by placing the Method 21 instrument probe
in close proximity to the area from which fugitive emissions were identified and moving
the probe across this area and other potential leak interfaces while observing the
instrument reading. If an increased reading is observed, monitoring personnel will move
the probe slowly around the area in which the increased reading was observed until a
maximum reading is obtained, leaving the probe at the location of the maximum reading
for two times the instrument response time. The maximum observed Method 21
instrument reading (C FEC ) will be noted.

• The FEC is considered repaired if C FEC – C background ≤ 500 ppm.

• The Method 21 instrument will be operated and maintained in accordance with
manufacturer’s recommendations.

If Method 21 instruments are used for re-surveying FECs, Method 21 instrument performance
evaluations will be conducted at the frequency described below in accordance with Section 8.1
of Method 21.
• A response factor test must be performed for methane prior to placing the Method 21
instrument into service to demonstrate that the response factor is less than 10. The test
does not have to be repeated at subsequent intervals. Response factor data from
reference sources for the specific make/model of Method 21 instrument may be used in
lieu of performing the response factor test. Monitoring personnel will maintain
documentation of the most recent acceptable response factor test or reference data with
the Method 21 instrument.
• A calibration precision test must be completed prior to placing the Method 21 instrument
into service, and at subsequent 3-month intervals or at the next use, whichever is later.
The calibration precision must be equal to or less than 10 percent of the calibration gas
value. Monitoring personnel will maintain documentation of the most recent acceptable
calibration precision test with the Method 21 instrument.
• A response time test must be performed prior to placing the Method 21 instrument into
service and anytime a modification is made to the sample pumping system or flow
configuration that would change the response time. The response time must be equal to
or less than 30 seconds. Monitoring personnel will maintain documentation of the most
recent acceptable response time test with the Method 21 instrument.
Method 21 instruments with unacceptable instrument performance evaluation results or
inadequate records will not be utilized.

Dominion Corporate FEM Plan 10 Rev. 5
Method 21 instruments will be calibrated in accordance with the manufacturer’s requirements
and the procedures in Section 10.1 of Method 21. Calibrations will be performed using
calibration gas containing methane at a concentration of 500 ppm. Prior to calibrations,
monitoring personnel will verify that the calibration gas used has not exceeded the certified
expiration date. Records of all calibration events will be maintained and will include: the date,
name of the monitoring personnel performing the calibration, and calibration results. A
calibration log can be used to document that the instrument was calibrated correctly each time
calibration was necessary.

The soap bubble test summarized in Section 8.3.3 of Method 21 may be used for the purposes
of verifying that a component has been repaired. The procedures for conducting a soap bubble
test are summarized below.
• Monitoring personnel will prepare a solution of concentrated detergent and water or
obtain a commercially available leak detection solution.
• Monitoring personnel will spray the soap solution over the FEC and will visually monitor
for the formation of bubbles.
• The FEC is considered repaired when no bubbles are observed.
• If bubbles are observed, an OGIC may be utilized to re-survey the FEC for repair
verification in accordance with Section 3.1 of this Plan. Alternatively, the soap bubble
test may be repeated to verify repair.

The soap bubble test will not be used on FECs, or portions thereof, that have continuously
moving parts, have surface temperatures that will boil or freeze the soap solution, have open
areas to the atmosphere that the soap solution cannot bridge 6, or that exhibit evidence of liquid
leakage.

6 If the size of the opening is too large for the soap solution to bridge, actions may be taken to reduce the size of the opening, e.g.,
tape off the opening and puncture the tape to provide the appropriately sized opening for performance of the soap bubble test.

