DAQ-2025-001925

Kaiser, Chris B.
NSPS Ja Flare Management Plan Submittal - Marathon Salt Lake City Refinery Update
To whom it may concern,
Attached please find the updated flare management plan for the Marathon Salt Lake City refinery. This plan replaces
the plan submitted October 27,2022.
From:
Sent:
To:
Cc:
Subject:
Attachments:
Best regards,
Chris Kaiser
Environmental Supervisor
Salt Lake City Refinery
C BKaiser@marathon petroleum.com
Marathon Petroleum
474 West 900 North
Salt Lake City, UT 84103
O:801 521 4959
M: 801 520 1860
c<'. brlt- 6''"J
Kaiser, Chris B.
Tuesday, November 5,2024 5:15 AM
[e-mail]
Kaiser, Chris B.
NSPS Ja Flare Management Plan Submittal - Marathon Salt Lake City Refinery Update
20241001S1C NSPS Ja FMP Rev 6 DRAFT FlNAL.pdf
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DIVISION OF AIR OUAL]TY
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marathonoetroleum. com
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Tesoro Refining & Mqrketing Compqny LtC
Soll Loke City Refinery
Flqre Monogemenl Plon (FMP)
NSPS Subport Jo
October 1,2024
Revision 6
DIVISION OF AIR QUALITY
NSPS Jo Flore Monogement Plon
October 1,2024
Contents
.............................. 5
Flare Minimization Results ..............1 1
2.2 Summary of Key Minimization Assessment Results at the North and South F|ares..........................13
2.3 Flare Minimization lmplementation at North and South F1ares.............. ..........................14
2.3.1.4 Refinery-Wide Startup and Shutdown...................... ..........................14
2.3.3 lmplementation of PSV Prevention Measures..... .............16
2.3.4 lnstallation of Flare Gas Recovery and Cogeneration Units... ..............17
Flare Flow Diagram
Flare Gas Line Flow Diagram........
3.1
3.2 .20
SLC Refinery FMP rev. 6 - 10/1/2024
3.3.2.1 North Flare HzS Measurement.............. ........................23
3.3.2.2 South Flare HzS Measurement.............. ........................23
3.3.2.3 Fuel Gas HzS Measurement (For Refinery Fuel Gas Sweeps) ..............................23
3.3.3.2 Additional calibration, maintenance and quality assurance procedures are specified
within the Flare CEMS QA/QC plan. South F1are............... .............25
4.0 Baseline Flow and Alternative Operating Scenarios [560.103a(aX4)].................... ...............27
4.1 Primary Baseline Flow Rate [560.103a(aX4xi)]...... . ... ........27
4.2 Alternative Operating Scenarios [560.103a(a)(4xii)].............. .......................27
4.2.1 Alternative Operating Scenario #1 - Fuel Gas Long/Low NHV while Maximizing Gasoline
4.2.1.1 Alternative Operating Scenario #1 Rationale ..........28
4.2.1.2 Alternative Operating Scenario #1 Daily Flow and Expected Duration ..........29
4.2.1.3 Alternative Operating Scenario #1 Baseline. ...........29
4.2.1.4 Alternative Operating Scenario #1 Procedures for Flare Discharge Minimization ..............29
4.2.2 Alternative Operating Scenario #2 - DDU Maintenance or Catalyst Chan9e......... ........................29
4.2.2.1 Alternative Operating Scenario #2 Rationale ..........29
4.2.2.2 Alternative Operating Scenario #2Daily Flow and Expected Duration ..........30
4.2.2.3 Alternative Operating Scenario #2 Baseline. ...........30
4.2.2.4 Alternative Operating Scenario #2 Procedures for Flare Discharge Minimization..............30
4.2.3 Alternative Operating Scenario #3 - Diesel #1 Production....................... ....................30
4.2.3.1 Alternative Operating Scenario #3 Rationale ..........30
4.2.3.2 Alternative Operating Scenario #3 Daily Flow and Expected Duration ..........31
4.2.3.3 Alternative Operating Scenario #3 Baseline. ...........31
4.2.3.4 Alternative Operating Scenario #3 Procedures for Flare Discharge Minimization..............31
4.2.4 Alternative Operating Scenario #4 - Plant Turnaround. ........................31
4.2.4.1 Alternative Operating Scenario #4 Rationale ..........32
4.2.4.2 Alternative Operating Scenario #4 Daily Flow and Expected Duration ..........32
4.2.4.3 Alternative Operating Scenario #4 Baseline. ...........32
4.2.4.4 Alternative Operating Scenario #4 Procedures for Flare Discharge Minimization..............32
SLC Refinery FMP rev. 6 - 10/1/2024
4.2.5 Alternative Operating Scenario #5 - North flare hydrogen venting to stabilize vent gas flow
4.2.5.1 Alternative Operating Scenario #5 Rationale ..........33
4.2.5.2 Alternative Operating Scenario #5 Daily Flow and Expected Duration ..........33
4.2.5.3 Alternative Operating Scenario #5 Baseline. ...........33
4.2.5.4 Alternative Operating Scenario #5 Procedures for Flare Discharge Mlnimization..............33
4.3 Primary and Alternative Baselines Summary..... .....................34
5.0 Startup and Shutdown Flare Minimization Procedures [560.103a(aX5)]................... .........35
5.1 lmplemented Startup and Shutdown Flare Flow Minimization Procedures..........................................35
5.1.2 Procedures to Minimize Staftup F1arin9............ ..................36
5.1.4 Procedures to Minimize Shutdown F1arin9........... .............36
5.2 Planned Startup and Shutdown Flare Flow Minimization Procedures................ ...........37
6.0 Fuel Gas lmbalance Flare Minimization Procedures [560.103a(aX6)]........... ........................38
6.1 lmplemented Fuel Gas lmbalance Flare Flow Minimization Procedures.. .....................38
6.1.1 Minimize NaturalGas Supplementation........ .....................38
6.2 Planned Fuel Gas lmbalance Flare Flow Minimization Procedures.. ................................39
7.0 Flare Gas Recovery Outage Reduction Procedures [560.103a(a)(7)] .. . ........ . . .................40
7.1 lmplemented Flare Gas Recovery Outage Reduction Procedures ..........40
7.2 Planned Flare Gas Recovery Outage Reduction Procedures.. ...................41
SLC Refinery FMP rev. 6 - 1A/1/2024
Appendix A
Appendix B
Appendix C
Appendix D
List of Appendices
Reserved
Flare Connection List
Flare and Flare Network Drawings
NSPS Ja Cross Reference Table
SLC Refinery FMP rev.6-10/1/2024
Lisl of Acronyms
ACFM
AMP
BSU
CEMS
CGA
CT
DDU
EPA
FCCU
FGR
FMP
GC
LPG
MOC
NSPS
P&ID
PPH
PSV
QA/QC
RCA
RMP
SCFD
SCFH
sor
Actual Cubic Feet per Minute
Alternative Monitoring Plan
Benzene Saturation Unit
Continuous Emission Monitoring System
Cylinder Gas Audit
Current Transformer
Diesel Desulfurization Unit
United States Environmental Protection Agency
Fluidized Catalytic Cracking Unit
Flare Gas Recovery
Flare Management Plan
Gas Chromatograph
Liquefied Petroleum Gas
Management of Change
New Source Performance Standard
Process and lnstrumentation Diagram
Pounds Per Hour
Process Safety Valve
Quality Assurance and Quality Control
Root Cause Analysis
Rocky Mountain Power
Standard Cubic Feet per Day
Standard Cubic Feet per Hour
Standard Operating lnstruction
SLC Refinery FMP rev. 6 - 10/1/2024
SRU
TGTU
TRS
TS
UFU
VRU
Sulfur Recovery Unit
Tail Gas Treating Unit
Total Reduced Sulfur
Total Sulfur
Ultraformer Unit
Vapor Recovery Unit
SLC Refinery FMP rev. 6 - 10/1/2024
Definitions
Terms used in this Flare Management Plan and 40 CFR Part 60 Subpart Ja are defined as follows by a0 CFR
560.101a:
Ancillary equipment means equipment used in conjunction with or that serve a refinery process unit.
Ancillary equipment includes, but is not limited to, storage tanks, product loading operations, wastewater
treatment systems, steam- or electricity-producing units (including coke gasification units), pressure relief
valves, pumps, sampling vents and continuous analyzer vents.
Cascaded flare system means a series of flares connected to one flare gas header system arranged with
increasing pressure set points so that discharges will be initially directed to the first flare in the series (i.e.,
the primary flare). lf the discharge pressure exceeds a set point at which the flow to the primary flare
would exceed the primary flare's capacity, flow will be diverted to the second flare in the series. Similarly,
flow would be diverted to a third (or fourth) flare if the pressure in the flare gas header system exceeds a
threshold where the flow to the first two (or three) flares would exceed their capacities.
Corrective action means the design, operation and maintenance changes that one takes consistent with
good engineering practice to reduce or eliminate the likelihood of the recurrence of the primary cause
and any other contributing cause(s) of an event identified by a root cause analysis as having resulted in a
discharge of gases to an affected flare in excess of specified thresholds.
Corrective action analysis means a description of all reasonable interim and long-term measures, if any,
that are available, and an explanation of why the selected corrective action(s) islare the best alternative(s),
including, but not limited to, considerations of cost effectiveness, technical feasibility, safety and
secondary impacts.
Emergency flare means a flare that combusts gas exclusively released as a result of malfunctions (and not
startup, shutdown, routine operations or any other cause) on four or fewer occasions in a rolling 365-day
period. For purposes of this rule, a flare cannot be categorized as an emergency flare unless it maintains a
water seal.
Flare means a combustion device that uses an uncontrolled volume of air to burn gases. The flare
includes the foundation, flare tip, structural support, burner, igniter, flare controls, including air injection
or steam injection systems, flame arrestors and the flare gas header system. ln the case of an
interconnected flare gas header system, the flare includes each individual flare serviced by the
interconnected flare gas header system and the interconnected flare gas header system. As noted in the
clarification and correction memo issued by the EPA dated Augusl27, 2013, "flare" does not include
thermal oxidizers, process heaters, or other truly enclosed combustion devices.
Flare gas header system means all piping and knockout pots, including those in a subheader system,
used to collect and transport gas to a flare either from a process unit or a pressure relief valve from the
fuel gas system, regardless of whether or not a flare gas recovery system draws gas from the flare gas
SLC Refinery FMP rev. 6 - 10/1/2024
header system. The flare gas header system includes piping inside the battery limit of a process unit if the
purpose of the piping is to transport gas to a flare or knockout pot that is paft of the flare.
Flare gas recovery system means a system of one or more compressors, piping and the associated water
seal, rupture disk or similar device used to divert gas from the flare and direct the gas to the fuel gas
system or to a fuel gas combustion device.
Fuel gas means any gas which is generated at a petroleum refinery and which is combusted. Fuel gas
includes natural gas when the natural gas is combined and combusted in any proportion with a gas
generated at a refinery. Fuel gas does not include gases generated by catalytic cracking unit catalyst
regenerators, coke calciners (used to make premium grade coke) and fluid coking burners but does
include gases from flexicoking unit gasifiers and other gasifiers. Fuel gas does not include vapors that are
collected and combusted in a thermal oxidizer or flare installed to control emissions from wastewater
treatment units other than those processing sour water, marine tank vessel loading operations or asphalt
processing units (i.e., asphalt blowing stills).
Fuel gas combustion device means any equipment, such as process heaters and boilers, used to
combust fuel gas. For the purposes of this subpart, fuel gas combustion device does not include flares or
facilities in which gases are combusted to produce sulfur or sulfuric acid.
Fuel gas rystem means a system of compressors, piping, knock-out pots, mix drums, and units used to
remove sulfur contaminants from the fuel gas (e.9., amine scrubbers) that collects refinery fuel gas from
one or more sources for treatment as necessary prior to combusting in process heaters or boilers. A fuel
gas system may have an overpressure vent to a flare but the primary purpose for a fuel gas system is to
provide fuel to the refinery.
Non-emergency flare means any flare that is not an emergency flare as defined in this subpart.
Petroleum means the crude oil removed from the earth and the oils derived from tar sands, shale, and
coal.
Petroleum refinery means any facility engaged in producing gasoline, kerosene, distillate fuel oils,
residual fuel oils, lubricants, asphalt (bitumen) or other products through distillation of petroleum or
through redistillation, cracking or reforming of unfinished petroleum derivatives. A facility that produces
only oil shale or tar sands-derived crude oil for further processing at a petroleum refinery using only
solvent extraction and/or distillation to recover diluent is not a petroleum refinery.
Primary flare means the first flare in a cascaded flare system.
Process upset gas means any gas generated by a petroleum refinery process unit or by ancillary
equipment as a result of startup, shutdown, upset or malfunction.
Purge gas means gas introduced between a flare's water seal and a flare's tip to prevent oxygen
infiltration (backflow) into the flare tip. For flares with no water seals, the function of purge gas is
performed by sweep gas (i.e., flares without water seals do not use purge gas).
SLC Refinery FMP rev. 6 - 10/1/2024
Reduced sulfur compounds means hydrogen sulfide (HzS), carbonyl sulfide, and carbon disulfide.
Refinery process unit means any segment of the petroleum refinery in which a specific processing
operation is conducted.
Root cause analysis means an assessment conducted through a process of investigation to determine
the primary cause, and any other contributing cause(s), of a discharge of gases in excess of specified
thresholds.
Secondary flare means a flare in a cascaded flare system that provides additional flare capacity and
pressure relief to a flare gas system when the flare gas flow exceeds the capacity of the primary flare. For
purposes of this subpart, a secondary flare is characterized by infrequent use and must maintain a water
seal.
Sweep gas means the gas introduced in a flare gas header system to maintain a constant flow of gas to
prevent oxygen buildup in the flare header. For flares with no water seals, sweep gas also performs the
function of preventing oxygen infiltration (backflow) into the flare tip.
SLC Refinery FMP rev. 6 - 10/1/2024
lntroduction
Summory
Tesoro Refining & Marketing Company LLC, doing business as Marathon, (Tesoro) owns and operates the
Salt Lake City Refinery located in Salt Lake County, Utahl. This Flare Management Plan (FMP) documents
actions to minimize waste gas flow to the flares and meet the equipment work practice and operational
standards set forth in 40 CFR Part 60.100a through 60.109a, also known as New Source Performance
Standard (NSPS) Subpart Ja.
The Salt Lake City Refinery operates three flares. The North and South flares are connected to the flare gas
recovery system (FGR) and all operating units except the Sulfur Recovery Unit (SRU) and Tail Gas Treating
Unit (TGTU). The FGR system was installed in 2015. The SRU Flare operates independently, services the
SRU and TGTU exclusively, and is not connected to the FGR system.
NSPS Ja was originally proposed in 2008 and was updated and revised for several years thereafter. The
Environmental Protection Agency (EPA) published final rule amendments in the Federal Register on
September 12,2012. A flare, as defined in NSPS Ja, is an affected facility and can trigger the rule
requirements via construction, modification or reconstruction. The modification provisions are specified in
560.100a(cX1)-(2). Tesoro has determined that the Nor1h, South, and SRU flares have triggered
modification via $60.100a(c)(1) and are therefore subject to NSPS Subpart Ja including the flare equipment
work practice and operational standards.
One of the work practice standards under NSPS Ja requires that a Flare Management Plan be developed
and submitted to the EPA. This document fulfills the 560.103a(aX1)-(7) requirements. For each of the three
affected flares at Tesoro Salt Lake City this FMP:
Lists the process units connected to the flare (560.103a(a)(1))
Documents Tesoro's flare minimization efforts (560.103a(a)(2))
Describes the flare (560.1 03a(a)(3))
Evaluates baseline flow to the flare and establishes alternative baselines for alternative operating
scenarios (560.1 03a(aX ))
Presents procedures to minimize flaring during startup and shutdown (560.103a(aX5))
Summarizes procedures to reduce flaring due to fuel gas imbalances (560.103a(aX6))
1 Tesoro Refining & Marketing Company LLC's parent company Andeavor merged with Marathon
Petroleum Corporation in 2018. By operation of this merger, Tesoro became an indirect and wholly
owned subsidiary of Marathon. Tesoro Refining & Marketing Company LLC remains the owner of the Salt
Lake City Refinery.
SLC Refinery FMP rev. 6 - 10/1/2024
o Describes procedures to minimize flare gas recovery system outages (560.103a(aX7))
The history of and revisions to this FMP are described in Appendix A.
Focility Descriplion
The Tesoro Salt Lake City Refinery processes approximately 66,000 barrels per day of crude oil, producing
primarilygasoline and dieselfuel. Otherproducts include liquid propane, refineryfuelgas, jetfuel, and
heavy fuel oil. Process units include Crude Distillation, Ultraformer, Fluid Catalytic Cracking with Vapor
Recovery, Alkylation, Polymerization, Cogeneration, Benzene Saturation, Gasoline Hydrotreating, Diesel
Desulfurization, Sulfur Recovery and Tail Gas Treating, Rail and Truck Loading Racks, Tank Farm, and
Wastewater Treatment.
