DAQ-2024-008265

DAQE-AN143380009-24

{{$d1 }}

Brandon Lithgoe
Ovintiv USA Incorporated
370 17th Street, Suite 1700
Denver, CO 80202
[e-mail]

Dear Mr. Lithgoe:

Re: Approval Order: Modification to Approval Order DAQE-AN143380008-23 to Adjust the
Facility's Potential to Emit (PTE) and Add Equipment
Project Number: N143380009

The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on January
30, 2024. Ovintiv USA Incorporated must comply with the requirements of this AO, all applicable state
requirements (R307), and Federal Standards.

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

Sincerely,

{{$s }}

Bryce C. Bird
Director

BCB:CB:jg

cc: TriCounty Health Department

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

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

May 28, 2024

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

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APPROVAL ORDER
DAQE-AN143380009-24
Modification to Approval Order DAQE-AN143380008-23 to Adjust
the Facility's Potential to Emit (PTE) and Add Equipment

Prepared By
Christine Bodell, Engineer
[phone]
[e-mail]

Issued to
Ovintiv USA Incorporated - Ranch Compressor Station

Issued On
{{$d2 }}

Issued By

{{$s }}

Bryce C. Bird
Director
Division of Air Quality

May 28, 2024
TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description.................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 5
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ................................................................................................................... 13
ACRONYMS ............................................................................................................................... 14

DAQE-AN143380009-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Ovintiv USA Incorporated Ovintiv USA Incorporated - Ranch Compressor
Station

Mailing Address Physical Address
370 17th Street, Suite 1700 SE 1/4 SE 1/4 Sec 14, T4S, R4W
Denver, CO 80202 Duchesne, UT 84000

Source Contact UTM Coordinates
Name: Brandon Lithgoe 559,854 m Easting
Phone: [phone],442,600 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12

SIC code 1311 (Crude Petroleum & Natural Gas)

SOURCE INFORMATION
General Description
Ovintiv USA Incorporated (Ovintiv) owns and operates the Ranch natural gas compressor station located
approximately six (6) miles southeast of Duchesne City in Duchesne County. The Ranch compressor
station receives natural gas from offsite well pads via flowlines and is capable of processing 30 million
cubic feet of natural gas per day. The station operates compressor engines, a generator engine, combined
condensate and produced water storage tanks, a glycol dehydration unit, a hydrogen sulfide ("H2S")
removal unit, a Joules Thompson ("JT") processing skid, a process flare, and a utility flare. Gas processed
by the facility is transferred to pipelines for public or private consumption.

NSR Classification
Minor Modification at Minor Source
Source Classification
Located in Uinta Basin O3 NAA
Duchesne County
Airs Source Size: B
Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
NSPS (Part 60), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After September 18,
2015
MACT (Part 63), A: General Provisions
DAQE-AN143380009-24
Page 4

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

Project Description
Ovintiv has requested the addition of the following emissions sources to its existing AO:

- One (1) 1,900 hp, natural gas-fired compressor engine - Caterpillar G3606A4 (ID: ENG-05);
- One (1) 1,380 hp, natural gas-fired compressor engine - Caterpillar G3516B (ID: ENG-06);
- One (1) 16,800-gallons condensate/produced water storage tank (ID: TANK-04)

The extra tank is being added to ensure adequate storage capacity for natural gas condensate and
produced water. The established production limits in Condition II.B.6.a of AO DAQE-AN143380008-23
for natural gas condensate and produced water are not changing.

SUMMARY OF EMISSIONS

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

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent 15687 57284.00
Carbon Monoxide 7.88 67.91
Nitrogen Oxides 15.83 68.10
Particulate Matter - PM10 1.11 3.31
Particulate Matter - PM2.5 1.11 3.31
Sulfur Dioxide 0.40 1.30
Volatile Organic Compounds 14.17 86.35

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 1840 5480
Acrolein (CAS #107028) 1140 3380
Benzene (Including Benzene From Gasoline) (CAS #71432) 120 1240
Formaldehyde (CAS #50000) 5060 19360
Generic HAPs (CAS #GHAPS) 40 220
Hexane (CAS #110543) 720 8360
Methanol (CAS #67561) 560 1640
Toluene (CAS #108883) 120 1140
Xylenes (Isomers And Mixture) (CAS #1330207) 60 540
Change (TPY) Total (TPY)
Total HAPs 4.83 20.68

DAQE-AN143380009-24
Page 5

SECTION I: GENERAL PROVISIONS

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

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

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

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

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

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

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

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

SECTION II: PERMITTED EQUIPMENT

II.A THE APPROVED EQUIPMENT

II.A.1 Ranch Compressor Station

II.A.2 One (1) Natural Gas/Water Separator

DAQE-AN143380009-24
Page 6

II.A.3 Six (6) Compressor Engines
Fuel: Natural Gas
Control Device: Catalytic Converter (each)

Ratings:
ENG-01:1,340 hp
ENG-02:1,340 hp
ENG-03:1,340 hp
ENG-04:1,775 hp
ENG-05:1,900 hp (New)
ENG-06:1,380 hp (New)

NSPS Applicability: Subpart JJJJ
MACT Applicability: Subpart ZZZZ

II.A.4 One (1) Emergency Generator Engine
Fuel: Natural Gas
Ratings 60 hp

NSPS Applicability: Subpart JJJJ
MACT Applicability: Subpart ZZZZ

II.A.5 One (1) TEG Dehydration Unit
Rated Capacity: 30 MMscf/day
One (1) BTEX Condenser
One (1) Attached 1.0 MMBtu/hr Reboiler (Natural Gas)

II.A.6 Four (4) Condensate/Produced Water Storage Tanks
Type: Vertical Fixed-Roof
Capacity: 16,800 Gallons, each
Contents: Condensate/Produced Water
*1 NEW

II.A.7 One (1) Process Flare (FLR-01)
Rated Capacity: 2.4 MMBtu/hr

II.A.8 One (1) Utility Flare (FLR-02)
Rated Capacity: 552.5 MMBtu/hr

II.A.9 One (1) Electric Line-Heater
- listed for informational purposes only -

II.A.10 One (1) Sulfur Removal Unit with Filter
- listed for informational purposes only -

II.A.11 One (1) JT Skid
Separates NGL from field gas

II.A.12 One (1) Compressed Natural Gas Liquid Storage Tank
Capacity: 18,000 gallons
Contents: NGL

DAQE-AN143380009-24
Page 7

SECTION II: SPECIAL PROVISIONS

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Site-Wide Requirements
II.B.1.a Unless otherwise stated in this Approval Order, the owner/operator shall not allow visible
emissions from any stationary point or fugitive emission source to exceed 10% opacity.
[R307-401-8]

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

II.B.1.b All emissions from the compressor blowdown/startup process and the combustion of produced
gas during compressor downtime, routine maintenance, and midstream facility downtime shall be
routed through the utility flare (FLR-02) before being vented to the atmosphere. [R307-401-8]

II.B.2 Natural Gas-Fired Engine Requirements
II.B.2.a The owner/operator shall not allow visible emissions from each natural gas-fired engine to
exceed 10% opacity. [R307-401-8]

II.B.2.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with
40 CFR 60, Method 9. [R307-401-8]

II.B.2.b The stack for each engine shall vent vertically unrestricted with no obstruction beyond the
opening of the stack. Stack height shall be no less than 50 feet as measured from ground level.
[R307-401-8]

II.B.2.c The owner/operator shall only use natural gas as fuel in each compressor engine and emergency
generator engine. [R307-401-8]

DAQE-AN143380009-24
Page 8

II.B.3 Stack Testing Requirements
II.B.3.a The owner/operator shall not emit more than the following rates from each 1,340 hp (ENG-01,
ENG-02, ENG-03) engine:

Pollutant (lb/hr)
NOx 2.95
CO 0.39
VOC 1.24

The owner/operator shall not emit more than the following rates from the 1,775 hp (ENG-04)
engine:

Pollutant (lb/hr)
NOx 1.96
CO 7.83
VOC 2.35

The owner/operator shall not emit more than the following rates from the 1,900 hp (ENG-05)
engine:

Pollutant (lb/hr)
NOx 2.09
CO 1.05
VOC 1.51

The owner/operator shall not emit more than the following rates from the 1,380 hp (ENG-06)
engine:

Pollutant (lb/hr)
NOx 1.52
CO 0.76
VOC 1.10

[R307-401-8]

II.B.3.b The owner/operator shall conduct any stack testing required by this AO according to the
following conditions. [R307-401-8]

II.B.3.b.1 Initial Test
The owner/operator shall conduct an initial stack test on the emission unit within 180 days after
startup of the emission unit. [R307-165-2]

II.B.3.b.2 Test Frequency
To demonstrate compliance with the NOx, CO, and VOC limits, the owner/operator shall conduct
a stack test on each emission unit every 8,760 hours of operation or every three (3) years,
whichever comes first, after the date of the most recent stack test of the emission unit. The
Director may require the owner/ operator to perform a stack test at any time.
[40 CFR 60 Subpart JJJJ, R307-165-2, R307-401-8]

II.B.3.b.3 Notification
At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test
protocol to the Director. The source test protocol shall include the items contained in
R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference.
[R307-165-3, R307-401-8]

DAQE-AN143380009-24
Page 9

II.B.3.b.4 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol and
according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]

II.B.3.b.5 Access
The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or
Mine Safety and Health Administration (MSHA)-approved access to the test location.
[R307-401-8]

II.B.3.b.6 Reporting
No later than 60 days after completing a stack test, the owner/operator shall submit a written
report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8]

II.B.3.b.7 Possible Rejection of Test Results
The Director may reject stack testing results if the test did not follow the approved source test
protocol or for a reason specified in R307-165-6. [R307-165-6, R307-401-8]

II.B.3.c Test Methods
When performing stack testing, the owner/operator shall use the appropriate EPA-approved test
methods as acceptable to the Director. Acceptable test methods for pollutants are listed below.
[R307-401-8]

II.B.3.c.1 Standard Conditions

A. Temperature - 68 degrees Fahrenheit (293 K)

B. Pressure - 29.92 in Hg (101.3 kPa)

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

[40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]

II.B.3.c.2 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]

II.B.3.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A,
Method 320; or other EPA-approved testing method as acceptable to the Director.
[R307-401-8]

II.B.3.c.4 CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the
Director. [R307-401-8]

II.B.4 Emergency Engine Requirements
II.B.4.a The owner/operator shall not operate the 60 hp emergency generator engine on site for more than
100 hours per rolling 12-month period during non-emergency situations. There is no time limit
on the use of the engines during emergencies. [40 CFR 63 Subpart ZZZZ, R307-401-8]

DAQE-AN143380009-24
Page 10

II.B.4.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new
12-month total by the 20th day of each month using data from the previous 12 months. Records
documenting the operation of each emergency engine shall be kept in a log and shall include the
following:

A. The date the emergency engine was used.

B. The duration of operation in hours.

C. The reason for the emergency engine usage.

[40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.4.a.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.5 Dehydrator Unit Requirements

II.B.5.a The owner/operator shall route all emissions from the dehydration unit, except for emissions
from the glycol separator, through the BTEX condenser. [R307-401-8]

II.B.5.b The owner/operator shall route all liquid discharge from the BTEX condenser system to one of
the condensates/produced water storage tanks. [R307-401-8]

II.B.5.c The owner/operator shall route all emissions from the BTEX condenser and the glycol separator
to the process flare (FLR-01). [R307-401-8]

II.B.5.d The owner/operator shall comply with all applicable requirements of R307-507. Oil and Gas
Industry: Dehydrators. [R307-507-4]

II.B.6 Storage Tank (Storage Vessel) Requirements
II.B.6.a The owner/operator shall not produce more than 120,450 barrels (1 barrel = 42 gallons) of
natural gas condensate and produced water, each, per rolling 12-month period. [R307-401-8]

II.B.6.a.1 The owner/operator shall:

A. Determine natural gas condensate and produced water production with
process flow meters and/or sales records.

B. Record natural gas condensate and produced water production on a
daily basis.

C. Use the monthly production data reported to the Utah Division of Oil, Gas,
and Mining to calculate a new 12-month total by the 20th day of each month
using data from the previous 12 months.

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

[R307-401-8]

II.B.6.b At all times after startup of production, the owner/operator shall route all gases, vapors, and
fumes from the oil storage tanks and produced water storage tanks on site to the process flare
(FLR-01). [40 CFR 60 Subpart OOOOa, R307-401-8]

II.B.6.c The owner/operator shall keep the storage tank thief hatches and other tank openings closed and
sealed, except during tank unloading or other maintenance activities. [R307-401-8]

DAQE-AN143380009-24
Page 11

II.B.6.d At least once each month, the owner/operator shall inspect each closed vent system (including
tank openings, thief hatches, and bypass devices) for defects that could result in air emissions,
according to 40 CFR 60.5416a(c). Records of inspections shall include the date of the inspection
and the results of the inspection. [R307-401-8, 40 CFR 60 Subpart OOOOa]

II.B.6.e The owner/operator shall comply with all applicable requirements of R307-506. Oil and Gas
Industry: Storage Vessels. [R307-401-8]

II.B.7 Truck Loading Requirements
II.B.7.a The owner/operator shall load the tanker trucks on site by the use of bottom filling or a
submerged fill pipe. [R307-401-8, R307-504]

II.B.7.b The owner/operator shall control VOC emissions during condensate truck loading operations at
all times by using a vapor capture line. The vapor capture line shall be connected from the tanker
truck to the process flare (FLR-01). [R307-504]

II.B.7.c The owner/operator shall comply with all applicable requirements of R307-504. Oil and Gas
Industry: Tank Truck Loading. [R307-401-8]

II.B.8 Flare Requirements
II.B.8.a The owner/operator shall use natural gas or plant gas as fuel for the pilot light in each flare.
[R307-401-8]

II.B.8.b Each flare shall operate with a continuous pilot flame and be equipped with an auto-igniter.
[R307-401-8]

II.B.8.c The owner or operator shall maintain records demonstrating the date of installation and
manufacturer specifications for each auto-igniter required under R307-503-4. [R307-401-8]

II.B.8.d The owner/operator shall install flares that are each certified to meet a VOC control efficiency of
no less than 98%. [R307-401-8]

II.B.8.d.1 To demonstrate compliance with the above condition, the owner/operator shall maintain records
of the manufacturer's emissions guarantee for the installed flares. [R307-401-8]

II.B.9 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair)
II.B.9.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.9.a.1 The plan shall address monitoring for "difficult-to-monitor" and "unsafe-to-monitor"
components. [R307-401-8]

DAQE-AN143380009-24
Page 12

II.B.9.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]

II.B.9.b.1 Monitoring surveys shall be conducted according to the following schedule:

A. No later than 60 days after startup of production, as defined in 40 CFR 60.5430a.

B. Semiannually after the initial monitoring survey. Consecutive semiannual
monitoring surveys shall be conducted at least four (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.9.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]

II.B.9.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.9.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]

II.B.9.d The owner/operator shall maintain records of the fugitive emissions monitoring plan, monitoring
surveys, repairs, and resurveys. [R307-401-8]

DAQE-AN143380009-24
Page 13

PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents:

Supersedes AO DAQE-AN143380008-23 dated September 20, 2023
Is Derived From NOI dated January 30, 2024
Incorporates Additional Information dated February 8, 2024
Incorporates DAQE-MN143380009-24 dated February 22, 2024

DAQE-AN143380009-24
Page 14

ACRONYMS

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

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

DAQE-IN143380009-24

April 18, 2024

Brandon Lithgoe
Ovintiv USA Incorporated
370 17th Street, Suite 1700
Denver, CO 80202
[e-mail]

Dear Mr. Lithgoe:

Re: Intent to Approve: Modification to Approval Order DAQE-AN143380008-23 to Adjust the
Facility's Potential to Emit (PTE) and Add Equipment
Project Number: N143380009

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

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

Sincerely,
{{$s }}

Alan D. Humpherys, Manager
New Source Review Section

ADH:CB:jg

cc: TriCounty Health Department

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

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

STATE OF UTAH
Department of Environmental Quality
Division of Air Quality

INTENT TO APPROVE
DAQE-IN143380009-24
Modification to Approval Order DAQE-AN143380008-23
to Adjust the Facility's Potential to Emit (PTE)
and Add Equipment

Prepared By
Christine Bodell, Engineer
[phone]
[e-mail]

Issued to
Ovintiv USA Incorporated - Ranch Compressor Station

Issued On
April 18, 2024
{{$s }}

New Source Review Section Manager
Alan D. Humpherys
{{#s=Sig_es_:signer1:signature}}

TABLE OF CONTENTS

TITLE/SIGNATURE PAGE ....................................................................................................... 1
GENERAL INFORMATION ...................................................................................................... 3
CONTACT/LOCATION INFORMATION ............................................................................... 3
SOURCE INFORMATION ........................................................................................................ 3
General Description ................................................................................................................ 3
NSR Classification .................................................................................................................. 3
Source Classification .............................................................................................................. 3
Applicable Federal Standards ................................................................................................. 3
Project Description .................................................................................................................. 4
SUMMARY OF EMISSIONS .................................................................................................... 4
PUBLIC NOTICE STATEMENT............................................................................................... 5
SECTION I: GENERAL PROVISIONS .................................................................................... 5
SECTION II: PERMITTED EQUIPMENT .............................................................................. 6
SECTION II: SPECIAL PROVISIONS ..................................................................................... 7
PERMIT HISTORY ................................................................................................................... 13
ACRONYMS ............................................................................................................................... 14

DAQE-IN143380009-24
Page 3

GENERAL INFORMATION

CONTACT/LOCATION INFORMATION

Owner Name Source Name
Ovintiv USA Incorporated Ovintiv USA Incorporated - Ranch Compressor Station

Mailing Address Physical Address
370 17th Street, Suite 1700 SE 1/4 SE 1/4 Sec 14, T4S, R4W
Denver, CO 80202 Duchesne, UT 84000

Source Contact UTM Coordinates
Name: Brandon Lithgoe 559,854 m Easting
Phone: [phone],442,600 m Northing
Email: [e-mail] Datum NAD83
UTM Zone 12
SIC code 1311 (Crude Petroleum & Natural Gas)

SOURCE INFORMATION
General Description
Ovintiv USA Incorporated (Ovintiv) owns and operates the Ranch natural gas compressor station located
approximately 6 miles southeast of Duchesne City in Duchesne County. The Ranch compressor station
receives natural gas from offsite well pads via flowlines and is capable of processing 30 million cubic feet
of natural gas per day. The station operates compressor engines, a generator engine, combined
condensate and produced water storage tanks, a glycol dehydration unit, a hydrogen sulfide ("H2S")
removal unit, a Joules Thompson ("JT") processing skid, a process flare, and a utility flare. Gas
processed by the facility is transferred to pipelines for public or private consumption.
NSR Classification
Minor Modification at Minor Source

Source Classification
Located in Uinta Basin O3 NAA
Duchesne County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
NSPS (Part 60), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After September 18,
2015
DAQE-IN143380009-24
Page 4

MACT (Part 63), A: General Provisions
MACT (Part 63), HH: National Emission Standards for Hazardous Air Pollutants From Oil and
Natural Gas Production Facilities
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

Project Description
Ovintiv has requested the addition of the following emissions sources to its existing AO:

- One (1) 1,900 hp, natural gas-fired compressor engine - Caterpillar G3606A4 (ID: ENG-05);
- One (1) 1,380 hp, natural gas-fired compressor engine - Caterpillar G3516B (ID: ENG-06);
- One (1) 16,800-gallons condensate/produced water storage tank (ID: TANK-04).

The extra tank is being added to ensure adequate storage capacity for natural gas condensate and
produced water. The established production limits in Condition II.B.6.a of AO DAQE-AN143380008-23
for natural gas condensate and produced water are not changing.

SUMMARY OF EMISSIONS

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

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent 15687 57284.00
Carbon Monoxide 7.88 67.91
Nitrogen Oxides 15.83 68.10
Particulate Matter - PM10 1.11 3.31
Particulate Matter - PM2.5 1.11 3.31
Sulfur Dioxide 0.40 1.30
Volatile Organic Compounds 14.17 86.35

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 1840 5480
Acrolein (CAS #107028) 1140 3380
Benzene (Including Benzene From Gasoline) (CAS #71432) 120 1240
Formaldehyde (CAS #50000) 5060 19360
Generic HAPs (CAS #GHAPS) 40 220
Hexane (CAS #110543) 720 8360
Methanol (CAS #67561) 560 1640
Toluene (CAS #108883) 120 1140
Xylenes (Isomers And Mixture) (CAS #1330207) 60 540
Change (TPY) Total (TPY)
Total HAPs 4.83 20.68

DAQE-IN143380009-24
Page 5

PUBLIC NOTICE STATEMENT
The NOI for the above-referenced project has been evaluated and has been found to be consistent with the requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be constructed, installed, established, or modified prior to the issuance of an AO by the Director. A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the intent to approve will be published in the Uintah Basin Standard on April 24, 2024. During the public comment period the proposal and the evaluation of its impact on air quality will be available for the public to review and provide comment. If anyone so requests a public hearing within 15 days of publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as close as practicable to the location of the source. Any comments received during the public comment period and the hearing will be evaluated. The proposed conditions of the AO may be changed as a result of the comments received.

SECTION I: GENERAL PROVISIONS

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

I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the two-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of two (2) years. [R307-401-8] I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107] I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150]
DAQE-IN143380009-24
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I.8 The owner/operator shall submit documentation of the status of construction or modification to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18]

SECTION II: PERMITTED EQUIPMENT

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO. II.A THE APPROVED EQUIPMENT II.A.1 Ranch Compressor Station II.A.2 One (1) Natural Gas/Water Separator II.A.3 Six (6) Compressor Engines Fuel: Natural Gas Control Device: Catalytic Converter (each) Ratings: ENG-01:1,340 hp ENG-02:1,340 hp ENG-03:1,340 hp ENG-04:1,775 hp ENG-05:1,900 hp (New) ENG-06:1,380 hp (New) NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.4 One (1) Emergency Generator Engine Fuel: Natural Gas Ratings 60 hp NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.5 One (1) TEG Dehydration Unit Rated Capacity: 30 MMscf/day One (1) BTEX Condenser One (1) Attached 1.0 MMBtu/hr Reboiler (Natural Gas) II.A.6 Four (4) Condensate/Produced Water Storage Tanks Type: Vertical Fixed-Roof Capacity: 16,800 Gallons, each Contents: Condensate/Produced Water *1 NEW II.A.7 One (1) Process Flare (FLR-01) Rated Capacity: 2.4 MMBtu/hr
DAQE-IN143380009-24
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II.A.8 One (1) Utility Flare (FLR-02) Rated Capacity: 552.5 MMBtu/hr II.A.9 One (1) Electric Line-Heater - listed for informational purposes only - II.A.10 One (1) Sulfur Removal Unit with Filter - listed for informational purposes only - II.A.11 One (1) JT Skid Separates NGL from field gas II.A.12 One (1) Compressed Natural Gas Liquid Storage Tank Capacity: 18,000 gallons Contents: NGL

SECTION II: SPECIAL PROVISIONS

The intent is to issue an air quality AO authorizing the project with the following recommended
conditions and that failure to comply with any of the conditions may constitute a violation of the AO. II.B REQUIREMENTS AND LIMITATIONS II.B.1 Site-Wide Requirements II.B.1.a Unless otherwise stated in this Approval Order, the owner/operator shall not allow visible emissions from any stationary point or fugitive emission source to exceed 10% opacity. [R307-401-8] II.B.1.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-401-8] II.B.1.b All emissions from the compressor blowdown/startup process and the combustion of produced gas during compressor downtime, routine maintenance, and midstream facility downtime shall be routed through the utility flare (FLR-02) before being vented to the atmosphere. [R307-401-8] II.B.2 Natural Gas-Fired Engine Requirements II.B.2.a The owner/operator shall not allow visible emissions from each natural gas-fired engine to exceed 10% opacity. [R307-401-8] II.B.2.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Method 9. [R307-401-8] II.B.2.b The stack for each engine shall vent vertically unrestricted with no obstruction beyond the opening of the stack. Stack height shall be no less than 50 feet as measured from ground level. [R307-401-8] II.B.2.c The owner/operator shall only use natural gas as fuel in each compressor engine and emergency generator engine. [R307-401-8]

DAQE-IN143380009-24
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II.B.3 Stack Testing Requirements II.B.3.a The owner/operator shall not emit more than the following rates from each 1,340 hp (ENG-01, ENG-02, ENG-03) engine: Pollutant (lb/hr) NOx 2.95 CO 0.39 VOC 1.24 The owner/operator shall not emit more than the following rates from the 1,775 hp (ENG-04) engine: Pollutant (lb/hr) NOx 1.96 CO 7.83 VOC 2.35 The owner/operator shall not emit more than the following rates from the 1,900 hp (ENG-05) engine: Pollutant (lb/hr) NOx 2.09 CO 1.05 VOC 1.51 The owner/operator shall not emit more than the following rates from the 1,380 hp (ENG-06) engine: Pollutant (lb/hr) NOx 1.52 CO 0.76 VOC 1.10 [R307-401-8] II.B.3.b The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8] II.B.3.b.1 Initial Test The owner/operator shall conduct an initial stack test on the emission unit within 180 days after startup of the emission unit. [R307-165-2] II.B.3.b.2 Test Frequency To demonstrate compliance with the NOx, CO and VOC limits, the owner/operator shall conduct a stack test on each emission unit every 8,760 hours of operation or every three (3) years, whichever comes first, after the date of the most recent stack test of the emission unit. The Director may require the owner/ operator to perform a stack test at any time. [40 CFR 60 Subpart JJJJ, R307-165-2, R307-401-8] II.B.3.b.3 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8]
DAQE-IN143380009-24
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II.B.3.b.4 Testing & Test Conditions The owner/operator shall conduct testing according to the approved source test protocol and according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8] II.B.3.b.5 Access The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or Mine Safety and Health Administration (MSHA)-approved access to the test location. [R307-401-8] II.B.3.b.6 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated results and supporting information. [R307-165-5, R307-401-8] II.B.3.b.7 Possible Rejection of Test Results The Director may reject stack testing results if the test did not follow the approved source test protocol or for a reason specified in R307-165-6. [R307-165-6, R307-401-8] II.B.3.c Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed below. [R307-401-8] II.B.3.c.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K). B. Pressure - 29.92 in Hg (101.3 kPa). C. Averaging Time - As specified in the applicable test method. [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8] II.B.3.c.2 NOx 40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.3.c.3 VOC 40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A, Method 320; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.3.c.4 CO 40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.4 Emergency Engine Requirements II.B.4.a The owner/operator shall not operate the 60 hp emergency generator engine on site for more than 100 hours per rolling 12-month period during non-emergency situations. There is no time limit on the use of the engines during emergencies. [40 CFR 63 Subpart ZZZZ, R307-401-8]
DAQE-IN143380009-24
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II.B.4.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. Records documenting the operation of each emergency engine shall be kept in a log and shall include the following: A. The date the emergency engine was used. B. The duration of operation in hours. C. The reason for the emergency engine usage. [40 CFR 63 Subpart ZZZZ, R307-401-8] II.B.4.a.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8] II.B.5 Dehydrator Unit Requirements II.B.5.a The owner/operator shall route all emissions from the dehydration unit, except for emissions from the glycol separator, through the BTEX condenser. [R307-401-8] II.B.5.b The owner/operator shall route all liquid discharge from the BTEX condenser system to one (1) of the condensates/produced water storage tanks. [R307-401-8] II.B.5.c The owner/operator shall route all emissions from the BTEX condenser and the glycol separator to the process flare (FLR-01). [R307-401-8] II.B.5.d The owner/operator shall comply with all applicable requirements of R307-507. Oil and Gas Industry: Dehydrators. [R307-507-4] II.B.6 Storage Tank (Storage Vessel) Requirements II.B.6.a The owner/operator shall not produce more than 120,450 barrels (1 barrel = 42 gallons) of natural gas condensate and produced water, each, per rolling 12-month period. [R307-401-8] II.B.6.a.1 The owner/operator shall: A. Determine natural gas condensate and produced water production with process flow meters and/or sales records. B. Record natural gas condensate and produced water production on a daily basis. C. Use the monthly production data reported to the Utah Division of Oil, Gas, and Mining to calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. D. Keep the production records for all periods the plant is in operation. [R307-401-8] II.B.6.b At all times after startup of production, the owner/operator shall route all gases, vapors, and fumes from the oil storage tanks and produced water storage tanks on site to the process flare (FLR-01). [40 CFR 60 Subpart OOOOa, R307-401-8] II.B.6.c The owner/operator shall keep the storage tank thief hatches and other tank openings closed and sealed except during tank unloading or other maintenance activities. [R307-401-8]
DAQE-IN143380009-24
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II.B.6.d At least once each month, the owner/operator shall inspect each closed vent system (including tank openings, thief hatches, and bypass devices) for defects that could result in air emissions according to 40 CFR 60.5416a(c). Records of inspections shall include the date of the inspection and the results of the inspection. [R307-401-8, 40 CFR 60 Subpart OOOOa] II.B.6.e The owner/operator shall comply with all applicable requirements of R307-506. Oil and Gas Industry: Storage Vessels. [R307-401-8] II.B.7 Truck Loading Requirements II.B.7.a The owner/operator shall load the tanker trucks on site by the use of bottom filling or a submerged fill pipe. [R307-401-8, R307-504] II.B.7.b The owner/operator shall control VOC emissions during condensate truck loading operations at all times by using a vapor capture line. The vapor capture line shall be connected from the tanker truck to the process flare (FLR-01). [R307-504] II.B.7.c The owner/operator shall comply with all applicable requirements of R307-504. Oil and Gas Industry: Tank Truck Loading. [R307-401-8] II.B.8 Flare Requirements II.B.8.a The owner/operator shall use natural gas or plant gas as fuel for the pilot light in each flare. [R307-401-8] II.B.8.b Each flare shall operate with a continuous pilot flame and be equipped with an auto-igniter. [R307-401-8] II.B.8.c The owner or operator shall maintain records demonstrating the date of installation and manufacturer specifications for each auto-igniter required under R307-503-4. [R307-401-8] II.B.8.d The owner/operator shall install flares that are each certified to meet a VOC control efficiency of no less than 98%. [R307-401-8] II.B.8.d.1 To demonstrate compliance with the above condition, the owner/operator shall maintain records of the manufacturer's emissions guarantee for the installed flares. [R307-401-8] II.B.9 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair) II.B.9.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.9.a.1 The plan shall address monitoring for "difficult-to-monitor" and "unsafe-to-monitor" components. [R307-401-8]
DAQE-IN143380009-24
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II.B.9.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, 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] II.B.9.b.1 Monitoring surveys shall be conducted according to the following schedule: A. No later than 60 days after startup of production, as defined in 40 CFR 60.5430a. 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.9.b.2 Monitoring surveys shall be conducted using one (1) 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] II.B.9.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 a 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.9.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] II.B.9.d The owner/operator shall maintain records of the fugitive emissions monitoring plan, monitoring surveys, repairs, and resurveys. [R307-401-8]
DAQE-IN143380009-24
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PERMIT HISTORY

This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN143380008-23 dated September 20, 2023 Is Derived From NOI dated January 30, 2024 Incorporates Additional Information dated February 8, 2024 Incorporates DAQE-MN143380009-24 dated February 22, 2024
DAQE-IN143380009-24
Page 14

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

DAQE-NN143380009-24

April 18, 2024

Uintah Basin Standard
Legal Advertising Department
268 South 200 East
Roosevelt, UT 84066

RE: Legal Notice of Intent to Approve

This letter will confirm the authorization to publish the attached NOTICE in the Uintah Basin Standard
(Account Number: 3207) on April 24, 2024.

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

Sincerely,

{{$s }}

Jeree Greenwood
Office Technician

Enclosure

cc: Uintah Basin Association of Governments
cc: Duchesne County

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

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

DAQE-NN143380009-24
Page 2
NOTICE

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

Company Name: Ovintiv USA Incorporated
Location: Ovintiv USA Incorporated - Ranch Compressor Station – SE 1/4 SE 1/4 Sec 14,
T4S, R4W, Duchesne, UT
Project Description: Ovintiv USA Incorporated (Ovintiv) owns and operates the Ranch natural gas
compressor station located approximately 6 miles southeast of Duchesne City in
Duchesne County. The Ranch compressor station receives natural gas from
offsite well pads via flowlines and is capable of processing 30 million cubic feet
of natural gas per day. The station operates compressor engines, a generator
engine, combined condensate and produced water storage tanks, a glycol
dehydration unit, a hydrogen sulfide ("H2S") removal unit, a Joules Thompson
("JT") processing skid, a process flare, and a utility flare. Gas processed by the
facility is transferred to pipelines for public or private consumption.

Ovintiv has requested the addition of the following emissions sources to its
existing AO:
- One (1) 1,900 hp, natural gas-fired compressor engine - Caterpillar G3606A4
(ID: ENG-05);
- One (1) 1,380 hp, natural gas-fired compressor engine - Caterpillar G3516B
(ID: ENG-06);
- One (1) 16,800-gallons condensate/produced water storage tank (ID: TANK-
04).

The extra tank is being added to ensure adequate storage capacity for natural gas
condensate and produced water. The established production limits in Condition
II.B.6.a of Approval Order DAQE-AN143380008-23 for natural gas condensate
and produced water are not changing.

The completed engineering evaluation and air quality impact analysis showed the proposed project meets
the requirements of federal air quality regulations and the State air quality rules. The Director intends to
issue an Approval Order pending a 30-day public comment period. The project proposal, estimate of the
effect on local air quality and draft Approval Order are available for public inspection and comment at the
Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments
received by the Division at this same address on or before May 24, 2024 will be considered in making the
final decision on the approval/disapproval of the proposed project. Email comments will also be accepted
at [e-mail]. If anyone so requests to the Director in writing within 15 days of publication of this
notice, a hearing will be held in accordance with
R307-401-7, UAC.

Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or
argument during an adjudicatory proceeding that was raised during the public comment period and was
supported with sufficient information or documentation to enable the Director to fully consider the
substance and significance of the issue.
Date of Notice: April 24, 2024
{{#s=Sig_es_:signer1:signature}}
Uintah Basin Standard
Publication Name:
Uintah Basin Standard
Publication URL:
Publication City and State:
Roosevelt, UT
Publication County:
Duchesne
Notice Popular Keyword Category:
Notice Keywords:
ovintiv USA
Notice Authentication Number:
202404241237383060160
1761527914
Notice URL:
Back
Notice Publish Date:
Wednesday, April 24, 2024
Notice Content
NOTICE A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been
received for consideration by the Director: Company Name: Location: Ovintiv USA Incorporated Ovintiv USA Incorporated - Ranch
Compressor Station - SE 1/4 SE 1/4 Sec 14, T4S, R4W, Duchesne, UT Project Description: Ovintiv USA Incorporated (Ovintiv) owns and
operates the Ranch natural gas compressor station located approximately 6 miles southeast of Duchesne City in Duchesne County. The Ranch
compressor station receives natural gas from offsite well pads via flowlines and is capable of processing 30 million cubic feet of natural gas
per day. The station operates compressor engines, a generator engine, combined condensate and produced water storage tanks, a glycol
dehydration unit, a hydrogen sulfide ("H2S") removal unit, a Joules Thompson ("JT") processing skid, a process flare, and a utility flare. Gas
processed by the facility is transferred to pipelines for public or private consumption. Ovintiv has requested the addition of the following
emissions sources to its existing AO: - One (1) 1,900 hp, natural gas-fired compressor engine - Caterpillar G3606A4 (ID: ENG-05); - One (1)
1,380 hp, natural gas-fired compressor engine - Caterpillar G3516B (ID: ENG-06); - One (1) 16,800-gallons condensate/produced water
storage tank (ID: TANK- 04). The extra tank is being added to ensure adequate storage capacity for natural gas condensate and produced
water. The established production limits in Condition II.B.6.a of Approval Order DAQE-AN143380008-23 for natural gas condensate and
produced water are not changing. The completed engineering evaluation and air quality impact analysis showed the proposed project meets
the requirements of federal air quality regulations and the State air quality rules. The Director intends to issue an Approval Order pending a
30-day public comment period. The project proposal, estimate of the effect on local air quality and draft Approval Order are available for
public inspection and comment at the Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments
received by the Division at this same address on or before May 24, 2024 will be considered in making the final decision on the
approval/disapproval of the proposed project. Email comments will also be accepted at [e-mail]. If anyone so requests to the
Director in writing within 15 days of publication of this notice, a hearing will be held in accordance with R307-401-7, UAC. Under Section 19-
1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or argument during an adjudicatory proceeding that was
raised during the public comment period and was supported with sufficient information or documentation to enable the Director to fully
consider the substance and significance of the issue. Date of Notice: April 24, 2024
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DAQE-

RN143380009
April 8, 2024

Brandon Lithgoe
Ovintiv USA Inc.
370 17th Street, Suite 1700
Denver, CO 80202
[e-mail]

Dear Brandon Lithgoe,

Re: Engineer Review:
Modification to DAQE-AN143380008-23 to Adjust the Facility's Potential to Emit (PTE) and
Add Equipment
Project Number: N143380009

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

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

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

Approval Signature _____________________________________________________________
(Signature & Date)

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

Kimberly D. Shelley Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird Director

State of Utah

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 1
UTAH DIVISION OF AIR QUALITY
ENGINEER REVIEW

SOURCE INFORMATION

Project Number N143380009
Owner Name Ovintiv USA Inc.
Mailing Address 370 17th Street, Suite 1700
Denver, CO, 80202

Source Name Ovintiv USA Inc. - Ranch Compressor Station
Source Location SE 1/4 SE 1/4 Sec 14, T4S, R4W
Duchesne, UT 84000

UTM Projection 559,854 m Easting, 4,442,600 m Northing
UTM Datum NAD83
UTM Zone UTM Zone 12
SIC Code 1311 (Crude Petroleum & Natural Gas)

Source Contact Brandon Lithgoe
Phone Number [phone]
Email [e-mail]

Billing Contact Brandon Lithgoe
Phone Number [phone]
Email [e-mail]

Project Engineer Christine Bodell, Engineer
Phone Number [phone]
Email [e-mail]

Notice of Intent (NOI) Submitted January 30, 2024
Date of Accepted Application February 27, 2024

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 2
SOURCE DESCRIPTION

General Description
Ovintiv USA Inc. (Ovintiv) owns and operates the Ranch natural gas compressor station located
approximately 6 miles southeast of Duchesne City in Duchesne County. The Ranch compressor
station receives natural gas from offsite well pads via flowlines and is capable of processing 30
million cubic feet of natural gas per day. The station operates compressor engines, a generator
engine, combined condensate and produced water storage tanks, a glycol dehydration unit, a
hydrogen sulfide ("H2S") removal unit, a Joules Thompson ("JT") processing skid, a process
flare, and a utility flare. Gas processed by the facility is transferred to pipelines for public or
private consumption.

NSR Classification:
Minor Modification at Minor Source

Source Classification
Located in Uinta Basin O3 NAA
Duchesne County
Airs Source Size: B

Applicable Federal Standards
NSPS (Part 60), A: General Provisions
NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines
NSPS (Part 60), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities
for which Construction, Modification or Reconstruction Commenced After September 18,
2015
MACT (Part 63), A: General Provisions
MACT (Part 63), HH: National Emission Standards for Hazardous Air Pollutants From Oil and
Natural Gas Production Facilities
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines

Project Proposal
Modification to DAQE-AN143380008-23 to Adjust the Facility's Potential to Emit (PTE) and
Add Equipment

Project Description
Ovintiv has requested the addition of the following emissions sources to its existing AO:
- One (1) 1,900 hp, natural gas-fired compressor engine - Caterpillar G3606A4 (ID: ENG-05);
- One (1) 1,380 hp, natural gas-fired compressor engine - Caterpillar G3516B (ID: ENG-06);
- One (1) 16,800-gallons condensate/produced water storage tank (ID: TANK-04)

The extra tank is being added to ensure adequate storage capacity for natural gas condensate and
produced water. The established production limits in Condition II.B.6.a of AO DAQE-
AN143380008-23 for natural gas condensate and produced water are not changing.

EMISSION IMPACT ANALYSIS
The criterial pollutant emission increases did not trigger the requirement for Ovintiv to conduct dispersion
modeling under Utah Administrative Code R307-410-4.

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 3

UAC R307-410-5 requires sources proposing any increase of HAPs emissions to submit all HAP emission
levels and pollutant release information for their facility. Acrolein, formaldehyde, and n-hexane emissions from
the vertically unrestricted engines on site each exceeded the respective emission threshold value (ETV).
However, the requirements of R307-410-5 do not apply to installations which are subject to an emission
standard promulgated under 42 U.S.C. 7412 at the time a notice of intent is submitted. Because the engines on
site are subject to 40 CFR 63 (MACT) Subpart ZZZZ, the source is exempt from the requirement to model
these HAPs.

The UDAQ conducted 1-hour and annual NO2 modeling analyses. The results indicated that the highest 1-hour
and annual NO2 impacts would be 83.09% and 40.40% of the NAAQS levels, respectively. No additional
conditions or limitations are recommended.

See modeling memorandum DAQE-MN143380009-24, dated February 22, 2024 for more information. [Last
updated March 11, 2024]

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 4
SUMMARY OF EMISSIONS

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

Criteria Pollutant Change (TPY) Total (TPY)
CO2 Equivalent 15687 57284.00
Carbon Monoxide 7.88 67.91
Nitrogen Oxides 15.83 68.10
Particulate Matter - PM10 1.11 3.31
Particulate Matter - PM2.5 1.11 3.31
Sulfur Dioxide 0.40 1.30
Volatile Organic Compounds 14.17 86.35

Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr)
Acetaldehyde (CAS #75070) 1840 5480
Acrolein (CAS #107028) 1140 3380
Benzene (Including Benzene From Gasoline) (CAS #71432) 120 1240
Formaldehyde (CAS #50000) 5060 19360
Generic HAPs (CAS #GHAPS) 40 220
Hexane (CAS #110543) 720 8360
Methanol (CAS #67561) 560 1640
Toluene (CAS #108883) 120 1140
Xylenes (Isomers And Mixture) (CAS #1330207) 60 540
Change (TPY) Total (TPY)
Total HAPs 4.83 20.68

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

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 5
Review of BACT for New/Modified Emission Units

1. BACT review regarding New Engines
Ovintiv is adding one (1) 4-stroke lean-burn compressor engine rated at 1,900 hp and one (1) 4-
stroke lean-burn compressor engine rated at 1,380 hp.

NOx, CO, VOCs
Each engine will be equipped with selective catalytic oxidation ("SCO") to reduce carbon
monoxide ("CO") and volatile organic compounds ("VOC") including formaldehyde ("HCHO)
emissions. As per the catalyst specification, the SCO systems will reduce the CO emission rate to
0.25 g/hp-hr, the VOC (excluding HCHO) emission rate to 0.28 g/hp-hr, and the HCHO emission
rate to 0.08 g/hp-hr in each engine.

Considering technical, economic, energy, and environmental impacts, the proposed BACT for
nitrogen oxides ("NOx") control for this project is the Caterpillar Advanced Digital Engine
Management III electronic control system. ADEMTM III is an advanced engine control module
(ECM) that integrates engine sensing/monitoring, air/fuel ratio control (AFRC), ignition timing,
and detonation control into one comprehensive engine control system. ADEMTM III allows each
engine to achieve a NOx emission rate of 0.5 g/hp-hr.

Non-selective catalytic reduction (NSCR), a post-combustion control technique that is used to
reduce NOx, was reviewed for this specific project, however NSCR is best suited for rich burn
engines and is considered technologically infeasible for these lean burn engines.

Selective catalytic reduction (SCR), a post-combustion control technique, was reviewed and
considered for this specific project but ultimately determined to be not economically feasible for
each new engine. An SCR system annualized cost per ton NOx removed for a 1,380 hp engine with
a NOx rating of 0.5 g/hp-hr is in the range of $12,185 to $26,902. Similarly, the SCR system
annualized cost per ton NOx removed for a 1,775 hp engine with a NOx rating of 0.5 g/hp-hr is in
the range of $13,337 to $25,230. (The 1,775 hp engine was chosen because this is a slightly older
model of the Caterpillar G3606 1,900 hp model chosen for this project, and the next engine size
with available data is 4,735 hp). The DAQ considers this cost prohibitive.

Particulate (PM10/PM2.5)
The combustion of natural gas in the engines will result in minor PM10/PM2.5 emissions. NSPS 40
CFR 60 Subpart JJJJ does not set PM emission limits for these types of engines. Available control
options for PM emissions include conducting proper maintenance and good combustion practices.
Ovintiv has a scheduled maintenance program for these engines and conducts annual NSPS JJJJ
stack testing.

Sulfur Dioxide (SO2)
Sulfur dioxide emissions are a result of sulfur present in natural gas. The only const-effective
control option identified for reducing SO2 is the use of good combustion practices. Ovintiv has a
scheduled maintenance program for these engines and conducts annual NSPS JJJJ stack testing.

Field gas used for these engines is conditioned through a series of processes before being used as
fuel gas. Field gas is routed through a coalescing filter, a H2S removal unit, a particulate filter, a
glycol dehydration unit, and a Joules Thompson process skid to remove heavier hydrocarbons.
Fuel conditioning helps enhance the performance of the engines and reduce emissions.

BACT Determination

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 6
Based on information provided above, DAQ recommends the following measures as BACT for the
natural gas-fired engines:

1. Use of combustion controls with air/fuel ratio and lean- burn design.
2. Limit exhaust concentrations, in g/bhp-hr, in the engines to 0.5 of NOx, 0.25 of CO, and 0.36 of
VOCs. For the 1,900 hp engine, this corresponds to a rate of 2.09 lb/hr, 1.05 lb/hr, and 1.51 lb/hr
of NOx, CO, and VOCs, respectively. For the 1,380 hp engine, this corresponds to a rate of 1.52
lb/hr, 0.76 lb/hr, and 1.10 lb/hr of NOx, CO, and VOCs, respectively.
3. Conduct manufacturer recommended maintenance and testing.
4. Limit visible emissions to 10% opacity.
[Last updated April 8, 2024]

3. BACT review regarding New Condensate/Storage Tank
Ovintiv is adding one (1) 16,800-gallon combination condensate/produced water storage tank. The
total condensate and produced water throughputs to the tanks is not changing. Therefore, emissions
from the tanks are not increasing. However, the new tank is a new source of VOC emissions.