4 DIFFICULT-TO-MONITOR (DTM) AND UNSAFE-TO-MONITOR (UTM) LOCATIONS
4.1 DIFFICULT-TO-MONITOR
FECs that cannot be monitored without elevating monitoring personnel more than two meters
above a support surface may be designated as DTM. The following information will be recorded
in a log for each FEC designated as DTM:
• The identification and location of the DTM FEC.
• An explanation of why the DTM FEC is difficult to monitor.
FECs designated as DTM will be monitored using the methodologies in Section 3 of this Plan at
a minimum of once per calendar year. Delaying monitoring due to a FEC being designated as
DTM may require regulatory agency notification and/or approval (see site-specific FEM plans in
Appendix A).
4.2 UNSAFE-TO-MONITOR
FECs may be designated as unsafe-to-monitor (UTM) if monitoring such FECs would expose
monitoring personnel to immediate danger while conducting a FEM survey. The following
information shall be recorded in a log for each FEC designated as UTM:
• The identification and location of the UTM FEC.
• An explanation of why the UTM FEC is unsafe-to-monitor.
• A schedule for monitoring the UTM FEC, or justification as to why the FEC is never
safe to be monitored.
FECs designated as UTM will be monitored using the methodologies in Section 3 of this Plan in
accordance with the UTM FEC monitoring schedule contained within the site-specific monitoring
plans. Delaying monitoring due to a FEC being designated as UTM may require regulatory
agency notification and/or approval (see site-specific FEM plans in Appendix A).

5 FUGITIVE EMISSIONS IDENTIFICATION, REPAIR AND RESURVEY
Fugitive emissions identification, repairs, and resurveys shall be performed in accordance with
the procedures outlined in this section. Records will be maintained as required in Section 6 of
this Plan.
5.1 FUGITIVE EMISSION IDENTIFICATION
When a source of fugitive emissions is identified via FEM or AVO inspections, monitoring
personnel will do one or both of the following: (i) equip the FEC with a tag that identifies the FEC
as a source of fugitive emissions; (ii) take a digital photograph of the FEC that includes the date
the photograph was taken and clearly identifies the location of the FEC within the facility (e.g.,
the latitude/longitude of the FEC or by descriptive landmarks visible in the photograph). These
requirements do not apply if the FEC is repaired and resurveyed during the FEM survey in
which the fugitive emissions are identified.
5.2 FUGITIVE EMISSION REPAIR
Monitoring personnel will provide a summary report at the end of each FEM survey that
documents the FECs identified as being sources of fugitive emissions, including those corrected
in the field during the survey. Applicable repair timeframes are delineated in the site-specific
FEM plans included in Appendix A. Procedures for repairs that cannot be completed in
accordance with the applicable repair timeframe are provided in Section 5.4 of this Plan.
5.3 RESURVEY
After the FEC has been repaired it must be resurveyed to verify that the repair was successful.
A FEC is considered repaired when one of the following conditions is met:
• If using an OGIC, the FEC is repaired when the OGIC shows no indication of visible
emissions from the FEC.
• If using a Method 21 instrument, the FEC is repaired if C FEC – C background ≤ 500 ppm.
• If using the Method 21 soap bubble test, the FEC is repaired when no bubbles are
observed.
The repair and resurvey must be completed within the applicable repair timeframe.
5.4 DELAY OF REPAIR
If repair or replacement of a FEC within the required timeframe is technically infeasible, would
require a vent blowdown or a station shutdown, or would be unsafe to repair during operation of
the unit, the FEC may be placed on delay of repair (DoR). The requirements for DoR may vary
by LNG station depending on the applicable FEM regulations. Site-specific provisions for
placing FECs on DoR, including required notifications and repair timeframes, are included in
Appendix A.

6 RECORDKEEPING

The following records will be maintained as a part of the fugitive emissions monitoring program.
• This FEM Plan.
• For each FEM survey7:
o Date of the survey
o Beginning and end time of the survey.
o Name of the operator(s) performing the survey and a note or resume describing
their training and experience.
o A list of the specific monitoring instrument(s) used (Manufacturer and Model
Number).
o Digital photographs or videos from the OGIC of the FEM survey being performed.
The digital file will include the date that the file was created and the
latitude/longitude of the Facility imbedded within the digital file. As an alternative
to imbedded latitude/longitude within the digital file, the digital photograph or
video may consist of an image of the FEM survey being performed with a
separately operating GPS device within the same digital picture or video provided
that the output of the GPS device can be clearly read in the image.
o Ambient temperature, sky conditions, and measured wind speed at the time of
the survey.
o Deviations from the monitoring plan or a statement that there were no deviations
from the monitoring plan.
o Number and type of DTM and UTM FECs monitored.
o Number and type of FECs from which fugitive emissions were detected.
o For FECs identified as sources of fugitive emissions and not repaired during the
FEM survey:
 Number and type of FECs that were tagged as a result of not being
repaired during the FEM survey when the fugitive emissions were
identified.
 If not tagged, a digital photograph or video of each fugitive emission
component. The digital photograph or video must clearly identify the
location of the component that must be repaired.
• For FECs subject to repair:
o Repair methods applied in each attempt to repair the FEC.
o The date of successful repair of the FEC.
o Number and type of FECs placed on DoR.
o A log of the number and type of FECs not repaired in accordance with this Plan.
o Monitoring methodology used to re-survey a repaired FEC that could not be
repaired during the FEM survey in which the fugitive emission was identified.

