DAQ-2025-002437

DAQE-GN143250014-25

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Jodee Sorensen
Red Leaf Resources, Inc.
32 West 200 South, Suite #552
Salt Lake City, UT 84101
[e-mail]

Dear Ms. Sorensen:

RE: Construction Schedule Update of Red Leaf Resources, Inc. Petroleum Processing Plant – CDS
SM; MACT (Part 63), Unclassified Area, NESHAP (Part 61), NSPS (Part 60),
Project Number: N143250014

The Utah Department of Environmental Quality, Division of Air Quality (DAQ), has reviewed your letter
dated February 12, 2024, with an update on the anticipated construction schedule and requesting an
extension to complete construction of the Red Leaf Resources, Inc. (Red Leaf) Petroleum Processing
Plant (DAQE-AN143250007-17, dated May 26, 2017).

Your letter indicated Red Leaf anticipates full construction to begin in Q3/Q4 2025, pending the
finalization of the project financing. Additionally, the BACT analysis is up to date with current emissions
control standards, and as a result, no changes have been requested by the DAQ.

DAQ will grant an extension to start full construction until December 31, 2025. DAQ considers full
construction as the construction of the approved emission units listed in AO DAQE-AN143250007-17.
DAQ requests an updated construction schedule be submitted at least three (3) months prior to December
31, 2025.

The charge for this project is billed based on the hours spent on it by DAQ staff. You will receive an
invoice for these charges shortly. If you have any questions, please contact John Persons, who can be
reached at [phone] or [e-mail].

Sincerely,

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Jon L. Black, Manager
New Source Review Section

JLB:JP:jg
{{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}} {{#s=Sig_es_:signer1:signature}}
195 North 1950 West • Salt Lake City, UT
Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820
Telephone [phone] • Fax [phone] • T.D.D. [phone]
www.deq.utah.gov
Printed on 100% recycled paper
State of Utah

SPENCER J. COX
Governor
DEIDRE HENDERSON
Lieutenant Governor

Department of
Environmental Quality

Tim Davis
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

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DAQE-AN143250007-17

May 26, 2017

Vincent Memmott
Uintah Partners, LLC
2105 West 1800 North
Farr West, UT 84404

Dear Mr. Memmott:

Re: Approval Order: Administrative Amendment as per R307-401-12 (Reduction in Air Pollutants)
to Approval Order DAQE-AN143250003-12 to Incorporate Changes in the Design of the
Petroleum Processing Plant
Project Number: N143250007

The attached document is the Approval Order for the above-referenced project. Future correspondence
on this Approval Order should include the engineer's name as well as the DAQE number as shown on the
upper right-hand corner of this letter. The project engineer for this action is Ms. Catherine Wyffels, who
may be reached at [phone].

Sincerely,

Bryce C. Bird
Director

BCB:CW:jf

cc: Patrick Wauters
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

GARY R. HERBERT
Governor

SPENCER J. COX
Lieutenant Governor

Department of
Environmental Quality

Alan Matheson
Executive Director

DIVISION OF AIR QUALITY
Bryce C. Bird
Director

STATE OF UTAH

Department of Environmental Quality

Division of Air Quality

APPROVAL ORDER: Administrative Amendment as per R307-
401-12 (Reduction in Air Pollutants) to Approval Order DAQE-
AN143250003-12 to Incorporate Changes in the Design of the
Petroleum Processing Plant

Prepared By: Ms. Catherine Wyffels, Engineer
Phone: [phone]
Email: [e-mail]

APPROVAL ORDER NUMBER

DAQE-AN143250007-17

Date: May 26, 2017

Uintah Partners, LLC
Source Contact:
Vincent Memmott
Phone: [phone]
Email: [e-mail]

Bryce C. Bird
Director

Abstract

Uintah Partners, LLC (Uintah) has requested an Administrative Amendment to AO DAQE-
AN143250003-12, dated August 2, 2012, to implement changes to its petroleum processing plant. Uintah
has proposed to remove the Catalytic Crude Upgrader (CCU) and associated units related to the
production of gasoline and diesel fuels. Uintah has requested to change their plant design to add
processes that produce heavier crude products, such as vacuum gas oil (VGO) distillate and waxy de-
asphalted oil (DAO). As part of this new plant design, Uintah has proposed to install a Vacuum
Distillation Unit (VDU), a Solvent De-Asphalting Unit (SDU), and a Base Oil Hydroprocessing Unit.
These proposed changes will result in a reduction of all criteria pollutants, HAPs, and greenhouse gases.
Based on this reduction in air pollutants, the AO will be updated in accordance with rule R307-401-12
(Reduction in Air Pollutants).