Emissions from storage tanks result from displacement of headspace vapor during filling
operations (working losses) and from diurnal temperature and heating variations (breathing losses).
Typically, filling losses constitute 80-90% of the total losses for fixed roof tanks. For the storage
tanks, the control technologies that were evaluated include a vapor recovery system, submerged
filling of tanks, and flaring. Vapor recovery systems typically control highly volatile substances
with high VOC waste streams. The storage tanks operate at a very low vapor pressure, making this
option technically infeasible. The storage tanks will be submerged filled to reduce working losses.
Lastly, flaring is an effective and feasible control technology for these storage tanks. Emissions
from these storage tanks are routed to the process flare with 98% VOC destruction efficiency. This
will reduce the total VOC emissions from the new tanks to 0.66 tons, annually.

Additional control technology for the new storage tank includes good operating practices and
maintenance. Ovintiv will conduct proper maintenance and operating practices on the tank. Thief
hatches on the storage tank shall be kept closed and latched except during vessel unloading or
other maintenance activities. Closed vent systems including vessel openings, thief hatches, and
bypass devices, for defects that can result in air emissions are inspected regularly. [Last updated
February 26, 2024]

4. BACT review regarding Component Fugitive Emissions
Operations at the Ovintiv Facility will generate fugitive VOC emissions. BACT to control fugitive
VOC emissions is the implementation of a fugitive leak detection and repair program per NSPS
OOOOa. [Last updated January 31, 2024]

SECTION I: GENERAL PROVISIONS

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

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 7
I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in
the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions
refer to those rules. [R307-101]

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

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

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

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

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

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

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

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

II.A THE APPROVED EQUIPMENT

II.A.1 Ranch Compressor Station

II.A.2 One (1) Natural Gas/Water Separator

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 8
II.A.3 Six (6) Compressor Engines
Fuel: Natural Gas
Control Device: Catalytic Converter (each)
Ratings:
ENG-01:1,340 hp
ENG-02:1,340 hp
ENG-03:1,340 hp
ENG-04:1,775 hp
ENG-05:1,900 hp (New)
ENG-06:1,380 hp (New)

NSPS Applicability: Subpart JJJJ
MACT Applicability: Subpart ZZZZ

II.A.4 One (1) Emergency Generator Engine
Fuel: Natural Gas
Ratings 60 hp

NSPS Applicability: Subpart JJJJ
MACT Applicability: Subpart ZZZZ

II.A.5 One (1) TEG Dehydration Unit
Rated Capacity: 30 MMscf/day
One (1) BTEX Condenser
One (1) Attached 1.0 MMBtu/hr Reboiler (Natural Gas)

II.A.6 Four (4) Condensate/Produced Water Storage Tanks
Type: Vertical Fixed-Roof
Capacity: 16,800 Gallons, each
Contents: Condensate/Produced Water
*1 NEW

II.A.7 One (1) Process Flare (FLR-01)
Rated Capacity: 2.4 MMBtu/hr

II.A.8 One (1) Utility Flare (FLR-02)
Rated Capacity: 552.5 MMBtu/hr

II.A.9 One (1) Electric Line-Heater
- listed for informational purposes only -

II.A.10 One (1) Sulfur Removal Unit with Filter
- listed for informational purposes only -

II.A.11 One (1) JT Skid
Separates NGL from field gas

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 9
II.A.12 One (1) Compressed Natural Gas Liquid Storage Tank
Capacity: 18,000 gallons
Contents: NGL

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

II.B REQUIREMENTS AND LIMITATIONS

II.B.1 Site-Wide Requirements
II.B.1.a Unless otherwise stated in this Approval Order, the owner/operator shall not allow visible
emissions from any stationary point or fugitive emission source to exceed 10% opacity.
[R307-401-8]

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

II.B.1.b All emissions from the compressor blowdown/startup process and the combustion of produced
gas during compressor downtime, routine maintenance, and midstream facility downtime shall
be routed through the utility flare (FLR-02) before being vented to the atmosphere. [R307-
401-8]

II.B.2 Natural Gas-Fired Engine Requirements
II.B.2.a The owner/operator shall not allow visible emissions from each natural gas-fired engine to
exceed 10% opacity. [R307-401-8]

II.B.2.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance
with 40 CFR 60, Method 9. [R307-401-8]

II.B.2.b The stack for each engine shall vent vertically unrestricted with no obstruction beyond the
opening of the stack. Stack height shall be no less than 50 feet as measured from ground level.
[R307-401-8]

II.B.2.c The owner/operator shall only use natural gas as fuel in each compressor engine and
emergency generator engine. [R307-401-8]

II.B.3 Stack Testing Requirements

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 10
II.B.3.a
NEW
The owner/operator shall not emit more than the following rates from each 1,340 hp (ENG-01,
ENG-02, ENG-03) engine:

Pollutant (lb/hr)
NOx 2.95
CO 0.39
VOC 1.24

The owner/operator shall not emit more than the following rates from the 1,775 hp (ENG-04)
engine:

Pollutant (lb/hr)
NOx 1.96
CO 7.83
VOC 2.35

The owner/operator shall not emit more than the following rates from the 1,900 hp (ENG-05)
engine:

Pollutant (lb/hr)
NOx 2.09
CO 1.05
VOC 1.51

The owner/operator shall not emit more than the following rates from the 1,380 hp (ENG-06)
engine:

Pollutant (lb/hr)
NOx 1.52
CO 0.76
VOC 1.10

[R307-401-8]

II.B.3.b.1 Initial Test
The owner/operator shall conduct an initial stack test on the emission unit within 180 days
after startup of the emission unit. [R307-165-2]

II.B.3.b The owner/operator shall conduct any stack testing required by this AO according to the
following conditions. [R307-401-8]

II.B.3.b.2 Test Frequency
To demonstrate compliance with the NOx, CO and VOC limits, the owner/operator shall
conduct a stack test on each emission unit every 8,760 hours of operation or every three (3)
years, whichever comes first, after the date of the most recent stack test of the emission unit.
The Director may require the owner/ operator to perform a stack test at any time. [40 CFR 60
Subpart JJJJ, R307-165-2, R307-401-8]

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 11
II.B.3.b.3 Notification
At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test
protocol to the Director. The source test protocol shall include the items contained in
R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference.
[R307-165-3, R307-401-8]

II.B.3.b.4 Testing & Test Conditions
The owner/operator shall conduct testing according to the approved source test protocol and
according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8]

II.B.3.b.5 Access
The owner/operator shall provide Occupational Safety and Health Administration (OSHA)- or
Mine Safety and Health Administration (MSHA)-approved access to the test location.
[R307-401-8]

II.B.3.b.6 Reporting
No later than 60 days after completing a stack test, the owner/operator shall submit a written
report of the results from the stack testing to the Director. The report shall include validated
results and supporting information. [R307-165-5, R307-401-8]

II.B.3.b.7 Possible Rejection of Test Results
The Director may reject stack testing results if the test did not follow the approved source test
protocol or for a reason specified in R307-165-6. [R307-165-6, R307-401-8]

II.B.3.c Test Methods
When performing stack testing, the owner/operator shall use the appropriate EPA-approved
test methods as acceptable to the Director. Acceptable test methods for pollutants are listed
below. [R307-401-8]

II.B.3.c.1 Standard Conditions

A. Temperature - 68 degrees Fahrenheit (293 K)

B. Pressure - 29.92 in Hg (101.3 kPa)

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

[40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8]

II.B.3.c.2 NOx
40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as
acceptable to the Director. [R307-401-8]

II.B.3.c.3 VOC
40 CFR 60, Appendix A, Method 18; Method 25; Method 25A; 40 CFR 63, Appendix A,
Method 320; or other EPA-approved testing method as acceptable to the Director.
[R307-401-8]

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 12
II.B.3.c.4 CO
40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to
the Director. [R307-401-8]

II.B.4 Emergency Engine Requirements
II.B.4.a The owner/operator shall not operate the 60 hp emergency generator engine on site for more
than 100 hours per rolling 12-month period during non-emergency situations. There is no
time limit on the use of the engines during emergencies. [40 CFR 63 Subpart ZZZZ, R307-
401-8]

II.B.4.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a
new 12-month total by the 20th day of each month using data from the previous 12 months.
Records documenting the operation of each emergency engine shall be kept in a log and shall
include the following:

A. The date the emergency engine was used

B. The duration of operation in hours

C. The reason for the emergency engine usage

[40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.4.a.2 To determine the duration of operation, the owner/operator shall install a non-resettable hour
meter for each emergency engine. [40 CFR 63 Subpart ZZZZ, R307-401-8]

II.B.5 Dehydrator Unit Requirements

II.B.5.a The owner/operator shall route all emissions from the dehydration unit, except for emissions
from the glycol separator, through the BTEX condenser. [R307-401-8]

II.B.5.b The owner/operator shall route all liquid discharge from the BTEX condenser system to one of
the condensates/produced water storage tanks. [R307-401-8]

II.B.5.c The owner/operator shall route all emissions from the BTEX condenser and the glycol
separator to the process flare (FLR-01). [R307-401-8]

II.B.5.d The owner/operator shall comply with all applicable requirements of R307-507. Oil and Gas
Industry: Dehydrators. [R307-507-4]

II.B.6 Storage Tank (Storage Vessel) Requirements
II.B.6.a The owner/operator shall not produce more than 120,450 barrels (1 barrel = 42 gallons) of
natural gas condensate and produced water, each, per rolling 12-month period. [R307-401-8]

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
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Page 13
II.B.6.a.1 The owner/operator shall:

A. Determine natural gas condensate and produced water production with
process flow meters and/or sales records.

B. Record natural gas condensate and produced water production on a
daily basis.

C. Use the monthly production data reported to the Utah Division of Oil, Gas,
and Mining to calculate a new 12-month total by the 20th day of each month
using data from the previous 12 months.

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

[R307-401-8]

II.B.6.b At all times after startup of production, the owner/operator shall route all gases, vapors, and
fumes from the oil storage tanks and produced water storage tanks on site to the process flare
(FLR-01). [40 CFR 60 Subpart OOOOa, R307-401-8]

II.B.6.c The owner/operator shall keep the storage tank thief hatches and other tank openings closed
and sealed except during tank unloading or other maintenance activities. [R307-401-8]

II.B.6.d At least once each month, the owner/operator shall inspect each closed vent system (including
tank openings, thief hatches, and bypass devices) for defects that could result in air emissions
according to 40 CFR 60.5416a(c). Records of inspections shall include the date of the
inspection and the results of the inspection. [R307-401-8, 40 CFR 60 Subpart OOOOa]

II.B.6.e The owner/operator shall comply with all applicable requirements of R307-506. Oil and Gas
Industry: Storage Vessels. [R307-401-8]

II.B.7 Truck Loading Requirements
II.B.7.a The owner/operator shall load the tanker trucks on site by the use of bottom filling or a
submerged fill pipe. [R307-401-8, R307-504]

II.B.7.b The owner/operator shall control VOC emissions during condensate truck loading operations
at all times by using a vapor capture line. The vapor capture line shall be connected from the
tanker truck to the process flare (FLR-01). [R307-504]

II.B.7.c The owner/operator shall comply with all applicable requirements of R307-504. Oil and Gas
Industry: Tank Truck Loading. [R307-401-8]

II.B.8 Flare Requirements
II.B.8.a The owner/operator shall use natural gas or plant gas as fuel for the pilot light in each flare.
[R307-401-8]

II.B.8.b Each flare shall operate with a continuous pilot flame and be equipped with an auto-igniter.
[R307-401-8]

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 14
II.B.8.c The owner or operator shall maintain records demonstrating the date of installation and
manufacturer specifications for each auto-igniter required under R307-503-4. [R307-401-8]

II.B.8.d The owner/operator shall install flares that are each certified to meet a VOC control efficiency
of no less than 98%. [R307-401-8]

II.B.8.d.1 To demonstrate compliance with the above condition, the owner/operator shall maintain
records of the manufacturer's emissions guarantee for the installed flares. [R307-401-8]

II.B.9 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair)
II.B.9.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.9.a.1 The plan shall address monitoring for "difficult-to-monitor" and "unsafe-to-monitor"
components. [R307-401-8]

II.B.9.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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Page 15
II.B.9.b.1 Monitoring surveys shall be conducted according to the following schedule:

A. No later than 60 days after startup of production, as defined in 40 CFR 60.5430a.

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.9.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]

II.B.9.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.9.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]

II.B.9.d The owner/operator shall maintain records of the fugitive emissions monitoring plan,
monitoring surveys, repairs, and resurveys. [R307-401-8]

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Page 16
PERMIT HISTORY

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

Supersedes DAQE-AN143380008-23 dated September 20, 2023
Is Derived From NOI dated January 30, 2024
Incorporates Additional Information dated February 8, 2024
Incorporates Modeling Memo DAQE-MN143380009-24 dated February 22, 2024

REVIEWER COMMENTS

1. Comment regarding Emissions Estimates and DAQ Acceptance:
Emission estimates for each equipment or process are below.

Oil/Condensate/Produced Water Truck Loading:
Emission estimates assume 200 loads per year of produced water and 669 loadouts of oil/condensate.
Vapors are routed to the process flare (FLR-01, 98% control efficiency).

NGL Truck Loading:
Emission estimates assume a maximum of 730 loads per year. Emissions are due to the venting of
residual condensate vapors to atmosphere from disconnecting the emptied hose. These emissions are
calculated using the Ideal Gas Law and are based on the entire hose volume venting to the
atmosphere. It is assumed that loading would occur only at one pressurized condensate vessel at a
time.

Storage Tanks:
Vent Gas composition determined from central tank battery data. All non-methane/ethane
components assumed to be emitted VOCs that are re-routed to the process flare (FLR-01, 98%
control efficiency).

TEG Glycol Dehydrator:
Emissions from the glycol dehydrator come from the glycol regenerator and condenser and were
estimated using a process simulation. The gas throughput to the glycol dehydration unit is 30
MMscf/day total, and controlled by the process flare (FLR-01, 98% control efficiency). The glycol
dehydrator has an attached 1 MMBtu/hr, natural gas-fired boiler. Emission factors for the boiler are
from AP-42, Chapter 1, Tables 1.4-1, 1.4-2 and 1.4-3. The annual hours of operation of the
dehydrator and boiler are each 8,760 hours.

Vapor Collection System Flares (process flare FLR-01 and utility flare FLR-02):
Emission factors were taken from AP-42 Tables 13.5-1 (NOx) and 13.5-2 (CO). Each flare operates
8,760 hours annually and has a 98% destruction efficiency.
Process Flare FLR-01 controls emission from the tanks, oil/condensate truck loading operations, and
the dehydrator separator gas/condenser vapor. Total annual volume (scf) of gas routed to the flare is
7,951,650 scf (including 183,960 scf from the pilot).
Utility Flare FLR-02 controls emission from the compressor blowdown/startup process, and will
combust produced gas during compressor downtime, routine maintenance, and midstream facility
downtime. Total annual volume (scf) of gas routed to the flare is 182,106,824 scf (including 858,824
scf from the pilot).

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
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Page 17
Emergency Generator:
Emission estimates from the 60 hp, natural gas-fired emergency generator engine were made using
the following emission concentrations: 2.8 g/hp-hr of NOx, 4.8 g/hp-hr of CO, and 1.0675 g/hp-hr of
VOCs. All other emission factors are from AP-42 Table 3.2-3. Per DAQ guidance, 100 hours of
operation per year was used for calculations.

Compressor Engines:
Emission estimates from the three (3) 1,340 hp, one (1) 1,775 hp, one (1) 1,900 hp, and one (1)
1,340 hp natural gas-fired compressor engines were made with manufacturer provided information.
For the 1,340 hp engines: 1.0 g/hp-hr of NOx, 3.61 g/hp-hr of CO (without controls), and 0.90 g/hp-
hr of VOCs (without controls). The use of a selective oxidation catalyst results in a controlled
emission concentration of 0.13 g/hp-hr of CO and 0.42 g/hp-hr of VOCs. All other emission factors
are from AP-42 Table 3.2-3. 8760 hours of operation annually is assumed.
For the 1,775 hp engine: 0.5 g/hp-hr of NOx, 2.0 g/hp-hr of CO (catalyst controlled), and 0.6 g/hp-hr
of VOCs (catalyst controlled). All other emission factors are from AP-42 Table 3.2-3. 8760 hours of
operation annually is assumed.
For the new 1,900 hp and new 1,380 hp engine: 0.5 g/hp-hr of NOx, 0.25 g/hp-hr of CO (catalyst
controlled), and 0.36 g/hp-hr of VOCs (catalyst controlled). All other emission factors are from AP-
42 Table 3.2-3. 8760 hours of operation annually is assumed. [Last updated February 26, 2024]

2. Comment regarding Emissions Estimates and DAQ Acceptance (Continued):

Fugitive VOCs:
Emission factors are from EPA's Protocol for Equipment Leak Emission Estimates, EPA-453/R95-
017, November 1995. The weight fractions of the gas stream were calculated from gas and oil
analyses. The facility consists of approximately 956 gas valves, 113 liquid valves, 2816 gas
connectors, 184 liquid connectors, 226 liquid flanges, 124 open-ended gas lines, and 56 gas pressure
relief valves, all operating for 8,760 per year [Last updated February 26, 2024]

3. Comment regarding Comment regarding 40 CFR 60 (NSPS) Federal Subpart Applicability:
40 CFR 60 (NSPS) Subpart Kb (Standards of Performance for Storage Vessels for Petroleum
Liquids for Which Construction, Reconstruction, or Modification Commenced After July 23, 1984)
applies to "...each storage vessel with a capacity greater than or equal to 75 cubic meters (19,800
gallons), that is used to store volatile organic liquids for which construction, reconstruction, or
modification is commenced after July 23, 1984." There are three (3) existing storage tanks on site,
each with a capacity of less than 16,800 gallons. Ovintiv is requesting to add one (1) new
condensate/produced water storage tank that has a capacity of 16,800 gallons. Therefore, NSPS
Subpart Kb does not apply to this facility.

40 CFR 60 (NSPS) Subpart KKK (Standards of Performance for Equipment Leaks of VOC From
Onshore Natural Gas Processing Plants for Which Construction, Reconstruction, or Modification
Commenced After January 20, 1984, and on or Before August 23, 2011) applies to "affected
facilities in onshore natural gas processing plants." This station does not meet the definition of
"natural gas processing plant" as defined in this subpart. While the JT skid removes condensable
hydrocarbons from the field gas to avoid condensation in the pipeline, NSPS subpart OOOO and
OOOOa post-date Subpart KKK and specifically exclude standalone JT skids from the defined
natural gas processing plants. Further, such a clarification is discussed in a 2004 letter released by
the EPA (J. KenKnight, Federal & Delegated Air Programs Unit, EPA Region 10 to R. Poteet,
Senior Environmental Coordinator, Conoco Phillips Alaska, Inc, November 10, 2004), which
discusses the intent of the rule to apply only to equipment that extracts liquids from field gas through
forced processes. According to the 2004 Memo, the EPA does not consider JT skids to be affected

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 18
facilities under Subpart KKK. Therefore, NSPS Subpart KKK does not apply to this facility.

40 CFR 60 NSPS Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal
Combustion Engines) applies to engines that were ordered after June 12, 2006 and manufactured on
or after July 1, 2007 for engines with maximum power greater than or equal to 500 hp
(§60.4230(a)(4)(i)). NSPS Subpart JJJJ applies to the Ovintiv as the six (6) compressor
engines were ordered after June 12, 2006 and manufactured after July 1, 2007. NSPS Subpart JJJJ
also applies to emergency engines that were manufactured on or after January 1, 2009 for engines
with a maximum engine power greater than 19 KW (25 HP). The 60 hp emergency engine on site
was manufactured after this date and is subject to the provisions of this subpart. Therefore, NSPS
Subpart JJJJ applies to each compressor engine and the emergency engine on site.

[Last updated February 26, 2024]

4. Comment regarding Comment regarding 40 CFR 60 (NSPS) Federal Subpart Applicability
(Continued):
40 CFR 60 (NSPS) Subpart OOOO (Standards of Performance for Crude Oil and Natural Gas
Facilities for Which Construction, Modification, or Reconstruction Commenced After August 23,
2011, and on or Before September 18, 2015) applies to the following onshore affected facilities that
commence construction, modification, or reconstruction after September 18, 2015: gas wells,
centrifugal compressors, reciprocating compressors, pneumatic controllers, storage vessels,
sweetening units, and hydraulically refractured wells. Potentially affected sources under this subpart
include the storage vessels and compressors located at the Ranch Compressor Station. TANK-01,
TANK-02, and the reciprocating compressors associated with compressor engines ENG-01 - ENG-
03 commenced construction before August 23, 2011, therefore are not subject to NSPS OOOO.
TANK-03 and TANK-04 and the reciprocating compressor associated with compressor engines
ENG-04 - ENG-06 commenced construction after September 18, 2015, therefore are not subject to
NSPS OOOO.

Construction commenced of the Joule-Thompson Skid after August 23, 2011. 40 CFR 60 NSPS
Subpart OOOO specifically exempts an isolated or standalone Joule-Thompson skid from the
definition of natural gas processing plant; therefore, NSPS Subpart OOOO does not apply to the
Joule-Thompson Skid.

Therefore, NSPS Subpart OOOO does not apply to this facility.

NSPS OOOOa (Standards of Performance for Crude Oil and Natural Gas Facilities for which
Construction, Modification or Reconstruction Commenced After September 18, 2015) applies to
affected sources that commenced construction, modification, or reconstruction after September 18,
2015. Potentially affected sources under this subpart include the storage vessels, compressors, and
fugitive emission components (as defined in § 60.5430a) at the Ranch Compressor Station. TANK-
01, TANK-02, and the reciprocating compressors associated with compressor engines ENG-01 -
ENG-03 commenced construction before September 18, 2015, therefore are not subject to NSPS
OOOOa. TANK-03 and TANK-04 commenced construction after September 18, 2015, however the
potential to emit (PTE) after controls is less than 6 tons per year (TPY) per vessel of volatile organic
compounds (VOC), therefore this is not an affected source as defined under 60.5365a(e). The
reciprocating compressor associated with compressor engines ENG-04-ENG-06 commenced
construction after September 18, 2015. Therefore, NSPS Subpart OOOOa applies to these
compressor-affected facilities.

The Ranch Compressor Station can be classified as a compressor station (as defined in § 60.5430a)

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 19
and since it was modified (defined in § 60.5365a(j)(1) as the addition of a compressor to a
compressor station) after the NSPS OOOOa applicability date (September 18, 2015), the collection
of fugitive emission components at the Ranch Compressor Station will be considered an affected
facility.
[Last updated February 26, 2024]

5. Comment regarding Comment regarding 40 CFR 63 (MACT) Federal Applicability:
40 CFR 63 Subpart HH (National Emission Standards for Hazardous Air Pollutants from Oil and
Natural Gas Production Facilities) applies to to owners/operators of emission points located at major
or area sources of hazardous air pollutants. An affected facility is defined as "any grouping of
equipment where...natural gas is processed, upgraded, or stored prior to entering the natural gas
transmission and storage source category... Examples of facilities in the oil and natural gas
production source category include, but are not limited to, ... a compressor station that transports
natural gas to a natural gas processing plant....". For area sources, the affected source includes each
triethylene glycol (TEG) dehydration unit located at an affected facility. The facility operates a TEG
dehydration unit and the facility is a compressor station. Therefore, this subpart applies to the
facility. The source must comply with provisions specified in 40 CFR 63.764, paragraph c(1)
through (3). Therefore, MACT Subpart HH applies to this facility.

40 CFR 63 Subpart ZZZZ (National Emissions Standards for Hazardous Air Pollutants for
Stationary Reciprocating Internal Combustion Engines) is applicable to owners/operators of
stationary RICE at a major or area sources of HAP emissions. MACT Subpart ZZZZ applies to the
Ovintiv Facility as the engines are RICE. The compressor engines will meet Subpart ZZZZ by
meeting 40 CFR Part 60, Subpart JJJJ as the Ovintiv Facility is an area source of HAP emissions.
Therefore, MACT Subpart ZZZZ applies to each compressor engine and the emergency engine on
site.
[Last updated February 26, 2024]

6. Comment regarding Title V Applicability:
Title V of the 1990 Clean Air Act (Title V) applies to the following:

1. Any major source
2. Any source subject to a standard, limitation, or other requirement under Section 111 of the Act,
Standards of Performance for New Stationary Sources;
3. Any source subject to a standard or other requirement under Section 112 of the Act, Hazardous
Air Pollutants.
4. Any Title IV affected source.

This facility is not a major source and is not a Title IV source. The facility is subject to regulations
under 40 CFR 60 (NSPS) Subpart JJJJ and OOOOa and 40 CFR 63 (MACT) Subparts HH and
ZZZZ. It is not subject to 40 CFR 61 (NESHAP) regulations. Unless otherwise required by law, the
owner or operator of an area source subject to the provisions of NSPS Subpart JJJJ, NSPS Subpart
OOOOa, MACT Subpart HH, or MACT Subpart ZZZZ is exempt the obligation to obtain a Title V
permit. No such reasons exist for this source. Therefore, Title V does not apply to the Ovintiv
facility.

[Last updated February 26, 2024]

Engineer Review N143380009: Ovintiv USA Inc. - Ranch Compressor Station
April 8, 2024
Page 20
ACRONYMS
The following lists commonly used acronyms and associated translations as they apply to this
document:
40 CFR Title 40 of the Code of Federal Regulations
AO Approval Order
BACT Best Available Control Technology
CAA Clean Air Act
CAAA Clean Air Act Amendments
CDS Classification Data System (used by EPA to classify sources by size/type)
CEM Continuous emissions monitor
CEMS Continuous emissions monitoring system
CFR Code of Federal Regulations
CMS Continuous monitoring system
CO Carbon monoxide
CO2 Carbon Dioxide
CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1
COM Continuous opacity monitor
DAQ/UDAQ Division of Air Quality
DAQE This is a document tracking code for internal UDAQ use
EPA Environmental Protection Agency
FDCP Fugitive dust control plan
GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i)
GWP Global Warming Potential - 40 CFR Part 86.1818-12(a)
HAP or HAPs Hazardous air pollutant(s)
ITA Intent to Approve
LB/HR Pounds per hour
LB/YR Pounds per year
MACT Maximum Achievable Control Technology
MMBTU Million British Thermal Units
NAA Nonattainment Area
NAAQS National Ambient Air Quality Standards
NESHAP National Emission Standards for Hazardous Air Pollutants
NOI Notice of Intent
NOx Oxides of nitrogen
NSPS New Source Performance Standard
NSR New Source Review
PM10 Particulate matter less than 10 microns in size
PM2.5 Particulate matter less than 2.5 microns in size
PSD Prevention of Significant Deterioration
PTE Potential to Emit
R307 Rules Series 307
R307-401 Rules Series 307 - Section 401
SO2 Sulfur dioxide
Title IV Title IV of the Clean Air Act
Title V Title V of the Clean Air Act
TPY Tons per year
UAC Utah Administrative Code
VOC Volatile organic compounds

DIA.(FT) VELO.
(FPS)
TEMP. (oF)
FUG-1 Fugitives NOX 0.00 0.00 12
ENG-01 Compressor Engine NOX 2.95 12.94 12 559,902 4,442,431 52 0 1.00 47.67 991
ENG-02 Compressor Engine NOX 2.95 12.94 12 559,916 4,442,431 52 0 1.00 47.67 991
ENG-03 Compressor Engine NOX 2.95 12.94 12 559,931 4,442,432 52 0 1.00 47.67 991
ENG-04 Compressor Engine NOX 1.96 8.57 12 559,946 4,442,440 52 0 1.67 22.58 835
ENG-05 Compressor Engine NOX 2.09 9.17 12 559,960 4,442,440 52 0 1.67 22.96 835
ENG-06 Compressor Engine NOX 1.52 6.66 12 559,976 4,442,440 52 0 1.67 16.27 971
GENENG-01 Generator Engine NOX 0.37 0.02 12 559,886 4,442,468 6.7 0 0.50 8.49 750
HTR-01 Dehy Reboiler NOX 0.10 0.43 12 559,938 4,442,507 15 0 0.5 73.82 400
DEHY-01 TEG Dehydrator NOX 0.09 0.38 12 559,938 4,442,507 20
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks NOX 0.05 0.08 12 559,884 4,442,560 20
NGL-LOAD Pressurized NGL Loading NOX 0.00 0.00 12 559,877 4,442,574 10
LOAD-1
Condensate and Produced Water
Loading NOX 0.02 0.00 12 559,879 4,442,563 10
FLR-02 Utility Flare Pilot NOX 35.85 3.90 12 560,028 4,442,582 60 0 17.86 65.62 1,832
FLR-01 Process Flare Pilot NOX 0.00 0.01 12 559,950 4,442,578 12.4 0 1.17 65.62 1,832
COMP-MSS Compressor Blowdowns/Startups NOX 1.72 0.05 12 559,916 4,442,431 10
Tank-MSS Tank Venting During Site Shutdown NOX 0.00 0.00 12 559,884 4,442,560 20
* See "Controlled Criteria Pollutants Emissions Summary" page for the remaining air contaminants and emission rates.
** All stacks are round vertical stack.
TONS/YR
Form 11 - Attachment
EMISSION POINT CHEMICAL COMPOSITION OF AIR CONTAMINANT UTM COORDINATES OF EMISSION STACK SOURCES
NUMBER NAME COMPONENT OR
AIR CONTAMINANT
NAME *
CONC.
(%V)
LB/HR
Emitted from FLR-01
(Process Flare)
Emitted from FLR-02
(Utility Flare)
ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT ABOVE
GROUND (FT)
HEIGHT
ABOVE
STRUCT.
(FT)
EXIT DATA**
Emitted from FLR-01
(Process Flare)

DAQE-MN143380009-24

M E M O R A N D U M

TO: Christine Bodell, NSR Engineer

FROM: Jason Krebs, Air Quality Modeler

DATE: February 22, 2024

SUBJECT: Modeling Analysis Review for the Notice of Intent for Ovinitiv USA Inc. – Ranch
Compressor Station, Duchesne County, Utah
_____________________________________________________________________________________
This is not a Major Prevention of Significant Deterioration (PSD) Source.

I. OBJECTIVE
Ovinitiv USA Inc. (Applicant) is seeking an approval order for their Ranch Compressor Station
located in Duchesne County, Utah. The Applicant is requesting approval for the addition of two
compressor engines and one condensate tank. The extra tank is being added to ensure adequate
storage capacity for natural gas condensate and produced water. The established throughput limits
for condensate and produces water will not be changing.

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

II. APPLICABLE RULE(S)

Utah Air Quality Rules:

R307-401-6 Condition for Issuing an Approval Order
R307-410-3 Use of Dispersion Models
R307-410-4 Modeling of Criteria Pollutants in Attainment Areas

III. MODELING METHODOLOGY

A. Applicability

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

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

SPENCER J. COX
Governor

DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Kimberly D. Shelley
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

JK
DAQE- MN143380009-24
Page 2
B. Assumptions

1. Topography/Terrain

The Plant is at an elevation 5754 feet with terrain features that have an affect on
concentration predictions.

a. Zone: 12

b. Approximate Location:

UTM (NAD83): 559854 meters East
4442600 meters North

2. Urban or Rural Area Designation

After a review of the appropriate 7.5 minute quadrangles, it was concluded the area is
“rural” for air modeling purposes.

3. Ambient Air

It was determined the Plant boundary used in the AQIA meets the State’s definition of
ambient air.

4. Building Downwash

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

5. Meteorology

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

Surface – Vernal Airport, UT NWS: 2016 - 2020
Upper Air – Grand Junction, CO NWS: 2016 - 2020

6. Background

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

7. Receptor and Terrain Elevations

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

DAQE- MN143380009-24
Page 3
8. Model and Options

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

9. Air Pollutant Emission Rates

Ovinitiv USA Inc. – Ranch Compressor Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
ENG_01 559902 4442431 2.9500 12.921 8760
ENG_02 559916 4442431 2.9500 12.921 8760
ENG_03 559931 4442431 2.9500 12.921 8760
ENG_04 559946 4442431 1.9600 8.585 8760
ENG_05 559960 4442431 2.0900 9.154 8760
ENG_06 559976 4442431 1.5200 6.658 8760
GENENG 559886 4442468 0.3700 1.621 8760
HTR01 559938 4442507 0.1000 0.438 8760
FLR_2 560028 4442582 0.8900 3.898 8760
FLR_1 559950 4442578 0.1600 0.701 8760

Total 15.9401 69.8176
Kinder Morgan Altamont LLC – Hideout Compressor Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
C_1 585022 4453075 1.26 5.50 8760
C_2 585038 4453075 1.26 5.50 8760
C_3 585055 4453075 1.26 5.50 8760
C_4 585071 4453075 1.26 5.50 8760
C_5 585087 4453074 1.26 5.50 8760
C_6 585103 4453074 1.26 5.50 8760
C_7 585120 4453075 1.26 5.50 8760
C_8 585136 4453075 1.26 5.50 8760
C_9 585152 4453075 1.26 5.50 8760
C_10 585169 4453075 1.26 5.50 8760
H_1 585107 4453148 0.12 0.51 8760
FL_1 585178 4453161 1.99 8.74 8760
DAQE- MN143380009-24
Page 4
COM_1 584996 4453072 0.39 1.70 8760
COM_2 585111 4453158 0.12 0.47 8760
H_2 585108 4453167 0.12 0.51 8760

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

Total 15.13 66.28
XCL Sandco, LLC – Anderson Sand Mine PM10
Source
UTM Coordinates Modeled Emission Rates
Easting Northing PM10
(m) (m) (lb/hr) (tons/yr) hrs/year
DRYER 569768 4461031 3.01 13.18 8760
PILE2 569848 4461058 0.08 0.35 8760
PILE3 569854 4460949 0.08 0.35 8760
PILE1 569981 4460886 0.11 0.48 8760
LDOUTRD 569989 4461121 0.80 3.50 8760
CRUSH 570073 4460875 0.32 1.40 8760
SCREENS 569910 4460957 1.25 5.48 8760
DISAREA 569745 4460896 2.72 11.91 8760
MINEEXCAV 570157 4460882 0.36 1.58 8760
MINERD 570119 4460781 1.12 4.91 8760
LDERDRY 569803 4461059 0.18 0.79 8760
LDERCRSH 570048 4460841 0.36 1.58 8760
TPWP 569997 4460905 0.36 1.58 8760
RJTRMNRD 569870 4460962 0.33 1.45 8760
PILE4 569983 4460808 0.05 0.22 8760
REJTTRSF 569874 4460963 0.06 0.26 8760
DAQE- MN143380009-24
Page 5
DRYPLNT 569738 4461045 0.35 1.53 8760
BLAST 570415 4460697 2.63 11.52 8760
DOME2 569710 4461091 0.02 0.07 8760
DOME1 569681 4461062 0.02 0.07 8760

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

Total 4.78 20.94
SCL Sandco, LLC – Anderson Sand Mine
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
DRYER 569768 4461031 6.90 30.22 8760
BLAST 570415 4460697 6.48 10.64 3285
DAQE- MN143380009-24
Page 6

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

Total 6.65 29.11

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

Total 5.02 21.99
Crusoe Energy Systems – Osguthorpe Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
EU01 576128 4457887 0.83 3.64 8760
EU02 576128 4457869 0.83 3.64 8760
EU03 576128 4457851 0.83 3.64 8760
EU04 576128 4457833 0.83 3.64 8760
EU05 576128 4457815 0.83 3.64 8760
EU06 576202 4457887 0.83 3.64 8760
EU07 576202 4457869 0.83 3.64 8760
DAQE- MN143380009-24
Page 7
EU08 576202 4457851 0.83 3.64 8760
EU09 576202 4457833 0.83 3.64 8760
EU10 576202 4457815 0.83 3.64 8760

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

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

Total 8.30 36.35
DAQE- MN143380009-24
Page 8
Crusoe Energy Systems – West Lateral Facility
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
WLAT01 562442 4452957 0.83 3.64 8760
WLAT02 562461 4452957 0.83 3.64 8760
WLAT03 562479 4452957 0.83 3.64 8760
WLAT04 562497 4452957 0.83 3.64 8760
WLAT05 562515 4452957 0.83 3.64 8760
WLAT06 562442 4452867 0.83 3.64 8760
WLAT07 562461 4452867 0.83 3.64 8760
WLAT08 562479 4452867 0.83 3.64 8760
WLAT09 562497 4452867 0.83 3.64 8760
WLAT10 562515 4452867 0.83 3.64 8760

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

Total 8.30 36.35
Crusoe Energy Systems - Duchesne Data Center Power Station
Source
UTM Coordinates Modeled Emission Rates
Easting Northing NOx
(m) (m) (lb/hr) (tons/yr) hrs/year
TURBINE 567796 4460080 13.33 58.40 8760
DAQE- MN143380009-24
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GEN1 567878 4460114 0.83 3.62 8760
GEN2 567878 4460095 0.83 3.62 8760
GEN3 567879 4460077 0.83 3.62 8760
GEN4 567879 4460060 0.83 3.62 8760
GEN5 567879 4460040 0.83 3.62 8760
GEN6 567951 4460114 0.83 3.62 8760
GEN7 567951 4460095 0.83 3.62 8760
GEN8 567952 4460077 0.83 3.62 8760
BOOST1 567793 4460065 0.17 0.76 8760
BOOST2 567793 4460048 0.17 0.76 8760
REB1 567757 4460042 0.05 0.24 8760
REB2 567763 4460047 0.05 0.24 8760
EGEN1 567879 4460019 2.45 10.73 100
EGEN2 567879 4460011 2.45 10.73 100
GEN9 567952 4460058 0.83 3.62 8760
GEN10 567952 4460041 0.83 3.62 8760

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

Total 15.73 68.89
DAQE- MN143380009-24
Page 10
Kinder Morgan Compressor Stations
Source
UTM Coordinates Modeled Emission Rates
Easting Northing Nox
(m) (m) (lb/hr) (tons/yr) hrs/year
KMWESTC1 551378 4463254 36.3529 159.226 8760
KMWESTC2 551387 4463265 37.3146 163.438 8760
CUMUL1 564020 4467280 78.1922 342.482 8760

Total 151.8597 665.1456
10. Source Location and Parameters
Source Type
Source Parameters
Elev, Ht Temp Flow Dia
(ft) (m) (ft) (K) (m/s) (m)
ENG_01 POINT 5751.6 15.8 52.0 806 47.70 0.30
ENG_02 POINT 5751.5 15.8 52.0 806 47.70 0.30
ENG_03 POINT 5751.2 15.8 52.0 806 47.70 0.30
ENG_04 POINT 5751.1 15.8 52.0 806 47.70 0.30
ENG_05 POINT 5750.9 15.8 52.0 806 22.96 0.30
ENG_06 POINT 5750.6 15.8 52.0 806 16.70 0.30
GENENG POINT 5751.2 2.0 6.7 672 2.59 0.15
HTR01 POINT 5749.3 4.6 15.0 478 22.50 0.15
FLR_2 POINT 5741.8 18.3 60.0 1273 20.00 0.55
FLR_1 POINT 5744.3 3.8 12.4 1273 20.00 5.44
C_1 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_2 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_3 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_4 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_5 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_6 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_7 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_8 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_9 POINT 5089.0 12.2 40.0 866 38.20 0.36
C_10 POINT 5089.0 12.2 40.0 866 38.20 0.36
H_1 POINT 5089.0 6.1 20.0 589 3.24 0.25
FL_1 POINT 5089.0 18.3 60.0 1273 20.00 0.36
COM_1 POINT 5089.0 3.7 12.0 1255 4.41 0.51
COM_2 POINT 5089.0 3.7 12.0 1255 0.92 0.51
DAQE- MN143380009-24
Page 11
H_2 POINT 5089.0 6.1 20.0 589 3.24 0.25
GEN1AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN2AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN3AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN4AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN5AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN6AG POINT 5416.7 7.0 23.0 738 26.49 0.51
GEN7AG POINT 5416.7 7.0 23.0 738 26.49 0.51
C1 POINT 5956.9 7.6 25.0 866 38.20 0.36
C2 POINT 5958.1 7.6 25.0 866 38.20 0.36
C3 POINT 5958.9 7.6 25.0 866 38.20 0.36
CMB1 POINT 5954.9 3.7 12.0 1255 2.41 0.51
REB1 POINT 5961.0 7.6 25.0 589 3.24 0.25
CMB2 POINT 5961.9 3.7 12.0 1255 2.41 0.51
FLARE POINT 5962.2 18.3 60.0 1273 20.00 0.36
KMWESTC1 POINT 6640.9 9.1 30.0 700 21.18 0.30
KMWESTC2 POINT 6639.1 9.1 30.0 700 21.18 0.30
C4 POINT 5958.9 7.6 25.0 866 38.20 0.36
DRYER POINT 5902.6 11.7 38.2 422 16.09 1.37
BLAST AREA_POLY 5897.2 0.0 0.0
COMBST POINT 5355.4 7.7 25.3 922 0.03 1.22
ENG1 POINT 5350.7 3.3 10.7 741 45.01 0.30
ENG2 POINT 5351.5 3.3 10.7 741 45.01 0.30
ENG3 POINT 5352.2 3.3 10.7 741 45.01 0.30
EU01 POINT 5307.9 7.6 25.0 861 56.60 0.33
EU02 POINT 5307.6 7.6 25.0 861 56.60 0.33
EU03 POINT 5307.9 7.6 25.0 861 56.60 0.33
EU04 POINT 5306.2 7.6 25.0 861 56.60 0.33
EU05 POINT 5304.3 7.6 25.0 861 56.60 0.33
EU06 POINT 5304.7 7.6 25.0 861 56.60 0.33
EU07 POINT 5305.2 7.6 25.0 861 56.60 0.33
EU08 POINT 5304.8 7.6 25.0 861 56.60 0.33
EU09 POINT 5302.7 7.6 25.0 861 56.60 0.33
EU10 POINT 5300.8 7.6 25.0 861 56.60 0.33
CUMUL1 POINT 6107.2 9.5 31.0 700 21.19 0.31
TURBINE POINT 5825.4 12.2 40.0 765 46.40 1.83
GEN8 POINT 5821.1 7.6 25.0 861 56.60 0.33
BOOST1 POINT 5823.7 7.6 25.0 944 16.47 0.33
BOOST2 POINT 5821.7 7.6 25.0 944 16.47 0.33
REB2 POINT 5822.4 5.5 18.0 450 6.10 0.30
DAQE- MN143380009-24
Page 12
EGEN1 POINT 5823.6 5.5 18.0 765 16.73 0.46
EGEN2 POINT 5820.9 5.5 18.0 765 16.73 0.46
GEN9 POINT 5820.3 7.6 25.0 861 56.60 0.33
GEN10 POINT 5818.8 7.6 25.0 861 56.60 0.33
RES01 POINT 5448.7 7.6 25.0 861 56.60 0.33
RES02 POINT 5448.6 7.6 25.0 861 56.60 0.33
RES03 POINT 5448.3 7.6 25.0 861 56.60 0.33
RES04 POINT 5447.9 7.6 25.0 861 56.60 0.33
RES05 POINT 5447.9 7.6 25.0 861 56.60 0.33
RES06 POINT 5446.0 7.6 25.0 861 56.60 0.33
RES07 POINT 5445.6 7.6 25.0 861 56.60 0.33
RES08 POINT 5445.0 7.6 25.0 861 56.60 0.33
RES09 POINT 5444.4 7.6 25.0 861 56.60 0.33
RES10 POINT 5444.1 7.6 25.0 861 56.60 0.33
WLAT01 POINT 5477.6 7.6 25.0 861 56.60 0.33
WLAT02 POINT 5476.7 7.6 25.0 861 56.60 0.33
WLAT03 POINT 5476.2 7.6 25.0 861 56.60 0.33
WLAT04 POINT 5476.4 7.6 25.0 861 56.60 0.33
WLAT05 POINT 5477.0 7.6 25.0 861 56.60 0.33
WLAT06 POINT 5488.1 7.6 25.0 861 56.60 0.33
WLAT07 POINT 5487.7 7.6 25.0 861 56.60 0.33
WLAT08 POINT 5487.5 7.6 25.0 861 56.60 0.33
WLAT09 POINT 5486.5 7.6 25.0 861 56.60 0.33
WLAT10 POINT 5484.9 7.6 25.0 861 56.60 0.33
ENGINE1 POINT 5375.5 15.8 52.0 806 58.16 0.30
ENGINE2 POINT 5375.5 15.8 52.0 806 58.16 0.30
ENGINE3 POINT 5375.4 15.8 52.0 806 58.16 0.30
HEATER POINT 5375.8 3.0 10.0 373 3.80 0.15
REBOILER POINT 5375.7 3.0 10.0 373 3.80 0.15
ENGINE4 POINT 5375.5 15.8 52.0 730 49.71 0.30
TNKHTR1 POINT 5375.5 6.1 20.0 373 3.80 0.15
TNKHTR2 POINT 5375.5 6.1 20.0 373 3.80 0.15
INCINER POINT 5375.6 6.1 20.0 981 1.92 1.22
ENGINE5 POINT 5375.5 15.8 52.0 806 58.16 0.30
PVGEN POINT 5374.0 2.4 8.0 704 28.46 0.15
TNKHTR3 POINT 5375.5 6.1 20.0 373 3.80 0.15
TNKHTR4 POINT 5375.5 6.1 20.0 373 3.80 0.15
SRC00041 POINT 5365.5 7.6 25.0 861 56.60 0.33
SRC00042 POINT 5366.2 7.6 25.0 861 56.60 0.33
SRC00043 POINT 5368.3 7.6 25.0 861 56.60 0.33
DAQE- MN143380009-24
Page 13
SRC00044 POINT 5369.9 7.6 25.0 861 56.60 0.33
SRC00045 POINT 5366.2 7.6 25.0 861 56.60 0.33
SRC00046 POINT 5366.7 7.6 25.0 861 56.60 0.33
SRC00047 POINT 5367.5 7.6 25.0 861 56.60 0.33
SRC00048 POINT 5368.8 7.6 25.0 861 56.60 0.33
SRC00049 POINT 5370.3 7.6 25.0 861 56.60 0.33
SRC00050 POINT 5366.9 7.6 25.0 861 56.60 0.33
MULL01 POINT 5270.6 7.6 25.0 861 56.60 0.33
MULL02 POINT 5269.8 7.6 25.0 861 56.60 0.33
MULL03 POINT 5268.7 7.6 25.0 861 56.60 0.33
MULL04 POINT 5267.4 7.6 25.0 861 56.60 0.33
MULL05 POINT 5266.0 7.6 25.0 861 56.60 0.33
MULL06 POINT 5260.5 7.6 25.0 861 56.60 0.33
MULL07 POINT 5259.6 7.6 25.0 861 56.60 0.33
MULL08 POINT 5259.0 7.6 25.0 861 56.60 0.33
MULL09 POINT 5258.7 7.6 25.0 861 56.60 0.33
MULL10 POINT 5258.3 7.6 25.0 861 56.60 0.33
COMP1 POINT 5329.8 7.3 24.0 718 57.88 0.36
COMP2 POINT 5331.1 7.3 24.0 718 57.88 0.36
UFLARE POINT 5325.1 21.3 70.0 811 96.81 0.30
TNKHEAT POINT 5341.6 6.1 20.0 373 3.80 0.15