Affected Flores
The refinery has three flares. All North and South flare networks are connected to the flare gas recovery
system (FGR) and provide relief for the operating units. The Sulfur Recovery Unit (SRU) Flare operates
independently and services the SRU and Tail Gas Treating Unit (IGTU) and is not connected to the FGR
system. Tesoro rents a thermal oxidizer to degas Group 1 tanks when they are taken out of service. The
thermal oxidizer does not meet the definition of a flare as defined by 40 CFR 60.101a.
The detailed specifications of the flares are included in Section 3.0 of this plan.
The flares are subject to NSPS Ja based on the addition of new piping connecting refinery process units
and ancillary equipment to the flare after June 24,2008. [40 CFR 560.100a(c)(1)]
Flore Minimizotion Resulis
The Salt Lake City Refinery has installed Flare Gas Recovery (FGR) which has reduced the baseline flaring
to zero, aside from purges and sweeps, during normal operation. Since installation in 2015, the FGR
system, along with emphasis on flare minimization, has significantly reduced the frequency and duration
of flare events.
SLC Refinery FMP rev. 6 - 10/1/2024 11
1.0 Flqre Conneclions [560.1O3o(oxl)l
A list of all flare connections including refinery process units, ancillary equipment, and fuel gas systems
connected to the affected flare(s) required by 560.103a(aX1) is included in Appendix B. Ancillary
equipment, as defined by 560.101a, includes, but is not limited to, storage tanks, product loading
operations, wastewater treatment systems, steam or electricity producing units, pressure relief valves,
pumps, sampling vents and continuous analyzer vents.
To complete this effort, Tesoro field-verified all flare connections after initially assembling the connection
list from piping and instrumentation diagrams (P&lDs). The initial flare connection verification was
conducted in 201 3 and 2014, and then updated in 201 5 after installation of the FGR system. Since 20'17,
connections to the North and South flares have been reviewed periodically, including a detailed review in
2019. The flare connection list and maps are kept up to date through the refinery's management of
change (MOC) process.
The extent of the flare connections required to be included in the FMP is broad based on the 560.101a
definition of ancillary equipment as follows:
Ancillary equipment meons equipment used in conjunction with or thot serve a refinery process unit.
Ancillory equipment includes, but is not limited to, storage tonks, product loading operotions,
wostewoter treotment systems, steom- or electricity-producing units (including coke gasification
units), pressure relief volves, pumps, sompling vents ond continuous onolyzer vents.
Per 560.103a(bX2), this FMP will be updated periodically to account for flare connection changes but does
not need to be resubmitted unless a primary or alternative baseline is changed, flare gas recovery is
installed, or a flare monitoring election is changed.
l.t North ond South Flores
The North and South flares are interconnected and service all units with the exception of the SRU and
TGTU. Though interconnected by FGR and cross-over connections, the North and South flares have
individual water seals and can be isolated from each other when necessary. These flares share common
primary and alternative baselines, as described in Section 4.0 below, and their combined flows are used to
determine Root Cause Analysis (RCA) triggers. The south flare tip and pilot systems were replaced during
the 2024 turnaround to ensure current best practice reliability.
1.2 SRU Flore
The SRU flare is entirely separate from the North and South flares. lt services only the SRU and TGTU.
Though flaring events are infrequent, the SRU flare is not considered an emergency flare for the purposes
of NSPS Ja monitoring requirements.
The SRU flare tip and pilot systems were replaced during the 2020 turnaround, including improved
metallurgy, to improve flare and pilot reliability.
SLC Refinery FMP rev. 6 - 10/1/2024
2.0 Flqre Minimizolion [S60.103o(ox2)l
560.103a(aX2) requires an assessment of whether discharges to affected flares from these process units,
ancillary equipment, and fuel gas systems can be minimized. The flare minimization assessment must (at a
minimum) consider the following:
o Elimination of process gas discharge to the flare through process operating changes or gas
recovery at the source.
o Reduction of the volume of process gas to the flare through process operating changes.
o lnstallation of a flare gas recovery system or, for facilities that are fuel gas rich, a flare gas
recovery system and a co-generation unit or combined heat and power unit.
o Minimization of sweep gas flow rates and, for flares with water seals, purge gas flow rates.
Descriptions of the minimization assessment and its results are included below.
2.1 Flore Minimizotion Assessmenl
The Salt Lake City Refinery conducted the minimization assessment that involved mapping and evaluating
all flare connections and reviewing historical flaring events to identify potential reduction projects beyond
the installation of FGR. This assessment considered the capital and annual operating costs, technical
feasibility, secondary environmental impacts, and safety aspects of each potential change. See Section 2.3
for the outcomes of specific projects that have been implemented driving further flare minimization and
reduction at the North and South Flares. Flare minimization measures presented here are consistent with
those in the site's Consent Decree Flare Management Plan and MACT CC Flare Management Plan.
As part of the current flare minimization effort at the SRU flare, each SRU flare connection was reviewed
by experienced operators, operation supervisors, process engineers, project engineers, and environmental
staff. During this detailed review, flare connections were discussed individually with the exception of
process safety valves (PSVs), which were evaluated as a group. PSVs are, by definition, safety devices
whose release is minimized via standard operating procedures. While PSV releases are minimized as part
of normal operations, they can sometimes leak and contribute to vent gas volumes. Though initially
addressed as a group, PSVs were discussed individually when historical flare contribution has occurred
due to relief or leaks. See the SRU Flare header connection list in Appendix B for the outcomes of this
individual connection minimization review.
2.2 Summory of Key Minimizotion Assessment Resulls of the North
ond South Flores
During planned startup and shutdown, for release events where significant flaring could occur, the
existing operating procedures are reviewed to ensure that Operations personnel are familiar with the
procedures and know their role. This review includes consideration of flare minimization for each planned
startup and shutdown with significant flaring risk.
SLC Refinery FMP rev. 6 - 10/1/2024 13
Emergency releases can be necessary to protect the equipment from damage and the community from
danger. Flares are an essential safety device for refineries and must be used as such in the case of
emergencies. However, steps have been taken to ensure good work practice standards in such events
where emergency releases are necessary.
Furthermore, the Salt Lake City Refinery utilizes FGR at the North and South Flares which increases the
flare waste gas capacity of the flare system prior to flaring. Additionally, the Salt Lake City Refinery utilizes
cogeneration units to consume excess fuel gas to produce power, consequently reducing the quantity of
flare waste gas sent to the flares. FGR and cogeneration both decrease the amount of flare waste gas
flared at the Salt Lake City Refinery by reducing fuel gas imbalance.
2.3 FIore Minimizolion lmplemenlotion ol North ond Soulh Flores
2.3.1 Procedurol Review
2.3.1.1 Updotes lo Procedures
Startup and shutdown procedures are updated as opportunities for reduce flaring are identified. Any
startup or shutdown event in which excessive flaring occurs are evaluated to determine if changes in
procedures, plans, or equipment configurations can be effectively used to prevent or minimize flaring in
the future. Variables to be manipulated will be evaluated in order to make the appropriate procedural
changes.
2.3.1.2 Flore Procedurot Troining
The Salt Lake City Refinery has focused on operator training and awareness of specific prevention
measures and general approaches to minimizing flaring. All operators are trained on the procedures that
were altered to prevent or mitigate flaring during startup, shutdown, maintenance and normal operations
situations. Similarly, all affected FGR operators are trained on unit training manuals with a focus on
maintaining a reliable, operational FGR as well as troubleshooting and responding to changes in flaring
process conditions.
2.3.1.3 Flore Coordinolor
To ensure procedures for startup and shutdown are implemented properly when flaring is anticipated, the
Salt Lake City Refinery has established the Flare Coordinator role. The role of Flare Coordinator is filled by
individuals as documented by the Salt Lake City Environmental Department based on the current
operating conditions. The Flare Coordinator is responsible for coordinating flaring and managing all flare
plans and contingencies. lt is the responsibility of the Flare Coordinator to coordinate and implement
startup and shutdown sequences that balance the fuel gas system to the degree possible based on
storage capacity, gas routing limitations, and operational stability. The capacity of the FGR will be
monitored by the Flare Coordinator throughout the startup or shutdown process.
2.3.1.4 Refinery-Wide Stortup ond Shutdown
Startup and shutdown flaring events fall into two categories: those that can be conducted without flaring
and those for which flaring may be (or is likely) unavoidable.
SLC Refinery FMP rev. 6 - 10/1/2024 14
Starlup and shutdown activities for which flaring can be eliminated range from small-scale maintenance
activities on single pieces of equipment up to full process unit shutdowns. The key factors in determining
whether flaring can be eliminated is whether there are processes capable of consuming the material
vented from the equipment or units being shut down. Factors leading to flaring thus include gas routing
and fuel gas demand limitations. Routing limitations may include pressure differentials, pipe
configurations, operability, and other factors. Fuel gas demand limitations may be localized to the
processes accepting vented material or refinery wide.
The overall "robustness" of a refinery's fuel gas system (i.e., the scale of its fuel gas producers and
consumers) relative to the scope of a startup or shutdown is a critical factor for the plant's ability to
accommodate this activity without flaring. ln addition to the refinery-wide methods of minimizing flaring
through specified startup and shutdown procedures, the methods for startup and shutdown of individual
process flare units or flare networks to prevent or minimize flaring have been identified.
2.3.1.5 Fuel Gos Consumplion
The key strategy used to prevent and minimize flaring during startup and shutdown is maximizing the
amount of material vented from equipment which can be consumed by refinery processes rather than
flared. lt is thus desirable to keep fuel gas consumers operating as long as possible while the processes
that produce fuel gas are shutdown. Similarly, upon startup, fuel gas consumers are brought online first as
possible to prevent or minimize flaring.
Though the refinery will schedule startup and shutdown sequences with material and fuel gas balances as
significant factors, there are challenges which can preclude complete implementation of this strategy.
These challenges include storage capacity for both feedstocks to and products from fuel gas consuming
units, gas routing limitations, and operational stability.
2.3.1.6 Venling Rote
ln addition to the startup and shutdown sequences, the rate at which these activities are conducted can
affect the volume of material flared. Plans for full process unit startup and shutdown events where flaring
is anticipated will include an evaluation of the rate at which venting should occur to prevent or minimize
flaring to the extent required by regulatory limits. At times it may be advantageous to conduct a certain
aspect of the event slowly, such as when a decreased vent rate allows excess material to be consumed by
another refinery process instead of exceeding the consumer's capacity. Alternatively, there are conditions
when a faster rate of venting may be required. An example of this condition would be venting of inert
constituents that cannot safely be routed to the FGR and must be flared.
lnerting and deinventorying will be conducted by maximizing consumption of vented material and by
reducing the quantity of gas required to render equipment inert in order to minimize flaring. When the
overall refinery fuel gas consumption volume is high, the nitrogen can be vented to the fuel gas system or
FGR without adversely affecting the combustion characteristics of fuel gas consumers. When the refinery
fuel gas consumption volume is low, such as during shutdown, or when there is not sufficient fuel gas
demand, the nitrogen must be vented to the flare system. Alternative means of inerting, including
chemical cleaning, steam-out rates and durations, and reducing the volume of inerting gases, have been
15SLC Refinery FMP rev. 6 - 10/1/2024
evaluated for the South Area and are scheduled to be completed for the North Area prior to the next
scheduled refinery tu rnaround.
2.3.2 Emergency Releose
The Salt Lake City Refinery has an extensive library of robust emergency procedures. The emergency
procedures outline the necessary steps to operate safely and without damage to the equipment, people
and the enviornment. Each emergency procedure outlines the purpose, responsibilities of the affected
employees, relevant supporting documents, materials and equipment necessary, and the procedure itself.
All emergency procedures must be read and understood prior to its performance. Any deviation from the
documented procedures must be documented in writing, reviewed, approved, and have proper
authorization.
ln the past few years, electric power outages were a significant cause of process upset flaring. The Salt
Lake City Refinery has completed the following electrical power infrastructure projects to improve power
reliability and minimize flaring due to local or refinery-wide power outages:
Converted a single bus system at the Rocky Mountain Power (RMP) substation to a ring bus
system
lnstalled two functionally independent Cogen systems
. Added redundant circuits to all major power distribution systems
lmproved Cogen reliability by debugging protection and control settings
Built a new main substation
o lmproved preventative maintenance procedures
. lmproved current transformer (CT) testing
. lmproved ground fault detection
. Reduced single points of failure
o Refined load shedding operations to minimize impacts of external power interruptions
The Salt Lake City Refinery has historically been served from a single overhead 46 kilovolt distribution line
with single taps branching off to the various substations throughout the plant. The four new medium
voltage substations installed at the refinery include redundant feeders, high speed protective relays and
automatic transfer schemes. The substations are also supplied by armored tray cables that reduce
exposure to lightning, faulting, and other hazards that often lead to power upsets and to flaring.
2.3.3 lmplementotion of PSV Prevention Meqsures
All Process Safety Valves (PSVs) connected to the flare have three primary prevention measures as listed
below.
SLC Refinery FMP rev. 6 - 10/1/2024 16
1. Documented routine inspections,
2. Designing equipment to codes and standards, and
3. Alarms, including monitoring at PSV, flare flow, or seal monitoring, coupled with operator action.
All three of these prevention measures reduce the flare waste gas sent to the flare header, therefore
reducing the frequency and volume of flare waste gas flared.
2.3.4 lnslollotion of Flore Gqs Recovery ond Cogenerotion Unils
The Salt Lake City Refinery installed a FGR in 2015. The Salt Lake City Refinery's FGR consists of three
compressors, each with 1.35 MMSCFD of recovery capacity, for the North and South Flares. All three
compressors are online during planned startup and shutdowns.
The FGR system operated without shutdown from 20'l 5 until 2020. The FGR was taken offline for
maintenance during the 2020 and 2024 turnarounds. Additional work scope during the 2020 turnaround
included SRU flare tip replacement and modernization, installation of a reengineered north flare flow
monitor and maintenance of the north flare and SRU flare.
The recovered flare gas is routed to an amine contactor column where hydrogen sulfide (HzS) is removed
from the gas. The treated recovered flare gas is sent to the fuel gas mix drum for use in the refinery fuel
gas system. 2024 turnaround scope included replacement of the south flare tip, new upgraded south flare
steam control valves, south flare header replacement (including port forfuture instruments), and new
upgraded south flare flow meters.
The Salt Lake City Refinery installed a cogeneration unit in 2003 The Salt Lake City Refinery's cogeneration
system consists of two units, each with 11.8 MW capacity. Excess fuel gas is combusted in the
cogeneration system to reduce the need for flaring due to fuel gas imbalance and for electricity
production.
SLC Refinery FMP rev. 6 - 10/1/2024 17
3.0 Description of Atfecled Flore(s) [560.103o(ox3)l
Toble 3-l Flore inlormotion requiremenls
Elevated or
ground Elevated Elevated Elevated 550.1 03a(a)(3XiXA)
Flare height 53.3m 53.3m 160ft $60.103a(aX3XiXA)
Type of assist
system Steam Steam Non-assisted 560.1 03a(aX3XiXB)
Simple or complex
flare tip Simple Simple Simple 960.103a(aX3XiXC)
Cascaded flare?
(Primary or
secondary)
Not Cascaded Not Cascaded Not Cascaded 560.1 03a(aX3XiXD)
Backup flare?No No No 560.103a(aX3XiXE)
Emergency flare?No No Nor 560.103a(aX3XiXF)
Flare gas recovery
system?Yes Yes No 560.103a(aX3XiXG)
Flare tip date
installed Circa 2013 March 2024 February 2020 560.103a(aX3Xii)
Flare tip
manufacturer John Zink John Zink Hamworthy John Zink Hamworthy 560.103a(aX3Xii)
Flare tip nominal
diameter 24 inches 24 inches 6 inches 550.103a(aX3Xii)
Flare tip effective
diameter 21.1 inches 20 inches 6 inches 560.103a(aX3Xii)
Maximum vent
gas flow rate2 209,000 pph 468,931 pph 9,400scFM 560.103a(aX3Xiii)
Minimum sweep
gas flow rate
15 SCFM
(for six sweeps)
16.7 SCFM
(for four sweeps)
20 scFM3
(for two sweeps)560.103a(aX3Xiii)
Minimum purge
gas flow rate 12 ACFM 16.7 ACFM Not Applicable3
(No water seal)950.103a(aX3Xiii)
Maximum pilot
gas flow ratea 50-75 SCFH 50 SCFH/Pilot for each
of Three pilots 21 pph $50.103a(aX3Xiii)
SLC Refinery FMP rev
Minimum total
steam flow rate (if
steam-assisted)
540 ppha 500 ppha Not Applicable
(Not assisted)560.103a(a)(3Xiii)
Purge gas type Natural Gas Natural Gas Not Applicable 550.103a(aX3Xiv)
Sweep gas type
Natural Gas,
Nitrogen,
Refinery Fuel Gas
Natural Gas, Nitrogen,
Refinery Fuel Gas Natural Gas, Nitrogen 560.1 03a(aX3Xiv)
Supplemental gas
type Refinery Fuel Gas Refinery Fuel Gas Not Applicable
(No supplemental gas)560.103a(aX3Xiv)
Pilot gas type Natural Gas Natural Gas Natural Gas 560.1 03a(aX3Xiv)
Water seal
description
including the
operating range
for the liquid level
26.1 to 78.0 inches
of water
26.'l to 78.0 inches of
water
Not Applicable
(no water seal)560.103a(aX3XviXA)
Monitorlng option
elected
Flare Flow, HzS
and
Total Sulfur
Monitors
Flare Flow, HzS and
Total Sulfur
Monitors
Flare Flow,
Total Sulfur
Monitor
550.103a(aX3XviXB)
Number of
compressors
3
(combined with
South Flare)
3
(combined with
North Flare)
NA (no FGR)560.1 03a(a)(3Xvii)(A)
Capacity of each
compressor 60,000 scFH 60,000 scFH NA (no FGR)550.103a(aX3XviiXA)
Recovered Gas
Monitoring
Flow Meter
Fr280160
Flow Meter
Fr280160 NA (no FGR)560.103a(aX3XviiXB)
Compressor
Staging
25 Seconds Based
on Pressure and
Recycle Valve
Output
25 Seconds Based on
Pressure and Recycle
Valve Output
NA (no FGR)560.103a(aX3XviiXC)
1. The SRU flare only receives process upset gas and sweeps but is not an emergenry flare because it does not have a
water seal.2. Maximum vent gas rates are based on refinery relief studies.