The new processing plant will consist of distillation towers, process heaters/boilers, a hydrotreating unit, a
SDU, a VDU, a Base Oil Hydroprocessing Unit, a sulfur recovery unit, storage tanks, a wastewater
treatment plant, a flare device, material unloading/loading racks, and various pollution control devices.
The plant will be capable of processing up to 45,000 barrels of crude oil per day, or 16,425,000 barrels
per year.

The plant is located approximately 10 miles south of Ft. Duchesne in Uintah County. Uintah County is
an unclassifiable area for ozone and is an attainment area of the NAAQS for all other criteria pollutants.
NSPS, NESHAP, and MACT regulations apply to this source. This source is subject to Title V for area
sources as specified in R307-415-5a, but is not required to obtain a Title V permit

The potential to emit, in tons per year, will be reduced as follows: PM10 -1.35, PM2.5 (Subset of PM10) -
0.34, NOx -2.37, SO2 -22.83, CO -50.37, VOC -10.16, HAPs -0.73, and CO2 Equivalent -176,592.

The potential to emit, in tons per year, will be as follows: PM10 = 20.17, PM2.5 (Subset of PM10) = 13.77,
NOx = 49.26, SO2 = 25.85, CO = 27.57, VOC = 23.42, HAPs = 2.61, and CO2 Equivalent = 303,379.

This air quality AO authorizes the project with the following conditions and failure to comply with any of
the conditions may constitute a violation of this order. This AO is issued to, and applies to the following:

Name of Permittee:

Uintah Partners, LLC
2105 West 1800 North
Farr West, UT 84404
Permitted Location:

Uintah Partners, LLC
Sec 14 T4S R1E
10 miles south of Fort Duchesne
Uintah County, UT

UTM coordinates: 597,552 m Easting, 4,444,131 m Northing, UTM Zone 12
UTM Datum: NAD83
SIC code: 2911 (Petroleum Refining)

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]

DAQE-AN143250007-17
Page 3
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: SPECIAL PROVISIONS

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

II.A.1 Petroleum Processing Plant
Uintah Partners, LLC

II.A.2 Crude Oil Distillation Unit
Fractionation tower
Crude Distillation Process Heater (Item II.A.11)
NSPS Applicability: 40 CFR 60 Subpart NNN

II.A.3 Vacuum Distillation Unit
Feed Tank
Vacuum Distillation Unit Process Heater (Item II.A.12)
NSPS Applicability: 40 CFR 60 Subpart NNN

II.A.4 Solvent De-Asphalting Unit
Absorption column
Stripping column
NSPS Applicability: 40 CFR 60 Subpart NNN

II.A.5 Base Oil Hydroprocessing Unit
Feed Tank
Feed Heater (II.A.13)
Isodewaxing Heater (Item II.A.14)
Hydrofinishing Heater (Item II.A.15)
NSPS Applicability: 40 CFR 60 Subpart NNN

DAQE-AN143250007-17
Page 4
II.A.6 Distillate Hydrotreating Unit
Feed Tank
Distillate Hydrotreating Heater (Item II.A.16)
Diesel Stabilizer Heater (Item II.A.17)
NSPS Applicability: 40 CFR 60 Subpart NNN

II.A.7 Hydrogen Plant
Reformer
Shift Converter
Gas Purifier
Menthanator
Heater (Item II.A.18)

II.A.8 Sulfur Recovery Unit and Amine Unit
Heat Exchanger
Reactor
NSPS Applicability: 40 CFR Subpart Ja

II.A.9 Wastewater Treatment
Oil/water separator with attached carbon adsorption bed
Flotation unit
Aerobic digestion unit
NSPS Applicability: 40 CFR 60 NSPS Subpart QQQ

II.A.10 Main Boiler
Rating: 315 MMBtu/hr
Fuel: Refinery off-gas or natural gas
Control: Tri-Mer SCR System or equivalent
NSPS Applicability: 40 CFR Subparts Db and Ja

