Document:

EX-10.1

 Exhibit 10.1 

FIRST AMENDED AND RESTATED SCHEDULES 

TO FOURTH AMENDED AND RESTATED OMNIBUS AGREEMENT 

A Fourth Amended and Restated Omnibus Agreement was executed as of October 30, 2017 (the “Fourth Amended and Restated Omnibus
Agreement”), among Andeavor, on behalf of itself and the other Andeavor Entities, Tesoro Refining & Marketing Company LLC, Tesoro Companies, Inc., Tesoro Alaska Company LLC, Andeavor Logistics LP and Tesoro Logistics GP, LLC.
Capitalized terms not otherwise defined in this document shall have the terms set forth in the Fourth Amended and Restated Omnibus Agreement. 

The Parties agree that the Schedules are hereby amended and restated in their entirety as of the date hereof to be as attached hereto.
Pursuant to Section 9.12 of the Fourth Amended and Restated Omnibus Agreement, such amended and restated Schedules shall replace the prior Schedules as of the date hereof and shall be incorporated by reference into the Fourth Amended and
Restated Omnibus Agreement for all purposes. 
 [Signature Page Follows] 

 Executed as of November 8, 2017. 

 

			
	ANDEAVOR
		
	By:	 	/S/ GREGORY J. GOFF
		 	Gregory J. Goff
		 	President and Chief Executive Officer

  

			
	TESORO REFINING & MARKETING COMPANY LLC
		
	By:	 	/S/ GREGORY J. GOFF
		 	Gregory J. Goff
		 	President

  

			
	TESORO COMPANIES, INC.
		
	By:	 	/S/ GREGORY J. GOFF
		 	Gregory J. Goff
		 	President

  

			
	TESORO ALASKA COMPANY LLC
		
	By:	 	/S/ GREGORY J. GOFF
		 	Gregory J. Goff
		 	President

 Signature Page 1 of 2 to 

First Amended and Restated Schedules to Fourth Amended and Restated Omnibus Agreement 

 
			
	ANDEAVOR LOGISTICS LP
		
	By:	 	Tesoro Logistics GP, LLC,
		 	its general partner

  

			
	By:	 	/S/ STEVEN M. STERIN
		 	Steven M. Sterin
		 	President and Chief Financial Officer

  

			
	TESORO LOGISTICS GP, LLC
		
	By:	 	/S/ STEVEN M. STERIN
		 	Steven M. Sterin
		 	President and Chief Financial Officer

 Signature Page 2 of 2 to 

First Amended and Restated Schedules to Fourth Amended and Restated Omnibus Agreement 

 Schedule I 

Pending Environmental Litigation 

For Initial Contribution Agreement listed on Schedule VII: 

None. 
 For Amorco Contribution Agreement listed on
Schedule VII: 
 None. 
 For Long Beach
Contribution Agreement listed on Schedule VII: 
 The soil and groundwater on the southern central portion of the site near the 24-inch crude oil line have been impacted with hydrocarbons from a release from the line first observed in September 2011. The California Regional Water Quality Control Board issued an Investigative Order dated
September 30, 2011 and to date all requirements of the order have been met. Additional investigative or remedial activities may be required. 

For Anacortes Rail Facility Contribution Agreement listed on Schedule VII: 

None. 
 For BP Carson Tranche 1 Contribution Agreement
listed on Schedule VII: 
 The environmental indemnification provisions of the Carson Assets Indemnity Agreement dated as of December 6, 2013
(“Carson Assets Indemnity Agreement”), among the Partnership, the General Partner, Tesoro Logistics Operations LLC (the “Operating Company”) and TRMC, supersede in their entirety the environmental indemnification
provisions of Article III of the Fourth Amended and Restated Omnibus Agreement, except as otherwise expressly provided in the Carson Assets Indemnity Agreement. 

For BP Carson Tranche 2 Contribution Agreement listed on Schedule VII: 

The environmental indemnification provisions of the Carson Assets Indemnity Agreement supersede in their entirety the environmental indemnification provisions
of Article III of the Fourth Amended and Restated Omnibus Agreement, except as otherwise expressly provided in the Carson Assets Indemnity Agreement. 

For West Coast Assets Contribution Agreement listed on Schedule VII: 

None. 
 For 2015 Line 88 and Carson Tankage Contribution
Agreement listed on Schedule VII: 
 None. 

 For 2016 Alaska Assets Contribution Agreement listed on Schedule VII: 

KENAI TANKAGE: Andeavor, Tesoro Alaska, TRMC, the Partnership and the General Partner are subject to a pending consent decree
with the United States Environmental Protection Agency and the Department of Justice pursuant to which injunctive relief will be ordered with respect a number of refineries (the “2016 Environmental Consent Decree”). 

ANCHORAGE AND FAIRBANKS TERMINALS: Andeavor, Tesoro Alaska, TRMC, the Partnership and the General Partner are subject to the
pending 2016 Environmental Consent Decree pursuant to which injunctive relief will be ordered with respect a number of refineries. 
 The
indemnification obligations of the Andeavor Entities under Section 3.1(a) of the Fourth Amended and Restated Omnibus Agreement with regard to the 2016 Environmental Consent Decree are limited as provided in Schedule IX. 

For Martinez Assets Contribution Agreement listed on Schedule VII: 

Andeavor, Tesoro Alaska, TRMC, the Partnership and the General Partner are subject to the 2016 Environmental Consent Decree. 

For Assets owned by WNRL on the Closing Date of the Merger Agreement and acquired by the Partnership pursuant to the Merger Agreement by virtue of its
acquisition of WNRL thereunder: 
 The environmental indemnification provisions in Article VI of the Sponsor Equity Restructuring Agreement dated
August 13, 2017 (“SERA”) between Andeavor, Andeavor Logistics LP and Tesoro Logistics GP, LLC supersede in their entirety the environmental indemnification provisions of Article III of the Fourth Amended and Restated Omnibus
Agreement, other than Section 3.5(b), and shall be the exclusive provisions for all indemnification obligations relating to the subject matter of the indemnities so provided in Article VI of the SERA. 

For 2017 Anacortes Assets Contribution Agreement listed on Schedule VII: 

 

	 	1.	In July 2016, the US EPA and the U.S. Department of Justice announced a $425 million settlement with TRMC, including the TRMC Anacortes Refinery, in relation to violations of the Clean Air Act. The settlement (the
Consent Decree) with the U.S. Department of Justice requires that the storage tanks be added to the Refinery’s LDAR program and be monitored regularly for leaks. Some valve locations are difficult to monitor and may require relocation nearer to
grade. These locations have been identified and will be addressed when the tanks are taken out of service during inspections. Per the Consent Decree, the Refinery must install closed-purge, closed-loop, or closed-vent samplers at all storage tanks
by 2021. According to facility representatives, there are 42 tanks left to retrofit. 

	 	2.	The recent Consent Decree with the U.S. Department of Justice has required that the Refinery perform a BWON (Benzene Waste Operations National Emission Standards for Hazardous Air Pollutants) Audit to recalculate the
Total Annual Benzene amount and the total benzene emitted under the 2 Mg per year exemption. During this process, the Refinery determined that it exceeded the 2 Mg exemption and reported the exceedance to NWCAA in the 2016 Annual Compliance
Certification air operating permit. 

 Schedule II 

Environmental Matters 
 For Initial
Contribution Agreement set forth on Schedule VII: 
 1. Anchorage #1 Terminal soil and groundwater have been impacted by gasoline and diesel releases
from previously buried pipelines. The site is considered characterized and is currently undergoing removal of product from the water table, groundwater treatment, and long-term monitoring. 

2. Anchorage #2 Terminal soil and groundwater have been impacted by gasoline releases occurring prior to Andeavor’s purchase of the facility. The site is
considered characterized and is currently undergoing groundwater monitoring and treatment. Off-site groundwater investigations are scheduled for 2012. 

3. Stockton Terminal soil and groundwater have been impacted by gasoline and diesel releases from pipelines and/or product storage tanks. The site is
considered substantially characterized and is undergoing groundwater treatment and groundwater monitoring. Off-site groundwater impacts are commingled with neighboring petroleum storage terminals. 

4. Burley Terminal groundwater was impacted by gasoline releases occurring prior to Andeavor’s purchase of the facility. Groundwater impacts were
commingled with neighboring petroleum storage terminals. Hydrocarbon concentrations in groundwater samples do not exceed previously established target levels for groundwater and surface water protection. Regulatory closure is pending. 

5. Wilmington Sales Terminal soil and groundwater have been impacted by gasoline releases occurring prior to Andeavor’s purchase of the facility.
Groundwater investigation and monitoring is on-going. Andeavor is indemnified by the previous owner for Investigation and remediation obligations. 

6. Salt Lake City Terminal soil and groundwater have been impacted by gasoline and diesel releases from pipelines and/or product storage tanks occurring prior
to Andeavor’s purchase of the facility. The site is considered characterized and is currently undergoing removal of product from the water table and long-term monitoring. There are no known soil or groundwater impacts at the Northwest Crude Oil
tank farm. 
 7. The Stockton Terminal emits volatile organic compounds (VOCs) below “major source” emission criteria. In 2010, the San Joaquin
Air Quality Management District announced it is reducing its major source threshold. When the Stockton Terminal expands its operations or increases throughput, the potential to emit VOC will increase and the Stockton terminal will become subject to
regulation as a major source. This will require a Title V Air Operating Permit. In addition, the Stockton facility will be required to install an automated continuous emission monitor at a cost of approximately $75,000. 

 For Amorco Contribution Agreement set forth on Schedule VII: 

1. The soil and groundwater on the site of the Tankage, as defined in the Amorco Contribution Agreement, have been impacted by methyl tertiary butyl ether
releases from previously buried pipelines. The site is considered characterized and is currently undergoing removal of methyl tertiary butyl ether from the water table, groundwater treatment, and long-term monitoring. 

2. Any environmental violation or contamination due to SHPL, as defined in the Amorco Contribution Agreement, being underground prior to the Closing Date.

 For Long Beach Contribution Agreement listed on Schedule VII: 

1. Any environmental violation or contamination, as defined in the Long Beach Contribution Agreement, prior to the Closing Date. 

2. Any anomalies in the Pipeline System that require repair as discovered by the first internal line inspection of any portion of the Pipeline System for
which TRMC is notified in writing prior to the First Deadline Date. 
 For Anacortes Rail Facility Contribution Agreement listed on Schedule
VII: 
 None. 
 For BP Carson Tranche 1
Contribution Agreement listed on Schedule VII: 
 The environmental indemnification provisions of the Carson Assets Indemnity Agreement supersede in
their entirety the environmental indemnification provisions of Article III of the Fourth Amended and Restated Omnibus Agreement, except as otherwise expressly provided in the Carson Assets Indemnity Agreement. 

For BP Carson Tranche 2 Contribution Agreement listed on Schedule VII: 

The environmental indemnification provisions of the Carson Assets Indemnity Agreement supersede in their entirety the environmental indemnification provisions
of Article III of the Fourth Amended and Restated Omnibus Agreement, except as otherwise expressly provided in the Carson Assets Indemnity Agreement. 

 For West Coast Assets Contribution Agreement listed on Schedule VII: 

1.  Nikiski Terminal. Subsurface soil and groundwater has not been assessed at this facility. There have been no historic releases that have
prompted a soil and groundwater investigations. The area within the tank containment berms was lined with low-permeability soils in the early 1990s. The loading rack, fuel filters and piping manifolds are
above concrete secondary containment. 
 2.  Anacortes Light Ends Rail Facility and planned diesel truck rack areas. Subsurface soil and
groundwater has not been assessed at this area of the Anacortes refinery. There have been no historic releases that have prompted a soil and groundwater investigation. 

3.  Anacortes Storage Facility. Historic tank overtopping events and tank bottom corrosion releases have impacted soil and groundwater in
the shore tank area of the Anacortes refinery. Groundwater near the shore tanks is monitored for natural attenuation. Groundwater between the tanks and the nearby shoreline has not been characterized, however the hydrocarbon concentrations in this
area is not expected to be a threat to human health or the environment. 
 4.  Martinez Refinery LPG Loading Area. Past waste disposal
and hydrocarbon releases have impacted areas surrounding the Martinez Refinery LPG loading rack, pad and tanks. Areas north and northeast of the rack were used for past waste disposal. There are documented intra-refinery pipeline releases in the
north and western boundaries of the LPG rack concrete pad. The refinery plans to excavate and cap the nearby waste disposal area in 2017. The pipeline releases are being remediated as part of the overall Martinez refinery cleanup. Soil and
groundwater directly beneath the loading rack, propane tanks and truck pad have not been sampled. 
 5.  Tesoro Alaska Pipeline. 

 

	 	•	 	The pump station for the Tesoro Alaska Pipeline is adjacent to the Kenai Refinery Lower Tank Farm. Multiple historic tank and buried pipeline releases have impacted soil and groundwater in the area; however there are no
documented releases from the pipeline pump station. The soil and groundwater surrounding the pump station is considered characterized and undergoing groundwater monitoring and treatment. 

 

	 	•	 	A pipeline release in 2001 resulted in soil, groundwater and surface water impacts in an undeveloped area of the Kenai Peninsula. The quantity of the release is not known. Soil surrounding the release was excavated and
stockpiled at the Kenai Refinery while groundwater and surface water were remediated on-site. The Alaska Department of Environmental Conservation issued a No Further Action letter for this cleanup effort in
2008. There are no other known release sites on the pipeline between the Kenai Refinery and Anchorage. 

	 	•	 	Historic spills and releases have impacted the Anchorage #1 terminal, including past releases from the Tesoro Alaska Pipeline receiving station. Groundwater remediation monitoring is ongoing across the Anchorage #1
terminal. In addition, a soil vapor venting system is being installed to address a flame suppressant compound detected in soils near the receiving station control room. 

For 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII: 

None 
 For 2016 Alaska Assets Contribution Agreement listed
on Schedule VII: 
 KENAI TANKAGE: 

Area of significant groundwater and soil impacts: (1) lower tank farm groundwater impact source area including 1988 jet fuel release and
unknown light products release in area of Tank 63, (2) process unit historic releases from oily water sewer system including releases from failed grout in subsurface sewer hubs, (3) groundwater issues generally 35 to 40 feet below ground
surface and groundwater impacts in three water-bearing zones below refinery and off-site and (4) possible contributor to refinery-wide groundwater impacts. 

ANCHORAGE AND FAIRBANKS TERMINALS: 

Pursuant to the Contribution, Conveyance and Assumption Agreement effective as of July 1, 2016 (the “Alaska Assets Contribution
Agreement”), among Tesoro Logistics LP, a Delaware limited partnership (the “Partnership”), Tesoro Logistics GP, LLC, a Delaware limited liability company and the general partner of the Partnership (the “General
Partner”), Tesoro Logistics Operations LLC, a Delaware limited liability company (the “Operating Company”), Tesoro Alaska Company LLC, a Delaware limited liability company (“TAC”) and Tesoro Corporation, a
Delaware corporation (“Tesoro”), TAC contributed 100% of the limited liability company interests (the “TAT Interests”) in Tesoro Alaska Terminals LLC, a Delaware limited liability company (“TAT”),
to the General Partner, the General Partner contributed 100% of the TAT Interests to the Partnership, and the Partnership contributed 100% of the TAT Interests to the Operating Company, all on the terms and conditions set forth in that contribution
agreement. 
 Prior to the date of the Alaska Assets Contribution Agreement, TAT acquired certain assets defined as the “Anchorage and
Fairbanks Terminals” in the Alaska Assets Contribution Agreement from Flint Hills Resources Alaska, LLC pursuant to an Asset Purchase Agreement, dated November 20, 2015 (the “Flint Hills APA”), by and between Flint Hills
Resources Alaska, LLC and TAC. As described in the Flint Hills APA, the following liabilities existed at the Anchorage and Fairbanks Terminals prior to the closing of the transactions contemplated under the Flint Hills APA: 

Anchorage Terminal: 
  

	 	1.	Deviations reported under Anchorage Air Permit No. AQ0235TVP03, Issue Date: April 2, 2014, Effective Date: May 2, 2014. 

	 	•	 	Flint Hills Resources Alaska, LLC did not submit a report as required under Condition 68 based upon defects listed in Condition 6.3 discovered during the out of service inspection conducted on T-4216 during July 2014. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated January 29, 2015. 

 

	 	•	 	Flint Hills Resources Alaska, LLC did not report all emissions or operations that exceed or deviate from the requirements of its permit within 30 days of the end of the month in which the excess emission or deviation
occurred. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated January 29, 2015. 

  

	 	•	 	Flint Hills Resources Alaska, LLC did not perform preventative maintenance in accordance with 40 CFR Subpart ZZZZ within 365 days of effective date on EU IDs 7, 8, and 9. The maintenance was performed 2 days after that
date. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated July 30, 2014. 

  

	 	•	 	Flint Hills Resources Alaska, LLC did not report all emissions or operations that exceed or deviate from the requirements of this permit within 30 days of the end of the month in which the excess emissions or deviation
occurred. The deviation report covering this incident is set out in the Flint Hills Resources Alaska, LLC deviation report dated January 29, 2015. 

  

	 	•	 	On April 10, 2014. ADEC issued Flint Hills Resources Alaska, LLC a letter of Acceptance of the Anchorage Facility Compliance Certificate, and identified 4 deviations from the air permit. 

 

	 	2.	In a letter dated July 22, 2015, the ADEC indicated that the Anchorage Terminal Oil Discharge Prevention and Contingency Plan needed the additional information specified in the July 22, 2015 letter to be
submitted in order for the plan renewal to be approved. On September 2, 2015, the facility submitted the requested information and is awaiting ADEC approval. 

 

	 	3.	On May 15, 2015 Flint Hills Resources Alaska, LLC received a notice of failure to pay Air Quality fees relating to Air Permit No. AQ0235TVP03. Those fees were paid on June 2, 2015. 

 

	 	4.	In a letter dated October 1, 2015, ADEC approved the facility’s request for a waiver of secondary containment, subject to the terms of the letter, until March 31, 2016. 

 

	 	5.	On July 24, 2014 ADEC issued a letter to Flint Hills Resources Alaska, LLC advising that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the July 22, 2014 Anchorage Facility Jet
Fuel release. 

  

	 	6.	On April 21, 2014, ADEC issued a letter to Flint Hills Resources Alaska, LLC advising it that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the April 20, 2014 gasoline release.

 Fairbanks Terminal: 
  

	 	(i)	In a letter dated May 29, 2015, ADEC detailed items that needed correction related to ADEC’s May 19, 2015 inspection of the terminal and its Oil Discharge Prevention and Contingency Plan. The facility has
submitted a response to ADEC and is working with the agency to correct the identified items. 

  

	 	(ii)	On April 24, 2014 ADEC advised Flint Hills Resources Alaska, LLC that the Primary Response Action Contractor is no longer an ADEC approved and registered contractor. Therefore, Flint Hills Resources Alaska,
LLC’s Fairbanks Facility Oil Discharge Prevention and Contingency Plan was out of compliance and needed amendment. 

  

	 	(iii)	Two underground storage tanks are located at the Fairbank Terminal, both of which are used to store heating oil. One underground storage tank was removed from the Purchased Site prior to Flint Hills Resources Alaska,
LLC’s leasehold. 

  

	 	(iv)	Asbestos materials has been identified and are known to be located at the Anchorage Facility in the following locations: 

  

					
	 Material Type
	  	 Location(s)
	  	 EPA Category

	 Gray Caulk
 (10% Chrysotile)
	  	Fire Pump Room, Warehouse	  	Category II
	 Sheetrock
 (4% Chrysotile)
	  	Boiler Room, Warehouse	  	Category II
	 Brown Insulation
 (5% Chrysotile)
	  	Heat Exchanger Building	  	Category I
	 Window Caulk
 (3% Chrysotile)
	  	Warehouse	  	Category II
	 Gray Mastic
 (10% Chrysotile)
	  	Concrete Pad Near Tank 4136	  	Category II
	 Black Mastic
 (6% Chrysotile)
	  	Concrete Pad Near Tank 4136	  	Category II
	 Black Mastic
 (17% Chrysotile)
	  	Exchanger on West Side of Asphalt Tank Farm	  	Category II
	 Black Mastic
 (6% Chrysotile)
	  	Piping located near railroad tracks on Ocean Dock Road.	  	Category II
	 Black Mastic
 (20% Chrysotile)
	  	Piping on side of Tank 4263, East Tank Farm	  	Category II
	 White Insulation
 (60% Chrysotile)
	  	Piping on side of Tank 4263, East Tank Farm	  	Category I
	 Mastic/Insulation
 (20% Chrysotile)
	  	Top skirt of Tank 4263, East Tank Farm	  	Category I
	 Mastic
 (15% Chrysotile)
	  	Sections of buried pipelines	  	Category II

 In the Flint Hills APA, Flint Hills Resources Alaska, LLC noted that it had no knowledge of other asbestos-containing material
currently located at the sites purchased by TAT. However, Flint Hills Resources Alaska, LLC noted that asbestos material has been removed in the past during renovation and/or demolition work at the purchased sites. 