IV. RESULTS AND CONCLUSIONS

A. National Ambient Air Quality Standards

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

Air
Pollutant
Period Prediction Class II
Significant
Impact
Level
Background Nearby
Sources
Total NAAQS Percent
(μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) NAAQS
NO2
1-
Hour 143.3 7.5 1.6 11.3 156.2 188 83.09%
Annual 22.7 1.0 17.4 0.3 40.4 100 40.40%

JMK:jg

lb/year TPY lb/hr tpy lb/hr tpy lb/yr TPY lb/yr TPY
NOx 52.27 2.09 9.17 1.52 6.66 68.11 *matches NOI within tolerance (rounding)
CO 60.03 1.05 4.59 0.76 3.33 67.95 *matches NOI within tolerance (rounding)
PM10 2.2 0.14 0.62 0.11 0.48 3.30 *matches NOI within tolerance (rounding)
PM2.5 2.2 0.14 0.62 0.11 0.48 3.30 *matches NOI within tolerance (rounding)
SO2 0.9 0.05 0.23 0.04 0.18 1.31 *matches NOI within tolerance (rounding)
VOC 72.18 1.51 6.60 1.10 4.80 0.6 2.62 86.20 *matches NOI within tolerance (rounding)
Acetaldehyde 3640 1.82 0.119 0.521 0.092 0.402 3640 2.74 *matches NOI within tolerance (rounding)
Acrolein 2240 1.12 0.073 0.321 0.056 0.247 2240 1.69 *matches NOI within tolerance (rounding)
Benzene 1120 0.56 0.006 0.027 0.005 0.021 1120 0.61 *matches NOI within tolerance (rounding)
Formaldehyde 14300 7.15 0.335 1.468 0.243 1.066 14301 9.68 *matches NOI within tolerance (rounding)
Hexane 7640 3.82 0.016 0.069 0.012 0.053 7640 3.94 *matches NOI within tolerance (rounding)
Methanol 1080 0.54 0.036 0.156 0.027 0.120 1080 0.82 *matches NOI within tolerance (rounding)
Toluene 1020 0.51 0.006 0.025 0.004 0.020 1020 0.56 *matches NOI within tolerance (rounding)
Xylenes 480 0.24 0.003 0.011 0.002 0.009 480 0.26 *matches NOI within tolerance (rounding)
Generic HAPs 180 0.09 0.004 0.018 0.003 0.014 180 0.12 *matches NOI within tolerance (rounding)
Total HAPs 31700 15.85 0.5975853 2.617 0.445609 1.952 31701 20.42 *matches NOI within tolerance (rounding)
Current AO ENG-05 ENG-06 New Tank Replaced Flare
*pilot light rating
changing, negligable
emission difference
*throughput the
same, no increases
New PTE New Fugitives (Tank)
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County 52.00 Field Gas
1.67 7495
835.00 1,084.51
Engine Data 12,021.00 1.48
EPN
Source Name Method of Emission Control Federal Standards Yes/No
Manufacturer SCO Yes
Model Number No
Serial Number Yes
Manufacture Date AFRC
Last Rebuild Date
Application UTM Coordinates
Horsepower:
Fuel consumption (Btu/hp-hr):Zone
Hours of operation per year: Easting (meters)
Engine Type:Northing (meters)
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%) 0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) = 0.052 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) = 0.230
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State emission
limit Emissions Emissions
(g/hp-hr) (lb/MMBtu) (lb/hr) (tpy) (g/hp-hr) (g/hp-hr) (g/hp-hr) (lb/hr) (tpy)
Total VOC (NMNEHC) 0.7 2.932 12.843 0.36 g/hp-hr 1.508 6.605
VOC (NMNEHC w/o HCHO) 0.55 0.0652 2.304 10.091 0.7 0.28 g/hp-hr 1.173 5.137
NOx 0.5 4.08 2.094 9.173 1.0 0.5 g/hp-hr 2.094 9.173
CO 2.07 0.317 8.671 37.978 2.0 0.25 g/hp-hr 1.047 4.587
PM (condensable)0.00991 0.141 0.618 0.00991 lb/MMBtu 0.141 0.618
PM2.5/10 (filterable)0.0000771 0.001 0.005 0.0000771 lb/MMBtu 0.001 0.005
PMTOTAL 0.00999 0.142 0.623 0.00999 lb/MMBtu 0.142 0.623
SO2 0.000588 0.008 0.037 0.052 0.230
Formaldehyde (HCHO) 0.15 0.0528 0.628 2.752 0.08 g/hp-hr 0.335 1.468
Benzene 0.000440 0.006 0.027 0.000440 lb/MMBtu 0.006 0.027
Toluene 0.000408 0.006 0.025 0.000408 lb/MMBtu 0.006 0.025
Ethylbenzene 0.000040 0.001 0.002 0.000040 lb/MMBtu 0.001 0.002
Xylene 0.000184 0.003 0.011 0.000184 lb/MMBtu 0.003 0.011
2,2,4-Trimethylpentane 0.000250 0.004 0.016 0.000250 lb/MMBtu 0.004 0.016
Acrolein 0.00514 0.073 0.321 0.00514 lb/MMBtu 0.073 0.321
Acetaldehyde 0.00836 0.119 0.521 0.00836 lb/MMBtu 0.119 0.521
n-Hexane 0.00111 0.016 0.069 0.00111 lb/MMBtu 0.016 0.069
Methanol 0.0025 0.036 0.156 0.0025 lb/MMBtu 0.036 0.156
Total HAPs 0.06353067 0.905 3.963 0.04196379 lb/MMBtu 0.598 2.617 --
CO2 110.00 1,566.455 6,861.073 110.00 lb/MMBtu 1,566.455 6,861.073
CH4 1.25 17.801 77.967 1.25 lb/MMBtu 17.801 77.967
CO2e 2,011.471 8,810.241 2,011.471 8,810.241 --
https://ww2.arb.ca.gov/sites/default/files/2020-06/gappc.pdf
ppmvd = (gm/Bhp-hr) * factor
Lean-burn Engines, natural gas fueled
Pollutant Factor ppmv
NOx 80 40
VOC 212 76.32
CO 123 30.75
Duchesne Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Exhaust Flowrate (cfm) Sulfur Content (grains/100scf)
TBD Stratified Charge MACT Subpart ZZZZ
ENG-05
Compressor Engine
Caterpillar Catalyst Type NSPS Subpart JJJJ
G3606 Parameter Adjustment NSPS Subpart IIII
TBD Other (Specify)
Gas Compression
1,900 Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes7,495
8,760
4 Stroke, Lean-Burn
Ideal Gas Law: 385.22 scf/lb-mole
Emission
factor used units Emission Factor Source
Mass balance
Not Applicable VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
NSPS JJJJ
NSPS JJJJ
AP-42, Table 3.2-2
Catalyst controlled
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Catalyst controlled
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County 52.00 Field Gas
1.67 7950
835.00 1,084.51
Engine Data 12,021.00 1.48
EPN
Source Name Method of Emission Control Federal Standards Yes/No
Manufacturer SCO Yes
Model Number No
Serial Number Yes
Manufacture Date AFRC
Last Rebuild Date
Application UTM Coordinates
Horsepower:
Fuel consumption (Btu/hp-hr):Zone
Hours of operation per year: Easting (meters)
Engine Type:Northing (meters)
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%) 0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) = 0.040 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) = 0.177
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State emission
limit Emissions Emissions
(g/hp-hr) (lb/MMBtu) (lb/hr) (tpy) (g/hp-hr) (g/hp-hr) (g/hp-hr) (lb/hr) (tpy)
Total VOC (NMNEHC) 0.85 2.586 11.327 0.36 g/hp-hr 1.095 4.797
VOC (NMNEHC w/o HCHO) 0.43 0.0652 1.308 5.730 0.7 0.28 g/hp-hr 0.852 3.731
NOx 0.5 4.08 1.521 6.663 1.0 0.5 g/hp-hr 1.521 6.663
CO 2.19 0.317 6.663 29.183 2.0 0.25 g/hp-hr 0.761 3.331
PM (condensable)0.00991 0.109 0.476 0.00991 lb/MMBtu 0.109 0.476
PM2.5/10 (filterable)0.0000771 0.001 0.004 0.0000771 lb/MMBtu 0.001 0.004
PMTOTAL 0.00999 0.110 0.480 0.00999 lb/MMBtu 0.110 0.480
SO2 0.000588 0.006 0.028 0.040 0.177
Formaldehyde (HCHO) 0.42 0.0528 1.278 5.597 0.08 g/hp-hr 0.243 1.066
Benzene 0.000440 0.005 0.021 0.000440 lb/MMBtu 0.005 0.021
Toluene 0.000408 0.004 0.020 0.000408 lb/MMBtu 0.004 0.020
Ethylbenzene 0.000040 4.39E-04 0.002 0.000040 lb/MMBtu 4.39E-04 0.002
Xylene 0.000184 0.002 0.009 0.000184 lb/MMBtu 0.002 0.009
2,2,4-Trimethylpentane 0.000250 0.003 0.012 0.000250 lb/MMBtu 0.003 0.012
Acrolein 0.00514 0.056 0.247 0.00514 lb/MMBtu 0.056 0.247
Acetaldehyde 0.00836 0.092 0.402 0.00836 lb/MMBtu 0.092 0.402
n-Hexane 0.00111 0.012 0.053 0.00111 lb/MMBtu 0.012 0.053
Methanol 0.0025 0.027 0.120 0.0025 lb/MMBtu 0.027 0.120
Total HAPs 0.13587981 1.491 6.529 0.040617 lb/MMBtu 0.446 1.952 --
CO2 110.00 1,206.810 5,285.828 110.00 lb/MMBtu 1,206.810 5,285.828
CH4 1.25 13.714 60.066 1.25 lb/MMBtu 13.714 60.066
CO2e 1,549.654 6,787.483 1,549.654 6,787.483 --
https://ww2.arb.ca.gov/sites/default/files/2020-06/gappc.pdf
ppmvd = (gm/Bhp-hr) * factor
Lean-burn Engines, natural gas fueled
Pollutant Factor ppmv
NOx 80 40
VOC 212 76.32
CO 123 30.75
Duchesne Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Exhaust Flowrate (cfm) Sulfur Content (grains/100scf)
TBD Stratified Charge MACT Subpart ZZZZ
ENG-06
Compressor Engine
Caterpillar Catalyst Type NSPS Subpart JJJJ
G3606 Parameter Adjustment NSPS Subpart IIII
TBD Other (Specify)
Gas Compression
1,380 Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes7,950
8,760
4 Stroke, Lean-Burn
Ideal Gas Law: 385.22 scf/lb-mole
Emission
factor used units Emission Factor Source
Mass balance
Not Applicable VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
NSPS JJJJ
NSPS JJJJ
AP-42, Table 3.2-2
Catalyst controlled
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Catalyst controlled
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2

January 30, 2024
VIA UDAQ NSR Permitting Online Portal
https://deq.utah.gov/air-quality/air-quality-permitting

Mr. Bryce Bird, Director
Utah Department of Environmental Quality
Division of Air Quality
195 North 1950 West
P.O. Box 144820
Salt Lake City, Utah 84116

RE: Notice of Intent Application
Ovintiv USA Inc.
Ranch Compressor Station
Approval Order: DAQE No. AN143380008-23
SE ¼ SE ¼ Section 14, Township 4S, Range 4W
Duchesne County, Utah
Dear Mr. Bird:

Ovintiv USA Inc. (“Ovintiv”) is submitting this Notice of Intent (“NOI”) to modify Approval Order
(“AO”) DAQE No. AN143380008-23, issued September 20, 2023, for the Ranch Compressor
Station. This registration includes the addition of two compressor engines, one additional
storage tank, updates to the fugitive emissions to account for the new equipment, and the
proposed replacement of the existing process flare with a new model. These modifications will
result in the following change in emissions:

Pollutant Permitted
Emissions (tpy)
Change in
Emissions
(tpy)
Proposed
Emissions (tpy)
PM10/PM2.5 2.20 1.11 3.31
NOx 52.27 15.83 68.10
SO2 0.90 0.40 1.30
CO 60.03 7.88 67.91
VOC 72.18 14.17 86.35
VOC (excluding fugitives) 50.70 11.55 62.25
Total GHG (CO2e) 41,597 15,687 57,283
Total HAPs 15.85 4.83 20.68

MR. BRYCE BIRD
UTAH DEPARTMENT OF ENVIRONMENTAL QUALITY
JANUARY 30, 2024
PAGE 2

If possible, Ovintiv requests that this NOI be reviewed by Ms. Christine Bodell of your staff.
Christine is very familiar with the current AO for this facility as she was the environmental
engineer who reviewed the last NOI in 2023 and she participated in a pre-NOI meeting for this
project on December 28, 2023.
If you have any questions or require additional information, please contact me at (281) 847-
6093 or by email at [e-mail].
Sincerely,

Brandon Lithgoe
Senior Air Quality Engineer

NOTICE OF INTENT APPLICATION
FOR
OVINTIV USA INC.
RANCH COMPRESSOR STATION
DUCHESNE COUNTY, UTAH
APPROVAL ORDER: DAQE # AN143380008-23

Submitted To:

UTAH DEPARTMENT OF ENVIRONMENTAL QUALITY
DIVISION OF AIR QUALITY
195 NORTH 1950 WEST
SALT LAKE CITY, UTAH 84116

Submitted By:

OVINTIV USA INC.
370 17TH ST, SUITE 1700
DENVER, CO 80202

JANUARY 2024

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 1
CONTENTS
1.0 INTRODUCTION ............................................................................................................... 2
1.1 Project Overview ..................................................................................................... 2
1.2 Site Location ........................................................................................................... 3
2.0 SITE PROCESS INFORMATION ...................................................................................... 4
2.1 Process Description ................................................................................................ 4
2.2 Emission Controls ................................................................................................... 4
2.3 Planned Maintenance, Startup, and Shutdown Activities ......................................... 5
2.4 Operating Schedule................................................................................................. 5
3.0 EMISSIONS DATA ............................................................................................................ 6
3.1 Emission Sources ................................................................................................... 6
3.2 Analyses ................................................................................................................. 7
3.3 Modeled Analyses ................................................................................................... 7
4.0 IMPACTS EVALUATION ................................................................................................... 9
4.1 Dispersion Modeling ................................................................................................ 9
5.0 BACT ANALYSIS .............................................................................................................10
6.0 REQUIREMENTS AND APPLICABILITY .........................................................................13

APPENDICES
Appendix A Notice of Intent Forms
Appendix B Regulatory Analysis
Appendix C Emissions Calculations
Appendix D Impacts Analyses
Appendix E Gas and Liquid Analyses
Appendix F Graphics: Area Map, Process Flow Diagram
Appendix G Supporting Documents

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 2
1.0 INTRODUCTION
1.1 PROJECT OVERVIEW
Ovintiv USA Inc. (“Ovintiv”) owns and operates the Ranch Compressor Station in Duchesne
County, Utah. The site is an existing natural gas compression station that consists of separators,
compressor engines, an emergency generator engine, a glycol dehydration unit, combined
condensate and produced water storage tanks, a hydrogen sulfide (“H2S”) removal unit, a process
flare, a utility flare, a Joules Thompson (“JT”) processing skid, a pressurized natural gas liquid
(“NGL”) storage tank, and condensate, produced water, and NGL loadouts.

The purpose of this submittal is to authorize the following revisions to the existing Approval Order
(“AO”), DAQE# AN143380008-23:

 Addition of two (2) compressor engines - (EPN: ENG-05 and ENG-06);
 Addition of one (1) condensate/produced water storage tank – 16,800 gallons (EPN:
TANK-04); and
 Replacement of existing equipment Process Flare (EPN: FLR-01) with a different model
to remain Process Flare (EPN: FLR-01).
1.1.1 Compressor Engines
The addition of two compressor engines (EPN: ENG-05 and ENG-06) will provide the
compression capacity needed for this facility to operate at its design capacity of 30 MMSCF/day.
All existing equipment is currently authorized for this capacity. Compressor engines are added
as needed and equipment specific data that is required for the permit application, such as
manufacture date and horsepower rating, becomes available.
1.1.2 Storage Tank
The addition of a fourth storage tank (EPN: TANK-04) is to ensure adequate storage capacity of
condensate and produced water between loadouts. The currently authorized condensate
throughput of 120,450 bbls/yr and produced water throughput of 120,450 bbls/yr will not change
and remains representative of site operations; this throughput is divided equally amongst the
storage tanks.
1.1.3 Process Flare
The Process Flare (EPN: FLR-01) is being upgraded to different model to ensure continued
reliability. The new model is a Steffes SAA-2 Air Assist Flare and meets all flare performance
requirements. There is a slight change to emissions due to a different flare pilot rating.

The documentation included in this submittal demonstrates compliance with applicable state and
federal standards.
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 3
1.2 SITE LOCATION
The Ranch Compressor Station is located in Duchesne County, approximately 6 miles southeast
of Duchesne City, Utah. An area map that shows the location of the Ranch Compressor Station
is included in Appendix F.

Latitude / Longitude: 40.130557, -110.296621
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 4
2.0 SITE PROCESS INFORMATION
2.1 PROCESS DESCRIPTION
The Ranch Compressor Station receives natural gas from offsite well pads via flowlines. The
natural gas stream is sent to an inlet separator and then to six compressors driven by natural gas-
fired compressor engines (EPN: ENG-01 through ENG-06). The high-pressure gas is then routed
to a coalescing filter, a H2S removal unit (a closed vessel with no associated emissions), and a
particulate filter before being sent to a glycol dehydration unit (EPN: DEHY-01, HTR-01).
Emissions from the glycol separator and the condenser are routed to the process flare (EPN:
FLR-01). A portion of dry gas from the glycol dehydration unit is routed to the JT processing skid
to be used as fuel gas that may be used on-site or transferred offsite by a pipeline. NGL from the
JT processing skid is transferred to a pressurized NGL storage vessel. Vapor from the NGL
storage tank is routed back to the inlet separator, and the NGL is transferred offsite via a
pressurized truck (EPN: NGL-LOAD). Gas from the inlet separator may be routed to a utility flare
(EPN: FLR-02). During compressor engine downtime for routine maintenance, gas from
compressor blowdowns is routed to the utility flare (EPN: FLR-02).

Condensate and produced water from the inlet separator are routed to four (4) 400-bbl combined
condensate/produced water storage tanks (EPN: TANK-01 through TANK-04). Condensate is
loaded into trucks for transport off-site (EPN: LOAD-1). Produced water is piped off-site using an
electric transfer pump or may be loaded into trucks for transport off-site (EPN: LOAD-1). A vapor
capture line is used during condensate truck loading such that loading vapors are routed to the
process flare (EPN: FLR-01).

Other sources of emissions include piping fugitive emissions (EPN: FUG-1), an emergency
generator engine (EPN: GENENG-01), and emissions from planned MSS activities, which are
detailed in Section 2.3.

See Appendix F for a simplified process flow diagram.

2.2 EMISSION CONTROLS
Vapors from the condensate and produced water storage tanks (EPN: TANK-01 through TANK-
04) are routed to the process flare (EPN: FLR-01) with 98% control efficiency. Emissions from the
tanks are calculated assuming all tank vapors are routed to the process flare for the entire year.

Vapors from condensate truck loadout (EPN: LOAD-1) are controlled by the process flare (EPN:
FLR-01) with 98% control efficiency. The tank trucks are not leak tested based on EPA standards;
therefore, a vapor capture/collection efficiency of 70% was used in the emission calculations.

Glycol separator and condenser vapors from the dehydration unit (EPN: DEHY-01) are routed to
the process flare (EPN: FLR-01) with 98% control efficiency.

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 5
Produced gas may be routed to the utility flare (EPN: FLR-02) with 98% control efficiency during
compressor downtime, routine maintenance, and midstream facility downtime. Gas from
compressor blowdowns (EPN: COMP-MSS) is routed to the utility flare (EPN: FLR-02) with 98%
control efficiency.

Each compressor engine (EPN: ENG-01 through ENG-06) is equipped with an air-to-fuel ratio
controller (“AFRC”) and a selective oxidation catalyst to reduce CO and VOC (including HCHO)
emissions.

The performance specification sheets for the equipment that is being modified or added as part
of this application (ENG-05, ENG-06, and FLR-01) are attached in Appendix G.

2.3 PLANNED MAINTENANCE, STARTUP, AND SHUTDOWN ACTIVITIES
This application includes estimated emission rates from planned MSS activities at this site. Annual
frequencies of planned MSS activities represented in this submittal are intended to be potential-
to-emit/worst case scenarios. The actual annual frequency of each activity necessary to maintain
good working order of facilities/equipment may vary. Emission calculations from the following
planned MSS activities are included in this submittal:
 Compressors Blowdowns/Startups (EPN: COMP-MSS/FLR-02);
 Tank venting during site shutdown (EPN: TANK-MSS).
2.4 OPERATING SCHEDULE
The facility operational schedule is 24 hours per day, 7 days per week, 52 weeks per year.

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 6
3.0 EMISSIONS DATA
3.1 EMISSION SOURCES
Emission sources for the Ranch Compressor Station are shown in this section. Emission rates
are based on an annual average daily produced throughput of 30 MMscf natural gas, 330 bbls of
condensate, 330 bbls of produced water, and 405 bbl NGL. The condensate and produced water
are combined into the storage tanks. Emissions calculations for these sources are in Appendix C.

Summary of Emission Sources and Calculation Methods
Source EPN Calculation Method
Fugitive Emissions FUG-1
Protocol for Equipment Leak
Emission Estimates, EPA-453/R95-
017, November 1995
Compressor Engines
Caterpillar G3516LE
Caterpillar G3516LE
Caterpillar G3516LE
Caterpillar G3606
Caterpillar G3606
Caterpillar G3516B
ENG-01
ENG-02
ENG-03
ENG-04
ENG-05
ENG-06
EPA AP-42 Chapter 3, NSPS JJJJ
Emission Factors, Manufacturer
data (representative), and Material
Balance for SO2 Emergency Generator Engine
Ford 6.8L V10 GENENG-01
1.0 MMBtu/hr Glycol Reboiler HTR-01
Dehydration Unit (condenser and
glycol separator) DEHY-01 ProMax v6.0, EPA AP-42 Flare
Factors
Truck Loading LOAD-1 EPA AP-42 Chapter 5
Pressurized NGL loading NGL-LOAD Ideal Gas Law
Process Flare FLR-01 EPA AP-42 Chapter 13 Flare
Factors, and Material Balance for
VOC and SO2 Utility Flare FLR-02
Storage Tanks
TANK-01
TANK-02
TANK-03
TANK-04
ProMax v6.0 and GOR Method for
flash calculation, EPA AP-42
Chapter 7 for breathing and working
calculation
Planned MSS Activities –
Compressor Blowdown COMP-MSS EPA AP-42 Flare Factors, Material
Balance for VOC and SO2
Planned MSS Activities – Tank
Venting During Site Shutdown Tank-MSS EPA AP-42 Chapter 7

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 7
3.2 ANALYSES
Emissions are based on site-specific gas and liquid analyses from facility inlet separator (see
Appendix E). Flash, gas, and liquid compositions were obtained from ProMax modeling using the
below gas and liquid analyses.
Summary of Gas and Liquid Analyses
Sample
Type Sample Location / Sample Date Equipment / Process Calculated
Gas Ranch – Facility Inlet Separator –
08/31/2022 Input to ProMax Model of the site.
Liquid Ranch – Facility Inlet Separator –
08/31/2022 Input to ProMax Model of the site.

3.3 MODELED ANALYSES
The process model ProMax v6.0 was used to model the compositions listed in the table below for
use in the emission calculations. The model was used to obtain stream compositions and gas-to-
oil ratios (“GOR”) of streams shown in the table below and to evaluate mass emissions from the
glycol separator and condenser. The inlet gas and liquid analyses (from laboratory samples listed
in the section above) are used as inputs to the ProMax model. H2S concentrations in other
streams throughout the process were simulated in ProMax based on the inlet H2S concentration
and dependent on changes in pressure, temperature, and chemical affinity. The calculation
method for each source is detailed in Section 3.1. The model reports are in Appendix G.

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 8
Summary of ProMax Model Stream Applications
Type ProMax Model
Process Stream Equipment / Process Calculated
Gas Inlet-Gas
Fugitive emissions – Gas components
Flare emissions – various streams
Compressor Blowdowns
Fuel Gas1 Fuel Flare pilot emissions
Emissions from combustion sources
Oil/Condensate Tank-Oil Fugitive emissions – Liquid components
Oil/Condensate B/W
Vapor2
Vapor in equilibrium
with liquid ProMax
Stream: Tank-Oil
Breathing/Working emissions –
Condensate/produced water storage tanks
Tank venting during site shutdown
Condensate and produced water loading
emissions
Oil/Condensate
Flash Tank-Flash Flash emissions – Condensate/produced water
storage tanks

1 Conservatively assumed H2S content of fuel gas after sweetening is 24 ppmv.
2 The composition of the vapor in equilibrium with the modeled Tank-Oil at the maximum bulk liquid
temperature was calculated based on the vapor pressure of each component of the liquid mixture. This
composition was used to estimate storage tanks breathing/working emissions and loading emissions. The
calculation method for this composition is documented in Appendix E.
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 9
4.0 IMPACTS EVALUATION
4.1 DISPERSION MODELING
The increase of the total controlled emission rate for NOx, CO, PM 10, PM2.5 and SO2 are less than
the emission increases specified in Table 1 of R307-410-4; therefore, dispersion modeling using
SCREEN3 of criteria pollutant impacts is not provided with application (available upon request).

An impact analysis has been conducted per R307-410-5 for each equipment at the facility due to
increases in emissions of hazardous air pollutants (“HAP”). As demonstrated in Attachment D,
the proposed maximum pound per hour emissions of all HAPs, except for formaldehyde, acrolein,
and n-hexane at the compressor engines (EPN: ENG-01 to ENG-06) and the utility flare (EPN:
FLR-02) are less than the emission threshold values; therefore, no further impacts evaluation was
performed for these HAPs.

SCREEN3 was performed to compare the estimated ambient concentration of the formaldehyde,
acrolein, and n-hexane hourly emissions of the compressor engines (EPN: ENG-01 to ENG-06)
and the utility flare (EPN: FLR-02) with their respective toxic screening levels. Dispersion
modeling results show that the estimated ambient concentrations are less than the toxic screening
levels. A summary of the impacts evaluation and supporting documentation is provided in
Appendix D.

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 10
5.0 BACT ANALYSIS
The following BACT analysis was conducted on new and modified emission units with an increase
in emissions.

BACT Analysis for Natural Gas-Fired Engines
Ovintiv is adding two (2) compressor engines: one (1) 4-stroke lean burn Caterpillar G3606
compressor engine rated at 1,900 hp and one (1) 4-stroke lean burn Caterpillar G3516B
compressor engine rated at 1,380 hp.

a. NOX
Considering technical, economic, energy, and environmental impacts, the proposed BACT
for nitrogen oxides (“NOX”) control for this project is the Caterpillar® Advanced Digital
Engine Management (ADEMTM) electronic control system. ADEMTM is an advanced
engine control module (ECM) that integrates engine sensing/monitoring, air/fuel ratio
control (AFRC), ignition timing, and detonation control into one comprehensive engine
control system. This control system allows the engine to achieve a NO X emission rate of
0.5 g/hp-hr.

Non-selective catalytic reduction (NSCR), a post-combustion control technique that is
used to reduce NOX, was reviewed for this specific project, however NSCR is best suited
for rich burn engines and is considered technologically infeasible for a lean burn engine.

These particular Caterpillar® lean-burn engines were selected due to Ovintiv’s experience
with their reliability and dependability over other rich-burn engines. Engine reliability and
uptime should be considered an important emission reduction strategy for a gas
compression application because any gas that cannot be compressed and sold would
otherwise flare during the engine downtime. Further these are similar engines as the
existing engines at this site. Introducing an entirely different engine and manufacturer
(e.g., rich-burn vs. lean-burn) may compromise existing maintenance and operation
practices, and spare parts program.

Selective catalytic reduction (SCR), a post-combustion control technique, was reviewed
and considered for this specific project but ultimately determined to be not economically
feasible for these engines. To complete the BACT analysis for this project recent reliable,
comparable, comprehensive and detailed cost data that is publicly available was reviewed.
This includes the estimated purchase cost for an SCR system and the estimated other
direct and indirect costs, such as installation, maintenance, operating, utility, reducing
agent consumption, and catalyst replacement costs in combination with the additional NO X
reduction. A detailed SCR cost analysis for the BACT determination for similar engines
was recently performed by the Pennsylvania Department of Environmental Protection
(PADEP). The analysis can be found in the Technical Support Document (TSD) for
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 11
PADEP’s General Operating Permit for Natural Gas Compressor Stations3. Based on the
detailed PADEP TSD SCR cost analysis found in “Table 21 – Revised SCR Cost
Analyses” on page 68 of the TSD (see Appendix G – Supporting Documents), the SCR
system annualized cost per ton NOX removed for a 1,380 hp engine with a NOX rating of
0.5 g/hp-hr is in the range of $12,185 to $26,902. Similarly, the SCR system annualized
cost per ton NOX removed for a 1,775 hp engine with a NOX rating of 0.5 g/hp-hr is in the
range of $13,337 to $25,230. (The 1,775 hp engine was chosen because this is simply a
slightly older model of the Caterpillar G3606 1,900 hp model chosen for this project, and
the next engine size with available data is 4,735 hp). Based on this, SCR was determined
to be not economically feasible for these engines.

b. CO, VOC, HCHO

The engines will be equipped with a selective catalytic oxidation (“SCO”) system to reduce
carbon monoxide (“CO”) and volatile organic compounds (“VOC”) including formaldehyde
(“HCHO) emissions. SCO is a post-combustion add-on control technology that utilizes a
catalyst to oxidize and lower emissions on lean burn engines. The catalyst units will in
installed in the engine exhaust piping, allowing the exhaust to pass over the catalyst bed
where the oxidation reaction occurs.

c. Particulate (PM10/PM2.5)
The combustion of natural gas in the engines will result in minor PM10/PM2.5 emissions.
NSPS 40 CFR 60 Subpart JJJJ does not set PM emission limits for these types of engines.

Available control options for PM emissions include conducting proper maintenance and
good combustion practices. Ovintiv has a scheduled maintenance program for these
engines and conducts annual NSPS JJJJ stack testing.

d. Sulfur Dioxide (SO2)
Sulfur dioxide emissions are a result of sulfur present in natural gas. The only control
option identified for reducing SO2 is the use of good combustion practices. Ovintiv has a
scheduled maintenance program for these engines and conducts annual NSPS JJJJ
stack testing.

e. Fuel Gas
Field gas used for these engines is conditioned through a series of processes before being
used as fuel gas. Field gas is routed through a coalescing filter, a H2S removal unit, a
particulate filter, a glycol dehydration unit, and a Joules Thompson process skid to remove
impurities such as water vapor and H2S. Fuel conditioning helps enhance the performance
of the engines and reduce emissions.

3 Commonwealth of Pennsylvania, Bureau or Air Quality, Pennsylvania Department of
Environmental Protection, Technical Support Document for the…General Operating Permit for
Natural Gas Compressor Stations, Final, June 2018.
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 12
BACT Analysis for Condensate/Produced Water Storage Tanks
Ovintiv is adding one (1) 16,800 gallon combination condensate/produced water storage tank and
revising the total condensate and produced water throughputs to the tanks. The increase in
throughput and the addition of tanks result in an increase in VOC emissions.

For the storage tanks, the control technologies that were evaluated include a vapor recovery
system, submerged filling of tanks, and flaring. A vapor recovery system is not a feasible control
technology for these tanks due to the 16 oz. tank design. The storage tanks are submerged filled
to reduce working losses. Flaring is an effective and feasible control technology for these storage
tanks. Emissions from these storage tanks are routed to the process flare with 98% control
efficiency.

Additional control technology for the storage tanks includes good operating practices and
maintenance. Ovintiv will conduct proper maintenance and operating practices on these tanks.
Thief hatches on the storage tanks shall be kept closed and latched except during vessel
unloading or other maintenance activities. Closed vent systems including vessel openings,
thief hatches, and bypass devices, for defects that can result in air emissions are inspected
regularly.
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC. 13

6.0 REQUIREMENTS AND APPLICABILITY
The Ranch Compressor Station satisfies the requirements of Rule R307-401, Rule R307-503
through Rule R307-510, all other provisions of Title R307, and the applicable federal requirements
as described in Appendix B.

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX A
APPLICATION FORMS

Form 1 Date __________________
Notice of Intent (NOI) Application Checklist
Company __________________
Utah Division of Air Quality
New Source Review Section
Source Identification Information [R307-401-5]
1. Company name, mailing address, physical address and telephone number
2. Company contact (Name, mailing address, and telephone number)
3. Name and contact of person submitting NOI application (if different than 2)
4. Source Universal Transverse Mercator (UTM) coordinates
5. Source Standard Industrial Classification (SIC) code
6. Area designation (attainment, maintenance, or nonattainment)
7. Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.)
8. Source size determination (Major, Minor, PSD)
9. Current Approval Order(s) and/or Title V Permit numbers
NOI Application Information:[R307-401]
N/A
N/A
A. Air quality analysis (air model, met data, background data, source impact analysis) N/A
Detailed description of the project and source process
Discussion of fuels, raw materials, and products consumed/produced
Description of equipment used in the process and operating schedule
Description of changes to the process, production rates, etc.
Site plan of source with building dimensions, stack parameters, etc.
Best Available Control Technology (BACT) Analysis [R307-401-8]
BACT analysis for all new and modified equipment
Emissions Related Information: [R307-401-2(b)]
Emission calculations for each new/modified unit and site-wide
(Include PM10, PM2.5, NOx, SO2, CO, VOCs, HAPs, and GHGs)
References/assumptions, SDS, for each calculation and pollutant
All speciated HAP emissions (list in lbs/hr)
Emissions Impact Analysis – Approved Modeling Protocol [R307-410]
Composition and physical characteristics of effluent
(emission rates, temperature, volume, pollutant types and concentrations)
Nonattainment/Maintenance Areas – Major NSR/Minor (offsetting only) [R307-403]
NAAQS demonstration, Lowest Achievable Emission Rate, Offset requirements
Alternative site analysis, Major source ownership compliance certification
Major Sources in Attainment or Unclassified Areas (PSD) [R307-405, R307-406]
Visibility impact analysis, Class I area impact N/A
Note: The Division of Air Quality will not accept documents containing confidential information or data.
Documents containing confidential information will be returned to the Source submitting the application.
□ □
□
✔
Form 2 Date 1/16/2024
Company Information/Notice of Intent (NOI)
Utah Division of Air Quality
New Source Review Section
Application for: Initial Approval Order Approval Order Modification

General Owner and Source Information
1.Company name and mailing address:
Ovintiv USA Inc.
370 17th St, Suite 1700
Denver, CO 80202
Phone No.: ((303)) 623-2300
Fax No.: ( )
2. Company** contact for environmental matters:
Brandon Lithgoe

Phone no.: [phone]
Email: [e-mail]

** Company contact only; consultant or independent contractor contact
information can be provided in a cover letter
3. Source name and physical address (if different from
above): Ranch Compressor Station

Phone no.: ( ) Fax no.: ( )
4. Source Property Universal Transverse Mercator
coordinates (UTM), including System and Datum:
UTM: 12
X: 559,926m Easting (NAD83)
Y: 4,442,485m Northing
5. The Source is located in: Duchesne County 6. Standard Industrial Classification Code (SIC) 1311
7. If request for modification, AO# to be modified: DAQE # AN143380008-23 DATED: 9 / 20 / 2023
8. Brief (50 words or less) description of process.
Natural Gas Compressor Station
Electronic NOI
9. A complete and accurate electronic NOI submitted to DAQ Permitting Mangers Jon Black ([e-mail]) or Alan
Humpherys ([e-mail]) can expedite review process. Please mark application type.
Hard Copy Submittal Electronic Copy Submittal ✔ Both
Authorization/Signature
I hereby certify that the information and data submitted in and with this application is completely true, accurate and
complete, based on reasonable inquiry made by me and to the best of my knowledge and belief.
Signature: Title: Senior Air Quality Engineer

Brandon Lithgoe
Name (Type or print)
Telephone Number:
[phone]
Email:
[e-mail]
Date:

1 of 1
1/30/2024
Page 1 of 1
Form 4 Company____________________________
Project Information Site ______________________________
Utah Division of Air Quality
New Source Review Section
Process Data - For Modification/Amendment ONLY
1. Permit Number_______________________________
If submitting a new permit, then use Form 3
Requested Changes
2. Name of process to be modified/added:
_______________________________
End product of this process:
_______________________________
3. Permit Change Type: New Increase*
Equipment
Process
Condition Change ____________________
Other ______________________________
Other ______________________________
Other ______________________________
4. Does new emission unit affect existing
permitted process limits?
Yes No
5. Condition(s) Changing:
6. Description of Permit/Process Change**
7. New or modified materials and quantities used in process. **
Material Quantity Annually
8. New or modified process emitting units **
Emitting Unit(s)Capacity(s)Manufacture Date(s)
*If the permit being modified does not include CO2e or PM2.5, the emissions need to be calculated and submitted to DAQ, which may result in an
emissions increase and a public comment period.
**If additional space is required, please generate a document to accommodate and attach to form.
TBD (New)
6/20/2012
TBD (New)
1,900 hp
1,380 hp
400 bbl
Page 1 of 1
Company___________________________
_____________________________
Form
Emissions Information
Criteria/GHGs/
Utah Division of Air Quality
New Source Review Section
Potential to Emit* Criteria Pollutants & GHGs
Criteria Pollutants Permitted Emissions
(tons/yr)
Emissions Increases
(tons/yr)
Proposed Emissions
(tons/yr)
PM10 Total
PM10 Fugitive
PM2.5
NOx
SO2
CO
VOC
VOC Fugitive
NH3
Greenhouse Gases CO2e CO2e CO2e
CO2
CH4
N2O
HFCs
PFCs
SF6
Total CO2e
*Potential to emit to include pollution control equipment as defined by R307-401-2.
Hazardous Air Pollutants**(**Defined in Section 112(b) of the Clean Air Act )
Hazardous Air
Pollutant***
Permitted Emissions
(tons/yr)
Emission Increase
(tons/yr)
Proposed
Emission (tons/yr)
Emission Increase
(lbs/hr)
Total HAP
*** Use additional sheets for pollutants if needed
Utah Division of Air Quality
New Source Review Section
Form 11
Company
Site/Source
Date /12/2024
Internal Combustion Engines
Equipment Information
1. Manufacturer: _______________________
Model no.: ___
The date the engine was constructed or________________
reconstructed ________________
2. Operating time of Emission Source:
maximum average
___Hours/day
Days/eek
____Weeks/year
___ Hours/day
Days/week
___ Weeks/year
Kw 3. Manufacturer's rated output at baseload, ISO hp or
Proposed site operating range _________________________hp or Kw
Gas Firing
4. Are you operating site equipment on pipeline quality natural gas: Yes No
5. Are you on an interruptible gas supply:
Yes No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
________________________ MMSCF/Year
7. Maximum firing rate:
_________________________ BTU/hr
8. Average firing rate:
________________________BTU/hr
Oil Firing
9. Type of oil:
Grade number 1 2 4 5 6 Other specify ___________
10. Annual consumption: ______________ gallons 11. Heat content:___________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight 13. Ash content: ____________% by weight
14. Average firing rate: gal/hr 15. Maximum firing rate: gal/hr
16. Direction of firing: horizontal tangential other: (specify)
Page 1 of 4
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o
n
s

p
e
r

y
e
a
r

(
T
/
Y
)

i
s

a
n
n
u
a
l

m
a
x
i
m
u
m

e
m
i
s
s
i
o
n

r
a
t
e

e
x
p
e
c
t
e
d

b
y

a
p
p
l
i
c
a
n
t
,

w
h
i
c
h

t
a
k
e
s

i
n
t
o

a
c
c
o
u
n
t

p
r
o
c
e
s
s

o
p
e
r
a
t
i
n
g

s
c
h
e
d
u
l
e
.
6.

A
s

a

m
i
n
i
m
u
m

a
p
p
l
i
c
a
n
t

m
u
s
t

f
u
r
n
i
s
h

a

f
a
c
i
l
i
t
y

p
l
o
t

p
l
a
n

d
r
a
w
n

t
o

s
c
a
l
e

s
h
o
w
i
n
g

a

p
l
a
n
t

b
e
n
c
h
m
a
r
k
,

l
a
t
i
t
u
d
e

a
n
d

l
o
n
g
i
t
u
d
e

c
o
r
r
e
c
t

t
o

t
h
e

n
e
a
r
e
s
t

s
e
c
o
n
d
f
o
r

t
h
e

b
e
n
c
h
m
a
r
k
,

a
n
d

a
l
l

e
m
i
s
s
i
o
n

p
o
i
n
t
s

d
i
m
e
n
s
i
o
n
e
d

wi
t
h

r
e
s
p
e
c
t

t
o

t
h
e

b
e
n
c
h
m
a
r
k
.

P
l
e
a
s
e

s
h
o
w

e
m
i
s
s
i
o
n

p
o
i
n
t

U
T
M

c
o
o
r
d
i
n
a
t
e
s

i
f

k
n
o
w
n
.
7.

S
u
p
p
l
y

a
d
d
i
t
i
o
n
a
l

i
n
f
o
r
m
a
t
i
o
n

a
s

f
o
l
l
o
w
s

i
f

a
p
p
r
o
p
r
i
a
t
e
:
(a
)

S
t
a
c
k

e
x
i
t

c
o
n
f
i
g
u
r
a
t
i
o
n

o
t
h
e
r

t
h
a
n

a

r
o
u
n
d

v
e
r
t
i
c
a
l

s
t
a
c
k
.

S
h
o
w

l
e
n
g
t
h

a
n
d

w
i
d
t
h

f
o
r

a

r
e
c
t
a
n
g
u
l
a
r

s
t
a
c
k
.

I
n
d
i
c
a
t
e

i
f

h
o
r
i
z
o
n
t
a
l

d
i
s
c
h
a
r
g
e

w
i
t
h

a

n
o
t
e
.
(b
)

S
t
a
c
k
'
s

h
e
i
g
h
t

a
b
o
v
e

s
u
p
p
o
r
t
i
n
g

o
r

a
d
j
a
c
e
n
t

s
t
r
u
c
t
u
r
e
s

i
f

s
t
r
u
c
t
u
r
e

i
s

w
i
t
h
i
n

t
h
r
e
e

"
s
t
a
c
k

h
e
i
g
h
t
s

a
b
o
v
e

g
r
o
u
n
d
"

o
f

s
t
a
c
k
.
Utah Division of Air Quality
New Source Review Section
Form 11
Company
Site/Source
Date
Internal Combustion Engines
Equipment Information
2. Operating time of Emission Source:
maximum average
___Hours/day
Days/eek
____Weeks/year
___ Hours/day
Days/week
___ Weeks/year
Kw3. Manufacturer's rated output at baseload, ISO hp or
Proposed site operating range _________________________hp or Kw
Gas Firing
4. Are you operating site equipment on pipeline quality natural gas: Yes No
5. Are you on an interruptible gas supply:
Yes No
If "yes", specify alternate fuel:
_______________________________
6. Annual consumption of fuel:
________________________ MMSCF/Year
7. Maximum firing rate:
_________________________ BTU/hr
8. Average firing rate:
________________________BTU/hr
Oil Firing
9. Type of oil:
Grade number 1 2 4 5 6 Other specify ___________
10. Annual consumption: ______________ gallons 11. Heat content:___________ BTU/lb or
______________ BTU/gal
12. Sulfur content:___________% by weight 13. Ash content: ____________% by weight
14. Average firing rate: gal/hr 15. Maximum firing rate: gal/hr
16. Direction of firing: horizontal tangential other: (specify)
Page 1 of 4
6/20/2012
1. Manufacturer: _______________________
Model no.: ___B
Pa
g
e

4

o
f

4
IN
T
E
R
N
A
L

C
O
M
B
U
S
T
I
O
N

E
N
G
I
N
E

FO
R
M

1
1

(
c
o
n
t
i
n
u
e
d
)

EM
I
S
S
I
O
N

S
O
U
R
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S

Re
v
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e
w

o
f

a
p
p
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s

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n
d

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s
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f

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w
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b
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s
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p
p
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g

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n
f
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m
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n

r
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d

o
n

t
h
i
s

f
o
r
m
.

AI
R

C
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N
T
A
M
I
N
A
N
T

D
A
T
A

E
M
I
S
S
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O
N

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N
T

D
I
S
C
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A
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E

P
A
R
A
M
E
T
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S

ST
A
C
K

S
O
U
R
C
E
S

(
7
)

EM
I
S
S
I
O
N

P
O
I
N
T

(1
)

CH
E
M
I
C
A
L

C
O
M
P
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I
T
I
O
N

OF

T
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L

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T
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A
M

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R

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N
T
A
M
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A
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T

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I
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I
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A
T
E

UT
M

C
O
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R
D
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N
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T
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S

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F

E
M
I
S
S
I
O
N

P
T
.

(
6
)

EX
I
T

D
A
T
A

NU
M
B
E
R

N
A
M
E

CO
M
P
O
N
E
N
T

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R

A
I
R

CO
N
T
A
M
I
N
A
N
T

N
A
M
E

(2
)

CO
N
C
.

(%
V
)

(
3
)

LB
/
H
R

(4
)

TO
N
S
/
Y
R

(5
)

ZO
N
E

E
A
S
T

(M
E
T
E
R
S
)

NO
R
T
H

(M
E
T
E
R
S
)

H
E
I
G
H
T

AB
O
V
E

GR
O
U
N
D

(F
T
)

HE
I
G
H
T

AB
O
V
E

ST
R
U
C
T
.

(F
T
)

DI
A
.

(F
T
)

VE
L
O
.