II.A.11 Crude Distillation Heater
Rating: 90 MMBtu/hr
Fuel: Refinery off-gas or natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR 60 Subparts Dc and Ja

II.A.12 Vacuum Distillation Unit Process Heater
Rating: 45 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR 60 Subparts Dc and Ja

II.A.13 Base Oil Feed Heater
Rating: 30 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR 60 Subparts Dc and Ja

II.A.14 Base Oil Isodewaxing Heater
Rating: 25 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR Subparts Dc and Ja

DAQE-AN143250007-17
Page 5
II.A.15 Base Oil Hydrofinishing Heater
Rating: 20 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR Subparts Dc and Ja

II.A.16 Distillate Hydrotreating Heater
Rating: 17.6 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR 60 Subparts Dc and Ja

II.A.17 Diesel Stabilizer Heater
Rating: 10 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR 60 Subparts Dc and Ja

II.A.18 Hydrogen Plant Heater
Rating: 21.3 MMBtu/hr
Fuel: Refinery off-gas and natural gas
Burner: Ultra-low NOx burner
NSPS Applicability: 40 CFR 60 Subparts Dc and Ja

II.A.19 Flare System
One (1) industrial flare device for use only during breakdowns, startups, and shutdowns (1.4
MMBtu/hr pilot fueled by pipeline-quality natural gas or refinery off-gas)

II.A.20 Cooling Tower
Capacity: 5,010 gpm
Controls: Attached drift eliminators and heat exchanger leak detection system

II.A.21 Fire System Pump Engine
Rating: 200 hp
Fuel: Diesel
NSPS Applicability: 40 CFR 60 Subpart IIII
MACT Applicability: 40 CFR 63 Subpart ZZZZ

II.A.22 Material Transfer Equipment
Crude oil receiving and naphtha, ULSD, VGO, DAO, and pitch product transfer equipment.
This equipment includes vapor collection apparatus that discharges to a regenerative carbon
adsorption system

II.A.23 In-Plant Haul Roads
Paved haul roads

II.A.24 Storage Tanks TK101 and TK102
External floating roof tanks
Capacity: 250,000 barrels
Content: Heavy crude oil
NSPS Applicability: 40 CFR 60 Subpart Kb

DAQE-AN143250007-17
Page 6
II.A.25 Storage Tanks TK201 and TK202
Internal floating roof tanks
Capacity: 100,000 barrels
Content: Heavy Waxy VGO
NSPS Applicability: None

II.A.26 Storage Tanks TK203 and TK204
Internal floating roof tanks
Capacity: 100,000 barrels each
Content: Waxy De-Asphalted Oil
NSPS Applicability: None

II.A.27 Storage Tanks TK205 and TK206
Vertical fixed roof tanks
Capacity: 100,000 barrels each
Content: ULSD middle distillate (C8-C12 molecule)
NSPS Applicability: None

II.A.28 Storage Tanks TK207 and TK208
Vertical fixed roof tanks
Capacity: 55,900 barrels each
Content: Light Waxy VGO
NSPS Applicability: None

II.A.29 Storage Tanks TK209 and TK210
Vertical fixed roof tanks
Capacity: 55,900 barrels each
Content: Medium Waxy VGO
NSPS Applicability: None

II.A.30 Storage Tank TK301
Vertical fixed roof tank
Capacity: 25,000 barrels
Content: Vacuum residuum
NSPS Applicability: None

II.A.31 Storage Tank TK302
Vertical internal floating roof tank
Capacity: 25,000 barrels
Content: Naphtha (C5 - C8 molecules)
NSPS Applicability: 40 CFR 60 Subpart Kb

II.A.32 Storage Tank TK303
Vertical fixed roof tank
Capacity: 25,000 barrels
Content: Hydrotreater Feed
NSPS Applicability: None

II.A.33 Storage Tank TK304
Internal floating roof tank
Capacity: 25,000 barrels each
Content: Pitch (vacuum reduced crude oil)
NSPS Applicability: None

DAQE-AN143250007-17
Page 7
II.A.34 Storage Tank TK305
Vertical fixed roof tank,
Capacity: 25,000 barrels
Content: ULSD Marketing
NSPS Applicability: None