3. Because the SRU flare does not have a water seal, the function of purge gas is performed by sweep gas.
4. Based on flare manufacturer's recommendation.
3.1 Flore Flow Diogrom
The diagrams required by 560.103a(aX3Xii) are included in Appendix C including the flare headers and
subheaders. The information required by 560.103a(aX3Xiv) is included in Table 3-1 above. The flare tip
drawing is confidential; a description is included in Appendix C and the flare tip drawing is on file at the
refinery.
SLC Refinery FMP rev. 6 - 10/1/2024 19
3.2 FIore Gos line Flow Diogrom
The diagram required by 560.103a(aX3Xiv) is included in Appendix C including all gas lines associated with
the flare. The information required by 560.1O3a(aX3Xiv) is included in Table 3-1 above.
3.3 lnstrumenlolion Specificolions
3.3.1 Flore Flow Meqsuremenl
3.3.1.1 Norlh Flore
Norfh Flore Flow I nslr u menlofion Specificofions
The Tesoro Salt Lake City Refinery has installed an ultrasonic GE Panametrics GF868 flare gas flow meter
system that uses dual path T17 transducers to measure the flow rate to the North refinery flare. The flow
meter has been installed in a representative measurement location downstream of the water seal. lt
utilizes live pressure and temperature correction. The instrumentation is used to report the flare flow rate
at standard conditions (68'F and 'l atmosphere).
Make: General Electric (GE)
Model: Panametrics Dual-Path GF868; four transducers model number T17
. TYPe: Ultrasonic
o Range: 0.1 fps to 394 fps
r Accuracy'. +/- 2o/o lo 5o/o of flare flow between 1 fps to 394 fps
. Precision: +/- 1o/o at 0.5 fps to 394 fps
o Flow meter instrument tags: FE-050225A, FE-0502258, FE-050225C, FE-050225D
o Pressure instrument tag: PT-050461
o Temperature instrument tag: TIT-050462
Additional calibration, maintenance and quality assurance procedures are specified within the Salt Lake
City Refinery Flare Continuous Emission Monitoring System (CEMS) Quality Assurance/Quality Control
(QA/QC) plan.
Since installation in 2015, the north flare flow meter has consistently recorded flows that do not exist
resulting in over reporting of flare volume. At the time of original installation, it was acknowledged the
pipe run in which the flow meter was installed was less than ideal, but Tesoro secured a manufacturer's
guaranteeof accuracyof themonitorasinstalled.2020 turnaroundscopeincludesinstallationof are-
engineered flow meter installation to more accurately measure low or zero flow scenarios. The north flare
flow meter continues to report positive flow that does not exist, particularly during afternoon sun. The
flow meter manufacturer believes these false positive flow readings are attributable to convection flows in
the flare header in a direction tangential to the header axis due to a phenomenon title diurnal effect.
SLC Refinery FMP rev. 6 - 10/1/2024 20
3.3.1.2 South Flore
Soufh Flore Flow lnslru menlofion Specificofions
The Tesoro Salt Lake City Refinery operates two co-located flow meters on the south flare. The primary
flow meter is an ultrasonic GE Panametrics GF868 flare gas flow meter system that uses dual path T17
transducers. While this flow meter is well suited for most operating scenarios, it is not designed to
accurately quantify low density gas streams such as occur during ultraformer hydrogen venting scenarios.
During these scenarios the refinery utilizes a FCI model ST100A thermal dispersion flow meter that
maintains required accuracy while measuring low density gas streams without requiring temperature or
pressure compensation. The thermal mass flow meter was replaced and upgraded during the 2024
turnaround. These flow meters are installed in a representative measurement location downstream of the
water seal. The ultrasonic flow meter utilizes live pressure and temperature correction. These instruments
are used to report the flare flow rate at standard conditions (68"F and 1 atmosphere).
A description of the ultrasonic flow meter is contained below:
Make: General Electric (GE)
Model: Panametrics Dual-Path GF868-2-1 1-20024-FM; four transducers model number T1 7-18-
10-36-NT-Tt
. TYPe: Ultrasonic
o Range: 0.1 fps to 394 fps
. Accuracy'. +/- 2o/olo 5o/o of flare flow between 1 fps to 394 fps
. Precision: +/- 1o/o at 0.5 fps to 394 fps
. Flow meter instrument tag: FE-040460A, FE-040460B, FE-040460C, FE-040460D
o Pressure instrument tag: PT-040461
. Temperature instrument tag: Tll-040462
A description of the thermal dispersion flow meter is contained below:
. Make: Fluid Components lnternational LLC (FCl)
. Model:ST100A
Type: Thermal dispersion
Range: Calibrated range is 0.833 to 1,538 Mscf/hr
Accuracy: +/- 1o/o of reading
Flow meter instrument tag: fi040364
SLC Refinery FMP rev. 6 - 10/1/2024 21
. Pressure instrument tag: None required
o Temperature instrument tag: None required
The refinery utilizes conditional logic to determine which of these monitors is best suited for flow
measurement at a particular point in time. This is done by evaluating flow in the ultraformer hydrogen
vent line as a surrogate for hydrogen content in the south flare header. lf the ultraformer hydrogen flow
rate, as measured by f032346, exceeds 240,000 SCFD, the south flare vent gas stream is considered to
have high hydrogen content and the thermal mass flow meter may be selected as the most accurate flow
measurement. lt should be noted this flow is generally zero except during episodic venting or ultraformer
hydrogen. ln all other cases the primary flow monitor, the ultrasonic instrument, is selected. Additionally,
during period of maintenance or instrument malfunction, data from either instrument may be substituted
to ensure redundancy and high instrument availability.
Additional calibration, maintenance and quality assurance procedures are specified within the Flare CEMS
QA/QC plan.
3.3.1.3 SRU Flore
SRU Flore F I ow I n str u me nloli o n Specificolions
The Tesoro Salt Lake City Refinery has installed an ultrasonic GE Panametrics GF868 flare gas flow meter
system that uses dual path T17 transducers to measure the flow rate to the SRU flare. The flow meter has
been installed in a representative measurement location downstream of the F-271 knockout drum on the
SRU flare header. lt utilizes live pressure and temperature correction. The instrumentation is used to
report the flare flow rate at standard conditions (68'F and 1 atmosphere).
Make: General Electric (GE)
Model: Panametrics Dual-Path GF868-2-11-21874-FM; four transducers model number T5-18-10-
33-NT-Tt
. TYPe: Ultrasonic
o Range: 0.'l fps to 394 fps
. Accuracy: +/- 2o/o to 5% of flare flow between 1 fps to 394 fps
o Precision: +/- 1o/o at 0.5 fps to 394 fps
. Flow meter instrument tag: FE-234494, FE-234498, FE-23449C, FE-23449D
o Pressure instrument tag: PT-23451
. Temperature instrument tag: TIT-23450
Additional calibration, maintenance and quality assurance procedures are specified within the Flare CEMS
QA/QC plan.
SLC Refinery FM P rev. 6 - 10/1/2024 22
3.3.2 Flore HzS Meosuremenl
3.3.2.1 North Flore HzS Meosurement
For North Flare HzS measurement, the Salt Lake City Refinery has installed a Siemens Maxum ll gas
chromatograph (GC). The detailed GC specifications are as follows:
o Make: Siemens
o Model:MAXUM ll
Type: Gas Chromatograph
Range:0-300 ppm
Accuracy.2.Oo/o
Precision:2.0%
. HzS meter instrument tag: AT-050830
Additional calibration, maintenance and quality assurance procedures are specified within the Flare CEMS
QA/QC plan.
3.3.2.2 South Flore HzS Meosurement
For South Flare HzS measurement, the Salt Lake City Refinery has installed a Siemens Maxum ll GC. The
detailed GC specifications are as follows:
Make:Siemens
Model:MAXUM ll
Type: Gas Chromatog raph
Range: 0-300 ppm
Accuracy:2.0o/o
Precision:2.07o
r HzS meter instrument tag: 4T-040830
Additional calibration, maintenance and quality assurance procedures are specified within the Flare CEMS
QA/QC plan.
3.3.2.3 Fuel Gos HzS Meosurement (For Refinery Fuel Gos Sweeps)
For Refinery Fuel Gas H2S measurement, the Salt Lake City Refinery has installed a Siemens Maxum ll GC.
The detailed GC specifications are as follows:
SLC Refinery FMP rev. 6 - 10/1/2024 23
Make: Siemens
Model:MAXUM ll
Type: Gas Chromatograph
Range: 0-300 ppm
Accuracy 2.0o/o
Precision:2.0%
. HzS meter instrument tag: Al-20711A
Additional calibration, maintenance and quality assurance procedures are specified within the CEMS
QA/QC plan.
3.3.3 Flore Totol Sulfur Meqsurement
3.3.3.1 North Flore
Norlh F I or e T o| ol S ulf ur I n slr u m e nlofion Specif c orions
The Tesoro Salt Lake City Refinery has installed a Siemens Maxum flare compliance analyzer for total
sulfur (TS) measurement to comply with the total reduced sulfur [IRS) monitoring requirements as
allowed by the regulation. The Siemens Maxum flare compliance analyzer uses three methods to monitor
for the full TS range anticipated at the Salt Lake City Refinery. The detailed design information for the TS
analyzer follows:
Make: Siemens
Model:MAXUM ll
Type: Gas Chromatograph
Method 1: 10-600 ppm as SO2
Method 2:450-20,000 ppm as SOz
Method 3: 15,000-100,000 ppm as SOz
Accuracy:2.0o/o
Precision: 2.0o/o for 1 0-600 ppm and 0.5o/o lor 450- 1 00,000 ppm
TRS meter instrument tag: 4T-050834
SLC Refinery FMP rev. 6 - 10/1/2024
3.3.3.2 Additionolcolibrolion, mointenonce ond quolity ossuronce procedures ore
specified wilhin the Flore CEMS OA/OC plon. South Flore
Soufh Flore Tolol Sulfur lnstrumenlofion Speclficofions
The Tesoro Salt Lake City Refinery has installed a Siemens Maxum flare compliance analyzer for TS
measurement to comply with the TRS monitoring requirements as allowed by the regulation. The Siemens
Maxum flare compliance analyzer uses three methods to monitor for the full TS range anticipated at the
Salt Lake City Refinery. The detailed design information for the TS analyzer follows:
Make: Siemens
Model: MAXUM ll
. Type: Gas Chromatograph
. Method 1:10-600 ppm as soz
o Method 2:450-20,000 ppm as SOz
o Method 3: 1 5,000-100,000 ppm as SOz
. Accuracy:2.0%o
r Precision:2.0o/ofor 10-600 ppm and 0.5o/otor 450-100,000 ppm
o TRS meter instrument tag:AT-040834
Additional calibration, maintenance and quality assurance procedures are specified within the Flare CEMS
QA/QC plan.
3.3.3.3 SRU Flore
SRU Flore Totol Sulfur lnstrumentofion Specificalions
The Tesoro Salt Lake City Refinery has installed a Siemens Maxum flare compliance analyzer for TS
measurement to comply with the TRS monitoring requirements as allowed by the regulation. The Siemens
Maxum flare compliance analyzer uses three methods to monitor for the full TS range anticipated at the
Salt Lake City Refinery. The detailed design information for the TS analyzer follows:
Make: Siemens
Model: MAXUM ll
Type: Gas Chromatograph
Method 1:20-1,200 ppm as SOz
Method 2: 900-40,000 ppm as SOz
Method 3:30,000-1,000,000 ppm as SOz
SLC Refinery FMP rev. 6 - 10/1/2024 25
Accuracy'. 2.0o/o
Precision: 2.0o/o f or 20-1 ,200 ppm, 1 .0% for 90-40,000 ppm, 0.5o/o f or 30,000- 1 ,000,000 ppm
o TS meter instrument tag: AI-23672
Additional calibration, maintenance and quality assurance procedures are specified within the Flare CEMS
QA/QC plan.
On July 27,2015, the EPA approved an Alternative Monitoring Plan (AMP)for the Tesoro Salt Lake City
Refinery regarding the concentration of the span gas used to check the daily calibration drift and high
range validation standards used during cylinder gas audits (CGAs). Tesoro requested that the extremely
high concentration hydrogen sulfide calibration gas which would be required by 40 CFR 60.13(dX1) and
Performance Specification 5 for the total sulfur CEMS at the SRU flare be eliminated. The approved AMP
requires Tesoro to conduct a linearity check over each of the three methods described above every three
(3) years. An R-squared correlation coefficient value of 0.95 or greater from the best-fit linear trend is
considered to be within tolerance.
Consistent with 40 CFR 560.107a(a)(2Xv), compliance with the HzS concentration requirements in
560.103a(h) for the SRU flare is demonstrated by the TRS analyzer. The span of Method 1 for the SRU TRS
analyzer is 20-1,200 ppm as total sulfur and satisfies the requirement in 560.107a(aX2)(v) that the
instrument has a span capable of accurately measuring concentrations between 20 and 300 ppmv.
The facility has at times experienced downtime with its gas chromatographs, in particular the total sulfur
units. During high analyzer downtime scenarios, the facility may rent certified continuous emission
monitoring systems to improve downtime performance. All analyzer serial numbers are reported in
quarterly continuous emission monitoring reports submitted to the Utah Division of Air Quality.
SLC Refinery FMP rev. 6 - 10/1/2024
4.0 Boseline Flow qnd Allernqlive Operoting
Scenorios [560.1 03o(ox4)l
NSPS Subpart Ja requires that a primary baseline flow rate be established for each flare. Alternative
operating scenarios with associated alternative baselines may also be established. Under NSPS Subpart Ja,
the trigger for conducting a mandatory root cause analysis (RCA) is 500,000 standard cubic feet per day
(SCFD) over the primary baseline during normal operations or 500,000 SCFD over any alternative baseline
while operating under the defined alternative operating scenarios. Required RCAs must be completed
within 45 days of the triggering event. A RCA does not need to be conducted for startup and shutdown
events if the procedures defined in Section 5.0 are followed, though the emissions associated with these
events must be reported.
Though the Tesoro Salt Lake City Refinery has three flares, there are two distinct flare systems. The North
and South Flares are interconnected and their individual flows and SOz emissions are combined for
baseline and compliance calculations. The SRU Flare operates independently. Therefore, there are two
systems for which baseline flow and alternatlve operating scenarios have been established.
The primary and alternative baselines for the Salt Lake City Refinery flares are summarized in Table 4-1 in
Section 4.3.
Any changes to the primary baseline flow or alternative baselines will require resubmission of this FMP.
4.1 Primory Boseline Flow Rote [560.103o(oXaXi)l
The primary baseline flow rate for the North and South Flare system, connected via FGR system, is zero.
The FGR system has been designed to capture all non-process upset gas flows. The RCA trigger for the
North and South flare system is thus 500,000 SCFD. This trigger applies to any Z4-hour period and must
be calculated on a rolling basis.
The SRU Flare has two regular contributions due to sweep gas; a natural gas sweep on the SRU flare
header and a nitrogen sweep on the Tail Gas Treating Unit (TGTU). These sweeps are necessary to ensure
the flare headers are purged of oxygen and that potentially acidic liquid does not accumulate. The
primary baseline flow for the SRU flare is 28,800 SCFD based on the minimum required flare sweeps and
the RCA trigger for the SRU flare is thus 528,800 SCFD. This trigger applies to any 24-hour period and
must be calculated on a rolling basis.
4.2 Allernotive Operoling Scenorios [560.1 O3o(oXaXii)l
The following alternative operating scenarios have been established based on past operating conditions
and updated to account for the anticipated flare minimization impacts of the FGR system. These are
appropriately designated as alternative operating scenarios, with corresponding alternative baselines,
because their root causes are understood and cannot be avoided without compromising the safety or
operational stability of the refinery, which would present risks of greater environmental impacts. These
scenarios are updated periodically based on learnings from previous flare events.