(F
P
S
)

TE
M
P
.

(OF)

GR
O
U
N
D

E
L
E
V
A
T
I
O
N

O
F

F
A
C
I
L
I
T
Y

A
B
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E

M
E
A
N

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E
A

L
E
V
E
L

_
_
_
_
_
_
_
_
_
_
_
_
_
_
_

f
e
e
t
.

UT
A
H

A
I
R

C
O
N
S
E
R
V
A
T
I
O
N

B
O
A
R
D

S
T
A
N
D
A
R
D

C
O
N
D
I
T
I
O
N
S

A
R
E

6
8
O F

A
N
D

1
4
.
7

P
S
I
A
.

Ge
n
e
r
a
l

I
n
s
t
r
u
c
t
i
o
n
s

f
o
r

t
h
i
s

f
o
r
m
.

1.

I
d
e
n
t
i
f
y

e
a
c
h

e
m
i
s
s
i
o
n
;

p
o
i
n
t

w
i
t
h

a

u
n
i
q
u
e

n
u
m
b
e
r

f
o
r

t
h
i
s

p
l
a
n
t

s
i
t
e

o
n

p
l
o
t

p
l
a
n
,

p
r
e
v
i
o
u
s

p
e
r
m
i
t
s

a
n
d

e
m
i
s
s
i
o
n

i
n
v
e
n
t
o
r
y

q
u
e
s
t
i
o
n
n
a
i
r
e
.

L
i
m
i
t

e
m
i
s
s
i
o
n

p
o
i
n
t

n
u
m
b
e
r

t
o

8

c
h
a
r
a
c
t
e
r

s
p
a
c
e
s
.

F
o
r

e
a
c
h
em
i
s
s
i
o
n

p
o
i
n
t

u
s
e

a
s

m
a
n
y

l
i
n
e
s

a
s

n
e
c
e
s
s
a
r
y

t
o

l
i
s
t

a
i
r

c
o
n
t
a
m
i
n
a
n
t

d
a
t
a
.

T
y
p
i
c
a
l

e
m
i
s
s
i
o
n

p
o
i
n
t

n
a
m
e
s

a
r
e
:

h
e
a
t
e
r
,

v
e
n
t
,

b
o
i
l
e
r
,

t
a
n
k
,

r
e
a
c
t
o
r
,

s
e
p
a
r
a
t
o
r
,

b
a
g
h
o
u
s
e
,

f
u
g
i
t
i
v
e
,

e
t
c
.

A
b
b
r
e
v
i
a
t
i
o
n
s

a
r
e

O
K
.

2.

T
y
p
i
c
a
l

c
o
m
p
o
n
e
n
t

n
a
m
e
s

a
r
e
:

a
i
r
,

H
2O,

n
i
t
r
o
g
e
n
,

o
x
y
g
e
n
,

C
O
2,
C
O
,

N
O
x,
S
O
x,
h
e
x
a
n
e
,

p
a
r
t
i
c
u
l
a
t
e

m
a
t
t
e
r

(
P
M
10

an
d

P
M
2.
5
),

e
t
c
.

A
b
b
r
e
v
i
a
t
i
o
n
s

a
r
e

O
K
.
3.

C
o
n
c
e
n
t
r
a
t
i
o
n

d
a
t
a

i
s

r
e
q
u
i
r
e
d

f
o
r

a
l
l

g
a
s
e
o
u
s

c
o
m
p
o
n
e
n
t
s
.

S
h
o
w

c
o
n
c
e
n
t
r
a
t
i
o
n

i
n

v
o
l
u
m
e

p
e
r
c
e
n
t

o
f

t
o
t
a
l

g
a
s

s
t
r
e
a
m
.
4.

P
o
u
n
d
s

p
e
r

h
o
u
r
.

(
#
/
h
r
)

i
s

m
a
x
i
m
u
m

e
m
i
s
s
i
o
n

r
a
t
e

e
x
p
e
c
t
e
d

b
y

a
p
p
l
i
c
a
n
t
.
5.

T
o
n
s

p
e
r

y
e
a
r

(
T
/
Y
)

i
s

a
n
n
u
a
l

m
a
x
i
m
u
m

e
m
i
s
s
i
o
n

r
a
t
e

e
x
p
e
c
t
e
d

b
y

a
p
p
l
i
c
a
n
t
,

w
h
i
c
h

t
a
k
e
s

i
n
t
o

a
c
c
o
u
n
t

p
r
o
c
e
s
s

o
p
e
r
a
t
i
n
g

s
c
h
e
d
u
l
e
.
6.

A
s

a

m
i
n
i
m
u
m

a
p
p
l
i
c
a
n
t

m
u
s
t

f
u
r
n
i
s
h

a

f
a
c
i
l
i
t
y

p
l
o
t

p
l
a
n

d
r
a
w
n

t
o

s
c
a
l
e

s
h
o
w
i
n
g

a

p
l
a
n
t

b
e
n
c
h
m
a
r
k
,

l
a
t
i
t
u
d
e

a
n
d

l
o
n
g
i
t
u
d
e

c
o
r
r
e
c
t

t
o

t
h
e

n
e
a
r
e
s
t

s
e
c
o
n
d
f
o
r

t
h
e

b
e
n
c
h
m
a
r
k
,

a
n
d

a
l
l

e
m
i
s
s
i
o
n

p
o
i
n
t
s

d
i
m
e
n
s
i
o
n
e
d

wi
t
h

r
e
s
p
e
c
t

t
o

t
h
e

b
e
n
c
h
m
a
r
k
.

P
l
e
a
s
e

s
h
o
w

e
m
i
s
s
i
o
n

p
o
i
n
t

U
T
M

c
o
o
r
d
i
n
a
t
e
s

i
f

k
n
o
w
n
.
7.

S
u
p
p
l
y

a
d
d
i
t
i
o
n
a
l

i
n
f
o
r
m
a
t
i
o
n

a
s

f
o
l
l
o
w
s

i
f

a
p
p
r
o
p
r
i
a
t
e
:
(a
)

S
t
a
c
k

e
x
i
t

c
o
n
f
i
g
u
r
a
t
i
o
n

o
t
h
e
r

t
h
a
n

a

r
o
u
n
d

v
e
r
t
i
c
a
l

s
t
a
c
k
.

S
h
o
w

l
e
n
g
t
h

a
n
d

w
i
d
t
h

f
o
r

a

r
e
c
t
a
n
g
u
l
a
r

s
t
a
c
k
.

I
n
d
i
c
a
t
e

i
f

h
o
r
i
z
o
n
t
a
l

d
i
s
c
h
a
r
g
e

w
i
t
h

a

n
o
t
e
.
(b
)

S
t
a
c
k
'
s

h
e
i
g
h
t

a
b
o
v
e

s
u
p
p
o
r
t
i
n
g

o
r

a
d
j
a
c
e
n
t

s
t
r
u
c
t
u
r
e
s

i
f

s
t
r
u
c
t
u
r
e

i
s

w
i
t
h
i
n

t
h
r
e
e

"
s
t
a
c
k

h
e
i
g
h
t
s

a
b
o
v
e

g
r
o
u
n
d
"

o
f

s
t
a
c
k
.
DIA.(FT) VELO.
(FPS)
TEMP. (oF)
FUG-1 Fugitives VOC 5.50 24.10 12
ENG-01 Compressor Engine VOC 1.24 5.45 12 559,902 4,442,431 52
ENG-02 Compressor Engine VOC 1.24 5.45 12 559,916 4,442,431 52
ENG-03 Compressor Engine VOC 1.24 5.45 12 559,931 4,442,432 52
ENG-04 Compressor Engine VOC 2.35 10.28 12 559,946 4,442,440 52
ENG-05 Compressor Engine VOC 1.51 6.60 12 559,960 4,442,440 52
ENG-06 Compressor Engine VOC 1.10 4.80 12 559,976 4,442,440 52
GENENG-01 Generator Engine VOC 0.14 0.01 12 559,886 4,442,468 6.7
HTR-01 Dehy Reboiler VOC 0.01 0.02 12 559,938 4,442,507 15
DEHY-01 TEG Dehydrator VOC 0.81 3.56 12 559,938 4,442,507 20
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks VOC 0.38 0.66 12 559,884 4,442,560 20
NGL-LOAD Pressurized NGL Loading VOC 0.81 0.30 12 559,877 4,442,574 10
LOAD-1
Condensate and Produced Water
Loading VOC 4.00 0.72 12 559,879 4,442,563 10
FLR-02 Utility Flare Pilot VOC 168.11 18.22 12 560,028 4,442,582 60
FLR-01 Process Flare Pilot VOC 0.00 0.02 12 559,950 4,442,578 12.4
COMP-MSS Compressor Blowdowns/Startups VOC 8.07 0.25 12 559,916 4,442,431 10
Tank-MSS Tank Venting During Site Shutdown VOC 12.58 0.45 12 559,884 4,442,560 20
* See "Controlled Criteria Pollutants Emissions Summary" page for the remaining air contaminants and emission rates.
** All stacks are round vertical stack.
CONC.
(%V)
LB/HR
Form 11 - Attachment
EXIT DATA**TONS/YR ZONE EAST
(METERS)
NORTH
(METERS)
HEIGHT ABOVE
GROUND (FT)
HEIGHT
ABOVE
STRUCT.
(FT)
EMISSION POINT CHEMICAL COMPOSITION OF AIR CONTAMINANT UTM COORDINATES OF EMISSION STACK SOURCES
NUMBER NAME COMPONENT OR
AIR CONTAMINANT
NAME *
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX B
REGULATORY ANALYSIS
FEDERAL REQUIREMENTS AND APPLICABILITY

This section presents a review of the federal air quality regulations that apply to operations as of January
2024 at the Ranch Compressor Station.

Subpart Description Applicability
40 CFR 60
Subpart A
General Provisions:
§60.18 – General control
device and work practice
requirements
The flares at this site are designed to operate in
accordance with the requirements of this subpart.
40 CFR 60
Subpart Dc
Standards of Performance
for Small Industrial-
Commercial-Institutional
Steam Generating Units
The maximum design heat input capacity of each
external combustion unit operating at this site is less
than 100 MMBtu/hr; therefore, this subpart does not
apply.
40 CFR 60
Subpart K
Standards of Performance
for Storage Vessels for
Petroleum Liquids for Which
Construction,
Reconstruction, or
Modification Commenced
After June 11, 1973, and
Prior to May 19, 1978
The storage tanks at the site commenced construction
after May 19, 1978; therefore, this subpart does not
apply.
40 CFR 60
Subpart Ka
Standards of Performance
for Storage Vessels for
Petroleum Liquids for Which
Construction,
Reconstruction, or
Modification Commenced
After May 18, 1978 and Prior
to July 23, 1984
The storage tanks at the site commenced construction
after July 23, 1984; therefore, this subpart does not
apply.
40 CFR 60
Subpart Kb
Standards of Performance
for Storage Vessels for
Petroleum Liquids for Which
Construction,
Reconstruction, or
Modification Commenced
After July 23, 1984
The storage tanks at the site each have a storage
capacity less than 1,589.874 cubic meters (m3);
therefore, this subpart does not apply per
§60.110b(d)(4).
Subpart Description Applicability
40 CFR 60
Subpart
KKK
Standards of Performance
for Equipment Leaks of VOC
From Onshore Natural Gas
Processing Plants for Which
Construction,
Reconstruction, or
Modification Commenced
After January 20, 1984, and
on or Before August 23,
2011.
This site does not meet the definition of natural gas
processing plant as defined in 40 CFR §60.631;
therefore, this subpart does not apply.
40 CFR 60
Subpart
LLL
Standards of Performance
for SO2 Emissions From
Onshore Natural Gas
Processing for Which
Construction,
Reconstruction, or
Modification Commenced
After January 20, 1984, and
on or Before August 23, 2011
This site does not operate an affected facility under this
subpart; therefore, this subpart does not apply.
40 CFR 60
Subpart IIII
Standards of Performance
for Stationary Compression
Ignition Internal Combustion
Engine
This site does not operate an affected facility under this
subpart; therefore, this subpart does not apply.
40 CFR 60
Subpart
JJJJ
Standards of Performance
for Stationary Spark Ignition
Internal Combustion Engines
The following stationary spark-ignited internal
combustion engines at the site are non-emergency, ≥
500 hp and were manufactured on or after July 1, 2007:
ENG- 04, ENG-05, ENG-06; therefore, they are subject to
this subpart per 60.4230(a)(4)(i). The engines will meet
the applicable requirements of this subpart.
40 CFR 60
Subpart
JJJJ
Standards of Performance
for Stationary Spark Ignition
Internal Combustion Engines
The following stationary spark-ignited internal
combustion engines at the site are non-emergency, lean-
burn, ≥ 500 hp, <1,350 hp and were manufactured on or
after January 1, 2008: ENG-01, ENG-02, ENG-03;
therefore, they are subject to this subpart per
60.4230(a)(4)(ii). The engines will meet the applicable
requirements of this subpart.
Subpart Description Applicability
40 CFR 60
Subpart
JJJJ
Standards of Performance
for Stationary Spark Ignition
Internal Combustion Engines
The following stationary spark-ignited internal
combustion engine at the site is emergency, > 25 hp and
was manufactured on or after January 1, 2009: GENENG-
01; therefore, it is subject to this subpart per
60.4230(a)(4)(iv). The engine will meet the applicable
requirements of this subpart.
40 CFR 60
Subpart
OOOO
Standards of Performance
for Crude Oil and Natural
Gas Production,
Transmission and
Distribution for which
Construction, Modification or
Reconstruction Commenced
after August 23, 2011, and
on or before September 18,
2015
The site has potentially affected facilities, which
commenced construction after August 23, 2011 and
before September 18, 2015, subject to the applicable
provisions of this subpart per §60.5365. Ovintiv will
comply with applicable requirements within the required
timeframes outlined in this subpart. See “Additional
Information” provided below.
40 CFR 60
Subpart
OOOOa
Standards of Performance
for Crude Oil and Natural
Gas Facilities for which
Construction, Modification or
Reconstruction Commenced
After September 18, 2015
The site has potentially affected facilities, which
commenced construction after September 18, 2015,
subject to the applicable provisions of this subpart per
§60.5365a. Ovintiv will comply with applicable
requirements within the required timeframes outlined in
this subpart. See “Additional Information” provided
below.
40 CFR 60
Subpart
OOOOb
Standards of Performance
for Crude Oil and Natural
Gas Facilities for which
Construction, Modification or
Reconstruction Commenced
After December 6, 2022
(per pre-published version
of the final rule released by
EPA on 11/30/2023)
The site has potentially affected facilities, which
commenced construction after December 6, 2022,
subject to the applicable provisions of this subpart per
§60.5365b. Ovintiv will comply with applicable
requirements within the required timeframes outlined in
this subpart. See “Additional Information” provided
below.
40 CFR 61
Subpart V
National Emission Standards
for Equipment Leaks
(Fugitive Emission Sources)
No sources at this site will operate in volatile hazardous
air pollutant (VHAP) service as defined in §61.241 of this
subpart.
Subpart Description Applicability
40 CFR 63
Subpart HH
National Emission Standards
for Hazardous Air Pollutants
From Oil and Natural Gas
Production Facilities
This site is an OGS located at an area source of HAP
emissions and operates a TEG dehydration unit (FIN:
DEHY-01) which is an affected source. This unit is
exempt from the requirements of paragraph §63.764(d)
per §63.764(e)(ii) as actual benzene emissions as
determined with federally enforceable controls are less
than 1 tpy. The dehydration unit will comply with this
subpart by meeting the recordkeeping requirements of
§63.774(d)(1).
40 CFR 63
Subpart
ZZZZ
National Emission Standards
for Hazardous Air Pollutants
for Stationary Reciprocating
Internal Combustion Engines
The following engines at the site are new stationary
RICE located at an area source of HAPs: ENG-01, ENG-
02, ENG-03, ENG-04, ENG-05, ENG-06, GENENG-01. Per
§63.6590, the engines will meet the requirements of this
subpart by meeting the requirements of 40 CFR Part 60,
Subpart JJJJ, as applicable.

Additional Information

NSPS OOOO applies to affected sources that commenced construction after August 23, 2011, and on
or before September 18, 2015. Potentially affected sources under this subpart include the storage
vessels and compressors located at the Ranch Compressor Station. TANK-01, TANK-02, and the
reciprocating compressors associated with compressor engines ENG-01 - ENG-03 commenced
construction before August 23, 2011, therefore are not subject to NSPS OOOO. TANK-03 and TANK-
04, and the reciprocating compressors associated with compressor engines ENG-04, ENG-05, and
ENG-06, commenced construction after September 18, 2015, therefore are not subject to NSPS
OOOO.

NSPS OOOOa applies to affected sources that commenced construction, modification, or
reconstruction after September 18, 2015. Potentially affected sources under this subpart include the
storage vessels, compressors, and fugitive emission components (as defined in § 60.5430a) at the
Ranch Compressor Station. TANK-01, TANK-02, and the reciprocating compressors associated with
compressor engines ENG-01 - ENG-03 commenced construction before September 18, 2015,
therefore are not subject to NSPS OOOOa.

NSPS OOOOb applies to affected sources that commenced construction, modification, or
reconstruction after December 6, 2022. Potentially affected sources under this subpart include the
storage vessels, compressors, and fugitive emission components (as defined in § 60.5430b) at the
Ranch Compressor Station. TANK-01, TANK-02, and the reciprocating compressors associated with
the compressor engines ENG-01 – ENG-03 commenced construction before December 6, 2022,
therefore are not subject to NSPS OOOOb. TANK-03 and TANK-04 will commence construction after
December 6, 2022 and therefore be subject to NSPS OOOOb (which will also include any existing
tanks that are connected to the same tank battery as TANK-03 and TANK-04). The reciprocating
compressors associated with compressor engine ENG-05 and ENG-06 commenced construction after
December 6, 2022 and Ovintiv will comply with all applicable requirements for these compressor
affected facilities.

The Ranch Compressor Station can be classified as a compressor station (as defined in § 60.5430b)
and since it was modified (defined in § 60.5365b(j)(1) as the addition of compressors to a compressor
station) after the NSPS OOOOb applicability date (December 6, 2022), the collection of fugitive
emission components at the Ranch Compressor Station will be considered an affected facility. Ovintiv
will comply with all applicable leak detection and repair (LDAR) and audio, visual, olfactory (AVO)
requirements within the required timelines.

NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX C
EMISSIONS CALCULATIONS

OIL AND GAS FACILITY INFORMATION
Company Name Ovintiv USA Inc.
Field Name Uinta
Facility/Well Name Ranch Compressor Station
Latitude/Longitude
40.13082 / -110.29638
Section, Township, Range Section 14, T4S, R2W
County Duchesne
Authorization Type Utah AO
Source Determination Minor
Area Designation Ozone Marginal Nonattaiment
Natural Gas Site Throughput (MMSCF/day): 30.00
Produced Water Site Average Throughput (bbl/day): 330
Oil/Condensate Site Average Throughput (bbl/day): 660
H2S Concentration - Maximum Stream (PPMV):24
Is the gas sweet or sour? Sweet
Is this site operational/producing? Yes
Has the site been registered before? Yes
Are MSS emissions included in this registration? Yes
Process Description Compressor Station
EQUIPMENT/PROCESSES AT SITE HOW MANY FOR THIS PROJECT/SITE?
ICE Engines 7
Heaters-Boilers 1
Condensate/Water Tanks 4
Loading Jobs 3
Glycol Units 1
Combustion Control Devices 2
Ovintiv USA Inc.
Ranch Compressor Station
Uncontrolled Criteria Pollutants Emissions Summary
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
FUG-1 Fugitives 5.50 24.10 -- -- -- -- -- -- -- -- -- -- 2E-04 0.00 0.24 1.05 7.33 32.12 -- -- 183.56 804.00
ENG-01 Compressor Engine 2.66 11.65 2.95 12.94 10.66 46.71 0.12 0.53 0.12 0.53 0.01 0.03 -- -- 1,327.19 5,813.09 15.08 66.06 -- -- 1,704.23 7,464.54
ENG-02 Compressor Engine 2.66 11.65 2.95 12.94 10.66 46.71 0.12 0.53 0.12 0.53 0.01 0.03 -- -- 1,327.19 5,813.09 15.08 66.06 -- -- 1,704.23 7,464.54
ENG-03 Compressor Engine 2.66 11.65 2.95 12.94 10.66 46.71 0.12 0.53 0.12 0.53 0.01 0.03 -- -- 1,327.19 5,813.09 15.08 66.06 -- -- 1,704.23 7,464.54
ENG-04 Compressor Engine 5.79 25.37 1.96 8.57 10.76 47.13 0.13 0.59 0.13 0.59 0.01 0.03 -- -- 1,477.85 6,472.97 16.79 73.56 -- -- 1,897.69 8,311.88
ENG-05 Compressor Engine 2.93 12.84 2.09 9.17 8.67 37.98 0.14 0.62 0.14 0.62 0.01 0.04 -- -- 1,566.46 6,861.07 17.80 77.97 -- -- 2,011.47 8,810.24
ENG-06 Compressor Engine 2.59 11.33 1.52 6.66 6.66 29.18 0.11 0.48 0.11 0.48 0.01 0.03 -- -- 1,206.81 5,285.83 13.71 60.07 -- -- 1,549.65 6,787.48
GENENG-01 Generator Engine 0.141 0.007 0.265 0.013 0.529 0.026 0.008 4.2E-04 0.008 4.2E-04 2.6E-04 1.3E-05 -- -- 47.896 2.395 0.100 0.005 -- -- 50.400 2.520
HTR-01 Dehy Reboiler 0.01 0.02 0.10 0.43 0.08 0.36 0.01 0.03 0.01 0.03 0.00 0.02 -- -- 117.65 515.31 0.00 0.01 0.00 0.01 118.35 518.37
DEHY-01 TEG Dehydrator 46.92 205.51 -- -- -- -- -- -- -- -- -- -- -- -- 4.65 20.35 11.59 50.75 -- -- 294.30 1,289.02
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks 19.02 33.24 -- -- -- -- -- -- -- -- -- -- 6E-05 1E-04 1.01 1.37 9.17 15.48 -- -- 230.18 388.26
NGL-LOAD Pressurized NGL Loading 0.81 0.30 -- -- -- -- -- -- -- -- -- -- -- -- 0.00 0.00 0.01 0.00 -- -- 0.28 0.10
LOAD-1 Condensate and Produced
Water Loading 12.56 2.29 -- -- -- -- -- -- -- -- -- -- 3E-05 6E-06 1.27 0.23 6.87 1.25 -- -- 173.03 31.55
Utility Flare Pilot 0.02 0.07 0.01 0.03 0.03 0.14 -- -- -- -- -- -- 2E-04 0.00 0.11 0.46 3.29 14.43 -- -- 82.47 361.23
Produced Gas 8,404.83 907.72 -- -- -- -- -- -- -- -- -- -- 0.37 0.04 425.17 45.92 12,997.61 1,403.74 -- -- 325,365.53 35,139.48
Process Flare Pilot 0.00 0.02 0.00 0.01 0.01 0.03 -- -- -- -- -- -- 4E-05 2E-04 0.02 0.10 0.71 3.09 -- -- 17.67 77.38
COMP-MSS Compressor
Blowdowns/Startups 403.43 12.59 -- -- -- -- -- -- -- -- -- -- 0.02 0.00 20.41 0.64 623.89 19.47 -- -- 15,617.55 487.27
Tank Venting During Site
Shutdown 12.582 0.453 -- -- -- -- -- -- -- -- -- -- 3.5E-05 1.3E-06 1.272 0.046 6.882 0.248 -- -- 173.323 6.240
Total Emissions 8,925.11 1,270.80 14.81 63.71 58.74 254.99 0.76 3.31 0.76 3.31 0.05 0.21 0.39 0.04 8,852.38 36,647.00 13,761.01 1,950.35 <0.01 0.01 352,878.15 85,408.64
Annual Emissions
(excluding Fugitives VOC) 1,246.70 63.71 254.99 3.31 3.31 0.21 0.04 36,647.00 1,950.35 0.01 85,408.64
MAXIMUM OPERATING SCHEDULE:
[1] HAPs are included in Total VOC
SO2 CH4CO2 CO2eN2OH2S
FLR-01
PM10 PM2.5CONOx
FLR-02
EPN VOC[1]
Emission Source Name
Hours/Day 24
Tank-MSS
Title V
Applicability
Estimated
Emissions
52Weeks/Year7Days/Week
Ovintiv USA Inc.
Ranch Compressor Station
Controlled Criteria Pollutants Emissions Summary
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
FUG-1 Fugitives 5.50 24.10 -- -- -- -- -- -- -- -- -- -- 2E-04 0.00 0.24 1.05 7.33 32.12 -- -- 183.56 804.00
ENG-01 Compressor Engine 1.24 5.45 2.95 12.94 0.39 1.71 0.12 0.53 0.12 0.53 0.04 0.19 -- -- 1,327.19 5,813.09 15.08 66.06 -- -- 1,704.23 7,464.54
ENG-02 Compressor Engine 1.24 5.45 2.95 12.94 0.39 1.71 0.12 0.53 0.12 0.53 0.04 0.19 -- -- 1,327.19 5,813.09 15.08 66.06 -- -- 1,704.23 7,464.54
ENG-03 Compressor Engine 1.24 5.45 2.95 12.94 0.39 1.71 0.12 0.53 0.12 0.53 0.04 0.19 -- -- 1,327.19 5,813.09 15.08 66.06 -- -- 1,704.23 7,464.54
ENG-04 Compressor Engine 2.35 10.28 1.96 8.57 7.83 34.28 0.13 0.59 0.13 0.59 0.05 0.22 -- -- 1,477.85 6,472.97 16.79 73.56 -- -- 1,897.69 8,311.88
ENG-05 Compressor Engine 1.51 6.60 2.09 9.17 1.05 4.59 0.14 0.62 0.14 0.62 0.05 0.23 -- -- 1,566.46 6,861.07 17.80 77.97 -- -- 2,011.47 8,810.24
ENG-06 Compressor Engine 1.10 4.80 1.52 6.66 0.76 3.33 0.11 0.48 0.11 0.48 0.04 0.18 -- -- 1,206.81 5,285.83 13.71 60.07 -- -- 1,549.65 6,787.48
GENENG-01 Generator Engine 0.14 0.01 0.370 0.019 0.635 0.032 0.008 4.2E-04 0.008 4.2E-04 0.002 8.0E-05 -- -- 47.896 2.395 0.100 0.005 -- -- 50.400 2.520
HTR-01 Dehy Reboiler 0.01 0.02 0.10 0.43 0.08 0.36 0.01 0.03 0.01 0.03 0.00 0.02 -- -- 117.65 515.31 0.00 0.01 0.00 0.01 118.35 518.37
DEHY-01 TEG Dehydrator 0.81 3.56 0.09 0.38 0.40 1.73 -- -- -- -- -- -- -- -- 186.78 818.08 0.23 1.01 0.00 0.01 193.41 847.13
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks 0.38 0.66 0.05 0.08 0.22 0.38 -- -- -- -- 1E-04 2E-04 1E-06 2E-06 100.82 173.58 0.18 0.31 0.00 0.00 105.87 182.13
NGL-LOAD Pressurized NGL Loading 0.81 0.30 -- -- -- -- -- -- -- -- -- -- -- -- 0.00 0.00 0.01 0.00 -- -- 0.28 0.10
LOAD-1 Condensate and Produced
Water Loading 4.00 0.72 0.02 0.00 0.11 0.02 -- -- -- -- 5E-05 8E-06 3E-05 6E-06 49.43 9.05 2.19 0.40 0.00 1E-04 104.37 18.97
Utility Flare Pilot 0.02 0.07 0.01 0.03 0.03 0.14 -- -- -- -- 4E-04 0.00 4E-06 2E-05 13.85 60.67 0.07 0.29 2E-04 0.00 15.57 68.20
Produced Gas 168.10 18.15 35.84 3.87 163.41 17.65 -- -- -- -- 0.69 0.07 0.01 0.00 70,946.72 7,662.25 259.95 28.07 1.16 0.13 77,791.84 8,401.52
Process Flare Pilot 0.00 0.02 0.00 0.01 0.01 0.03 -- -- -- -- 8E-05 4E-04 9E-07 4E-06 2.97 13.00 0.01 0.06 5E-05 2E-04 3.34 14.61
COMP-MSS Compressor
Blowdowns/Startups 8.07 0.25 1.72 0.05 7.84 0.24 -- -- -- -- 0.03 0.00 4E-04 1E-05 3,405.44 106.25 12.48 0.39 0.06 0.00 3,734.01 116.50
Tank Venting During Site
Shutdown 12.58 0.45 -- -- -- -- -- -- -- -- -- -- 3E-05 1E-06 1.27 0.05 6.88 0.25 -- -- 173.32 6.24
Total Emissions 209.10 86.35 52.64 68.10 183.54 67.91 0.76 3.31 0.76 3.31 1.01 1.30 0.01 <0.01 83,105.75 45,420.83 383.00 472.68 1.23 0.15 93,045.83 57,283.50
Annual Emissions
(excluding Fugitives VOC) 62.25 68.10 67.91 3.31 3.31 1.30 <0.01 45,420.83 472.68 0.15 57,283.50
MAXIMUM OPERATING SCHEDULE:
[1] HAPs are included in Total VOC
FLR-02
Tank-MSS
Title V
Applicability
Estimated
Emissions
FLR-01
24 Weeks/YearDays/WeekHours/Day 527
CO PM10 PM2.5EPN Emission Source Name
VOC[1]NOx SO2 CO2 CH4 N2O CO2eH2S
Ovintiv USA Inc.
Ranch Compressor Station
Uncontrolled Hazardous Air Pollutants Emissions Summary
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
FUG-1 Fugitives 0.44 1.91 2E-04 0.00 0.02 0.10 0.05 0.22 0.00 0.01 0.03 0.15 -- -- -- -- -- -- -- -- 0.55 2.40
ENG-01 Compressor Engine 0.01 0.06 0.00 0.01 0.01 0.02 0.00 0.02 5E-04 0.00 0.00 0.01 1.24 5.43 0.06 0.27 0.10 0.44 0.03 0.13 1.47 6.46
ENG-02 Compressor Engine 0.01 0.06 0.00 0.01 0.01 0.02 0.00 0.02 5E-04 0.00 0.00 0.01 1.24 5.43 0.06 0.27 0.10 0.44 0.03 0.13 1.47 6.46
ENG-03 Compressor Engine 0.01 0.06 0.00 0.01 0.01 0.02 0.00 0.02 5E-04 0.00 0.00 0.01 1.24 5.43 0.06 0.27 0.10 0.44 0.03 0.13 1.47 6.46
ENG-04 Compressor Engine 0.01 0.07 0.00 0.01 0.01 0.03 0.01 0.02 0.00 0.00 0.00 0.01 1.02 4.46 0.07 0.30 0.11 0.49 0.03 0.15 1.28 5.60
ENG-05 Compressor Engine 0.02 0.07 0.00 0.02 0.01 0.03 0.01 0.03 0.00 0.00 0.00 0.01 0.63 2.75 0.07 0.32 0.12 0.52 0.04 0.16 0.90 3.96
ENG-06 Compressor Engine 0.01 0.05 0.00 0.01 0.00 0.02 0.00 0.02 4E-04 0.00 0.00 0.01 1.28 5.60 0.06 0.25 0.09 0.40 0.03 0.12 1.49 6.53
GENENG-01 Generator Engine -- -- -- -- 0.001 3.4E-05 2.4E-04 1.2E-05 1.3E-05 6.5E-07 8.7E-05 4.4E-06 0.009 4.5E-04 0.001 5.7E-05 0.001 6.1E-05 0.001 6.7E-05 0.014 0.001
HTR-01 Dehy Reboiler 0.00 0.01 -- -- 2E-06 9E-06 3E-06 1E-05 -- -- -- -- 7E-05 3E-04 -- -- -- -- -- -- 0.00 0.01
DEHY-01 TEG Dehydrator 2.77 12.11 0.00 0.00 4.98 21.81 2.20 9.62 0.01 0.04 0.07 0.29 -- -- -- -- -- -- -- -- 10.02 43.87
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks 1.80 3.12 0.00 0.00 0.08 0.15 0.15 0.27 0.01 0.01 0.05 0.09 -- -- -- -- -- -- -- -- 2.08 3.63
NGL-LOAD Pressurized NGL Loading 0.07 0.02 9E-06 3E-06 0.00 0.00 0.00 3E-04 3E-06 9E-07 2E-05 7E-06 -- -- -- -- -- -- -- -- 0.07 0.03
LOAD-1 Condensate and Produced
Water Loading 1.23 0.23 0.00 1E-04 0.04 0.01 0.08 0.02 0.00 0.00 0.02 0.00 -- -- -- -- -- -- -- -- 1.38 0.25
Utility Flare Pilot 0.00 0.01 1E-07 5E-07 2E-04 0.00 1E-05 5E-05 8E-09 4E-08 6E-08 2E-07 -- -- -- -- -- -- -- -- 0.00 0.01
Produced Gas 684.32 73.91 0.12 0.01 36.81 3.98 61.02 6.59 2.58 0.28 25.80 2.79 -- -- -- -- -- -- -- -- 810.64 87.55
Process Flare Pilot 0.00 0.00 3E-08 1E-07 3E-05 2E-04 2E-06 1E-05 2E-09 8E-09 1E-08 5E-08 -- -- -- -- -- -- -- -- 0.00 0.00
COMP-MSS Compressor
Blowdowns/Startups 32.85 1.02 0.01 2E-04 1.77 0.06 2.93 0.09 0.12 0.00 1.24 0.04 -- -- -- -- -- -- -- -- 38.91 1.21
Tank Venting During Site
Shutdown 1.24 0.04 0.00 3E-05 0.04 0.00 0.08 0.00 0.00 1E-04 0.02 0.00 -- -- -- -- -- -- -- -- 1.39 0.05
Total Emissions 724.80 92.75 0.15 0.10 43.77 26.25 66.54 16.94 2.73 0.35 27.25 3.42 6.65 29.11 0.39 1.69 0.63 2.74 0.19 0.82 873.15 174.49
MAXIMUM OPERATING SCHEDULE:
FLR-02
Xylene Acrolein Acetaldehyde
EPN Emission Source Name
n-Hexane 2,2,4-TMP Benzene HAP TotalToluene Ethylbenzene Formaldehyde Methanol
FLR-01
Tank-MSS
Weeks/YearDays/WeekHours/Day 52724
Estimated
Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Controlled Hazardous Air Pollutants Emissions Summary
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
FUG-1 Fugitives 0.44 1.91 2E-04 0.00 0.02 0.10 0.05 0.22 0.00 0.01 0.03 0.15 -- -- -- -- -- -- -- -- 0.55 2.40
ENG-01 Compressor Engine 0.01 0.06 0.00 0.01 0.01 0.02 0.00 0.02 5E-04 0.00 0.00 0.01 0.41 1.81 0.06 0.27 0.10 0.44 0.03 0.13 0.64 2.79
ENG-02 Compressor Engine 0.01 0.06 0.00 0.01 0.01 0.02 0.00 0.02 5E-04 0.00 0.00 0.01 0.41 1.81 0.06 0.27 0.10 0.44 0.03 0.13 0.64 2.79
ENG-03 Compressor Engine 0.01 0.06 0.00 0.01 0.01 0.02 0.00 0.02 5E-04 0.00 0.00 0.01 0.41 1.81 0.06 0.27 0.10 0.44 0.03 0.13 0.64 2.79
ENG-04 Compressor Engine 0.01 0.07 0.00 0.01 0.01 0.03 0.01 0.02 0.00 0.00 0.00 0.01 0.39 1.71 0.07 0.30 0.11 0.49 0.03 0.15 0.64 2.80
ENG-05 Compressor Engine 0.02 0.07 0.00 0.02 0.01 0.03 0.01 0.03 0.00 0.00 0.00 0.01 0.34 1.47 0.07 0.32 0.12 0.52 0.04 0.16 0.60 2.62
ENG-06 Compressor Engine 0.01 0.05 0.00 0.01 0.00 0.02 0.00 0.02 4E-04 0.00 0.00 0.01 0.24 1.07 0.06 0.25 0.09 0.40 0.03 0.12 0.45 1.95
GENENG-01 Generator Engine -- -- -- -- 0.001 3.4E-05 2.4E-04 1.2E-05 1.3E-05 6.5E-07 8.7E-05 4.4E-06 0.009 4.5E-04 0.001 5.7E-05 0.001 6.1E-05 0.001 6.7E-05 0.014 0.001
HTR-01 Dehy Reboiler 0.00 0.01 -- -- 2E-06 9E-06 3E-06 1E-05 -- -- -- -- 7E-05 3E-04 -- -- -- -- -- -- 0.00 0.01
DEHY-01 TEG Dehydrator 0.04 0.19 7E-06 3E-05 0.06 0.28 0.02 0.07 2E-05 1E-04 2E-04 0.00 -- -- -- -- -- -- -- -- 0.12 0.55
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks 0.04 0.06 2E-05 4E-05 0.00 0.00 0.00 0.01 1E-04 2E-04 0.00 0.00 -- -- -- -- -- -- -- -- 0.04 0.07
NGL-LOAD Pressurized NGL Loading 0.07 0.02 9E-06 3E-06 0.00 0.00 0.00 3E-04 3E-06 9E-07 2E-05 7E-06 -- -- -- -- -- -- -- -- 0.07 0.03
LOAD-1 Condensate and Produced
Water Loading 0.39 0.07 2E-04 4E-05 0.01 0.00 0.03 0.00 0.00 2E-04 0.01 0.00 -- -- -- -- -- -- -- -- 0.44 0.08
Utility Flare Pilot 5E-05 2E-04 2E-09 1E-08 3E-06 1E-05 2E-07 9E-07 2E-10 7E-10 1E-09 5E-09 -- -- -- -- -- -- -- -- 6E-05 3E-04
Produced Gas 13.69 1.48 0.00 3E-04 0.74 0.08 1.22 0.13 0.05 0.01 0.52 0.06 -- -- -- -- -- -- -- -- 16.21 1.75
Process Flare Pilot 1E-05 5E-05 5E-10 2E-09 7E-07 3E-06 5E-08 2E-07 4E-11 2E-10 2E-10 1E-09 -- -- -- -- -- -- -- -- 1E-05 5E-05
COMP-MSS Compressor
Blowdowns/Startups 0.66 0.02 1E-04 4E-06 0.04 0.00 0.06 0.00 0.00 8E-05 0.02 0.00 -- -- -- -- -- -- -- -- 0.78 0.02
Tank Venting During Site
Shutdown 1.24 0.04 0.00 3E-05 0.04 0.00 0.08 0.00 0.00 1E-04 0.02 0.00 -- -- -- -- -- -- -- -- 1.39 0.05
Total Emissions 16.64 4.18 0.02 0.08 0.95 0.62 1.49 0.57 0.06 0.03 0.62 0.27 2.22 9.68 0.39 1.69 0.63 2.74 0.19 0.82 23.21 20.68
MAXIMUM OPERATING SCHEDULE:
FLR-02
Xylene Acrolein Acetaldehyde
EPN Emission Source Name
n-Hexane 2,2,4-TMP Benzene HAP TotalToluene Ethylbenzene Formaldehyde Methanol
FLR-01
Tank-MSS
Weeks/YearDays/WeekHours/Day 52724
Estimated
Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Fugitives Emission Calculations
EPN FUG-1
Source Name Fugitives
Description Units Gas Service Liquid Service
TOC wt% 97.86% 99.99%
VOC wt% 32.80% 99.82%
n-Hexane wt% 2.67% 6.58%
2,2,4-Trimethylpentane wt% 0.00% 0.01%
Benzene wt% 0.14% 0.34%
Toluene wt% 0.24% 2.11%
Ethylbenzene wt% 0.01% 0.22%
Xylene wt% 0.10% 2.49%
H2S wt% 0.00% 0.00%
CO2 wt% 1.66% 0.01%
CH4 wt% 50.72% 0.03%
Valve - 1102 113
Connector - 3174 184
Flange - 0 226
Open-ended Line - 130 0
Pressure Relief Valve - 64 0
Emission Factor Source - Table 2-4 Table 2-4
Valve lb TOC/hr/component 9.92E-03 5.51E-03
Connector lb TOC/hr/component 4.41E-04 4.63E-04
Flange lb TOC/hr/component 8.60E-04 2.43E-04
Open-ended Line lb TOC/hr/component 4.41E-03 3.09E-03
Pressure Relief Valve lb TOC/hr/component 1.94E-02 1.65E-02
TOTAL
lb/hr tpy
TOC 14.15 61.96 0.76 3.34 14.91 65.30
VOC 4.74 20.77 0.76 3.33 5.50 24.10
n-Hexane 0.39 1.69 0.05 0.22 0.44 1.91
2,2,4-Trimethylpentane 6.7E-05 2.9E-04 8.6E-05 3.8E-04 1.5E-04 6.7E-04
Benzene 0.02 0.09 2.6E-03 0.01 0.02 0.10
Toluene 0.03 0.15 0.02 0.07 0.05 0.22
Ethylbenzene 1.5E-03 0.01 1.7E-03 0.01 3.1E-03 0.01
Xylene 0.01 0.06 0.02 0.08 0.03 0.15
H2S 2.1E-04 9.1E-04 1.6E-08 7.0E-08 2.1E-04 9.1E-04
CO2 0.24 1.05 4.2E-05 1.8E-04 0.24 1.05
CH4 7.33 32.12 2.4E-04 1.1E-03 7.33 32.12
CO2e 183.55 803.97 0.01 0.03 183.56 804.00
Notes:
Example Calculation:
Gas Service:
VOC = (1102 valve * 9.92E-3 lb TOC/hr/valve + 3174 connector * 4.41E-4 lb TOC/hr/connector + 0 flange * 8.60E-4 lb
TOC/hr/flange + 130 open-ended line * 4.41E-3 lb TOC/hr/Open-ended Line+ 64 pressure relief valve * 1.94E-2 lb
TOC/hr/pressure relief valve) * 32.80 wt% VOC / 97.86 wt% TOC * 8,760 hr/yr / (2000 lb/ton) = 20.77 tpy
Stream
Composition
Emissions
Component
Counts
Component counts estimated based on 40 CFR 98 Subpart W, Table W-1C counts for Western US Onshore oil production and estimated
counts at Ovintiv sites.
Emission factors from Protocol for Equipment Leak Emission Estimates, EPA-453/R95-017, November 1995.
tpylb/hrtpylb/hr
Components
TOC Emissions
Emission Calculations
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 52.00 Field Gas
1.00 9004
991.00 1,084.51
Engine Data 8,985.00 1.48
EPN ENG-01
Source Name Compressor Engine Method of Emission Control Federal Standards Yes/No
Manufacturer Caterpillar SCO Yes
Model Number G3516LE No
Serial Number 4EK01150 Yes
Manufacture Date 10/1/2012 AFRC
Last Rebuild Date
Application Gas Compression UTM Coordinates
Horsepower: 1,340
Fuel consumption (Btu/hp-hr):9,004 Zone 12
Hours of operation per year:8,760 Easting (meters)559,901.50
Engine Type: 4 Stroke, Lean-Burn Northing (meters) 4,442,431.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%)0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) =0.044 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) =0.194
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State
emission limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 0.9 2.659 11.645 Not Applicable 0.421 g/hp-hr 1.244 5.448
VOC (NMNEHC w/o HCHO) 0.48 0.0652 1.418 6.211 0.7 0.281 g/hp-hr 0.830 3.636
NOx 1.0 4.08 2.954 12.939 1.0 1.0 g/hp-hr 2.954 12.939
CO 3.61 0.317 10.665 46.711 2.0 0.132 g/hp-hr 0.390 1.708
PM (condensable)0.00991 0.120 0.524 0.00991 lb/MMBtu 0.120 0.524
PM2.5/10 (filterable)0.0000771 0.001 0.004 0.0000771 lb/MMBtu 0.001 0.004
PMTOTAL 0.00999 0.121 0.528 0.00999 lb/MMBtu 0.121 0.528
SO2 0.000588 0.007 0.031 0.044 0.194
Formaldehyde (HCHO)0.42 0.0528 1.241 5.435 0.14 g/hp-hr 0.414 1.812
Benzene 0.000440 0.005 0.023 0.000440 lb/MMBtu 0.005 0.023
Toluene 0.000408 0.005 0.022 0.000408 lb/MMBtu 0.005 0.022
Ethylbenzene 0.000040 4.83E-04 0.002 0.000040 lb/MMBtu 4.83E-04 0.002
Xylene 0.000184 0.002 0.010 0.000184 lb/MMBtu 0.002 0.010
2,2,4-Trimethylpentane 0.000250 0.003 0.013 0.000250 lb/MMBtu 0.003 0.013
Acrolein 0.00514 0.062 0.272 0.00514 lb/MMBtu 0.062 0.272
Acetaldehyde 0.00836 0.101 0.442 0.00836 lb/MMBtu 0.101 0.442
n-Hexane 0.00111 0.013 0.059 0.00111 lb/MMBtu 0.013 0.059
Methanol 0.0025 0.030 0.132 0.0025 lb/MMBtu 0.030 0.132
Total HAPs 0.12224579 1.475 6.460 0.05271107 lb/MMBtu 0.636 2.786 --
CO2 110.00 1,327.190 5,813.090 110.00 lb/MMBtu 1,327.190 5,813.090
CH4 1.25 15.082 66.058 1.25 lb/MMBtu 15.082 66.058
CO2e 1,704.232 7,464.537 1,704.232 7,464.537 --
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Fuel Type
Heat Value (Btu/scf)
Fuel Consumption (BTU/bhp-hr)Stack diameter (feet)
Stack height (feet)
Stage Temperature (°F)
AP-42, Table 3.2-2
Catalyst controlled
Mass balance
AP-42, Table 3.2-2
AP-42, Table 3.2-2
NSPS JJJJ
Adjusted manufacturer controlled
Emission Factor SourceEmission
factor used units
AP-42, Table 3.2-2
Adjusted manufacturer controlled
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Sulfur Content (grains/100scf)
NSPS Subpart JJJJ
NSPS Subpart IIII
MACT Subpart ZZZZ
Catalyst Type
Parameter Adjustment
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 52.00 Field Gas
1.00 9004
991.00 1,084.51
Engine Data 8,985.00 1.48
EPN ENG-02
Source Name Compressor Engine Method of Emission Control Federal Standards Yes/No
Manufacturer Caterpillar SCO Yes
Model Number G3516LE No
Serial Number 4EK2548 Yes
Manufacture Date 6/2/2020 AFRC
Last Rebuild Date
Application Gas Compression UTM Coordinates
Horsepower: 1,340
Fuel consumption (Btu/hp-hr):9,004 Zone 12
Hours of operation per year:8,760 Easting (meters)559,916.00
Engine Type: 4 Stroke, Lean-Burn Northing (meters) 4,442,431.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%)0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) =0.044 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) =0.194
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State
emission limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 0.9 2.659 11.645 Not Applicable 0.421 g/hp-hr 1.244 5.448
VOC (NMNEHC w/o HCHO) 0.48 0.0652 1.418 6.211 0.7 0.281 g/hp-hr 0.830 3.636
NOx 1.0 4.08 2.954 12.939 1.0 1.0 g/hp-hr 2.954 12.939
CO 3.61 0.317 10.665 46.711 2.0 0.132 g/hp-hr 0.390 1.708
PM (condensable)0.00991 0.120 0.524 0.00991 lb/MMBtu 0.120 0.524
PM2.5/10 (filterable)0.0000771 0.001 0.004 0.0000771 lb/MMBtu 0.001 0.004
PMTOTAL 0.00999 0.121 0.528 0.00999 lb/MMBtu 0.121 0.528
SO2 0.000588 0.007 0.031 0.044 0.194
Formaldehyde (HCHO)0.42 0.0528 1.241 5.435 0.14 g/hp-hr 0.414 1.812
Benzene 0.000440 0.005 0.023 0.000440 lb/MMBtu 0.005 0.023
Toluene 0.000408 0.005 0.022 0.000408 lb/MMBtu 0.005 0.022
Ethylbenzene 0.000040 4.83E-04 0.002 0.000040 lb/MMBtu 4.83E-04 0.002
Xylene 0.000184 0.002 0.010 0.000184 lb/MMBtu 0.002 0.010
2,2,4-Trimethylpentane 0.000250 0.003 0.013 0.000250 lb/MMBtu 0.003 0.013
Acrolein 0.00514 0.062 0.272 0.00514 lb/MMBtu 0.062 0.272
Acetaldehyde 0.00836 0.101 0.442 0.00836 lb/MMBtu 0.101 0.442
n-Hexane 0.00111 0.013 0.059 0.00111 lb/MMBtu 0.013 0.059
Methanol 0.0025 0.030 0.132 0.0025 lb/MMBtu 0.030 0.132
Total HAPs 0.12224579 1.475 6.460 0.05271107 lb/MMBtu 0.636 2.786 --
CO2 110.00 1,327.190 5,813.090 110.00 lb/MMBtu 1,327.190 5,813.090
CH4 1.25 15.082 66.058 1.25 lb/MMBtu 15.082 66.058
CO2e 1,704.232 7,464.537 1,704.232 7,464.537 --
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Adjusted manufacturer controlled
NSPS JJJJ
Adjusted manufacturer controlled
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Emission
factor used units Emission Factor Source
Mass balance
Catalyst controlled
Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Catalyst Type NSPS Subpart JJJJ
Sulfur Content (grains/100scf)
MACT Subpart ZZZZ
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Parameter Adjustment NSPS Subpart IIII
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 52.00 Field Gas
1.00 9004
991.00 1,084.51
Engine Data 8,985.00 1.48
EPN ENG-03
Source Name Compressor Engine Method of Emission Control Federal Standards Yes/No
Manufacturer Caterpillar SCO Yes
Model Number G3516LE No
Serial Number 4EK02067 Yes
Manufacture Date 4/5/2013 AFRC
Last Rebuild Date
Application Gas Compression UTM Coordinates
Horsepower: 1,340
Fuel consumption (Btu/hp-hr):9,004 Zone 12
Hours of operation per year:8,760 Easting (meters)559,931.00
Engine Type: 4 Stroke, Lean-Burn Northing (meters) 4,442,432.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%)0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) =0.044 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) =0.194
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State
emission limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 0.9 2.659 11.645 Not Applicable 0.421 g/hp-hr 1.244 5.448
VOC (NMNEHC w/o HCHO) 0.48 0.0652 1.418 6.211 0.7 0.281 g/hp-hr 0.830 3.636
NOx 1.0 4.08 2.954 12.939 1.0 1.0 g/hp-hr 2.954 12.939
CO 3.61 0.317 10.665 46.711 2.0 0.132 g/hp-hr 0.390 1.708
PM (condensable)0.00991 0.120 0.524 0.00991 lb/MMBtu 0.120 0.524
PM2.5/10 (filterable)0.0000771 0.001 0.004 0.0000771 lb/MMBtu 0.001 0.004
PMTOTAL 0.00999 0.121 0.528 0.00999 lb/MMBtu 0.121 0.528
SO2 0.000588 0.007 0.031 0.044 0.194
Formaldehyde (HCHO)0.42 0.0528 1.241 5.435 0.14 g/hp-hr 0.414 1.812
Benzene 0.000440 0.005 0.023 0.000440 lb/MMBtu 0.005 0.023
Toluene 0.000408 0.005 0.022 0.000408 lb/MMBtu 0.005 0.022
Ethylbenzene 0.000040 4.83E-04 0.002 0.000040 lb/MMBtu 4.83E-04 0.002
Xylene 0.000184 0.002 0.010 0.000184 lb/MMBtu 0.002 0.010
2,2,4-Trimethylpentane 0.000250 0.003 0.013 0.000250 lb/MMBtu 0.003 0.013
Acrolein 0.00514 0.062 0.272 0.00514 lb/MMBtu 0.062 0.272
Acetaldehyde 0.00836 0.101 0.442 0.00836 lb/MMBtu 0.101 0.442
n-Hexane 0.00111 0.013 0.059 0.00111 lb/MMBtu 0.013 0.059
Methanol 0.0025 0.030 0.132 0.0025 lb/MMBtu 0.030 0.132
Total HAPs 0.12224579 1.475 6.460 0.05271107 lb/MMBtu 0.636 2.786 --
CO2 110.00 1,327.190 5,813.090 110.00 lb/MMBtu 1,327.190 5,813.090
CH4 1.25 15.082 66.058 1.25 lb/MMBtu 15.082 66.058
CO2e 1,704.232 7,464.537 1,704.232 7,464.537 --
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Adjusted manufacturer controlled
NSPS JJJJ
Adjusted manufacturer controlled
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Emission
factor used units Emission Factor Source
Mass balance
Catalyst controlled
Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Catalyst Type NSPS Subpart JJJJ
Sulfur Content (grains/100scf)
MACT Subpart ZZZZ
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Parameter Adjustment NSPS Subpart IIII
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 52.00 Field Gas
1.67 7569
835.00 1,084.51
Engine Data 11,822.00 1.48
EPN ENG-04
Source Name Compressor Engine Method of Emission Control Federal Standards Yes/No
Manufacturer Caterpillar SCO Yes
Model Number G3606A3 No
Serial Number 3XF00116 Yes
Manufacture Date 8/19/1997 AFRC
Last Rebuild Date
Application Gas Compression UTM Coordinates
Horsepower: 1,775
Fuel consumption (Btu/hp-hr):7,569 Zone 12
Hours of operation per year:8,760 Easting (meters)559,946.00
Engine Type: 4 Stroke, Lean-Burn Northing (meters) 4,442,440.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%)0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) =0.049 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) =0.217
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State
emission limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 1.48 5.792 25.367 Not Applicable 0.6 g/hp-hr 2.348 10.284
VOC (NMNEHC w/o HCHO) 1.22 0.0652 4.774 20.911 0.7 0.5 g/hp-hr 1.957 8.570
NOx 0.5 4.08 1.957 8.570 1.0 0.5 g/hp-hr 1.957 8.570
CO 2.75 0.317 10.761 47.135 2.0 2.0 g/hp-hr 7.826 34.280
PM (condensable)0.00991 0.133 0.583 0.00991 lb/MMBtu 0.133 0.583
PM2.5/10 (filterable)0.0000771 0.001 0.005 0.0000771 lb/MMBtu 0.001 0.005
PMTOTAL 0.00999 0.134 0.588 0.00999 lb/MMBtu 0.134 0.588
SO2 0.000588 0.008 0.035 0.049 0.217
Formaldehyde (HCHO)0.26 0.0528 1.017 4.456 0.1 g/hp-hr 0.391 1.714
Benzene 0.000440 0.006 0.026 0.000440 lb/MMBtu 0.006 0.026
Toluene 0.000408 0.005 0.024 0.000408 lb/MMBtu 0.005 0.024
Ethylbenzene 0.000040 0.001 0.002 0.000040 lb/MMBtu 0.001 0.002
Xylene 0.000184 0.002 0.011 0.000184 lb/MMBtu 0.002 0.011
2,2,4-Trimethylpentane 0.000250 0.003 0.015 0.000250 lb/MMBtu 0.003 0.015
Acrolein 0.00514 0.069 0.302 0.00514 lb/MMBtu 0.069 0.302
Acetaldehyde 0.00836 0.112 0.492 0.00836 lb/MMBtu 0.112 0.492
n-Hexane 0.00111 0.015 0.065 0.00111 lb/MMBtu 0.015 0.065
Methanol 0.0025 0.034 0.147 0.0025 lb/MMBtu 0.034 0.147
Total HAPs 0.09513917 1.278 5.598 0.04755915 lb/MMBtu 0.639 2.799 --
CO2 110.00 1,477.847 6,472.971 110.00 lb/MMBtu 1,477.847 6,472.971
CH4 1.25 16.794 73.556 1.25 lb/MMBtu 16.794 73.556
CO2e 1,897.690 8,311.883 1,897.690 8,311.883 --
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Catalyst controlled
Adjusted manufacturer controlled
Catalyst controlled
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Emission
factor used units Emission Factor Source
Mass balance
Catalyst controlled
Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Catalyst Type NSPS Subpart JJJJ
Sulfur Content (grains/100scf)
MACT Subpart ZZZZ
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Parameter Adjustment NSPS Subpart IIII
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 52.00 Field Gas
1.67 7495
835.00 1,084.51
Engine Data 12,021.00 1.48
EPN ENG-05
Source Name Compressor Engine Method of Emission Control Federal Standards Yes/No
Manufacturer Caterpillar SCO Yes
Model Number G3606A4 No
Serial Number TBD Yes
Manufacture Date TBD AFRC
Last Rebuild Date
Application Gas Compression UTM Coordinates
Horsepower: 1,900
Fuel consumption (Btu/hp-hr):7,495 Zone 12
Hours of operation per year:8,760 Easting (meters)559,960.00
Engine Type: 4 Stroke, Lean-Burn Northing (meters) 4,442,440.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%)0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) =0.052 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) =0.230
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State
emission limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 0.7 2.932 12.843 Not Applicable 0.36 g/hp-hr 1.508 6.605
VOC (NMNEHC w/o HCHO) 0.55 0.0652 2.304 10.091 0.7 0.28 g/hp-hr 1.173 5.137
NOx 0.5 4.08 2.094 9.173 1.0 0.5 g/hp-hr 2.094 9.173
CO 2.07 0.317 8.671 37.978 2.0 0.25 g/hp-hr 1.047 4.587
PM (condensable)0.00991 0.141 0.618 0.00991 lb/MMBtu 0.141 0.618
PM2.5/10 (filterable)0.0000771 0.001 0.005 0.0000771 lb/MMBtu 0.001 0.005
PMTOTAL 0.00999 0.142 0.623 0.00999 lb/MMBtu 0.142 0.623
SO2 0.000588 0.008 0.037 0.052 0.230
Formaldehyde (HCHO)0.15 0.0528 0.628 2.752 0.08 g/hp-hr 0.335 1.468
Benzene 0.000440 0.006 0.027 0.000440 lb/MMBtu 0.006 0.027
Toluene 0.000408 0.006 0.025 0.000408 lb/MMBtu 0.006 0.025
Ethylbenzene 0.000040 0.001 0.002 0.000040 lb/MMBtu 0.001 0.002
Xylene 0.000184 0.003 0.011 0.000184 lb/MMBtu 0.003 0.011
2,2,4-Trimethylpentane 0.000250 0.004 0.016 0.000250 lb/MMBtu 0.004 0.016
Acrolein 0.00514 0.073 0.321 0.00514 lb/MMBtu 0.073 0.321
Acetaldehyde 0.00836 0.119 0.521 0.00836 lb/MMBtu 0.119 0.521
n-Hexane 0.00111 0.016 0.069 0.00111 lb/MMBtu 0.016 0.069
Methanol 0.0025 0.036 0.156 0.0025 lb/MMBtu 0.036 0.156
Total HAPs 0.06353067 0.905 3.963 0.04196379 lb/MMBtu 0.598 2.617 --
CO2 110.00 1,566.455 6,861.073 110.00 lb/MMBtu 1,566.455 6,861.073
CH4 1.25 17.801 77.967 1.25 lb/MMBtu 17.801 77.967
CO2e 2,011.471 8,810.241 2,011.471 8,810.241 --
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Catalyst controlled
Manufacturer controlled
Catalyst controlled
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Emission
factor used units Emission Factor Source
Mass balance
Catalyst controlled
Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Catalyst Type NSPS Subpart JJJJ
Sulfur Content (grains/100scf)
MACT Subpart ZZZZ
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Parameter Adjustment NSPS Subpart IIII
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 52.00 Field Gas
1.67 7950
971.00 1,084.51
Engine Data 8,521.00 1.48
EPN ENG-06
Source Name Compressor Engine Method of Emission Control Federal Standards Yes/No
Manufacturer Caterpillar SCO Yes
Model Number G3516B No
Serial Number JEF01825 Yes
Manufacture Date 6/20/2012 AFRC
Last Rebuild Date
Application Gas Compression UTM Coordinates
Horsepower: 1,380
Fuel consumption (Btu/hp-hr):7,950 Zone 12
Hours of operation per year:8,760 Easting (meters)559,976.00
Engine Type: 4 Stroke, Lean-Burn Northing (meters) 4,442,440.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%) 0.0024
- Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) = 0.040
Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) = 0.177
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-2
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State emission
limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 0.85 2.586 11.327 Not Applicable 0.36 g/hp-hr
1.095 4.797
VOC (NMNEHC w/o HCHO) 0.43 0.0652 1.308 5.730 0.7 0.28 g/hp-hr 0.852 3.731
NOx 0.5 4.08 1.521 6.663 1.0 0.5 g/hp-hr 1.521 6.663
CO 2.19 0.317 6.663 29.183 2.0 0.25 g/hp-hr 0.761 3.331
PM (condensable)0.00991 0.109 0.476 0.00991 lb/MMBtu 0.109 0.476
PM2.5/10 (filterable)0.0000771 0.001 0.004 0.0000771 lb/MMBtu 0.001 0.004
PMTOTAL 0.00999 0.110 0.480 0.00999 lb/MMBtu 0.110 0.480
SO2 0.000588 0.006 0.028 0.040 0.177
Formaldehyde (HCHO)0.42 0.0528 1.278 5.597 0.08 g/hp-hr 0.243 1.066
Benzene 0.000440 0.005 0.021 0.000440 lb/MMBtu 0.005 0.021
Toluene 0.000408 0.004 0.020 0.000408 lb/MMBtu 0.004 0.020
Ethylbenzene 0.000040 4.39E-04 0.002 0.000040 lb/MMBtu 4.39E-04 0.002
Xylene 0.000184 0.002 0.009 0.000184 lb/MMBtu 0.002 0.009
Acrolein 0.00514 0.056 0.247 0.00514 lb/MMBtu 0.056 0.247
Acetaldehyde 0.00836 0.092 0.402 0.00836 lb/MMBtu 0.092 0.402
Methanol 0.0025 0.027 0.120 0.0025 lb/MMBtu 0.027 0.120
Total HAPs 0.13587981 1.491 6.529 0.040617 lb/MMBtu 0.446 1.952 --
CO2 110.00 1,206.810 5,285.828 110.00 lb/MMBtu 1,206.810 5,285.828
CH4 1.25 13.714 60.066 1.25 lb/MMBtu 13.714 60.066
CO2e 1,549.654 6,787.483 1,549.654 6,787.483 --
Catalyst Type NSPS Subpart JJJJ
Sulfur Content (grains/100scf)
MACT Subpart ZZZZ
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Parameter Adjustment NSPS Subpart IIII
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Emission
factor used units Emission Factor Source
Mass balance
Catalyst controlled
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Catalyst controlled
Manufacturer controlled
Catalyst controlled
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
AP-42, Table 3.2-2
AP-42, Table 3.2-2
AP-42, Table 3.2-2
Ovintiv USA Inc.
Ranch Compressor Station
Internal Combustion Engine Emissions
Site Location Discharge Parameters Fuel Data
County Duchesne 6.71 Field Gas
0.50 7257
750.00 1,084.51
Engine Data 400.00 1.48
EPN GENENG-01
ID Number 09 Method of Emission Control Federal Standards
Name Generator Engine Yes/No
Manufacturer Ford NSCR Yes
Model Number 6.8L V10 No
Serial Number L140779880 Yes
Manufacture Date 12/19/2014 AFRC
Last Rebuild Date
Application Emergency/Standby UTM Coordinates
Horsepower: 60
Fuel consumption (Btu/hp-hr):7,257 Zone 12
Hours of operation per year:100 Easting (meters)559,886.00
Engine Type: 4 Stroke, Rich-Burn Northing (meters) 4,442,468.00
SO2 Mass Balance calculation for sour gas fuel:Notes:
Hourly emission rate calculation:
Fuel Heat Value (Btu/scf)1,085 - Hourly emission rate (lb/hr) = EF (lb/MMBtu) × Fuel Consumption (Btu/hp-hr) × Engine horsepower (hp) / 1,000,000 (Btu/MMBtu)
Fuel H2S content (mol%) 0.0024 - Hourly emission rate (lb/hr) = EF (g/hp-hr) × Engine horsepower (hp) / 453.59 (g/lb)
- SO2 mass balance hourly emission rate (lb/hr) = Fuel Consumption (Btu/hp-hr) x Engine horsepower (hp) / Fuel Heat Value (Btu/scf) x Fuel H2S content (mol%) / Molar volume (scf/lb-mole) x MW SO2 (lb/lb-mole)
SO2 produced (lb/hr) = 0.002 Annual emission rate (tpy) = Hourly Emission Rate (lb/hr) × Hours of operation per year (hrs/yr) / 2,000 (lb/ton)
SO2 produced (tpy) = 0.000
AP-42 Emission factor conversion: EF (g/hp-hr) = EF (lb/MMBtu) x 453.59 (g/lb) x Fuel consumption (Btu/hp-hr) / 1,000,000 (Btu/MMBtu)
MW SO2 = 64.06 lb/lb-mole
Fuel H2S content of 24 ppm is conservatively assumed.
To Determine Emissions for Air Permitting
Manufacturer
uncontrolled
emission
factor
AP-42,
Table 3.2-3
Uncontrolled
Emissions
Uncontrolled
Emissions
Manufacturer
controlled
emission
factor
NSPS JJJJ
emission limit
State emission
limit Emissions Emissions
(g/hp-hr)(lb/MMBtu)(lb/hr)(tpy)(g/hp-hr)(g/hp-hr)(g/hp-hr)(lb/hr)(tpy)
Total VOC (NMNEHC) 0.141 0.007 Not Applicable 1.0675 g/hp-hr 0.141 0.007
VOC (NMNEHC w/o HCHO) 1.0 0.0091 0.132 0.007 1.0 g/hp-hr 0.132 0.007
NOx 2.0 2.21 0.265 0.013 2.8 2.8 g/hp-hr 0.370 0.019
CO 4.0 3.72 0.529 0.026 4.8 4.8 g/hp-hr 0.635 0.032
PM (condensable)0.00991 0.004 2.16E-04 0.00991 lb/MMBtu 0.004 2.16E-04
PM2.5/10 (filterable)0.0095 0.004 2.07E-04 0.0095 lb/MMBtu 0.004 2.07E-04
PMTOTAL 0.01941 0.008 4.23E-04 0.01941 lb/MMBtu 0.008 4.23E-04
SO2 0.000588 2.56E-04 1.28E-05 0.002 8.01E-05
Formaldehyde (HCHO)0.0205 0.009 4.46E-04 0.0675 g/hp-hr 0.009 4.46E-04
Benzene 0.00158 0.001 3.44E-05 0.00158 lb/MMBtu 0.001 3.44E-05
Toluene 0.000560 2.44E-04 1.22E-05 0.000560 lb/MMBtu 2.44E-04 1.22E-05
Ethylbenzene 0.000030 1.31E-05 6.53E-07 0.000030 lb/MMBtu 1.31E-05 6.53E-07
Xylene 0.000200 8.71E-05 4.35E-06 0.000200 lb/MMBtu 8.71E-05 4.35E-06
2,2,4-Trimethylpentane 0.000000 -- -- 0.000000 lb/MMBtu -- --
Acrolein 0.00263 0.001 5.73E-05 0.00263 lb/MMBtu 0.001 5.73E-05
Acetaldehyde 0.00279 0.001 6.07E-05 0.00279 lb/MMBtu 0.001 6.07E-05
n-Hexane 0.000000 -- -- 0.000000 lb/MMBtu -- --
Methanol 0.00306 0.001 6.66E-05 0.00306 lb/MMBtu 0.001 6.66E-05
1,3-Butadiene 0.000670 2.92E-04 1.46E-05 0.000670 lb/MMBtu 2.92E-04 1.46E-05
Total HAPs (w/o HCHO)0.01195368 0.005 2.60E-04 0.01195368 lb/MMBtu 0.005 2.60E-04
Total HAPs 0.03245368 0.014 0.001 0.03245368 lb/MMBtu 0.014 0.001 --
CO2 110.00 47.896 2.395 110.00 lb/MMBtu 47.896 2.395
CH4 0.230 0.100 0.005 0.23 lb/MMBtu 0.100 0.005
CO2e 50.400 2.520 50.400 2.520 --
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
Manufacturer uncontrolled
NSPS JJJJ
NSPS JJJJ
VOC (NMNEHC, w/o HCHO) + Formaldehyde (HCHO)
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
AP-42, Table 3.2-3
Emission
factor used units Emission Factor Source
Mass balance
AP-42, Table 3.2-3
Stack height (feet) Fuel Type
Stack diameter (feet) Fuel Consumption (BTU/bhp-hr)
Stage Temperature (°F) Heat Value (Btu/scf)
Ideal Gas Law: 385.22 scf/lb-mole
Does the Total VOC (NMNEHC)
emission factor being used below
include formaldehyde?
Yes
Catalyst Type NSPS Subpart JJJJ
Sulfur Content (grains/100scf)
MACT Subpart ZZZZ
Exhaust Flowrate (cfm)
Stratified Charge
Other (Specify)
Parameter Adjustment NSPS Subpart IIII
Ovintiv USA Inc.
Ranch Compressor Station
Glycol Dehydrator Emissions
Calculated Using Process Simulator
DEHY-01
FLR-01
FLR-01
Source Name TEG Dehydrator
TEG Dehydrator Information
Emission Calculation Method:Process Simulation
Type of Glycol Used:TEG
Annual Hours of Operation:8760
Dry Gas Flow Rate (MMSCF/day):30
Location at site where gas was sampled:Inlet Separator
Date of Sample:8/31/2022
Is sample site-specific or representative?Site-specific
Wet Gas Temperature (°F):79
Wet Gas Pressure (psig):865
Lean Glycol Flow Rate (gpm)7.5
Glycol Separator Temperature (°F)90
Glycol Separator Pressure (psig)30
Condenser Temperature (F)100
EPN
Glycol Separator Control
Regen./Condenser Control
Ovintiv USA Inc.
Ranch Compressor Station
Glycol Dehydrator Emissions
Calculated Using Process Simulator
DEHY-01
FLR-01
FLR-01
Source Name TEG Dehydrator
EPN
Glycol Separator Control
Regen./Condenser Control
Glycol Separator
lb/hr tpy
VOC 20.307 88.944
n-Hexane 0.709 3.103
2,2,4-Trimethylpentane 9.0E-05 3.9E-04
Benzene 0.072 0.317
Toluene 0.017 0.073
Ethylbenzene 3.9E-05 1.7E-04
Xylene 3.1E-04 0.001
CO2 3.195 13.993
CH4 11.209 49.095
CO2e 283.416 1,241.363
Glycol Separator emissions controlled by?Flare
Control Device DRE (%)98.0%
VOC 0.406 1.779
n-Hexane 0.014 0.062
2,2,4-Trimethylpentane 1.8E-06 7.9E-06
Benzene 0.001 0.006
Toluene 3.3E-04 0.001
Ethylbenzene 7.7E-07 3.4E-06
Xylene 6.2E-06 2.7E-05
CO2 118.724 520.012
CH4 0.224 0.982
N2O 0.002 0.008
CO2e 124.877 546.959
NOx 0.057 0.248
CO 0.259 1.132
Uncontrolled
Glycol Separator
Emissions
Controlled
Glycol Separator
Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Glycol Dehydrator Emissions
Calculated Using Process Simulator
DEHY-01
FLR-01
FLR-01
Source Name TEG Dehydrator
EPN
Glycol Separator Control
Regen./Condenser Control
Regen./Condenser Control
lb/hr tpy
VOC 26.614 116.571
n-Hexane 2.057 9.009
2,2,4-Trimethylpentane 0.001 0.003
Benzene 4.908 21.497
Toluene 2.179 9.542
Ethylbenzene 0.008 0.036
Xylene 0.067 0.292
CO2 1.451 6.355
CH4 0.377 1.652
CO2e 10.881 47.659
Regenerator emissions controlled by?Condenser
VOC 20.358 89.169
n-Hexane 1.517 6.646
2,2,4-Trimethylpentane 2.8E-04 0.001
Benzene 3.141 13.756
Toluene 0.780 3.416
Ethylbenzene 0.001 0.005
Xylene 0.010 0.042
CO2 1.446 6.335
CH4 0.377 1.651
CO2e 10.871 47.614
Condenser emissions controlled by?Flare
Control Efficiency (%)98.0%
VOC 0.407 1.783
n-Hexane 0.030 0.133
2,2,4-Trimethylpentane 5.7E-06 2.5E-05
Benzene 0.063 0.275
Toluene 0.016 0.068
Ethylbenzene 2.2E-05 9.6E-05
Xylene 1.9E-04 0.001
CO2 68.052 298.069
CH4 0.008 0.033
N2O 0.001 0.004
CO2e 68.531 300.166
NOx 0.030 0.132
CO 0.137 0.600
Controlled
Glycol Regenerator
Emissions
Uncontrolled
Glycol Regenerator
Emissions
Post-Condenser
Glycol Regenerator
Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Glycol Dehydrator Emissions
Calculated Using Process Simulator
DEHY-01
FLR-01
FLR-01
Source Name TEG Dehydrator
EPN
Glycol Separator Control
Regen./Condenser Control
Sum of Glycol Separator and Regenerator Emissions
lb/hr tpy
VOC 46.921 205.515
n-Hexane 2.765 12.112
2,2,4-Trimethylpentane 0.001 0.003
Benzene 4.980 21.814
Toluene 2.195 9.616
Ethylbenzene 0.008 0.036
Xylene 0.067 0.293
CO2 4.646 20.348
CH4 11.586 50.747
CO2e 294.297 1,289.022
VOC 0.813 3.562
n-Hexane 0.045 0.195
2,2,4-Trimethylpentane 7.5E-06 3.3E-05
Benzene 0.064 0.281
Toluene 0.016 0.070
Ethylbenzene 2.3E-05 9.9E-05
Xylene 2.0E-04 0.001
CO2 186.777 818.082
CH4 0.232 1.015
N2O 0.003 0.012
CO2e 193.408 847.125
NOx 0.087 0.380
CO 0.395 1.732
Federal Applicability
40 CFR Part 63 - Subpart HH
Example Calculation:
Controlled Glycol Separator Emission:
VOC = 20.31 lb/hr * (1 - 98%) * 8,760 hr/yr/ (2000 lb/ton) = 1.78 tpy
Uncontrolled Emissions
Controlled Emissions
All area sources, with TEG dehydration units, will have some requirements under this rule. Emission reduction requirements may apply or
only recordkeeping requirements may apply.
Is this subpart applicable?
If yes, how will compliance be achieved? If
no, please explain why.
Yes
Affected source is exempt from control requirements per 40 CFR 63.764 (e)(1)(ii);
benzene emissions are less than 0.90 Mg/yr (1.0 tpy).
Maintenance of records to support determination of exemption are required under
§63.774(d)(1)(ii).
Ovintiv USA Inc.
Ranch Compressor Station
Heaters-Boilers Emissions
Heater and Boiler Emission Calculations (fueled by natural gas)
EPN HTR-01
Source Name Dehy Reboiler
Heater/Boiler rating (MMBtu/hr): 1.000
Rating above is (select from list):below 100 MMBtu/hr, uncontrolled
Operating hours/year: 8760
Fuel Heat Value (Btu/SCF): 1,085
Pollutant Emission Factor (lb/MMBtu) lb/hr tpy
VOC 0.00539 0.005 0.024
NOx 0.098 0.098 0.429
CO 0.0824 0.082 0.361
PM total 0.00745 0.007 0.033
PM condensable 0.00559 0.006 0.024
PM filterable 0.00186 0.002 0.008
SO2 0.00368 0.004 0.016
Benzene 0.00000206 2.1E-06 9.0E-06
Toluene 0.00000333 3.3E-06 1.5E-05
n-Hexane 0.00176 0.002 0.008
Formaldehyde 0.0000735 7.4E-05 3.2E-04
Total HAPs 0.00185 0.002 0.008
CO2 117.65 117.650 515.307
Methane 0.00225 0.002 0.010
N2O 0.00216 0.002 0.009
CO2e -- 118.350 518.373
Fuel H2S content (mol %) =0.0024
SO2 produced (lb/hr) = 0.0037 SO2 MW 64.06 lb/lb-mole
SO2 produced (tpy) = 0.0161 Ideal Gas Law 385.22 SCF/lb-mole
HAPs are included in Total VOC.
Fuel H2S content of 24 ppm is conservatively assumed.
Example Calculation:
NOx = 0.098 lb/MMBtu * 1.00 MMBtu/hr *8,760 hr/yr /(2000 lb/ton) = 0.429 tpy
Emission Factors from AP-42, Chapter 1, Tables 1.4-1, 1.4-2 and 1.4-3. Modified from lb/MMCF to lb/MMBtu by
dividing by 1020 MMBtu/ MMCF (per AP-42 guidance).
SO2 Mass Balance calculation:
If the heater/boiler is fueled by Sour Gas, cannot use emission factors above to calculate SO2 emissions, must use SO2 mass balance:
(assume uncontrolled, unless specifically stated otherwise)
Enter any notes here:
Ovintiv USA Inc.
Ranch Compressor Station
Tank Emissions - AP-42
Breathing Working Losses From Storage Tanks
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
Variable Reference Hourly Annual Hourly Annual Hourly Annual Hourly Annual
EPN TANK-01 TANK-02 TANK-03 TANK-04
Tank contents Oil/Condensate Oil/Condensate Oil/Condensate Oil/Condensate
Tank Type VFR VFR VFR VFR
Roof Type Cone Cone Cone Cone
Tank Insulation Fully Insulated Fully Insulated Fully Insulated Fully Insulated
Is tank heated? No No No No
Height (VFR) / Length (HFR)HS / L ft 20 20 20 20
Diameter D ft 12 12 12 12
Average Liquid Height HL ft 10 10 10 10
Maximum Liquid Height HLX Eq. 7.1-37 ft 19 19 19 19
Tank Capacity TCG bbl 400 400 400 400
Throughput Q gal 2,310 2,529,450 2,310 2,529,450 2,310 2,529,450 2,310 2,529,450
Annual Liquid Level Increases ΣHQI Eq. 7.1-37 ft/yr - 2,989 - 2,989 - 2,989 - 2,989
Turnovers N Eq. 7.1-36 - 166.08 - 166.08 - 166.08 - 166.08
Tank Shell Radius RS ft 6 6.00 6 6
Cone Roof Height HR Eq. 7.1-18 ft 0.38 0.38 0.38 0.38
Cone Roof Outage HRO Eq. 7.1-17 ft 0.13 0.13 0.13 0.13
Vapor Space Outage HVO Eq. 7.1-16 ft 10.13 10.13 10.13 10.13
Breather Vent Vacuum Setting psig -0.03 -0.03 -0.03 -0.03
Breather Vent Pressure Setting psig 0.03 0.03 0.03 0.03
Breather Vent Pressure Range ΔPB Eq. 7.1-10 psi 0.06 0.06 0.06 0.06
Surface Color-Shade Tan Tan Tan Tan
Reflective Condition Average Average Average Average
Paint Solar Absorptance α Tbl 7.1-6 0.49 0.49 0.49 0.49
Meteorological data city* Salt Lake City, UT Salt Lake City, UT Salt Lake City, UT Salt Lake City, UT
Daily Total Solar Insolation Factor I Tbl 7.1-7 Btu/ft2-d 2,338 1,442 2338.00 1442 2338.00 1442 2,338 1,442
Atmospheric Pressure PA Tbl 7.1-7 psia 12.62 12.62 12.62 12.62 12.62 12.62 12.62 12.62
Daily Maximum Ambient Temperature TAX Tbl 7.1-7 °R 552.07 522.97 552.07 522.97 552.07 522.97 552.07 522.97
Daily Minimum Ambient Temperature TAN Tbl 7.1-7 °R 526.07 502.57 526.07 503 526.07 503 526.07 502.57
Daily Ambient Temp. Change ΔTA Eq. 7.1-11 °R 26.00 20.40 26.00 20.40 26.00 20.40 26.00 20.40
Daily Avg. Ambient Temperature TAA Eq. 7.1-30 °R 539.07 512.77 539.07 512.77 539.07 512.77 539.07 512.77
Liquid Bulk Temperature TB Eq. 7.1-31 °R 542.51 514.89 542.51 514.89 542.51 514.89 542.51 514.89
Daily Vapor Temperature Range ΔTV Eq. 7.1-6 °R 39.83 28.30 39.83 28.30 39.83 28.30 39.83 28.30
Annual Average Vapor Temperature TV Eq. 7.1-33 °R 550.41 519.77 550.41 519.77 550.41 519.77 550.41 519.77
Daily Avg. Liquid Surface Temperature TLA Eq. 7.1-27 °R 545.43 516.69 545.43 516.69 545.43 516.69 545.43 516.69
Daily Max. Avg. Liq. Surf. Temp.TLX Fig. 7.1-17 °R 555.38 523.76 555.38 523.76 555.38 523.765 555.38 523.76
Daily Min. Avg. Liq. Surf. Temp.TLN Fig. 7.1-17 °R 535.47 509.62 535.47 509.62 535.47 509.615 535.47 509.62
Product Type Crude Crude Crude Crude
RVP 6.40 6.40 6.40 6.40
Constant A Fig. 7.1-15,16 11.02 11.02 11.02 11.02
Constant B Fig. 7.1-15,16 °R 5003.46 5003.46 5003.46 5003.46
Vapor Molecular Wt. MV lb/lb-mole 31.33 31.33 31.33 31.33
True Vapor Pressure @ TLA PVA Eq. 7.1-25 psia 6.37 3.82 6.37 3.82 6.37 3.82 6.37 3.82
True Vapor Pressure @ TLX PVX Eq. 7.1-25 psia 7.50 4.36 7.50 4.36 7.50 4.36 7.50 4.36
True Vapor Pressure @ TLN PVN Eq. 7.1-25 psia 5.37 3.34 5.37 3.34 5.37 3.34 5.37 3.34
Daily Vapor Pressure Range ΔPV Eq. 7.1-9 psia 2.14 1.01 2.14 1.01 2.14 1.01 2.14 1.01
Vapor Space Expansion Factor KE Eq. 7.1-5,12 /day 0.40 0.16 0.40 0.16 0.40 0.16 0.40 0.16
Vented Vapor Saturation Factor KS Eq. 7.1-21 0.23 0.33 0.23 0.33 0.23 0.33 0.23 0.33
Working Loss Product Factor KP Eq. 7.1-37 0.75 0.75 0.75 0.75
Turnover Factor KN Eq. 7.1-35 - 1.00 - 1.00 - 1.00 - 1.00
Net Working Loss Throughput VQ Eq. 7.1-39 ft3 - 338,103 - 338,103 - 338,103 - 338,103
Vapor Space Volume VV Eq. 7.1-3 ft3 1145.11 1145.11 1145.11 1145.11
Vapor Density WV Eq. 7.1-22 lb/ft3 0.03 0.02 0.03 0.02 0.03 0.02 0.03 0.02
Units
AP-42
Variable
Parameter Name
Ovintiv USA Inc.
Ranch Compressor Station
Tank Emissions - AP-42
Breathing Working Losses From Storage Tanks
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
Variable Reference Hourly Annual Hourly Annual Hourly Annual Hourly Annual
Units
AP-42
Variable
Parameter Name
Percent Water in the Tank (%) 50% 50% 50% 50%
Emissions Calculations lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
Breathing 0.148 0.240 0.148 0.240 0.148 0.240 0.148 0.240
Working 12.180 2.722 12.180 2.722 12.180 2.722 12.180 2.722
Total 12.180 2.962 12.180 2.962 12.180 2.962 12.180 2.962
Breathing 0.156 0.253 0.156 0.253 0.156 0.253 0.156 0.253
Working 12.831 2.867 12.831 2.867 12.831 2.867 12.831 2.867
Total 12.831 3.120 12.831 3.120 12.831 3.120 12.831 3.120
THC 94.93% 94.93% 94.93% 94.93%
VOC 49.51% 49.51% 49.51% 49.51%
n-Hexane 4.87% 4.87% 4.87% 4.87%
2,2,4-Trimethylpentane 0.00% 0.00% 0.00% 0.00%
Benzene 0.15% 0.15% 0.15% 0.15%
Toluene 0.33% 0.33% 0.33% 0.33%
Ethylbenzene 0.01% 0.01% 0.01% 0.01%
Xylene 0.10% 0.10% 0.10% 0.10%
H2S 0.00% 0.00% 0.00% 0.00%
CO2 5.01% 5.01% 5.01% 5.01%
CH4 27.08% 27.08% 27.08% 27.08%
VOC 6.353 1.545 6.353 1.545 6.353 1.545 6.353 1.545
n-Hexane 0.625 0.152 0.625 0.152 0.625 0.152 0.625 0.152
2,2,4-Trimethylpentane 3.67E-04 8.94E-05 3.67E-04 8.94E-05 3.67E-04 8.94E-05 3.67E-04 8.94E-05
Benzene 0.019 0.005 0.019 0.005 0.019 0.005 0.019 0.005
Toluene 0.042 0.010 0.042 0.010 0.042 0.010 0.042 0.010
Ethylbenzene 0.002 3.93E-04 0.002 3.93E-04 0.002 3.93E-04 0.002 3.93E-04
Xylene 0.013 0.003 0.013 0.003 0.013 0.003 0.013 0.003
H2S 1.76E-05 4.29E-06 1.76E-05 4.29E-06 1.76E-05 4.29E-06 1.76E-05 4.29E-06
CO2 0.643 0.156 0.643 0.156 0.643 0.156 0.643 0.156
CH4 3.475 0.845 3.475 0.845 3.475 0.845 3.475 0.845
CO2e 87.516 21.280 87.516 21.280 87.516 21.280 87.516 21.280
* Hourly emissions calculated per TCEQ guidance, APDG 6250, September 2014
† Total HAPs include 2,2,4-trimethylpentane, formaldehyde and BTEX and are
included in VOC
Tank Vapor weight %s
Total Stream Uncontrolled
Total HC Uncontrolled*
Uncontrolled Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Flash Losses From Storage Tanks
Gas Oil Ratio (GOR) Method
Source Name Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
EPN TANK-01 TANK-02 TANK-03 TANK-04
Flash Gas Composition Heat value
(Btu/scf)
MW
(lb/lb-mol)Mol % Wt.% Mol % Wt.% Mol % Wt.% Mol % Wt.%
nitrogen 0 28.01 0.10%0.08%0.10%0.08%0.10%0.08%0.10%0.08%
CO2 0 44.01 1.13% 1.52% 1.13% 1.52% 1.13% 1.52% 1.13% 1.52%
H2S 586.8 34.08 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00%
methane (C1) 909.4 16.04 50.59% 24.87% 50.59% 24.87% 50.59% 24.87% 50.59% 24.87%
ethane (C2) 1618.7 30.07 19.40% 17.87% 19.40% 17.87% 19.40% 17.87% 19.40% 17.87%
propane (C3) 2314.9 44.10 11.10% 14.99% 11.10% 14.99% 11.10% 14.99% 11.10% 14.99%
iso-butane (C4) 3000.4 58.12 1.84% 3.27% 1.84% 3.27% 1.84% 3.27% 1.84% 3.27%
nor-butane (C4) 3010.8 58.12 4.83% 8.61% 4.83% 8.61% 4.83% 8.61% 4.83% 8.61%
iso-pentane (C5) 3699 72.15 1.39% 3.06% 1.39% 3.06% 1.39% 3.06% 1.39% 3.06%
nor-pentane (C5) 3706.9 72.15 2.89% 6.39% 2.89% 6.39% 2.89% 6.39% 2.89% 6.39%
hexanes (C6) 4403.8 86.17 1.72% 4.55% 1.72% 4.55% 1.72% 4.55% 1.72% 4.55%
heptanes (C7) 5100 100.20 2.06% 6.34% 2.06% 6.34% 2.06% 6.34% 2.06% 6.34%
octanes (C8) 5796.1 114.23 0.56% 1.96% 0.56% 1.96% 0.56% 1.96% 0.56% 1.96%
nonanes (C9) 6493.2 128.26 0.08% 0.31% 0.08% 0.31% 0.08% 0.31% 0.08% 0.31%
decanes (C10+) 7189.6 142.29 0.02% 0.08% 0.02% 0.08% 0.02% 0.08% 0.02% 0.08%
n-hexanes 4403.8 86.17 1.95% 5.16% 1.95% 5.16% 1.95% 5.16% 1.95% 5.16%
2,2,4-trimethylpentane 5559.2 114.23 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00%
benzene 3590.9 78.11 0.11% 0.27% 0.11% 0.27% 0.11% 0.27% 0.11% 0.27%
toluene 4273.6 92.14 0.16% 0.47% 0.16% 0.47% 0.16% 0.47% 0.16% 0.47%
ethylbenzene 4970.5 106.17 0.00% 0.02% 0.00% 0.02% 0.00% 0.02% 0.00% 0.02%
xylenes (M,P,O) 4958.2 106.17 0.05% 0.15% 0.05% 0.15% 0.05% 0.15% 0.05% 0.15%
Flash Gas MW lb/lb-mol 32.64 32.64 32.64 32.64
GOR (scf of flash gas/bbl) scf/bbl 9.5 9.5 9.5 9.5
Production bbl/hr bbl/yr bbl/hr bbl/yr bbl/hr bbl/yr bbl/hr bbl/yr
Amount of liquid flashed 55.0 60225.0 55.0 60225.0 55.0 60225.0 55.0 60225.0
Percent Reduction for Produced Water Tank Calculation
as Oil/Condensate 50% 50% 50% 50%
Emissions Calculations lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
Total Uncontrolled Emissions
(After % reduction for Produced Water)22.212 12.161 22.212 12.161 22.212 12.161 22.212 12.161
VOC 55.64% 55.64% 55.64% 55.64%
n-Hexane 5.16% 5.16% 5.16% 5.16%
2,2,4-Trimethylpentane 0.00% 0.00% 0.00% 0.00%
Benzene 0.27% 0.27% 0.27% 0.27%
Toluene 0.47% 0.47% 0.47% 0.47%
Ethylbenzene 0.02% 0.02% 0.02% 0.02%
Xylene 0.15% 0.15% 0.15% 0.15%
H2S 0.00% 0.00% 0.00% 0.00%
CO2 1.52% 1.52% 1.52% 1.52%
CH4 24.87% 24.87% 24.87% 24.87%
VOC 12.359 6.766 12.359 6.766 12.359 6.766 12.359 6.766
n-Hexane 1.146 0.627 1.146 0.627 1.146 0.627 1.146 0.627
2,2,4-Trimethylpentane 0.001 3.69E-04 0.001 3.69E-04 0.001 3.69E-04 0.001 3.69E-04
Benzene 0.061 0.033 0.061 0.033 0.061 0.033 0.061 0.033
Toluene 0.103 0.057 0.103 0.057 0.103 0.057 0.103 0.057
Ethylbenzene 0.003 0.002 0.003 0.002 0.003 0.002 0.003 0.002
Xylene 0.034 0.019 0.034 0.019 0.034 0.019 0.034 0.019
H2S 4.29E-05 2.35E-05 4.29E-05 2.35E-05 4.29E-05 2.35E-05 4.29E-05 2.35E-05
CO2 0.338 0.185 0.338 0.185 0.338 0.185 0.338 0.185
CH4 5.523 3.024 5.523 3.024 5.523 3.024 5.523 3.024
CO2e 138.421 75.786 138.421 75.786 138.421 75.786 138.421 75.786
Example Calculation:
TANK-01 Uncontrolled VOC emission:
VOC =
Tank Emissions
Uncontrolled Emissions
* Total HAPs include 2,2,4-trimethylpentane, formaldehyde
and BTEX and are included in VOC
Flash Gas Composition
(Wt.%)
9.5 scf/bbl * 60,225 bbl/yr / 385.22 scf/lbmol * 32.64 lb/lb-mol * 50.00 % oil content / (2000 lb/ton) = 12.16 tpy
Ovintiv USA Inc.
Ranch Compressor Station
Tank Emissions Summary
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
Condensate/PW
Tank
EPN TANK-01 TANK-02 TANK-03 TANK-04
Control Device FLR-01 FLR-01 FLR-01 FLR-01
Tank Contents Oil/Condensate Oil/Condensate Oil/Condensate Oil/Condensate
Hours of VRU capture 0 0 0 0
Capture Efficiency % 100% 100% 100% 100%
Hours of capture by control device only
(hrs/year)**8760 8760 8760 8760
Control Efficiency (%) 98% 98% 98% 98%
Total hours of combustion control 8760 8760 8760 8760
Hours with uncaptured/uncontrolled emissions 0 0 0 0
Hours Uncontrolled 0 0 0 0
Emissions Calculations lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
Breathing 0.156 0.253 0.156 0.253 0.156 0.253 0.156 0.253
Working 12.831 2.867 12.831 2.867 12.831 2.867 12.831 2.867
Flashing 22.212 12.161 22.212 12.161 22.212 12.161 22.212 12.161
Worst case total † 35.042 15.281 35.042 15.281 35.042 15.281 35.042 15.281
VOC 49.51% 49.51% 49.51% 49.51%
n-Hexane 4.87% 4.87% 4.87% 4.87%
2,2,4-Trimethylpentane 0.00% 0.00% 0.00% 0.00%
Benzene 0.15% 0.15% 0.15% 0.15%
Toluene 0.33% 0.33% 0.33% 0.33%
Ethylbenzene 0.01% 0.01% 0.01% 0.01%
Xylene 0.10% 0.10% 0.10% 0.10%
H2S 0.00% 0.00% 0.00% 0.00%
CO2 5.01% 5.01% 5.01% 5.01%
CH4 27.08% 27.08% 27.08% 27.08%
VOC 55.64% 55.64% 55.64% 55.64%
n-Hexane 5.16% 5.16% 5.16% 5.16%
2,2,4-Trimethylpentane 0.00% 0.00% 0.00% 0.00%
Benzene 0.27% 0.27% 0.27% 0.27%
Toluene 0.47% 0.47% 0.47% 0.47%
Ethylbenzene 0.02% 0.02% 0.02% 0.02%
Xylene 0.15% 0.15% 0.15% 0.15%
H2S 0.00% 0.00% 0.00% 0.00%
CO2 1.52% 1.52% 1.52% 1.52%
CH4 24.87% 24.87% 24.87% 24.87%
VOC 18.712 8.311 18.712 8.311 18.712 8.311 18.712 8.311
n-Hexane 1.771 0.779 1.771 0.779 1.771 0.779 1.771 0.779
2,2,4-Trimethylpentane 0.001 4.58E-04 0.001 4.58E-04 0.001 4.58E-04 0.001 4.58E-04
Benzene 0.080 0.038 0.080 0.038 0.080 0.038 0.080 0.038
Toluene 0.146 0.067 0.146 0.067 0.146 0.067 0.146 0.067
Ethylbenzene 0.005 0.002 0.005 0.002 0.005 0.002 0.005 0.002
Xylene 0.047 0.022 0.047 0.022 0.047 0.022 0.047 0.022
H2S 6.05E-05 2.78E-05 6.05E-05 2.78E-05 6.05E-05 2.78E-05 6.05E-05 2.78E-05
CO2 0.981 0.341 0.981 0.341 0.981 0.341 0.981 0.341
CH4 8.998 3.869 8.998 3.869 8.998 3.869 8.998 3.869
Source Name
Flashing
Uncontrolled Emissions
Breathing/Working
Combustion
Control
Device
Total Stream Uncontrolled Emissions
(After any % reduction taken for produced water)
Stream
Composition
(Wt. %)
Ovintiv USA Inc.
Ranch Compressor Station
Tank Emissions Summary
Notes:
Uncontrolled Totals
lb/hr tpy
VOC 19.020 33.245
n-Hexane 1.801 3.117
2,2,4-Trimethylpentane 0.001 0.002
Benzene 0.080 0.151
Toluene 0.148 0.268
Ethylbenzene 0.005 0.009
Xylene 0.048 0.088
H2S 6.14E-05 0.000
CO2 1.012 1.366
CH4 9.167 15.476
CO2e 230.183 388.263
Controlled Totals [including contribution from flare(s)]
lb/hr tpy
VOC 0.380 0.665
n-Hexane 0.036 0.062
2,2,4-Trimethylpentane 0.000 0.000
Benzene 0.002 0.003
Toluene 0.003 0.005
Ethylbenzene 0.000 0.000
Xylene 0.001 0.002
H2S 0.000 0.000
CO2 100.820 173.583
CH4 0.183 0.310
N2O 0.002 0.003
CO2e 105.871 182.127
NOx 0.048 0.083
CO 0.221 0.380
SO2 0.000 0.000
Example Calculation:
TANK-01 Uncontrolled VOC emission:
VOC =
** Does not include hours that the VRU vapors are routed to the
combustion device, if VRU present.
† Includes flash emissions and the maximum of breathing and
working emissions.
((0.25 tpy (breathing HC emission) + 2.87 tpy (working HC emission)) * 49.51 wt% VOC(breathing/working
composition) + 12.16 tpy (flashing HC emissions) * 55.64 % wt% VOC (flashing composition)) = 8.31 tpy
Ovintiv USA Inc.
Ranch Compressor Station
Loading Emissions
Produced Water
Loading Oil/Condensate Loading
LOAD-1 LOAD-1
N/A FLR-01
Product Produced Water Oil/Condensate
Number of loadouts per year 200 669
Vapor Balance Collection Efficiency 0.0% 70.0%
Capture Efficiency % 0.0% 100.0%
Control Efficiency (%) 0.0% 98.0%
Total hours of combustion control 0 8,760
Hours Uncontrolled 8,760 0
Loading Loss Calculation Hourly Annual Hourly Annual
Percent Reduction for Produced Water Calculation as Oil/Condensate 99% 0%
S, Saturation Factor † dimensionless 0.6 0.6
M, Molecular Weight of Vapors †† lb/lb-mole 31.33 31.33
P, True vapor pressure of liquid loaded †† psia 7.50 3.82 7.50 3.82
T, Temperature of bulk liquid loaded †† °R 555.38 516.69 555.38 516.69
Loading Loss, LL (lbHC/1000 gal loaded) ‡ lbHC/1000 gal loaded 3.164 1.732 3.164 1.732
Loading Rate gal 5,040 1,008,000 7,560 5,058,900
Emission Calculations lb/hr tpy lb/hr tpy
Total HC Uncontrolled Emissions
(After % reduction taken for produced water )0.159 0.009 23.922 4.382
Total Stream Uncontrolled Emissions
(After % reduction taken for produced water )0.168 0.009 25.200 4.616
VOC 49.51% 49.51%
n-Hexane 4.87% 4.87%
2,2,4-Trimethylpentane <0.01% <0.01%
Benzene 0.15% 0.15%
Toluene 0.33% 0.33%
Ethylbenzene 0.01% 0.01%
Xylene 0.10% 0.10%
H2S <0.01% <0.01%
CO2 5.01% 5.01%
CH4 27.08% 27.08%
Produced Water Loading Oil/Condensate Loading Totals
lb/hr tpy lb/hr tpy lb/hr tpy
VOC 0.083 0.005 12.477 2.286 12.560 2.290
n-Hexane 0.008 4.5E-04 1.227 0.225 1.235 0.225
2,2,4-Trimethylpentane 4.8E-06 2.6E-07 0.001 1.3E-04 0.001 1.3E-04
Benzene 2.5E-04 1.3E-05 0.037 0.007 0.037 0.007
Toluene 0.001 3.0E-05 0.083 0.015 0.084 0.015
Ethylbenzene 2.1E-05 1.2E-06 0.003 0.001 0.003 0.001
Xylene 1.6E-04 9.0E-06 0.025 0.005 0.025 0.005
H2S 2.3E-07 1.3E-08 3.5E-05 6.3E-06 3.5E-05 6.4E-06
CO2 0.008 4.6E-04 1.262 0.231 1.270 0.232
CH4 0.045 0.002 6.825 1.250 6.870 1.253
CO2e 1.146 0.063 171.884 31.485 173.030 31.548
Stream Composition
(Wt.%)
Source Name
EPN
Control Device
Combustion Control Device
Emissions Summary
Uncontrolled Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Loading Emissions
"Effective" Vapor Balance Collection Efficiency 100% 70%
Uncaptured Emissions 0 0 7.560 1.385
Captured Emissions (i.e. is available for VRU
& Combustion Control Device to capture)0.168 0.0092 17.640 3.2313
Uncontrolled, i.e. Not captured by control
device(s), incl. uncaptured during vapor balance 0.168 0.009 0 0
Captured and sent to combustion control device 0 0 17.640 3.231
Total Stream Uncaptured Emissions (FIN/EPN: LOAD-1/LOAD-1) 0.168 0.009 7.560 1.385
VOC 0.083 0.005 3.743 0.686 3.826 0.690
n-Hexane 0.008 4.5E-04 0.368 0.067 0.376 0.068
2,2,4-Trimethylpentane 4.8E-06 2.6E-07 2.2E-04 4.0E-05 2.2E-04 4.0E-05
Benzene 2.5E-04 1.3E-05 0.011 0.002 0.011 0.002
Toluene 0.001 3.0E-05 0.025 0.005 0.025 0.005
Ethylbenzene 2.1E-05 1.2E-06 0.001 1.7E-04 0.001 1.8E-04
Xylene 1.6E-04 9.0E-06 0.007 0.001 0.008 0.001
H2S 2.3E-07 1.3E-08 1.0E-05 1.9E-06 1.1E-05 1.9E-06
CO2 0.008 4.6E-04 0.379 0.069 0.387 0.070
CH4 0.045 0.002 2.047 0.375 2.093 0.378
CO2e 1.146 0.063 51.565 9.446 52.711 9.508
Total Stream sent to Combustion
Control (Worst case between VRU-to-CC or CC)0 0 17.640 3.231
VOC 0.083 0.005 3.918 0.718 4.001 0.722
n-Hexane 0.008 4.5E-04 0.385 0.071 0.393 0.071
2,2,4-Trimethylpentane 4.8E-06 2.6E-07 2.3E-04 4.2E-05 2.3E-04 4.2E-05
Benzene 2.5E-04 1.3E-05 0.012 0.002 0.012 0.002
Toluene 0.001 3.0E-05 0.026 0.005 0.027 0.005
Ethylbenzene 2.1E-05 1.2E-06 0.001 1.8E-04 0.001 1.8E-04
Xylene 1.6E-04 9.0E-06 0.008 0.001 0.008 0.001
H2S 2.3E-07 1.3E-08 1.1E-05 2.0E-06 1.1E-05 2.0E-06
CO2 0.008 4.6E-04 49.417 9.052 49.426 9.053
CH4 0.045 0.002 2.143 0.393 2.189 0.395
N2O 0 0 0.001 1.4E-04 0.001 1.4E-04
CO2e 1.146 0.063 103.219 18.908 104.365 18.970
NOx 0 0 0.023 0.004 0.023 0.004
CO 0 0 0.107 0.020 0.107 0.020
SO2 0 0 4.6E-05 8.3E-06 4.6E-05 8.3E-06
Example Calculation:
VOC = 12.46 * 0.6 * 31.33 lb/lb-mole * 3.82 psia / 516.69 °R * (1 - 0%) ) lb/1000 gal* 5,058,900 gal/yr * 49.51
wt% VOC / 94.93 wt% HC / (2000 lb/ton) = 2.29 tpy
Controlled Emissions
Uncaptured Emissions
(FIN/EPN: LOAD-1/LOAD-1)
Ovintiv USA Inc.
Ranch Compressor Station
Pressurized Natural Gas Liquids Loading Emissions
Source Name Pressurized NGL Loading
EPN NGL-LOAD
Calculation Basis:
Emission Calculation Method:
Vapors Emitted per Truck Disconnection (lb/disconnect):
Liquid Hose Volume (gal) x Liquid Density (lb/gal) + Vapor Hose Volume (ft3) x Vapor Density (lb/ft3)
Hourly VOC Emission Rate (lb/hr) (one disconnection per hour):
Vapors Emitted per Truck Disconnection (lb/disconnect) x VOC concentration (wt%)
Annual VOC Emission rate (tpy):
Vapors Emitted per Truck Disconnection (lb/disconnect) x # of Annual Disconnections x VOC Concentration (wt%)
Pressurized Condensate Information Liquid hose disconnection
Pressurized Liquid MW (lb/lb-mol) 57.06 Hose length (ft) 0.50
Pressurized drip liquid density (lb/gal) 4.92 Hose diameter (in) 2.00
Pressurized drip vapor density (lb/ft3)1.35 Hose volume (gal) 0.08
Loading pressure (psig) 100 Emissions (lb/disconnect) 0.401
Loading Temperature (F) -8
Number of truck loadouts per year 730 Vapor hose disconnection
Hose length (ft) 16.00
Hose diameter (in) 2.00
Emissions (lb/disconnect) 0.471
Pressurized Condensate Composition wt%Total Emissions lb/hr tpy
VOC 92.89% VOC 0.811 0.296
n-Hexane 7.45% n-Hexane 0.065 0.024
2,2,4-Trimethylpentane 0.00% 2,2,4-Trimethylpentane 9.20E-06 3.36E-06
Benzene 0.33% Benzene 0.003 0.001
Toluene 0.09% Toluene 0.001 2.94E-04
Ethylbenzene 0.00% Ethylbenzene 2.59E-06 9.47E-07
Xylene 0.00% Xylene 2.01E-05 7.34E-06
H2S 0.00%H2S -- --
CO2 0.21%CO2 0.002 0.001
CO2e 0.284 0.104
Example Calculation:
VOC =
Emissions from pressurized condensate loading are due to the venting of residual condensate vapors to
atmosphere from disconnecting the emptied hose. These emissions are calculated using the Ideal Gas Law
and are based on the entire hose volume venting to the atmosphere. It is assumed that loading would occur
only at one pressurized condensate vessel at a time.
(0.08 gal (Liquid hose volume) * 4.92 lb/gal (liquid density) + 0.35 ft3 (Vapor hose volume) * 1.35 lb/ft3
(vapor density)) * 92.89wt% VOC * 0,730 loadout/year / (2000 lb/ton) = 0.30 tpy
Ovintiv USA Inc.
Ranch Compressor Station
Flare / Vapor Combustor Reference
Emissions Calculation Methods:
[1] • Hourly Stream Flow (lb/hr) = (lb/lb-mol) * (P) * (scf/hr) * / (R) * (T)
• Hourly Flow Rate (using GOR) (scf/hr) = GOR * Max throughput (bbl/hr)
• Annual Stream Flow (tpy) = (lb/lb-mol) * (P) * (scf/yr) * / (R) * (T) * 2000
• Annual Flow Rate (using GOR) (scf/yr) = GOR * Annual hourly throughput (bbl/hr) * Hrs/yr
[2] • Hourly Flow Rate (scf/hr) = Total lb/hr * T * R / P * Stream MW
• Annual Flow Rate (scf/yr) = Total tpy * T * R / P * Stream MW
• NOx/CO (lb/hr) = (scf/hr)*EF (lb/MMBtu) * HV (Btu/scf) / 10^6
• SO2 (lb/hr) = (H2S lb/hr)*(64 lb SO2/lb-mol)/(34.08 lb H2S/lb-mol)
Flare Tip Velocity Calculation Method:
Actual Flare Tip Velocity (ft/sec) = (scf/hr)*(1 hr/3600 sec)/(flare tip area)
Heat Content Requirement Calculation Method:
For SO2, Q = (0.53)*(105)*(lb/hr SO2)
Flare Emission Factors
Pollutant Waste Gas
NOx lb/MMBtu 0.068
CO lb/MMBtu 0.31
N2O kg/MMBtu 0.001
EPN FLR-02 FLR-01
Source Name Utility Flare Process Flare
Flare Information (If Controlled by Flare)
Flare Steam Assisted (y or n) NO NO
Pilot or Auto-ignitor? Pilot Pilot
Pilot Flow (scf/hr): 98.04 21.00
Destruction Efficiency (%): 98 98
Stack height (ft): 60 12.4
Flare Tip Diameter (in): 12 6
Actual Flare Tip Velocity
Total Gas Volume to Flare (scf/hr): 853,431.373 1,377.020
Flare Tip Diameter (ft) 1.00 0.50
Flare Tip Area (ft2)0.785 0.196
Flare Tip Velocity (ft/sec): 301.840 1.948
40 CFR 98.233(z)(2)(vi)
AP-42, Table 13.5-2
AP-42, Table 13.5-1
Source
Ovintiv USA Inc.
Ranch Compressor Station
Flare / Vapor Combustor Emissions
EPN FLR-01
Source Name Process Flare
[1] [2] [2] [2] [2] [2] Calculation Method
Flare Pilot
Tanks (B/W) -
Condensate/Produced
Water
Tanks (Flash) -
Condensate/Produced
Water
Truck Loading -
Oil/Condensate DEHY-01 Separator Gas DEHY-01 Condenser
Vapor Totals
Hourly Annual Hourly Annual Hourly Annual Hourly Annual Hourly Annual Hourly Annual Hourly Annual
FLR-01 Multiple Tanks Multiple Tanks LOAD-1 DEHY-01 DEHY-01 FIN
Yes Yes Yes Yes Yes Yes Routed to Flare?
8,760 8,760 8,760 8,760 8,760 8,760 Hours/year Routed to Flare
Fuel Gas Analysis Oil/Condensate
BW Vapor Oil/Condensate Flash Oil/Condensate
BW Vapor Dehy 1 Flash Tank Vapor Dehy 1 Condenser Vapor Analysis Used
VOC wt% 15.64% 49.51% 55.64% 49.51% 46.60% 84.63% wt% VOC
n-Hexane wt% 0.05% 4.87% 5.16% 4.87% 1.63% 6.31% wt% n-Hexane
2,2,4-Trimethylpentane wt% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% wt% 2,2,4-Trimethylpentane
Benzene wt% 0.00% 0.15% 0.27% 0.15% 0.17% 13.06% wt% Benzene
Toluene wt% 0.00% 0.33% 0.47% 0.33% 0.04% 3.24% wt% Toluene
Ethylbenzene wt% 0.00% 0.01% 0.02% 0.01% 0.00% 0.00% wt% Ethylbenzene
Xylene wt% 0.00% 0.10% 0.15% 0.10% 0.00% 0.04% wt% Xylene
H2S wt% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% wt%H2S
CO2 wt% 2.07% 5.01% 1.52% 5.01% 7.33% 6.01% wt%CO2
CH4 wt% 64.44% 27.08% 24.87% 27.08% 25.72% 1.57% wt%CH4
lb/lb-mol 20.09 31.33 32.64 31.33 30.33 58.62 lb/lb-mol Stream MW
Heating Value BTU/scf 1,084.51 1,589.80 1,710.17 1,589.80 1,506.70 2,793.99 1,710 1,755 BTU/scf Heating Value
scf/bbl N/A N/A 9.53 N/A N/A N/A scf/bbl GOR
Heat Release MMBTU 0.023 200 0.263 488 0.448 1,964 0.345 126 0.834 7,305 0.442 3,869 2.355 13,952 MMBTU Heat Release
scf 21.00 183,960 165.42 306,888 262.18 1,148,352 216.90 79,461 553.45 4,848,183 158.08 1,384,806 1,377.02 7,951,650 scf Flow Rate
EMISSIONS
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
1.10 4.80 13.45 12.48 22.21 48.64 17.64 3.23 43.57 190.85 24.06 105.37 122.03 365.37 Total Stream Flow (after any reduction taken for PW)
VOC 0.171 0.750 6.661 6.179 12.359 27.066 8.734 1.600 20.307 88.944 20.358 89.169 68.590 213.707 VOC
n-Hexane 0.001 0.003 0.655 0.607 1.146 2.510 0.859 0.157 0.709 3.103 1.517 6.646 4.886 13.026 n-Hexane
2,2,4-Trimethylpentane 2.60E-08 1.14E-07 3.85E-04 3.57E-04 0.001 0.001 0.001 9.25E-05 9.00E-05 3.94E-04 2.85E-04 0.001 0.002 0.004 2,2,4-Trimethylpentane
Benzene 3.48E-05 1.53E-04 0.020 0.018 0.061 0.133 0.026 0.005 0.072 0.317 3.141 13.756 3.320 14.230 Benzene
Toluene 2.26E-06 9.91E-06 0.044 0.041 0.103 0.227 0.058 0.011 0.017 0.073 0.780 3.416 1.002 3.767 Toluene
Ethylbenzene 1.79E-09 7.84E-09 0.002 0.002 0.003 0.007 0.002 4.07E-04 3.87E-05 1.69E-04 0.001 0.005 0.008 0.014 Ethylbenzene
Xylene 1.22E-08 5.34E-08 0.013 0.012 0.034 0.075 0.017 0.003 3.08E-04 0.001 0.010 0.042 0.075 0.134 Xylene
H2S 4.46E-05 1.95E-04 1.85E-05 1.72E-05 4.29E-05 9.39E-05 2.43E-05 4.44E-06 0 0 0 0 1.30E-04 3.11E-04 H2S
CO2 0.023 0.099 0.674 0.625 0.338 0.741 0.883 0.162 3.195 13.993 1.446 6.335 6.559 21.954 CO2
CH4 0.706 3.091 3.644 3.380 5.523 12.096 4.777 0.875 11.209 49.095 0.377 1.651 26.236 70.188 CH4
CO2e 17.666 77.376 91.761 85.120 138.421 303.143 120.319 22.040 283.416 1,241.363 10.871 47.614 662.454 1,776.655 CO2e
VOC 0.003 0.015 0.133 0.124 0.247 0.541 0.175 0.032 0.406 1.779 0.407 1.783 1.372 4.274 VOC
n-Hexane 1.16E-05 5.09E-05 0.013 0.012 0.023 0.050 0.017 0.003 0.014 0.062 0.030 0.133 0.098 0.261 n-Hexane
2,2,4-Trimethylpentane 5.21E-10 2.28E-09 7.71E-06 7.15E-06 1.35E-05 2.95E-05 1.01E-05 1.85E-06 1.80E-06 7.88E-06 5.69E-06 2.49E-05 3.88E-05 7.13E-05 2,2,4-Trimethylpentane
Benzene 6.97E-07 3.05E-06 3.94E-04 3.66E-04 0.001 0.003 0.001 9.47E-05 0.001 0.006 0.063 0.275 0.066 0.285 Benzene
Toluene 4.53E-08 1.98E-07 0.001 0.001 0.002 0.005 0.001 2.13E-04 3.34E-04 0.001 0.016 0.068 0.020 0.075 Toluene
Ethylbenzene 3.58E-11 1.57E-10 3.39E-05 3.14E-05 6.79E-05 1.49E-04 4.44E-05 8.14E-06 7.73E-07 3.39E-06 2.19E-05 9.60E-05 1.69E-04 2.88E-04 Ethylbenzene
Xylene 2.44E-10 1.07E-09 2.64E-04 2.45E-04 0.001 0.002 3.46E-04 6.34E-05 6.15E-06 2.70E-05 1.91E-04 0.001 0.001 0.003 Xylene
H2S 8.92E-07 3.91E-06 3.70E-07 3.43E-07 8.57E-07 1.88E-06 4.85E-07 8.89E-08 0 0 0 0 2.60E-06 6.22E-06 H2S
CO2 2.967 12.997 37.400 34.693 63.420 138.890 49.039 8.983 118.724 520.012 68.052 298.069 339.603 1,013.645 CO2
CH4 0.014 0.062 0.073 0.068 0.110 0.242 0.096 0.018 0.224 0.982 0.008 0.033 0.525 1.404 CH4
N2O 5.02E-05 2.20E-04 0.001 0.001 0.001 0.002 0.001 1.39E-04 0.002 0.008 0.001 0.004 0.005 0.015 N2O
CO2e 3.335 14.608 39.394 36.543 66.477 145.584 51.654 9.462 124.877 546.959 68.531 300.166 354.267 1,053.321 CO2e
NOx 0.002 0.007 0.018 0.017 0.030 0.067 0.023 0.004 0.057 0.248 0.030 0.132 0.160 0.474 NOx
CO 0.007 0.031 0.082 0.076 0.139 0.304 0.107 0.020 0.259 1.132 0.137 0.600 0.730 2.162 CO
SO2 8.37E-05 3.67E-04 3.47E-05 3.22E-05 8.05E-05 1.76E-04 4.56E-05 8.34E-06 0 0 0 0 2.45E-04 0.001 SO2
Notes:Constants
527.67
10.73159
14.7
Example Calculation:
NOx = 0.068 lb/MMBtu * (183,960 scf/yr (flare pilot) * 1,085 BTU/scf + 306,888 scf/yr (Tank breathing and working) * 1,590 BTU/scf + 1,148,352 scf/yr (tank flash) * 1,710 BTU/scf +
4,848,183 scf/yr (dehy separator gas) * 1,507 BTU/scf + 1,384,806 scf/yr (dehy condenser vapor) * 2,794 BTU/scf) / (1e6 BTU/MMBtu) / (2000 lb/ton) = 0.47 tpy
Uncontrolled
Emissions
Uncontrolled
Emissions
FIN
Hours/year Routed to Flare
Analysis Used
- See Flare / Vapor Combustor Reference Page for calculation methods and equipment details
- Flow rate assumptions for the following sources: PROD-GAS = GOR (scf/bbl) x Oil/Condensate Throughput (bbl/hr)
- Hourly and annual individual stream contributions represented in calculations are to determine a worst-case PTE emission rate at EPN: FLR-01 during normal operations. Actual individual stream flow rates will
vary. Ovintiv will monitor total flow rate to the flare to ensure compliance with the authorization.
Routed to Flare?
T (absolute temperature - Rankine)
R (universal gas constant) - (psia*ft3)/(lbmolR)
P (Pressure (psia))
Total Stream Flow (after any reduction taken for PW)
Flow Rate
Controlled
Emissions
Controlled
Emissions
GOR
Stream MW
Stream
Composition
Stream
Composition
Ovintiv USA Inc.
Ranch Compressor Station
Flare / Vapor Combustor Emissions
EPN FLR-02
Source Name Utility Flare
[1][1][1]Calculation Method
Flare Pilot Produced Gas
Compressor
Blowdowns/Startups Totals
Hourly Annual Hourly Annual Hourly Annual Hourly Annual
FLR-02 PROD-GAS COMP-MSS FIN
Yes Yes Yes Routed to Flare?
8,760 8,760 62 Hours/year Routed to Flare
Fuel Gas Analysis Gas Analysis Gas Analysis Analysis Used
VOC wt% 15.64% 32.80% 32.80% wt% VOC
n-Hexane wt% 0.05% 2.67% 2.67% wt% n-Hexane
2,2,4-Trimethylpentane wt% 0.00% 0.00% 0.00% wt% 2,2,4-Trimethylpentane
Benzene wt% 0.00% 0.14% 0.14% wt% Benzene
Toluene wt% 0.00% 0.24% 0.24% wt% Toluene
Ethylbenzene wt% 0.00% 0.01% 0.01% wt% Ethylbenzene
Xylene wt% 0.00% 0.10% 0.10% wt% Xylene
H2S wt% 0.00% 0.00% 0.00% wt%H2S
CO2 wt% 2.07% 1.66% 1.66% wt%CO2
CH4 wt% 64.44% 50.72% 50.72% wt%CH4
lb/lb-mol 20.09 23.69 23.69 lb/lb-mol Stream MW
Heating Value BTU/scf 1,084.51 1,265.11 1,265.11 647 639 BTU/scf Heating Value
scf/bbl N/A N/A N/A scf/bbl GOR
Heat Release MMBTU 0.106 931 527.129 113,860 25.302 1,579 552.538 116,370 MMBTU Heat Release
scf 98.04 858,824 416,666.67 90,000,000 20,000.00 1,248,000 853,431.37 182,106,824 scf Flow Rate
EMISSIONS
lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy
5.11 22.39 25,624.67 2,767.46 1,229.98 38.38 26,859.77 2,828.23 Total Stream Flow (after any reduction taken for PW)
VOC 0.800 3.503 8,404.831 907.722 403.432 12.587 8,809.063 923.812 VOC
n-Hexane 0.003 0.012 684.323 73.907 32.848 1.025 717.174 74.944 n-Hexane
2,2,4-Trimethylpentane 1.22E-07 5.32E-07 0.119 0.013 0.006 1.78E-04 0.124 0.013 2,2,4-Trimethylpentane
Benzene 1.63E-04 0.001 36.806 3.975 1.767 0.055 38.573 4.031 Benzene
Toluene 1.06E-05 4.63E-05 61.016 6.590 2.929 0.091 63.945 6.681 Toluene
Ethylbenzene 8.35E-09 3.66E-08 2.578 0.278 0.124 0.004 2.702 0.282 Ethylbenzene
Xylene 5.69E-08 2.49E-07 25.796 2.786 1.238 0.039 27.034 2.825 Xylene
H2S 2.08E-04 0.001 0.369 0.040 0.018 0.001 0.387 0.041 H2S
CO2 0.106 0.463 425.172 45.919 20.408 0.637 445.686 47.018 CO2
CH4 3.295 14.431 12,997.614 1,403.742 623.885 19.465 13,624.794 1,437.638 CH4
CO2e 82.473 361.231 325,365.527 35,139.477 15,617.545 487.267 341,065.545 35,987.976 CO2e
VOC 0.016 0.070 168.097 18.154 8.069 0.252 176.181 18.476 VOC
n-Hexane 5.42E-05 2.38E-04 13.686 1.478 0.657 0.020 14.343 1.499 n-Hexane
2,2,4-Trimethylpentane 2.43E-09 1.06E-08 0.002 2.56E-04 1.14E-04 3.56E-06 0.002 2.60E-04 2,2,4-Trimethylpentane
Benzene 3.25E-06 1.42E-05 0.736 0.080 0.035 0.001 0.771 0.081 Benzene
Toluene 2.11E-07 9.25E-07 1.220 0.132 0.059 0.002 1.279 0.134 Toluene
Ethylbenzene 1.67E-10 7.32E-10 0.052 0.006 0.002 7.72E-05 0.054 0.006 Ethylbenzene
Xylene 1.14E-09 4.99E-09 0.516 0.056 0.025 0.001 0.541 0.056 Xylene
H2S 4.16E-06 1.82E-05 0.007 0.001 3.54E-04 1.10E-05 0.008 0.001 H2S
CO2 13.853 60.675 70,946.722 7,662.246 3,405.443 106.250 74,366.017 7,829.170 CO2
CH4 0.066 0.289 259.952 28.075 12.478 0.389 272.496 28.753 CH4
N2O 2.34E-04 0.001 1.162 0.126 0.056 0.002 1.218 0.128 N2O
CO2e 15.570 68.196 77,791.840 8,401.519 3,734.008 116.501 81,541.419 8,586.216 CO2e
NOx 0.007 0.032 35.845 3.871 1.721 0.054 37.573 3.957 NOx
CO 0.033 0.144 163.410 17.648 7.844 0.245 171.287 18.037 CO
SO2 3.91E-04 0.002 0.692 0.075 0.033 0.001 0.726 0.078 SO2
Notes:Constants
527.67
10.73159
14.7
Example Calculation:
NOx = 0.068 lb/MMBtu * (858,824 scf/yr (flare pilot) * 1,085 BTU/scf + (90,000,000 scf/yr (produced gas) + 1,248,000 scf/yr (compressor
blowdowns))* 1,265 BTU/scf ) / (1e6 BTU/MMBtu) / (2000 lb/ton) = 3.96 tpy
Uncontrolled
Emissions
Uncontrolled
Emissions
Controlled
Emissions
- See Flare / Vapor Combustor Reference Page for calculation methods and equipment details
- Flow rate assumptions for the following sources: PROD-GAS (Separator Gas) = Estimated hourly flow rates (scf/hr); PROD-GAS =
Estimated hourly flow rates (scf/hr)
- Hourly and annual individual stream contributions represented in calculations are to determine a worst-case PTE emission rate at
EPN: FLR-02 during normal operations. Actual individual stream flow rates will vary. Ovintiv will monitor total flow rate to the flare to
ensure compliance with the authorization.
T (absolute temperature - Rankine)
R (universal gas constant) - (psia*ft3)/(lbmolR)
P (Pressure (psia))
Total Stream Flow (after any reduction taken for PW)
Stream
Data
Controlled
Emissions
Analysis Used
Stream
Data
Flow Rate
Stream MW
GOR
FIN
Hours/year Routed to Flare
Routed to Flare?
Ovintiv USA Inc.
Ranch Compressor Station
Planned MSS Emissions - Compressor Blowdowns
EPN COMP-MSS Control Device FLR-02
Source Name Compressor Blowdowns/Startups
Venting Volume (scf/event): 4,000
Hourly Blowdown/Startup Events (event/hr): 5
Number of Events Per Year Per Compressor: 52
Total Compressors: 6
Total Annual Events (event/yr): 312
Total Annual Vented Volume (scf/yr): 1,248,000
Capture Efficiency % 100%
Control Efficiency (%) 98%
MW (lb/lb-mol) 23.69
VOC 32.800%(from Gas Analysis composition)
n-Hexane 2.671%(from Gas Analysis composition)
2,2,4-Trimethylpentane 0.000%(from Gas Analysis composition)
Benzene 0.144%(from Gas Analysis composition)
Toluene 0.238%(from Gas Analysis composition)
Ethylbenzene 0.010%(from Gas Analysis composition)
Xylene 0.101%(from Gas Analysis composition)
H2S 0.001%(from Gas Analysis composition)
CO2 1.659%(from Gas Analysis composition)
CH4 50.723%(from Gas Analysis composition)
lb/hr tpy
Total 1,229.984 38.376
VOC 403.432 12.587
n-Hexane 32.848 1.025
2,2,4-Trimethylpentane 0.006 1.78E-04
Benzene 1.767 0.055
Toluene 2.929 0.091
Ethylbenzene 0.124 0.004
Xylene 1.238 0.039
H2S 0.018 0.001
CO2 20.408 0.637
CH4 623.885 19.465
CO2e 15,617.545 487.267
lb/hr tpy
VOC 8.069 0.252
n-Hexane 0.657 0.020
2,2,4-Trimethylpentane 1.14E-04 3.56E-06
Benzene 0.035 0.001
Toluene 0.059 0.002
Ethylbenzene 0.002 7.72E-05
Xylene 0.025 0.001
H2S 3.54E-04 1.10E-05
CO2 3,405.443 106.250
CH4 12.478 0.389
N2O 0.056 0.002
CO2e 3,734.008 116.501
NOx 1.721 0.054
CO 7.844 0.245
SO2 0.033 0.001
Notes:
Example Calculation:
Total Uncontrolled Emissions (lb/hr)
= (Volume per Event) x (Events per Hour) x MW / (Constant scf/lb-mol)
= 4,000 scf/event x 5 event/hr x 23.69 lb/lb-mol / 385.22 scf/lb-mol
Blowdown/Startups: Assume that blowdown/startup for the largest compressor
occurs in one hour.
Gas Composition
(wt%)
Uncontrolled Emissions
Controlled Emissions
Ovintiv USA Inc.
Ranch Compressor Station
Planned MSS Emissions - Tanks Venting
EPN
Identifier
Calculation Basis:
Tank Type Breathing Losses (lb/hr)
Condensate/PW Tanks 25.411 (from AP-42 tank emission calculations page)
Constants and Variables:
Activity duration (hrs/yr): 72 (conservatively assumed)
VOC 49.512% (from Oil/Condensate BW Vapor composition)
n-Hexane 4.868% (from Oil/Condensate BW Vapor composition)
2,2,4-Trimethylpentane 0.003% (from Oil/Condensate BW Vapor composition)
Benzene 0.147% (from Oil/Condensate BW Vapor composition)
Toluene 0.329% (from Oil/Condensate BW Vapor composition)
Ethylbenzene 0.013% (from Oil/Condensate BW Vapor composition)
Xylene 0.098% (from Oil/Condensate BW Vapor composition)
H2S 0.000% (from Oil/Condensate BW Vapor composition)
CO2 5.008% (from Oil/Condensate BW Vapor composition)
CH4 27.083% (from Oil/Condensate BW Vapor composition)
lb/hr tpy lb/hr tpy
Total Emissions 25.411 0.915 25.411 0.915
VOC 12.582 0.453 12.582 0.453
n-Hexane 1.237 0.045 1.237 0.045
2,2,4-Trimethylpentane 0.001 2.6E-05 0.001 2.6E-05
Benzene 0.037 0.001 0.037 0.001
Toluene 0.084 0.003 0.084 0.003
Ethylbenzene 0.003 1.2E-04 0.003 1.2E-04
Xylene 0.025 0.001 0.025 0.001
H2S 3.5E-05 1.3E-06 3.5E-05 1.3E-06
CO2 1.272 0.046 1.272 0.046
CH4 6.882 0.248 6.882 0.248
CO2e 173.323 6.240 173.323 6.240
Tank-MSS
Tank Venting During Site Shutdown
This activity represents emissions from storage tanks venting to atmosphere during a site shutdown. It is assumed that during a shutdown, no liquids are introduced into the tanks,
therefore no working or flashing emissions would occur. Emissions from oil/condensate and produced water tanks venting to atmosphere during site shutdown are estimated based on
breathing emissions from all tanks venting to atmosphere. It is conservatively assumed that this activity may occur for up to 72 hours per year.
Total Emissions
Condensate/PW Tanks TOTAL
Gas Composition
(wt%)
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX D
IMPACTS ANALYSES

