First Amended and Restated Schedules to the Fourth Amended and Restated Omnibus Agreement, dated as of November 8, 2017, by and among Andeavor, Tesoro Refining & Marketing Company LLC, Tesoro Companies, Inc., Tesoro Alaska Company LLC, Andeavor Logistics LP and Tesoro Logistics GP, LLC

EX-10.1 4 d476918dex101.htm EX-10.1 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:

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.

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:

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

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:

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.

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.

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.

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.

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.

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:

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:

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;

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

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:

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.

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.

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.

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.

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.

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).

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.

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.

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:

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.

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.

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.

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.

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

Expense Projects

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.

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:

All capital costs related to:

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.

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

Any costs or expenses related to:

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.

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:

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.

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.

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.

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.

Idea# 2013215028, AFE ###-###-#### (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.

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

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

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.

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).

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).

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).

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).

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).

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).

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

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

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

November 15, 2022

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

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

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 (2^nd) 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 (5^th) anniversary of the First Closing Date or the Second Closing Date, as applicable

Andeavor, TRMC, Tesoro Alaska

The tenth (10^th) 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

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

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

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.