 Flint Hills Resources Alaska, LLC stated in the Flint Hills APA that it has no knowledge of polychlorinated
biphenyls (“PCB”) material or equipment containing PCBs existing at the purchased sites. Flint Hills Resources Alaska, LLC, however, noted that it understands that PCBs may have been present under prior lessees operations of the
sites but has no direct knowledge of this. 
 Flint Hills Resources Alaska, LLC stated in the Flint Hills APA that it understands “disposal areas”
to include areas where Hazardous Materials have been Released. See Section 3.11(h) of Seller Disclosure Schedule under the Flint Hills APA for Flint Hills Resources Alaska, LLC’s knowledge regarding disposal areas on the Purchased Sites.
In addition, a significant amount of fill material was used to augment the elevation and stability of the soils beneath the Anchorage facility. This fill included debris and materials such as such as wood, metal, and concrete. Flint Hills Resources
Alaska LLC stated in the Flint Hills APA that it has no knowledge that the fill material contained Hazardous Materials when it was placed on the site. 

Flint Hills Resources Alaska, LLC stated in the Flint Hills APA that: 
  

	 	1.	On July 24, 2014 ADEC issued a letter to Flint Hills Resources Alaska, LLC advising that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the July 22, 2014 Anchorage Facility Jet
Fuel release. 

  

	 	2.	On April 21, 2014, ADEC issued a letter to Flint Hills Resources Alaska, LLC advising it that Flint Hills Resources Alaska, LLC is a responsible party under Alaska law for the April 20, 2014 gasoline release.

  

	 	3.	In a letter dated July 22, 2015, ADEC indicated that the Anchorage Terminal Oil Discharge Prevention and Contingency Plan needed the additional information specified in the July 22 letter to be submitted in
order for the plan renewal to be approved. On September 2, 2015, the facility submitted the requested information and is awaiting ADEC approval. 

Flint Hills Resources Alaska, LLC assumed all environmental liabilities known at the time the Purchased Facilities were acquired from Williams in 2004. 

For Martinez Assets Contribution Agreement listed on Schedule VII: 

MARTINEZ TANKAGE: 
 The following
pending refinery notices of violation: 
  

	 	1.	Notice issued April 16, 2013 by the Bay Area Air Quality Management District (“BAAQMD”) related to liquid discovered on internal floating roof of Tank 870; 

 

	 	2.	Notice issued February 11, 2014 by BAAQMD related to a leaking PV valve on Tract 3 VRS Tank 613; and 

  

	 	3.	Notice issued August 12, 2014 by BAAQMD related to a  1⁄2 inch gap at well sliding cover on Tank 692. 

 Existing soil and groundwater contamination has been identified and is being managed under
existing programs and agreements by TRMC and third parties, within three (3) solid waste management units located on Tract 3 of the “Licensed Premises” (as defined in the November 21, 2016 License Agreement between TRMC and the
Operating Company)Anacortes, on which the crude oil, feedstock and refined product storage tankage are situated, with such waste management units being identified as areas within red or green boundary lines on the WMU HAZARD MAP-Orientation Unit Or System Overall General Sheets, as reflected on the Golden Eagle Refinery Plat, Drawing Number
020-DA-518-001, as copy of which is shown below. 
  

 
 For Assets owned by WNRL on the Closing Date of the Merger Agreement and acquired by the Partnership pursuant to the
Merger Agreement by virtue of its acquisition of WNRL thereunder: 
 None. The environmental indemnification provisions in Article VI of the Sponsor
Equity Restructuring Agreement dated August 13, 2017 (“SERA”) between Andeavor, Andeavor Logistics LP and Tesoro Logistics GP, LLC supersede in their entirety the environmental indemnification provisions of Article III of the Fourth
Amended and Restated Omnibus Agreement, other than Section 3.5(b), and shall be the exclusive provisions for all indemnification obligations relating to the subject matter of the indemnities so provided in Article VI of the SERA. 

 For 2017 Anacortes Assets Contribution Agreement listed on Schedule VII: 

 

	 	1.	The transfer piping on the wharf has not been reviewed for risk of surge. In the event of misalignment during cargo operations or accidental valve closure on vessel or shore there is a potential to overpressure the
transfer piping. A surge study will be conducted and any required modifications will be undertaken. 

  

	 	2.	There is a seep of oil through the north secondary containment dike for Tanks 6 and 7 and into the adjacent storm water swale. Absorbent booms are placed at intervals in the swale to contain the oil. Any oil that makes
its way to the wastewater treatment facility can be managed at the flume. Additional information about the seep, as well as investigation efforts to determine the source, was provided in a memo from Pacific Groundwater Group. Investigation efforts
have not yet identified the source of the seep. TRMC personnel have reported the seep to the Washington State Department of Ecology Industrial Section. 

  

	 	3.	The tank containment dikes are coated with asphalt and roofing tar and the asphalt coating is deteriorating on many of the dikes, vegetation is encroaching, and some minor sloughing was noted. If not maintained, further
erosion may occur to containment dikes and there are potential compliance risk related to 40 CFR 121, SPCC, and WAC 173-180-320. A tank containment dike erosion control
program is in place but needs to be accelerated to mitigate erosion issues over next three years. 

  

	 	4.	Certain floating roof deck fittings do not meet the requirements of Refinery MACT Subpart CC for storage tanks. According to TRMC representatives, seals/gaskets need to be replaced on 27 tanks in the Assets covered by
the 2017 Anacortes Contribution Agreement. 

  

	 	5.	Per the Consent Decree mentioned in Schedule 1, the Refinery must install closed-purge, closed-loop, or closed-vent samplers at all storage tanks by 2021. According to facility representatives, there are 42 tanks left
to retrofit in the Assets covered by the 2017 Anacortes Contribution Agreement. 

  

	 	6.	Several out-of-service assets are included in the drop, including 17 tanks, the asphalt loading rack, pipelines, the red dye shed, and lead
shed areas. TRMC has indicated a total of 17 out-of-service tanks (Tanks 34, 46, 47, 48, 55, 62, 88, 89, 90, 95, 98, 99, 110, 147, 159, 232, and 249). 

 

	 	7.	Propane and butane vessels were observed to potentially not have drain-away protection that is sized and configured for one-half the largest vessel. A release should be able to
drain away from the vessels to prevent further releases, explosions, and fires. 

 Schedule III 

Pending Litigation 
 For Initial
Contribution Agreement listed on Schedule VII: 
 None. 

For Amorco Contribution Agreement listed on Schedule VII: 

None. 
 For Long Beach Contribution Agreement listed on
Schedule VII: 
 None. 
 For Anacortes Rail
Facility Contribution Agreement listed on Schedule VII: 
 None. 

For BP Carson Tranche 1 Contribution Agreement listed on Schedule VII: 

None. 
 For BP Carson Tranche 2 Contribution Agreement
listed on Schedule VII: 
 None. 
 For West Coast
Assets Contribution Agreement listed on Schedule VII: 
 None. 

For 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII: 

None. 
 For 2016 Alaska Assets Contribution Agreement
listed on Schedule VII: 
 KENAI TANKAGE: None. 

ANCHORAGE AND FAIRBANKS TERMINALS: None. 

For Martinez Assets Contribution Agreement listed on Schedule VII: 

None.  

 For Assets owned by WNRL on the Closing Date of the Merger Agreement and acquired by the Partnership
pursuant to the Merger Agreement by virtue of its acquisition of WNRL thereunder: 
 The Additional Indemnification provisions in Article VI of SERA
supersede in their entirety the indemnification provisions of Section 3.5(a) of the Fourth Amended and Restated Omnibus Agreement, and shall be the exclusive provisions for all indemnification obligations relating to the subject matter of the
indemnities so provided in of Section 3.5(a) of the Fourth Amended and Restated Omnibus Agreement. 
 For 2017 Anacortes Assets Contribution
Agreement listed on Schedule VII: 
 None 

 Schedule IV 

Section 4.1(a): General and Administrative Services 
  

	(1)	Executive management services of Andeavor employees who devote less than 50% of their business time to the business and affairs of the Partnership, including stock based compensation expense 

 

	(2)	Financial and administrative services (including, but not limited to, treasury and accounting) 

  

	(3)	Information technology services 

  

	(4)	Legal services 

  

	(5)	Health, safety and environmental services 

  

	(6)	Human resources services 

 Section 4.1(c)(vii): Other Reimbursable Expenses 

For Initial Contribution Agreement listed on Schedule VII: 

None. 
 For Amorco Contribution Agreement listed on
Schedule VII: 
 None. 
 For Long Beach
Contribution Agreement listed on Schedule VII: 
 None. 

For Anacortes Rail Facility Contribution Agreement listed on Schedule VII: 

None. 
 For BP Carson Tranche 1 Contribution Agreement
listed on Schedule VII: 
 None. 
 For BP Carson
Tranche 2 Contribution Agreement listed on Schedule VII: 
 None. 

 For West Coast Assets Contribution Agreement listed on Schedule VII: 

None. 
 For 2015 Line 88 and Carson Tankage Contribution
Agreement listed on Schedule VII: 
 None. 
 For
2016 Alaska Assets Contribution Agreement listed on Schedule VII: 
 KENAI TANKAGE: None. 

ANCHORAGE AND FAIRBANKS TERMINALS: None. 

For Martinez Assets Contribution Agreement listed on Schedule VII: 

None. 
 For Assets owned by WNRL on the Closing Date of the
Merger Agreement and acquired by the Partnership pursuant to the Merger Agreement by virtue of its acquisition of WNRL thereunder: 
 None. 

For 2017 Anacortes Assets Contribution Agreement listed on Schedule VII: 

None. 

 Schedule V 

ROFO Assets 
  

			
	 Asset
	  	 Owner

		
	 Nikiski Dock and Storage Facility (Nikiski, Alaska)

A single-berth dock and storage facility located at the Kenai Refinery that includes five crude oil storage tanks with a combined capacity of approximately
930,000 barrels, ballast water treatment capability and associated pipelines, pumps and metering stations. The dock and storage facility receives crude oil from marine tankers and from local production fields via pipeline and truck, and also
delivers refined products from the refinery to marine vessels.
	  	Tesoro Alaska
		
	 Jal NGL Terminal (Lea County, New Mexico)

A terminal that receives, stores, and ships various light hydrocarbon products or natural gas liquids (“NGLs”) via truck, rail, and pipeline. Primary
storage at the Jal NGL Terminal consists of four large NGL storage caverns, with combined storage capacity of approximately 562,000 barrels, that are connected to the Enterprise Products Partners L.P. (“Enterprise”) MAPL system connecting
NGL hubs at Conway, Kansas and Mt. Belvieu, Texas. Brine ponds are available on site to support product movement in and out of the storage caverns. The terminal also includes 17 storage tanks with a combined shell storage capacity of approximately
15,000 barrels, and loading and unloading capacity of up to 6,000 bpd, utilizing either a three-bay truck rack or a rail loading facility located on the Texas-New Mexico
Railroad that has 16 loading spots.
	  	Western Refining Company, LP

 Schedule VI 

Existing Capital and Expense Projects 

For Initial Contribution Agreement listed on Schedule VII: 

Expense Projects 
 None. 

Capital Projects 
 1. That certain
project related to AFE # 102120001, which provides for side stream ethanol blending into all gasoline at the Salt Lake City terminal by adding truck ethanol unloading capability, utilizing the existing premium day tank for ethanol and delivering
premium direct from the Salt Lake City refinery tankage. New ethanol truck unloading facilities will be installed. New Pumps will also be installed for delivering higher volumes of premium gasoline from the Salt Lake City refinery to the Salt Lake
City terminal. An ethanol injection skid will be installed along with piping changing to the existing Salt Lake City terminal to allow the ethanol to be injected in the gasoline stream. This project has been completed. 

2. That certain project AFE# 112120005 at the Mandan refinery, to update additive equipment to allow the offering of Shell additized gasoline.
This project has been completed. 
 3. That certain project related to AFE # 107120005, which provides for ratio ethanol blending into
gasoline on the rack at the Burley, Idaho Terminal by adding truck ethanol unloading capability, adding tankage for ethanol storage and installing new ethanol meters associated with each gasoline loading arm. New ethanol truck unloading facilities
will also be installed. 
 4. That certain project AFE# 104100015-M at the Mandan refinery, to
update the truck rack sprinkler system. This project has been completed. 
 5. That certain project number AFE# 122120002 (TCM Idea#
2010113017) at the Mandan refinery, to upgrade the rack blending hydraulic system to reduce/eliminate inaccurate blends at the load rack. 

6. That certain project number TCM Idea # 2011433001 at the Mandan refinery, to move the JP8 to new bay and have three bays for loading
product across the rack. This project has been cancelled. 
 7. That certain project number TCM Idea # 2011432602 at the Stockton terminal,
install a continuous vapor emission monitor on the vapor recovery unit for compliance with air quality regulations. 

 For Amorco Contribution Agreement listed on Schedule VII: 

Expense Projects 
 All major expense
projects that are within the scope of open Work Orders as of the applicable Closing Date. 
 Capital Projects 

1. That certain project related to AFE# 097100014 and AFE# 107100014 at the Amorco terminal, which provide repairs and upgrades to the wharf
regarding MOTEMS standards. 
 2. That certain project related to AFE# 112100001 at the Amorco terminal, which installs a jet mixer system
for crude lab testing. 
 For Long Beach Contribution Agreement listed on Schedule VII: 

Expense Projects 
 1. Any cost that
may be incurred to adjust diesel fuel tank vents near light fixtures after a review is conducted and if action is deemed necessary. 
 2.
Costs related to substantial repair or replacement project scheduled for 2012 and 2013 for the pipeline segments in the portion of the Southern California Edison
right-of-way area immediately adjacent to the marine terminal to address corrosion, and include IO# 3021407 titled “SCA Wilmington Edison Reroute” and IO#
3021749 titled “SCA. Edison Reroute 24 inch, 16 inch, 14 inch”. 
 Capital Projects 

1. That certain project related to AFE# 072104079LBT titled “UG Piping – LBT” related to underground pipeline repairs at the
Terminal. In addition, any subsequent new projects to address the same specific under-ground piping issues per AFE# 072104079LBT (i.e. a second phase UG Piping project) that would occur on or before the end of year 2015. 

2. That certain project related to the TCM Idea# 2012433432 AFE# 125120020 titled “LBT Berth 84a Loading Arm Replacement” which
repairs or replaces the loading arms at the Terminal and any related AFE project that will occur upon final project approval to substantially repair or replace the loading arms at the Terminal. 

3. That certain project related to the TCM Idea# 2012433433 AFE# 125120021 titled “LBT Berth 86 Loading Arm Replacement” which
repairs or replaces the loading arms at the Terminal and any related AFE project that will occur upon final project approval to substantially repair or replace the loading arms at the Terminal. 

 4. Any remaining costs of those certain projects related to the leak detection on the Terminal
and Terminal Pipelines which are substantially complete and include AFE# 107110002, AFE# 117110001, AFE# 117110003, AFE# 117110002, and AFE# 125120002. 

For Anacortes Rail Facility Contribution Agreement listed on Schedule VII: 

Expense Projects 
 None. 

Capital Projects 
 Any capital
costs or expenses that may be incurred for the installation of a custody transfer meter related to the AFE# 125120017 titled “CROF Custody Transfer Meter and Station”. 

For BP Carson Tranche 1 Contribution Agreement listed on Schedule VII: 

Expense Projects 
 Expenses
associated with the API 653 internal inspection, the Carson Crude Terminal Tank 401 (AFE# 13E1219120001BP/WBS 19125.E012.975) scheduled to start in November 2013, including without limitation, cleaning of such Tank (including any waste removal) and
any repairs to such Tank required as a result of such inspection. 
 Capital Projects 

None.  
 For BP Carson Tranche 2
Contribution Agreement listed on Schedule VII: 
 Expense Projects 

1. All 2013 and 2014 costs related to AFE# 136104215BP-M (PRISM ID 32503) for a partial replacement of
Rhodia Sulfuric Acid Line 29 will be reimbursed by TRMC to cover the 2014 expenditure of $1.1 million for line neutralization, the pig run and tie-ins. Subject to confirmation with the refinery on exact
outage dates, the bulk of this cost will be incurred in March and April. 
 2. All 2013 costs or 2013 carry-over costs related to AFE# 13E1012000002BP-M12 & 13E1012000002BP-M5 PRISM ID 32518 (under the 2013 AFE # 13E1012000002BP) for the Manual Entry Corrosion Program at Terminal 2 will be reimbursed by
TRMC. All 2014 costs will be covered by the Partnership’s 2013 budget.  

 3. All remaining 2013 inspection and repair costs related to AFE#
13E1012000002BP-M2 (PRISM ID 32549) associated with the Marine Terminal 2 – TK 218 – API 653 Internal Inspection only (not including repairs at this point) will be reimbursed by TRMC. TRMC shall
review and approve the tank repair scope and review inspection reports to prevent unnecessary upgrades or “urban renewal.” 
 4.
All remaining 2013 inspection and repair costs related to AFE# 13E1212000001-M (PRISM ID 31418) associated with the Marine Terminal 2 – TK 205 – API 653 Internal Inspection only (not including
repairs at this point) will be reimbursed by TRMC. TRMC shall review and approve the tank repair scope and review inspection reports to prevent unnecessary upgrades or “urban renewal.” 

5. Remaining expenses related to AFE# 13E1179000001-M (PRISM ID 32040) to upgrade PLC systems in the
LA Basin will be reimbursed by TRMC. 
 6. All remaining 2013 inspection and repair costs related to AFE#
13E1212000002-M (PRISM ID 31419) associated with the Marine Terminal 2 – TK 217 – API 653 Internal Inspection only (not including repairs at this point) will be reimbursed by TRMC. TRMC shall review
and approve the tank repair scope and review inspection reports to prevent unnecessary upgrades or “urban renewal.” 
 7. All
remaining expenses related to AFE# 136104222BP-M (PRISM ID 32556) associated with the Pipeline OQ Verification will be reimbursed by TRMC. 

8. All remaining 2013 inspection and repair costs related to AFE# 13E1012000006-M (PRISM ID 31409)
associated with the Carson Products – TK VH1 – API 653 Inspection only (not including repairs at this point) will be reimbursed by TRMC. TRMC shall review and approve the tank repair scope and review inspection reports to prevent
unnecessary upgrades or “urban renewal. 
 Capital Projects 

1. Maintenance capital expenditures related to that certain AFE# 136104194BP-M (PRISM ID 32480) at
Terminal 2 to replace all fire water piping at Berths 76, 77 and 78 areas of Terminal 2 in Long Beach, CA with new piping. This project will also replace all associated valves, fixtures, monitors, and fire-fighting accessories. 

2. Maintenance capital expenditures related to that certain TCM Idea# 2013434229 (PRISM ID 25829) at Terminal 2 to replace the existing
bladder type foam tank with two atmospheric tanks and foam skids located at either end of the facility along with new piping to support the installation. 

 3. Maintenance capital expenditures related to that certain TCM Idea# 2013434243 (PRISM ID 20054)
at Terminal 2 to replace the existing loading arms at T2’s Berth 77 and 78. The current parts are so old that they are no longer readily available, so in order to properly maintain this equipment to minimize down-time for repairs, these arms
should be replaced with the newest models. 
 4. All capital expenditures related to that certain AFE#
136104077BP-M (PRISM ID 32481) for MOTEMS dock side piping upgrades at Terminal 2. 
 5. Maintenance
capital expenditures related to that certain AFE# 145120008 (PRISM ID 32560) at Terminal 2 to replace the main 12kV electrical switchgear that experienced electrical damage due to several factors: nearing its equipment service life, component
degradation, exposure to the elements. The main copper busbar component of the switchgear was recently replaced and dipped in epoxy coating. However, during the repairs, cracks on the insulation of the main horizontal operating bus were discovered.
The exterior enclosure is slowly showing signs of corrosion and the glastic insulation materials are degrading. 
 6. Upon TRMC’s
approval to complete the following projects, all capital costs incurred to connect the Los Angeles Wilmington and Carson refinery systems, as well as the crude and product pipeline systems: TCM Idea# 2013434786, AFE#
132110022-M (TCM Idea# 2013434419), TCM Idea# 2013434788, AFE# 132110023-M (TCM Idea# 2013434417), AFE# 132110025-M (TCM Idea#
2013434418), AFE# 132110030-M (TCM Idea# 2013434420), AFE# 132110031-M (TCM Idea# 2013434784), TCM Idea# 2013434785 and AFE# 132110026 (TCM Idea# 2013434137). 

7. Upon TRMC’s approval to complete the project, all capital costs related to the project at Terminal 2 targeted to reduce
Andeavor’s demurrage cost due to barge delivered additive alternative, under AFE# 132110024-M (TCM Idea# 2013434220). 

8. All capital costs related to AFE# 131907046, the implementation of an equivalent solution using Andeavor ECC 6 MOC module, including
necessary configuration changes and customization of interfaces to be completed and executed in line with other transformation projects identified as part of integrating other BP assets such as TMS5 to DTN Guardian3, Load Tracker, etc. in the
Logistics area. 
 9. All capital costs related to AFE# 131907047. As a part of the BP Carson Tranche 1 Contribution Agreement, Andeavor
acquired Maximo, i-Maintain, Maximo Mobile and Primavera. These applications are used for scheduling and managing routine maintenance tasks and planning capital projects (Primavera). These business functions will be transitioned to SAP PM (using
GWOS) and a TSO instance of Primavera. This initiative should be performed in line with Maximo to SAP PM transformation project and with other logistics and refining projects. 