SLC Refinery FMP rev. 6 - 10/1/2024 27
Alternative operating scenarios have been established for the following conditions for the North and
South Flare System:
1. Fuel gas long or low fuel gas NHV while maximizing gasoline production
2. Diesel Desulfurization Unit (DDU) maintenance, outage or catalyst change
3. Diesel #1 production
4. Plant turnarounds
5. North flare hydrogen venting to stabilize vent gas flow meter low range readings
When the refinery is operating under one of these alternative operating scenarios, and thus subject to an
alternative baseline, that status will be documented. Documentation will include the conditions qualifying
the operations as one of the alternative operating scenarlos, the flare gas volume and sulfur content for
the duration of the event, and the procedures utilized to minimize flaring.
To minimize the environmental impact of alternative operating scenarios, in 2017 the refinery installed an
ultraformer hydrogen vent line that allows the facility to preferentially flare a hydrogen rich stream while
keeping higher emitting streams in the FGR system. Ultraformer hydrogen vent gas has a preponderance
of hydrogen which has a high effective Btu content and emits less regulated pollutants when combusted
than gas stream with a higher hydrocarbon content. This also allows the facility to reject hydrogen from
the refinery fuel gas system to ensure available gas provides safe and stable combustion, thereby
minimizing the volume and emissions intensity of gasses flared and the amount of supplemental natural
gas needed to maintain fuel gas NHV. Preferentially venting ultraformer hydrogen is a key minimization
effort for each of the alternative operating scenarios. During the first three alternative operating scenarios,
the flare gas composition is expected to be primarily hydrogen.
There are no alternative baselines for the SRU Flare.
4.2.1 Alternolive Operoting Scenqrio #l - Fuel Gos [ong/[ow NHV while
Moximizing Gosoline Produclion
When the refinery is operating in a manner that maximizes gasoline production, a refinery fuel gas
imbalance may result that necessitates flaring of excess refinery fuel gas that cannot be consumed by
refinery process heaters and boilers, either due to low quality (NHV) or excess refinery fuel gas generation.
Low heat content in fuel gas causes process heater and boiler flames to become unstable and presents an
unacceptable process safety risk. This alternative operating scenario has been established to describe this
condition, along with the anticipated flare gas volume and the procedures to minimize flaring while the
facility is refinery fuel gas long/low NHV.
4.2.1.1 Alternotive Operoting Scenorio #l Rotionole
The Salt Lake City Refinery supplies gasoline to meet market demand. Gasoline production may
potentially cause a refinery fuel gas imbalance (long/low NHV).
By preferentially venting ultraformer hydrogen during this scenario, the volume and emissions intensity of
the flare event is minimized.
SLC Refinery FMP rev. 6 - 10/1/2024
4.2.1.2 Alternolive Operoting Scenorio #l Doily Flow ond Expecled Durotion
The anticipated daily flow when refinery is fuel gas long/low NHV while maximizing gasoline production is
1,500,000 standard cubic feet per day (SCFD). The duration of this condition varies due to market demand,
fluctuations in liquefied petroleum gas (LPG) recovery in the FCCU, hydrogen production at the
Ultraformer Unit (UFU), and efficiency fluctuations in the refinery furnaces and steam production.
4.2.1.3 Aliernqtive Operoting Scenorio #l Boseline
The alternative baseline for Alternative Operating Scenario #1 is 1,500,000 SCFD.
When the refinery is determined to be operating under this scenario, the RCA trigger for the North and
South Flare System will thus be 2,000,000 SCFD (1,500,000 + 500,000 SCFD).
4.2.1.4 Allernotive Operoting Scenorio #1 Procedures for Flore Dischorge Minimizotion
During fuel gas long scenarios while maximizing gasoline production, the refinery takes the following
steps to minimize flaring:
. When possible, venting to flare will preferentially be achieved through the UFU hydrogen vent to
flare. This minimizes hydrocarbon flow to the flare.
r Natural gas supplementation is minimized except as needed to maintain fuel gas quality
(BTU/SCF) to ensure safe and correct operation of boilers and fired heaters.
o Refinery steam generation is maximized.
o Operating parameters are adjusted as practical while still meeting gasoline demand
Detailed procedures are described in the refinery's Fuel Gas Balance Guidelines (OPS-OI-005).
4.2.2 Allernolive Operollng Scenorio #2 - DDU Mointenonce or Cololysl Chonge
The DDU requires preventative maintenance and catalyst changes, which reduces the refinery hydrogen
demand and leads to a refinery fuel gas long scenario. To minimize the environmental impact of this
scenario, in 2017 the refinery installed an ultraformer hydrogen vent line that allows the facility to
preferentially flare a hydrogen rich stream while keeping higher emitting streams in the FGR system. This
also allows the facility to reject hydrogen from the refinery fuel gas system to ensure available gas
provides safe and stable combustion, thereby minimizing the volume and emissions intensity of gasses
flared.
4.2.2.1 Allernotive Operoling Scenorio #2 Rotionole
The DDU must be maintained at a high operating level to ensure the sulfur specifications for diesel fuel
are met. Maintaining this level of operation can require the unit to be shut down independently from the
rest of the refinery, leading to a fuel gas long scenario.
SLC Refinery FMP rev. 6 - 10/1/2024 29
By preferentially venting ultraformer hydrogen during this scenario, the volume and emissions intensity of
the flare event is minimized.
4.2.2.2 Alternolive Operoling Scenorio #2 Doily Flow ond Expecled Durolion
The anticipated daily flare flow when the DDU is shut down for maintenance or catalyst change is
3,500,000 SCFD. The anticipated duration for each event is up to 28 days assuming maintenance activities
go according to plan.
4.2.2.3 Alternolive Operoling Scenorio #2 Boseline
The alternative baseline for the North and South Flare System for Alternative Operating Scenario #2 is
9,500,000 scFD.
When the refinery is determined to be operating under this scenario, the RCA trigger will thus be
10,000,000 SCFD (9,500,000 + 500,000 SCFD).
4.2.2.4 Allernolive Operoling Scenorio #2 Procedures for Flqre Dischorge Minimizolion
During refinery fuel gas long scenarios due to DDU maintenance or catalyst change, the refinery takes the
following steps to minimize flaring:
r lf feasible, maintenance and catalyst changes are conducted with a DDU slowdown rather than
full shutdown
o When possible, venting to flare will preferentially be achieved through the UFU hydrogen vent to
flare. This minimizes hydrocarbon flow to the flare.
o Natural gas supplementation is minimized except as needed to maintain fuel gas quality
(BTU/SCF) to ensure safe and correct operation of boilers and fired heaters
o Refinery steam generation is maximized
. Operating parameters are adjusted as practical
Detailed procedures are described in the refinery's Fuel Gas Balance Guidelines (OPS-OI-005).
4.2.3 Allernolive Operoling Scenorlo #3 - Diesel #l Production
During the winter, the refinery produces Diesel #1, which reduces hydrogen demand due to the reduction
of sulfur compounds and heavy components in the feed.
4.2.3.1 Allernotive Operoting Scenorio #3 Rotionole
During a Diesel #1 run, light distillate is run through the DDU which leads to a significant decrease in
hydrogen demand. Diesel #1 runs are generally conducted twice per month in the winter and may lead to
a refinery fuel gas long or low NHV scenario.
By preferentially venting ultraformer hydrogen during this scenario, the volume and emissions intensity of
the flare event is minimized.
SLC Refinery FMP rev. 6 - 10/1/2024
4.2.3.2 Allernotive Operoling Scenorio #3 Doily Flow ond Expected Durotion
The anticipated daily flare flow during Diesel #1 runs is 6,500,000 SCFD. The anticipated duration is
approximately four days, twice per month during the winter months (winter diesel season is October
through April).
4.2.3.3 Atternotive Operoting Scenorio #3 Boseline
The alternative baseline for the North and South Flare System for Alternative Operating Scenario #3 is
6,500,000 scFD.
When the refinery is determined to be operating under this scenario, the RCA trigger will thus be
7,000,000 SCFD (6,500,000 + 500,000 SCFD).
4.2.3.4 Allernolive Operoting Scenorio #3 Procedures for Flore Dischorge Minimizotion
During refinery fuel gas long scenarios due to Diesel #1 runs, the refinery takes the following steps to
minimize flaring:
o When possible, venting to flare will preferentially be achieved through the UFU hydrogen vent to
flare. This minimizes hydrocarbon flow to the flare.
o Natural gas supplementation is minimized except as needed to maintain fuel gas quality
(BTU/SCF) to ensure safe and correct operation of boilers and fired heaters.
. Refinery steam generation is maximized
o Operating parameters are adjusted as practical
Detailed procedures are described in the refinery's Fuel Gas Balance procedure (OPS-Ol-005).
4.2.4 Alternolive Operoling Scenorio #4 - Plonl Turnqround
Approximately once every three to six years the refinery undergoes an extended outage for maintenance
and/or project work. During turnarounds all or part of the plant may be shutdown. Depending on the
nature and extent of work being performed the duration of these events can last several weeks.
Generally, the greatest risk of flaring during turnarounds occurs during shutdown at the beginning of the
event and startup at the end of the event.
Turnaround work scope often involves physical entry of pro€ess vessels by workers. To allow safe entry
into vessels, during shutdown the vessels are de-inventoried, flushed with process materials, steam
cleaned (sometimes with chemical cleaning agents), purged with inert gasses and vented to the
atmosphere, fuel gas system or flare system (or some combination thereof). During startup, the vessels
must be purged of oxygen priorto introducing process materials. Each scenario where a portion of the
plant is prepared for turnaround work or returned to operational service is evaluated individually.
31SLC Refinery FMP rev. 6 - 10/1/2024
Shutdown and startup sequencing and duration is planned to balance safety, flare minimization,
secondary environmental effects, operability and to minimize downtime.
While startup and shutdown flare minimization procedures detailed in Section 5 are applied to
turnarounds, turnarounds are distinct from more common outages because of the extent of units being
shut down, the extent of cleaning involved and the potential to shutdown flare gas management systems
such as headers, flare gas recovery equipment and the actual flares.
Purging process vessels and piping with inert gasses such as steam or nitrogen causes challenges
maintaining required flare gas or fuel gas net heating value and often requires supplementing with
natural gas.
4.2.4.1 Aliernotive Operoling Scenorio #4 Rotionole
All refinery equipment must be periodically shut down for maintenance or modification to ensure
ongoing safe and reliable operation. Because of the interconnected nature of operational units, these
activities are generally grouped into partial or full plant turnarounds.
4.2.4.2 Allernotive Operoling Scenorlo #4 Doily Flow ond Expected Durolion
The anticipated daily flare flow when the partial or full'refinery is shut down or started up for turnaround
is 5,00,000 SCFD. The anticipated duration for each event is one to three months depending on the nature
and extent of work being performed.
4.2.4.3 Allernotive Operoting Scenorlo #4 Boseline
The alternative baseline for the North and South Flare System for Alternative Operating Scenario #4 is
6,000,000 scFD.
When the refinery is determined to be operating under this scenario, the RCA trigger will thus be
6,500,000 SCFD (6,000,000 + 500,000 SCFD).
4.2.4.4 Allernotive Operoling Scenorio #4 Procedures for Flore Dischorge Minimizotion
During turnaround scenarios, the refinery takes the following steps to minimize flaring:
Frequency of turnarounds is minimized to the extent practicable.
Work is sequenced to contain process gasses in the refinery fuel gas system to the extent
practicable.
Deinventory, flushing, steaming, chemical cleaning and purging activities are planned to balance
safety, flare minimization, secondary environmental effects and operability.
Natural gas supplementation is minimized except as needed to maintain fuel gas quality
(BTU/SCF) to ensure safe and correct operation of boilers and fired heaters and compliance with
environmental limitations.
Refinery steam may be vented to maintain fuel gas balance
Operating parameters are adjusted as practical
a
a
a
a
SLC Refinery FMP rev. 6 - 10/1/2024
4.2.5 Alternolive Operoling Scenorio #5 - Norlh flore hydrogen venling to
siqbilize venl gos flow meler Iow ronge reodings
ln addition to New Source Performance Standards Subpart Ja (NSPS Ja), the refinery must also comply
with Consent Decree (CD) requirements. The refinery CD includes stringent 30 day and 365 day flare
volume caps. The refinery has experienced convection flows perpendicular to the header axis in the north
flare header that do not represent actual flow to the flare but jeopardize compliance with these flare caps.
This effect has been documented in published literature, including Flore Gos Ultrasonic Flow Measurement
with lmproved Accuracy ot Low Flow ond Enhanced lmmunity to Cross FIow (James E Matson et. al., The
Americas Flow Measurement Conference, April 2012). During these conditions, the refinery has found that
venting a small volume of hydrogen via bypass to the flare header disrupts convection flows and results in
a more accurate flow reading. This is generally accomplished with third-party supplied high purity
hydrogen. Hydrogen is excluded from the CD flare caps, thereby resulting in improved compliance with
the CD flare caps, but a slight increase in flows measured again the NSPS Ja flare caps. As previously
noted, hydrogen has a high Btu value, does not result in emissions of regulated pollutants, and reduces
visible flare emissions.
4.2.5.1 Alternotive Operoting Scenorio #5 Rotionole
The Salt Lake City Refinery complies with multiple, inconsistent flare regulations. This practice has been
adopted to enhance compliance with CD requirements.
4.2.5.2 Allernotive Operoling Scenorio #5 Dolly Flow ond Expecled Durotion
The duration of this practice depends on the current compliance status of multiple regulations. The
refinery has an incentive to minimize this practice as it is generally accomplished with purchased high
purity hydrogen.
4.2.5.3 Allernotive Operoling Scenorio #5 Boseline
The alternative baseline for Alternative Operating Scenario #5 is 500,000 SCFD. This quantity is based on
the experience of the refinery.
When the refinery is determined to be operating under this scenario, the RCA trigger for the North and
South Flare System will thus be 1,000,000 SCFD (500,000 + 500,000 SCFD).
4.2.5.4 Allernolive Operoling Scenorio #5 Procedures for Flore Dischorge Minimizotion
During north flare hydrogen venting scenarios, the amount of hydrogen vented will be minimized as
practicable to enhance compliance with other regulatory requirements. Other flaring sources will be
minimized as practicable.
Periods when operating
Detailed procedures are described in the refinery's Fuel Gas Balance Guidelines (OPS-OI-005).
SLC Refinery FMP rev. 6 - 10/1/2024 33
4.3 Primory ond Allernolive Boselines Summory
Tqbte 4-l Primory ond Allernolive Bosellne Summory
North & South
Primary O SCFD s00,000 scFD 500 lblday SOz Normal Operation 4.1
North & South
Alternative #1 1,s00,000 scFD 2,000,000 scFD 500 lblday SOz
Refinery Fuel Gas
long while
Maximizing
Gasoline
Production
4.2;l
North & South
Alternative #2 6,500,000 scFD 7,000,000 scFD 500 lblday 5Oz
Refinery Fuel Gas
long due to DDU
maintenance or
catalyst change
4.2.2
North & South
Alternative #3 9,500,000 scFD 10,000,000 scFD 500 lblday SOz
Refinery Fuel Gas
long due to Diesel
#1 runs during the
winter months
4.2.3
North & South
Alternative #4 6,000,000 6,s00,00 500 lblday SOz Turnaround 4.2.4
North & South
Alternative #5 s00,000 1,000,000 500 lblday SOz
North flare
hydrogen venting
to stabilize vent gas
flow meter low
range readings
4.2.5
SRU Primary 28,800 SCFD 528,800 SCFD 500 lb/day SOz All SRU Operation 4.1
SLC Refinery FMP rev. 6 - 10/1/2024
5.0 Storlup ond Shuldown Flore Minimizolion
Proced ures [S60. 1 03o(ox5)l
The procedures for minimizing flaring during the planned startup and shutdown of the refinery, areas,
units, and equipment are described in Section 5.1 below. Detailed procedures are included in the
refinery's Flare Management Plan and the unit startup and shutdown procedures.
Per 560.103a(dX3):
lf the dischorge from o flore is the result of a plonned stortup or shutdown of o refinery process unit
or ancillory equipment connected to the affected flare and the procedures in poragroph (a)(5) of this
section were followed, a root couse onolysis and corrective oction onalysis b not required; however,
the dischorge must be recorded os described in 560.108a(c)(6) and reported as described in
560.108a(d)(s).
Section 5.1 below describes the procedures required by $60.103a(a)(5). lmplementation of these
procedures will be documented for each planned startup and shutdown to demonstrate compliance with
560.103a(dX3). When the procedures are implemented, a RCA is not required for flow in excess of the RCA
triggers described in Section 4.0, though the discharge must be recorded and reported.
The refinery will verify that these procedures have been followed by completing the Startup and
Shutdown Flare Minimization Checklist in the Flare Management Plan RWP. Under this checklist, the
refinery will evaluate each opportunity for flare minimization and document the course chosen to best
balance safety, flare minimization, secondary environmental effects, and operability.
5.1 lmplemented Stortup ond Shuldown Flore Flow Minimizolion
Procedures
A pre-shutdown flare evaluation will be conducted for each planned startup and shutdown of the refinery,
individual area, process unit, or system with significant flaring potential. The flare evaluation will
document each element that may result in flaring along with the minimization procedure described below
and in the refinery's Flare Management Plan.