7 §60.5420a(c)(15)(ii)(A) through (I)

All records will be maintained in hard copy or electronic format onsite for a minimum of five
years.

Appendix A

Site-Specific FEM Plans

(November 2022) Page 1 of 3
SITE-SPECIFIC FUGITIVE EMISSIONS MONITORING PLAN [1]
Facility Name: Magna LNG Station
Physical Address: 1731 South 8000 West, Magna, UT
Latitude: 40.7306°
Longitude: -112.0798°
FEM Regulatory Driver: Utah BACT
Affected FECs: All
Initial FEM deadline: Within 60 days of start of production after completion of commissioning activities
FEM Frequency: Semiannually at least four (4) months apart
Leak (Fugitive Emissions)
Definition:
• Visible emissions from a FEC when using an OGIC.
• Measured concentration of ≥500 ppm (methane) when using a Method 21
instrument.
Repair & Resurvey: Leaking FEC must be repaired and resurveyed within 15 days of leak identification
unless subject to Delay of Repair provisions.
Repair Definition:
A FEC is considered repaired when a resurvey indicates:
• There are no visible emissions when using an OGIC.
• C FEC – C background ≤ 500 ppm when using a Method 21 instrument; or
• No bubbles are observed when using the Method 21 soap bubble test.
Difficult to Monitor (DTM)
FECs:
FECs that are not monitored because they are DTM must be listed on the attached
DTM log. DTM FECs must be monitored at a minimum of once per calendar year.
Unsafe to Monitor (UTM)
FECs:
FECs that are not monitored because they are UTM must be listed on the attached
UTM log. UTM FECs must be monitored in accordance with the schedule listed on
the UTM table.
Delay of Repair (DoR):
• FECs on DoR must be designated as such
• A FEC may not be placed on DoR due to unavailability of parts.
• FECs on DoR must be repaired or replaced upon the earlier of the following:
during the next compressor station shutdown; after an unscheduled, planned, or
emergency vent blowdown; or, within two years after the leak was identified.
Notes:
[1] This Site-Specific Fugitive Emissions Monitoring Plan is a supplement to the Corporate Fugitive Emissions
Monitoring Plan, which is incorporated herein by reference.

(November 2022) Page 2 of 3
Difficult-to-Monitor (DTM) Fugitive Emission Component Log
Magna LNG Station
Component Identification Component Location DTM Justification

(November 2022) Page 3 of 3
Unsafe-to-Monitor (UTM) Fugitive Emission Component Log
Magna LNG Station
Component Identification Component Location UTM Justification Monitoring Schedule

STARTSTOP

Appendix B

NSPS OOOOa Compliance Verification

EPA 0000a CERTIFIED
INDEPENDENT TESTING DEEMS FLIR CAMERAS COMPLIANT
FLIR is proud to announce its GFx320, GF320, GF300, and G300a cameras have been independently tested and deemed
compliant with the EPA’s NSPS 40 CFR part 60, subpart OOOOa sensitivity standard for optical gas imaging equipment.
Testing was performed by the National Physical Laboratory (NPL), which confirmed the FLIR GFx320, GF320, GF300,
and G300a optical gas imaging cameras are capable of imaging a gas that is half methane/half propane at a
concentration of 10,000 ppm at a flow rate of ≤60g/hr from a quarter inch diameter orifice.
Note: GFx320, GF320, GF300, and G300a cameras have identical detectors, hydrocarbon filters, optical platforms, and HSM algorithms.
CALIBRATION REQUIREMENTS
GAS COMPOUND DETECTION
QUESTIONS AND MANUALS
GAS DETECTION TRAINING
Gas Detection: No Calibration Required
The GFx320, GF320, GF300, and G300a camera’s ability to detect gases is
not influenced by any calibration process and will not degrade over time.
The GFx320, GF320, GF300, and G300a optical gas imaging
cameras are capable of imaging a wide array of gas compounds,
but were specifically designed to see the following hydrocarbons:
To download the latest GF Manual or address questions to
the FLIR Gas Detection team, please go to our FLIR Customer
Support Portal: http://flir.custhelp.com
Learn about ITC training courses for gas detection and OOOOa
program development – www.infraredtraining.com
Visit our blog for the latest updates in FLIR Gas Detection -
www.flir.com/FLIRNews
Isoprene
MEK
Methanol
MIBK
Octane
Pentane
Propylene
Toluene
Xylene
1-Pentene
Methane
Benzene
Propane
Butane
Ethane
Ethanol
Ethylbenzene
Ethylene
Heptane
Hexane
Methane leaks now visible with FLIR OGI cameras
www.flir.com/ogi