 10. All capital costs related to AFE# 131907045. This project, in conjunction with
Andeavor’s acquisition of the BP Carson City Refinery, is designed to transition and successfully integrate the Southwest’s Logistics Mechanical Integrity Inspection System Information Technology assets into the Andeavor Information
Technology application landscape. 
 For West Coast Assets Contribution Agreement listed on Schedule VII: 

Expense Projects 
 1. Nikiski
Terminal. Tesoro Alaska shall reimburse the Partnership Group for any costs or expenses incurred by the Partnership Group to reinstate water supply to the Operating Company’s Nikiski Terminal in connection with the water suppression
system. 
 2. Anacortes Light Ends Rail Facility. TRMC shall reimburse the Partnership Group for any costs and expenses
incurred by the Partnership Group: 
  

	 	•	 	to determine the adequacy of fire water at the facility; 

  

	 	•	 	with respect to any modifications needed to be made to fire water system to provide adequate fire water; and 

  

	 	•	 	for relocation of the knockout drum, if relocation is required. 

 3. Anacortes Storage
Facility 
  

	 	•	 	TRMC shall reimburse the Partnership Group for any costs and expenses incurred by the Partnership Group to restore Tank 135 to API 653 specifications. TRMC shall be deemed to be the generator of all hazardous waste and
other waste removed from Tank 135 in connection with such cleaning and restoration and shall be responsible for all obligations arising as the generator of such hazardous waste and other waste. 

 

	 	•	 	TRMC shall reimburse the Partnership Group for any costs and expenses incurred by the Partnership Group for decommissioning and repair of sewer lines for Tanks 165 and 166. 

4. Martinez Light Ends Rail Facility. TRMC shall reimburse the Partnership Group for any costs and expenses incurred by the
Partnership Group: 
  

	 	•	 	to determine the adequacy of fire water at the facility; and 

  

	 	•	 	with respect to any modifications needed to be made to fire water system to provide adequate fire water. 

5. Martinez Clean Products Truck Rack. TRMC shall reimburse the Partnership Group for any costs and expenses incurred by the
Partnership Group: 
  

	 	•	 	if required to supplement data currently available in the baseline inspections records in order to properly document corrosion, to carry out new tank corrosion inspections on Tanks 777, 778 and 890, as well as any
repairs resulting from such inspections to meet API 653 standards; and 

	 	•	 	with respect to Tank 777, the tank berm size and tank proximity evaluation scheduled to completed by year-end 2014, as well as any required adjustments resulting therefrom.

 6. Martinez Light Ends Storage. If required to supplement data currently available in the baseline inspection
records in order to properly document pipe integrity, TRMC shall reimburse the Partnership Group for any costs and expenses incurred by the Partnership Group for inspections and analyses conducted to confirm baseline pipe integrity by year-end 2014, as well as any repairs arising from defects identified through such inspections. 
 7.
Tesoro Alaska Pipeline 
  

	 	•	 	Andeavor shall reimburse the Partnership Group for any costs or expenses incurred by the Partnership Group to carry out the repairs and tests identified in the Coffman Engineers report dated May 8, 2014, including
the planned hydro-test in 2015 and any resulting repairs therefrom. 

  

	 	•	 	Andeavor shall reimburse the Partnership Group for any costs or expenses incurred by the Partnership Group to carry out repairs identified pursuant to the inspection on the Tesoro Alaska Pipeline as a result of the
inspection scheduled to begin June 30, 2014. 

 Capital Projects 

Martinez Capital Projects 

1. All capital costs related to AFE# 127100012—Design, procure, and install Biodiesel Blending Facility at existing Martinez Tract 3 Truck
Loading Rack. 
 2. All capital costs related to AFE# 132100017— Martinez gasoline loading rack filtration. 

3. All capital costs related to AFE# TBD regarding Fall Protection for Top Loading Tank Cars and Trucks. 

4. All capital costs related to AFE# 132100017 regarding the installation of a new Tract 3 Gasoline Loading Rack Filtration System to replace
the existing rental units. 
 5. All capital costs related to AFE# PTS 12475 regarding LPG Tank Car Loading Rack Improvements. 

6. All capital costs related to AFE# TBD regarding the installation of a system to add ExxonMobil additives to gasoline at the Tr. 3 truck
loading rack. 
 7. All capital costs related to AFE# 145110009 regarding the implementation of Tesoro Alaska Pipeline mainline delivery
strainer. 

 Alaska Capital Projects 

1. All capital costs related to AFE# 125100055—Additive reservoir tank and pumping system for the Nikiski Terminal truck loading rack.

 2. All capital costs related to AFE# 125110005—Fabrication and installation of a skid-mounted clay treatment system at the Tesoro
Alaska Pipeline Port of Anchorage delivery facility. 
 3. All capital costs related to AFE# 125110007— Provision of inline strainers
upstream of the Kenai Pump station pipeline pumps and upstream of the Anchorage receiving station control valve. 
 4. All capital costs
related to AFE# 124100034—Purchase and installation of (5) IP CCTV Cameras, and security video monitoring station for Tesoro Alaska Pipeline Anchorage control room (located at the Port of Anchorage Industrial Park), MLV 7 on Northern
Lights Blvd, and the ASIG Filter Building located at Ted Stevens International Airport. 
 5. All capital costs related to AFE# 145110002
regarding the installation of semi-deep cathodic protection wells, a new rectifier and electrical service at the Tesoro Alaska Pipeline. 

6. All capital costs related to AFE# 124100030 regarding new CCTV monitoring system at the Nikiski Terminal. 

7. All capital costs related to AFE# 145120005 regarding a new cathodic protection anode bed and rectifier for the Nikiski Terminal. 

 For 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII: 

Capital Projects 
 TRMC shall reimburse the
Partnership Group for: 
 1. Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the
Partnership Group for all capital costs incurred for the execution of the following piping systems projects: AFE# 136104160BP (TCM Idea# 2013218160), TCM Idea# 2013212538, TCM idea# 2013212540 and TCM Idea# 2013212539. For any such projects listed
above in this section 1 that are required to maintain safe operation of the Assets, the Partnership shall determine the final project scope in its sole discretion. 

2. Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all
capital costs incurred for the execution of the following instrumentation and control projects: AFE# 154100014 (TCM Idea# 2014217001), TCM Idea #2014217008, AFE# 136104169BP (TCM Idea# 2013218169), AFE# 136104190BP (TCM Idea# 2013218190), TCM
Idea# 2013212558, and TCM Idea # 2014217023. For any such projects listed above in this section 2 that are required to maintain safe operation of the Assets, the Partnership shall determine the final project scope in its sole discretion. 

3. Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all
capital costs incurred for the execution of the following tank improvements: TCM Idea# 2014217135 (tk 56), TCM Idea# 2013212585 (tk 1), TCM Idea# 2014217132 (tk 90), TCM Idea# 2014217133 (tk 11), TCM Idea# 2013212575 (tk 34), TCM Idea # 2013212587
(tk 35), TCM Idea# 2013212588 (tk 10), TCM Idea# 2013212589 (tk 58), TCM Idea# 2013212592 (tk 39), TCM Idea# 2013212593 (tk 968), TCM Idea# 2013212595 (tk 60), TCM Idea# 2013212596 (tk 69), TCM Idea # 2013212597 (tk 57), TCM Idea# 2013212599 (tk
51). For any such projects listed above in this section 3 that are required to maintain safe operation of the Assets, the Partnership shall determine the final project scope in its sole discretion. 

4. All capital costs related to the repair or replacement of brick structure piping supports, with the scope of repairs to be
developed in 2016 and the execution of such repairs to be completed in 2017. 
 5. All capital costs related to the upgrade
or replacement of the cathodic protection system for the tanks as identified through a cathodic protection assessment to be completed prior to year end 2016. An action plan will be developed to address recommendations identified through the
assessment. The program is expected to commence in 2016 and will be executed over a 4-year period. 

6. All capital costs related to the multi-phase upgrade or replacement of tank level measurement and transmitter instruments,
upon mutual consent of TRMC and the Partnership of the scope for the multi-year project. Notwithstanding the foregoing, the Partnership in its 

 
sole discretion shall determine the final scope of any element of the tank level instrument upgrade project required to maintain safe operation of the Assets. TRMC’s reimbursement to the
Partnership Group for capital costs incurred during the Term to complete the tank level instrument upgrade or replacement project shall not exceed $15,000,000 in the aggregate. 

Expense Projects 

1. With respect to the Remaining Pipeline 88 Interest (as defined in the 2015 Line 88 and Carson Tankage Contribution Agreement
listed on Schedule VII), TRMC shall reimburse the Partnership for any costs and expenses associated with curing any anomalies identified by the August 2015 in-line inspection thereof. 

2. With respect to the Tankage (as defined in the 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule
VII), as well as the land on which such Tankage is located, TRMC shall reimburse the Partnership for any costs and expenses associated with any liabilities, costs and expenses that might be imposed upon the Partnership as operator of the Tankage and
which relate to the environmental condition of the land on which the Tankage is located and surrounding lands, including but not limited to any government-imposed fines or remediation costs and natural resource damages, but excluding (i) any
liabilities, costs and expenses that arise from any releases or discharges of hydrocarbons or other substances from the Tankage after the date hereof or (ii) any liabilities, costs and expenses that arise from negligent acts or omissions or
willful misconduct of the Partnership and its agents, contractors and representatives. 
 3. Until the later of
(i) November 12, 2020 or (ii) the completion of any repairs identified by any applicable non-invasive or external inspections that occurred prior to such date, TRMC shall reimburse the
Partnership Group for any costs and expenses incurred by the Partnership Group to restore any tank included in the 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII to API 653 or API 510 specifications that are identified
through the Partnership Group’s non-invasive or external inspections. 
 4.
During the term (including any extension thereof) of the Carson II Storage Services Agreement, dated as of November 12, 2015, by and among TRMC, the General Partner, the Partnership and the Operating Company (the “Carson II Storage
Agreement”), TRMC shall reimburse the Partnership Group for any costs and expenses incurred by the Partnership Group to restore any tank included in the 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII to API 653 or
API 510 specifications, as determined by the results of the first scheduled internal inspection of any such tank after the date hereof (the “First Internal Inspection”). TRMC shall be deemed to be the generator of all hazardous waste and
other waste removed from any such tanks in connection with such cleaning and restoration and shall be responsible for all obligations arising as the generator of such hazardous waste and other waste. 

 

	 	a)	TRMC and the Operating Company shall mutually agree on the inspection schedule and the duration of such inspections so as to minimize disruption within the Wilmington and Carson refinery systems, with TRMC having the
right to approve the final inspection schedule. 

	 	b)	If TRMC fails to renew the Carson II Storage Services Agreement, prior to November 12, 2022, in accordance with the terms thereof, the Partnership Group may elect to accelerate API 653 or API 510 inspections prior
to the expiration of the Carson II Storage Agreement. 

 5. Notwithstanding Sections 3 and 4 above, the parties
agree that the following tanks included in the 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 24 months prior
to the date of that Contribution Agreement, and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of TRMC: 

 

			
	 Tank Number
	  	 Year of Last
Inspection

	53	  	2013
	87	  	2013
	41	  	2013
	4	  	2013
	88	  	2013
	5	  	2013
	24	  	2013
	325	  	2013
	326	  	2013
	45	  	2014
	65	  	2014
	89	  	2014
	276	  	2014
	289	  	2014
	303	  	2014
	340	  	2014
	50	  	2014
	302	  	2014
	138	  	2014
	139	  	2014
	289	  	2015
	65	  	2015
	969	  	2015
	40	  	2015
	955	  	2015
	194	  	2015

 For 2016 Alaska Assets Contribution Agreement listed on Schedule VII: 

KENAI TANKAGE: 
 Capital Projects 

TAC shall reimburse the Partnership Group for: 
  

	 	1.	Upon mutual consent on project scope between TAC and the Partnership, TAC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following instrumentation and control projects:
AFE# 2012217023 (TCM Idea# 137100002), TCM Idea# 2014216018, TCM Idea# 2007002425. For any such projects listed above in this section 1 that are required to maintain safe operation of the Assets, the Partnership shall determine the final project
scope in its sole discretion. 

  

	 	2.	All capital costs related to the assessment and upgrade or replacement of tank level measurement and transmitter instruments, upon mutual consent of TAC and the Partnership of the scope for the multi-year project.
Notwithstanding the foregoing, the Partnership in its sole discretion shall determine the final scope of any element of the tank level instrument upgrade project required to maintain safe operation of the Assets. 

 

	 	3.	All capital costs related to installation of tank liners during first API 653 inspection cycle to bring each tank into conformance with Alaska Department of Environmental Conversation standards. 

 

	 	4.	All capital costs related to the assessment and necessary upgrades of cathodic protection system including: 

  

	 	•	 	Additional anode ground beds 

  

	 	•	 	Additional surface distributed anodes 

  

	 	•	 	Additional amperes of cathodic protection for on-grade storage tanks 

  

	 	•	 	Under tank monitoring systems 

 The program is expected to commence in 2016 and will be executed
over a 3-year period. 
  

	 	5.	All capital costs related to internal inspection, assessment and repair of Tank 11 internal floating roof. 

Expense Projects 
  

	 	1.	The parties agree that Tank 37 included in the Alaska Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 24
months prior to the date hereof, and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of TAC. 

	 	2.	Any costs or expenses related to: 

  

	 	•	 	Completion of pressure relief documentation, expected to be complete by year-end 2016. 

  

	 	•	 	Completion of area classification plans per NEC 500.4, expected to be complete by year-end 2017. 

ANCHORAGE AND FAIRBANKS TERMINALS: 
 Capital
Projects 
 TAC shall reimburse the Partnership Group for: 
  

	 	1.	All capital costs related to: 

  

	 	a)	Anchorage Terminal 

  

	 	•	 	Installation of permanent fire water pipeline supports with proper coating; expected to be complete by year-end 2017. 

 

	 	•	 	Assessment, evaluation and potential replacement of two deep anode ground beds (No. 2 and No. 5); expected to be completed within cathodic protection program by year-end
2018. 

  

	 	•	 	Installation of third tank floor on Tank 4236 with either new cathodic protection system or an El Segundo system; expected to be complete by year-end 2020. 

 

	 	•	 	Assessment and upgrades to add access platforms and roof protection to east side filter vessels; expected to be complete by year-end 2017. 

 

	 	b)	Fairbanks Terminal 

  

	 	•	 	Assessment, evaluation and potential replacement of two deep anode ground beds and installation of two new rectifiers to allow ground beds to be operated independently; expected to be completed within cathodic
protection program by year-end 2018. 

 Expense Projects 

 

	 	1.	Any costs or expenses related to: 

  

	 	a.	Anchorage Terminal 

  

	 	•	 	Inspection and assessment of buried product pipeline; expected to be complete by year-end 2017. 

 

	 	•	 	Assessment of manual operation of rail car sump tankage; expected to be complete by year-end 2017. 

 

	 	b.	Fairbanks Terminal—Any costs or expenses related to: 

  

	 	•	 	Arc flash assessment; expected to be complete by year-end 2017. 

 Relief
valve sizing and selection assessment; expected to be complete by year-end 2017. 

 For Martinez Assets Contribution Agreement listed on Schedule VII: 

Capital Projects 
 TRMC shall reimburse the
Partnership Group for: 
 1. Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the
Partnership Group for all capital costs incurred for the execution of the following secondary containment projects identified for Tract 3 and Tract 6: AFE# 127100010 (TCM Idea# 2007000713), TCM Idea# 2012211027. In addition, TRMC shall reimburse the
Partnership for any additional capital costs or expenses that are associated with the regulatory mandated validation of secondary containment volumes for the Spill Prevention Controls and Countermeasures Plan. For any such projects listed above in
this section 1 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion. 

2. Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all
capital costs incurred for the execution of the following tank repairs, improvements and new build projects: AFE# 152100015 (TCM Idea# 2007000694), TCM Idea# 2007000701, TCM Idea# 2009001043, TCM Idea# 2012211055, TCM Idea# 2012211056, TCM Idea#
2012211080, TCM Idea# 2012211082, TCM Idea# 2013211049, TCM Idea# 2013211073, TCM Idea# 2014211011, TCM Idea# 2014211038, TCM Idea# 2014211040. For any such projects listed above in this section 2 that are required to maintain safe operation and
compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion. 
 3. Upon mutual
consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the Avon Warf Upgrade project (MOTEMS), AFE# 077100030 (TCM Idea# 2007001314), and the Avon
Wharf Pipeline Surge Protection project, AFE # 154100001 (TCM Idea # 2012211075). In addition, TRMC shall reimburse the Partnership for any additional capital costs or expenses that are determined to be required to bring the Avon Wharf into
compliance with MOTEMS at the time of the commencement of service of the replacement Wharf, but not for future MOTEMS that may be imposed after the replacement Wharf is approved and permitted for operation. For any such projects listed above in this
section 3 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion. 

4. Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all
capital costs incurred for the execution of the following miscellaneous projects: TCM Idea# 2007001600, TCM Idea# 2014211008. For any such projects listed above in this section 4 that are required to maintain safe operation of the Assets, the
Partnership shall determine the final project scope in its sole discretion. 
 5. All capital costs related to the
replacement and associated initial permitting requirements of the Marine Vapor Control System. 

 6. All capital costs related to the upgrade or replacement of the cathodic
protection system for the tanks as identified through a cathodic protection assessment. An action plan will be developed to address recommendations identified through the assessment. The program is expected to commence in 2017 and will be executed
over a 4-year period. 
 7. All capital costs and expenses that may be associated
with the Asset Retirement Obligations with respect to the existing Avon Wharf and its berths (but not including any future costs of demolition and retirement of the structures on the replacement Wharf now being constructed). 

8. All capital costs and expenses that may be associated with the removal of abandoned pipelines in the Licensed Premises, but
only to the extent that such abandoned pipelines have never been used to provide services under the Martinez Storage Services Agreement and such pipelines are then required to be removed pursuant to applicable law, regulation or governmental order.

 9. All capital costs and expenses related to the Getty pipeline thermal expansion assessment and potential relocation of
the pipeline above ground, per refinery inspection recommendation. 
 10. All capital costs and expenses related to the
assessment and potential repairs to underground storm water piping. 
 Expense Projects 

1. The parties agree that the following tanks included in the Martinez Assets Contribution Agreement listed on Schedule VII
have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510 standards within the 24 months prior to the date of that Contribution Agreement, or the next scheduled tank inspection falls beyond the year 2036, and such tanks
are excluded from the reimbursement requirements listed in Section 5.1(a) of this Agreement, unless such actions fail to meet such compliance standards due to the negligence of TRMC. 

 

	
	 Tank Number

	026
	258
	517
	601
	612
	641
	690
	701
	702
	709
	710
	711

 For Assets owned by Western Refining, Inc. and Western Refining Logistics LP and their subsidiaries prior
to the Closing Date of the Merger Agreement and acquired by the Partnership pursuant to the Merger Agreement by virtue of its acquisition of WNRL thereunder: 

None, except as provided under the SERA, which and shall be the exclusive provisions for all such matters provided in the SERA. 

 For 2017 Anacortes Assets Contribution Agreement listed on Schedule VII: 

Capital Projects 
 TRMC shall reimburse the
Partnership Group for: 
  

	 	1.	Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following gasoline blending unit projects
identified: TCM Idea# 2017211656, TCM Idea# 2016215025, TCM Idea# 2014215018, and TCM Idea# 2012215056. For any such projects listed above in this section 1 that are required to maintain safe operation and compliance of the Assets, the Partnership
shall determine the final project scope in its sole discretion. 

  

	 	2.	Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following tank repairs, improvements and new
build projects: TCM Idea# 2015215024, TCM Idea# 2015215023, TCM Idea# 2015215020, TCM Idea# 2015215022, TCM Idea# 2015215006, TCM Idea# 2016215005, TCM Idea# 2015215008, AFE# DTKRS.0600.2017.03 (TCM Idea# 2015215017), AFE# DTKRS.0600.2017.02 (TCM
Idea# 2015215018), AFE# DTKRS.0600.2017.01 (TCM Idea# 2015215010), TCM Idea# 2015215019, TCM Idea# 2015215015, TCM Idea# 2015215012, TCM Idea# 2015215026, TCM Idea# 2009005038, AFE# DTKRS.0600.2016.03 (TCM Idea# 2011215042), AFE# DTKRS.0600.2016.05
(TCM Idea# 2009005041). For any such projects listed above in this section 2 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final project scope in its sole discretion.

  

	 	3.	Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the tank improvement program listed under AFE#
164100007 (TCM Idea# 2015215004). The Partnership, in its sole discretion, shall determine the final scope of the project listed above in this section 3, if required to maintain safe operation and compliance of the Assets. 

 

	 	4.	Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all capital costs incurred for the execution of the following manifest rail unloading project
identified: TCM Idea# 2016215023. The Partnership, in its sole discretion, shall determine the final scope of the project listed above in this section 4, if required to maintain safe operation and compliance of the Assets. 

 

	 	5.	 Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group
for all capital costs incurred for the execution of the following miscellaneous projects identified: AFE# 172100068 (TCM Idea# 2017211658), AFE# 162100077 (TCM Idea# 2016215022), TCM

	 	
Idea# 2013215028, AFE#172100086 (TCM Idea # 2014215009). For any such projects listed above in this section 5 that are required to maintain safe operation and compliance of the Assets, the
Partnership shall determine the final project scope in its sole discretion. 