Ovintiv USA Inc.
Ranch Compressor Station
Impacts Analysis
SCREEN3 Modeling
Stack parameters
MMBtu/hr m m
Flow
(m/s)
Temp
(K)m (µg/m3) /
(lb/hr)
(µg/m3) /
(lb/hr)
ENG-01 Compressor Engine 15.85 0.30 626 806 830 0.38 0.38
ENG-02 Compressor Engine 15.85 0.30 626 806 830 0.38 0.38
ENG-03 Compressor Engine 15.85 0.30 626 806 830 0.38 0.38
ENG-04 Compressor Engine 15.85 0.51 296 719 924 0.31 0.31
ENG-05 Compressor Engine 15.85 0.51 301 719 921 0.31 0.31
ENG-06 Compressor Engine 15.85 0.51 213 795 821 0.38 0.38
Utility Flare Pilot
Produced Gas
Notes:
Emission Source Name
Heat
Release Stack Gas ExitStack
Height
EPN
[1] A unit emission rate of 1 lb/hr was used in SCREEN3 modeling. The Screen3 generic impact, Ghourly (µg/m3) / (lb/hr) was determined for each EPN.
38,702,830 1,195 0.07FLR-02
Stack
Diameter
SCREEN3 Results [1]
SCREEN3
Ghourly
adjusted
Distance
to max
SCREEN3
Ghourly
18.29 0.07
Ovintiv USA Inc.
Ranch Compressor Station
R307-410-5 - Documentation of Ambient Air Impacts for Hazardous Air Pollutants
EPN Emission
Source Name
Type of
release
Max release
duration
(min/hr)
Release
height
(m)
Height of
adjacent
building
(m)
Distance to
ambient air
(m)
Pollutant Hourly
Emission
Rate (lb/hr)
TLV [1]
(mg/m3)
Emission
Threhold Factor
[2]
(m3lb/mg-hr)
Emission
Threshold
Value (lb/hr)
Is max hourly
emission rate
equal or greater
than emission
threshold
value?
Toxic
Screening
Levels
(mg/m3)
Concentration
based on
Screen3 Results
(mg/m3)
Is ambient
concentration of
pollutant equal to
or greater than
the Toxic
screening level?
Benzene 0.02 32 0.198 6.34 No No further analysis required
Toluene 0.05 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.03 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.44 176 0.066 11.62 No No further analysis required
Formaldehyde 0.41 0.37 0.154 0.06 Yes 3.70E-02 1.56E-04 No
Benzene 0.01 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.06 0.23 0.066 0.02 Yes 2.30E-02 2.34E-05 No
Acetaldehyde 0.10 45 0.066 2.97 No No further analysis required
n-Hexane 0.01 176 0.066 11.62 No No further analysis required
Methanol 0.03 263 0.066 17.36 No No further analysis required
Formaldehyde 0.41 0.37 0.154 0.06 Yes 3.70E-02 1.56E-04 No
Benzene 0.01 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.06 0.23 0.066 0.02 Yes 2.30E-02 2.34E-05 No
Acetaldehyde 0.10 45 0.066 2.97 No No further analysis required
n-Hexane 0.01 176 0.066 11.62 No No further analysis required
Methanol 0.03 263 0.066 17.36 No No further analysis required
Formaldehyde 0.41 0.37 0.154 0.06 Yes 3.70E-02 1.56E-04 No
Benzene 0.01 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.06 0.23 0.066 0.02 Yes 2.30E-02 2.34E-05 No
Acetaldehyde 0.10 45 0.066 2.97 No No further analysis required
n-Hexane 0.01 176 0.066 11.62 No No further analysis required
Methanol 0.03 263 0.066 17.36 No No further analysis required
Compressor
Engine
Vertically
unrestricted
N/A >=20FUG-1 Fugitives Fugitives 60 N/A
7.32 >=5060 15.85
7.32 >=50
ENG-02 Compressor
Engine
Vertically
unrestricted 60 15.85 7.32 >=50
ENG-03 Compressor
Engine
Vertically
unrestricted 60
ENG-01
15.85
Ovintiv USA Inc.
Ranch Compressor Station
R307-410-5 - Documentation of Ambient Air Impacts for Hazardous Air Pollutants
EPN Emission
Source Name
Type of
release
Max release
duration
(min/hr)
Release
height
(m)
Height of
adjacent
building
(m)
Distance to
ambient air
(m)
Pollutant Hourly
Emission
Rate (lb/hr)
TLV [1]
(mg/m3)
Emission
Threhold Factor
[2]
(m3lb/mg-hr)
Emission
Threshold
Value (lb/hr)
Is max hourly
emission rate
equal or greater
than emission
threshold
value?
Toxic
Screening
Levels
(mg/m3)
Concentration
based on
Screen3 Results
(mg/m3)
Is ambient
concentration of
pollutant equal to
or greater than
the Toxic
screening level?
Formaldehyde 0.39 0.37 0.154 0.06 Yes 3.70E-02 1.22E-04 No
Benzene 0.01 32 0.198 6.34 No No further analysis required
Toluene 0.01 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.07 0.23 0.066 0.02 Yes 2.30E-02 2.15E-05 No
Acetaldehyde 0.11 45 0.066 2.97 No No further analysis required
n-Hexane 0.01 176 0.066 11.62 No No further analysis required
Methanol 0.03 263 0.066 17.36 No No further analysis required
Formaldehyde 0.34 0.37 0.154 0.06 Yes 3.70E-02 1.03E-04 No
Benzene 0.01 32 0.198 6.34 No No further analysis required
Toluene 0.01 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.07 0.23 0.066 0.02 Yes 2.30E-02 2.25E-05 No
Acetaldehyde 0.12 45 0.066 2.97 No No further analysis required
n-Hexane 0.02 176 0.066 11.62 No No further analysis required
Methanol 0.04 263 0.066 17.36 No No further analysis required
Formaldehyde 0.24 0.37 0.154 0.06 Yes 3.70E-02 9.36E-05 No
Benzene 0.00 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.06 0.23 0.066 0.02 Yes 2.30E-02 2.17E-05 No
Acetaldehyde 0.09 45 0.066 2.97 No No further analysis required
n-Hexane 0.01 176 0.066 11.62 No No further analysis required
Methanol 0.03 263 0.066 17.36 No No further analysis required
Formaldehyde 0.01 0.37 0.154 0.06 No No further analysis required
Benzene 0.00 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
Acrolein 0.00 0.23 0.066 0.02 No No further analysis required
Acetaldehyde 0.00 45 0.066 2.97 No No further analysis required
n-Hexane 0.00 176 0.066 11.62 No No further analysis required
Methanol 0.00 263 0.066 17.36 No No further analysis required
ENG-06 Compressor
Engine
Vertically
unrestricted 60 15.85 7.32 >=50
GENENG-01 Generator
Engine
Vertically
unrestricted 60 2.04 7.32 >=50
>=50ENG-04 Compressor
Engine
Vertically
unrestricted 60 15.85
ENG-05 Compressor
Engine
Vertically
unrestricted 60 15.85 7.32 >=50
7.32
Ovintiv USA Inc.
Ranch Compressor Station
R307-410-5 - Documentation of Ambient Air Impacts for Hazardous Air Pollutants
EPN Emission
Source Name
Type of
release
Max release
duration
(min/hr)
Release
height
(m)
Height of
adjacent
building
(m)
Distance to
ambient air
(m)
Pollutant Hourly
Emission
Rate (lb/hr)
TLV [1]
(mg/m3)
Emission
Threhold Factor
[2]
(m3lb/mg-hr)
Emission
Threshold
Value (lb/hr)
Is max hourly
emission rate
equal or greater
than emission
threshold
value?
Toxic
Screening
Levels
(mg/m3)
Concentration
based on
Screen3 Results
(mg/m3)
Is ambient
concentration of
pollutant equal to
or greater than
the Toxic
screening level?
Benzene 0.00 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.00 176 0.066 11.62 No No further analysis required
Benzene 0.06 32 0.198 6.34 No No further analysis required
Toluene 0.02 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.04 176 0.066 11.62 No No further analysis required
Benzene 0.00 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.04 176 0.066 11.62 No No further analysis required
N/A >=50
TANK-01, TANK-02,
TANK-03, TANK-04 Storage Tanks Vertically
unrestricted 60 6.10 N/A >=50
DEHY-01 TEG
Dehydrator
Vertically
unrestricted 60 6.10
HTR-01 Dehy Reboiler Vertically
unrestricted 60 4.57 N/A >=50
Ovintiv USA Inc.
Ranch Compressor Station
R307-410-5 - Documentation of Ambient Air Impacts for Hazardous Air Pollutants
EPN Emission
Source Name
Type of
release
Max release
duration
(min/hr)
Release
height
(m)
Height of
adjacent
building
(m)
Distance to
ambient air
(m)
Pollutant Hourly
Emission
Rate (lb/hr)
TLV [1]
(mg/m3)
Emission
Threhold Factor
[2]
(m3lb/mg-hr)
Emission
Threshold
Value (lb/hr)
Is max hourly
emission rate
equal or greater
than emission
threshold
value?
Toxic
Screening
Levels
(mg/m3)
Concentration
based on
Screen3 Results
(mg/m3)
Is ambient
concentration of
pollutant equal to
or greater than
the Toxic
screening level?
Benzene 0.00 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.07 176 0.066 11.62 No No further analysis required
Benzene 0.01 32 0.198 6.34 No No further analysis required
Toluene 0.03 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.01 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.39 176 0.066 11.62 No No further analysis required
Benzene 0.74 32 0.198 6.34 No No further analysis required
Toluene 1.22 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.05 434 0.066 28.64 No No further analysis required
Xylene 0.52 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 13.69 176 0.066 11.62 Yes 1.76E+01 1.01E-03 No
Benzene 0.00 32 0.198 6.34 No No further analysis required
Toluene 0.00 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.00 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.00 176 0.066 11.62 No No further analysis required
Benzene 0.04 32 0.198 6.34 No No further analysis required
Toluene 0.06 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.02 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 0.66 176 0.066 11.62 No No further analysis required
Benzene 0.04 32 0.198 6.34 No No further analysis required
Toluene 0.08 188 0.066 12.41 No No further analysis required
Ethylbenzene 0.00 434 0.066 28.64 No No further analysis required
Xylene 0.02 434 0.066 28.64 No No further analysis required
2,2,4-
Trimethylpentane 0.00 1402 0.066 92.53 No No further analysis required
n-Hexane 1.24 176 0.066 11.62 No No further analysis required
[1] TLV - Threshold Limit Value
[2] From Table 2 of R307-410-5
[3] A unit emission rate of 1 lb/hr was used in SCREEN3 modeling. The concentration is calculated by multiplying SCREEN3 result by hourly emission rate of each source.
N/A >=50
Tank-MSS
Tank Venting
During Site
Shutdown
Vertically
unrestricted 60 6.10 N/A >=50
COMP-MSS
Compressor
Blowdowns/St
artups
Vertically
unrestricted 60 3.05
FLR-01 Process Flare
Pilot
Vertically
unrestricted 60 3.78 N/A >=50
N/A >=50FLR-02 Utility Flare Vertically
unrestricted 60 18.29
LOAD-1
Condensate
and Produced
Water Loading
Vertically
unrestricted 60 3.05 N/A >=50
NGL-LOAD Pressurized
NGL Loading
Vertically
unrestricted 60 3.05 N/A >=50
01/03/23
17:56:02
*** SCREEN3 MODEL RUN ***
*** VERSION DATED 13043 ***
ENG-01 through ENG-03
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) = 0.126000
STACK HEIGHT (M) = 15.8500
STK INSIDE DIAM (M) = 0.3000
STK EXIT VELOCITY (M/S)= 626.0000
STK GAS EXIT TEMP (K) = 806.0000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) = 0.0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 0.0000
MIN HORIZ BLDG DIM (M) = 0.0000
MAX HORIZ BLDG DIM (M) = 0.0000
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.
BUOY. FLUX = 87.910 M**4/S**3; MOM. FLUX = 3205.264 M**4/S**2.
*** FULL METEOROLOGY ***
**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING
DISTANCES ***
DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M)
DWASH
------- ---------- ---- ----- ----- ------ ------ ------ ------
-----
1. 0.000 1 1.0 1.0 566.7 565.70 12.34 12.33
NO
100. 0.1186E-01 5 1.0 1.2 10000.0 141.10 36.30 35.96
NO
200. 0.1322E-01 5 1.0 1.2 10000.0 141.10 37.63 36.32
NO
300. 0.4619E-01 3 10.0 10.5 3200.0 70.08 36.00 23.10
NO
400. 0.1455 3 10.0 10.5 3200.0 70.08 45.98 28.63
NO
500. 0.2550 3 10.0 10.5 3200.0 70.08 56.12 34.66
NO
600. 0.3235 3 10.0 10.5 3200.0 70.08 66.17 40.73
NO
700. 0.3629 4 20.0 21.4 6400.0 42.35 49.75 25.17
NO
800. 0.3768 4 20.0 21.4 6400.0 42.35 56.09 27.83
NO
900. 0.3745 4 20.0 21.4 6400.0 42.35 62.34 30.42
NO
1000. 0.3630 4 20.0 21.4 6400.0 42.35 68.55 32.97
NO

MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M:
830. 0.3774 4 20.0 21.4 6400.0 42.35 58.03 28.64
NO

DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB

********************************************
* SUMMARY OF TERRAIN HEIGHTS ENTERED FOR *
* SIMPLE ELEVATED TERRAIN PROCEDURE *
********************************************

TERRAIN DISTANCE RANGE (M)
HT (M) MINIMUM MAXIMUM
------- -------- --------
0. 1. 1000.

