Document:

Exhibit

Exhibit 10.102
Fourth Amendment to the Third Amended and Restated Terminal Services Agreement
This Fourth Amendment to the Third Amended and Restated Terminal Services Agreement (“Amendment”) is dated July 1, 2019 by and between Marathon Petroleum Company LP (“MPC”), a Delaware limited partnership whose offices are located at 539 South Main Street, Findlay, Ohio 45840 and MPLX Terminals LLC (“Terminal Owner”), a Delaware limited liability company whose offices are located at 200 East Hardin Street, Findlay, Ohio 45840. Each of MPC and Terminal Owner shall be referred to herein individually as a “Party” or collectively as the “Parties”.

WHEREAS, MPC and Terminal Owner are Parties to that certain Third Amended and Restated Terminal Services Agreement, dated March  1, 2017, as amended on September 1, 2017, October 31, 2017, and March 20, 2018 (as amended, the “Agreement”); 
        
WHEREAS, on April 1, 2019, Terminal Owner sold its remaining outstanding membership interests in Johnson County Terminal, LLC, and purchased an additional 25% of the outstanding membership interests in Guilford County Terminal Company, LLC, bringing Terminal Owner’s total membership interests in Guilford County Terminal Company, LLC to 60% (the “April 1, 2019 Equity Transaction”); and

WHEREAS, MPC and Terminal Owner desire to amend the Agreement to reflect the April 1, 2019 Equity Transaction and other conforming changes associated with Ethanol Excess Volume Value Capture as defined in Schedule 5.1 to this Amendment and as more specifically provided in the  revisions to Sections 3.6(a), 4.1(a), 4.3(d)(i) and (ii), 5.1, 5.3 and Schedules 1.1, 3.1, 5.1, and 7.1 as provided in this Amendment.

NOW, THEREFORE, in consideration of the foregoing and for other good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the parties hereto agree that the foregoing recitals are incorporated herein by reference and as follows: 

1.  Except for the provisions of the Agreement specifically addressed in this Amendment, all other provisions of the Agreement shall remain in full force and effect.

2.  Capitalized terms used but not defined in this Amendment shall have the meaning ascribed to such terms in the Agreement.

3.  Section 3.6(a) is hereby deleted in its entirety and replaced with the following:

“3.6  Blending Services.
		
	a.
	Renewable Blending.  MPC may direct Terminal Owner to blend ethanol, biodiesel, biomass-based diesel or renewable diesel with any Products as a part of the Services hereunder.  Subject to Section 3.6(c), Terminal Owner shall provide or cause to be provided at each applicable Terminal blending services utilizing equipment including tanks, pumps, piping, and other equipment (the “Blending Equipment”) necessary to blend ethanol, biodiesel, biomass-based diesel and renewable diesel into Products.  MPC shall be responsible for providing all of the ethanol, biodiesel, biomass-based diesel and renewable diesel that it desires to be blended with Products at a Terminal.  Terminal Owner shall blend ethanol, biodiesel, biomass-based diesel and renewable diesel into the Products as directed by MPC. Terminal Owner shall provide a PTD with information about the blending of ethanol, biodiesel, biomass-based diesel or renewable diesel as directed by MPC, in addition to language required by applicable Laws. Terminal Owner shall also provide services with respect to in-tank denaturing of ethanol as a part of the Services hereunder.  Except for fees related to ethanol denaturing services and Ethanol Excess Volume Value Capture, which are separately set forth in Schedule 5.1, Fees for blending-related Services performed at each Terminal are included in the per Gallon throughput fees set forth in Schedule 5.1.”

4.  Section 4.1(a) is hereby deleted in its entirety and replaced with the following:

“4.1    Quarterly Volume Commitment.

		
	a.
	Commitment.  During each Calendar Quarter, MPC will tender the respective volumes of Products identified by Calendar Quarter for each Terminal in Schedule 3.1 (each a “Minimum Quarterly Terminal Volume Commitment”) for redelivery (including transshipments but excluding Transmix and EV) at each Terminal.”

5.  Section 4.3(d)(i) and (ii) are hereby deleted in their entirety and replaced with the following:

“(d) Prospective Volume Adjustment Opportunity.  
		