  

	 	6.	All capital costs related to the installation of closed-purge, closed-loop, or closed-vent samplers at all storage tanks by 2021 (per the Consent Decree mentioned in Schedule 1). According to TRMC representatives, as
recorded in section 2.2.4 of ERM’s Due Diligence Summary Report (October 2017), there are 42 tanks left to retrofit in the Assets covered by the 2017 Anacortes Contribution Agreement.. 

Expense and/or Capital Projects 
  

	 	1.	The parties agree that the following tanks included in the 2017 Anacortes Assets Contribution Agreement listed on Schedule VII have been inspected, cleaned, and repaired to ensure compliance with API 653 or API 510
standards within the 36 months prior to the date hereof and are excluded from the reimbursement requirements listed above unless such actions fail to meet such compliance standards due to the negligence of TRMC. 

 

	
	 Tank Number

	TK001
	TK019
	TK024
	TK025
	TK026
	TK028
	TK060
	TK091
	TK092
	TK134
	TK248
	TK156
	TK158
	TK180
	TK241 A
	TK241 B

  

	 	2.	Upon mutual consent on project scope between TRMC and the Partnership, TRMC shall reimburse the Partnership Group for all expense and capital costs incurred for the execution of the following miscellaneous projects
identified in the tables below. 

 Tank Farm Projects 

 

			
		 	 IEA)—Replace aging power poles in Tank Farm

		 	 IEA)—Upgrade Switch Racks

		 	 IEA)—Tank Farm Conduit

			
		 	 IEA)—Replace MOV’s in the tank farm

		 	 IEA)—Replace Coggins Conduit and wire

		 	 IEA)—Tank Farm Grounding

		 	 IEA)—Install electric heat tracing

		 	 PIPE)—Upgrade steam piping in tank farm

		 	 REF)—Sample station compliance

		 	 IEA)—Skim oil sump level controller to
P-709

		 	 INSP)—Required inspection work on V-801

		 	 INSP)—Required inspection work on TK-38

		 	 REF)—Purchase tank 8 heater

		 	 TKWK)—Roof Drains, Seal Failures

		 	 IEA)—Back pressure regulator for C4 to storage

		 	 INSP)—Offsite/Rack Piping RBMI Implementation – Field

 Marine Terminal Projects 
  

			
		 	 REF)—Contingency boom replacement

		 	 IEA)—Causeway Conduit

		 	 PPXX)—Abrasive Blast and recoat wharf lines and remove asbestos conduit

		 	 REF)—Rebuild bumpers to be prioritized by operations

		 	 WINP)—Install stairway to access spill boats

 Rail Projects 
  

			
		 	 RAIL)—Rail Maintenance & Inspection

		 	 Rail)—Rail Track Repair

 Note, the above projects in this section 2 are characterized by Program and Technical ID or Work Note shown in
the Major Special Maintenance (MSM) budget of the Andeavor Anacortes Refinery. For any such projects listed above in this section 2 that are required to maintain safe operation and compliance of the Assets, the Partnership shall determine the final
project scope in its sole discretion. 
  

	 	3.	All additional operating expenses associated with accelerating the tank containment dike erosion control program, for the mitigation of erosion issues, over the next five years. This issue is recorded in section 2.2.2
of ERM’s Due Diligence Summary Report (October 2017) as well as section 3.2.1 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017). 

  

	 	4.	All costs related to the installation of independent high-high level switches, consistent with the established tank inspection and repair program. This issue is recorded in section 3.2.1 of Coffman’s Mechanical
Integrity Due Diligence Study (September 2017). 

  

	 	5.	All costs for any future modifications required to comply with Andeavor “Tank & Loading Rack” fire protection standard CPER-004 currently under review. This
issue is recorded in section 3.4.11 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017). 

	 	6.	All costs for implementing a surge study for the wharf transfer piping and for any required modifications discovered as a result of this study. This issue is recorded in sections 2.2.1 and 6.2.1 of ERM’s Due
Diligence Summary Report (October 2017). 

  

	 	7.	All costs for implementing a study of the dike arrangement to the north and east sides of Tank 38, which may not adequately direct contents to the remote containment area in the event of a vessel failure, and for any
required modifications discovered as a result of this study. This issue is recorded in section 3.2.2 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017). 

 

	 	8.	All costs for potential future expenses of investigation and mitigation work related to seep of oil through the north secondary containment dike for tanks 6 and 7. This issue is recorded in sections 6.1.1 and 6.2.3 of
ERM’s Due Diligence Summary Report (October 2017). 

  

	 	9.	All costs related to the installation of storage tank seals and gaskets, required by Refinery Sector Rule MACT Subpart CC, to be identified in the established compliance schedule for tank inspection and repair. This
issue is recorded in section 2.2.3 of ERM’s Due Diligence Summary Report (October 2017). 

  

	 	10.	All costs to empty, blind-flange or air-gap any of the out-of-service tanks listed below.

  

	
	 Tank Number

	TK034
	TK046
	TK047
	TK048
	TK055
	TK062
	TK088
	TK089
	TK090
	TK095
	TK098
	TK099
	TK110
	TK147
	TK159
	TK232
	TK249

  

	 	11.	All costs for removal of out-of-service assets identified in section 6.2.8 of ERM’s Due Diligence Summary Report (October 2017). These
assets include 17 tanks (shown in Section 10 above), asphalt loading rack, pipelines, red dye shed and lead shed. 

	 	12.	All costs related to the performing of an assessment of propane and butane vessel containment areas, and any resulting project expenses required, to ensure compliance with National Fire Protection Association (NFPA)
fire codes. This issue is recorded in section 6.3.3 of ERM’s Due Diligence Summary Report (October 2017). 

  

	 	13.	All costs related to performing an initial direct assessment, and any resulting required repairs, of the Andeavor-owned segment of the underground “Kinder Morgan” crude pipeline. This issue is recorded in
section 3.3.1 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017). 

  

	 	14.	All costs related to performing an initial inspection, and any resulting required repairs, of the wharf sumps. This issue is recorded in section 3.3.5 of Coffman’s Mechanical Integrity Due Diligence Study
(September 2017). 

  

	 	15.	All costs related to performing an initial inspection, and any resulting required repairs, of the cathodic protection (CP) systems for the aboveground storage tank bottoms, buried facility piping and marine structures.
During this inspection the rectifiers will be surveyed and any rectifiers which are not Nationally Recognized Testing Laboratory (NRTL) listed per OSHA (Occupational Safety and Health Administration) and NFPA requirements will be replaced and costs
will be subject for reimbursement. These issues are recorded in section 3.4.17 of Coffman’s Mechanical Integrity Due Diligence Study (September 2017). 

  

	 	16.	All cost of in-service inspections and evaluations of the condition of tank walls and tank floors for each of the following tanks, using accepted engineering methods for non-invasive external inspections that do not
require that a tank be emptied or structurally altered, which are conducted before the earlier of (i) an API 653 inspection of such tank and (ii) November 7, 2022, up to an aggregate reimbursable cost not to exceed two million dollars for all such
tanks. 

  

	
	Tank Number
	TK003
	TK005
	TK006
	TK008
	TK011
	TK013
	TK015
	TK017
	TK018
	TK021
	TK022
	TK027
	TK030
	TK032
	TK033
	TK035
	TK036
	TK037
	TK038
	TK113
	TK114
	TK142
	TK148
	TK230
	TK247
	TK054
	TK056
	TK138
	TK160
	TK157
	TK221
	TK222
	TK223
	TK224
	TK225
	TK226
	TK227
	TK228
	TK229

 Schedule VII 

Contribution Agreements, Other Transactions and Applicable Terms 

Initial Contribution Agreement 
  

															
	 Contribution Agreement
	  	 Closing Date
	  	 First Deadline
Date
	  	 Second Deadline
Date
	  	 Andeavor
Indemnifying
Parties
	  	 Andeavor
Indemnified
Parties
	  	 Third Deadline
Date
	  	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement, dated as April 26, 2011, among the Partnership, the General Partner, the Operating Company, Andeavor, Tesoro Alaska, TRMC and Tesoro High Plains Pipeline Company LLC	  	April 26, 2011	  	April 26, 2013	  	April 26, 2016	  	TRMC and Tesoro Alaska	  	TRMC	  	April 26, 2021	  	Yes

 Amorco Contribution Agreement 

 

															
	 Contribution Agreement
	  	 Closing Date
	  	 First Deadline
Date
	  	 Second
Deadline Date
	  	 Andeavor
Indemnifying
Parties
	  	 Andeavor
Indemnified
Parties
	  	 Third Deadline
Date
	  	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement dated as of April 1, 2012, among the Partnership, the General Partner, the Operating Company, Tesoro and TRMC	  	April 1, 2012	  	April 1, 2014	  	April 1, 2017	  	TRMC	  	TRMC	  	April 1, 2022	  	Yes

 Long Beach Contribution Agreement 

 

															
	 Contribution
Agreement
	 	 Closing Date
	 	 First

Deadline Date
	 	 Second

Deadline Date
	 	 Andeavor
Indemnifying
Parties
	 	 Andeavor
Indemnified
Parties
	 	 Third

Deadline Date
	 	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement executed as of September 14, 2012, among the Partnership, the General Partner, the Operating Company, Andeavor and TRMC	 	Execution Date is September 14, 2012, and various Effective Times are upon receipt of the Long Beach Approval, the CDFG Approval and the Other Approvals as set forth in the agreement, as applicable	 	September 14, 2014	 	September 14, 2017	 	TRMC	 	TRMC	 	September 14, 2022	 	Yes

 Anacortes Rail Facility Contribution Agreement 

 

															
	 Contribution Agreement
	 	 Closing Date
	 	 First

Deadline Date
	 	 Second

Deadline Date
	 	 Andeavor
Indemnifying
Parties
	 	 Andeavor
Indemnified
Parties
	 	 Third

Deadline Date
	 	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement executed as of November 15, 2012, among the Partnership, the General Partner, the Operating Company, Andeavor and TRMC	 	November 15, 2012	 	November 15, 2014	 	November 15, 2017	 	TRMC	 	TRMC	 	November 15, 2022	 	No

 BP Carson Tranche 1 Contribution Agreement 

 

															
	 Contribution Agreement
	  	 Closing Date
	  	 First Deadline
Date
	  	 Second Deadline
Date
	  	 Andeavor
Indemnifying
Parties
	  	 Andeavor
Indemnified
Parties
	  	 Third Deadline
Date
	  	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement executed as of May 17, 2013, among the Partnership, the General Partner, the Operating Company, Andeavor and TRMC	  	June 1, 2013	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	No

 BP Carson Tranche 2 Contribution Agreement 

 

															
	 Contribution Agreement
	  	 Closing Date
	  	 First Deadline
Date
	  	 Second Deadline
Date
	  	 Andeavor
Indemnifying
Parties
	  	 Andeavor
Indemnified
Parties
	  	 Third Deadline
Date
	  	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement executed as of November 18, 2013, among the Partnership, the General Partner, the Operating Company, Andeavor, TRMC and Carson Cogeneration Company	  	December 6, 2013	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	No

 West Coast Assets Contribution Agreement 

 

															
	 Contribution Agreement
	  	 Closing Date
	  	 First

Deadline
 Date
	  	 Second

Deadline
 Date
	  	 Andeavor
Indemnifying
Parties
	  	 Andeavor
Indemnified
Parties
	  	 Third

Deadline
 Date
	  	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement executed as of June 23, 2014, among the Partnership, the General Partner, the Operating Company, Tesoro Logistics Pipelines LLC, Andeavor, TRMC and Tesoro Alaska	  	 First Closing Date: July 1, 2014
  

Second Closing Date has the meaning set forth in the Contribution Agreement
	  	The second (2nd) anniversary of the First Closing Date or the Second Closing Date, as applicable	  	 With respect to Section 3.1(a): Not applicable
  

With respect to Section 3.2: The fifth (5th) anniversary of the First Closing Date or the Second
Closing Date, as applicable
	  	Andeavor, TRMC, Tesoro Alaska	  	Andeavor, TRMC, Tesoro Alaska	  	The tenth (10th) anniversary of the First Closing Date or the Second Closing Date, as applicable.	  	Yes

 2015 Line 88 and Carson Tankage Contribution Agreement 

 

															
	 Contribution Agreement
	 	 Closing Date
	 	 First

Deadline
 Date
	 	 Second

Deadline
 Date
	 	 Andeavor
Indemnifying
Parties
	 	 Andeavor
Indemnified
Parties
	 	 Third

Deadline
 Date
	 	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement effective as of November 12, 2015, among the Partnership, the General Partner, the Operating Company, Tesoro SoCal Pipeline Company LLC, Andeavor, TRMC and Carson Cogeneration
Company	 	November 12, 2015	 	November 12, 2017	 	November 12, 2020	 	Andeavor, TRMC, Carson Cogen	 	Andeavor, TRMC, Carson Cogen	 	November 12, 2025	 	Yes

 2016 Alaska Assets Contribution Agreement 

 

															
	 Contribution
Agreement
	 	 Closing Date
	 	 First

Deadline
 Date
	 	 Second

Deadline
 Date
	 	 Andeavor
Indemnifying
Parties
	 	 Andeavor
Indemnified
Parties
	 	 Third

Deadline
 Date
	 	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement effective as of July 1, 2016, among the Partnership, the General Partner, the Operating Company, Tesoro Alaska Company LLC, and Andeavor	 	July 1, 2016	 	July 1, 2018	 	July 1, 2021	 	Tesoro Alaska Company LLC	 	Not applicable	 	July 1, 2026	 	Yes
								
	KENAI TANKAGE	 		 		 		 		 		 		 	
								
	Contribution, Conveyance and Assumption Agreement effective as of July 1, 2016, among the Partnership, the General Partner, the Operating Company, Tesoro Alaska Company LLC, and Andeavor	 	September 16, 2016	 	September 16, 2018	 	September 16, 2023	 	Tesoro Alaska Company LLC	 	Not applicable	 	September 16, 2026	 	Yes
								
	ANCHORAGE AND FAIRBANKS TERMINALS	 		 		 		 		 		 		 	

 Martinez Assets Contribution Agreement 

 

															
	 Contribution Agreement
	 	 Closing Date
	 	 First

Deadline
 Date
	 	 Second

Deadline
 Date
	 	 Andeavor
Indemnifying
Parties
	 	 Andeavor
Indemnified
Parties
	 	 Third

Deadline
 Date
	 	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement effective as of November 21, 2016, among the Partnership, the General Partner, the Operating Company, TRMC and Andeavor	 	November 21, 2016	 	November 21, 2018	 	November 21, 2021	 	TRMC	 	Not applicable	 	November 21, 2026	 	Yes

 For Assets owned by Western Refining, Inc. and Western Refining Logistics LP and their subsidiaries prior
to the Closing Date of the Merger Agreement and acquired by the Partnership pursuant to the Merger Agreement by virtue of its acquisition of WNRL thereunder: 
  

															
	 Pre-Merger Agreement

WNRL Assets
	  	 Closing Date
	  	 First
Deadline

Date
	  	 Second
Deadline

Date
	  	 Andeavor
Indemnifying
Parties
	  	 Andeavor
Indemnified
Parties
	  	 Third
Deadline

Date
	  	
Omnibus
Section 5.1(b)
Applies

	For Assets owned by WNRL on the Closing Date of the Merger Agreement and acquired by the Partnership pursuant to the Merger Agreement by virtue of its acquisition of WNRL thereunder	  	October 30, 2017	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	Not Applicable	  	No

 2017 Anacortes Assets Contribution Agreement 

 

															
	 Contribution Agreement
	 	 Closing Date
	 	 First

Deadline
 Date
	 	 Second

Deadline
 Date
	 	 Andeavor
Indemnifying
Parties
	 	 Andeavor
Indemnified
Parties
	 	 Third

Deadline
 Date
	 	
Omnibus
Section 5.1(b)
Applies

	Contribution, Conveyance and Assumption Agreement effective as of November 8, 2017, among the Partnership, the Operating Company, TRMC and Andeavor	 	November 8, 2017	 	November 8, 2019	 	November 8, 2022	 	TRMC	 	Not applicable	 	November 8, 2027	 	Yes

 Schedule VIII 

Administrative Fee and Indemnification Deductibles 

Monthly Administrative Fee 
 $1,083,333 

Annual Environmental Deductible 
 $800,000 

Annual ROW Deductible 
 $800,000 

 Schedule IX 

Special Indemnification Provisions 

For Initial Contribution Agreement listed on Schedule VII: 

None. 
 For Amorco Contribution Agreement listed on
Schedule VII: 
 Addition to Right of Way Indemnification. As of the Closing Date for the Amorco Contribution Agreement, TRMC shall own the
leasehold rights in the “Wharf Lease” issued by the California State Lands Commission and the easements, rights of way and permits for the “SHPL,” all as defined in the Amorco Contribution Agreement, and the Partnership Group
shall provide operational, maintenance and management services with respect to such Assets pursuant to the MTUTA. Title to Wharf Lease rights and the SHPL are scheduled to be contributed to the Partnership Group at a later date, as set forth in the
Amorco Contribution Agreement. The Right of Way Indemnification set forth in Section 3.2 herein applies to the extent that a Loss arises with respect to a Partnership Group Member’s interests under the MTUTA before title to such Assets is
contributed to the Partnership Group Member or with respect to a Partnership Group Member’s failure to become the owner of such valid and indefeasible easement rights or fee ownership or leasehold interests in such Assets after they are finally
contributed to the Partnership Group as contemplated in the Amorco Contribution Agreement. The Closing Date provided for in this Agreement shall be as set forth above, without regard to when title to these Assets is finally contributed to a
Partnership Group Member. 
 For Long Beach Contribution Agreement listed on Schedule VII: 

Addition to Right of Way Indemnification. As of the Closing Date for the Long Beach Contribution Agreement, TRMC shall own the leasehold rights in the
“Terminal Lease” issued by the Port of Long Beach and the easements, rights of way and permits for the “Terminal Pipelines,” all as defined in the Long Beach Contribution Agreement, and the Partnership Group shall provide
operational, maintenance and management services with respect to such Assets pursuant to the Long Beach Operating Agreement, as defined in the Long Beach Contribution Agreement. Title to Terminal Lease rights and the Terminal Pipelines are scheduled
to be contributed to the Partnership Group at a later date, as set forth in the Long Beach Contribution Agreement. The Right of Way Indemnification set forth in Section 3.2 herein applies to the extent that a Loss arises with respect to a
Partnership Group Member’s interests under the BAUTA before title to such Assets is contributed to the Partnership Group Member or with respect to a Partnership Group Member’s failure to become the owner of such valid and indefeasible
easement rights or fee ownership or leasehold interests in such Assets after they are finally contributed to the Partnership Group as contemplated in the Long Beach Contribution Agreement. The Closing Date provided for in this Agreement shall be as
set forth above, without regard to when title to these Assets is finally contributed to a Partnership Group Member. 

 For Anacortes Rail Facility Contribution Agreement listed on Schedule VII: 

Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the Anacortes Track Use and Throughput Agreement
among the General Partner, the Partnership, the Operating Company and TRMC, (iii) the Anacortes Mutual Track Use Agreement among the General Partner, the Partnership, the Operating Company and TRMC, and (iv) the Ground Lease between TRMC
and the Operating Company, all dated as of November 15, 2012, the parties hereto agree that the indemnification provisions of any of those agreements shall control over any of the other agreements to the extent the subject matter of the
indemnification is specifically referenced or provided for in that agreement. For the avoidance of doubt, the indemnification provisions of the Fourth Amended and Restated Omnibus Agreement shall be subordinate to the respective indemnification
provisions of each of the other agreements referenced above. 
 For BP Carson Tranche 1 Contribution Agreement listed on Schedule VII: 

Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the BP Carson Tranche 1 Contribution Agreement
listed on Schedule VII, (iii) the Master Terminalling Services Agreement – Southern California among TRMC, the General Partner, the Partnership and the Operating Company dated as of June 1, 2013, as amended, and (iv) the
Carson Storage Services Agreement among TRMC, the General Partner, the Partnership and the Operating Company dated as of June 1, 2013, the parties hereto agree that the indemnification provisions of any of those agreements shall control over
any of the other agreements to the extent the subject matter of the indemnification is specifically referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced agreements and the Carson
Assets Indemnity Agreement, the provisions of the Carson Assets Indemnity Agreement shall prevail with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as
set forth in the above-referenced agreements. Notwithstanding anything to the contrary in the Fourth Amended and Restated Omnibus Agreement, the indemnification provisions of Sections 3.2 and 3.5 thereof shall not apply to the Assets as defined in
the BP Carson Tranche 1 Contribution Agreement listed on Schedule VII. 