II.B Requirements and Limitations

II.B.1 The Uintah Partners Petroleum Processing Plant shall be subject to the following

II.B.1.a Unless otherwise specified in this AO, visible emissions from any stationary point or fugitive
emission source associated with the source or with the control equipment shall not exceed 10%
opacity. [R307-401-8]

II.B.1.a.1 Unless otherwise specified in this AO, 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 The owner/operator shall develop and implement a written leak-detection-and-repair (LDAR)
plan consistent with the requirements of 40 CFR 60 Subpart GGGa. [40 CFR 60.482]

II.B.1.c The owner/operator shall not process more than 16,425,000 barrels of crude oil per rolling 12-
month period. [R307-401-8]
.
II.B.1.c.1 The owner/operator shall calculate a new 12-month total using data from the previous 12
months. Monthly calculations shall be made no later than 20 days after the end of each
calendar month. Records of crude oil processed shall be kept for all periods when the plant is
in operation. Volume of crude oil processed shall be determined by examination of company
purchase records. The records of crude oil processed shall be kept on a daily basis. [R307-
401-8]

II.B.2 The In-Plant Haul Roads shall be subject to the following conditions

II.B.2.a The owner/operator shall comply with all applicable requirements of R307-205 for Fugitive
Emission and Fugitive Dust sources. [R307-205]

II.B.2.b Visible fugitive dust emissions from haul-road traffic and mobile equipment in operational
areas shall not exceed 20% opacity at any point. [R307-401-8]

II.B.2.b.1 Visible emission determinations shall use procedures similar to Method 9. The normal
requirement for observations to be made at 15-second intervals over a six-minute period,
however, shall not apply. Visible emissions shall be measured at the densest point of the
plume but at a point not less than 1/2 vehicle length behind the vehicle and not less than 1/2
the height of the vehicle. [R307-401-8]

II.B.2.c The in-plant haul roads shall be paved, and shall be periodically swept, or sprayed clean as dry
conditions warrant or as determined necessary by the Director. Records of cleaning paved
roads shall be kept for periods the plant is in operation. The records shall include the
following items:

1. Date of cleaning(s)

2. Time of day cleaning(s) were performed

[R307-401-8]

DAQE-AN143250007-17
Page 8
II.B.3 The Wastewater Treatment Plant shall be subject to the following

II.B.3.a A monitoring device capable of monitoring and recording the VOC concentrations or reading
of organics in the exhaust gases of the carbon adsorption system shall be installed in
accordance with 40 CFR 60.695 and 40 CFR 61.354. The activated carbon adsorption canister
shall be replaced immediately when carbon breakthrough is indicated. [40 CFR 60.695 (a)(3),
40 CFR 61.354 (d)]

II.B.3.a.1 The VOC concentrations or reading of organics in the exhaust gases of the carbon adsorption
system shall be monitored on a daily basis or at intervals no greater than 20% of the design
replacement interval of the carbon adsorption canister, whichever is greater. [40 CFR 60.695
(a)(3)(ii), 40 CFR 61.354 (d)]

II.B.4 The Boilers/Process Heaters shall be subject to the following

II.B.4.a The owner/operator shall only use refinery off-gas or natural gas as fuel in all boilers/process
heaters. [R307-401-8]

II.B.4.b The owner/operator shall install boilers/process heaters with ultra-low NOx burners with a NOx
rating of 15 ppm or less. The owner/operator shall maintain documentation showing that the
boilers/process heaters meet this emission standard. The documentation shall be made
available to the Director or Director's representative upon request. [R307-401-8]

II.B.4.c Emissions to the atmosphere from the boilers/process heaters listed below shall not exceed the
following emission limits:

Emission Point Pollutant lb/MMBtu ppmdv (3% O2 dry)

Crude Distillation Process Heater NOx* 0.030 15

Vacuum Distillation Heater NOx* 0.030 15

Main Boiler NOx** 0.011 9.5

*Determined on a 3-hour rolling average basis
**Determined on a 30-day rolling average basis

[40 CFR 60.102a (g)(2), R307-401-8]

II.B.4.c.1 Testing to show compliance with the emission limitations stated in the above condition shall
be performed as specified below:

A. Testing Test
Emission Point Pollutant Status Frequency

Crude Distillation Process Heater NOx * #

Vacuum Distillation Heater NOx * #

Main Boiler NOx ** ##

B. Testing Status

* Initial testing shall be performed within 180 days after startup.
** The initial compliance test shall be conducted within the first 30 operating days of
operation in which the affected source operates using a CEMS.
DAQE-AN143250007-17
Page 9
# The test shall be performed at least every 2 years based on the date of the last stack
test.
## Compliance shall be demonstrated through use of a continuous emissions
monitoring system (CEMS). Requirements for CEMS are described in II.B.4.c.2.