	(i) 
	Commencing with the fifth anniversary of the Effective Date and continuing every five years under the Term thereafter (each such date, an “Adjustment Opportunity Date”), Terminal Owner shall provide a statement to MPC, along with reasonable supporting documentation, showing (A) the Terminals or Terminal Complexes for which a Terminal Deficiency Payment was made during the previous five year period; (B) the average actual volumes of Products tendered for redelivery (including transshipments but excluding Transmix and EV) at each such Terminal or Terminal Complex, as applicable, on a Calendar Quarter basis; and (C) a calculation showing the percentage decrease of the volumes calculated in Section 4.3(d)(i)(B) (“x”) versus the Minimum Quarterly Terminal Volume Commitments or Aggregate Committed Complex Volume, as applicable (“y”), such calculation being expressed mathematically as (x-y)/y.  

(ii)  If the percentage reduction calculated for any such Terminal or Terminal Complex, as applicable, in Section 4.3(d)(i)(C) is equal to or greater than 25%, then MPC, at its option, may require Terminal Owner to negotiate in good faith, a reasonable reduction in the Minimum Quarterly Terminal Volume Commitments for such Terminals not to exceed the percentage reduction determined in Section 4.3(d)(i)(C); provided, however, that if MPC requires Terminal Owner to negotiate a volume adjustment pursuant to this Section, Terminal Owner may require MPC to negotiate in good faith (A) a reasonable reduction in the Reserved Capacity for such Terminals not to exceed the percentage difference determined in Section 4.3(d)(i)(C), and (B) a reasonable increase in the Minimum Quarterly Terminal Volume Commitments at Terminals where the average actual volumes of Products tendered for redelivery (including transshipments but excluding Transmix and EV) at each such Terminal on a Calendar Quarter basis exceeds the Minimum Quarterly Terminal Volume Commitments by 25% or more for the same previous five year period.”
6.  Section 5.1 is hereby deleted in its entirety and replaced with the following:

“5.1  Fees.  In consideration of the Reserved Capacity and the Services performed by Terminal Owner hereunder, MPC shall pay Terminal Owner the following fees (collectively, the “Fees”):  
		
	(a)
	Base Throughput Fee.  The base throughput fee for each corresponding Terminal set forth on Schedule 5.1 (each a “Base Throughput Fee”) shall apply to volumes of MPC’s Products (excluding Transmix and EV) redelivered hereunder up to the Minimum Quarterly Terminal Volume Commitment.  The Base Throughput Fee shall be charged on a per Gallon basis measured at the redelivery point and, except for the Marine Docks, butane blending and ethanol denaturing, is inclusive of all Services provided hereunder, including additization, renewable fuel blending and Transmix handling.

		
	(b)
	Excess Throughput Fee.  For volume of MPC’s Products (excluding Transmix and EV) redelivered hereunder in excess of the Minimum Quarterly Terminal Volume Commitment, the excess throughput fee for each corresponding Terminal set forth on Schedule 5.1 (each an “Excess Throughput Fee”) shall apply.  The Excess Throughput Fee shall be charged on a per Gallon basis measured at the redelivery point and, except for the Marine Docks, butane blending and ethanol denaturing, is inclusive of all Services provided hereunder, including additization, renewable fuel blending and Transmix handling.  

		
	(c)
	Marine Docks.  With respect to the Marine Docks, the Fees shall also include a Monthly facility fee set forth on Schedule 5.1 for the exclusive suite of Services typically applicable to marine dock facilities and provided at the Marine Docks.  Such facility fees for the Marine Docks shall be payable by MPC on a Monthly basis during the Term, regardless of the actual volumes of Products throughput by or on behalf of MPC at such Marine Docks.

		
	(d) 
	Butane Blending.  The fees for butane blending Services provided by Terminal Owner to MPC or its designated customers hereunder shall be calculated and charged as set forth on Schedule 5.1.

		
	(e) 
	Ethanol Denaturing.  The fees for ethanol denaturing Services provided by Terminal Owner hereunder shall be calculated and charged as set forth on Schedule 5.1.

		
	(f)  
	Deficiency.  