For the North and South Areas, the shutdown of individual pieces of equipment or small systems that can
be accommodated by the FGR operator without flaring do not require a full flare evaluation. ln such cases,
the operator of the unit in which the small-scale shutdown is taking place will coordinate with the FGR
operatorto ensure there is sufficient capacity in the FGR system to capture all vent gases from equipment
and avoid flaring. Because a flare minimization evaluation of the procedures belowwill not be conducted,
the RCA exemption cited in 560.103a(dX3) will not apply in these cases.
Planned shutdowns in the SRU and TGTU will be evaluated when the activity poses a risk of exceeding the
flow or SOz RCA triggers.
SLC Refinery FMP rev. 6 - 10/1/2024 35
5.1.1 Storlup Floring Risks
During planned startups, there are risks of flaring due to the following operations:
1. Refinery fuel gas imbalance
2. Evacuation of oxygen and inert gases from operating units
3- Pressure control
5.1.2 Procedures to Minimize Slorlup Floring
The flaring risks cited in Section 5.1.1 will be addressed by the following procedures:
1.Refinery fuel gas imbalance will be prevented, to the extent possible, by coordinating the
sequence and rate of startup and by following the procedures described in Section 5.'1. When safe
and practicable, the refinery will start up refinery fuel gas consumers prior to fuel gas generators
and coordinate their rates to prevent a refinery fuel gas long scenario. When a refinery fuel gas
long scenario cannot be avoided, its duration and volume will be limited to the extent practicable.
Evacuation of oxygen and inert gases from operating units may require flaring when it is unsafe to
vent these gases to the FGR system due to safety or operability concerns (e.9., when these
materials would adversely affect the refinery fuel gas system). When practicable, this venting will
be coordinated to minimize the hydrocarbons vented from the unit or other operating units due
to the water seal being broken.
Upon startup, many vessels require venting to the flare header for pressure control until steady
state operating conditions are achieved. When practicable, this venting will be planned to occur
when the FGR system is online and the refinery fuel gas system is able to receive and effectively
combust the vented gases. When the FGR system is unable to accept the vented gases, efforts will
be made to limit the volume and duration of flaring.
Shuldown Floring Risks
planned shutdowns, there are risks of flaring due to the following operations:
Depressuring equipment and operating units
Final deinventorying of liquid and low-pressure vapor from equipment and operating units
Cleaning equipment and operating units using steaming and chemical cleaning
Gas routing limitations due to offline equipment
Refinery fuel gas imbalance
5.1.3
During
1.
2.
3.
4.
5.
2.
5.1.4 Procedures lo Minimize Shutdown Flqring
The flaring risks cited in Section 5.1.3 will be addressed by the following procedures:
1. Equipment will be depressured to the refinery fuel gas system when feasible based on piping and
equipment pressure. When direct depressuring to the refinery fuel gas system is infeasible, the
equipment will be vented to the flare header, recovered through the FGR system and sent to the
SLC Refinery FMP rev. 6 - 10/1/2024
amine treating and refinery fuel gas systems. Any hydrocarbons unable to be vented to the FGR
system which must be flared will be limited to the extent possible without compromising safety.
Final deinventorying of liquid and low-pressure vapor from equipment and operating units will be
achieved using the FGR system, when feasible. Any hydrocarbons unable to be vented to the FGR
system which must be flared will be limited to the extent possible without compromising safety.
After equipment is deinventoried it needs to be rendered inerl by removing hydrocarbons so the
equipment residuals are below specified safety and environmental limits. lnerting is achieved by a
combination of steaming and, when practicable, chemical cleaning.
o Steaming is required for all inerting efforts including those supplemented by chemical
cleaning, which reduces the overall volume of steam required. When safe and technically
feasible, cleaning steam will be condensed and removed from the flare system.
Condensers can be used when suitable discharge ports are available from the equipment
being deinventoried, when it is practicable to coordinate their use, and when it is feasible
to dispose of their liquid discharge. When using condensers is not feasible, steaming
through the FGR system will be used if steaming to FGR would not exceed the
temperature limits of the compressors or reduce the refinery fuel gas heating value below
the minimum requirement of 740 btu/scf. lf steaming to FGR is not feasible based on the
conditions cited above, steaming to the flare may be required. Steaming to the flare
displaces the water seal and allows all interconnected equipment to vent directly to the
flare. ln such cases, steaming will be conducted as quickly as possible to minimize the
flaring of vent gas from interconnected equipment.
Chemical cleaning reduces flaring emissions and reduces the duration of preparing the
equipment for vessel entry. Chemical cleaning is used when safe and technically feasible.
Gas routing limitations due to offline equipment arise when interconnected systems are required
to be shut down in a sequence that prevents certain units and equipment from routing their
gases to the refinery fuel gas or FGR systems. The sequence of unit and equipment shutdown will
be considered to reduce gas routing limitations and to avoid flaring unless doing otherwise would
present a greater risk to safety, flaring, or secondary environmental impacts via operability.
5.2 Plonned Stortup ond Shuldown Flore Flow Minimizotion
Procedures
Additional methods of minimizing flaring during planned startups and shutdowns are being evaluated for
future implementation including expanded use of condensers and chemical cleaning.
Flaring performance during planned startups and shutdowns will be monitored moving fonvard and
procedures will be updated as opportunities to further minimize flaring are identified.
4.
SLC Refinery FMP rev. 6 - 10/1/2024 37
6.0 Fuel Gos lmbolqnce Flore Minimizqtion
Procedures [560.1 03o(ox6)l
Tesoro Salt Lake City has well-established procedures for addressing refinery fuel gas imbalances and
minimize flaring. These procedures are described in Section 6.'l below.
6.1 lmplemenled Fuel Gos lmbolonce Flore Flow Minimizotion
Procedures
ln conjunction with the five (5) alternative operating scenarios described in Section 4.0 of this FMP, flare
minimization during refinery fuel gas imbalances is achieved by preventing, when possible, refinery fuel
gas long scenarios, preparing for those which are unavoidable, and responding to them appropriately.
Preventing refinery fuel gas long scenarios, when practicable, is achieved by coordinating production rates
and planned outages. The two primary contributing causes to refinery fuel gas long scenarios are
misalignment between refinery fuel gas producers and refinery fuel gas consumers, and high inventories
of propane and butane. When practicable, outages of refinery fuel gas users will be coordinated with
reduced rates or outages at refinery fuel gas producers, primarily the FCCU and the UFU. The Salt Lake
City Refinery endeavors to manage propane and butane inventories to ensure these gases do not need to
be vented to the flare network when insufficient refinery fuel gas demand exists to prevent flaring.
Preparation for unavoidable refinery fuel gas long scenarios is focused on minimizing propane and butane
inventories prior to the events. By limiting inventories to the extent practical prior to the refinery fuel gas
imbalance events, the quantity of propane and butane flared is reduced.
Tesoro Salt Lake City's Standard Operating lnstruction (OPS-Ol-005) contains the detailed instructions for
minimizing flaring during refinery fuel gas imbalances when they cannot be prevented. The key elements
of this work instruction include minimizing natural gas supplementation, decreasing refinery fuel gas
production, and increasing refinery fuel gas consumption. Strategies for achieving these goals are
described in Sections 6.1.1-6.1.3. The procedures in OPS-OI-005 have proven sufficient to address refinery
fuel gas imbalances during normal operations. Abnormal operating conditions, including planned or
unplanned outages in one or more units or areas, are addressed in Sections 4.0 and 5.0 of this flare
management plan.
6.1.1 Minimize Nqlurol Gos Supplementoiion
When a refinery fuel gas long scenario is identified, natural gas supplementation will be minimized to the
refinery fuel gas system as soon as practicable.
6.1.2 lncreose Fuel Gos Consumplion
Refinery fuel gas consumption will be increased by maximizing the Cogen firing rate, increasing the rate
and subsequent refinery fuel gas demand at key refinery fuel gas consuming units, and maximizing
hydrogen uptake as practicable.
SLC Refinery FMP rev. 6 - 10/1/2024 38
Maximizing the Cogen firing rate will generate electrical power and steam for the refinery. ln cases where
Cogen is at its maximum rate or othenvise limited, refinery fuel gas may also be routed to the Cogen Duct
Burner to produce additional steam.
During periods of fuelgas imbalance, refineryfuel gas consuming units, including the Crude Unit, DDU,
and Benzene Saturation Unit (BSU), will increase production to consume excess refinery fuel gas.
Hydrogen inputs to the refinery will be reduced to the degree practicable to further limit the energy input
to the refinery and maximize refinery fuel gas usage.
6.1.3 Decreose Fuel Gos Produclion
Refinery fuel gas production will be reduced by decreasing the FCCU operating temperature, decreasing
the feed rates to the FCCU and UFU to the extent required to comply with regulatory flare volume caps,
and increasing propane recovery at the following units: Vapor Recovery Unit (VRU), Ultraformer Unit
(UFU), Diesel Desulfurization Unit (DDU), and Benzene Saturation Unit (BSU).
Decreasing the operating temperature of the FCCU reduces the amount of refinery fuel gas produced in
the unit. ln most minor refinery fuel gas imbalance situations, this is sufficient to restore balance. lf
reducing the temperature of the FCCU is not sufficient, the following additional steps may be taken.
Decreasing the feed rate to the FCCU and UFU, to the extent necessary to comply with regulatory flare
volume caps, will reduce refinery fuel gas production. Feed rates are adjusted, as needed, to bring the
refinery fuel gas production and consumption into balance. The feed rates are reduced only to the extent
necessary to comply with regulatory flare volume caps or their specified minimums, below which there is a
significant risk of instability and increased emissions due to an unplanned shutdown.
lf decreasing the operating temperature in the FCCU and decreasing the feed rate of the FCCU and UFU,
paired with the increase of refinery fuel gas consumption described in Section 6.1.2, are insufficient to
restore balance to the refinery fuel gas system, refinery fuel gas production can be further reduced by
increasing the recovery of propane at the VRU, UFU, DDU, and BSU. Propane recovery is normally
maximized during refinery operation but can be moderated at times to balance storage capacity. Under a
refinery fuel gas long scenario, increasing inventories of propane is beneficial for reducing the volume of
refinery fuel gas.
6.2 Plonned Fuel Gos lmbolonce Flore Flow Minimizotion Procedures
There are currently no planned refinery fuel gas imbalance flare flow minimization procedures that have
not already been implemented. The refinery's flaring will be evaluated moving forward and procedures
will be updated when safe, technically feasible, and appropriate.
SLC Refinery FMP rev. 6 - 10/1/2024 39
7.0 Flore Gos Recovery Ouloge Reduclion
Procedures [S60.1 03o(ox7)l
7.1 lmplemenied Flore Gos Recovery Outoge Reduction Procedures
FGR system outage reduction procedures include the following categories, each of which are described in
more detail below:
1. Design
2. Preventative Maintenance
3. Operating Approach
4. Online Monitoring
5. Operator Training
The FGR system has been designed to minimize outages by including three liquid ring seal compressors,
redundant systems for online maintenance, and online monitoring. The three compressors will operate in
primary, secondary, and backup roles as described in the operating approach section below. Redundant
systems include key flow, pressure, and other monitoring instrumentation, spare pumps, multiple fans for
the liquid ring water cooling system, and duplicate ring water basket strainers to allow for online
swapping, cleaning, and maintenance. The FGR system has been designed with extensive online
monitoring to ensure the system is operating effectively prior to high flare gas recovery loads, detect
problems proactively, and determine when maintenance is required as described below.
Preventative maintenance on the FGR compressors and supporting systems are conducted in accordance
with the manufacturers'recommendations. The manufacturer's recommended preventative maintenance
includes visual inspections, measurement of key parameters, lubrication checks, and filter replacements.
Detailed maintenance procedures and schedules are in the compressors'operation and maintenance
manual. The installation of three compressors, each of which is capable of handling the refinery's normal
flare flow, enables timely and effective completion of preventative maintenance. As described below, one
compressor operates in manual mode while the other two operate and respond to flare header conditions
automatically in primary and secondary modes. This configuration allows preventative maintenance to be
conducted on any compressor except during rare times when all three compressors are needed to
manage the flare header flow, usually associated with shutdown activities. Preventative maintenance on
the FGR system's supporting equipment is scheduled to coincide with times when flare flows are very low
or during facility shutdowns.
The three FGR compressors installed at the Salt Lake City Refinery allow for a flexible operating approach
that allows the refinery to adapt to different operating conditions while maintaining the compressors as
described above. One compressor will typically operate in primary service, another in secondary service,
and the last in manual service. Each compressor has been designed to capture the anticipated refinery
flow during normal operations and can serve in the primary, secondary, or manual mode. The primary
compressor will operate continuously. When there is not enough vent gas to meet the compressor's
required minimum, a portion of the compressed gas is recycled. The secondary compressor will come
SLC Refinery FMP rev, 6 - 10/1/2024 40
online when flare header pressure rises to a set point that indicates the primary compressor has reached
its capacity. When the suction pressure drops and the recycle valve is required to open, the secondary
compressor will automatically shut down. The manual compressor may be started directly by either the
board or field operator during times when flare header loads are anticipated to exceed the primary and
secondary compressors' capacities. Prior to the startup of any compressor, specific conditions must be
met to ensure safe and reliable operation.
The FGR system has extensive online monitoring for the compressors, seal drums, and their supporting
equipment. Online monitoring systems have been designed to alarm initially when operating conditions
approach their limits to allow operators to take corrective action. lf the operating conditions cannot be
returned to normal operating ranges, the system will automatically shut down the compressor to prevent
unsafe conditions and damage to the compressors and other refinery equipment. The compressors will
only be restarted after all parameters are returned to normal ranges.
All refinery operators have been trained on the basic operation of FGR to ensure they understand how the
flare gas loads affect the system. The FGR operators and maintenance personnel have received additional
training on the control logic, alarms, operating approach, troubleshooting, and maintenance of the FGR
system.
While the FGR system has operated almost continuously since it was installed in 2015, it underwent
extensive maintenance during plantwide turnarounds in 2020 and 2024. These maintenance periods were
minimized in accordance with site CD requirements.
Since the FGR system has been operating it has consistently surpassed the availability requirements
established in the facility's consent Decree.
7.2 Plonned Flore Gos Recovery Outoge Reduction Procedures
There are currently no planned flare gas recovery outage reduction procedures that have not been
implemented. The Salt Lake City Refinery will monitor FGR system uptime and the causes of any outages,
then update the procedures if necessary.
SLC Refinery FMP rev. 6 - 10/1/2024 41
8.0 FMP Revision Deloils
8.1 Revision Summory
Toble 8-l Hlstory ol revlslons
Revision details are included in Appendix A.
8.2 Chonges for Nexl Revision
Toble 8-2 Chonges lor nexl revislon
These changes have been documented and will be incorporated in the next revision of this plan. Changes
are documented here to allow this plan to remain current between major revisions.
November 11,2015
Update to Alternative Scenario - DDU (4.2.2) and to flare
minimization efforts (2.0 - 2.3)
November 11,2019
Update alternative operating scenarios to reflect full use of
ultraformer hydrogen vent line and use of thermal dispersion flow
meter to measure low density gas streams at south flare.
Added alternative baseline scenario for TAR Updated information
for new SRU flare tip installed during 2020 TAR Updated north
flare flow meter information.
Technical correction per collaborative audit finding North and
South supplemental gas is Refinery Fuel Gas. Updated Table 3.1.