 For BP Carson Tranche 2 Contribution Agreement listed on Schedule VII: 

Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the BP Carson Tranche 2 Contribution Agreement
listed on Schedule VII, (iii) the Amended and Restated Master Terminalling Services Agreement – Southern California among TRMC, the General Partner, the Partnership and the Operating Company dated as of December 6, 2013, (iv)
the Long Beach Storage Services Agreement among TRMC, the General Partner, the Partnership and the Operating Company dated as of December 6, 2013, (v) the Berth 121 Operating Agreement between the Operating Company and Carson Cogeneration
Company, dated as of December 6, 2013, (vi) the Terminals 2 and 3 Operating Agreement among the Partnership, the General Partner, the Operating Company and TRMC, dated as of December 6, 2013, (vii) the Amended and Restated Long Beach Berth
Access Use and Throughput Agreement among the Partnership, the General Partner, the Operating Company and TRMC, dated as of December 6, 2013, (viii) the Long Beach Berth Throughput Agreement among the Partnership, the General Partner, the
Operating Company, TRMC and Carson Cogeneration Company, dated as of December 6, 2013, (ix) the SoCal Transportation Services Agreement between TRMC and Tesoro SoCal Pipeline Company LLC, dated as of December 6, 2013, (x) the Long Beach
Pipeline Throughput Agreement among the Partnership, the General Partner, the Operating Company and TRMC, dated as of December 6, 2013, (xi) the Carson Coke Handling Services Agreement among the Partnership, the General Partner, the Operating
Company and TRMC, dated as of December 6, 2013, (xii) the Coke Barn Lease Agreement between the Operating Company and TRMC, dated as of December 6, 2013 and (xiii) the Terminals 2 and 3 Ground Lease between the Operating Company and
TRMC, dated as of December 6, 2013, the parties hereto agree that the indemnification provisions of any of those agreements shall control over any of the other agreements to the extent the subject matter of the indemnification is specifically
referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced agreements and the Carson Assets Indemnity Agreement, the provisions of the Carson Assets Indemnity Agreement shall prevail
with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as set forth in the above-referenced agreements. 

 For West Coast Assets Contribution Agreement listed on Schedule VII: 

Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the Terminalling Services Agreement –
Nikiski, among the General Partner, the Partnership, the Operating Company and Tesoro Alaska, (iii) the Terminalling Services Agreement – Anacortes, among the General Partner, the Partnership, the Operating Company and TRMC, (iv) the
Terminalling Services Agreement – Martinez, among the General Partner, the Partnership, the Operating Company and TRMC, and (v) the Storage Services Agreement – Anacortes, the Terminalling Services Agreement – Anacortes, among
the General Partner, the Partnership, the Operating Company and TRMC, the parties hereto agree that the indemnification provisions of any of those agreements shall control over any of the other agreements to the extent the subject matter of the
indemnification is specifically referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced agreements and the Fourth Amended and Restated Omnibus Agreement, the provisions of the Fourth
Amended and Restated Omnibus Agreement shall prevail with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as set forth in the above-referenced agreements.

 For 2015 Line 88 and Carson Tankage Contribution Agreement listed on Schedule VII: 

Other. Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the Carson II Storage Agreement,
and (iii) Amendment No. 1 to the (SoCal) Transportation Services Agreement dated November 12, 2015, between TRMC and Tesoro SoCal Pipeline Company LLC, the parties hereto agree that the indemnification provisions of any of those
agreements shall control over any of the other agreements to the extent the subject matter of the indemnification is specifically referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced
agreements and the Fourth Amended and Restated Omnibus Agreement, the provisions of the Fourth Amended and Restated Omnibus Agreement shall prevail with respect to issues related to the contribution of the assets described therein, but not with
respect to the ordinary operations of such assets as set forth in the above-referenced agreements. 
 For 2016 Alaska Assets Contribution Agreement
listed on Schedule VII: 
 The Partnership Group agree that, after the Effective Date, they shall not knowingly breach any covenants of TAC contained
in that certain Asset Purchase Agreement dated as of November 20, 2015 by and between Flint Hills Resources Alaska, LLC and TAC (the “Flint Hills APA”) as if the Partnership Group were parties thereto instead of TAC. 

Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the Kenai Storage Services Agreement, and
(iii) the Alaska Terminalling Services Agreement, the parties hereto agree that the indemnification provisions of any of those agreements shall control over any of the other agreements to the extent the subject matter of the indemnification is
specifically referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced agreements and the Fourth Amended and Restated Omnibus Agreement, the provisions of the Fourth Amended and Restated
Omnibus Agreement shall prevail with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as set forth in the above-referenced agreements. 

 Notwithstanding any other provisions of the Fourth Amended and Restated Omnibus Agreement, the indemnification
obligations of the Andeavor Entities under Section 3.1(a) of the Fourth Amended and Restated Omnibus Agreement with regard to the 2016 Environmental Consent Decree are limited to reimbursement for any capital expenditures that the Partnership
Group may be required to make to comply therewith and any fines or other penalties which may be levied for any failure therewith (except to the extent such fines or other penalties are the result of the failure of the Partnership Group to comply
therewith with regard to the contributed assets) and such indemnification obligations shall extend to or cover any increased ongoing operating or maintenance expenses incurred by the Partnership Group in connection with their compliance therewith.

 For Martinez Assets Contribution Agreement listed on Schedule VII: 

Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the Martinez Storage Services Agreement, dated as
of November 21 2016, between TRMC and the Operating Company; (iii) the Avon Marine Terminal Operating Agreement, dated as of November 21 2016, between TRMC and the Operating Company; (iv) the License Agreement, dated as of
November 21 2016, between TRMC and the Operating Company; and (v) the Avon Marine Terminal Sublease Agreement and the Avon Marine Terminal Use and Throughput Agreement to be entered into between TRMC and the Operating Company pursuant to
Section 2.5 of the Martinez Assets Contribution Agreement, the parties hereto agree that the indemnification provisions of any of those agreements shall control over any of the other agreements to the extent the subject matter of the
indemnification is specifically referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced agreements and the Fourth Amended and Restated Omnibus Agreement, the provisions of the Fourth
Amended and Restated Omnibus Agreement shall prevail with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as set forth in the above-referenced agreements.

 For Assets owned by WNRL on the Closing Date of the Merger Agreement and acquired by the Partnership pursuant to the Merger Agreement by virtue of
its acquisition of WNRL thereunder: 
 Notwithstanding any other provisions of the Fourth Amended and Restated Omnibus Agreement, the Parties hereto
agree that the indemnification provisions in Article VI of the SERA shall control and prevail over any of the provision of the Fourth Amended and Restated Omnibus Agreement, other than Section 3.5(b), and shall be the exclusive provisions for
all indemnification obligations relating to the subject matter of the indemnities so provided in Article VI of the SERA. 

 For 2017 Anacortes Assets Contribution Agreement listed on Schedule VII: 

1. Notwithstanding any other provisions of (i) the Fourth Amended and Restated Omnibus Agreement, (ii) the Anacortes Storage Services Agreement
– Anacortes II, dated as of November 8, 2017, between TRMC and the Operating Company; (iii) the Anacortes Marine Terminal Operating Agreement, dated as of November 8, 2017, between TRMC and the Operating Company; (iv) the
Pipeline Transportation Services Agreement – Anacortes Short Haul Pipelines dated as of November 8, 2017, between TRMC and the Operating Company, (v) the Ground Lease dated as of November 8, 2017, between TRMC and the Operating
Company with respect to the real property underlying the Tankage; (vi) the Second Amendment dated as of November 8, 2017, to that certain Ground Lease between TRMC and the Operating Company relating to a portion of the Anacortes Refinery
dated as of November 15, 2012, (vii) the First Amendment dated as of November 8, 2017, to that certain Ground Lease between TRMC and the Operating Company relating to a portion of the Anacortes Refinery dated as of July 1, 2014,
(viii) the Sublease Rights and Escrow Agreement between TRMC and the Operating Company dated as of November 8, 2017 and (ix) the Anacortes Marine Terminal Use and Throughput Agreement to be entered into between TRMC and the Operating
Company pursuant to Sublease Rights and Escrow Agreement, the Parties hereto agree that the indemnification provisions of any of those agreements shall control over any of the other agreements to the extent the subject matter of the indemnification
is specifically referenced or provided for in that agreement. In the event of a conflict of provisions of any of the above-referenced agreements and the Fourth Amended and Restated Omnibus Agreement, the provisions of the Fourth Amended and Restated
Omnibus Agreement shall prevail with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as set forth in the above-referenced agreements. 

2. The expenses reimbursable to the Partnership Group for repairs and maintenance of any aboveground storage tanks, included within the Assets conveyed,
contributed or otherwise transferred pursuant to the 2017 Anacortes Contribution Agreement (“2017 Anacortes Storage Tanks”), under Section 5.1(b) of the Fourth Amended and Restated Omnibus Agreement required to bring any of the 2017
Anacortes Storage Tanks into compliance with API Standard 653 shall include the expense of any required earthwork (such as new sandbeds) to restore such storage tanks to active service; provided that such expenses shall not include any expenses for
Covered Environmental Losses, which shall continue to be governed by Section 3.1 of the Fourth Amended and Restated Omnibus Agreement and the provisions of paragraph 3 below. 

3. For any of the 2017 Anacortes Storage Tanks for which the first API 653 internal inspection has not been completed prior to the fifth anniversary of the
applicable Closing Date, the Operating Company shall conduct a detailed review of all available inspection records or other reports applicable to such storage tanks and shall make inspections of the visible external condition of the tanks prior to
such fifth anniversary of the applicable Closing Date. If such review and inspection indicates, in the reasonable judgment of the Operating Company, that there exists a reasonable concern regarding the structural integrity of any such tank, then:

 (a) The Operating Company shall provide written notice of such reasonable concern to TRMC, including a detailed description of the
Operating Company’s reasons for such concern; 

 (b) The Operating Company shall schedule the first API 653 internal inspection of any such tank
at the soonest practical date; and 
 (c) The Identification Deadline with regard to any Covered Environmental Losses caused by any release
from such tank first identified at the time of such first API 653 internal inspection of such tank shall be extended for a period of sixty (60) days following the completion of such first API 653 internal inspection of such tank.EX-10.2

 Exhibit 10.2 

STORAGE SERVICES AGREEMENT – ANACORTES II 

This Storage Services Agreement – Anacortes II (this “Agreement”) is effective as of the Commencement Date (as defined
below), by and between Tesoro Logistics Operations LLC, a Delaware limited liability company (“TLO”), and for purposes of Section 24(a) only, Tesoro Logistics GP, LLC, a Delaware limited liability company
(the “General Partner”), and Andeavor Logistics LP, a Delaware limited partnership (the “Partnership”), on the one hand, and Tesoro Refining & Marketing Company LLC, a Delaware limited liability company
(“Customer”), on the other hand. 
 RECITALS 

WHEREAS, on the date hereof, Customer will contribute certain assets to the General Partner, the General Partner will contribute those
assets to the Partnership and the Partnership will contribute those assets to TLO pursuant to the Contribution, Conveyance and Assumption Agreement dated as of the date hereof (the “Contribution Agreement”); 

WHEREAS, pursuant to the Contribution Agreement, TLO is the owner of the storage facility for crude oil, refinery feedstocks, refined
products and chemicals located in Anacortes, Washington, described in Schedule A (“Storage Facility II”), which includes without limitation the Tanks, Blending Unit, Transfer Pump House and Pipelines defined below; 

WHEREAS, TLO desires to provide storage, handling, blending and other services with respect to crude oil, refinery feedstocks and
refined products owned by Customer and stored at Storage Facility II; 
 WHEREAS, the Tanks at Storage Facility II have an aggregate
Shell Capacity (as defined below) of approximately 3.9 million Barrels (as defined below); 
 WHEREAS, the Parties hereto
entered into that certain Storage Services Agreement – Anacortes, dated July 1, 2014, with regard to different storage facilities at the Refinery other than Storage Facility II, which agreement remains in full force and effect; 

WHEREAS, by virtue of its direct and indirect ownership interests in the Partnership, Customer has an economic interest in the
financial and commercial success of the Partnership and its operating subsidiary, TLO; and 
 WHEREAS, Customer and TLO desire to
enter into this Agreement to memorialize the terms of their commercial relationship related to the subject matter hereof. 
 NOW,
THEREFORE, in consideration of the covenants and obligations contained herein, the Parties (as defined below) to this Agreement hereby agree as follows: 
  

	1.	DEFINITIONS 

 Capitalized terms used throughout this Agreement shall have the meanings
set forth below, unless otherwise specifically defined herein. 
 “Agreement” has the meaning set forth in the Preamble.

  
 1 

 “Andeavor” means Andeavor, a Delaware corporation, and the parent company of
Customer. 
 “Applicable Law” means any applicable statute, law, regulation, ordinance, rule, determination, judgment, rule
of law, order, decree, permit, approval, concession, grant, franchise, license, requirement, or any similar form of decision of, or any provision or condition of any permit, license or other operating authorization issued by any Governmental
Authority having or asserting jurisdiction over the matter or matters in question, whether now or hereafter in effect. 

“ASTM” means ASTM International, formerly known as the American Society for Testing and Materials. 

“Barrel” means a volume equal to 42 U.S. gallons of 231 cubic inches each, at 60 degrees Fahrenheit under one atmosphere of
pressure. 
 “Blending Unit” means the gasoline blending unit at Storage Facility II described in Schedule A. 

“Business Day” means a day, other than a Saturday or Sunday, on which banks in New York, New York are open for the general
transaction of business. 
 “Capacity Resolution” has the meaning set forth in Section 6(b). 

“Commencement Date” means November 8, 2017. 

“Confidential Information” means all confidential, proprietary or non-public
information of a Party, whether set forth in writing, orally or in any other manner, including all non-public information and material of such Party (and of companies with which such Party has entered into
confidentiality agreements) that another Party obtains knowledge of or access to, including non-public information regarding products, processes, business strategies and plans, customer lists, research and
development programs, computer programs, hardware configuration information, technical drawings, algorithms, know-how, formulas, processes, ideas, inventions (whether patentable or not), trade secrets,
schematics and other technical, business, marketing and product development plans, revenues, expenses, earnings projections, forecasts, strategies, and other non-public business, technological, and financial
information. 
 “Contribution Agreement” has the meaning set forth in the Recitals. 

“Control” means the possession, directly or indirectly, of the power to direct or cause the direction of the management and
policies of a Person, whether through ownership of voting securities, by contract, or otherwise. 
 “Customer” has the
meaning set forth in the Preamble. 
 “Customer Group” has the meaning set forth in Section 19(a). 

“Customer Termination Notice” has the meaning set forth in Section 22(b). 

“Extension Period” has the meaning set forth in Section 3. 

“First Offer Period” has the meaning set forth in Section 21(b). 

“Force Majeure” means events or circumstances, whether foreseeable or not, which are not reasonably within the control of TLO
and which, by the exercise of due diligence, TLO is unable to prevent or overcome, that prevent performance of TLO’s obligations or limits Customer’s ability to make 

  
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effective use of the Operating Capacity of Storage Facility II, including: acts of God, strikes, lockouts or other industrial disturbances, wars, riots, fires, floods, storms, orders of
Governmental Authorities, explosions, terrorist acts, breakage, accident to machinery, equipment, storage tanks or lines of pipe, and inability to obtain or unavoidable delays in obtaining material or equipment and similar events, excluding
circumstances due to market conditions. 
 “Force Majeure Notice” has the meaning set forth in Section 22(a). 

“Force Majeure Period” has the meaning set forth in Section 22(a). 

“General Partner” has the meaning set forth in the Preamble. 

“Governmental Authority” means any federal, state, local or foreign government or any provincial, departmental or other
political subdivision thereof, or any entity, body or authority exercising executive, legislative, judicial, regulatory, administrative or other governmental functions or any court, department, commission, board, bureau, agency, instrumentality or
administrative body of any of the foregoing. 
 “Month” means the period commencing on the Commencement Date and ending on
the last day of the calendar month in which service begins and each successive calendar month thereafter. 
 “Omnibus
Agreement” means that certain Fourth Amended and Restated Omnibus Agreement, dated as of October 30, 2017, by and among Andeavor, Customer, Tesoro Companies, Inc., Tesoro Alaska Company LLC, the General Partner and the Partnership, as
such agreement (and the schedules thereto) may be amended, supplemented or restated from time to time. 
 “Operating
Capacity” means the effective storage capacity of a Tank, taking into account accepted engineering principles, industry standards, American Petroleum Institute guidelines and Applicable Laws, only as to Products that such Tank is capable of
storing, within the requirements of applicable permit requirements and under actual conditions as they may exist at any time. 

“Operating Procedures” has the meaning set forth in Section 14(a). 

“Partnership” has the meaning set forth in the Preamble. 

“Partnership Change of Control” means Andeavor ceases to Control the General Partner. 

“Partnership Group” has the meaning set forth in Section 19(b). 

“Party” or “Parties” means that each of Customer and TLO is a “Party” and collectively are the
“Parties” to this Agreement. 
 “Person” means any individual, partnership, limited partnership, joint venture,
corporation, limited liability company, limited liability partnership, trust, unincorporated organization or Governmental Authority or any department or agency thereof. 

“Pipeline” or “Pipelines” means those pipelines within Storage Facility II that connect the Tanks to
one another and to the receiving and delivery flanges of Storage Facility II. 
 “Product” or “Products”
means crude oil, refinery feedstocks, refined products, and other materials stored in the Tanks in the ordinary course of business. 

  
 3 

 “psig” means pound per square inch gauge. 

“Receiving Party Personnel” has the meaning set forth in Section 28(d). 

“Refinery” means Customer’s refinery located in Anacortes, Washington. 

“Related Agreements” means the Transportation Services Agreement (Anacortes Short-Haul Pipelines), the Anacortes Manifest
Rail Terminalling Services Agreement, and the Anacortes Marine Terminal Operating Agreement entered into between Customer and TLO concurrently herewith. 

“Restoration” has the meaning set forth in Section 6(a). 

“Right of First Refusal” has the meaning set forth in Section 21(b). 

“Secondment Agreement” shall mean the First Amended and Restated Secondment and Logistics Services Agreement dated as of
October 30, 2017, as amended, and related service orders. 
 “Shell Capacity” means the gross storage capacity of a
Tank, based upon its dimensions, as set forth for each Tank on Schedule B attached hereto and in applicable Terminal Service Orders. 

“Storage Facility II” has the meaning set forth in the Recitals. 

“Storage Services Fee” has the meaning set forth in Section 4(a). 

“Subcontractor Customer” has the meaning set forth in Section 24(c). 

“Surcharge” has the meaning set forth in Section 7(b)(i). 

“Tank Heels” consist of the minimum quantity of Product which either (a) must remain in a Tank during all periods when
the Tank is available for service to keep the Tank in regulatory compliance or (b) is necessary for physical operation of the Tank.

“Tanks” mean the tanks owned by TLO and listed on Schedule B attached hereto, each of which is used for the storage of
Products and located at Storage Facility II. 
 “Term” and “Initial Term” each have the meaning set forth
in Section 3. 
 “Terminal Service Order” has the meaning set forth in Section 5(a). 

“Termination Notice” has the meaning set forth in Section 22(a). 

“TLO” has the meaning set forth in the Preamble. 
  

	2.	STORAGE COMMITMENT 

 (a) Commitment. During the Term of this Agreement and subject
to the terms and conditions of this Agreement and the effective Operating Capacity of each Tank and Storage Facility II as a whole, TLO shall, as applicable, store Products tendered by Customer at Storage Facility II. 

  
 4 

 (b) Dedicated Storage. The Tanks shall be dedicated and used exclusively for the storage
of Customer’s Products or Products of approved Subcontractor Customers. Customer shall be responsible for maintaining all Tank Heels required for operation of the Tanks. Tank Heels cannot be withdrawn from any Tank without prior approval of
TLO. 
  

	3.	TERM 

 (a) The initial term of this Agreement shall commence on the Commencement Date and
shall continue through November 7, 2027 (the “Initial Term”); provided, however, that Customer may, at its option, extend the Initial Term for up to two (2) renewal terms of five (5) years each (each, an
“Extension Period”) by providing written notice of its intent to TLO no less than three hundred sixty-five (365) calendar days prior to the end of the Initial Term or the then-current Extension Period. 

(b) If Customer has not provided written notice of its intent to extend the Initial Term for the first Extension Period pursuant to clause
(a) above, TLO may, at its option, provide written notice to Customer no less than ninety (90) days prior to the end of the Initial Term to extend the Initial Term for an additional two (2) years. 

(c) The Initial Term, and any Extension Period shall be referred to herein as the “Term.” Without limitation on the
provisions of Section 21, upon expiration of the Term the parties shall meet and use good faith efforts to reach agreement (without any obligation on the part of either party to reach such agreement) regarding a new
agreement for storage services at Storage Facility II. 
  

	4.	STORAGE SERVICES FEE 

 (a) Customer shall pay a Monthly fee (the “Storage
Services Fee”) to TLO to reserve, on a firm basis, all of the existing aggregate Shell Capacity of all of the Tanks in Storage Facility II and to compensate TLO for the services performed by TLO under this Agreement. Such fee shall be
payable by Customer on a Monthly basis throughout the Term of this Agreement, regardless of the actual volumes of Products stored by TLO on behalf of Customer. The Parties recognize that the existing Operating Capacity of certain Tanks may be less
than the Shell Capacity of such Tanks, but the Parties acknowledge and agree that the Storage Services Fee shall be set in terms of a dollar-per-Barrel per Month rate
based on Shell Capacity in the applicable Terminal Service Order. The Storage Services Fee shall be calculated using the per Barrel rate set forth on the Terminal Service Orders executed effective as of the Commencement Date for the then-existing
aggregate Shell Capacity of all of the Tanks in Storage Facility II. The Storage Services Fee owed for any partial Month during the Term shall be prorated in accordance with the ratio of (i) the number of days in such Month during which this
Agreement is effective to (ii) the total number of days in such Month. 
  