		
	(i) 
	Quarterly Deficiency.  If MPC fails to meet any of its Minimum Quarterly Terminal Volume Commitments during any Calendar Quarter, then MPC will pay Terminal Owner a deficiency payment (each, a “Terminal Deficiency Payment”) equal to the volume in Gallons of the Minimum Quarterly Terminal Volume Commitment deficiency multiplied by the applicable Base Throughput Fee for the affected Terminal; provided, that notwithstanding anything to the contrary herein including the fact that MPC failed to meet a Minimum Quarterly Terminal Volume Commitment for a particular Terminal during a Calendar Quarter, (A) MPC shall not be liable for payment of any Terminal Deficiency Payment if (1) such Terminal is included in a Terminal Complex; and (2) the applicable Aggregate Actual Complex Volume for the applicable Calendar Quarter meets or exceeds the Aggregate Committed Complex Volume for such Calendar Quarter; and (B) if the Aggregate Committed Complex Volume for such Calendar Quarter exceeds the Aggregate Actual Complex Volume for such Calendar Quarter, MPC, as to such Terminals in the Terminal Complex, shall be liable for a Terminal Deficiency Payment equal to the sum of: (1) at each Terminal included in such Terminal Complex which failed to meet its Minimum Quarterly Terminal Volume Commitment, the volume in Gallons of the Minimum Quarterly Terminal Volume Commitment deficiency divided by the sum of the differences between the volume in Gallons of the Minimum Quarterly Terminal Volume Commitment and the actual volume of Products in Gallons tendered for redelivery at each Terminal in such Terminal Complex that experienced a deficiency during such Calendar Quarter, (2) for each such Terminal, multiplied by the difference by which the Aggregate Committed Complex Volume for such Calendar Quarter exceeds the Aggregate Actual Complex Volume for such Calendar Quarter, and (3) multiplied by the applicable Base Throughput Fee for each such Terminal.  

		
	(ii)
	Quarterly True-Up.  Promptly following each Calendar Quarter, Terminal Owner shall provide MPC a written statement showing the Quarterly Aggregate Volume Commitment versus the Actual Quarterly Aggregate Volume.  If the Actual Quarterly Aggregate Volume exceeds the Quarterly Aggregate Volume Commitment, MPC shall not owe and shall be relieved from payment to Terminal Owner of any Terminal Deficiency Payments determined pursuant to Section 5.1(f)(i) for the applicable Calendar Quarter.

		
	(iii) 
	Exclusive Remedy.  Section 5.1(f) sets forth Terminal Owner’s sole and exclusive remedy for MPC’s failure to meet any of its Minimum Quarterly Terminal Volume Commitments or, if applicable, Aggregate Committed Complex Volumes, during any applicable Calendar Quarter.

		
	(g) 
	Unit Train Ethanol Receipts. The fees for Services provided by Terminal Owner to MPC to support Unit Train Ethanol Receipts shall be calculated and charged as set forth on Schedule 5.1. 

(h)  Ethanol Excess Volume Value Capture.  The fees for Services provided by Terminal Owner related to Ethanol Excess Volume Value Capture will be calculated and charged as set forth on Schedule 5.1.
7.  Section 5.3 is deleted in its entirety and replaced with the following:
“5.3    Adjustments.  As of January 1, 2017, and as of January 1 of each year thereafter during the Term, Terminal Owner shall upwardly adjust each of the Fees (excluding fees for Unit Train Ethanol Receipts and Ethanol Excess Volume Value Capture) annually by two percent (2%).
8.  Schedule 1.1 is hereby amended to add the following definitions:

“BGE” has the meaning set forth in Schedule 5.1.”
“Ethanol Excess Volume Value Capture has the meaning set forth in Schedule 5.1.”
“EV” has the meaning set forth in Schedule 5.1.”

 9.  Schedule 3.1 is hereby deleted in its entirety and replaced with the attached Schedule 3.1.

10.  Schedule 5.1 is hereby deleted in its entirety and replaced with the attached Schedule 5.1.

11.  Schedule 7.1 is hereby deleted in its entirety and replaced with the attached Schedule 7.1.

12. The effective date of the Sections and Schedules contained in this Amendment is July 1, 2019.

		
	13.
	This Amendment constitutes the entire agreement among the parties regarding this subject matter and may be amended or modified only by a written instrument signed by each of the parties.

		
	14.
	This Amendment supersedes any other prior agreements or understandings of the parties relating to this subject matter and the parties are not relying on any statement, representation, promise or inducement not expressly set forth herein.