Minor technical updates. Updates to Sections 4.2.2,4.2.3 and
addition of Section 4.2.5
SLC Refinery FMP rev. 6 - 10/1/2024 42
Appendix A
Reserved
Appendix B
Flore Conneclion Lisl ond SRU Minimizolion Assessmenl
Solt Loke City Refinery Flore Conneclion lisl
Table 1: North Flare Connections
ALK-OO1 North Alky F-446 - PSV 6-82 PSV
ALK-OO2 North Alky F-447 - PSV 6-83 PSV
ALK-OO3 North Alky l-448 - Manual Manual
ALK-O04 North Alky F-403 - PSV 6-18 PSV
ALK-OO5 North Alky C-402A Samole Alkv Feed & F-452 Out - Samole Sample
ALK-OO6 North Alkv F-402 - PSV 6-17 PSV
ALK-OO7 North Alkv F-425 - PSV 6-39 PSV
ALK-OO8 North Alky F-402 - DIB Sample Point Sample
ALK-OO9 North Alkv F-426A Chroma - GC Sample Sample
ALK-O1O North Alky c-402B - PSV 5-59 PSV
ALK-o11 North Alkv c-402A - PSV 6-58 PSV
ALK-012 North Alkv F-452 - PSV 6-97 PSV
ALK-o13 North Alkv F-4274 - PSV 6-40 PSV
ALK-014 North Alky F-4278 - PSV 6-44 PSV
ALK-o15 North Alky F-427AlBlClD Vent (propane bullets)- Manual Manual
ALK-o16 North Alkv F-453A/B J-929s Seal Pots - Seal Pot Seal Pot/Seal
ALK-017 North Alky )-929A/B - Manual Manual
ALK-018 North Alkv F-406 - PSV 6-21 PSV
ALK-019 North Alky F-409 - PSV 6-25 PSV
ALK-O2O North Alky c-415 - PSV 6-84 PSV
ALK-021 North Alky J-4114 - Seal Pot Seal Pot/Seal
ALK-022 North Alky l-417 - Manual Manual
ALK-023 North Alky J-409a - Manual Manual
ALK-024 North Alky J-408A - Seal Pot Seal Pot/Seal
ALK.025 North Alky J-408 - Seal Pot seal oot/seal
ALK-026 North Alky J-4tL - Pumo Seals Seal Pot/Seal
ALK-027 North Alkv J-407A - Manual Manual
ALK-028 North Alky Reactor Effluent Samoler - Manual Manual
ALK-029 North AIKV l-407 - Manual Manual
ALK-O3O North Alky J-406A - Seal Pot seal pot/seal
ALK-031 North Alky J-4O6 - Seal Pot seal oot/seal
ALK-032 North Alky F-415B - PSV 6-35 PSV
ALK-033 North Alky F-4158 - PCV 6418 Control Valve
ALK-034 North Alky l-422/F4L5B - Manual Manual
ALK-035 North Alky Nitrosen - PCV 8278 Control Valve
ALK-036 North Alky J-439 I J-438/ )-437 - Manual Manual
ALK-037 North Alky F-446 - Manual Manual
ALK.O38 North Alky F-403 - Manual Manual
ALK-039 North Alky J-413G SS Tubing - Pump Seal Seal Pot/Seal
ALK-O4O North Alkv J-413G - Manual Manual
ALK-041 North Alkv -413F - Manual Manual
ALK-042 North Alkv ,-413C - Manual Manual
ALK-043 North Rlky J-4138 - Manual Manual
ALK-044 North Alkv -413E - Manual Manual
ALK-045 North Alkv -4134 - Manual Manual
ALK-045 North Alky F-410A/B - Manual Manual
ALK-047 North Alky F-429 Pressure Controller - Manual Manual
ALK-048 North Alky -4128 SS - Manual Manual
ALK-049 North Alky a-472A SS - Manual Manual
ALK-O5O North Alkv -402 AlB TS - Manual Manual
ALK-051 North Alky F-436 - Manual Manual
ALK-052 North Alky F -445 I J-4351J-4358 - Ma nual Manual
ALK-053 North Alky Nitroeen Puree - Sweeo )weep
ALK-054 North Alky F-442 - PSV 5-80 PSV
ALK-055 North Alky F-434 - PSV 6-77 PSV
ALK-056 North Alky F-401D - PSV 6-16 Bvoass PSV
ALK-057 North Alky F-401C - PSV 6-14 Bvpass PSV
ALK-058 North Alky F-401D - PSV 6-16 PSV
ALK-059 North Alky F-401D - PSV 6-15 PSV
ALK.O50 North Alky F-401C - PSV 6-14 PSV
ALK-061 North Alky F-401C - PSV 6-13 PSV
ALK-052 North Alky F-4018 - PSV 6-12 Bvoass PSV
ALK-063 North Alky F-401A - PSV 6-10 Bvoass PSV
ALK-064 North Alky F-4018 - PSV 6-12 PSV
ALK-055 North Alkv F-4018 - PSV 6-11 PSV
ALK-066 North Alky F-401A - PSV 6-10 PSV
ALK-057 North Alky F-401A - PSV 6-11 PSV
ALK-068 North Alky F-448 - PSV 6-67 PSV
ALK.O59 North Alky t-445 - PSV 6-81 PSV
ALK-O7O North Alky F-436 - PSV 6-78 PSV
ALK-071 North Alky F-4tt - PSV 6-28 PSV
ALK.O72 North Alky F-4158 - Manual Manual
ALK.O73 North Alky F-418 Vent - Vent Vent
ALK.O74 North Alkv -830 Knockout Pot - Manual Manual
ALK-075 North Alky -154A/B PPs - Pump Pumo
ALK-076 North Alky C-152s SS/C-151s SS/C-150s SS/C-158/C-159 SS - Drains Drain
ALK-077 North Alkv F-4O2 - Pressure Valve Control Valve
ALK-078 North Alkv F-426A - Pressure Valve Control Valve
ALK.O79 North Alkv F-452 - Pressure Valve Control Valve
ALK-O8O North Alky F-405W - Manual Pumpout
ALK-08'l North Alky F-406W - Manual Pumpout
ALK-082 North Alky C-415 - Manual Pumoout
ALK-083 North Alkv F-409W - Manual Pumpout
ALK-084 North Alky F-407W - Manual Pumpout
ALK-085 North Alky C-414 - Manual Pumoout
ALK-085 North Alky E-404 - Manual Pumpout
ALK.O87 North Alky F-4158 - Manual Pumoout
ALK-088 North Alky C-401 - Manual Pumpout
ALK-089 North Alkv C-408 - Manual Pumpout
ALK-09O North Alky E-402 - Manual Pumpout
ALK-091 North Alky C-406A - Manual Pumoout
ALK-092 North Alky E-401 - Manual )umpout
ALK-093 North Alky C-4068 - Manual )umpout
BLR-OO1 North BLR BLR System - PSV 15-103/15-89/15-90/15-91 )SV
BLR.OO2 North BLR t-848/849 - PSV 15-10U15-102 )SV
BLR-OO3 North BLR J-988 A/B - Seal Pot ieal Pot/Seal
BLR-O04 North BLR Proposed Location for New Loading Rack 1-6 (716 Track) -
Futu re Futu re
BLR-OO5 North BLR TK 155 - PSV 15-72 )SV
BLR-OO6 North BLR Load Rail spots 1-4 (715 Track) Truck Rack, Truck lsland -
Loadins Rack -oading
BLR-OO7 North BLR J-929A/B - PSV 15-59 )SV
BLR-O08 North BLR BLR - PSV 15-62 PSV
BLR-OO9 North BLR Prooane to C-402 - PSV 15-69 )SV
BLR-01 O North BLR F-872 - PSV 15-58 )SV
BLR-o1 1 North BLR J-952 - Manual Vent Manual
BLR.O1 2 North BLR F-872 - HCV-149 lontrol Valve
BLR-01 3 North BLR E-818 - PSV 15-76 PSV
BLR-014 North BLR E-818 - Hot Propane Manual
BLR-o,I5 North BLR J-951A to Loadine Soot - PSV 15-54 PSV
BLR.O1 5 North BLR J-9514 to Tk-155 - PSV 15-52 PSV
BLR-01 7 North BLR Butane Rack - PSV 15-88 PSV
BLR-01 8 North BLR J-954 Compressor Packing Vents - PSV 15-84,85,86,87 PSV
BLR-o1 9 North BLR F-870A - Manual Drain Manual
BLR-O2O North BLR J-951 A/B - Manual Manual
BLR-02 1 North BLR F-871 - PSV 15-53 PSV
BLR-022 North BLR F-871- HCV-135 Sontrol Valve
BLR-023 North BLR Butane Loadins - PSV 15-56.57 PSV
BLR-024 North BLR j-852A/B - PSV 15-55 PSV
BLR.O25 North BLR J-852A(B - PSV 15-51 P5V
BLR-025 North BLR Nitrogen Purge - Sweep N2 Puree
BLR.O27 North BLR iC4 to Alkv - PSV 15-71 PSV
BLR-028 North BLR iC4 to Alky - PSV 15-70 PSV
BLR-029 North BLR Rail Loading Arms C3 and C4 - PSV 15-61,62,63,64,65,66 )SV
BLR-O3O North BLR TK-155 - Vent y'ent
BLR-031 North BLR )-813A/B/C - Manual Drains Manual
BLR.O32 North BLR TK-155 - PCV 14206 lontrol Valve
BLR-033 North BLR )-8521J-876L-830lTk 329 - Manual Vent/Drain Manual
coB-001 North COB F-51 COB FG KO Drum - Manual Drain Vlanual
coB-002 North COB coB - PCV-120270 lontrol Valve
coB-003 North COB F-51 - PSV 3-9 )SV
coG-001 North COGEN East/West Duct Burner Drains - Drains Manual
coG-002 North COGEN v-957 - PSV 13-66 PSV
coG-003 North COGEN V-917 - Manual Drain Vanual
coG-004 North COGEN v-977 - PSV 13-35 PSV
coG-005 North COGEN V-957 COGEN FG KO drum - Manual Drain Vlanual
coG-005 North COGEN l-82 Gas Fuel Filter - Manual Vent Manual
coG-007 North COGEN J-81 Gas Fuel Filter - Manual Vent Manual
coG-008 North COGEN v-935 - PSV 13-67 PSV
coG-009 North COGEN V-9541V-O5tlV-935 - Manual Vents Manual
coc-010 North COGEN v-953 - PSV 13-54 PSV
coc-011 North COGEN E-951 TS - PSV 13-65 PSV
coc-012 North COGEN /-951 - PSV 13-63 PSV
coc-013 North COGEN r'-917 Sweet Gas Purge - Sweep )weep
coc-014 North COGEN r'-917 Sweet Gas Purge (#2) - Sweep iweep
coc-015 North COGEN North Flare Connection - V-917lCoeen Manual
FCU-OO1 North FCU F-15 FCC FG KO Drum - Manual Drain Manual
FCU-OO2 North FCU :-05 SS - Manual Drain Manual
FCU.OO3 North FCU -05 TS - Manual Drain Manual
FCU-004 North FCU -09 - Manual Drain Manual
FCU-005 North FCU LCO Wash to C-13s - Manual )umpout
FCU-006 North FCU -13 - Manual Drain )umpout
FCU-OO7 North FCU 15 TS - Manual Drain Vlanual
FCU-OO8 North FCU Slurrv Line - Manual Drain Vlanual
FCU-009 North FCU :-1318 TS/C-132C TS - Manual Drain Vanual
FCU-O1O North FCU -1148 TS/C-1168 TS - Manual Drain Vanual
FCU-o11 North FCU -19A/J-19B - Manual Drain Vlanual
FCU-0'r2 North FCU -06 TS - Manual Drain Vlanual
FCU-013 North FCU :-06 SS - Manual Drain Vanual
FCU-014 North FCU -03A/B - Manual Drain Vlanual
FCU.O15 North FCU E-1 - PCV 100880 lontrol Valve
GHT-OO1 North GHT :eed Sampler Vent - Manual Vent Vlanual
GHT-OO2 North GHT )-701A/70t8 Seal Pot - Seal Pot/Seal Seal Pot/Seal
GHT-OO3 North GHT )-701 - PSV 7-01 PSV
GHT-OO4 North GHT )-706 - Manual Drain Manual
GHT-OO5 North GHT )-706 - PSV 7-08 PSV
GHT.OO6 North GHT )-705 Overhead - PCV270180 Control Valve
GHT-OO7 North GHT )-7O3BlA Seal Pot - Manual Vent Seal Pot/Seal
GHT-OO8 North GHT )-703A Seal Pot - Manual Vent Seal Pot/Seal
GHT-OO9 North GHT >-703A/B - Manual Vents Manual
GHT-O1O North GHT F-701 Fuel Gas - XV270042C Vent Control Valve
GHT-o1'r North GHT F-701 Pilot Gas - XV270046C Vent Control Valve
GHT.O12 North GHT D-702 Bottoms - SW Boot Manual
GHT-o13 North GHT D-702 Bottoms - PSV 7-02 PSV
GHT-014 North GHT 0-702 - xv-270101 Control Valve
GHT-o15 North GHT R-701 Bottoms - Manual Vent Manual
GHT-0,I6 North GHT D-705 Waterboot - Manual Drain Manual
GHT-o17 North GHT c-702 - PSV 7-07 PSV
GHT-o18 North GHT C-702 Bottoms - Manual Drain Manual
GHT-o19 North GHT c-707 - PSV 7-03 PSV
GHT-O2O North GHT D-703 Bottoms - Manual Drain Manual
GHT.021 North GHT SP/14 Sample Point Vent - Sample Sample
GHT-022 North GHT D-704 - PSV 7-04 PSV
GHT-023 North GHT K701A D-709 - PSV 7-05 PSV
GHT-024 North GHT D-710 - PSV 7-06 PSV
GHT-025 North GHT D-7tt - PSV 7-09 PSV
GHT-026 North GHT K-701A - Outboard Vent Seal Pot/Seal
GHT.O27 North GHT K-7014 - lnboard Vent Seal Pot/Seal
GHT-028 North GHT K-7018 - lnboard Vent Seal Pot/Seal
GHT-029 North GHT K-7018 - Pressure Packine Vent Packins Vent
GHT-O3O North GHT K-7018 - Outboard Vent Seal Pot/Seal
GHT.O31 North GHT K-7014 (D-7071D-709) - Manual Vent Manual
GHT-032 North GHT K-7018 (D-7O8{D-7LO) - Manual Vent Manual
GHT-033 North GHT K-701A - Pressure Packing Vent Packine Vent
GHT.O34 North GHT Natural Gas Purse - Purqe Sweep
PLY-OO1 North Poly E-323 - PSV 8-36 PSV
PLY-OO2 North Poly F-322 - PSV 6-57 PSV
PLY-OO3 North Poly F-32OW/F-321W - Manual Manual
PLY-O04 North Poly F-310 Poly/Debut - Sample Point Level Gauge Sample
PLY-OO5 North Poly F-302/F-3O3 - Manual Manual
PLY-OO6 North Poly F-310W (PolyDebut Ovh) - LCV 8103 Control Valve
PLY-OO7 North Poly F-322 - Samole Point Uostream of FCV-8206 Mixed
PLY-OO8 North Poly -330A/J-331 - PSV 8-22,23 PSV
PLY-OO9 North Poly -3028 - Manual Manual
PLY-o1 O North Poly -304 Discharpe - Manual Manual
PLY-o1 1 North Poly -304 Suction - Manual Manual
PLY-01 2 North Poly :-309 TS - PSV 8-28 PSV
PLY-o1 3 North Poly -309 SS - PSV 8-27 PSV
PLY-014 North Poly :-307 - PSV 8-13 PSV
PLY-01 5 North Poly E-321 - PSV 8-6 PSV
PLY-o1 6 North Poly -321 - PSV 8-15 PSV
PLY.O1 7 North Poly =-322AlB - Manual Manual
PLY.Ol 8 North Poly F-310 - PSV 8-30 PSV
PLY-o1 9 North Poly F-302 - PSV 8-7 PSV
PLY-02O North Poly F-303 - PSV 8-8 PSV
PLY-02 1 North Poly FCV-8103 - Sample Point iample
PtY-022 North Poly Dethanizer OVH Chromatosraoh - FCV-8205 Control Valve
PLY-023 North Polv F-310 (Polv Debut OVH) - PCV-8101 Control Valve
PLY-024 North Poly F-321 DeC2 OVH - OOS 30s
PLY-025 North Poly F-320 - PSV 8-11 PSV
PLY-026 North Poly J-3308 - Manual Manual
PtY-027 North Poly F-321 LCILG - Manual Manual
PLY-028 North Poly J-331A/B Seal Pot - Seal Pot/Seal Manual
PLY-029 North Poly F-444 Ethvl Mercaptan Svstem - Mercaptan Dosing Manual
PLY-O3O North Poly F-324 - PSV 8-34 PSV
PLY-03'r North Poly F-325 - PSV 8-35 PSV
PLY-032 North Poly F-325 - LCV-S259 (Polv)Pumpout
PLY-033 North Poly F-321 DeC2 OVH - OOS los
TF-001 North TF J-852A{B - Manual Manual
TF-002 North TF IK-305/306/329 - Control Valve Vent y'ent
UFU-OO1 North UFU UFU V-6 Flare KO Drum - KO Drum Drum
VRU-OO1 North VRU E-4 FCC SW Flash Drum - Process Vent Vent
VRU-OO2 North VRU VRU/FCC Pump - Vents/Drains Vent
VRU-OO3 North VRU F-l10 East/West Pump Room - ManualVent Manual
VRU-O04 North VRU F-16 - Manual Drain Manual
VRU-OO5 North VRU F-L02 - PSV 2-13 PSV
VRU-O05 North VRU c-102 ss - Psv 2-60 PSV
VRU-OO7 North VRU c-132C TS - PSV 2-49 PSV
VRU.OOS North VRU c-09 ss - Psv 2-72 PSV
VRU-OO9 North VRU E-103 - LAL 110328 oos
VRU-O1O North VRU c-09A ss - Psv 2-66 PSV
VRU-011 North VRU C-L07lD, t07C-L,2,3,4 - Manual Vent Manual
VRU-012 North VRU c-1148 TS - PSV 2-45 PSV
VRU-013 North VRU c-11 - PSV 2-64 PSV
VRU-014 North VRU c-115A/B SS - PSV 2-89 PSV
vRU-0't5 North VRU E-105 1110535 - Manual Vent Manual
VRU-015 North VRU E-105 OVH - Samole Sample
VRU-017 North VRU E-108 - PSV 2-812-9 PSV
VRU-018 North VRU E-109 - PSV 2-10111 and PSV 2-52 PSV
VRU-019 North VRU E-106 - Manual Drain Manual
VRU-O2O North VRU c-116 - PSV 2-91 PSV
VRU-021 North VRU F-101A - PSV 2-81 PSV
VRU-022 North VRU E-107 - PSV 2-7 PSV
VRU-023 North VRU F-105A - PSV 2-84 PSV
VRU-024 North VRU FCV-110518/C-109A - Sample Samole
VRU-025 North VRU c-120A SS - PSV 2-62 PSV
VRU-026 North VRU c-06ss - PSV 1-54 PSV
VRU-027 North VRU FCC Pumpout Header - Header Header
VRU-028 North VRU c-038 - PSV 1-55 PSV
VRU-029 North VRU F-109 - Manual Drain Manual
VRU-O3O North VRU VRU Pumpout Header - Header Header
VRU-031 North VRU )-L27AlB - Seal Pot Seal Pot/Seal
VRU-032 North VRU F-101A - Drain Drain
VRU-033 North VRU J-100A - PCV11385 Control Valve
VRU.O34 North VRU J-100A - Drv Gas Seal Seal Pot/Seal
VRU-035 North VRU J-110 B/C - Seal Pot Seal Pot/Seal
VRU-036 North VRU J-t048/C - Seal Pot Seal Pot/Seal
VRU-037 North VRU F-141Vent & F-141ILG 111392 Drain - Manual Vent