***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************

CALCULATION MAX CONC DIST TO TERRAIN
PROCEDURE (UG/M**3) MAX (M) HT (M)
-------------- ----------- --------- -------
SIMPLE TERRAIN 0.3774 830. 0.

***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************

03/24/23

16:54:05
*** SCREEN3 MODEL RUN ***
*** VERSION DATED 13043 ***

ENG-04

SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) = 0.126000
STACK HEIGHT (M) = 15.8500
STK INSIDE DIAM (M) = 0.5100
STK EXIT VELOCITY (M/S)= 296.0000
STK GAS EXIT TEMP (K) = 719.0000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) = 0.0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 0.0000
MIN HORIZ BLDG DIM (M) = 0.0000
MAX HORIZ BLDG DIM (M) = 0.0000

THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.

BUOY. FLUX = 111.828 M**4/S**3; MOM. FLUX = 2321.681 M**4/S**2.

*** FULL METEOROLOGY ***

**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************

*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING
DISTANCES ***

DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M)
DWASH
------- ---------- ---- ----- ----- ------ ------ ------ ------
-----
1. 0.000 1 1.0 1.0 652.1 651.11 11.04 11.03
NO
100. 0.1145E-01 5 1.0 1.2 10000.0 151.56 39.25 38.93
NO
200. 0.1253E-01 5 1.0 1.2 10000.0 151.56 40.48 39.27
NO
300. 0.1409E-01 5 1.0 1.2 10000.0 151.56 42.29 39.74
NO
400. 0.7036E-01 3 10.0 10.5 3200.0 78.50 46.08 28.81
NO
500. 0.1576 3 10.0 10.5 3200.0 78.50 56.35 35.04
NO
600. 0.2269 3 10.0 10.5 3200.0 78.50 66.42 41.14
NO
700. 0.2764 4 20.0 21.4 6400.0 46.46 49.85 25.36
NO
800. 0.3031 4 20.0 21.4 6400.0 46.46 56.26 28.17
NO
900. 0.3108 4 20.0 21.4 6400.0 46.46 62.50 30.74
NO
1000. 0.3088 4 20.0 21.4 6400.0 46.46 68.69 33.26
NO
1100. 0.2975 4 20.0 21.4 6400.0 46.46 74.82 35.23
NO
1200. 0.2847 4 20.0 21.4 6400.0 46.46 80.91 37.14
NO
1300. 0.2714 4 20.0 21.4 6400.0 46.46 86.96 38.99
NO
1400. 0.2580 4 20.0 21.4 6400.0 46.46 92.96 40.81
NO
1500. 0.2465 4 15.0 16.1 4800.0 56.67 99.23 43.27
NO
1600. 0.2386 4 15.0 16.1 4800.0 56.67 105.14 44.98
NO
1700. 0.2304 4 15.0 16.1 4800.0 56.67 111.02 46.65
NO
1800. 0.2221 4 15.0 16.1 4800.0 56.67 116.87 48.29
NO
1900. 0.2139 4 15.0 16.1 4800.0 56.67 122.69 49.90
NO
2000. 0.2059 4 15.0 16.1 4800.0 56.67 128.47 51.49
NO

MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M:
924. 0.3110 4 20.0 21.4 6400.0 46.46 64.05 31.37
NO

DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB

***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************

CALCULATION MAX CONC DIST TO TERRAIN
PROCEDURE (UG/M**3) MAX (M) HT (M)
-------------- ----------- --------- -------
SIMPLE TERRAIN 0.3110 924. 0.

***************************************************
12/21/23
07:46:56
*** SCREEN3 MODEL RUN ***
*** VERSION DATED 13043 ***
ENG-05
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) = 0.126000
STACK HEIGHT (M) = 15.8500
STK INSIDE DIAM (M) = 0.5100
STK EXIT VELOCITY (M/S)= 301.0000
STK GAS EXIT TEMP (K) = 719.0000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) = 0.0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 0.0000
MIN HORIZ BLDG DIM (M) = 0.0000
MAX HORIZ BLDG DIM (M) = 0.0000
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.
BUOY. FLUX = 113.717 M**4/S**3; MOM. FLUX = 2400.778 M**4/S**2.
*** FULL METEOROLOGY ***
**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
------- ---------- ---- ----- ----- ------ ------ ------ ------ -----
1. 0.000 1 1.0 1.0 658.5 657.53 11.16 11.16 NO
100. 0.1141E-01 5 1.0 1.2 10000.0 152.32 39.47 39.15 NO
200. 0.1248E-01 5 1.0 1.2 10000.0 152.32 40.69 39.49 NO
300. 0.1402E-01 5 1.0 1.2 10000.0 152.32 42.49 39.95 NO
400. 0.6662E-01 3 10.0 10.5 3200.0 79.14 46.10 28.83 NO
500. 0.1518 3 10.0 10.5 3200.0 79.14 56.37 35.06 NO
600. 0.2207 3 10.0 10.5 3200.0 79.14 66.43 41.17 NO
700. 0.2706 4 20.0 21.4 6400.0 46.77 49.86 25.38 NO
800. 0.2981 4 20.0 21.4 6400.0 46.77 56.27 28.20 NO
900. 0.3063 4 20.0 21.4 6400.0 46.77 62.51 30.76 NO
1000. 0.3049 4 20.0 21.4 6400.0 46.77 68.70 33.29 NO
MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M:
931. 0.3068 4 20.0 21.4 6400.0 46.77 64.50 31.57 NO
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
********************************************
* SUMMARY OF TERRAIN HEIGHTS ENTERED FOR *
* SIMPLE ELEVATED TERRAIN PROCEDURE *
********************************************
TERRAIN DISTANCE RANGE (M)
HT (M) MINIMUM MAXIMUM
------- -------- --------
0. 1. 1000.
***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************
CALCULATION MAX CONC DIST TO TERRAIN
PROCEDURE (UG/M**3) MAX (M) HT (M)
-------------- ----------- --------- -------
SIMPLE TERRAIN 0.3068 931. 0.
***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************
12/21/23
08:11:18
*** SCREEN3 MODEL RUN ***
*** VERSION DATED 13043 ***
ENG-06
SIMPLE TERRAIN INPUTS:
SOURCE TYPE = POINT
EMISSION RATE (G/S) = 0.126000
STACK HEIGHT (M) = 15.8500
STK INSIDE DIAM (M) = 0.5100
STK EXIT VELOCITY (M/S)= 213.0000
STK GAS EXIT TEMP (K) = 795.0000
AMBIENT AIR TEMP (K) = 293.0000
RECEPTOR HEIGHT (M) = 0.0000
URBAN/RURAL OPTION = RURAL
BUILDING HEIGHT (M) = 0.0000
MIN HORIZ BLDG DIM (M) = 0.0000
MAX HORIZ BLDG DIM (M) = 0.0000
THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.
BUOY. FLUX = 85.762 M**4/S**3; MOM. FLUX = 1087.277 M**4/S**2.
*** FULL METEOROLOGY ***
**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************
*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING DISTANCES ***
DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M) DWASH
------- ---------- ---- ----- ----- ------ ------ ------ ------ -----
1. 0.000 1 1.0 1.0 558.6 557.60 8.55 8.55 NO
100. 0.1190E-01 5 1.0 1.2 10000.0 140.07 36.01 35.67 NO
200. 0.1329E-01 5 1.0 1.2 10000.0 140.07 37.35 36.03 NO
300. 0.3575E-01 3 10.0 10.5 3200.0 69.28 35.36 22.08 NO
400. 0.1510 3 10.0 10.5 3200.0 69.28 45.86 28.44 NO
500. 0.2664 3 10.0 10.5 3200.0 69.28 56.10 34.63 NO
600. 0.3340 3 10.0 10.5 3200.0 69.28 66.14 40.69 NO
700. 0.3721 4 20.0 21.4 6400.0 41.96 49.74 25.15 NO
800. 0.3844 4 20.0 21.4 6400.0 41.96 56.07 27.80 NO
900. 0.3810 4 20.0 21.4 6400.0 41.96 62.33 30.40 NO
1000. 0.3684 4 20.0 21.4 6400.0 41.96 68.53 32.95 NO
1100. 0.3487 4 20.0 21.4 6400.0 41.96 74.68 34.93 NO
1200. 0.3292 4 15.0 16.1 4800.0 50.66 81.05 37.44 NO
1300. 0.3175 4 15.0 16.1 4800.0 50.66 87.09 39.28 NO
1400. 0.3051 4 15.0 16.1 4800.0 50.66 93.08 41.08 NO
1500. 0.2923 4 15.0 16.1 4800.0 50.66 99.04 42.84 NO
1600. 0.2796 4 15.0 16.1 4800.0 50.66 104.97 44.56 NO
1700. 0.2671 4 15.0 16.1 4800.0 50.66 110.85 46.25 NO
1800. 0.2552 4 15.0 16.1 4800.0 50.66 116.71 47.91 NO
1900. 0.2439 4 10.0 10.7 3200.0 68.07 123.04 50.76 NO
2000. 0.2383 4 10.0 10.7 3200.0 68.07 128.81 52.32 NO
MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M:
821. 0.3847 4 20.0 21.4 6400.0 41.96 57.45 28.38 NO
DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB
********************************************
* SUMMARY OF TERRAIN HEIGHTS ENTERED FOR *
* SIMPLE ELEVATED TERRAIN PROCEDURE *
********************************************
TERRAIN DISTANCE RANGE (M)
HT (M) MINIMUM MAXIMUM
------- -------- --------
0. 1. 2000.
***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************
CALCULATION MAX CONC DIST TO TERRAIN
PROCEDURE (UG/M**3) MAX (M) HT (M)
-------------- ----------- --------- -------
SIMPLE TERRAIN 0.3847 821. 0.
***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************

03/24/23

16:55:45
*** SCREEN3 MODEL RUN ***
*** VERSION DATED 13043 ***

FLR-02

SIMPLE TERRAIN INPUTS:
SOURCE TYPE = FLARE
EMISSION RATE (G/S) = 0.126000
FLARE STACK HEIGHT (M) = 18.2900
TOT HEAT RLS (CAL/S) = 0.387028E+08
RECEPTOR HEIGHT (M) = 0.0000
URBAN/RURAL OPTION = RURAL
EFF RELEASE HEIGHT (M) = 37.6055
BUILDING HEIGHT (M) = 0.0000
MIN HORIZ BLDG DIM (M) = 0.0000
MAX HORIZ BLDG DIM (M) = 0.0000

THE REGULATORY (DEFAULT) MIXING HEIGHT OPTION WAS SELECTED.
THE REGULATORY (DEFAULT) ANEMOMETER HEIGHT OF 10.0 METERS WAS ENTERED.

BUOY. FLUX = 641.705 M**4/S**3; MOM. FLUX = 391.299 M**4/S**2.

*** FULL METEOROLOGY ***

**********************************
*** SCREEN AUTOMATED DISTANCES ***
**********************************

*** TERRAIN HEIGHT OF 0. M ABOVE STACK BASE USED FOR FOLLOWING
DISTANCES ***

DIST CONC U10M USTK MIX HT PLUME SIGMA SIGMA
(M) (UG/M**3) STAB (M/S) (M/S) (M) HT (M) Y (M) Z (M)
DWASH
------- ---------- ---- ----- ----- ------ ------ ------ ------
-----
1. 0.000 1 1.0 1.1 1744.5 1743.52 5.34 5.33
NO
100. 0.8529E-04 5 1.0 1.6 10000.0 257.27 53.78 53.55
NO
200. 0.1527E-02 5 1.0 1.6 10000.0 257.27 63.83 63.07
NO
300. 0.1611E-02 5 1.0 1.6 10000.0 257.27 64.99 63.36
NO
400. 0.1704E-02 5 1.0 1.6 10000.0 257.27 66.51 63.68
NO
500. 0.1810E-02 5 1.0 1.6 10000.0 257.27 68.33 64.05
NO
600. 0.1931E-02 5 1.0 1.6 10000.0 257.27 70.42 64.46
NO
700. 0.9960E-02 1 3.0 3.3 960.0 606.24 179.21 233.30
NO
800. 0.2670E-01 1 3.0 3.3 960.0 606.24 200.09 301.25
NO
900. 0.4108E-01 1 3.0 3.3 960.0 606.24 220.54 379.91
NO
1000. 0.6058E-01 1 2.5 2.7 800.0 719.97 253.42 476.07
NO
1100. 0.7134E-01 1 2.5 2.7 800.0 719.97 273.84 576.04
NO
1200. 0.7404E-01 1 2.5 2.7 800.0 719.97 293.95 687.04
NO
1300. 0.7344E-01 1 2.0 2.2 891.6 890.56 339.04 819.29
NO
1400. 0.7093E-01 1 2.0 2.2 891.6 890.56 359.61 952.08
NO
1500. 0.6755E-01 1 2.0 2.2 891.6 890.56 379.92 1096.19
NO
1600. 0.6444E-01 1 2.0 2.2 891.6 890.56 398.68 1251.27
NO
1700. 0.6230E-01 1 2.0 2.2 891.6 890.56 412.44 1416.46
NO
1800. 0.6027E-01 1 2.0 2.2 891.6 890.56 426.35 1593.53
NO
1900. 0.5835E-01 1 2.0 2.2 891.6 890.56 440.36 1782.46
NO
2000. 0.5653E-01 1 2.0 2.2 891.6 890.56 454.48 1983.24
NO

MAXIMUM 1-HR CONCENTRATION AT OR BEYOND 1. M:
1195. 0.7404E-01 1 2.5 2.7 800.0 719.97 292.75 680.07
NO

DWASH= MEANS NO CALC MADE (CONC = 0.0)
DWASH=NO MEANS NO BUILDING DOWNWASH USED
DWASH=HS MEANS HUBER-SNYDER DOWNWASH USED
DWASH=SS MEANS SCHULMAN-SCIRE DOWNWASH USED
DWASH=NA MEANS DOWNWASH NOT APPLICABLE, X<3*LB

***************************************
*** SUMMARY OF SCREEN MODEL RESULTS ***
***************************************

CALCULATION MAX CONC DIST TO TERRAIN
PROCEDURE (UG/M**3) MAX (M) HT (M)
-------------- ----------- --------- -------
SIMPLE TERRAIN 0.7404E-01 1195. 0.

***************************************************
** REMEMBER TO INCLUDE BACKGROUND CONCENTRATIONS **
***************************************************
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX E
GAS AND LIQUID ANALYSES

Ovintiv USA Inc.
Ranch Compressor Station
Gas Analysis Fuel Gas Analysis Oil/Condensate
Analysis
Oil/Condensate
BW Vapor
Where was the sample taken?Inlet Separator
JT Skid After
Sweetening Unit
(Normalized)
Tank Oil Vapor in equilibrium
with Tank Oil
Sample type?Gas Gas Liquid Gas
Who analyzed the sample?Alliance ProMax ProMax NA
Date of sample:8/31/2022 8/31/2022 NA
Temperature (F):85 0 78 96
Pressure (psig):16 206.068*0 0
Component
Molecular
Weight
(grams/mole)
Net Heating
Value
(Btu/scf)
mole % weight % mole % weight % mole % weight % mol% weight %
nitrogen 28.013 0 0.386 0.456 0.419 0.584 0.000 0.000 0.070 0.063
CO2 44.010 0 0.893 1.659 0.943 2.066 0.013 0.006 3.565 5.008
H2S 34.082 586.8 0.001 0.001 0.002 0.004 0.000 0.000 0.000 0.000
methane (C1)16.042 909.4 74.905 50.723 80.696 64.443 0.208 0.032 52.891 27.083
ethane (C2)30.069 1618.7 11.294 14.335 11.530 17.258 0.515 0.147 19.104 18.335
propane (C3)44.096 2314.9 5.172 9.626 4.530 9.945 1.028 0.429 9.360 13.174
iso-butane (C4)58.122 3000.4 0.807 1.981 0.509 1.474 0.428 0.236 1.482 2.749
nor-butane (C4)58.122 3010.8 2.093 5.136 1.028 2.975 1.644 0.905 3.988 7.398
iso-pentane (C5)72.149 3699 0.586 1.785 0.128 0.458 1.208 0.826 1.137 2.618
nor-pentane (C5)72.149 3706.9 1.207 3.677 0.180 0.645 3.485 2.381 2.481 5.713
hexanes (C6)86.170 4403.8 0.645 2.345 0.020 0.087 6.211 5.068 1.364 3.751
heptanes (C7)100.200 5100 0.742 3.139 0.001 0.004 26.631 25.271 1.884 6.027
octanes (C8)114.230 5796.1 0.251 1.213 0.000 0.000 23.556 25.483 0.578 2.107
nonanes (C9)128.260 6493.2 0.047 0.253 0.000 0.000 10.590 12.864 0.091 0.373
decanes (C10+)142.290 7189.6 0.080 0.482 0.000 0.000 10.837 14.603 0.032 0.146
n-hexanes 86.170 4403.8 0.734 2.671 0.012 0.053 8.060 6.578 1.770 4.868
2,2,4-trimethylpentane 114.23 5559.2 0.000 0.000 0.000 0.000 0.010 0.011 0.001 0.003
benzene 78.110 3590.9 0.044 0.144 0.001 0.003 0.460 0.340 0.059 0.147
toluene 92.140 4273.6 0.061 0.238 0.000 0.000 2.423 2.114 0.112 0.329
ethylbenzene 106.170 4970.5 0.002 0.010 0.000 0.000 0.219 0.220 0.004 0.013
xylenes (M,P,O)106.170 4958.2 0.022 0.101 0.000 0.000 2.474 2.487 0.029 0.098
TOTALS:99.975 99.975 100.000 100.000 100.000 100.000 100.000 100.000
GOR N/A N/A N/A N/A
Heat release (Btu/scf)1265.11 1084.51 5343.13 1589.80
Molecular Weight (lb/lb-mol)23.69 20.09 105.59 31.33
Gas Specific Gravity 0.82 0.69 N/A 1.08
VOC content of total sample (%)12.495 32.800 6.410 15.644 99.264 99.816 24.370 49.512
VOC content of hydrocarbon fraction (%) 12.660 33.518 6.498 16.071 99.277 99.822 25.290 52.157
Benzene content of total sample (%)0.044 0.144 0.001 0.003 0.460 0.340 0.059 0.147
Benzene content of hydrocarbon fraction (%) 0.044 0.147 0.001 0.003 0.460 0.340 0.061 0.154
HAPs content of total sample (%)0.864 3.164 0.013 0.056 13.646 11.751 1.974 5.457
HAPs content of hydrocarbon fraction (%) 0.875 3.233 0.013 0.058 13.648 11.751 2.048 5.748
H2S content of sample (%)0.0010 0.0014 0.0024 0.0041 0.0000 0.0000 0.0001 0.0001
H2S content of sample (ppm)10.00 14.39 24.00 40.72 0.07 0.02 1.26 1.38
H2S content of sample (grains/100 SCF)0.6 1.5 N/A 0.1
EXTENDED GAS ANALYSIS
SAMPLE DATA
PROJECT NO…………………………….AAS-2022-0874 SAMPLE ID…………………….…………………………………Gas
COMPANY NAME………...………………………Ovintiv USA, Inc.ANALYSIS DATE……………………………………………..9/8/2022
SITE………………………………..……………………………………………..Ranch SAMPLE DATE…………………………………………….8/31/2022
UNIT ID…………………………………………………………………………Facility Inlet CYLINDER NO…………………………………………….GV-11
SAMPLED BY………………………………………………………….MJW LAB ANALYST……………………………………………………….……….CLB
FIELD DATA
SAMPLE PRESSURE………………...…..…………………………...………..15.5 psig SAMPLE TEMP…………………………………..85 F
AMBIENT PRESSURE…………..…………………………. 12.3 psi AMBIENT TEMP……………………………………………….90 F
COMMENTS:*The H2S field stain tube value of 0.00006 mole% is substitued into the MOLE% column. All other values
from the GC are renormalized. The WT%, GPM, and physical constants are adjusted to reflect this change.
LABORATORY DATA
COMPONENT MOLE %WT%GPM
HYDROGEN SULFIDE…………………………..……..……………………………...………….………………………………..0.0001 0.0001 0.0000
CARBON DIOXIDE…………………………...……...…………………………………..……………………………………………0.8932 1.6599 0.1527
NITROGEN…………………………...……...…………………………………..……………………………………………0.3858 0.4564 0.0425
METHANE…...………………………………………..……….…………….…...……………………………………….74.9054 50.7438 12.7242
ETHANE...…………………………………………………...…………………..………………………….11.2942 14.3408 3.0265
PROPANE…………………….……………………………………………………….....…………………………….5.1716 9.6299 1.4277
ISOBUTANE………………………………………………………….....…………………………….0.8074 1.9817 0.2647
N-BUTANE…………………...………………………………………...……...……………………………….2.0934 5.1380 0.6613
ISOPENTANE……………………………………………………………………………………………0.5860 1.7853 0.2147
N-PENTANE………………………...…………………………………..……...…………………………………..1.1598 3.5336 0.4213
CYCLOPENTANE………………………………….……….……………...…………………………..0.0476 0.1411 0.0141
N-HEXANE……………………………………..…......………………..……………………………………………0.7342 2.6718 0.3025
CYCLOHEXANE……………….……………………………………………………………………………0.1477 0.5248 0.0503
OTHER HEXANES………………………….………………………………………………………………………….0.4971 1.7996 0.1989
HEPTANES……………………………….……………………………………………………………………………….0.5783 2.4446 0.2658
METHYLCYCLOHEXANE…………..……………………………………………………………………0.1638 0.6791 0.0659
2,2,4 TRIMETHYLPENTANE…………………….………………………………………………………….0.0001 0.0005 0.0000
BENZENE…………………………………...………………………………………………………………..0.0436 0.1437 0.0122
TOLUENE………………………………..…………………………………………………………………0.0612 0.2382 0.0205
ETHYLBENZENE………………...…………………………………………………………………………..0.0022 0.0101 0.0009
XYLENES……………………………………...………………………………………………………………….0.0225 0.1007 0.0087
OCTANES……………………..………………………………………………………….. 0.2515 1.2068 0.1252
NONANES……………………………………………………………………..0.0467 0.2522 0.0260
DECANES………………………………………………………………………………….0.0803 0.4821 0.0493
SUBTOTAL 99.9737 99.9645 20.0761
OXYGEN/ARGON 0.0263 0.0355 0.0023
TOTAL 100.00 100.00 20.08
BTU @
MOLECULAR WEIGHT……………………….…………………………………………23.6811 NET DRY REAL 1264.4492 /scf
RELATIVE DENSITY (AIR=1)……………………………………..…………………………0.8176
COMPRESSIBILITY FACTOR………………………………………...….0.9954 GROSS DRY REAL 1394.9534 /scf
GROSS WET REAL 1370.4024 /scf
ANALYTICAL PROCEDURES TAKEN FROM GPA 2286-95
5530 Marshall Street
Arvada, Colorado 80002
Phone: [phone]
Fax: [phone]
SAMPLE DATA
PROJECT NO………...…….………………….AAS-2022-0874 SAMPLE ID…….………………………………..Pressurized Liquid
COMPANY NAME………...….…..…..………Ovintiv USA, Inc.ANALYSIS DATE…………………………………………9/7/2022
SITE………………………….………….………Ranch Comp Station SAMPLE DATE………….….……………………..8/31/2022
..……………UNIT ID………………………Inlet Separator CYLINDER NO………….…………………..…..40102
SAMPLED BY……………….…………………MJW LAB ANALYST………………………………………………………………CLB
FIELD DATA
SAMPLE PROBE PRESSURE (psig)…………………..…......................................17.7 SAMPLE PROBE TEMP (⁰F)……..….…..…………………………………..79
UNIT GAUGE PRESSURE (psig)…………………………16 UNIT GAUGE TEMP (⁰F)……………………………NA
AMBIENT PRESSURE (psi)…………..…..….……………..12.3 AMBIENT TEMP (⁰F)……...…….………………………………..90
COMMENTS:
LABORATORY DATA
COMPONENT MOLE %WT%LV%
CARBON DIOXIDE…………………………..……..……………………………...………….………………………………..0.0224 0.0102 0.0088
NITROGEN (AIR)…………………………...……...…………………………………..……………………………………………0.0000 0.0000 0.0000
METHANE…...………………………………………..……….…………….…...……………………………………….0.7093 0.1175 0.2766
ETHANE...…………………………………………………...…………………..………………………….0.7290 0.2264 0.4485
PROPANE…………………….……………………………………………………….....…………………………….1.2268 0.5588 0.7775
ISOBUTANE………………………………………………………….....…………………………….0.5012 0.3009 0.3773
N-BUTANE…………………...………………………………………...……...……………………………….1.9918 1.1959 1.4445
ISOPENTANE……………………………………………………………………………………………1.6795 1.2517 1.4129
N-PENTANE………………………...…………………………………..……...…………………………………..4.7582 3.5462 3.9676
CYCLOPENTANE………………………………….……….……………...…………………………..0.3563 0.2581 0.2427
N-HEXANE……………………………………..…......………………..……………………………………………13.9142 12.3862 13.1622
CYCLOHEXANE……………….……………………………………………………………………………3.6811 3.2002 2.8804
OTHER HEXANES………………………….………………………………………………………………………….8.0799 7.1438 7.3438
OTHER HEPTANES……………………………….……………………………………………………………………………….24.3460 25.1486 25.5412
METHYLCYCLOHEXANE…………..……………………………………………………………………6.5595 6.6530 6.0624
2,2,4 TRIMETHYLPENTANE…………………….………………………………………………………….0.0281 0.0331 0.0324
BENZENE…………………………………...………………………………………………………………..0.7427 0.5993 0.4778
TOLUENE………………………………..…………………………………………………………………2.5312 2.4092 1.9488
ETHYLBENZENE………………...…………………………………………………………………………..0.1495 0.1639 0.1326
XYLENES……………………………………...………………………………………………………………….1.6865 1.8495 1.4980
OTHER OCTANES……………………………………………………………………………16.8362 19.7799 19.3124
NONANES……………………………………………………………………………….6.8557 9.0678 8.7802
DECANES PLUS……………………………………………………………………………………2.6151 4.0997 3.8714
TOTAL 100.00000 100.00000 100.00000
SAMPLE FRACTIONS TOTAL C6+ C7+C10+
SPG LIQUID………………………………………………………………………………..0.706 0.717 0.727 0.748
API GRAVITY……………………………………………………………………………………..69.0 65.8 63.2 57.7
MOLECULAR WEIGHT………………………………………………………………………………96.8 101.8 108.7 151.1
ABSOLUTE DENSITY (lbs/gal)………………………………………………………………………………………………..5.9 6.0 6.1 6.2
HEATING VALUE LIQUID IDL GAS (GBTU/gal)…………………………..119879.2 122624.3 123900.0 129689.7
GBTU/GAL LIQUID…………………………………………………………..119981.3 121742.9 123012.1 126513.2
NBTU/GAL LIQUID…………………………………………………………………….112321.4 114567.7 114717.2 118628.3
VAPOR/LIQUID (SCF/gal)………………………………………………………………………………………23.1 22.3 21.2 15.7
VAPOR PRESSURE (psia)……………………………………………………………………………….48.4 2.3 1.2 0.1
ANALYTICAL PROCEDURES TAKEN FROM GPA-2186, ASTM D6730-01(2011), ASTM D7169, GPA-2103M.
5530 Marshall Street
Arvada, Colorado 80002
Phone: [phone]
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EXTENDED NATURAL GAS LIQUID ANALYSIS
Page 1 of 6 8:49 AM, 9/13/2022
SAMPLE DATA
PROJECT NO………...…….………………….AAS-2022-0874 SAMPLE ID…….………………………………..Pressurized Liquid
COMPANY NAME………...….…..…..………Ovintiv USA, Inc.ANALYSIS DATE…………………………………………9/7/2022
SITE………………………….………….………Ranch Comp Station SAMPLE DATE………….….……………………..8/31/2022
UNIT ID…………………………....……………Slug Catcher CYLINDER NO………….…………………..…..40102
SAMPLED BY……………….…………………MJW LAB ANALYST………………………………………………………………CLB
FIELD DATA
SAMPLE PROBE PRESSURE (psig)…………………..…......................................17.7 SAMPLE PROBE TEMP (⁰F)……..….…..…………………………………..79
UNIT GAUGE PRESSURE (psig)…………………………16 UNIT GAUGE TEMP (⁰F)……………………………NA
AMBIENT PRESSURE (psi)…………..…..….……………..12.3 AMBIENT TEMP (⁰F)……...…….………………………………..90
COMMENTS:
LABORATORY DATA
COMPONENT MOLE %WT%LV%
Air…………………………………………………………………0.0000 0.0000 0.0000
Carbon Dioxide…………………………………..0.0224 0.0102 0.0088
Methane………………………………………………0.7093 0.1175 0.2766
Ethane…………………………………………………………..0.7290 0.2264 0.4485
Propane…………………………………………………………1.2268 0.5588 0.7775
Isobutane……………………………………………...………………………..0.5012 0.3009 0.3773
n-Butane……………………………………………………………..1.9918 1.1959 1.4445
Cyclopentane……………………………………………..0.3563 0.2581 0.2427
Isopentane……………………………………………………………………………1.6795 1.2517 1.4129
n-Pentane…………………………………………….4.7582 3.5462 3.9676
Unknown C5s……………………………………………..0.0000 0.0000 0.0000
Neopentane………………………………………………………….0.0000 0.0000 0.0000
Benzene……………………………………………………………..….0.7427 0.5993 0.4778
Methylcyclopentane……………………………………………………………………………….2.3430 2.0369 1.9062
Cyclohexane………………………………………………………………………..3.6811 3.2002 2.8804
2,2-Dimethylbutane……………………………………………………………………..0.0710 0.0632 0.0681
Neohexane……………………………………………………………………………………………0.0000 0.0000 0.0000
2-Methylpentane…………………………………………………………………………………………….3.2925 2.9310 3.1411
2,3-Dimethylbutane……………………………………………………………….0.3481 0.3099 0.3281
3-Methylpentane……………………………………………………………………………..2.0253 1.8029 1.9002
Unknown C6s…………………………………………………………………….0.0000 0.0000 0.0000
n-Hexane………………………………………………………………..13.9142 12.3862 13.1622
Toluene……………………………………………………………..2.5312 2.4092 1.9488
1,1-Dimethylcyclopentane………………………………………0.3995 0.4052 0.3766
1,t-3-Dimethylcyclopentane………………………………………………0.4185 0.4245 0.3975
1,c-3-Dimethylcyclopentane…………………………………..0.5100 0.5173 0.4863
1,t-2-Dimethylcyclopentane…………………………………………0.8254 0.8372 0.7809
Methylcyclohexane………………………………………………..6.5595 6.6530 6.0624
1,c-2-Dimethylcyclopentane………………………………………………0.0542 0.0550 0.0499
Ethylcyclopentane…………………………………..0.2632 0.2670 0.2442
Cycloheptane…………………………………………………………0.0000 0.0000 0.0000
2,2-Dimethylpentane…………………………………………………0.1381 0.1429 0.1486
2,4-Dimethylpentane…………………………………………………………0.3005 0.3111 0.3239
2,2,3-Trimethylbutane………………………………………………………0.0196 0.0203 0.0206
3,3-Dimethylpentane…………………………………………………………………0.0978 0.1012 0.1024
2-Methylhexane………………………………………………………..2.1877 2.2645 2.3370
2,3-Dimethylpentane……………………………………………………………….0.6985 0.7230 0.7289
3-Methylhexane………………………………………………………………..2.3167 2.3979 2.4447
3-Ethylpentane………………………………………………………………….0.1956 0.2025 0.2031
n-Heptane…………………………………………….15.9206 16.4791 16.8966
Triptane………………………………………0.0000 0.0000 0.0000
Unknown C7s………………………………………………….0.0000 0.0000 0.0000
5530 Marshall Street
Arvada, Colorado 80002
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EXTENDED NATURAL GAS LIQUID ANALYSIS
DHA COMPONENT ANALYSIS
Page 2 of 6 8:49 AM, 9/13/2022
Styrene……………………………………………………0.0000 0.0000 0.0000
Ethylbenzene……………………………………………………………0.1495 0.1639 0.1326
o-Xylene…………………………………………………………..0.2942 0.3227 0.2573
m-Xylene………………………………………………………….1.0062 1.1034 0.8957
p-Xylene………………………………………………………………………0.3861 0.4234 0.3450
1,1,3-Trimethylcyclopentane…………………………………………………………0.0000 0.0000 0.0000
1,t-2,c-4-Trimethylcyclopentane…………………………0.2503 0.2902 0.2722
1,t-2,c-3-Trimethylcyclopentane………………………………..0.2275 0.2638 0.2453
1,c-3-Dimethylcyclohexane……………………………0.0156 0.0180 0.0165
1,t-4-Dimetylcyclohexane………………………..0.0000 0.0000 0.0000
1,1-Dimethylcyclohexane………………………………0.2235 0.2590 0.2327
1-Methyl-c-3-ethylcyclopentane……………………………………0.0583 0.0675 0.0613
1-Methyl-t-2-ethylcyclopentane…………………………0.1126 0.1305 0.1189
1,1,2-Trimethylcyclopentane…………………………0.1842 0.2136 0.1939
1,c-2,t-4-Trimethylcyclopentane…………………………….0.0000 0.0000 0.0000
1,c-2,t-3-Trimethylcyclopentane……………………..1.3697 1.5876 1.4451
1-Methyl-t-3-ethylcyclopentane……………………………………0.0521 0.0603 0.0555
1-Methyl-1-ethylcyclopentane……………………………….0.0339 0.0392 0.0352
1,t-3-Dimethylcyclohexane……………………………0.5242 0.6077 0.5431
1,c-4-Dimethylcyclohexane…………………………………….0.0000 0.0000 0.0000
1,c-2,c-3-Trimethylcyclopentane……………………………….0.0000 0.0000 0.0000
Isopropylcyclopentane…………………………….0.0353 0.0409 0.0369
1-Ethyl-c-2-methylcyclopentane……………………………..0.0000 0.0000 0.0000
1,c-2-Dimethylcyclohexane…………………………………………………0.0419 0.0486 0.0428
n-Propylcyclopentane………………………………………………0.8755 1.0149 0.9169
Ethylcyclohexane…………………………………0.1445 0.1675 0.1491
Cyclooctane…………………………………………0.0000 0.0000 0.0000
n-Octane………………………………………………..7.7502 9.1451 9.1336
Unknown C8s…………………………………0.1444 0.1704 0.1701
Dilsobutyl………………………………………..0.0000 0.0000 0.0000
Isooctane……………………………………………………..0.0000 0.0000 0.0000
2,2,4-Trimethylpentane………………………………..0.0281 0.0331 0.0324
2,2-Dimethylhexane……………………………0.2409 0.2842 0.2864
2,4-Dimethylhexane……………………………………….0.2172 0.2563 0.2564
2,5-Dimethylhexane…………………………….0.1403 0.1656 0.1673
2,2,3-Trimethylpentane………………………………………0.0000 0.0000 0.0000
3,3-Dimethylhexane……………………………..0.1013 0.1195 0.1180
2,3,4-Trimethylpentane………………………………..0.0243 0.0287 0.0280
2,3-Dimethylhexane……………………………………..0.1650 0.1947 0.1917
2-Methylheptane………………………………..……..2.0723 2.4453 2.4556
4-Methylheptane…………………………………0.4398 0.5190 0.5163
3-Methylheptane…………………………………………0.8504 1.0035 0.9966
3,4-Dimethylhexane…………………………….0.0401 0.0473 0.0461
3-Ethylhexane………………………………….0.5011 0.5912 0.5809
C9………………………………………………………………..…..6.8557 9.0678 8.7802
C10……………………………………………………………..1.7301 2.5429 2.4427
C11………………………………………………………………..0.5294 0.8548 0.8101
C12……………………………………………………0.1691 0.2975 0.2786
C13…………………………………………………….0.0896 0.1706 0.1457
C14…………………………………………………………0.0312 0.0640 0.0540
C15………………………………………………………………….0.0172 0.0377 0.0316
C16……………………………………………………………….0.0116 0.0272 0.0226
C17……………………………………………………………..0.0087 0.0217 0.0181
C18…………………………………………………………..0.0068 0.0179 0.0149
C19…………………………………………………………………………0.0053 0.0147 0.0121
C20………………………………………………………….0.0045 0.0131 0.0107
C21…………………………………………………………………………..0.0033 0.0102 0.0083
C22………………………………………………………………………..0.0031 0.0099 0.0080
C23…………………………………………………………………….0.0023 0.0077 0.0062
C24………………………………………………………………..0.0021 0.0072 0.0058
C25…………………………………………………………….0.0007 0.0027 0.0021
C26……………………………………………………….0.0000 0.0000 0.0000
C27…………………………………………………………………..0.0000 0.0000 0.0000
C28………………………………………………………………..0.0000 0.0000 0.0000
C29…………………………………………………………………..0.0000 0.0000 0.0000
C30……………………………………………………….0.0000 0.0000 0.0000
C31…………………………………………………….0.0000 0.0000 0.0000
C32…………………………………………………..0.0000 0.0000 0.0000
C33……………………………………………………..0.0000 0.0000 0.0000
C34………………………………………………….0.0000 0.0000 0.0000
C35……………………………………………………0.0000 0.0000 0.0000
C36+…………………………………………………0.0000 0.0000 0.0000
TOTAL 100.0000 100.0000 100.0000
Page 3 of 6 8:49 AM, 9/13/2022
SAMPLE DATA
PROJECT NO………...…….………………….AAS-2022-0874 SAMPLE ID…….………………………………..Pressurized Liquid
COMPANY NAME………...….…..…..………Ovintiv USA, Inc.ANALYSIS DATE…………………………………………9/7/2022
SITE………………………….………….………Ranch Comp Station SAMPLE DATE………….….……………………..8/31/2022
UNIT ID…………………………....……………Slug Catcher CYLINDER NO………….…………………..…..40102
SAMPLED BY……………….…………………MJW LAB ANALYST………………………………………………………………CLB
FIELD DATA
SAMPLE PROBE PRESSURE (psig)…………………..…......................................17.7 SAMPLE PROBE TEMP (⁰F)……..….…..…………………………………..79
UNIT GAUGE PRESSURE (psig)…………………………16 UNIT GAUGE TEMP (⁰F)……………………………NA
AMBIENT PRESSURE (psi)…………..…..….……………..12.3 AMBIENT TEMP (⁰F)……...…….………………………………..90
COMMENTS:
LABORATORY DATA
COMPONENT MOLE %WT%LV%
Air……………………………………………………..0.0000 0.0000 0.0000
Carbon Dioxide…………………………………………………………….…0.0224 0.0102 0.0088
C1……………………………………………………..0.7093 0.1175 0.2766
C2…………………………………………………..0.7290 0.2264 0.4485
C3……………………………………………………………………..1.2268 0.5588 0.7775
C4…………………………………………………………………………2.4930 1.4968 1.8218
C5……………………………………………………………………………6.7939 5.0560 5.6232
C6…………………………………………..……………….26.4179 23.3295 23.8642
C7……………………………………...…………………..33.4367 34.2108 33.5524
C8………………………………………………………………18.7002 21.8264 20.9754
C9……………………………………………………………………………6.8557 9.0678 8.7802
C10………………………………………………………………..1.7301 2.5429 2.4427
C11……………………………………………………………………………….0.5294 0.8548 0.8101
C12………………………………………………………………………………………..0.1691 0.2975 0.2786
C13……………………………………………………..0.0896 0.1706 0.1457
C14……………………………………………………..0.0312 0.0640 0.0540
C15………………………………………………….0.0172 0.0377 0.0316
C16………………………………………………………………….0.0116 0.0272 0.0226
C17………………………………………………………………0.0087 0.0217 0.0181
C18……………………………………………………………………..0.0068 0.0179 0.0149
C19………………………………………………………………….0.0053 0.0147 0.0121
C20…………………………………………………………………..0.0045 0.0131 0.0107
C21………………………………………………………………………….0.0033 0.0102 0.0083
C22………………………………………………………………………………0.0031 0.0099 0.0080
C23…………………………………………………………………………..0.0023 0.0077 0.0062
C24……………………………………………………………………………..0.0021 0.0072 0.0058
C25…………………………………………………………………..0.0007 0.0027 0.0021
C26……………………………………………………………………….0.0000 0.0000 0.0000
C27…………………………………………….0.0000 0.0000 0.0000
C28…………………………………………………………………..0.0000 0.0000 0.0000
C29……………………………………………………..0.0000 0.0000 0.0000
C30……………………………………………………0.0000 0.0000 0.0000
C31………………………………………………………0.0000 0.0000 0.0000
C32………………………………………………….0.0000 0.0000 0.0000
C33…………………………………………………..0.0000 0.0000 0.0000
C34………………………………………………….0.0000 0.0000 0.0000
C35……………………………………………………0.0000 0.0000 0.0000
C36+………………………………………………..0.0000 0.0000 0.0000
TOTAL 100.0000 100.0000 100.0000
5530 Marshall Street
Arvada, Colorado 80002
Phone: [phone]
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EXTENDED NATURAL GAS LIQUIDS ANALYSIS
BY CARBON NUMBER
Page 4 of 6 8:49 AM, 9/13/2022
SAMPLE DATA
PROJECT NO………...…….………………….AAS-2022-0874 SAMPLE ID…….………………………………..Sales Oil
COMPANY NAME………...….…..…..………Ovintiv USA, Inc.ANALYSIS DATE…………………………………………9/7/2022
SITE………………………….………….………Ranch Comp Station SAMPLE DATE………….….……………………..8/31/2022
UNIT ID…………………………....……………Storage Tank CYLINDER NO………….…………………..…..Jar
SAMPLED BY……………….…………………Ovintiv USA, Inc.LAB ANALYST………………………………………………………………CLB
FIELD DATA
SAMPLE PRESSURE (psig)…………………..…......................................NA SAMPLE TEMP (⁰F)……..….…..…………………………………..86
AMBIENT PRESSURE (psi)…………..…..….……………..12.3 AMBIENT TEMP (⁰F)……...…….………………………………..90
COMMENTS:
LABORATORY DATA
API GRAVITY…………………………………..67.3
ASTM D5002
RVP EQUIVALENT (psi)…………………….7.3
ASTM D6377*
NOTES:*RVPe = VPCR4(100⁰F) x A
A = 0.915 for ambient samples or 0.834 for pressurized samples
5530 Marshall Street
Arvada, Colorado 80002
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Fax: [phone]
PHYSICAL PROPERTY TESTING
Page 5 of 6 8:49 AM, 9/13/2022
SAMPLE DATA
PROJECT NO………...…….………………….AAS-2022-0874 SAMPLE ID…….………………………………..Pressurized Liquid
COMPANY NAME………...….…..…..………Ovintiv USA, Inc.ANALYSIS DATE…………………………………………9/7/2022
SITE………………………….………….………Ranch Comp Station SAMPLE DATE………….….……………………..8/31/2022
UNIT ID…………………………....……………Slug Catcher CYLINDER NO………….…………………..…..40102
SAMPLED BY……………….…………………MJW LAB ANALYST………………………………………………………………CLB
FIELD DATA
SAMPLE PROBE PRESSURE (psig)…………………..…......................................17.7 SAMPLE PROBE TEMP (⁰F)……..….…..…………………………………..79
UNIT GAUGE PRESSURE (psig)…………………………16 UNIT GAUGE TEMP (⁰F)……………………………NA
AMBIENT PRESSURE (psi)…………..…..….……………..12.3 AMBIENT TEMP (⁰F)……...…….………………………………..90
COMMENTS:
RECORDED PRESSURE (psia)…………………………………………………………………………………….30.0
PROMAX CALCULATED PRESSURE (psia)…………………………29.8
DIFFERENCE………………………………………………………….0.7%
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BUBBLE POINT QUALITY ASSURANCE
Page 6 of 6 8:49 AM, 9/13/2022
Ovintiv USA Inc.
Ranch Compressor Station
Gas Analysis Fuel Gas Analysis Oil/Condensate
Analysis
Oil/Condensate
BW Vapor
Where was the sample taken?Inlet Separator
JT Skid After
Sweetening Unit
(Normalized)
Tank Oil Vapor in equilibrium
with Tank Oil
Sample type?Gas Gas Liquid Gas
Who analyzed the sample?Alliance ProMax ProMax NA
Date of sample:8/31/2022 8/31/2022 NA NA
Temperature (F):85 0 78 96
Pressure (psig):16 206 0 0
Component
Molecular
Weight
(grams/mole)
Net Heating
Value
(Btu/scf)
mole % weight % mole % weight % mole % weight % mol% weight %
nitrogen 28.013 0 0.386 0.456 0.419 0.584 0.000 0.000 0.070 0.063
CO2 44.010 0 0.893 1.659 0.943 2.066 0.013 0.006 3.565 5.008
H2S 34.082 586.8 0.001 0.001 0.002 0.004 0.000 0.000 0.000 0.000
methane (C1) 16.042 909.4 74.905 50.723 80.696 64.443 0.208 0.032 52.891 27.083
ethane (C2) 30.069 1618.7 11.294 14.335 11.530 17.258 0.515 0.147 19.104 18.335
propane (C3) 44.096 2314.9 5.172 9.626 4.530 9.945 1.028 0.429 9.360 13.174
iso-butane (C4) 58.122 3000.4 0.807 1.981 0.509 1.474 0.428 0.236 1.482 2.749
nor-butane (C4) 58.122 3010.8 2.093 5.136 1.028 2.975 1.644 0.905 3.988 7.398
iso-pentane (C5) 72.149 3699 0.586 1.785 0.128 0.458 1.208 0.826 1.137 2.618
nor-pentane (C5) 72.149 3706.9 1.207 3.677 0.180 0.645 3.485 2.381 2.481 5.713
hexanes (C6) 86.170 4403.8 0.645 2.345 0.020 0.087 6.211 5.068 1.364 3.751
heptanes (C7) 100.200 5100 0.742 3.139 0.001 0.004 26.631 25.271 1.884 6.027
octanes (C8) 114.230 5796.1 0.251 1.213 0.000 0.000 23.556 25.483 0.578 2.107
nonanes (C9) 128.260 6493.2 0.047 0.253 0.000 0.000 10.590 12.864 0.091 0.373
decanes (C10+) 142.290 7189.6 0.080 0.482 0.000 0.000 10.837 14.603 0.032 0.146
n-hexanes 86.170 4403.8 0.734 2.671 0.012 0.053 8.060 6.578 1.770 4.868
2,2,4-trimethylpentane 114.23 5559.2 0.000 0.000 0.000 0.000 0.010 0.011 0.001 0.003
benzene 78.110 3590.9 0.044 0.144 0.001 0.003 0.460 0.340 0.059 0.147
toluene 92.140 4273.6 0.061 0.238 0.000 0.000 2.423 2.114 0.112 0.329
ethylbenzene 106.170 4970.5 0.002 0.010 0.000 0.000 0.219 0.220 0.004 0.013
xylenes (M,P,O) 106.170 4958.2 0.022 0.101 0.000 0.000 2.474 2.487 0.029 0.098
TOTALS: 99.975 99.975 100.000 100.000 100.000 100.000 100.000 100.000
GOR N/A N/A N/A N/A
Heat release (Btu/scf) 1265.11 1084.51 5343.13 1589.80
Molecular Weight (lb/lb-mol) 23.69 20.09 105.59 31.33
Gas Specific Gravity 0.82 0.69 N/A 1.08
VOC content of total sample (%) 12.495 32.800 6.410 15.644 99.264 99.816 24.370 49.512
VOC content of hydrocarbon fraction (%) 12.660 33.518 6.498 16.071 99.277 99.822 25.290 52.157
Benzene content of total sample (%) 0.044 0.144 0.001 0.003 0.460 0.340 0.059 0.147
Benzene content of hydrocarbon fraction (%) 0.044 0.147 0.001 0.003 0.460 0.340 0.061 0.154
HAPs content of total sample (%) 0.864 3.164 0.013 0.056 13.646 11.751 1.974 5.457
HAPs content of hydrocarbon fraction (%) 0.875 3.233 0.013 0.058 13.648 11.751 2.048 5.748
H2S content of sample (%)0.0010 0.0014 0.0024 0.0041 0.0000 0.0000 0.0001 0.0001
H2S content of sample (ppm)10.00 14.39 24.00 40.72 0.07 0.02 1.26 1.38
H2S content of sample (grains/100 SCF)0.6 1.5 N/A 0.1
Ovintiv USA Inc.
Ranch Compressor Station
Where was the sample taken?
Sample type?
Who analyzed the sample?
Date of sample:
Temperature (F):
Pressure (psig):
Component
Molecular
Weight
(grams/mole)
Net Heating
Value
(Btu/scf)
nitrogen 28.013 0
CO2 44.010 0
H2S 34.082 586.8
methane (C1)16.042 909.4
ethane (C2)30.069 1618.7
propane (C3)44.096 2314.9
iso-butane (C4)58.122 3000.4
nor-butane (C4)58.122 3010.8
iso-pentane (C5)72.149 3699
nor-pentane (C5)72.149 3706.9
hexanes (C6)86.170 4403.8
heptanes (C7)100.200 5100
octanes (C8)114.230 5796.1
nonanes (C9)128.260 6493.2
decanes (C10+)142.290 7189.6
n-hexanes 86.170 4403.8
2,2,4-trimethylpentane 114.23 5559.2
benzene 78.110 3590.9
toluene 92.140 4273.6
ethylbenzene 106.170 4970.5
xylenes (M,P,O)106.170 4958.2
TOTALS:
GOR
Heat release (Btu/scf)
Molecular Weight (lb/lb-mol)
Gas Specific Gravity
VOC content of total sample (%)
VOC content of hydrocarbon fraction (%)
Benzene content of total sample (%)
Benzene content of hydrocarbon fraction (%)
HAPs content of total sample (%)
HAPs content of hydrocarbon fraction (%)
H2S content of sample (%)
H2S content of sample (ppm)
H2S content of sample (grains/100 SCF)
PCSV Liquid Oil/Condensate
Flash
NGL Tank Oil Tank
Liquid Gas
ProMax ProMax
NA NA
-7.94489 78
100 0
mole % weight % mole % weight %
0.002 0.001 0.097 0.083
0.274 0.211 1.129 1.523
0.000 0.000 0.000 0.000
4.604 1.294 50.587 24.867
10.638 5.606 19.400 17.875
20.022 15.473 11.095 14.991
6.814 6.941 1.839 3.274
22.477 22.896 4.833 8.608
7.901 9.991 1.386 3.064
15.664 19.807 2.890 6.388
5.264 7.950 1.725 4.554
1.075 1.888 2.064 6.338
0.032 0.065 0.561 1.963
0.000 0.001 0.078 0.306
0.000 0.000 0.019 0.082
4.933 7.450 1.954 5.160
0.001 0.001 0.001 0.003
0.240 0.328 0.114 0.273
0.057 0.092 0.165 0.466
0.000 0.000 0.005 0.015
0.001 0.002 0.048 0.155
99.999 99.999 99.989 99.989
N/A 9.5
2948.62 1710.17
57.06 32.64
N/A 1.13
84.482 92.887 28.776 55.641
84.716 93.085 29.136 56.556
0.240 0.328 0.114 0.273
0.241 0.329 0.116 0.278
5.232 7.875 2.287 6.072
5.247 7.892 2.315 6.172
0.0000 0.0000 0.0002 0.0002
0.00 0.00 1.85 1.93
N/A 0.1
Ovintiv USA Inc.
Ranch Compressor Station
Oil Breathing/Working Vapor Composition
Breathing/Working vapor for:Tank Oil
Maximum temperature of bulk liquid (°R):555.38 (from AP-42 Tanks calculations)
Compound Molecular Weight
(lb/lb-mol)mol% in liquid A B C Vp (mmHg) @ T mol % in vapor wt% in vapor
nitrogen 28.013 0.00%6.72531 285.5727 270.09 617,297.3 0.07%0.06%
CO2 44.010 0.01%9.81367 1340.9768 271.883 281,596.7 3.56%5.01%
H2S 34.082 0.00%7.11958 802.2266 249.61 20,174.6 0.00%0.00%
methane (C1)16.042 0.21%6.84377 435.4534 271.361 265,600.9 52.89%27.08%
ethane (C2)30.069 0.51%6.95185 698.9298 260.264 38,715.2 19.10%18.33%
propane (C3)44.096 1.03%7.02022 889.8642 257.084 9,500.3 9.36%13.17%
iso-butane (C4)58.122 0.43%6.93551 954.182 247.077 3,610.3 1.48%2.75%
nor-butane (C4)58.122 1.64%7.00908 1022.3862 248.145 2,531.0 3.99%7.40%
iso-pentane (C5)72.149 1.21%7.0303 1140.4542 247.012 981.7 1.14%2.62%
nor-pentane (C5)72.149 3.49%7.00892 1134.1488 238.678 742.7 2.48%5.71%
hexanes (C6)86.170 6.21%6.98978 1216.9154 227.451 229.1 1.36%3.75%
heptanes (C7)100.200 26.63%7.0467 1341.8887 223.733 73.8 1.88%6.03%
octanes (C8)114.230 23.56%7.14535 1498.9589 225.874 25.6 0.58%2.11%
nonanes (C9)128.260 10.59%7.18909 1607.7359 222.414 9.0 0.09%0.37%
decanes (C10+)142.290 10.84%7.22035 1694.6279 216.459 3.1 0.03%0.15%
n-hexanes 86.170 8.06%6.98978 1216.9154 227.451 229.1 1.77%4.87%
2,2,4-trimethylpentane 114.230 0.01%6.99021 1358.7529 231.405 79.0 0.00%0.00%
benzene 78.110 0.46%6.81432 1090.4312 197.146 133.4 0.06%0.15%
toluene 92.140 2.42%7.13657 1457.2871 231.827 48.2 0.11%0.33%
ethylbenzene 106.170 0.22%7.1561 1559.5452 228.582 17.7 0.00%0.01%
xylenes (M,P,O)106.170 2.47% 7.21217 1546.919 217.144 12.2 0.03% 0.10%
VOC (C3) wt% = 13.17%
VOC (C4+) wt% = 36.34%
VOC wt% = 49.51%
Benzene wt% = 0.15%
H2S wt% =0.00%
HAPs wt% = 5.46%
Vapor MW (lb/lb-mol) = 31.33
Notes:
Vapor pressure calculation methodology and factors from of "The Yaws
Handbook of Vapor Pressure - Antoine Coefficients", Carl L. Yaws, Gulf
Professional Publishing.
log10(Vp) = A - B/(T + C)
Vp = Vapor Pressure (mmHg)
A, B, C = regeression coefficients for chemical compounds
T = Maximum temperature of bulk liquid (°C, from AP-42 Tanks Calculations)
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX F
GRAPHICS: AREA MAP, PROCESS FLOW DIAGRAM