		
	15.
	This Amendment may be executed in one or more counterparts, and in both original form and one or more photocopies, each of which shall be deemed to be an original, but all of which together shall be deemed to constitute one and the same instrument.

[SIGNATURE PAGE FOLLOWS]

IN WITNESS WHEREOF, the parties hereto have caused this Amendment to be executed by their respective authorized representatives.
	
					
	Marathon Petroleum Company LP
By: MPC Investment LLC, its General Partner
	 
	 
	MPLX Terminals LLC

	 
	 
	 
	 
	 

	By:  
	/s/  D. L. Whikehart
	 
	By:
	/s/  L. A. Wilkins

	 
	D. L. Whikehart
	 
	 
	L. A. Wilkins

	 
	Title:  Senior Vice President, Light Products Supply and Logistics
	 
	 
	Title:   President

Schedule 3.1 – Terminals and Minimum Quarterly Terminal Volume Commitments

	
																			
	 
	Terminal Name
	State
	Region
	Facility Type
	Loading Hours
	Gallons
	RC Assets

	 
	Lanes
	Docks
	Shell Capacity

	 
	Bay City
	MI
	MW
	Pipeline
	24/7
	71,625,000
	3
	 
	437,600

	 
	Bellevue
	OH
	MW
	Pipeline
	24/7
	5,664,000
	1
	 
	-

	 
	Belton
	SC
	SE
	Pipeline
	24/7
	74,949,000
	3
	 
	370,500

	 
	Birmingham
	AL
	SE
	Pipeline
	24/7
	58,131,000
	2
	 
	251,000

	 
	Brecksville
	OH
	MW
	Pipeline
	24/7
	30,912,000
	2
	 
	454,800

	 
	Canton
	OH
	MW
	Refinery
	24/7
	159,134,000
	6
	 
	48,500

	 
	Champaign
	IL
	MW
	Pipeline
	24/7
	96,441,000
	4
	 
	554,500

	 
	Charleston
	WV
	MW
	Barge
	24/7
	36,360,000
	2
	1
	165,700

	 
	Charlotte (East)
	NC
	SE
	Pipeline
	24/7
	110,751,000
	4
	 
	451,800

	 
	Charlotte (West)
	NC
	SE
	Pipeline
	24/7
	41,871,000
	2
	 
	152,700

	 
	Cincinnati
	OH
	MW
	Barge
	24/7
	54,021,000
	2
	1
	438,700

	 
	Columbus (East & West)
	OH
	MW
	Pipeline
	24/7
	197,481,000
	4
	 
	749,700

	 
	Columbus (GA)
	GA
	SE
	Pipeline
	24/7
	22,335,000
	1
	 
	132,600

	 
	Covington
	KY
	MW
	Barge
	24/7
	100,056,000
	4
	1
	342,100

	 
	Detroit
	MI
	MW
	Refinery
	24/7
	260,460,000
	6
	 
	-

	 
	Doraville
	GA
	SE
	Pipeline
	24/7
	52,626,000
	2
	 
	217,100

	 
	Evansville
	IN
	MW
	Barge
	24/7
	37,686,000
	2
	1
	126,000

	 
	Flint
	MI
	MW
	Pipeline
	24/7
	37,401,000
	2
	 
	223,800

	 
	Ft. Lauderdale (Eisenhower)
	FL
	SE
	Marine
	24/7
	112,170,000
	4
	1
	559,900

	 
	Ft. Lauderdale (Spangler)
	FL
	SE
	Marine
	24/7
	107,451,000
	3
	1
	473,800

	 
	Garyville
	LA
	SE
	Refinery
	24/7
	61,788,000
	2
	 
	96,700

	 
	Greensboro (Guilford County)
	NC
	SE
	Pipeline
	24/7
	43,170,000
	 
	 
	414,700

	 
	Hammond
	IN
	MW
	Pipeline
	24/7
	117,831,000
	3
	 
	1,193,800

	 
	Heath
	OH