C. Notification

The Director shall be notified at least 30 days prior to conducting any required emission
testing. A source test protocol shall be submitted to DAQ when the testing notification is
submitted to the Director.

D. Sample Location

The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix
A, Method 1, or other EPA-approved testing method, as acceptable to the Director. An
Occupational Safety and Health Administration (OSHA) or Mine Safety and Health
Administration (MSHA) approved access shall be provided to the test location.

E. Volumetric Flow Rate

40 CFR 60, Appendix A, Method 2 or other EPA-approved testing method, as acceptable to
the Director.

F. Nitrogen Oxides (NOx)

Main Boiler: Continuous Emission Monitor (see Condition II.B.4.c.2).

Crude Distillation Process Heater and Vacuum Distillation Heater: 40 CFR 60, Appendix A,
Method 7, 7A, 7B, 7C, 7D, 7E, or other EPA-approved testing method, as acceptable to the
Director.

G. Calculations

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

H. Existing Source Operation

For an existing source/emission point, the production rate during all compliance testing shall
be no less than 90% of the average production achieved in the previous three years.

The source test protocol shall be approved by the Director prior to performing the test(s). The
source test protocol shall outline the proposed test methodologies, stack to be tested, and
procedures to be used. A pretest conference shall be held, if directed by the Director.

[40 CFR 60.107a(c) and (d), R307-401-8]

II.B.4.c.2 The owner/operator shall install, calibrate, maintain and continuously operate continuous
emissions monitoring system (CEMS) on the main boiler stack. The owner/operator shall
record the opacity of emissions and the quantity of NOx emissions at the main boiler stack.
The monitoring system shall comply with all applicable sections of R307-170, UAC; and 40
CFR 60, Appendix B.

DAQE-AN143250007-17
Page 10
For the NOx mass emission limits, during any time when the CEMS is inoperable and
otherwise not measuring emissions of NOx from the main boiler stack, the owner/operator
shall apply the missing data substitution procedures used by the Director or the missing data
substitution procedures in 40 CFR Part 75, Subpart D, whichever is deemed appropriate by the
Director. The 30-day rolling average emission rate of the total pounds of NOx emitted shall
include all main boiler stack emissions that occur during the specified period including during
each startup, shutdown, or malfunction.

In addition to the NOx CEMS the owner/operator shall install, certify, maintain, and operate a
diluent gas (oxygen [O2] or carbon dioxide [CO2]) monitor, to determine the hourly NOx
emission rate in parts per million (ppm) or pounds per million British thermal units
(lb/MMBtu).

Except for system breakdown, repairs, calibration checks, and zero and span adjustments
required under paragraph (d) of 40 CFR 60.13, the owner/operator of an affected source shall
continuously operate all required continuous monitoring devices and shall meet minimum
frequency of operation requirements as outlined in 40 CFR 60.13 and Section UAC R307-170.

[40 CFR 60.107a(c) and (d), R307-170]

II.B.4.d All boilers/process heaters shall comply with the following emission limits:

SO2 emissions to the atmosphere shall be less than or equal to 20 ppmvd, corrected to 0% O2,
3-hour rolling average, and
SO2 emissions to the atmosphere shall be less than or equal to 8 ppmvd, corrected to 0% O2,
365-day rolling average;

or

H2S concentration in refinery off-gas shall be less than or equal to 162 ppmv, 3-hour rolling
average, and
H2S concentration in refinery off-gas shall be less than or equal to 60 ppmv, 365-day rolling
average.