Appendix C

Method 21 Compliance Verification

www.dodtec.com 675 Industrial Dr. BLDG A
Cary, IL 60013
Office [phone]
Fax [phone]

September 6, 2016
Terence Trefiak
Target Emission Services Inc
1200 Smith St
Houston, TX 77002

Terence,
The New Cosmos XP-3160 meets or exceeds the monitoring instrument specifications as listed in the
EPA 40 CFR Part 60 Appendix 7 – Method 21 document.
The XP 3160 is a portable VOC (methane) monitoring instrument suitable for Class 1, Division 1
conditions and is capable of measuring the leak definition concentration specified in the regulation.
The scale of the XP-3160 is readable to ±2.5 percent of the specified leak definition concentration. It is
equipped with a 1/4in OD probe with a flow rate measured at 0.5 L/min.
The XP-3160 has a response time less than 30 seconds and a response factor for methane of less than
10.
For any and all application related questions please contact DOD Technologies at PH [phone] or
[e-mail].

Regards,
Jaclyn Langosch
DOD Technologies, Inc.

Appendix D

FEM Plan Revision Log

FEM Plan Revision Log

Revision
Number Date Comments
0 November 2022 Initial FEM Plan
WWW.TARGETEMISSION.COM
Repair Required:
Total:
Month Year Month Leak Tests:
Vent Tests:
No Emission Tests:
Total Tests
District: Facility: Emission ID # Notification ID # Emission Type Detection Date Process Block
Field
Equipment
Designation
Component Sub Source
Operating
Mode
LE
L

+
/
o
r

Sa
f
e
t
y

H
a
z
a
r
d
*
Emission
Severity
Rate
(cfm)Gas Type
Detection Method
/
Quantification
Method
Yearly Gas Value Repair
Recommendation Initial PPM Reading LDAR Tag ID
Bu
b
b
l
e

T
e
s
t
Repair Status Repair
Status Date
First
Attempt
Due Date
Final
Repair
Due Date
DOR Start
Date
DOR End
Date
DOR
Reason
DOR
Approver
Name
Final PPM
Reading Re
p
a
i
r