	5.	TERMINAL SERVICE ORDERS 

 (a) Description. TLO and Customer shall enter into the
Terminal Service Orders referred to in Section 5(b) and may enter into additional terminal service orders substantially in the form attached hereto as Exhibit 1 (each, a “Terminal Service Order”). Upon a request by
Customer pursuant to this Agreement or as deemed necessary or appropriate by TLO in connection with the services to be delivered pursuant hereto, TLO shall generate a Terminal Service Order to set forth the specific terms and conditions for
providing the applicable services described therein and the applicable fees to be charged for such services. No Terminal Service Order shall be effective until fully executed by both TLO and Customer. 

  
 5 

 (b) Included Items. Items available for inclusion on a Terminal Service Order include, but
are not limited to, the following: 
 (i) the Shell Capacity of each Tank; 

(ii) the Storage Services Fee pursuant to Section 4; 

(iii) any reimbursement pursuant to Section 7(a); 

(iv) any Surcharge pursuant to Section 7(b); 

(v) any modification, cleaning, or conversion of a Tank as requested by Customer pursuant to Section 8(a); 

(vi) any reimbursement related to newly imposed taxes and regulations pursuant to Section 9; 

(vii) any steam services pursuant to Section 15(a); 

(vii) any oily water removal pursuant to Section 15(b); and 

(ix) any other services that may be agreed upon by the Parties. 

(c) Fee Increases. Any fees of a fixed amount set forth in this Agreement and any Terminal Service Order shall be increased on
July 1 of each year of the Term, commencing on July 1, 2018, by a percentage equal to the greater of zero or the positive change, if any, in the CPI-U (All Urban Consumers) for the prior
calendar year, as reported by the Bureau of Labor Statistics, and rounded to the nearest one-tenth (1/10) of one percent (1%). 

(d) Conflicts. In case of any conflict between the terms of this Agreement and the terms of any Terminal Service Order, the terms of
the applicable Terminal Service Order shall govern. 
  

	6.	CAPABILITIES OF FACILITIES 

 (a) Maintenance and Repair. Subject to Force Majeure
and interruptions for routine repair and maintenance, consistent with customary terminal industry standards, TLO shall maintain each Tank and the Pipelines in a condition and with a capacity sufficient to store and handle a volume of Customer’s
Products at least equal to the current Operating Capacity for Storage Facility II as a whole. TLO’s obligations may be temporarily suspended during the occurrence of, and for the entire duration of, a Force Majeure or other interruption of
service, to the extent such Force Majeure or other interruption of service impairs TLO’s ability to perform such obligations. If for any reason, including, without limitation, a Force Majeure event, the condition of any Tanks and/or associated
Pipelines is below the level necessary for TLO to store and handle a volume of Customer’s Products at least equal to the current Operating Capacity for such Tanks and/or associated Pipelines, then within a reasonable period of time thereafter,
TLO shall make repairs to restore the capacity of such Tank and/or associated Pipeline(s) to ensure service at the current Operating Capacity (“Restoration”). Except as provided below in Section 6(b), all of such Restoration
shall be at TLO’s cost and expense unless the damage creating the need for such repairs was caused by the negligence or willful misconduct of Customer, its employees, agents or customers. (If Customer directly incurs any such costs and expenses
for which TLO is responsible with regard to the Tanks, TLO shall reimburse Customer for such costs and expenses.) Notwithstanding the foregoing, TLO shall schedule maintenance to minimize the opportunity cost and disruption to

  
 6 

 
Customer’s business and shall minimize the number of Tanks taken out of service during any such scheduled maintenance. Prior to January 1 of each year of the Term of this Agreement, the
Parties shall mutually agree upon the maintenance plan and schedule for the Tanks for the following calendar year (e.g., prior to January 1, 2019, the Parties shall mutually agree on such plan and schedule for 2020). 

(b) Capacity Resolution. In the event of the failure of TLO to maintain any Pipeline or Tank in a condition and with a capacity
sufficient to store and handle a volume of Customer’s Products equal to its current Operating Capacity, then either Party shall have the right to call a meeting between executives of both Parties by providing at least two (2) Business
Days’ advance written notice. Any such meeting shall be held at a mutually agreeable location and will be attended by executives of both Parties each having sufficient authority to commit his or her respective Party to a Capacity Resolution (as
defined below). At the meeting, the Parties will negotiate in good faith with the objective of reaching a joint resolution for the Restoration of capacity of the Tank and/or its associated Pipeline(s) which will, among other things, specify steps to
be taken by TLO to fully accomplish Restoration and the deadlines by which the Restoration must be completed (the “Capacity Resolution”). Without limiting the generality of the foregoing, the Capacity Resolution shall set forth an
agreed upon time schedule for the Restoration activities. Such time schedule shall be reasonable under the circumstances, consistent with customary terminal industry standards and shall take into consideration TLO’s economic considerations
relating to costs of the repairs and Customer’s requirements concerning its refining and marketing operations. TLO shall use commercially reasonable efforts to continue to provide storage of Customer’s Products at Storage Facility II, to
the extent Storage Facility II has the capability of doing so, during the period before Restoration is completed. In the event that Customer’s economic considerations justify incurring additional costs to restore the Tank and/or associated
Pipeline(s) in a more expedited manner than the time schedule determined in accordance with the preceding sentences, Customer may require TLO to expedite the Restoration to the extent reasonably possible, subject to Customer’s payment upon the
occurrence of mutually agreed upon milestones in the Restoration process. In the event that a Tank is taken out of service or the Operating Capacity of a Tank is reduced, and the Parties agree that the Restoration of such Tank to its full Operating
Capacity is not justified under the standards set forth in the preceding sentences, then the Parties shall negotiate an appropriate adjustment to the Storage Services Fee to account for the reduced Operating Capacity available for Customer’s
use. In the event the Parties agree to an expedited Restoration plan in which Customer agrees to pay the Restoration costs based on milestone payments or if the Parties agree to a reduced Storage Services Fee, then neither Party shall have the right
to terminate this Agreement or any applicable Terminal Service Order pursuant to Section 23 below, so long as any such Restoration is completed with due diligence. 

(c) Customer’s Right To Cure. If at any time after the occurrence of (x) a Partnership Change of Control or (y) a sale
of the Refinery, TLO either (i) refuses or fails to meet with Customer within the period set forth in Section 6(b), (ii) fails to agree to perform a Capacity Resolution in accordance with the standards set forth in Section 6(b), or
(iii) fails to perform its obligations in compliance with the terms of a Capacity Resolution, Customer may, as its sole remedy for any breach by TLO of any of its obligations under Section 6(b), require TLO to complete a Restoration of the
affected Pipeline or Tank, and the Storage Services Fee shall be reduced, as described in Section 6(b) above, to account for the reduced Operating Capacity available for Customer’s use until such Restoration is completed. Any such
Restoration required under this Section 6(c) shall be completed by TLO at Customer’s cost. TLO shall use commercially reasonable efforts to continue to provide storage and throughput of Customer’s Products at the affected Tank or
Pipeline while such Restoration is being completed. Any work performed by TLO pursuant to this Section 6(c) shall be performed and completed in a good and workmanlike manner consistent with applicable pipeline industry standards and in
accordance with Applicable Law. Additionally, during such period after the occurrence of (x) a Partnership Change of Control or (y) a sale of the Refinery, Customer may exercise any remedies available to it under this Agreement or any
Terminal Service Order (other than termination), including the right to immediately seek temporary and permanent injunctive relief for specific performance by TLO of the applicable provisions of this Agreement or any Terminal Service Order,
including, without limitation, the obligation to make Restorations as described herein. 

  
 7 

 (d) Existing Contractors. TLO may continue to utilize labor, equipment, materials and
supplies provided by contractors under their existing service agreements with Customer to perform work to be performed by TLO hereunder, without the requirement that such existing contracts be amended, assigned or replaced. Such contracts with
Customer may continue to cover the work to be provided by TLO hereunder, as provided under Section 4(a) of the Secondment Agreement, and TLO shall be responsible for the costs and expenses of such work performed by such contractors pursuant to
those provisions of the Secondment Agreement. 
  

	7.	REIMBURSEMENT; SURCHARGES 

 (a) Reimbursement. Customer shall reimburse TLO for
all of the following: (i) the actual cost of any expenditures that TLO agrees to make upon Customer’s request, and (ii) any cleaning, degassing or other preparation of the Tanks at the expiration of this Agreement. The means of paying
such reimbursement for item (i) above shall be set forth in a Terminal Service Order, and may include direct reimbursement, either before or after TLO incurs such expenditures or an additional ongoing fee to reimburse TLO for its expenditures.

 (b) Surcharges. 

(i) If, during the Term, any existing laws or regulations are changed or any new laws or regulations are enacted (other than
with respect to taxes and those matters that are addressed in Section 9) that require TLO to make substantial and unanticipated expenditures (whether capitalized or otherwise) with respect to Storage Facility II or with respect to the services
provided hereunder, TLO may, subject to the terms of this Section 7(b), impose a surcharge to increase the applicable service fee (a “Surcharge”) to cover Customer’s pro rata share of the cost of complying with these laws
or regulations, based upon the percentage of Customer’s use of the services or facilities impacted by such new laws or regulations. 

(ii) TLO shall notify Customer of any proposed Surcharge to be imposed pursuant to Section 7(b)(i) sufficient to cover the
cost of any required capital projects and any ongoing increased operating costs. TLO and Customer then shall negotiate in good faith for up to thirty (30) days to mutually determine the effect of the change in law or regulation or new law or
regulation, the cost thereof, and how such cost shall be amortized at an interest rate of no more than LIBOR plus six percent (LIBOR + 6%) as a Surcharge, with the understanding that TLO and Customer shall use their reasonable commercial efforts to
mitigate the impact of, and comply with, these laws and regulations. Without limiting the foregoing, if expenditures requiring a Surcharge may be avoided or reduced through changes in operations, then the Parties shall negotiate in good faith
to set forth the appropriate changes to Operating Capacities or other performance standards set forth in a Terminal Service Order to evidence the reduction of the amount of a Surcharge while leaving the Parties in the same relative economic position
they held before the laws or regulations were changed or enacted. 
 (iii) In the event any Surcharge results in less than a
fifteen percent (15%) increase in the applicable service fee, Customer will be assessed such Surcharge on all future invoices during the period in which such Surcharge is in effect for the applicable amortization period, and TLO shall not terminate
the affected service from this Agreement. 

  
 8 

 (iv) In the event any Surcharge results in a fifteen percent (15%) or more
increase in the applicable service fee, TLO shall notify Customer of the amount of the Monthly Surcharge required to reimburse TLO for its costs, plus carrying costs, together with reasonable supporting detail for the nature and amount of any such
Surcharge. 
 (A) If within thirty (30) days of such notification provided in Section 7(b)(iv), Customer does not
agree to pay such Surcharge or to reimburse TLO up front for its costs, TLO may elect to either: 
 (1) require Customer to
pay such Surcharge, up to a fifteen percent (15%) increase in the applicable service fee; or 
 (2) terminate the Tank(s) or
other facilities from this Agreement upon notice to Customer. 
 (B) TLO’s performance obligations under this Agreement
shall be suspended or reduced during the above thirty (30)-day period to the extent that TLO would be obligated to make such expenditures to continue performance during such period. 

(v) Following a resolution with respect to the amount and manner of payment of a Surcharge pursuant to this Section 7, the
Parties shall execute an appropriate Terminal Service Order memorializing the terms of such resolution. 
 (vi) In lieu of
paying the Surcharge in connection with any required capital project, Customer may, at its option, elect to pay the full cost of the substantial and unanticipated expenditures upon completion of a project. 

 

	8.	TANK MODIFICATION, REPAIR AND CLEANING; REMOVAL OF PRODUCT 

 (a) Tank
Modifications. Each of the Tanks shall be used for its historical service, provided however, that Customer may request that a Tank be changed for storage of a different grade or type of Product. In such an instance, TLO shall agree to a change
in such service, if the same can be accomplished in accordance with reasonable commercial standards, accepted industry and engineering guidelines, permit requirements and Applicable Law. If any such modifications, improvements, vapor recovery,
cleaning, degassing, or other preparation of the tanks is performed by TLO at the request of Customer, Customer shall bear all direct costs attributable thereto, including, without limitation, the cost of removal, processing, transportation, and
disposal of all waste and the cost of any taxes or mutually agreed charges TLO may be required to pay in regard to such waste (subject to subparagraph (c) below), which costs shall be set forth on the applicable Terminal Service Order. TLO may
require Customer to pay all such amounts prior to commencement of any remodeling work on the Tanks, or by mutual agreement, the Parties may agree upon an increase in the Storage Services Fee to reimburse TLO for its costs of such modifications, plus
a reasonable return on capital. All of such costs associated with Tank modifications shall be documented by a Terminal Service Order to be executed by the Parties. 

(b) Responsibility for Fees. Should TLO take any of the Tanks out of service for regulatory requirements, repair, or maintenance,
Customer shall be solely responsible for any alternative storage or Product movements as required and all third-party fees associated with such movements that are not within Storage Facility II, and Customer shall be responsible to TLO for any
Storage Services Fees for any Tanks taken out of service during the period that such Tank is out of service. 

  
 9 

 (c) Removal of Product. Materials stored in or removed from any Storage Facility II shall
at all times remain owned by Customer or any applicable Subcontractor Customer, and the owner of the Product shall always remain responsible for, at the owner’s sole cost, receiving custody of all of its materials to be removed from Storage
Facility II, making appropriate arrangements to receive custody at Storage Facility II in a manner acceptable to TLO, and disposal of such material after custody is returned to the owner. Customer shall be responsible for any fees and costs
associated with the disposal of hazardous waste (unless caused by TLO’s negligence). TLO shall have no obligations regarding disposition of such materials, other than to return custody to the owner at Storage Facility II. 

 

	9.	NEWLY IMPOSED TAXES AND REGULATIONS 

 Customer shall promptly reimburse TLO for any newly
imposed taxes, levies, royalties, assessments, licenses, fees, charges, surcharges and sums due of any nature whatsoever (other than income taxes, gross receipt taxes and similar taxes) by any federal, state or local government or agency that TLO
incurs on Customer’s behalf for the services provided by TLO under this Agreement or any applicable Terminal Service Order. If TLO is required to pay any of the foregoing, Customer shall promptly reimburse TLO in accordance with the payment
terms set forth in this Agreement. Any such newly imposed taxes shall be specified in an applicable Terminal Service Order. 
  

	10.	PAYMENTS 

 TLO shall invoice Customer on a Monthly basis, and Customer shall pay all
amounts due under this Agreement and any Terminal Service Order no later than ten (10) days after Customer’s receipt of TLO’s invoice. Any past due payments owed by Customer shall accrue interest, payable on demand, at the lesser of
(i) the rate of interest announced publicly by JPMorgan Chase Bank, in New York, New York, as JPMorgan Chase Bank’s prime rate (which Parties acknowledge and agree is announced by such bank and used by the Parties for reference purposes
only and may not represent the lowest or best rate available to any of the customers of such bank or the Parties), plus four percent (4%), and (ii) the highest rate of interest (if any) permitted by Applicable Law, from the due date of
the payment through the actual date of payment.  
  

	11.	SCHEDULING 

 All scheduling of delivery into and redelivery out of the Tanks shall be
decided by mutual agreement of the Parties. Customer shall identify to TLO prior to the delivery of any Product to Storage Facility II, the specific Tanks to be used for receiving and storing such Product. 

 

	12.	SERVICES; VOLUME LOSSES; MEASUREMENT 

 (a) Services. The services provided by TLO
pursuant to this Agreement or any applicable Terminal Service Order shall consist of storage, pumping, blending and trans-shipment of the Products at or through the Tanks. 

(b) Measurement and Volume Loss Control Practices. 

(i) TLO shall have no obligation to measure volume gains and losses. In the event third-party Products are stored at Storage
Facility II, the Parties shall mutually determine the measurement and volume loss control practices for Storage Facility II.  

  
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 (ii) Subject to Section 18(b), TLO shall be responsible to Customer only for
Product losses and/or shortages resulting from the negligent or wrongful acts and omissions of TLO; provided that TLO shall not be responsible to Customer for any Product losses and/or shortages for which Customer is compensated by its
cargo/inventory insurance carrier, including through the cargo/inventory insurance coverage required by Section 26. If Customer fails to maintain the cargo/inventory insurance coverage required by Section 26, then TLO shall also not be
responsible to Customer for any Product losses and/or shortages to the extent Customer would have been compensated by its insurance carrier had Customer maintained the cargo/inventory insurance coverage required by Section 26. 

(iii) Customer shall be responsible for all Product losses and/or shortages it may suffer other than those covered by
Section 12(b)(ii). 
 (c) Pipeline Measurement. All quantities of Products received and delivered by pipeline shall be measured
and determined based upon the meter readings of the pipeline operator, as reflected by delivery tickets, or if such meters are unavailable, by applicable calibration tables. All quantities shall be adjusted to net gallons at 60° F in accordance
with ASTM D-1250 Petroleum Measurement Tables, or latest revisions thereof. Meters and temperature probes shall be calibrated according to applicable API standards. Customer shall have the right, at its sole
expense, and in accordance with applicable procedure, to independently certify such calibration. 
 (d) Storage Tank Measurement.
Storage Tank gauging shall be performed by TLO’s personnel. Customer may perform joint gauging at its sole expense with TLO’s personnel at the time of delivery or receipt of Product, to verify the amount involved. If Customer requests an
independent gauger, such gauger must be acceptable to TLO and such gauging shall be at Customer’s sole expense. 
  

	13.	CUSTODY TRANSFER AND TITLE 

 TLO shall be deemed to have custody of the Products after
they enter TLO’s facilities at the Refinery until such time as the Products exit TLO’s facilities at the Refinery and are delivered by TLO to Customer at the Refinery pursuant to this Agreement or pursuant to the Related Agreements. Upon re-delivery of any Product to Customer’s account, Customer shall become solely responsible for any loss, damage or injury to Person or property or the environment, arising out of transportation, possession or
use of such Product after transfer of custody. Title to all of Customer’s Products received in Storage Facility II shall remain with Customer at all times. Both Parties acknowledge that this Agreement and any Terminal Service Order
represent a bailment of Products by Customer to TLO and not a consignment of Products, it being understood that TLO has no authority hereunder to sell or seek purchasers for the Products of Customer. Customer hereby warrants that it shall have good
title to and the right to deliver, store and receive Products pursuant to the terms of this Agreement or any applicable Terminal Service Order. Customer acknowledges that, notwithstanding anything to the contrary contained in this Agreement or in
any Terminal Service Order, Customer acquires no right, title or interest in or to Storage Facility II), except the right to receive, deliver and store the Products in the Tanks. TLO shall retain control of Storage Facility II. 

 

	14.	OPERATING PROCEDURES; SERVICE INTERRUPTIONS 

 (a) Operating Procedures for
Customer. Customer hereby agrees to strictly abide by any and all procedures established by TLO, if any (the “Operating Procedures”), relating to the operation and use of Storage Facility II (including the Tanks) and the
Pipelines that generally apply to receipt, delivery, storage, and movement of Products at Storage Facility II. TLO shall provide Customer with a current copy of its Operating Procedures, if any, and shall provide Customer with thirty
(30) days’ prior written notice of any changes to the Operating Procedures, unless a shorter implementation of such revised Operating Procedures is required by Applicable Law or emergency conditions. Customer shall have the

  
 11 

 
right to approve any material revisions to the Operating Procedures, which shall not be unreasonably withheld, prior to their becoming effective, unless otherwise required under Applicable Law or
emergency conditions, and the material revisions shall be reflected in a Terminal Service Order between the Parties. 
 (b) Operating
Procedures for TLO. TLO shall carry out the handling of the Products at Storage Facility II, the Tanks, and the Pipelines in accordance with any Operating Procedures. 

(c) Service Interruptions. TLO shall use reasonable commercial efforts to minimize the interruption of service at each Tank and/or any
of the associated Pipeline(s). TLO shall promptly inform Customer’s operational personnel of any anticipated partial or complete interruption of service at any Tank and/or associated Pipelines, including relevant information about the nature,
extent, cause and expected duration of the interruption and the actions TLO is taking to resume full operations, provided that TLO shall not have any liability for any failure to notify, or delay in notifying, Customer of any such matters except to
the extent Customer has been materially prejudiced or damaged by such failure or delay. 
 (d) In connection with TLO’s maintenance and
operation of each Tank and/or any of the associated Pipeline(s), Customer shall grant TLO reasonable commercial use of additional designated sites at the Refinery as may be required for (i) storage of spare parts, pipes, pumps and other
equipment; (ii) a laydown yard for construction activities in the event of any major repair or replacement of a Tank; or (iii) any additional commercially reasonable storage requirement. Notwithstanding the foregoing, Customer shall
retain the right to designate where and when any sites can be used by TLO for such additional storage facilities and TLO’s use of such sites shall not interfere with Customer’s normal operation of the Refinery. 

 

	15.	STEAM SERVICES; REMOVAL OF OILY WATER 

 (a) Steam Services. Customer, at its sole
cost and expense, shall provide TLO steam for Storage Facility II, measuring 1200 psig at 1500 ° F, pursuant to an applicable Terminal Service Order. 

(b) Removal of Oily Water. Customer, at its sole cost and expense, shall provide TLO such services for oily water removal as may be set
forth in an applicable Terminal Service Order. 
  