[40 CFR 60.102a (g)(1)(i), 40 CFR 60.102a (g)(1)(ii)]

II.B.4.d.1 The owner/operator shall install, calibrate, maintain, and operate a continuous monitoring
system to measure the effluent SO2 emissions from the crude distillation heater and the main
boiler; or install, calibrate, maintain, and operate a continuous monitoring system to measure
the H2S content in the refinery off-gas. The continuous monitoring system shall comply with
all applicable sections of R307-170 and 40 CFR 60, Appendix B. [40 CFR 60.102a (g)(1)(i),
40 CFR 60.102a (g)(1)(ii), 40 CFR 60.107a(a), R307-170]

II.B.4.e The owner/operator shall install, calibrate, maintain, and operate a flow indicator for the
measurement of the vent stream flow of refinery off-gas from the amine unit to the
boilers/process heaters. Flow measurement shall occur at least once every hour. The accuracy
of the monitoring devices must be certified by the manufacturer. The monitoring device shall
be accurate within plus or minus five percent of the design gas flow rate and must be
calibrated on an annual basis according to the manufacturer's instructions. [40 CFR 60.663
(c)(1)]

DAQE-AN143250007-17
Page 11
II.B.4.f The owner/operator shall install, calibrate, maintain, and operate a temperature monitoring
device for the measurement of the temperature in the firebox of the boilers/process heaters, as
required in 40 CFR 60.663(c)(2). The accuracy of the monitoring device must be certified by
the manufacturer. The monitoring device shall be accurate within plus or minus 0.5°C (1°F)
and must be calibrated on an annual basis according to the manufacturer's instructions. [40
CFR 60.663 (c)(2)]

II.B.4.g The owner/operator shall monitor and record the periods of operation of the main boiler. The
records must be readily available for inspection. [40 CFR 60.663 (d)]

II.B.5 The Flare System shall be subject to the following

II.B.5.a The owner/operator shall develop and implement a written flare management plan consistent
with 40 CFR 60.103a. [40 CFR 60.103a]

II.B.5.b The owner/operator shall not allow flow to the flare except in breakdown, startup, or shutdown
situations when the flare is used for safety purposes. [R307-401-8]

II.B.5.b.1 The flow to the flare device shall be determined by use of a flow meter. Flow measurement
shall occur at least once every hour. The accuracy of the monitoring device must be certified
by the manufacturer. The monitoring device shall be accurate within plus or minus five
percent of the design gas flow rate and must be calibrated on an annual basis according to the
manufacturer's instructions. [R307-401-8]

II.B.5.c The flare system shall comply with the following emission limits at all times except during
unavoidable process upsets or plant emergency:

H2S concentration in refinery off-gas in excess of 162 ppmv, 3-hour rolling average, and

H2S concentration in refinery off-gas in excess of 60 ppmv, 365-day rolling average.

[R307-401-8]

II.B.5.c.1 The owner/operator shall install, calibrate, maintain, and operate a continuous monitoring
system to measure the H2S content in the refinery off-gas. The continuous monitoring system
shall comply with all applicable sections of R307-170 and 40 CFR 60, Appendix B. [R307-
170, R307-401-8]

II.B.6 The Fire System Pump Engine shall be subject to the following

II.B.6.a The sulfur content of any diesel fuel used in the fire pump engine shall not exceed 15 ppm by
weight. [40 CFR 60.4207 (b)]

II.B.6.a.1 The sulfur content shall be determined by ASTM Method D-4294-89 or approved equivalent.
Certification of diesel fuels shall be either by Uintah Partners' own testing or test reports from
the fuel marketer. [40 CFR 60.4207(b), R307-203]

II.B.7 The Material Transfer Equipment shall be subject to the following

II.B.7.a The product loading rack shall be equipped with a vapor collection system. Collected gases
shall be routed to a regenerative carbon adsorption system. [R307-401-8]

II.B.7.b Gaseous emissions from the regeneration of carbon adsorption canisters shall be routed to the
production process. In the event of a breakdown, startup, or shutdown situation, emissions
from the carbon adsorption system shall be routed to the operating flare. [R307-401-8]

DAQE-AN143250007-17
Page 12
II.B.8 All Cooling Towers shall be subject to the following

II.B.8.a The total dissolved solids present in the water supplied to the cooling towers shall not exceed
2,600 ppmw. [R307-401-8]