VRU-038 North VRU C-L14A{B SS - Drain Drain
VRU-039 North VRU J-100 Discharee - PSV 2-18 PSV
VRU-O4O North VRU C-149A/B SS - Drain Drain
VRU.041 North VRU C-L57AlB SS - Drain Drain
VRU-042 North VRU J-10/1038 - Seal Pots Seal Pot/Seal
VRU-043 North VRU E-110 - PSV 2-86 PSV
VRU.O44 North VRU E-111 - PSV 2-87 PSV
VRU-045 North VRU F-102 - PSV 2-82 PSV
VRU-046 North VRU F-102W8 - Drain Drain
VRU-047 North VRU F-141 WB/LG 110321 - Drain Drain
VRU-048 North VRU E-111/C-156A SS/TS & 1G111335 - Drain Drain
VRU-049 North VRU J-150A/B - Casins Drains Drain
VRU-O5O North VRU J-150A/B - Seal Pots Seal Pot/Seal
VRU-051 North VRU F-103 - PSV 2-83 PSV
VRU-052 North VRU c-129 SS - PSV 2-88 PSV
VRU-053 North VRU c-131 C TS - PSV 2-48 PSV
VRU-054 North VRU F-15 FCC FG DO Drum - Manual Drain Manual
VRU-055 North VRU F-12W - Drain Drain
VRU-056 North VRU c-04 uc04 2 TS - PSV 1-23 )sv
VRU.O57 North VRU F-12 - PSV PSV
VRU-058 North VRU F-101 - PSV )SV
VRU-059 North VRU J-100 Suction - PCV101231 lontrol Valve
VRU-O60 North VRU F-110 East/West Pump Room - Pump Vent Drum )rum
VRU-061 North VRU F-101 - PSV 2-L2 PSV
VRU-062 North VRU F-109 - PSV 2-15 )sv
VRU-063 North VRU E-106 - Manual Drain Vanual
VRU-064 North VRU C-117S - Manual Drain Vlanual
VRU-065 North VRU F-105A LlLl422 - Manual Drain Vanual
VRU-066 North VRU C-120A SS - Manual Drain Vlanual
VRU-067 North VRU t-729 - PSV 2-50 )SV
VRU-068 North VRU Nitrosen Purge - Manual )umpout
VRU-069 North VRU C-113 SS - Manual Drain Vlanual
VRU-O7O North VRU C-109A SS - Manual Drain Vlanual
VRU-071 North VRU F-105A/F-105W - Manual Drain Vtanual
VRU-072 North VRU E-105 - Manual Drain Vlanual
VRU-073 North VRU C-LlAlC-lt4B SS - Manual Drain Vlanual
VRU-074 North VRU C-129 SS/TS - Manual Drain Vlanual
VRU-075 North VRU C-108A SS/C-1088 SS - Manual Drain Vlanual
VRU-076 North VRU F-103W - Manual Drain Vlanual
VRU-077 North VRU C-105-3/C-104 A/C-105-1 T/C-105-3 - Manual )umoout
VRU-078 North VRU C-131C SS - Manual Drain Vlanual
VRU-079 North VRU C-131B SS - Manual Drain Vlanual
VRU-O8O North VRU C-101A SS - Manual Drain Vanual
VRU-081 North VRU C-102 SS - Manual Drain Manual
VRU-082 North VRU C-1018 SS - Manual Drain Manual
VRU-083 North VRU F-102W - Manual Drain Manual
VRU-084 North VRU C-!03 2l L05-21 tO5-31 1044 - Manual Drain Manual
VRU-085 North VRU C-132B SS/C-132C SS/E102 - Manual Drain Manual
Solt Loke City Refinery Flore Connection
Table 2: South Flare Connections
BSU-OO1 South Bensat P-5038 - Plan 52 Seal Seal Pot/Seal
BSU-OO2 South Bensat BSU Stab BTM - Samole Sample
BSU-003 South Bensat D-509 H2 - Sample iample
BSU-O04 South Bensat BSU C-501 - PSV 5-09 PSV
BSU-005 South Bensat BSU E-509 TS - PSV 5-11 PSV
BSU-O06 South Bensat BSU E-514 TS - PSV 5-02 PSV
BSU-007 South Bensat BSU C-s02 - PSV 5-01 PSV
BSU-O08 South Bensat BSU D.508 - PSV 5-08 PSV
BSU-O09 South Bensat P-506A - Plan 52 Seal Seal Pot/Seal
BSU-010 South Bensat P-5068 - Plan 52 Seal Seal Pot/Seal
BSU-011 South Bensat P-507A - Plan 52 Seal Seal Pot/Seal
BSU-012 South Bensat P-5078 - Plan 52 Seal Seal Pot/Seal
BSU-013 South Bensat BSU Emergency Depressuring - Pressure Valve Emergency
BSU-014 South Bensat P-502A - Plan 52 Seal ieal Pot/Seal
BSU-01 5 South Bensat BSU D-504A - PSV 5-05 PSV
BSU-015 South Bensat BSU D-5048 - PSV 5-06 PSV
BSU-0,I7 South Bensat BSU D-507 - PSV 5-07 PSV
BSU-01 8 South Bensat BSU D-511 - PSV 5.13 PSV
BSU-01 9 South Bensat BSU E-504 SS - PSV 5-15 PSV
BSU-020 South Bensat BSU H2 DDU - PSV 5-04 PSV
BSU-021 South Bensat BSU R-501 - PSV 5-19 PSV
BSU-022 South Bensat D-513 - Close Drain Receiver Drain
BSU-023 South Bensat Nitrogen Purge Rotometer - PCV250162 )weep
BSU-024 South Bensat P-501A - Plan 52 Seal Seal Pot/Seal
BSU-025 South Bensat P-5018 - Plan 52 Seal ieal Pot/Seal
BSU-026 South Bensat P-5028 - Plan 52 Seal ieal Pot/Seal
BSU-027 South Bensat R-501 - Bottom Drain Drain
DDU-OO1 South DDU DDU D-527 - PSV 26-07 PSV
DDU-OO2 South DDU DDU D-627 - Bridle Vent y'ent
DDU-OO3 South DDU E-67OTS - DDU RD-204 Rupture Disc
DDU-OO4 South DDU DDU C-612 - PSV 26-20 PSV
DDU-OO5 South DDU DDU C-612 - Bridle Vent y'ent
DDU.OO6 South DDU DDU P-509A/B - Plan 52 ieal Pot/Seal
DDU-OO7 South DDU DDU RD-26-202 - E-657 TS Ruoture Disc
DDU.OO8 South DDU DDU K-686 - PSV 26-13 )SV
DDU.OO9 South DDU DDU K-685 - PSV 25-12 )SV
DDU-O1O South DDU DDU K-685 - PSV 26-26 )sv
DDU-011 South DDU DDU K-686 - PSV 26-14 )SV
DDU-012 South DDU DDU D-631 - PSV 26-11 )sv
DDU-013 South DDU DDU D-630 - PSV 26.08 )SV
DDU-014 South DDU DDU D-528 -PSV26-24 )sv
DDU.O15 South DDU DDU D-624 - PSV 26-05 )SV
DDU-016 South DDU DDU K-586 & K-685A - Packine Vents y'ent
DDU-017 South DDU DDU K-686 & K-586A - Casins Vent y'ent
DDU-018 South DDU DDU D-633 - Bridle ManualVents Vent
DDU-019 South DDU DDU K-686 - 1st Stase Depressure-628 Vent Vent
DDU.O2O South DDU DDU D-633, K-687 - Drain & Vent Vent
DDU-021 South DDU DDU Startup/Shutdown Normally Routed to Fuel Gas -
Pressure Valve Control Valve
DDU-022 South DDU DDU D-633 Normally Routed to F-12 - Pressure Valve Control Valve
DDU-023 South DDU DDU D-632 - Manual Vent Manual
DDU-024 South DDU DDU E-660 - Manual Vent Manual
DDU-025 South DDU DDU C-611 - PSV 26-15 PSV
DDU-026 South DDU DDU P-609 - Seal Flush Seal Pot/Seal
DDU-027 South DDU DDU P-60716074 - Seal Flush Seal Pot/Seal
DDU.O28 South DDU DDU E-658 SS - PSV 26-60 PSV
DDU-029 South DDU DDU P-601A - Seal Flush Seal Pot/Seal
DDU-O3O South DDU DDU R-604 - Sample Station Sample
DDU-031 South DDU DDU D-635 - PSV 26-34 PSV
DDU-032 South DDU DDU D-522 - Automatic Deoressurins Valves Emersencv
DDU-033 South DDU Natural Gas Flare Gas Purge - Sweep >weep
DDU-034 South DDU DDU D-623 - PSV 26.04 PSV
DDU.035 South DDU DDU D-521 - PSV 25-03 PSV
DDU-036 South DDU DDU D-625, D-623. C-610 - Manual Bridle Vents Vent
DDU-037 South DDU DDU D-620 Blanket Gas (N2) - N2 Purge N2 Puree
DDU-038 South DDU DDU D.620 - PSV 26-01 PSV
DDU.O39 South DDU DDU P-612A - Manual Blowdown Manual
DDU-O4O South DDU DDU P-618 - Manual Blowdown Manual
DDU-041 South DDU DDU D-627 - PSV 26-07 PSV
DDU-042 South DDU DDU D-627 - Bridle Vent Bridle Vent
DDU-043 South DDU DDU C-216 - PSV 26-20 PSV
DDU-044 South DDU DDU C-612 - Bridle Vent Bridle Vent
DDU-045 South DDU DDU K-685A - Manual and Packine/Casins Vent Manual
DDU.046 South DDU DDU K-686A - PSV 26-49 PSV
DDU-047 South DDU DDU D-644 -PSV 26-47 PSV
DDU-048 South DDU DDU D-543 - PSV 26-46 PSV
DDU-049 South DDU DDU K-686A - PSV 26-48 PSV
N2C-001 South N2C E-L}gAlBlClD - Manual Blowdown Manual
N2C-002 South N2C N2C V-108/V-tL4/V-t09 - Manual Pumpout Manual
N2C-003 South N2C N2C H-101 Coils - Manual Pumpout Manual
N2C-004 South N2C Fuel Gas Purge Rotometer - Sweep >weep
N2C-005 South N2C N2C V-105 - PSV 9-6 PSV
N2C-006 South N2C N2C V-120 - PSV 9-40 PSV
N2C-007 South N2C N2C V-112 - PSV 9-38 PSV
N2C-008 South N2C N2C V-102 - PSV 9-3 PSV
N2C-009 South N2C N2C V-102 - PSV 9-4 PSV
N2C-010 South N2C N2C V-102 - PSV 9-5 PSV
N2C-011 South N2C N2C V-102 - PSV 9-56 PSV
N2C-012 South N2C N2C V-102 - PSV 9-58 PSV
N2C-013 South N2C N2C E-108 - PSV 9-49 PSV
N2C-014 South N2C N2C E-106A SS - PSV 9-56 PSV
N2C-015 South N2C N2C V-112, E-117, K-100 - Manual Blowdown Manual
N2C-016 South N2C N2C P-119A/B, V-113A - Manual Blowdown Manual
N2C-017 South N2C N2C V-113A - PSV 9-51 PSV
N2C-018 South N2C N2C E-120 SS - PSV 9-53 PSV
N2C-019 South N2C N2C V-106 - PSV 9-1 PSV
N2C-020 South N2C N2C V-101 - PSV 9-2 PSV
N2C-021 South N2C N2C V-123 - PSV 9-74 PSV
N2C-022 South N2C N2C F-65 -PSV tL-27 PSV
N2C-023 South N2C N2C F-15 . PSV 11.3 PSV
N2C-024 South N2C N2C V-108 - PSV 9-36 PSV
N2C-02s South N2C N2C E-115A/B - PSV 9-64 PSV
N2C-026 South N2C N2C F-11 - PSV 11-23 PSV
N2C-027 South N2C N2C V-116 - PSV 9-33 PSV
N2C-028 South N2C N2C V-122 - PSV 9-73 PSV
N2C-029 South N2C N2C V-121 - PSV 9-69 PSV
N2C-030 South N2C N2C E-119SS - PSV 9-60 PSV
N2C-031 South N2C N2C V-115 - PSV 9-37 PSV
N2C-032 South N2C N2C E-1058 SS - PSV 9-51 PSV
N2C-033 South N2C N2C E-107A SS - PSV 9-75 PSV
N2C-034 South N2C N2C V-106 - Manual Blowdown Manual
N2C-035 South N2C N2C V-PCV 1119 - Manual Blowdown Manual
N2C-036 South N2C N2C C-12 - PSV 11-31 PSV
N2C-037 South N2C N2C V-917 - Excess FG Vent
UFU.OO2 South UFU UFU P-509A/B - Suction Pipe Drain Drain
UFU-OO3 South UFU UFU C-15 TS - Manual Pumpout Manual
UFU.OO4 South UFU UFU C-10 SS - Manual Pumoout Manual
UFU-OO5 South UFU UFU C-15 SS - Manual Pumpout Manual
UFU-006 South UFU UFU E-5 - Manual Pumoout Manual
UFU-OO7 South UFU UFU J-8 - Manual Pumpout Manual
UFU.OOS South UFU UFU J-15A - Manual Pumpout Manual
UFU-OO9 South UFU UFU J-14CID - Manual Pumpout Manual
UFU-O1O South UFU UFU J-12AIB - Manual Pumpout Manual
UFU-011 South UFU UFU P-2AIB - Manual Pumpout Manual
UFU-012 South UFU UFU i-10A/B - Manual Pumpout Manual
UFU.O13 South UFU UFU C-8 TS - Manual Pumpout Manual
UFU.O14 South UFU UFU E-75 SS - Manual Pumoout Manual
UFU-0,I5 South UFU UFU C-16 SS - Manual Pumpout Manual
UFU-015 South UFU UFU C-8. PSV 11.4 PSV
UFU-O'I7 South UFU UFU E-6 - PSV 11-28 PSV
UFU-018 South UFU UFU E-5 - PSV 11-11 PSV
UFU-019 South UFU UFU E.5. PSV 11.10 PSV
UFU-O2O South UFU UFU C-15 - PSV 11.18 PSV
UFU-021 South UFU PCV020306 F-4 PREFRAC OVH - Pressure Valve Control Valve
UFU-022 South UFU F-5 UFU FD DRUM VENT- Vent Vent
UFU-023 South UFU UFU F-5. PSV 11-8 PSV
UFU-024 South UFU UFU F-3. PSV 11-7 PSV
UFU-025 South UFU UFU V-15 - PSV 11-16 PSV
UFU-026 South UFU UFU F-10 - PSV 11-17 PSV
UFU-027 South UFU UFU F-13 - PSV 11-13 )SV
UFU.O28 South UFU UFU C-78 - Manual Pumoout Vlanual
UFU-029 South UFU UFU C-13 SS, C-12 SS - Manual Pumpout Vanual
UFU-O30 South UFU UFU C-7A - Manual Pumoout Vlanual
UFU-03'I South UFU UFU l-14C - Seal Pot ieal Pot/Seal
UFU-032 South UFU UFU J-14D - Seal Pot >eal Pot/Seal
UFU-033 South UFU UFU V-51 - Manual Pumoout Manual
UFU-034 South UFU UFU E-51A TS/SS - Manual Pumpout Manual
UFU.O35 South UFU UFU R-51 - Manual Pumoout Manual
UFU-036 South UFU UFU R-52 - Manual Pumpout Manual
UFU-037 South UFU UFU E-51C SS - Manual Pumpout Manual
UFU.038 South UFU UFU E-228 - Manual Pumpout Manual
UFU-039 South UFU UFU E-80 - Manual Pumpout Manual
UFU-O4O South UFU UFU E-77 - Manual Pumoout Manual
UFU-041 South UFU UFU P-51 - Manual Pumpout Manual
UFU.O42 South UFU UFU V-4 - Manual Pumpout Manual
UFU-043 South UFU UFU V-8 BTM/V-3W - Manual Pumpout Manual
UFU-044 South UFU UFU E-208lV-52 - Manual Pumpout Manual
UFU-045 South UFU UFU P-72A/B - Manual Pumpout Manual
UFU-046 South UFU UFU P-S2AIB - Manual Pumpout Manual
UFU-047 South UFU UFU E.77 - PSV 10.46 PSV
UFU-048 South UFU URUF V-52 . PSV 10-48 PSV
UFU-049 South UFU UFU F-1 Convec - PSV 10-5 PSV
UFU-O5O South UFU UFU V-15 - PSV 1O-9 PSV
UFU-051 South UFU UFU V-l - Manual Pumpout Manual
UFU-052 South UFU UFU V-8 Overhead - ManualVent Manual
UFU-053 South UFU UFU V-12 - Manual Blowdown Manual
UFU-054 South UFU UFU V-11 - Manual Blowdown Manual
UFU.O55 South UFU UFU K-IA/B - Manual Blowdown Manual
UFU-056 South UFU UFU V-8 - Purge Gas (FG) Rotometer Sweep
UFU-057 South UFU UFU V-8 - PSV 10-14 PSV
UFU-058 South UFU UFU V-4 - PSV 10-15 PSV
UFU-059 South UFU UFU P-IA/B - Manual Pumoout Manual
UFU.060 South UFU UFU P-73 - Manual Pumpout Manual
UFU-061 South UFU UFU P-38 - Manual Pumpout Manual
UFU-062 South UFU UFU V-2 - PSV 10-13 PSV
UFU-063 South UFU llc079 - E-19 TS Pumpout Pumpout
UFU-064 South UFU UFU TCV030110 - E-19 TS Pumpout Manual
UFU-065 South UFU UFU Reeen Header - HCV032062 Control Valve
UFU-056 South UFU UFU Uooer Blowdown Header - Header Header
UFU.067 South UFU UFU E-2 - PSV 1O-4 PSV
UFU.O58 South UFU UFU V-80 - PSV 10-71 PSV
UFU-069 South UFU UFU R-51 - PSV 10-72 PSV
UFU-O7O South UFU UFU R-52 - PSV 10-73 PSV
UFU-071 South UFU UFU V-72 - PSV 10-38 PSV
UFU-072 South UFU UFU V-71 - PSV 10-37 PSV
UFU-073 South UFU UFU V-8 - PSV 1O-31 PSV
UFU-074 South UFU UFU RX.4 - PSV 10-22 PSV
UFU-075 South UFU UFU RX-3 - PSV 10-21 PSV
UFU-076 South UFU UFU RX.2 - PSV 10-20 PSV
UFU-077 South UFU UFU RX-1 - PSV 10-19 PSV
UFU-078 South UFU UFU RX.5. PSV 10.23 PSV
UFU-079 South UFU UFU C-13 - PSV 11-30 PSV
UFU-O8O South UFU UFU F-14 - PSV 11-12 PSV
Soll Loke Clty Rcllnery Flore Connecllon Lltl
T.bl. 3: SRU Fl.n Conn ciloG .nd
sRU.00l SRU SRU
:ormer Flare Connection (lsolaled
)ut avarlable lor luture use))OS Connfttion onnecton is out of 5etoice. lncluded for referen(e
sRU 002 SRU SRU ;Ru Flare Heads iHG and PSV Sample Tubing ;ample is required for 5afe and reliable process operation Minimal llare
:ontnbulon a5 required tor peEof,nel and proces! safety
sRU.003 SRU SRU 201 )sv,201 )qV fdr.m.rdpnd u(.6nlv N6 minimirairon
sRU 004 SRU SRU .207 )sv,638 )SV for emerqenq use only No minimizaton
sRU.005 SRU SRU .202 ,sv 202 )qV f6. .m.rd.nd u<e 6nlv No minimi2anon
sRU 006 SRU 5RU 201 ,lV f6r pmaroend uso onlv No minimizarron
sRU-007 SRU SRU 207 vlanual Vent to the flare header
sRU 008 SRU SRU )o\)sv 205 ,SV for ememen& use onlv No mrnimizatron
(RIl-OOg sRU SRI])05 )\v-274 ,SV for emeroeno u3e onlv. No minimizaton
sRU-01 0 SRU SRU 2M ,sv-226 ,5V lor emeroeno use onlv No mrnimrzalon
sRU-01 1 SRU SRU 201 ,5V.1 15 )5V for emeroeno u5e onlv. No minrmrzanon
sRU-012 SRU SRU 261 'sv- 101 PSV for emeroeno use onlv No minimrzauon
sRU,01 l SRU SRU -206 Regenerator Reflux Drum 'cv -2758 Emergency use only No minimization rs porsible ai there ia no nomal, non.