AREA MAP
Ranch Compressor Station
40.130557, -110.296621
Facility Location
Duchesne County, Utah
Process Flow Diagram
Ranch Compressor Station
Ovintiv USA Inc. – Duchesne County, UT
Revision date: 2024-01-16
Condensate
Field Gas
Sweet Gas
Produced Water
Vapors
PL Process Liquids
Condensate/PW

Sales
Pipeline
Process Flare
FLR-01
On and Off-
Site Fuel
System
JT Skid Compressor Engines
ENG-01 through ENG-06
Produced Water
Truck Loading
LOAD-1
Off-site
Production
Wells
Gas Sweetening
Unit
Combination Tanks
(Condensate &
Produced Water)
TANK-01,02,03,04
Dehydration Unit
HTR-01, DEHY-01
Inlet Separator
Condensate
Truck Loading
LOAD-1
PL
Utility Flare
FLR-02
NGL Storage Vessel
NGL Storage Vessel
Truck Loading
NGL-LOAD
PL
Particulate
Filter
Coalescing
Filter
Electric-Driven
Air Compressor
Emergency
Generator
GENENG-01
PL
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
APPENDIX G
SUPPORTING DOCUMENTS

Client Name:Ovintiv
Location:Ranch CS
Job:
ProMax Filename:O:\Denver\Sdrive\EHS-Regulatory\Air\Uinta\Permitting\ProMax\Compressor Station Ranch 2023.02.13.pmx
ProMax Version:6.0.22251.0
Simulation Initiated:2023-03-09 9:35:05 AM
A question mark (?) after a value, throughout the report, denotes an extrapolated or approximate value.
Office: [phone]
FAX: [phone]
mailto:[e-mail]
http://www.bre.com/
Report Navigator can be activated via the ProMax Navigator Toolbar.
An asterisk (*), throughout the report, denotes a user specified value.
P.O. Box 4747 Bryan, Texas 77805
Simulation Report
Project: Compressor Station Ranch 2023.02.13.pmx
Licensed to Ovintiv USA Inc. and Affiliates
Bryan Research & Engineering, LLC
Chemical Engineering Consultants
48 bbl/d
Std Liquid Volumetric Flow
Reid Vapor Pressure(RVP)
71
6.4015
bbl/d
psi
Temperature
Pressure
Std Liquid Volumetric Flow
Bubble Point Pressure
79
17.7
89.735
17.585
°F
psig
bbl/d
psig
85
15.5
6379.2
°F
psig
MSCFD
79
17.7
6401.3
°F
psig
MSCFD 80.817
840
5274.3
°F
psig
MSCFD
0
206.07
1975
°F
psig
MSCFD
50.364 bbl/d
78.14
12.3
0.6769
°F
psia
MSCFD
Process Streams Analysis-
Gas
Analysis-
Oil
CF-Liq Dry Gas HP Drain NGL-Gas NGL-Liq On/Off
Site Fuel
Pipeline-
Gas
Sep-Gas Sep-Oil Tank-
Flash
Tank-Inlet Tank-Oil
Composition Status: Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved
Phase: Total From Block: -- --Coalescing
Filter
From Dehy
Unit
MIX-102 NGL Vessel NGL Vessel JT Skid SPLT-100 VSSL-100 VSSL-100 Combination
Tanks
MIX-100 Combination
Tanks
To Block: MIX-104 MIX-104 MIX-102 SPLT-100 -- -- -- -- -- 1st Stg
Scrubber
MIX-100 --Combination
Tanks
--
%%%%%%%%%%%%%%
0.8932* 0.0224000* 0.60 0.92 0.26 1.26 0.27 0.94 0.92 0.89 0.03 1.13 0.03 0.01
0.3858*0*0.06 0.41 0.02 0.14 0.00 0.42 0.41 0.38 0.00 0.10 0.00 0.00
0.0001*0*0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
74.9054*0.709299*25.94 78.31 9.80 71.48 4.60 80.70 78.31 74.65 0.74 50.59 0.74 0.21
11.2942*0.728999*13.71 11.52 6.57 17.61 10.64 11.53 11.52 11.26 0.72 19.40 0.72 0.51
5.1716*1.22680*13.93 4.99 8.04 6.87 20.02 4.50 4.99 5.16 1.13 11.09 1.13 1.03
0.8074*0.501199*3.69 0.71 2.59 0.73 6.81 0.51 0.71 0.81 0.44 1.84 0.44 0.43
2.0934*1.99180*11.92 1.70 9.17 1.44 22.48 1.03 1.70 2.10 1.68 4.83 1.68 1.64
0.586*1.67950*4.61 0.37 4.59 0.17 7.90 0.13 0.37 0.59 1.21 1.39 1.21 1.21
1.1598*4.75819*9.80 0.64 10.89 0.23 15.14 0.18 0.64 1.19 3.26 2.77 3.26 3.26
0.0476*0.356299*0.43 0.02 0.57 0.01 0.52 0.00 0.02 0.05 0.22 0.12 0.22 0.22
0.7342*13.9142*6.13 0.17 12.84 0.01 4.93 0.01 0.17 0.84 8.00 1.95 8.00 8.06
0.1477*3.68109*1.09 0.02 2.83 0.00 0.73 0.00 0.02 0.17 2.34 0.40 2.34 2.36
0.4971*8.07988*4.59 0.16 7.80 0.02 4.54 0.02 0.16 0.57 3.83 1.32 3.83 3.85
0.5783*24.3460*2.13 0.03 12.62 0.00 0.85 0.00 0.03 0.70 20.85 1.61 20.85 21.05
0.1638*6.55949*0.62 0.01 3.57 0.00 0.23 0.00 0.01 0.20 5.52 0.46 5.52 5.58
0.0001*0.0280999*0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.01 0.00 0.01 0.01
0.0436*0.742699*0.35 0.01 0.74 0.00 0.24 0.00 0.01 0.05 0.46 0.11 0.46 0.46
0.0612*2.53119*0.21 0.00 1.29 0.00 0.06 0.00 0.00 0.07 2.40 0.16 2.40 2.42
0.0022*0.149500*0.00 0.00 0.04 0.00 0.00 0.00 0.00 0.00 0.22 0.00 0.22 0.22
0.0225*1.68650*0.01 0.00 0.39 0.00 0.00 0.00 0.00 0.02 2.45 0.05 2.45 2.47
0.2515*16.8362*0.18 0.00 4.59 0.00 0.03 0.00 0.00 0.24 23.31 0.56 23.31 23.56
0.0467*6.85569*0.00 0.00 0.64 0.00 0.00 0.00 0.00 0.03 10.48 0.08 10.48 10.59
0.0803*2.61509*0.00 0.00 0.16 0.00 0.00 0.00 0.00 0.01 10.72 0.02 10.72 10.84
0.0263*0*0.01 0.03 0.00 0.02 0.00 0.03 0.03 0.03 0.00 0.01 0.00 0.00
Process Streams Analysis-
Gas
Analysis-
Oil
CF-Liq Dry Gas HP Drain NGL-Gas NGL-Liq On/Off
Site Fuel
Pipeline-
Gas
Sep-Gas Sep-Oil Tank-
Flash
Tank-Inlet Tank-Oil
Properties Status: Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved Solved
Phase: Total From Block: -- --Coalescing
Filter
From Dehy
Unit
MIX-102 NGL Vessel NGL Vessel JT Skid SPLT-100 VSSL-100 VSSL-100 Combination
Tanks
MIX-100 Combination
Tanks
To Block: MIX-104 MIX-104 MIX-102 SPLT-100 -- -- -- -- -- 1st Stg
Scrubber
MIX-100 --Combination
Tanks
--
Property Units
Temperature °F 85* 79* 79.7272 80.8171 65.5382 -7.94489 -7.94489 0* 80.8171 79* 79 78.1414 79 78.1414
Pressure psig 15.5*17.7*895 840 90 100*100 206.068*840 17.7*17.7 0*17.7 0
Mole Fraction Vapor %99.8782 0 0 100 12.4639 100 0 100 100 100 0 100 0 0
Std Vapor Volumetric Flow MMSCFD 6.37915*0.0858200 0.07 30.00 0.34 0.01 0.06 1.98 5.27 6.40 0.06 0.00067690 0.06370946 0.063033
Std Liquid Volumetric Flow sgpm 88.6131 2.61728*1.42 399.73 8.37 0.07 1.40 25.76 70.28 89.15 2.08 0.01104809 2.08188180 2.070834
Propane
Isobutane
n-Butane
Isopentane
n-Pentane
Cyclopentane
Mole Fraction
Carbon Dioxide
Nitrogen
Hydrogen Sulfide
Methane
Ethane
Benzene
Toluene
Ethylbenzene
m-Xylene
Octane
Nonane
n-Hexane
Cyclohexane
2-Methylpentane
Heptane
Methylcyclohexane
2,2,4-Trimethylpentane
C10+
Argon
30017 MSCFD
Process Streams Condenser-
Vapor
Condenser-
Water
Glycol Regen-
Vapor
Glycol Sep-
Gas
Outlet Gas TEG Lean TEG Rich Wet Gas
Composition Status: Solved Solved Solved Solved Solved Solved Solved Solved
Phase: Total From Block: Condenser Condenser Glycol
Regenerator
Glycol Sep DVDR-1 TEG Makeup Glycol Sep Saturator
To Block: -- -- Condenser -- From Dehy Unit Glycol Pump Cross Exchanger Glycol Contactor
%%%%%%%%
7.58 0.00 1.25 5.05 0.92 0.00 0.10 0.92
0.00 0.00 0.00 0.06 0.41 0.00 0.00 0.40
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
5.42 0.00 0.89 48.58 78.31 0.00 0.07 78.23
9.77 0.01 1.61 20.33 11.52 0.00 0.13 11.51
13.26 0.03 2.20 12.86 4.99 0.00 0.18 4.99
2.78 0.01 0.47 1.88 0.71 0.00 0.04 0.71
13.22 0.09 2.25 5.82 1.70 0.00 0.18 1.70
4.51 0.08 0.81 1.23 0.37 0.00 0.06 0.37
10.73 0.25 1.97 2.41 0.64 0.00 0.16 0.64
2.40 0.10 0.48 0.13 0.02 0.00 0.04 0.02
4.06 0.28 0.91 0.57 0.17 0.00 0.07 0.17
2.61 0.28 0.66 0.12 0.02 0.00 0.05 0.02
3.17 0.16 0.66 0.55 0.16 0.00 0.05 0.16
0.90 0.21 0.32 0.09 0.03 0.00 0.03 0.03
0.60 0.14 0.22 0.03 0.01 0.00 0.02 0.01
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
9.27 1.03 2.38 0.06 0.01 0.01 0.20 0.01
1.95 0.69 0.90 0.01 0.00 0.01 0.08 0.00
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.02 0.02 0.02 0.00 0.00 0.00 0.00 0.00
0.03 0.02 0.02 0.00 0.00 0.00 0.00 0.00
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
7.70 96.60 81.97 0.17 0.00 9.97 15.71 0.07
0.00 0.00 0.00 0.00 0.00 90.01 82.83 0.00
0.01 0.00 0.00 0.03 0.03 0.00 0.00 0.03
Process Streams Condenser-
Vapor
Condenser-
Water
Glycol Regen-
Vapor
Glycol Sep-
Gas
Outlet Gas TEG Lean TEG Rich Wet Gas
Properties Status: Solved Solved Solved Solved Solved Solved Solved Solved
Phase: Total From Block: Condenser Condenser Glycol
Regenerator
Glycol Sep DVDR-1 TEG Makeup Glycol Sep Saturator
To Block: -- -- Condenser -- From Dehy Unit Glycol Pump Cross Exchanger Glycol Contactor
Property Units
Temperature °F 100* 100 196.292 90.1090 80.8171 128.720 90.1090 79.1550
Pressure psig 0*0 0.29 30 840 0.29 30 865
Mole Fraction Vapor %100 0 100 100 100 0 0 99.9341
Std Vapor Volumetric Flow MMSCFD 0.004 0.020 0.024 0.013 30.000 0.281 0.306 30.038
Std Liquid Volumetric Flow sgpm 0.078 0.094 0.172 0.207 399.729 7.500 7.672 400.113
Propane
Isobutane
n-Butane
Isopentane
n-Pentane
Cyclopentane
Mole Fraction
Carbon Dioxide
Nitrogen
Hydrogen Sulfide
Methane
Ethane
Benzene
Toluene
Ethylbenzene
m-Xylene
Octane
Nonane
n-Hexane
Cyclohexane
2-Methylpentane
Heptane
Methylcyclohexane
2,2,4-Trimethylpentane
C10+
Water
Triethylene Glycol
Argon
June 2018 Page 68 of 97
Table 21 - Revised SCR Cost Analyses

(All dollar values
in 2016 dollars)A
Vendor A
1,380 hp @
0.50 g/bhp-h
Vendor B
1,380 hp @
0.50 g/bhp-h
GCA
Vendor C1,2
1,380 hp @
0.50 g/bhp-h
Vendor C
1,380 hp @
0.50 g/bhp-h
Vendor A
1,380 hp @
0.35 g/bhp-h
Vendor B
1,380 hp @
0.35 g/bhp-h
Vendor C
1,380 hp @
0.35 g/bhp-h
Cardinal1,2,3
1,775 hp @
0.50 g/bhp-h
Cardinal
1,775 hp @
0.50 g/bhp-h
GCA1,2
1,775 hp @
0.50 g/bhp-h
GCA
1,775 hp @
0.50 g/bhp-h
Vendor A
4,735 hp @
0.50 g/bhp-h
Vendor B
4,735 hp @
0.50 g/bhp-h
GCA4
4,735 hp @
0.50 g/bhp-h
GCA
4,735 hp @
0.50 g/bhp-h
SCR System $107,000 $150,000 $146,000 $146,000 $107,000 $150,000 $146,000 $152,484 $152,484 $130,000 $130,000 $105,000 $225,000 $495,685 $495,685
Reductant Tank and
Other Auxiliary Equipment $11,000 $30,000 $0 $0 $11,000 $30,000 $0 $37,043 $37,043 $0 $0 $20,000 $50,000 $58,257 $58,257
Customer Supplied Equipment $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0
Instrumentation $0 $0 $14,600 $0 $0 $0 $0 $16,110 $0 $13,000 $0 $0 $0 $0 $0
Initial Fill of Reductant $711 $711 $2,500 $3,960 $498 $498 $3,960 $5,000 $5,000 $2,500 $3,600 $2,440 $2,440 $9,750 $3,024
Freight $5,936 $9,036 $7,300 $7,498 $5,925 $9,025 $7,498 $10,532 $9,726 $6,500 $6,680 $6,372 $13,872 $13,750 $27,848
Total Purchased Equipment Costs $124,647 $189,747 $170,400 $157,458 $124,423 $189,523 $157,458 $221,169 $204,253 $152,000 $140,280 $133,812 $291,312 $577,442 $584,814
Total Direct Installation Costs $162,041 $246,671 $131,400 $204,695 $161,750 $246,380 $204,695 $144,989 $265,529 $117,000 $182,364 $173,956 $378,706 $0 $760,259
Commissioning Costs $0 $0 $11,500 $11,500 $0 $0 $11,500 $100,000 $100,000 $11,500 $11,500 $0 $0 $0 $0
Total Indirect Installation Costs $38,640 $58,821 $58,878 $48,812 $38,571 $58,752 $48,812 $113,030 $63,319 $52,450 $43,487 $41,482 $90,307 $463,072 $181,292
Total Capital Investment $200,681 $305,492 $372,178 $265,007 $200,321 $305,132 $265,007 $548,284 $428,848 $332,950 $237,351 $215,437 $469,012 $1,040,514 $941,551
Operating and Supervisory
Labor Costs $5,009 $2,362 $65,000 $5,009 $5,009 $2,362 $5,009 $62,400 $5,009 $65,000 $5,009 $5,009 $4,723 $21,000 $5,009
Maintenance Cost $9,583 $3,347 $3,722 $9,583 $9,583 $3,347 $9,583 $8,224 $9,583 $3,330 $9,583 $9,583 $6,694 $37,500 $9,583
Reductant Consumption Cost $4,326 $18,540 $24,090 $24,090 $3,028 $18,540 $24,090 $8,760 $8,760 $24,090 $21,900 $14,843 $37,080 $18,396 $14,843
Annual Electricity Cost $3,524 $3,524 $5,000 $3,524 $3,524 $3,524 $3,524 $5,807 $3,993 $5,000 $3,993 $10,551 $10,551 $5,000 $10,551
Annual Catalyst Replacement Cost $14,248 $11,614 $22,500 $14,248 $14,023 $11,614 $14,023 $20,000 $8,078 $18,000 $14,827 $22,371 $23,227 $47,388 $22,371
Direct Annual Costs $36,690 $39,387 $120,312 $56,454 $35,167 $39,387 $56,229 $105,191 $35,423 $115,420 $55,312 $62,357 $82,275 $129,284 $62,357
Overhead $11,351 $14,549 $0 $23,209 $10,572 $14,549 $23,209 $0 $14,011 $0 $21,895 $17,661 $29,098 $0 $17,661
Administrative Charges $4,014 $6,110 $0 $5,300 $4,006 $6,103 $5,300 $0 $8,577 $0 $4,747 $4,309 $9,380 $0 $18,831
Property Tax $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0
Insurance $2,007 $3,055 $0 $2,650 $2,003 $3,051 $2,650 $0 $4,288 $0 $2,374 $2,154 $4,690 $0 $9,416
Capital Recovery $18,942 $28,835 $40,861 $25,014 $18,908 $28,801 $25,014 $89,233 $40,479 $36,555 $22,404 $20,335 $44,270 $98,214 $88,873
Indirect Annual Costs $36,314 $52,550 $40,861 $56,173 $35,490 $52,505 $56,173 $89,233 $67,356 $36,555 $51,419 $44,459 $87,439 $98,214 $134,781
Total Annual Costs $73,004 $91,937 $161,173 $112,627 $70,657 $91,892 $112,402 $194,424 $102,779 $151,975 $106,731 $106,816 $169,714 $227,498 $197,138
TPY of NOX
Emissions Reduced 5.99 5.99 5.99 5.99 4.19 4.19 4.19 7.71 7.71 7.71 7.71 20.56 20.56 20.56 20.56
Cost Per Ton $12,185 $15,345 $26,902 $18,799 $16,848 $21,911 $26,802 $25,230 $13,337 $19,722 $13,850 $5,196 $8,256 $11,067 $9,590
TPY of All Polutants
Emissions Reduced 55.63 55.63
Cost Per Ton $3,495 $1,848
1 Quote included instrumentation.
2 Company used interest rate and/or equipment life different than EPA directed 7.0% interest rate and 20 years equipment life.
3 Quote included oxidation catalyst.
4 Company made arithmetic error; listed PEC as $517,942 when $495,685 + $58,257 = $553,942.
A The Department orginially used the Capital Cost Factors from Table 2.5 in the October 2000 version of the Control Cost Manual. The updated chapter uses a base equation to calculate TCI. The Department uses the base OAQPS calculation method in the reanalysis, which may result in an overestimation of cost.
STANDARD
CONTINUOUS
GAV
WITH AIR FUEL RATIO CONTROL
Ovintiv-UT 3606
72.5-84.8
42.2
1168
5500
80
1900 bhp@1000rpm
RATING STRATEGY:
RATING LEVEL:
FUEL SYSTEM:
SITE CONDITIONS:
FUEL:
FUEL PRESSURE RANGE(psia): (See note 1)
FUEL METHANE NUMBER:
FUEL LHV (Btu/scf):
ALTITUDE(ft):
INLET AIR TEMPERATURE(°F):
STANDARD RATED POWER:
ENGINE SPEED (rpm):1000
COMPRESSION RATIO:7.6
AFTERCOOLER TYPE:SCAC
AFTERCOOLER - STAGE 2 INLET (°F):130
AFTERCOOLER - STAGE 1 INLET (°F):174
JACKET WATER OUTLET (°F):190
ASPIRATION:TA
COOLING SYSTEM:JW+1AC, OC+2AC
CONTROL SYSTEM:ADEM4
EXHAUST MANIFOLD:DRY
COMBUSTION:LOW EMISSION
NOx EMISSION LEVEL (g/bhp-hr NOx):0.5
SET POINT TIMING:16
RATING NOTES LOAD 100%100%75%50%
ENGINE POWER (WITHOUT FAN)(2)bhp 1900 1900 1425 950
INLET AIR TEMPERATURE °F 80 80 80 80
MAXIMUM
RATING
SITE RATING AT MAXIMUM
INLET AIR TEMPERATURE
ENGINE DATA
FUEL CONSUMPTION (LHV)(3)Btu/bhp-hr 6805 6805 7085 7661
FUEL CONSUMPTION (HHV)(3)Btu/bhp-hr 7495 7495 7803 8437
AIR FLOW (@inlet air temp, 14.7 psia)(WET)(4)(5)ft3/min 4976 4976 3769 2589
AIR FLOW (WET)(4)(5)lb/hr 21941 21941 16618 11417
FUEL FLOW (60°F, 14.7 psia)scfm 185 185 144 104
INLET MANIFOLD PRESSURE (6)in Hg(abs)107.7 107.7 82.2 58.2
EXHAUST TEMPERATURE - ENGINE OUTLET (7)°F 781 781 837 916
EXHAUST GAS FLOW (@engine outlet temp, 14.5 psia)(WET)(5)(8)ft3/min 12121 12121 9611 7020
EXHAUST GAS MASS FLOW (WET)(5)(8)lb/hr 22573 22573 17112 11773
EMISSIONS DATA - ENGINE OUT
NOx (as NO2)(9)(10)g/bhp-hr 0.50 0.50 0.50 0.50
CO (9)(10)g/bhp-hr 2.07 2.07 2.07 2.07
THC (mol. wt. of 15.84)(9)(10)g/bhp-hr 2.07 2.07 2.16 2.28
NMHC (mol. wt. of 15.84)(9)(10)g/bhp-hr 0.90 0.90 0.94 0.99
NMNEHC (VOCs) (mol. wt. of 15.84)(9)(10)(11)g/bhp-hr 0.55 0.55 0.57 0.60
HCHO (Formaldehyde)(9)(10)g/bhp-hr 0.15 0.15 0.16 0.19
CO2 (9)(10)g/bhp-hr 484 484 500 541
EXHAUST OXYGEN (9)(12)% DRY 11.4 11.4 11.2 10.8
HEAT REJECTION
HEAT REJ. TO JACKET WATER (JW)(13)Btu/min 23223 23223 20495 16663
HEAT REJ. TO ATMOSPHERE (13)Btu/min 5263 5263 5300 5454
HEAT REJ. TO LUBE OIL (OC)(13)Btu/min 11639 11639 10940 9463
HEAT REJ. TO A/C - STAGE 1 (1AC)(13)(14)Btu/min 19778 19778 10058 3342
HEAT REJ. TO A/C - STAGE 2 (2AC)(13)(14)Btu/min 9440 9440 5575 2628
COOLING SYSTEM SIZING CRITERIA
TOTAL JACKET WATER CIRCUIT (JW+1AC)(14)(15)Btu/min 46311
TOTAL STAGE 2 AFTERCOOLER CIRCUIT (OC+2AC)(14)(15)Btu/min 23878
A cooling system safety factor of 0% has been added to the cooling system sizing criteria.
CONDITIONS AND DEFINITIONS
Engine rating obtained and presented in accordance with ISO 3046/1, adjusted for fuel, site altitude and site inlet air temperature. 100% rating at maximum inlet air temperature
is the maximum engine capability for the specified fuel at site altitude and maximum site inlet air temperature. Maximum rating is the maximum capability at the specified
aftercooler inlet temperature for the specified fuel at site altitude and reduced inlet air temperature. Refer to product O&M manual for details on additional lower load capability.
No overload permitted at rating shown.
For notes information consult page three.
GAS COMPRESSION APPLICATION
Page 1 of 4Data generated by GERP Web Version 2.7.0.63
Ref. Dta Set EM6490-04-001, Printed 02Nov2023
GAS ENGINE SITE SPECIFIC TECHNICAL DATAG3606
ovintiv-UT

Confidential Communication
…………………………………………………………………………………………………………………………………………………………………

To Dalyce Watson Phone
J-W Energy Fax
Date January 3, 2024 Email [e-mail]

RE: EMISSIONS GUARANTEE – Unit 8047

Dalyce,

We hereby guarantee that our QUICK-LIDTM Model DC64L2-18/20 catalytic silencer described below:

Catalyst model DC64L2-18/20HGS
Catalyst coating Oxidation A Coat
Outside Diameter of catalyst substrate 24.23” x 3.7”
No. of catalyst 2 (room for 4)
Cell Density 300 cpsi

and sized for the following engine:

Engine model CAT G3606A4
Power 1900 HP @ 1000 rpm
Exhaust Flow 22573 lb/hr
Exhaust Temperature 781F
Fuel NG High BTU per supplied GERP

will perform as follows:

SILENCER SYSTEM DATA
Silencer Grade Hospital
Approx. Attenuation 35-40 dBA

Emissions Engine Output
(g/bhp-hr)

Converter Output
(g/bhp-hr)

Nitrogen Oxides (NOx) 0.50 0.50
Carbon Monoxide (CO) 2.07 0.25
Volatile Organic Compounds (VOC) 0.55 0.28
Formaldehyde (HCHO) 0.15 0.08

for a period of 1 year (after invoice date) or 8000 hours, whichever comes first, subject to all terms and conditions
contained in the attached warranty document being respected and met.

Best regards,
DCL America

Sam Kirk
Sales Manager – Gas Compression

STANDARD
CONTINUOUS
CAT WIDE RANGE
WITH AIR FUEL RATIO CONTROL
Ovintiv-UT
7.0-40.0
72.1
1007
5500
80
1380 bhp@1400rpm
RATING STRATEGY:
RATING LEVEL:
FUEL SYSTEM:
SITE CONDITIONS:
FUEL:
FUEL PRESSURE RANGE(psig): (See note 1)
FUEL METHANE NUMBER:
FUEL LHV (Btu/scf):
ALTITUDE(ft):
INLET AIR TEMPERATURE(°F):
STANDARD RATED POWER:
ENGINE SPEED (rpm):1400
COMPRESSION RATIO:8
AFTERCOOLER TYPE:SCAC
AFTERCOOLER - STAGE 2 INLET (°F):130
AFTERCOOLER - STAGE 1 INLET (°F):201
JACKET WATER OUTLET (°F):210
ASPIRATION:TA
COOLING SYSTEM:JW+OC+1AC, 2AC
CONTROL SYSTEM:ADEM3
EXHAUST MANIFOLD:DRY
COMBUSTION:LOW EMISSION
NOx EMISSION LEVEL (g/bhp-hr NOx):0.5
SET POINT TIMING:30
RATING NOTES LOAD 100%100%75%52%
ENGINE POWER (WITHOUT FAN)(2)bhp 1345 1330 997 690
INLET AIR TEMPERATURE °F 77 80 80 80
MAXIMUM
RATING
SITE RATING AT MAXIMUM
INLET AIR TEMPERATURE
ENGINE DATA
FUEL CONSUMPTION (LHV)(3)Btu/bhp-hr 7188 7204 7550 8065
FUEL CONSUMPTION (HHV)(3)Btu/bhp-hr 7950 7967 8350 8920
AIR FLOW (@inlet air temp, 14.7 psia)(WET)(4)(5)ft3/min 2973 2956 2250 1598
AIR FLOW (WET)(4)(5)lb/hr 13183 13035 9919 7047
FUEL FLOW (60°F, 14.7 psia)scfm 160 159 125 92
INLET MANIFOLD PRESSURE (6)in Hg(abs)86.9 86.1 69.0 49.9
EXHAUST TEMPERATURE - ENGINE OUTLET (7)°F 971 970 957 965
EXHAUST GAS FLOW (@engine outlet temp, 14.5 psia)(WET)(5)(8)ft3/min 8521 8422 6359 4554
EXHAUST GAS MASS FLOW (WET)(5)(8)lb/hr 13645 13492 10279 7313
EMISSIONS DATA - ENGINE OUT
NOx (as NO2)(9)(10)g/bhp-hr 0.50 0.50 0.50 0.50
CO (9)(10)g/bhp-hr 2.19 2.19 2.19 2.12
THC (mol. wt. of 15.84)(9)(10)g/bhp-hr 4.28 4.27 4.16 3.96
NMHC (mol. wt. of 15.84)(9)(10)g/bhp-hr 1.01 1.01 0.98 0.93
NMNEHC (VOCs) (mol. wt. of 15.84)(9)(10)(11)g/bhp-hr 0.43 0.43 0.42 0.40
HCHO (Formaldehyde)(9)(10)g/bhp-hr 0.42 0.42 0.40 0.39
CO2 (9)(10)g/bhp-hr 466 467 489 524
EXHAUST OXYGEN (9)(12)% DRY 9.1 9.0 8.6 8.0
HEAT REJECTION
HEAT REJ. TO JACKET WATER (JW)(13)Btu/min 22510 22554 21863 20598
HEAT REJ. TO ATMOSPHERE (13)Btu/min 6008 5962 4981 4074
HEAT REJ. TO LUBE OIL (OC)(13)Btu/min 4429 4407 3918 3363
HEAT REJ. TO A/C - STAGE 1 (1AC)(13)(14)Btu/min 10957 10957 6949 2393
HEAT REJ. TO A/C - STAGE 2 (2AC)(13)(14)Btu/min 5311 5311 4112 2641
COOLING SYSTEM SIZING CRITERIA
TOTAL JACKET WATER CIRCUIT (JW+OC+1AC)(14)(15)Btu/min 41603
TOTAL AFTERCOOLER CIRCUIT (2AC)(14)(15)Btu/min 5576
A cooling system safety factor of 0% has been added to the cooling system sizing criteria.
CONDITIONS AND DEFINITIONS
Engine rating obtained and presented in accordance with ISO 3046/1, adjusted for fuel, site altitude and site inlet air temperature. 100% rating at maximum inlet air temperature
is the maximum engine capability for the specified fuel at site altitude and maximum site inlet air temperature. Maximum rating is the maximum capability at the specified
aftercooler inlet temperature for the specified fuel at site altitude and reduced inlet air temperature. Refer to product O&M manual for details on additional lower load capability.
No overload permitted at rating shown.
For notes information consult page three.
GAS COMPRESSION APPLICATION
Page 1 of 4Data generated by GERP Web Version 2.7.0.63
Ref. Dta Set EM1748-03-001, Printed 06Dec2023
GAS ENGINE SITE SPECIFIC TECHNICAL DATAG3516B
ovintiv-UT

Confidential Communication
…………………………………………………………………………………………………………………………………………………………………

To Dalyce Watson Phone
J-W Energy Fax
Date January 3, 2024 Email [e-mail]

RE: EMISSIONS GUARANTEE – Unit 5813

Dalyce,

We hereby guarantee that our QUICK-LIDTM Model DC63L2-14HGS catalytic silencer described below:

Catalyst model DC63L2-14HGS
Catalyst coating Standard Oxidation Q Coat
Outside Diameter of catalyst substrate 20.41” x 3.7”
No. of catalyst 4
Cell Density 300 cpsi

and sized for the following engine:

Engine model CAT G3516B
Power 1330 HP @ 1000 rpm
Exhaust Flow 13492 lb/hr
Exhaust Temperature 971F
Fuel NG per supplied GERP

will perform as follows:

SILENCER SYSTEM DATA
Silencer Grade Hospital
Approx. Attenuation 35-40 dBA

Emissions Engine Output
(g/bhp-hr)

Converter Output
(g/bhp-hr)

Nitrogen Oxides (NOx) 0.50 0.50
Carbon Monoxide (CO) 2.19 0.25
Volatile Organic Compounds (VOC) 0.43 0.28
Formaldehyde (HCHO) 0.42 0.08

for a period of 1 year (after invoice date) or 8000 hours, whichever comes first, subject to all terms and conditions
contained in the attached warranty document being respected and met.

Best regards,
DCL America

Sam Kirk
Sales Manager – Gas Compression

3050 Highway 22 North | Dickinson, ND 58601 | 701-483-5400 | www.steffes.com
ECO # REV #
Document # 1203204
5
AIR ASSIST FLARE
MODELS: SAA-2 & FCSAA-210
206806
REV 5 Page | 2

The Steffes Model 2 Air Assist Flare is intended for burning low pressure waste gas on production oil
sites. It was designed to help operators meet the requirements set forth in EPA 40 CFR 60.18.
Establishing the proper assist-air fan speed for this product is the responsibility of the flare operator
after installation. It is recommended that one adjust the assist-air fan speed sufficiently to eliminate
visible emissions and smoke (evaluate using Method 22). However, one must not set the fan speed
so high that it reduces the overall combustion efficiency or eliminates the visible flame. Generally, a
visible flame is a strong indication that the flare is operating near its maximum efficiency. The assist -
air fan speed can be adjusted through the flare controller. Please see the manual below for details.
Standard equipment includes flare, flare base, pilot, flare fan controller, hardware, and sparker. The
controller operates a fan at the flare. A green indicator light, which signals a pilot flame is detected,
and a red indicator light, which signals no flame is detected, are located on the front of the controller
box along with a temperature display of the thermocouple temperature. These indicator lights acti-
vate when the temperature is above or below the preset factory set point.
Optional equipment includes datalogger and temp transmitter.
OVERVIEW
*Data is for reference only. Call factory for more specifics.
SPECIFICATIONS*
Pilot - Gas Flow Rate
Orifice #70 MTD
Propane @ 8 PSI 11 cu. ft. / hr.*
Propane @ 10 PSI 13 cu. ft. / hr.*
Natural Gas Multiply Flow by 1.6
Flare
Max Flow Rate 200,000 SCFD
at 2400 BTU/ft^3*
Min Flow Rate 1,000 SCFD
Weight 160 lbf
Controller
Certification ETL Listed to UL Standard 508A
Input Voltage 120 V AC
Outside Operating Temperature -40 to 150° F
Ignition Voltage 13,500 V
Maximum Acceptable Fault Current 5000 A
Thermocouple K-Type
Pilot Lit Indication
Green—Pilot Lit (Temp > 250°F)
Red—Pilot Not Lit (Temp < 250°F)
Communication
Temperature Display
Data Logger (optional)
Temperature Transmitter (optional)
Dry Contact N/O when OK
Fan Speed Control Potentiometer
Fan Output Diagnostic
Overcurrent
Rotor locked
Phase short circuit
Fan Power Cable (optional)
10’ 14-4 MCHL with 4 Pin Deutsch
50’ 14-4 MCHL with 4 Pin Deutsch
75’ 12-4 MCHL
120’ 10-4 MCHL
Page | 3 REV 5

DIMENSIONS
1.5ft 1.8ft
6.7 ft
6 ft
12.4 ft
See extension manual for guy wire configurations. with taller flares
NOTICE OF INTENT APPLICATION
RANCH COMPRESSOR STATION
OVINTIV USA INC.
END OF APPLICATION