	16.	LIENS 

 TLO hereby waives, relinquishes and releases any and all liens, including without
limitation, any and all warehouseman’s liens, custodian’s liens, rights of retention and/or similar rights under all applicable laws, which TLO would or might otherwise have under or with respect to all Products stored or handled
hereunder. TLO further agrees to furnish documents reasonably acceptable to Customer and its lender(s) (if applicable), and to cooperate with Customer in assuring and demonstrating that Product titled in Customer’s name shall not be subject to
any lien on Storage Facility II or TLO’s Product stored there. 
  

	17.	COMPLIANCE WITH LAW AND GOVERNMENT REGULATIONS 

 (a) Compliance With Law. None of
the Products covered by this Agreement or any Terminal Service Order shall be derived from any Product which was produced or withdrawn from storage in violation of any federal, state or other governmental law, nor in violation of any rule,
regulation or promulgated by any governmental agency having jurisdiction. 
 (b) Licenses and Permits. TLO shall maintain all
necessary licenses and permits for the storage of Products at Storage Facility II. 

  
 12 

 (c) Applicable Law. The Parties are entering into this Agreement and any Terminal Service
Order in reliance upon and shall fully comply with all Applicable Law which directly or indirectly affects the Products hereunder, or any receipt, throughput delivery, transportation, handling or storage of Products hereunder or the ownership,
operation or condition of Storage Facility II. Each Party shall be responsible for compliance with all Applicable Laws associated with such Party’s respective performance hereunder and the operation of such Party’s facilities. In the event
any action or obligation imposed upon a Party under this Agreement and any Terminal Service Order shall at any time be in conflict with any requirement of Applicable Law, then this Agreement and any Terminal Service Order, shall immediately be
modified to conform the action or obligation so adversely affected to the requirements of the Applicable Law, and all other provisions of this Agreement and any Terminal Service Order shall remain effective. 

(d) New Or Changed Applicable Law. If during the Term, any new Applicable Law becomes effective or any existing Applicable Law or its
interpretation is materially changed, which change is not addressed by another provision of this Agreement or any Terminal Service Order and which has a material adverse economic impact upon a Party, then either Party, acting in good faith, shall
have the option to request renegotiation of the relevant provisions of this Agreement or any Terminal Service Order with respect to future performance. The Parties shall then meet and negotiate in good faith amendments to this Agreement or to an
applicable Terminal Service Order that will conform to the new Applicable Law while preserving the Parties’ economic, operational, commercial and competitive arrangements in accordance with the understandings set forth herein. 

 

	18.	LIMITATION ON LIABILITY; WARRANTIES 

 (a) No Special Damages. IN NO EVENT SHALL A
PARTY BE LIABLE TO THE OTHER PARTY FOR ANY LOST PROFITS OR INDIRECT, SPECIAL, INCIDENTAL, CONSEQUENTIAL OR PUNITIVE DAMAGES, NO MATTER HOW CHARACTERIZED, RELATING TO THIS AGREEMENT AND ARISING FROM ANY CAUSE WHATSOEVER, EXCEPT WITH RESPECT TO
INDIRECT, SPECIAL, INCIDENTAL, CONSEQUENTIAL OR PUNITIVE DAMAGES ACTUALLY AWARDED TO A THIRD PARTY OR ASSESSED BY A GOVERNMENTAL AUTHORITY AND FOR WHICH A PARTY IS PROPERLY ENTITLED TO INDEMNIFICATION FROM THE OTHER PARTY PURSUANT TO THE EXPRESS
PROVISIONS OF THIS AGREEMENT. 
 (b) Claims and Liability for Lost Product. TLO shall not be liable to Customer for lost or
damaged Product unless Customer notifies TLO in writing within ninety (90) days of the report of any incident or the date Customer learns of any such loss or damage to the Product. TLO’s maximum liability to Customer for any lost or
damaged Product shall be limited to (i) the lesser of (1) the replacement value of the Product at the time of the incident based upon the price as posted by Platts or similar publication for similar Product in the same locality, and if no
other similar Product is in the locality, then in the state, or (2) the actual cost paid for the Product by Customer (copies of Customer’s invoices of cost paid must be provided), less (ii) the salvage value, if any, of the damaged
Product. 
 (c) No Guarantees or Warranties. Except as expressly provided in this Agreement, neither Customer nor TLO makes any
guarantees or warranties of any kind, expressed or implied. TLO specifically disclaims all implied warranties of any kind or nature, including any implied warranty of merchantability and/or any implied warranty of fitness for a particular purpose.

  
 13 

	19.	INDEMNIFICATION 

 (a) TLO Indemnities. Notwithstanding anything else contained in
this Agreement or any Terminal Service Order, TLO shall release, defend, protect, indemnify, and hold harmless Customer, its carriers, and each of its and their respective affiliates, officers, directors, employees, agents, contractors, successors,
and assigns (excluding any member of the Partnership Group) (collectively the “Customer Group”), from and against any and all demands, claims (including third-party claims), losses, costs, suits, or causes of action (including, but
not limited to, any judgments, losses, liabilities, fines, penalties, expenses, interest, reasonable legal fees, costs of suit, and damages, whether in law or equity and whether in contract, tort, or otherwise) for or relating to (i) personal
or bodily injury to, or death of the employees of Customer, TLO or the General Partner, and, as applicable, their carriers, customers, representatives, and agents, (ii) loss of or damage to any property, products, material, and/or equipment
belonging to Customer, TLO and, as applicable, their carriers, customers, representatives, and agents, and each of their respective affiliates, contractors, and subcontractors (except for those volume losses of Products provided for herein), (iii)
loss of or damage to any other property, products, material, and/or equipment of any other description (except for those volume losses of Products provided for herein), and/or personal or bodily injury to, or death of any other Person or Persons;
and with respect to clauses (i) through (iii) above, which is caused by or resulting in whole or in part from the negligent or wrongful acts or omissions of TLO or the General Partner in connection with the ownership or operation of the
Pipelines or Storage Facility II and the services provided hereunder, and, as applicable, their carriers, customers (other than Customer), representatives, and agents, or those of their respective employees with respect to such matters, and
(iv) any losses incurred by the Customer Group due to violations of this Agreement or any Terminal Service Order by TLO, or, as applicable, its customers (other than Customer), representatives, and agents; PROVIDED THAT TLO SHALL
NOT BE OBLIGATED TO RELEASE, INDEMNIFY OR HOLD HARMLESS CUSTOMER OR ANY MEMBER OF THE CUSTOMER GROUP FROM AND AGAINST ANY CLAIMS TO THE EXTENT THEY RESULT FROM THE BREACH OF CONTRACT, STRICT LIABILITY OR THE NEGLIGENT ACTS, ERRORS, OMISSIONS OR
WILLFUL MISCONDUCT OF CUSTOMER OR ANY MEMBER OF THE CUSTOMER GROUP. 
 (b) Customer Indemnities. Notwithstanding anything else
contained in this Agreement or any Terminal Service Order, Customer shall release, defend, protect, indemnify, and hold harmless TLO, General Partner, the Partnership, their subsidiaries and their respective officers, directors, members, managers,
employees, agents, contractors, successors, and assigns (collectively the “Partnership Group”) from and against any and all demands, claims (including third-party claims), losses, costs, suits, or causes of action (including, but
not limited to, any judgments, losses, liabilities, fines, penalties, expenses, interest, reasonable legal fees, costs of suit, and damages, whether in law or equity and whether in contract, tort, or otherwise) for or relating to (i) personal
or bodily injury to, or death of the employees of TLO, the General Partner, Customer, and, as applicable, their carriers, customers, representatives, and agents; (ii) loss of or damage to any property, products, material, and/or equipment
belonging to TLO, Customer, and, as applicable, their carriers, customers, representatives, and agents, and each of their respective affiliates, contractors, and subcontractors (except for those volume losses of Products provided for herein); (iii)
loss of or damage to any other property, products, material, and/or equipment of any other description (except for those volume losses of Products provided for herein), and/or personal or bodily injury to, or death of any other Person or Persons;
and with respect to clauses (i) through (iii) above, which is caused by or resulting in whole or in part from the negligent or wrongful acts or omissions of Customer, in connection with Customer’s use of the Pipelines or Storage Facility
II and the services provided hereunder and Customer’s Products stored hereunder, and, as applicable, its carriers, customers, representatives, and agents, or those of their respective employees with respect to such matters; and (iv) any
losses incurred by the Partnership Group due to violations of this Agreement or any Terminal Service Order by Customer, or, as applicable, its carriers, customers, representatives, and agents; PROVIDED THAT CUSTOMER SHALL NOT BE
OBLIGATED TO RELEASE, INDEMNIFY OR HOLD HARMLESS TLO OR ANY MEMBER OF THE PARTNERSHIP GROUP FROM AND AGAINST ANY CLAIMS TO THE EXTENT THEY RESULT FROM THE BREACH OF CONTRACT, STRICT LIABILITY OR THE NEGLIGENT ACTS, ERRORS, OMISSIONS OR WILLFUL
MISCONDUCT OF TLO OR ANY MEMBER OF THE PARTNERSHIP GROUP. 

  
 14 

 (c) Written Claim. Neither Party shall be obligated to indemnify the other Party or be
liable to the other Party unless a written claim for indemnity is delivered to the other Party within ninety (90) days after the date that a claim is reported or discovered, whichever is earlier. 

(d) No Limitation. Except as expressly provided otherwise in Section 18, the scope of these indemnity provisions may not be
altered, restricted, limited, or changed by any other provision of this Agreement. The indemnity obligations of the Parties as set out in this Section 19 are independent of any insurance requirements as set out in Section 26, and such
indemnity obligations shall not be lessened or extinguished by reason of a Party’s failure to obtain the required insurance coverages or by any defenses asserted by a Party’s insurers. 

(e) Survival. These indemnity obligations shall survive the termination of this Agreement until all applicable statutes of limitation
have run regarding any claims that could be made with respect to the activities contemplated by this Agreement. 
 (f) Mutual and Express
Acknowledgement. THE INDEMNIFICATION PROVISIONS PROVIDED FOR IN THIS AGREEMENT HAVE BEEN EXPRESSLY NEGOTIATED IN EVERY DETAIL, ARE INTENDED TO BE GIVEN FULL AND LITERAL EFFECT, AND SHALL BE APPLICABLE WHETHER OR NOT THE LIABILITIES, OBLIGATIONS,
CLAIMS, JUDGMENTS, LOSSES, COSTS, EXPENSES OR DAMAGES IN QUESTION ARISE OR AROSE SOLELY OR IN PART FROM THE GROSS, ACTIVE, PASSIVE OR CONCURRENT NEGLIGENCE, STRICT LIABILITY, OR OTHER FAULT OF ANY INDEMNIFIED PARTY. EACH PARTY ACKNOWLEDGES THAT THIS
STATEMENT COMPLIES WITH THE EXPRESS NEGLIGENCE RULE AND CONSTITUTES CONSPICUOUS NOTICE. NOTICE IN THIS CONSPICUOUS NOTICE IS NOT INTENDED TO PROVIDE OR ALTER THE RIGHTS AND OBLIGATIONS OF THE PARTIES, ALL OF WHICH ARE SPECIFIED ELSEWHERE IN THIS
AGREEMENT. 
 (g) Third Party Indemnification. If any Party has the rights to indemnification from a third party, the indemnifying
party under this Agreement shall have the right of subrogation with respect to any amounts received from such third-party indemnification claim. 
  

	20.	TERMINATION 

 (a) Termination for Default. A Party shall be in default under this
Agreement or any Terminal Service Order if: 
 (i) the Party breaches any provision of this Agreement, a Terminal Service
Order or any of the Related Agreements, which breach has a material adverse effect on the other Party, and such breach is not excused by Force Majeure or cured within fifteen (15) Business Days after notice thereof (which notice shall describe
such breach in reasonable detail) is received by such Party (unless such failure is not commercially reasonably capable of being cured in such fifteen (15) Business Day period in which case such Party shall have commenced remedial action to
cure such breach and shall continue to diligently and timely pursue the completion of such remedial action after such notice); or 

  
 15 

 (ii) the Party (A) files a petition or otherwise commences, authorizes or
acquiesces in the commencement of a proceeding or cause of action under any bankruptcy, insolvency, reorganization or similar Applicable Law, or has any such petition filed or commenced against it, (B) makes an assignment or any general
arrangement for the benefit of creditors, (C) otherwise becomes bankrupt or insolvent (however evidenced) or (D) has a liquidator, administrator, receiver, trustee, conservator or similar official appointed with respect to it or any
substantial portion of its property or assets. 
 If either Party is in default as described above, then (i) if Customer is in default, TLO may or
(ii) if TLO is in default, Customer may: (A) terminate this Agreement and all applicable Terminal Service Orders upon notice to the defaulting Party; (B) withhold any payments due to the defaulting Party under this Agreement and the
Terminal Service Orders; and/or (C) pursue any other remedy at law or in equity. 
 (b) Obligation to Cure. If a Party breaches
any provision of this Agreement or a Terminal Service Order, which breach does not have a material adverse effect on the other Party, the breaching Party shall still have the obligation to cure such breach. 

(c) Obligations at Termination. Unless otherwise mutually agreed by the Parties, within thirty (30) days of the termination or
expiration of this Agreement, (i) Customer shall promptly remove all of its removable Products from Storage Facility II and (ii) TLO shall remove the remaining Tank Heels and tank bottoms and deliver them to Customer or Customer’s
designee. In the event all of the Product is not removed within such thirty (30) day period, Customer shall be assessed a holdover storage fee, calculated on the same basis as the Storage Services Fee, to all Products held in storage more than
thirty (30) days beyond the termination or expiration of this Agreement until such time Customer’s entire Product is removed from the Tanks and Storage Facility II; provided, however, that Customer shall not be assessed any storage fees
associated with the removal of Product to the extent that Customer’s ability to remove such Product is delayed or hindered by TLO, its agents, or contractors for any reason. 

 

	21.	RIGHT TO ENTER INTO A NEW STORAGE AGREEMENT 

 (a) Right to Enter New Agreement.
Within two (2) years of termination of this Agreement for reasons other than (x) a default by Customer and (y) any other termination of this Agreement initiated by TLO pursuant to Section 20, Customer shall have the right to
require TLO to enter into a new storage services agreement (with ancillary Terminal Service Orders, as appropriate) with Customer that (i) is consistent with the terms set forth in this Agreement and Terminal Service Orders in effect at the
time of such termination, (ii) relates to Storage Facility II and the Tanks, and (iii) has commercial terms that are, in the aggregate, equal to or more favorable to TLO than fair market value terms as would be agreed by similarly-situated
parties negotiating at arm’s length; provided, however, TLO shall not be required to enter into any such new storage services agreement with a term that extends beyond November 7, 2037. 

(b) New Agreement; Right of First Refusal. In the event that TLO proposes to enter into a storage services agreement with a third party
within two (2) years after the termination of this Agreement for reasons other than (x) by default by Customer and (y) any other termination of this Agreement initiated by Customer pursuant to Section 20, TLO shall give Customer
ninety (90) days’ prior written notice of any proposed new storage services agreement with a third party, including (i) details of all of the material terms and conditions thereof and (ii) a thirty
(30)-day period (beginning upon Customer’s receipt of such written notice) (the “First Offer Period”) in which Customer may make a good faith offer to enter into a new storage services
agreement with TLO (the “Right of First Refusal”). If Customer makes an offer on terms no less favorable to TLO than the third-party offer with respect to such storage services agreement during the First Offer Period, then TLO shall
be obligated to enter into a storage services agreement with Customer on the terms set forth in Customer’s offer to TLO. If Customer does not exercise its Right of First Refusal in the manner set forth above, TLO may, for the next ninety
(90) days, proceed with the negotiation of the third-party storage services agreement. If no third party agreement is consummated during such ninety-day period, the terms and conditions of this
Section 21(b) shall again become effective. 

  
 16 

	22.	FORCE MAJEURE 

 (a) Force Majeure Notice. As soon as possible upon the occurrence
of a Force Majeure, TLO shall provide Customer with written notice of the occurrence of such Force Majeure (a “Force Majeure Notice”). TLO shall identify in such Force Majeure Notice the approximate length of time that TLO
reasonably believes in good faith such Force Majeure shall continue (the “Force Majeure Period”). For the duration of the Force Majeure Period, the Storage Services Fee shall be reduced by an amount equal to the Shell Capacity for
each affected Tank, provided that if Customer is able to continue to store Product in a Tank during the Force Majeure Period, but at a reduced Operating Capacity, the Storage Services Fee shall be reduced in proportion to the amount the effective
Operating Capacity is reduced. If TLO advises in any Force Majeure Notice that it reasonably believes in good faith that the Force Majeure Period shall continue for more than twelve (12) consecutive Months, then, subject to Section 6
above, at any time after TLO delivers such Force Majeure Notice, either Party may terminate that portion of this Agreement or any Terminal Service Order solely with respect to the affected Tank(s) at Storage Facility II, but only upon delivery to
the other Party of a notice (a “Termination Notice”) at least twelve (12) Months prior to the expiration of the Force Majeure Period; provided, however; that such Termination Notice shall be deemed cancelled and of no effect if
the Force Majeure Period ends prior to the expiration of such twelve-Month period. For the avoidance of doubt, neither Party may exercise its right under this Section 22(a) to terminate this Agreement or any Terminal Service Order as a result
of a Force Majeure with respect to any machinery, storage, tanks, lines of pipe or other equipment that has been unaffected by, or has been restored to working order since, the applicable Force Majeure, including pursuant to a Restoration under
Section 6. 
 (b) Termination Notice. Notwithstanding the foregoing, if Customer delivers a Termination Notice to TLO (the
“Customer Termination Notice”) and, within thirty (30) days after receiving such Customer Termination Notice, TLO notifies Customer that TLO reasonably believes in good faith that it shall be capable of fully performing its
obligations under this Agreement or any Terminal Service Order within a reasonable period of time and Customer mutually agrees, which agreement shall not be unreasonably withheld, then the Customer Termination Notice shall be deemed revoked and the
applicable portion of this Agreement or any Terminal Service Order shall continue in full force and effect as if such Customer Termination Notice had never been given. 
  

	23.	SUSPENSION OF REFINERY OPERATIONS 

 This Agreement shall continue in full force and
effect regardless of whether Customer decides to permanently or temporarily suspend refining operations at the Refinery. Customer is not permitted to suspend or reduce its obligations under this Agreement or any Terminal Service Order in connection
with a shutdown of the Refinery for scheduled turnarounds or other regular servicing or maintenance. If refining operations at the Refinery are suspended for any reason (including Refinery turnarounds and other scheduled maintenance), then Customer
shall remain liable for Storage Services Fees under this Agreement and any Terminal Service Order for the duration of the suspension. Customer shall provide at least thirty (30) days’ prior written notice of any suspension of operations at
the Refinery due to a planned turnaround or scheduled maintenance. 

  
 17 

	24.	ASSIGNMENT; SUBCONTRACT; PARTNERSHIP CHANGE OF CONTROL 

 (a) Assignment to TLO. As
of the Commencement Date, the General Partner shall assign all of its rights and obligations under this Agreement to the Partnership. The Partnership shall immediately assign its rights and obligations hereunder to TLO. Upon such assignment to TLO,
TLO shall have all of the respective rights and obligations set forth herein during the Term of this Agreement. 
 (b) Customer
Assignment to Third Party. Customer shall not assign any of its rights or obligations under this Agreement without TLO’s prior written consent, which consent shall not be unreasonably withheld, conditioned or delayed; provided,
however, that Customer may assign this Agreement without TLO’s consent in connection with a sale by Customer of the Refinery so long as the transferee: (i) agrees to assume all of Customer’s obligations under this Agreement and
(ii) is financially and operationally capable of fulfilling the terms of this Agreement, which determination shall be made by Customer in its reasonable judgment. 

(c) Subcontract. Should Customer desire to subcontract to a third party (“Subcontractor Customer”) any dedicated
storage subject to a Terminal Service Order, Customer must notify TLO in writing prior to the proposed start of the subcontract. TLO has the right to approve any Subcontractor Customer, which approval shall not be unreasonably withheld, conditioned
or delayed. Unless otherwise agreed in writing between Customer and TLO, and between Subcontractor Customer and TLO, Customer will continue to be liable for all terms and conditions of this Agreement related to any subcontracted Tank, including, but
not limited to, remittance of any fees set forth in a Terminal Service Order applicable to the subcontracted Tank. Customer shall be responsible for collection of any fees due to Customer from the Subcontractor Customer. Customer and TLO may
mutually agree that operational notices concerning scheduling and similar matters can be directly provided between TLO and any Subcontractor Customer. 

(d) TLO Assignment. TLO shall not assign any of its rights or obligations under this Agreement without Customer’s prior written
consent; provided, however, TLO shall be permitted to make a collateral assignment of this Agreement solely to secure working capital financing for TLO. 

(e) Notification of Assignment. Any assignment that is not undertaken in accordance with the provisions set forth above shall be null
and void ab initio. A Party making any assignment shall promptly notify the other Party of such assignment, regardless of whether consent is required. This Agreement shall be binding upon and inure to the benefit of the Parties hereto and
their respective successors and permitted assigns. 
 (f) Partnership Change of Control. Customer’s obligations hereunder shall
not terminate in connection with a Partnership Change of Control. TLO shall provide Customer with notice of any Partnership Change of Control at least sixty (60) days prior to the effective date thereof. 