	MW
	Pipeline
	24/7
	49,524,000
	2
	 
	11,100

	 
	Huntington
	IN
	MW
	Pipeline
	24/7
	35,220,000
	2
	 
	187,000

	 
	Indianapolis
	IN
	MW
	Pipeline
	24/7
	64,806,000
	3
	 
	951,600

	 
	Jackson
	MI
	MW
	Pipeline
	24/7
	21,828,000
	2
	 
	263,700

	 
	Jacksonville
	FL
	SE
	Marine
	24/7
	139,122,000
	5
	1
	1,156,900

	 
	Kenova/Catlettsburg Docks
	WV/KY
	MW
	Marine Docks
	24/7
	712,500,000
	 
	4
	1,421,100

	 
	Knoxville
	TN
	SE
	Pipeline
	24/7
	77,520,000
	4
	 
	332,800

	 
	Lansing
	MI
	MW
	Pipeline
	24/7
	59,682,000
	3
	 
	174,700

	 
	Lexington
	KY
	MW
	Pipeline
	24/7
	79,470,000
	3
	 
	205,300

	 
	Lima
	OH
	MW
	Pipeline
	24/7
	92,961,000
	2
	 
	854,000

	 
	Louisville (Algonquin)
	KY
	MW
	Barge
	24/7
	202,890,000
	6
	1
	1,215,400

	 
	Louisville (Kramers)
	KY
	MW
	Barge
	24/7
	115,401,000
	4
	1
	558,300

	 
	Macon
	GA
	SE
	Pipeline
	24/7
	79,296,000
	3
	 
	309,700

	 
	Marietta
	OH
	MW
	Barge
	24/7
	46,947,000
	3
	2
	170,700

	 
	Midland
	PA
	MW
	Barge
	24/7
	54,573,000
	2
	1
	390,400

	 
	Montgomery
	AL
	SE
	Pipeline
	24/7
	53,745,000
	2
	 
	191,700

	 
	Mt. Prospect
	IL
	MW
	Pipeline
	24/7
	53,487,000
	3
	 
	333,200

	 
	Mt. Vernon
	IN
	MW
	Barge
	24/7
	105,945,000
	1
	1
	630,000

	
																			
	 
	Muncie
	IN
	MW
	Pipeline
	24/7
	42,747,000
	2
	 
	243,800

	 
	Nashville (Bordeaux)
	TN
	SE
	Pipeline
	24/7
	64,008,000
	3
	1
	233,800

	 
	Nashville (Downtown)
	TN
	SE
	Barge
	24/7
	44,289,000
	2
	1
	250,800

	 
	Nashville (51st)
	TN
	SE
	Pipeline
	24/7
	60,903,000
	3
	 
	331,100

	 
	Niles
	MI
	MW
	Pipeline
	24/7
	74,589,000
	2
	 
	631,100

	 
	North Muskegon
	MI
	MW
	Pipeline
	24/7
	113,175,000
	5
	 
	440,200

	 
	Oregon
	OH
	MW
	Pipeline
	24/7
	53,250,000
	2
	 
	247,800

	 
	Paducah
	KY
	MW
	Barge
	24/7
	30,654,000
	2
	1
	208,300

	 
	Powder Springs
	GA
	SE
	Pipeline
	24/7
	78,300,000
	3
	 
	338,300

	 
	Robinson
	IL
	MW
	Refinery
	24/7
	74,736,000
	4
	 
	7,300

	 
	Rockford
	IL
	MW
	Pipeline
	24/7
	48,678,000
	3
	 
	326,000

	 
	Romulus
	MI
	MW
	Pipeline
	24/7
	27,309,000
	3
	 
	268,400

	 
	Selma (Buffalo)
	NC
	SE
	Pipeline
	24/7
	123,750,000
	3
	 
	549,000

	 
	Selma (West Oak)
	NC
	SE
	Pipeline
	24/7
	134,537,000
	4
	 
	355,000

	 
	Speedway
	IN
	MW
	Pipeline
	24/7
	124,647,000
	5
	 
	526,300

	 
	Steubenville
	OH
	MW
	Pipeline
	24/7
	16,599,000
	2
	 
	111,400

	 
	Tampa
	FL
	SE
	Marine
	24/7
	334,203,000
	10
	1
	1,231,700

	 
	Viney Branch
	KY
	MW
	Refinery
	24/7
	114,474,000
	6
	 
	57,100

	 
	Youngstown
	OH
	MW
	Pipeline
	24/7
	28,176,000
	2
	 
	131,000

Terminal Complexes:

1.    Brecksville and Canton
2.    Charlotte (West) and Charlotte (East)
3.    Cincinnati and Covington
4.    Evansville and Mt. Vernon
5.    Ft. Lauderdale (Spangler) and Ft. Lauderdale (Eisenhower)
6.    Indianapolis and Speedway
7.    Louisville (Kramers) and Louisville (Algonquin)
8.    Nashville (Bordeaux), Nashville (Downtown) and Nashville (51st)
9.    Selma (Buffalo) and Selma (West Oak)

Schedule 5.1 – Fees (Effective January 2019)

	
			
	Terminal Name
	Base Throughput Fee
	Excess Throughput Fee

	Bay City
	0.01634260
	0.01347734

	Bellevue
	0.01326510
	0.01326510

	Belton
	0.01443243
	0.01273450

	Birmingham
	0.01496303
	0.01284062

	Brecksville
	0.03310969
	0.01326510

	Canton
	0.01326510
	0.01326510

	Champaign
	0.01411407
	0.01326510

	Charleston
	0.02292209
	0.01368958

	Charlotte (East)
	0.01464467
	0.01305286

	Charlotte (West)
	0.01835890
	0.01252225

	Cincinnati
	0.02950158
	0.01368958

	Columbus (East & West)
	0.01241613
	0.01241613

	Columbus (GA)
	0.02727305
	0.01294674

	Covington
	0.01655484
	0.01623648

	Detroit
	0.01326510
	0.01326510

	Doraville
	0.01963235
	0.01294674

	Evansville
	0.02079968
	0.01390182

	Flint
	0.02292209
	0.01337122

	Ft. Lauderdale (Eisenhower)
	0.01782829
	0.01337122

	Ft. Lauderdale (Spangler)
	0.01432631
	0.01432631

	Garyville
	0.01400795
	0.01241613

	Greensboro (Friendship) – Guilford County
	0.01273450
	0.01273450

	Hammond
	0.01920786
	0.01252225

	Heath
	0.01220389
	0.01220389

	Huntington
	0.01931399
	0.01347734

	Indianapolis
	0.02642408
	0.01347734

	Jackson
	0.03947694
	0.01347734

	
			
	Jacksonville
	0.02897098
	0.01390182

	Kenova/Catlettsburg Docks
	0.00689785
	0.00689785

	Knoxville
	0.01305286
	0.01262838

	Lansing
	0.01496303
	0.01347734

	Lexington
	0.01337122
	0.01305286

	Lima
	0.01825278
	0.01220389

	Louisville (Algonquin)
	0.01857114
	0.01273450

	Louisville (Kramers)
	0.01581200
	0.01337122

	Macon
	0.01411407
	0.01241613

	Marietta
	0.02154252
	0.01368958

	Midland
	0.02493839
	0.01199165

	Montgomery
	0.01644872
	0.01284062

	Mt. Prospect
	0.02313433
	0.01326510

	Mt. Vernon
	0.01687321
	0.01167329

	Muncie
	0.01697933
	0.01326510

	Nashville (Bordeaux)
	0.01475079
	0.01284062

	Nashville (Downtown)
	0.02090580
	0.01284062

	Nashville (51st)
	0.01750993
	0.01284062

	Niles
	0.01899562
	0.01315898

	North Muskegon
	0.01347734
	0.01347734

	Oregon
	0.01708545
	0.01326510

	Paducah
	0.02706080
	0.01326510

	Powder Springs
	0.01549364
	0.01294674

	Robinson
	0.01390182
	0.01294674

	Rockford
	0.02111804
	0.01305286

	Romulus
	0.03703616
	0.01358346

	Selma (Buffalo)
	0.01294674
	0.01294674

	Selma (West Oak)
	0.01294674
	0.01294674

	Speedway
	0.01347734
	0.01347734

	Steubenville
	0.03194236
	0.01315898

	Tampa
	0.01453855
	0.01347734

	Viney Branch
	0.01337122
	0.01337122

	
			
	Youngstown
	0.02313433
	0.01284062

Marine Docks
Kenova/Catlettsburg Docks includes Kenova Light Product, and Catlettsburg Crude, Heavy Oil, and Light Oil Docks