II.B.8.a.1 The owner/operator shall test the water in the cooling tower sump at least once every seven
calendar days in accordance with Method 2450 C or approved equivalent. [R307-401-8]

II.B.9 Sulfur Recovery Unit (SRU) shall be subject to the following:

II.B.9.a The feed streams to the SRU shall include the offgas streams from the Crude Distillation Unit,
Distillate Hydrotreater Unit, Vacuum Distillation Unit, and Base Oil Hydroprocessing Unit;
and the sour gas from the Sour Water Stripper. [R307-401-8]

II.B.9.a.1 The SRU plant shall remove no less than 95% of the sulfur contained in the feed streams. [40
CFR 60 Subpart Ja, R307-401-8]

II.B.9.b The owner/operator shall monitor and operate the SRU in accordance with the requirements of
40 CFR 60.106a. Monitoring and operational records shall be made available to the Director
upon request. [R307-401]

Section III: APPLICABLE FEDERAL REQUIREMENTS

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

NSPS (Part 60), A: General Provisions
NSPS (Part 60), Db: Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units
NSPS (Part 60), Dc: Standards of Performance for Small Industrial-Commercial-Institutional Steam
Generating Units
NSPS (Part 60), Ja: Standards of Performance for Petroleum Refineries for Which Construction,
Reconstruction, or Modification Commenced After May 14, 2007
NSPS (Part 60), Kb: Standards of Performance for Volatile Organic Liquid Storage Vessels (Including
Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced
After July 23, 1984
NSPS (Part 60), GGGa: Standards of Performance for Equipment Leaks of VOC in Petroleum Refineries for
Which Construction, Reconstruction, or Modification Commenced After November 7, 2006
NSPS (Part 60), NNN: Standards of Performance for Volatile Organic Compound (VOC) Emissions From
Synthetic Organic Chemical Manufacturing Industry (SOCMI) Distillation Operations
NSPS (Part 60), QQQ: Standards of Performance for VOC Emissions From Petroleum Refinery Wastewater
Systems
NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion
Engines
NESHAP (Part 61), A: General Provisions
NESHAP (Part 61), FF: National Emission Standard for Benzene Waste Operations
MACT (Part 63), A: General Provisions
MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary
Reciprocating Internal Combustion Engines

DAQE-AN143250007-17
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PERMIT HISTORY

This AO is based on the following documents:

Incorporates Additional Information dated April 19, 2017
Incorporates Additional Information dated April 3, 2017
Incorporates Additional Information dated March 23, 2017
Incorporates Additional Information dated March 2, 2017
Is Derived From NOI dated January 31, 2017
Supersedes AO DAQE-AN143250003-12 dated August 2, 2012

ADMINISTRATIVE CODING

The following information is for UDAQ internal classification use only:

Uintah County
CDS SM
MACT (Part 63), Unclassified Area, NESHAP (Part 61), NSPS (Part 60)

DAQE-AN143250007-17
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 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
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

February 12, 2024 
Jon Black 
Department of Environmental Quality 
Division of Air Quality 
New Source Review 
Re: Construction schedule update and extension to commence construction of the Uintah Partners, LLC 
Petroleum/Wax Processing Plant 
Project Number: N143250011 
Approval Order: DAQE‐AN143250007‐17 
Extension: DAQE‐GN143250013‐22 

Mr. Black, 
Please find attached the construction schedule update and request to extend the current Approval Order 
DAQE‐GN143250013‐22. 
As discussed  during the meeting held in your office on August 31, 2023, Red Leaf Resources and Uintah 
Partners have been working hard to find investors to support the construction of the above‐mentioned 
Wax Processing Plant. While good progress has been made with several investors and on the Engineering 
design (Pre‐FEED completed in June 2023), the current financial environment, characterized by high 
interest rates, constitutes, temporarily, a high hurdle that may become surmountable once  interest rates 
are lowered.  Red Leaf Resources Inc. and Uintah Partners, LLC, work hard and are committed towards 
the realization and the success of the Project.  
As such, we are requesting an extension of the current Approval Order expiry date to commence 
construction of the Uintah Partners Petroleum/Wax Processing Plant.  
We anticipate  that the full  construction effort will begin in Q3/Q4 2025, pending finalization of Project
financing. 
Please contact me if you have any questions or need additional information. 
Regards, 
Filippo Segatori