 

	25.	ACCOUNTING PROVISIONS AND DOCUMENTATION; AUDIT 

 (a) Storage Services Fee
Documentation. Within ten (10) Business Days following the end of each Month, TLO shall furnish Customer with a statement showing, by Tank, a calculation of all of Customer’s Monthly Storage Services Fee. TLO shall furnish all
appropriate documentation to support the calculation of all fees, and, to the extent reasonably available, to document movement of Products through Storage Facility II. 

(b) Access. Each Party and its duly authorized agents and/or representatives shall have reasonable access to the accounting records and
other documents maintained by the other Party which relate to this Agreement, and shall have the right to audit such records at any reasonable time or times during the Term and for a period of up to three (3) years after termination of this
Agreement. Claims as to shortage in quantity or defects in quality shall be made by written notice within ninety (90) days after the delivery in question or shall be deemed to have been waived. 

  
 18 

	26.	INSURANCE 

 (a) Coverage. At all times during the Term and for a period of two
(2) years after termination of this Agreement for any coverage maintained on a “claims-made” or “occurrence” basis, Customer shall maintain at its expense the below listed insurance in the amounts specified below, or
self-insurance in such amounts as may be agreed pursuant to a Terminal Service Order. Such insurance shall provide coverage to TLO and such policies, other than Worker’s Compensation Insurance, shall include TLO as an Additional Insured. Each
policy shall provide that it is primary to and not contributory with any other insurance, including any self-insured retention, maintained by TLO (which shall be excess) and each policy shall provide the full coverage required by this Agreement and
any Terminal Service Order. All such insurance shall be written with carriers and underwriters acceptable to TLO, and eligible to do business in the state where Storage Facility II is located and having and maintaining an A.M. Best financial
strength rating of no less than “A-” and financial size rating no less than “VII”; provided that Customer may procure worker’s compensation insurance from the state where Storage
Facility II is located. All limits listed below are required MINIMUM LIMITS: 
 (i) Workers Compensation and Occupational Disease Insurance
which fully complies with Applicable Law of the state where Storage Facility II is located, in limits not less than statutory requirements; 

(ii) Employers Liability Insurance with a minimum limit of $1,000,000 for each accident, covering injury or death to any employee which may be
outside the scope of the worker’s compensation statute of the jurisdiction in which the worker’s service is performed, and in the aggregate as respects occupational disease; 

(iii) Commercial General Liability Insurance, with minimum limits of $1,000,000 combined single limit per occurrence for bodily injury and
property damage liability, or such higher limits as may be required by TLO or by Applicable Law from time to time. This policy shall include Broad Form Contractual Liability insurance coverage which shall specifically apply to the obligations
assumed in this Agreement and any Terminal Service Order by Customer; 
 (iv) Automobile Liability Insurance covering all owned, non-owned and hired vehicles, with minimum limits of $1,000,000 combined single limit per occurrence for bodily injury and property damage liability, or such higher limit(s) as may be required by Customer or by
Applicable Law from time to time. Limits of liability for this insurance must be not less than $1,000,000 per occurrence; 
 (v) Excess
(Umbrella) Liability Insurance with limits not less than $4,000,000 per occurrence. Additional excess limits may be utilized to supplement inadequate limits in the primary policies required in items (ii), (iii), and (iv) above; 

(vi) Pollution Legal Liability with limits not less than $25,000,000 per loss with an annual aggregate of $25,000,000. Coverage shall apply to
bodily injury and property damage including loss of use of damaged property and property that has not been physically injured; cleanup costs, defense, including costs and expenses incurred in the investigation, defense or settlement of claim; and

 (vii) Cargo/Inventory Insurance, with a limit of no less than $1,000,000, which property insurance shall be first-party property insurance
to adequately cover all Products owned by Customer located at Storage Facility II. 

  
 19 

 (b) Waiver of Subrogation. All such policies must be endorsed with a Waiver of Subrogation
endorsement, effectively waiving rights of recovery under subrogation or otherwise, against TLO, and shall contain where applicable, a severability of interest clause and a standard cross liability clause. 

(c) Insurance Certificates. Upon execution of this Agreement and prior to the operation of any equipment by Customer, Customer will
furnish to TLO, and at least annually thereafter (or at any other times upon request by TLO) during the Term (and for any coverage maintained on a “claims-made” basis, for two (2) years after the termination of this Agreement or any
applicable Terminal Service Order), insurance certificates and/or certified copies of the original policies to evidence the insurance required herein. Such certificates shall be in the form of the “Accord” Certificate of Insurance, and
reflect that they are for the benefit of TLO and shall provide that there will be no material change in or cancellation of the policies unless TLO is given at least thirty (30) days prior written notice. Certificates providing evidence of
renewal of coverage shall be furnished to TLO prior to policy expiration. 
 (d) Self-Insurance. Customer shall be solely responsible
for any deductibles or self-insured retention. 
  

	27.	NOTICE 

 All notices or requests or consents provided for by, or permitted to be given
pursuant to, this Agreement must be in writing and must be given by depositing same in the United States mail, addressed to the Person to be notified, postpaid, and registered or certified with return receipt requested or by delivering such notice
in person or by facsimile to such Party. Notice given by personal delivery or mail shall be effective upon actual receipt. Notice given by facsimile shall be effective upon actual receipt if received during the recipient’s normal business hours
or at the beginning of the recipient’s next business day after receipt if not received during the recipient’s normal business hours. All notices to be sent to a Party pursuant to this Agreement shall be sent to or made at the address set
forth below or at such other address as such Party may stipulate to the other Parties in the manner provided in this Section 27. 

If to Customer, to: 
 Tesoro
Refining & Marketing Company LLC 
 19100 Ridgewood Parkway 

San Antonio, Texas 78259 

Attention: General Counsel 
 If to
TLO, to: 
 Tesoro Logistics Operations LLC 

19100 Ridgewood Parkway 
 San
Antonio, Texas 78259 
 For legal notices: 

Attention: General Counsel 

For all other notices and communications: 

Attention: Don J. Sorensen, Senior Vice President, Logistics 

phone: (210) 626-6195 

email: Don.J.Sorensen@andeavor.com 
 or to such
other address or to such other Person as either Party will have last designated by notice to the other Party. 

  
 20 

	28.	CONFIDENTIAL INFORMATION 

 (a) Obligations. Each Party shall use reasonable
efforts to retain the other Parties’ Confidential Information in confidence and not disclose the same to any third party nor use the same, except as authorized by the disclosing Party in writing or as expressly permitted in this
Section 28. Each Party further agrees to take the same care with the other Party’s Confidential Information as it does with its own, but in no event less than a reasonable degree of care. Excepted from these
obligations of confidence and non-use is that information which: 
 (i) is available, or become
available, to the general public without fault of the receiving Party; 
 (ii) was in the possession of the receiving Party on a non-confidential basis prior to receipt of the same from the disclosing Party (it being understood, for the avoidance of doubt, that this exception shall not apply to information of TLO that was in the possession of
Customer or any of its affiliates as a result of their ownership or operation of Storage Facility II prior to the Commencement Date); 

(iii) is obtained by the receiving Party without an obligation of confidence from a third party who is rightfully in possession of such
information and, to the receiving Party’s knowledge, is under no obligation of confidentiality to the disclosing Party; or 
 (iv) is
independently developed by the receiving Party without reference to or use of the disclosing Party’s Confidential Information. 
 For the purpose of
this Section 28, a specific item of Confidential Information shall not be deemed to be within the foregoing exceptions merely because it is embraced by, or underlies, more general information in the public domain or in the
possession of the receiving Party. 
 (b) Required Disclosure. Notwithstanding Section 28(a) above, if the receiving Party
becomes legally compelled to disclose the Confidential Information by a court, Governmental Authority or Applicable Law, or is required to disclose by the listing standards of any applicable securities exchange of the disclosing Party’s
Confidential Information, the receiving Party shall promptly advise the disclosing Party of such requirement to disclose Confidential Information as soon as the receiving Party becomes aware that such a requirement to disclose might become
effective, in order that, where possible, the disclosing Party may seek a protective order or such other remedy as the disclosing Party may consider appropriate in the circumstances. The receiving Party shall disclose only that portion of the
disclosing Party’s Confidential Information that it is required to disclose and shall cooperate with the disclosing Party in allowing the disclosing Party to obtain such protective order or other relief. 

(c) Return of Information. Upon written request by the disclosing Party, all of the disclosing Party’s Confidential Information in
whatever form shall be returned to the disclosing Party or destroyed with destruction certified by the receiving Party upon termination of this Agreement, without the receiving Party retaining copies thereof except that one copy of all such
Confidential Information may be retained by a Party’s legal department solely to the extent that such Party is required to keep a copy of such Confidential Information pursuant to Applicable Law, and the receiving Party shall be entitled to
retain any Confidential Information in the electronic form or stored on automatic computer back-up archiving systems during the period such backup or archived materials are retained under such Party’s
customary procedures and policies; provided, however, that any Confidential Information retained by the receiving Party shall be maintained subject to confidentiality pursuant to the terms of this Section 28, and such archived or back-up Confidential Information shall not be accessed except as required by Applicable Law. 

  
 21 

 (d) Receiving Party Personnel. The receiving Party will limit access to the Confidential
Information of the disclosing Party to those of its employees, attorneys and contractors that have a need to know such information in order for the receiving Party to exercise or perform its rights and obligations under this Agreement or any
Terminal Service Order (the “Receiving Party Personnel”). The Receiving Party Personnel who have access to any Confidential Information of the disclosing Party will be made aware of the confidentiality provision of this Agreement,
and will be required to abide by the terms thereof. Any third party contractors that are given access to Confidential Information of a disclosing Party pursuant to the terms hereof shall be required to sign a written agreement pursuant to which such
Receiving Party Personnel agree to be bound by the provisions of this Agreement, which written agreement will expressly state that it is enforceable against such Receiving Party Personnel by the disclosing Party. 

(e) Survival. The obligation of confidentiality under this Section 28 shall survive the termination of this Agreement for a period
of two (2) years. 
  

	29.	MISCELLANEOUS 

 (a) Modification; Waiver. This Agreement or any Terminal Service
Order may be amended or modified only by a written instrument executed by the Parties. Any of the terms and conditions of this Agreement or any Terminal Service Order may be waived in writing at any time by the Party entitled to the benefits
thereof. No waiver of any of the terms and conditions of this Agreement or any Terminal Service Order, or any breach thereof, will be effective unless in writing signed by a duly authorized individual on behalf of the Party against which the waiver
is sought to be enforced. No waiver of any term or condition or of any breach of this Agreement or any Terminal Service Order will be deemed or will constitute a waiver of any other term or condition or of any later breach (whether or not similar),
nor will such waiver constitute a continuing waiver unless otherwise expressly provided. 
 (b) Integration. This Agreement, together
with the Schedules and Terminal Service Orders and the other agreements executed on the date hereof in connection with the transactions contemplated by the Contribution Agreement, constitutes the entire agreement among the Parties pertaining to the
subject matter hereof and supersedes all prior agreements and understandings of the Parties in connection therewith. In the event of a conflict of provisions of this Agreement and the Omnibus Agreement, the provisions of the Omnibus Agreement shall
prevail with respect to issues related to the contribution of the assets described therein, but not with respect to the ordinary operations of such assets as set forth in this Agreement. 

(c) Construction and Interpretation. In interpreting this Agreement, unless the context expressly requires otherwise, all of the
following apply to the interpretation of this Agreement: 
 (i) Preparation of this Agreement has been a joint effort of the
Parties and the resulting Agreement shall not be interpreted against one of the Parties as the drafting Party. 
 (ii) Plural
and singular words each include the other. 
 (iii) Masculine, feminine and neutral genders each include the others. 

(iv) The word “or” is not exclusive and includes “and/or.” 

(v) The words “includes” and “including” are not limiting. 

(vi) References to the Parties include their respective successors and permitted assignees. 

  
 22 

 (vii) The headings in this Agreement are included for convenience and do not
affect the construction or interpretation of any provision of, or the rights or obligations of a Party under, this Agreement. 
 (d)
Governing Law; Jurisdiction. This Agreement and any Terminal Service Order shall be governed by the laws of the State of Texas without giving effect to its conflict of laws principles. Each Party hereby irrevocably submits to the exclusive
jurisdiction of any federal court of competent jurisdiction situated in the United States District Court for the Western District of Texas, San Antonio Division, or if such federal court declines to exercise or does not have jurisdiction, in the
district court of Bexar County, Texas. The Parties expressly and irrevocably submit to the jurisdiction of said Courts and irrevocably waive any objection which they may now or hereafter have to the laying of venue of any action, suit or proceeding
arising out of or relating to this Agreement or any Terminal Service Order brought in such Courts, irrevocably waive any claim that any such action, suit or proceeding brought in any such Court has been brought in an inconvenient forum and further
irrevocably waive the right to object, with respect to such claim, action, suit or proceeding brought in any such Court, that such Court does not have jurisdiction over such Party. The Parties hereby irrevocably consent to the service of process by
registered mail, postage prepaid, or by personal service within or without the State of Texas. Nothing contained herein shall affect the right to serve process in any manner permitted by law. 

(e) Counterparts. This Agreement and any Terminal Service Order may be executed in one or more counterparts (including by facsimile or
portable document format (pdf)) for the convenience of the Parties hereto, each of which counterparts will be deemed an original, but all of which counterparts together will constitute one and the same agreement. 

(f) Severability. Whenever possible, each provision of this Agreement and any Terminal Service Order will be interpreted in such manner
as to be valid and effective under applicable law, but if any provision of this Agreement or any Terminal Service Order or the application of any such provision to any Person or circumstance will be held invalid, illegal or unenforceable in any
respect by a court of competent jurisdiction, such invalidity, illegality or unenforceability will not affect any other provision hereof, and the Parties will negotiate in good faith with a view to substitute for such provision a suitable and
equitable solution in order to carry out, so far as may be valid and enforceable, the intent and purpose of such invalid, illegal or unenforceable provision. 

(g) No Third-Party Beneficiaries. Except as specifically provided herein, including as set forth in Section 19, it is expressly
understood that the provisions of this Agreement and any Terminal Service Order do not impart enforceable rights in anyone who is not a Party or successor or permitted assignee of a Party. 

(h) WAIVER OF JURY TRIAL. EACH PARTY WAIVES, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY RIGHT IT MAY HAVE TO A TRIAL BY
JURY IN RESPECT OF ANY PROCEEDINGS RELATING TO THIS AGREEMENT OR ANY PERFORMANCE OR FAILURE TO PERFORM OF ANY OBLIGATION HEREUNDER. 
 (i)
Schedules and Terminal Service Orders(s). Each of the Schedules and Terminal Service Order(s) attached hereto and referred to herein is hereby incorporated in and made a part of this Agreement as if set forth in full herein. 

[Signature Page Follows] 

  
 23 

 IN WITNESS WHEREOF, the Parties hereto have duly executed this Agreement as of the
Commencement Date. 
  

									
	TESORO LOGISTICS OPERATIONS LLC	 		 	 TESORO REFINING & MARKETING COMPANY

LLC

					
	By:	 	/S/ STEVEN M. STERIN	 		 	By:	 	/S/ GREGORY J. GOFF
		 	 Steven M. Sterin
 President and Chief Financial
Officer
	 		 		 	 Gregory J. Goff
 President

  

			
	 Solely in respect of Section 24(a) only:

 

	ANDEAVOR LOGISTICS LP
		
	By:	 	TESORO LOGISTICS GP, LLC,
		 	its general partner

  

			
	By:	 	/S/ STEVEN M. STERIN
		 	Steven M. Sterin
		 	President and Chief Financial Officer

  

			
	 Solely in respect of Section 24(a) only:

 

	TESORO LOGISTICS GP, LLC
		
	By:	 	/S/ STEVEN M. STERIN
		 	Steven M. Sterin
		 	President and Chief Financial Officer

 Signature Page to Storage Services Agreement – Anacortes II 

 SCHEDULE A 

Storage Facility 

Sixty-six (66) crude and black-oil, petroleum product, and chemicals
storage tanks with a total shell capacity of approximately 3.9 million Barrels, a gasoline blending unit, a transfer pump house, and pipelines and other appurtenances that allow the transport of crude oil and petroleum products to and from the
nearby dock and to and from other facilities located at the Refinery. 
 Schedule A 

Storage Services Agreement – Anacortes II 

 SCHEDULE B 

TANKS 
  

			
	 TANK NUMBER
	  	SHELL CAPACITY (in Barrels)
	1	  	150,000
	2	  	150,000
	3	  	150,000
	4	  	150,000
	5	  	150,000
	6	  	150,000
	7	  	150,000
	8	  	80,000
	9	  	80,000
	10	  	55,000
	11	  	80,000
	12	  	80,000
	13	  	80,000
	14	  	80,000
	15	  	55,000
	16	  	55,000
	17	  	55,000
	18	  	55,000
	19	  	30,000
	20	  	30,000
	21	  	30,000
	22	  	30,000
	23	  	30,000
	24	  	80,000
	25	  	30,000
	26	  	80,000
	27	  	30,000
	28	  	30,000
	29	  	80,000
	30	  	30,000
	31	  	30,000
	32	  	80,000
	33	  	30,000
	34	  	80,000 (OOS)
	35	  	80,000
	36	  	80,000
	37	  	12,000
	38	  	12,000

 Schedule B 

Storage Services Agreement – Anacortes II 

			
	 TANK NUMBER
	  	SHELL CAPACITY (in Barrels)
	45	  	0.3
	46	  	0.3 (OOS)
	47	  	0.3 (OOS)
	48	  	0.4 (OOS)
	53	  	1,000
	54	  	1,000
	55	  	1,000 (OOS)
	56	  	0.5
	60	  	150,000
	62	  	NA (OOS)
	88	  	10,000 (OOS)
	89	  	10,000 (OOS)
	90	  	10,000 (OOS)
	91	  	30,000
	92	  	150,000
	95	  	NA (OOS)
	98	  	NA (OOS)
	99	  	NA (OOS)
	109	  	0.6
	110	  	NA (OOS)
	113	  	30,000
	114	  	114,000
	115	  	0.6
	134	  	100,000
	138	  	NA
	142	  	150,000
	147	  	NA (OOS)
	148	  	150,000
	156	  	NA
	157	  	NA
	158	  	NA
	159	  	NA (OOS)
	160	  	2,000
	171	  	130,000
	180	  	NA
	202	  	187,000
	203	  	193,000
	221	  	NA
	222	  	NA
	223	  	NA
	224	  	NA

 Schedule B 

Storage Services Agreement – Anacortes II 

			
	 TANK NUMBER
	  	SHELL CAPACITY (in Barrels)
	225	  	NA
	226	  	NA
	227	  	NA
	228	  	NA
	229	  	NA
	230	  	30,000
	231	  	101,000
	232	  	NA (OOS)
	247	  	18,000
	248	  	18,000
	249	  	NA (OOS)
	241 A	  	NA
	241 B	  	NA
	255	  	NA
	280	  	NA
	801	  	0.9
	802	  	0.9
	803	  	0.9
	804	  	0.9
	866	  	0.7
	867	  	0.7
	877	  	NA

 Schedule B 

Storage Services Agreement – Anacortes II 

 EXHIBIT 1 

FORM OF TERMINAL SERVICE ORDER 

(ANACORTES [    ]-             
    , 20    ) 
 This Terminal Service Order is entered as of
                         , 20    , by and between Tesoro Refining & Marketing
Company LLC, a Delaware limited liability company, and Tesoro Logistics Operations LLC, a Delaware limited liability company, pursuant to and in accordance with the terms of the Storage Services Agreement – Anacortes II dated as of
November 8, 2017, by and among such parties, and Tesoro Logistics GP, LLC, a Delaware limited liability company, and Andeavor Logistics LP, a Delaware limited partnership (the “Agreement”). 

Capitalized terms not otherwise defined herein shall have the meaning set forth in the Agreement. 

Pursuant to Section 5 of the Agreement, the parties hereto agree to the following provisions: 

[Insert applicable provisions: 

(i) the Shell Capacity of each Tank; 

(ii) the Storage Services Fee pursuant to Section 4; 

(iii) any reimbursement pursuant to Section 7(a); 

(iv) any Surcharge pursuant to Section 7(b); 

(v) any modification, cleaning, or conversion of a Tank as requested by Customer pursuant to Section 8(a); 

(vi) any reimbursement related to newly imposed taxes and regulations pursuant to Section 9; 

(vii) any steam services pursuant to Section 15(a); 

(viii) any oily water removal pursuant to Section 15(b); and 

(ix) any other services or use of facilities that may be agreed upon by the Parties.] 

Except as set forth in this Terminal Service Order, the other terms of the Agreement shall continue in full force and effect and shall apply to the terms of
this Terminal Service Order. 
 Exhibit 1 

Storage Services Agreement – Anacortes II 

 IN WITNESS WHEREOF, the parties hereto have duly executed this Terminal Service Order as
of the date first written above. 
 TESORO REFINING & MARKETING COMPANY LLC 

 

			
	By:	 	 

			
	Name:	 	
	Title:	 	
	
	TESORO LOGISTICS OPERATIONS LLC

			
		
	By:	 	 

			
	Name:	 	
	Title:	 	

 Exhibit 1 

Storage Services Agreement – Anacortes II

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