Kenova/Catlettsburg Docks - $2,653,020 per month

Butane Blending  

(A)Facilities with Third Party Licensed Blending Technology 

From and after July 1, 2019, at facilities at which Energy Transfer Partners LP (“ETP”) licenses blending technology to MPC, Terminal Owner’s fee for performing the butane blending service shall be calculated as follows:

Ninety-five percent (95%) of the difference between the Daily Gasoline Value (defined below) and the Daily Butane Value (defined below).  Expressed as a formula, the Butane Blending Service Fee is:  

Butane Blending Service Fee = (DGV-DBV)* 95%

 NOTE: Terminal Owner will reflect an annual true up value cost or revenue, as defined in Section 4 of this Schedule 5.1, as a separate line item on any monthly invoices submitted pursuant to this Agreement.

Definitions:

1.Daily Gasoline Value (“DGV”): Expressed as a formula: 

DGV = (GB)*(GPV+TF)

GB: number of gallons of butane blended on a given day at the terminal site. 
GPV: daily gasoline posted value per gallon.
TF: the transportation fee for moving spot purchased gasoline to the terminal for the gasoline grade in which the butane is blended.  

         a.   The GPV is calculated by location as follows:

	
			
	Location
	Market
	GPV Price Calculation

	Bay City
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Charlotte East
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Jacksonville
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Lansing
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Nashville 51st
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Selma Buffalo
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Selma Oak
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Speedway
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	North Muskegon
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Tampa
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

b. The TF is the avoided MPC cost of transporting one Gallon of gasoline (in the most cost effective method possible) to a terminal blending location, as verified and provided by MPC’s Supply Distribution & Planning - Light Products Project Analysis organization.

		
	2.
	Daily Butane Value (“DBV”): the daily agreed upon butane purchase price (“BPP”) from ETP plus the total daily RIN value (DRV), multiplied by the daily total number of butane gallons blended (“GB”). Expressed as a formula:

DBV = (GB)*(BPP+DRV)

Bay City DBV = (GB)*(BPP+1/2DRV)

“DRV” will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually or the most recent requirements and will be adjusted retroactively for any difference between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year. OPIS daily posting for the respective RINs pricing will be used. In order to minimize the daily average RINs Cost, postings for prior years RINs will be used up to the maximum allowable percentage.

		
	3.
	Profit Sharing Payment  (“PSP”): For each calendar month, a Profit Sharing Payment is paid by ETP to MPC for volumes blended at the Bay City terminal.  The (“PSP”) is calculated as the volume of gallons blended (“GB”) at Bay City in such month multiplied by fifty percent multiplied by the following value: (A) the volume weighted daily average of the high and low assessments of Argus posted Chicago Cycle 1 gasoline price (85 CBOB) minus (B) the volume weighted daily average of the high and low assessments of the OPIS posted Mt. Belvieu TET normal butane price minus (C) the average supply cost. 

Fee calculations pursuant to this Schedule 5.1 for butane blending services completed prior to July 1, 2019 shall not be affected by changes in the foregoing formulas.

		
	4.
	Annual True-Up: This cost or revenue is intended to cover changes in the estimated vs actual transportation costs, half of shared maintenance expenses, and estimated vs actual butane purchase costs. The cost or revenue is calculated by ETP. MPC will pass ninety-five (95%) of this to Terminal Owner.

		
	B)
	Facilities Without Third Party Licensed Blending Technology

From and after September 1, 2018, at facilities at which no third party licensed blending technology is utilized, Terminal Owner’s fee for performing the tank butane blending service shall be calculated as follows:

Ninety-five percent (95%) of the difference between the Tank Daily Gasoline Value (defined below) and the Tank Daily Butane Value (defined below).  Expressed as a formula, the Tank Butane Blending Service Fee is:  

Tank Butane Blending Service Fee = (TDGV-TDBV)* 95%

Definitions:
		
	1.
	Tank Daily Gasoline Value (“TDGV”): Expressed as a formula: 

TDGV = (GB)*(GPV+TF)

GB: number of gallons of butane blended on a given day at the terminal site. 
GPV: daily gasoline posted value per gallon.
TF: the avoided transportation fee for moving spot purchased gasoline to the terminal for the gasoline grade in which the butane is blended.  

		
	a.
	The GPV is calculated by location using the daily posted average of either Argus 85 CBOB or Argus PREM spot prices for the respective blend and market derived from Schedule 3.1.

		
	b.
	The TF is the avoided MPC cost of transporting one Gallon of gasoline (in the most cost effective method possible) to a terminal blending location, as verified and provided by MPC’s Supply Distribution & Planning - Light Products Project Analysis organization.