Co
n
f
i
m
a
t
i
o
n

Me
t
h
o
d
Work
Order #
Repair Status History
(Date - Status - Comment - User - DOR
Approver)
DEUWI - Utah Magna LNG 32210033 Leak 12/14/2022 Separator/Filter Coalescing Skid Valve - BACT Valve Stem N/A No LOW 0.03
Custom
Gas
Optical Gas Imaging/
Optical Gas Imaging $29 Tighten valve packing - - Yes Repaired 02/16/2023 - 12/29/2022 - - - - - Bubble Test
- 02/16/2023 - Repaired - tightened - J Grandis
- 12/14/2022 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 32210034 Leak 12/14/2022
Inlet/Discharge
Piping
Inlet/Discharge
Piping Connector - BACT Threaded Connection N/A No LOW 0.02
Custom
Gas
Optical Gas Imaging/
Optical Gas Imaging $19 Reseal connection and
tighten - - Yes Repaired 12/14/2022 - 12/29/2022 - - - - - OGI
- 12/14/2022 - Repaired - Operator Tightened. -
Melanie Bell
- 12/14/2022 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 32210035 Leak 12/14/2022 Separator/Filter Separator/Filter Valve - BACT Valve Stem N/A No LOW 0.06
Custom
Gas
Optical Gas Imaging/
Optical Gas Imaging $58 Tighten valve packing - - Yes Repaired 12/14/2022 - 12/29/2022 - - - - - Bubble Test
- 12/14/2022 - Repaired - tightened - J Grandis
- 12/14/2022 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 32210036 Leak 12/14/2022 Boiler
Middle Heater
4140 Connector - BACT Threaded Connection N/A No LOW 0.05 Fuel Gas
Optical Gas Imaging/
Optical Gas Imaging $48 Reseal connection and
tighten - - Yes Repaired 12/14/2022 - 12/29/2022 - - - - - Bubble Test
- 12/14/2022 - Repaired - tightened - J Grandis
- 12/14/2022 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 32210037 Leak 12/14/2022 Boiler West Heater 4120 Connector - BACT Threaded Connection N/A No LOW 0.03 Fuel Gas
Optical Gas Imaging/
Optical Gas Imaging $29 Reseal connection and
tighten - - Yes Repaired 12/14/2022 - 12/29/2022 - - - - - OGI
- 12/14/2022 - Repaired - Operator Tightened. -
Melanie Bell
- 12/14/2022 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 33610035 Leak 09/29/2023
Fuel Gas Supply
System
Feed Gas
Compressor M-
1000
Valve - BACT Other N/A No LOW 0.09 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $132 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Stem of
Body Bleed Valve. - Matt Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610036 Leak 09/29/2023 Process Building West Heater 4120 Connector - BACT Threaded Connection N/A No LOW 0.06 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $87 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610037 Leak 09/29/2023
Fuel Gas Supply
System West Heater 4120 Connector - BACT Threaded Connection N/A No LOW 0.07 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $102 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610038 Leak 09/29/2023 Separator/Filter Separator/Filter
Pressure Relief Device -
BACT Valve Seat N/A No MEDIUM 0.12 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $174 N/A - - No Repaired 10/28/2023 - 10/14/2023 10/12/2023 10/31/2023 - - 0 PPM Monitor
- 10/28/2023 - Repaired - Replaced with New
PSV - J Grandis
- 10/02/2023 - Delay of Repair - Tightened ball
valve. - B Nosich - DOR Approver: Brian Nosich
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610039 Leak 09/29/2023 Separator/Filter Separator/Filter Connector - BACT Threaded Connection N/A No LOW 0.08 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $116 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened and Re
Taped Plug. - Matt Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610040 Leak 09/29/2023 Separator/Filter Coalescing Skid
Pressure Relief Device -
BACT Valve Seat N/A No MEDIUM 0.15 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $218 N/A - - No Repaired 10/25/2023 - 10/14/2023 10/12/2023 10/31/2023 - - 0 PPM Monitor
- 10/25/2023 - Repaired - replaced with new
PRV - J Grandis
- 10/02/2023 - Delay of Repair - Tightened ball
DEUWI - Utah Magna LNG 33610041 Leak 09/29/2023 Separator/Filter Coalescing Skid
Pressure Relief Device -
BACT Valve Seat N/A No LOW 0.08 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $116 N/A - - No Repaired 10/30/2023 - 10/14/2023 10/12/2023 10/31/2023 - - 0 PPM Monitor
- 10/30/2023 - Repaired - replaced with new psv
- J Grandis
- 10/02/2023 - Delay of Repair - Tightened ball