Drocess uDset qas flare header (ontnbution.
sRU.014 SRU SRU 2ll Sour Water Stripper ,cv-0258 Emergenay use onV No minimization is possible as there rJ no normal, non
oro(es9 uptet qa5 flare header contnbution
sRU 01 5 SRU SRU 231 Sour Water StnpDer ,5V-102 PSV for €merqenry use onlv. No minrmrzalron
sRU 016 SRU SRU ,weet Gas ,cv 2308 Ehergency use only No minrmrzation is possible as there is no nomal, non-
oro(ess uDset Qas flare header (ontribution.
sRU,01 7 SRU 5RU 231 ,sv 023 PSV for emeroenry u5e onlv No minimization
sRU 018 SRU SRU ,Jatural Gas latural Gas Swep ,wep oas has been mrnrmrzed to the enent practrcable
sRU -O19 SRU SRU GU 'Gu Header Conn*tion leader (onnelion - flare (oninbulions mrnrmized by indiudual TGU
sRU 020 SRU SRU ;ample is required for safe and reliable process operation. Minimal flare
:ontribution as required for peEonnel and process safeiy
sRU -02 1 SRU SRU 202 'SV f6r.m.rd.nd u<p 6nlv No mrhihrrrron
IGU -OO']SRU TGU .235 ,sv 0l ,SV for.h.rd.nd u<e onlv No minimrzation
TGU.OO2 SRU IGU "212 tv -2498 .mergency use only. No mrnamazation rs possible as there rs no normal, non
rrd.F<< (.<Fr da( flerF hFidEr.oniribuiion
TGU.OO3 SRU TGU 2r 3 lanual Vent {ormally no flow Used only for maintenan(e as required to safely vent gaset
o lhe flare header
TGU.OO4 SRU T6U GTU Flare Header {itrooen Sweo ,wep qas has bs mrnrmr2ed to tl.e erlent pra(li(able
TGU.OOS SRU TGU 2v ,sv-08 rsv f6r.m..oFn.v u(.6nlv N6 minimiren6n
TGU,OOS SRU TGU 243NA 'ump lormally no flow. Ured only for maintenance as required to safely vent gases
Son toke City R.llncry Florc Conn.cflon tld
no llow. Used only for maintsance as equircd to tafely vent gas6
no flow used only for maintenan<e as cquiEd to rafely vent gasea
no flow used only for maintenan(e as required to iafely vent gas6
Appendix C
Flore Drowings
Flore Detoil Drowings
E.r hdnt 61tr bFnd
-
hE v.il&
-
lliryFudO
J?
tuIG..
-
lltof.n
I
Fdtro uE mwK
I I *-ffi.*
Fbnhda
tun hjna Gld ba.id
dmfdtu
Ui ONAILEOFURI UWNG
I t*.;I:;.- t,
F.n hxlq k blrd
-
, tEl or
+
UI
..Mttu
l[htil
rm qtt uE cfr [itttv
TAILEDMTE OUWS
I I E!-E,m I
Flore Network Drowings
iloilh FhnA
FrDm North
Flarr B
Xorth Flrn B
ToV€
Soulh FI.r!
To Norh
Fl.ra A
+
S rhr t{-a<a}
,L'r! tu.lrd lt../a
Soutfi Flrl!
+hhffi)
----> Fhe PmWffi
+hp
SRU Flare 8-271
+ MarnF!.GH..d.i.)
+ Fl.nn! fr@.. und H..d.r.
+ sEa
Flore Tip Drowlngs
The Salt Lake City Refinery utilizes John Zink flare tips as described in Section 3.0 of this FMP.
The flare tip drawings are subject to confidentiality agreements between Tesoro and the equipment
manufacturer. ln accordance with guidance received from the U.S. Environmental Protection Agency
pertaining to confidential business information in FMPs, the drawings are not submitted with this FMP.
The drawings are on flle at the refinery.
Appendix D
NSPS Jo Cross Reference Toble
@.103r(.)(2)
h..crn6r d*Sd dkh.q6 to rffErd i.u l6m tk pecr unb..fttury Slr.nr.nd tud Fr rF&h. (.n h hhimld tu tun minim[xion
$srm6tnusr (.r. mhlmum) contldr6. tm. in Fqr.ph! (.X2Xi) Sdgh fu) ot frBrdbn. tu.i!6.h6t hu:tpd..lor..r&.1. in cmt of cdB
tinim lz.tion A$.Em.ni ?o.2.3ninimirtnd.h.m.W(, d. r[rm.ni dih ju{ii(.tion3, th.r lld &.non cdld not b &hidd l.d uFn rk.raitm..! $.h Mn or orr.tor of .n
rmp! impbmoulsd.ry ddd DsuEth.i c.nrcr r.Fn.Uy &@mpE.rof rht d.E-
@.101.1.)(l)1i
\d.*np!o. ot.rth.trerd n.r..o.Lrn'.g rh. rnrofr.ron f p.r.gr.pht (.xr)n) rhrdgh lvtr, or rhE qnon
) A9.n.,.1 d.'(npto6 ol rh.11.... in(luding rh.,nlom.toi,. p.r4..ph' (.XlXi)(A) th@9h (6) ol rh6 '*to.A)Sdher
^
g.grilnd 0.r. o..la.ld tnclldhg heqhl)
B) n. ryroi !$Gr syn.m (.9.,.ri *..o, pr.eeur.,.on .tr{d)
c) Mdhertr,3 rfrpl. orcompl.x fl.r. tp (..9., nrg.d. !.qu.nn.l)
0) Wh€lhn rh. ll.r. B p.n oi. c.3crd.d,la.. ryei.m (.nd il eo wh.th.rthe fl.r.6 pnmrry or r.(ond.ry)
E) whetherth. fl.c 5.e.t.i. b.ckup to anoth.ri...
nwh.lherth.i.r.8...m..g.iryll.r.or. non..m..g.n.yll.c
G) wh.rhd lh. fl.a 6 qurpFd w(h. fl...9.r...@q !ytl.m.
lO (TrU. I 1)
@.1ot.{.xlxii)
)6.npM.nd empLp,{6r flddqr.d AM9 thrnt E6.6m d tk ldM.g.mp.rrol ihtue Eerip(Oa rnr[ld m.Nt&E .lor..l.d
ffdh tip di.md( np drmg)j khtd sS drum(.) d pl(r) (i6dudn9 dim66 ed &€n..Fb):tun hd(r)..d ebld(r);.338t rytr6:lO[.bE!-i). ].1.
@ 103.1.)(llltrD
r.r. d6'9. p.r.m.r..t, rncrudr.g rh. mumlm,.nr 9.3 rrd..r.;mrh6om ffiP 9.r n@..1.;m'.rm!m Frye 9.r rril r.t. (r.ny)tmurduft 3uPPr.m.nt.r9.r
il..i.r nuimuB pilot q.i flnr.iq.nd, il rh. ll.r. r il..m .tqrrd- mhhum tobl il.!fr ..r.l.r. D6r9^ P...o.l.ri I 0 (T.bl. l.l)
S.103.{.Xr(il)
)6.npM ..d impl. p,oc63 fltrdi{r.o rhmng.ll9.3 hh6 (iftluding fl.E. FE. (n.Pp[..b|.). sEp, {ppbd.nt.l.nd pibr 9.r} thd.r..$fir.ld dh ln
l.n. forpE., ryrp ruppl.6.nt.l.d pilotSr. idolty S.9F ol9.r usd. Ocign.t.Si.h lln...reG.mpt Ircm rulfui HE orf,{monildng.d why (..9.,
rtur.lgt, inh.mdy ld rutui pilot 9.r. O6i9n.hdi.h linc.d monirod..d d.ntt on th pm6t nd dhgruh th.ld.tion.nd VF ol o.h monbr.
3.0(T.bl.3-l).12,
e 103.(.)(3Xv)
or...h flil..t.. H25. !!llu. <onr.nt preteue orw.r., r!.1 monno.,d..tfi.d 'n p.r.gr.ph (.)(3)tv) ol thE 3.dDn. prd,d!. d.r.ild d6(nPno. o, rh.
@.1oil.X!Xvi)
0 6.lgry IG, cd.ry r[B .d r[G +pr w$. rh 9r Rry irbn k9n4 3ud.d oF.td 6 opur.n Ifi kpt llid r6sftq
lm rr.dP,.httu dn.tudo:
A) Bcddb ol tu*.t..!.1iftbdinglhW.nng,.n$ btuli+id H.
l) b@.tbn ot th. mo.bdhg opiM.hd (fld.d altur monitonE o. @eE.dw.rd i..lli+d hd mdibh.q).
v.rdSd.d hndry OprM lq [D.qdq,
rdry..d FGR F.B
o. traEi.qurPPd wlh. ll.r.9.! r.(@.ry sytr.m
A)A d.(ipiion ol thillrr! 9.3 r!<ov.ry ry(.m, indudiig numbs o{ compr.soE.nd (.p.(ty ol...h compresor.
B) Adscdprio. oI th. mohiloring p...m.1.8 u'.d to qu.nrtihc rh@nr ofn.,.9.s rftderd
C) Fo.efr.nrwnh n,g.d.ompE roB,6. mdrmuB sm. p.nod.4rd ro *9n 98 rftd.ry Sth th. r.(ond.ry.onpr6ro(r, th. montronng p...m.l.r.nd
trGdu.B u3d lo n'nrnr. lh. dur.ton o,,.l..rs dunno (onor.$or (.orna ard. tuenfr(.non lo,tr th.6urmom t6. mnd c.nnor hl!frkr.du(d.
)0(Irb].l l),3r.
O.103.(.Xa)
6a.b.tb ol6. &liilhb tu i.E tubrlh. iil b rhtumunb&tm'd.ftdndo6dn9 h midhr.rs &tdm6l'nFrq.ph (.X2)
h6.d6. Bdimfln 6 rct trt&Fhq6 kdpqe3 k(1.- F i.td.d trd rhtu6'rEBal) pd& 66.F k M.n ramuy
nm.ryB.r.linc.ndAl.m.tn.8u.lin. Fl*R.c
hr tu me$m6r pLn ncb&
i) A rim.ry bElin. f,@ nb th.r*ll b Bd s tk &l.uh b.rllim ld.ll.dituhr s.qr thor rEifrolt d.nm.d in fr. pl..;
ii) A &.nprion ol6<h rfi.lcondhion forSi.h.n.lt.m.b b.*lin. b 6t.blbhd, inchdiq th 6t6.1. for..ch.h.m.t. b.r.lina th. d.it ffd for.eh
ilt.h.r. b.r.lin. .nd th. .e.4.d dunlion ol lh. .pei.l condliion. ,or ...h .lt.m.t b.r.lln.; .nd
ielofd ldS6.r.sr und., tsr4r.ph (.Xt) h@gh(7) of thi rcibn, a.ppliobh
tftd!6 lo mr..m,!. or.lmr..t. dBch.rgs to lh. ll.r.dun.g lh. ph^nd.trnup..d lhuld@n ol lh. r.n..ry p.e.r! un(!..d.n<il|.ry 4rpm.nl lh.l.€
o.6.dd ro th..l!..id flr.., lq.h.rw(h. tchdul. lo, lh. p.o6pl rmpl.D..t.to. ol.ny p.cdor.t !h.l c.nrct rc46.bt & 'mpl.m.nld.r of th. drl.ol
h. iubmtrro. ol ih. fhc 6.n.9.6..1 pl.n.
rtuo r.d ShuIdM Fl.r. Mr.'mr2.non PredB 5o
@.1o1.(.X6)
rddE b d.. n.nng 'n c.ec d tu.l 93 rmbl.m. (i.., r.6r tu.l 98 lor rh. rfinql.n ry .d), lryths wth . r.hd!l.ld lh. prmpt
hpl.mfibtid ol.ny prc.dc lh.t c..^otru.ro^.bly h imphnnld.r ofthcd.t.ofth..ubmbrion dfr.i.ru m.nq.m..l p1...u.l 6.r lhbl.ft. Fl.m Mi.rmi,rrld Prd.du16 6.0
tr.103r(.X7)
orfl.Es.qurpp.d sth ll.r.9.! rEd.ry ry{.mt proc.d!cr io mr^rmre lh. t.q!.ncy.nd du..no^ oldr.96 ol lh. ll.E 9.t r.cd.ry lyrl.m.nd poc.dur.3 to
rhrmtr.S.volu6.o,98fl.rddunn93u(houl.96,lq.lh.r*[h.lchdolelorth.proilpl 6pl.m.nt.nonol..yproc.dur.slh.l<.nnol(i$h.btb.
npl.m6t.d .r ol rh. d.re ot rh. tubmBroi o, $. fr. m...9.m..1 pl..GR Up!m.Pr@d!..5 0
-iilFDrP,\RTMENT oF
' Jrir por'THTENTAL QUALITY
DIVISION OF AIR OUALITY