DEUWI - Utah Magna LNG 33610042 Leak 09/29/2023 Separator/Filter Mol Sieve Skid Connector - BACT Threaded Connection N/A No LOW 0.08 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $116 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610043 Leak 09/29/2023 Separator/Filter Mol Sieve Skid Connector - BACT Threaded Connection N/A No LOW 0.09 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $131 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610044 Leak 09/29/2023 Separator/Filter Mol Sieve Skid Connector - BACT Threaded Connection N/A No MEDIUM 0.15 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $218 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610045 Leak 09/29/2023 Separator/Filter Mol Sieve Skid Connector - BACT Threaded Connection N/A No LOW 0.10 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $145 N/A - - Yes Repaired 10/02/2023 - 10/14/2023 - - - - - Bubble Test
- 10/02/2023 - Repaired - Tightened ball valve. -
B Nosich
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610046 Leak 09/29/2023
Fuel Gas Supply
System Fuel Gas Heater Connector - BACT Threaded Connection N/A No LOW 0.06 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $87 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 33610047 Leak 09/29/2023
Fuel Gas Supply
System Re-Boiler Connector - BACT Threaded Connection N/A No LOW 0.07 Sweet Gas
Optical Gas Imaging/
Optical Gas Imaging $102 N/A - - Yes Repaired 09/29/2023 - 10/14/2023 - - - - - OGI
- 09/29/2023 - Repaired - Tightened Plug. - Matt
Balash
- 09/29/2023 - Leaking - - Matt Balash
DEUWI - Utah Magna LNG 32810016 Leak 04/20/2023 Dehydrator Mol Sieve Skid Connector - BACT Threaded Connection N/A No LOW 0.07
Custom
Gas
Optical Gas Imaging/
Optical Gas Imaging $106 Reseal connection and
tighten - - Yes Repaired 04/20/2023 - 05/05/2023 - - - - - OGI
- 04/20/2023 - Repaired - resealed and
Tightened Connection - Zachary Hudecek
- 04/20/2023 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 32810017 Leak 04/20/2023 Dehydrator Mol Sieve Skid Connector - BACT Threaded Connection N/A No LOW 0.06
Custom
Gas
Optical Gas Imaging/
Optical Gas Imaging $91 Reseal connection and
tighten - - Yes Repaired 04/20/2023 - 05/05/2023 - - - - - OGI
- 04/20/2023 - Repaired - resealed and
Tightened Connection - Zachary Hudecek
- 04/20/2023 - Leaking - - Collin Simpson
DEUWI - Utah Magna LNG 32810018 Leak 04/20/2023
Fuel Gas Supply
System Regen Heater Connector - BACT Threaded Connection N/A No LOW 0.03 Fuel Gas
Optical Gas Imaging/
Optical Gas Imaging $45 Reseal connection and
tighten - - Yes Repaired 04/20/2023 - 05/05/2023 - - - - - OGI
- 04/20/2023 - Repaired - Resealed and
Tightened Connection - Zachary Hudecek
- 04/20/2023 - Leaking - - Collin Simpson
1.55 $2,167
Company: District(s):
Dominion DEUWI - Utah
Date Range:
Start: End:
Year
Emission Description
Total Leak Count:
Leaks
21
Leaking:
0
Repaired:
21
Delay of Repair:
00
Mandatory
Emission Tests
LDAR Leak Count:
Non-LDAR Leak Count:
REGULATORY EMISSION DETAIL REPORT
REPAIR STATUS
Unsuccessful Attempt:
012 2022 11
0
Vents 0
0
0
0
2023
21
0
TOTAL
Packing of Bottom Gate Valve V-
2026, West Side of Inlet Filter,
Southwest of Coalescing Skid.
Plug Below Drain Gate Valve on
Treated Gas To Cold Box Line,
Northeast of Mole-Sieve Skid.
Packing of Top West Gate Valve to
West Sightglass, North of Filter
Separator on Heavy Ends Separator
Threaded Connection Below Flange
on Fuel Gas Line to Middle Heater
4140, Northwest Side.
Plug Below North Drain Gate Valve
Below North Control Valve ZZ-4120
on Fuel Gas Line, West Side of West
Body Bleed on Valve VBCB01 V-
1003 on Gas Cooler Line From Feed
Gas Compressor M-1000.
Bottom Plug on Drain Valve on Fuel
Gas Line for Heater 4120.
Plug on Drain Valve on Start of Fuel
Gas Line to Heater 4120.
Pressure Relief Valve Seat on Heavy
End Seperator.
Bottom Plug on Drain Valve
VGD3902.
PRV on Treated Gas Coalescer
Seperator.
PRV on Inlet Seperator on Coalescer
Skid.
Plug on Drain Valve on Mercury Filter
Line on Valve V6D3902.
Bottom Plug on Drain Valve on Inlet
Line to Mercury Filter.
Plug on Middle Ball Valve on Dust
Filter.
Plug of West Vent Valve on Regen
Heater Fuel Gas Line.
Plug on Top Ball Valve on Dust Filter.
Top Plug on Ball Valve on Fuel Gas
Line Going Into Regen Fuel Gas
Heater.
Bottom Drain Plug of Ball Valve on
Fuel Gas Line for the Reboiler.
Bottom West Thread to Needle Valve
Manifold Below PDI-2280, West Side
of Mol Sieve Skid.
Top West Thread to Needle Valve
Manifold Below PDI-2280, West Side
of Mol Sieve Skid.
Page 1