		
	2.
	Tank Daily Butane Value (“TDBV”): the daily agreed upon tank butane purchase price (“TBPP”) from supplier, plus the total daily RIN value (DRV), multiplied by the daily total number of butane gallons blended (“GB”). Expressed as a formula:

DBV = (GB)*(TBPP+DRV+TC)

		
	a.
	The TC is the trucking cost of transporting one Gallon of butane (in the most cost effective method possible) to a terminal blending location..

		
	b.
	 “DRV” will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually or the most recent requirements and will be adjusted retroactively for any difference between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year. OPIS daily posting for the respective RINs pricing will be used. In order to minimize the daily average RINs Cost, postings for prior years RINs will be used up to the maximum allowable percentage.

		
	3.
	In the event MPC requests the butane skid for temporary use at an MPC owned terminal(s), MPC shall pay an MPLX Tank Butane Blending Equipment Service Fee equal to 5% of the blending value. Expressed as a formula:

		
	a.
	MPLX Tank Butane Blending Equipment Service Fee = (TDGV-TDBV)* 5%.

		
	4.
	Annual Adjustment to Revenue: This cost or revenue is intended to cover changes in the estimated vs actual transportation costs. Annually during the month of April, MPC will issue an adjustment of revenue to MPLX. This adjustment will be the result in changes of actual vs previously estimated trucking costs associated with delivery of butane to the terminals for the previous April- March.

Ethanol Denaturing

$0.02 per Gallon of undenatured ethanol.

Unit Train Ethanol Receipts

Beginning on January 15, 2017 and continuing thereafter for so long as the Master Terminal Services Agreement by and between MPC and ECO Energy Distribution Services LLC dated October 19, 2015 (the “ECO Agreement”) has not terminated, been cancelled or otherwise expired pursuant to its terms or agreement of the parties thereto, each of the following shall apply:

1.MPC shall pay Terminal Owner $0.0135 per Gallon for Unit Train Ethanol Receipts; provided that the invoice for the month ending March 31 of each year (or upon termination of the ECO Agreement, prorated according to the time of such termination) shall include an additional fee of $0.0135 per Gallon of Unit Train Ethanol Receipts that are less than 111,360,000 Gallons for the 12-month period ending on March 31 of the same year (prorated for the time period between January 15, 2017 through March 31, 2017). The $0.0135 per Gallon fee set forth in this Section shall be adjusted at the time of and in an amount equal to any adjustment to the Throughput Fees (as defined in the ECO Agreement) pursuant to Section 6.1(b) of the Eco Agreement, as may be amended from time to time.

At the end of each Calendar Quarter, Terminal Owner shall credit MPC on the monthly invoice (or upon termination of the ECO Agreement, prorated according to the time of such termination) an amount equal to the sum of (a) the Base Throughput Fee for Selma (Buffalo) set forth in Schedule 5.1 (as adjusted) multiplied by the volume (in Gallons) of ethanol redelivered by truck from the Selma (Buffalo) Terminal to the Selma (West Oak) Terminals during such Calendar Quarter; and (b) the Base Throughput Fee for Selma (Buffalo) set forth in Schedule 5.1 (as adjusted) multiplied by the volume (in Gallons) of ethanol redelivered per MPC’s direction from the Selma (Buffalo) Terminal into trucks for ECO during such Calendar Quarter.

Ethanol Excess Volume Value Capture

MPC will pay Terminal Owner fees as calculated herein for EV at Terminals where sales volume is made on a temperature corrected basis.

The value will be calculated via the following method: Multiply the volume by the price per the calculations described in the following two paragraphs.

The volume will be calculated via the following method: The American Petroleum Institute’s Manual of Petroleum Measurement Standards Chapter 11.3.4 “Miscellaneous Hydrocarbon Properties – Denatured Ethanol and Gasoline Blend Densities and Volume Correction Factors” (“Chapter 11.3.4”) provides data-based equations for Blends of Gasoline and Ethanol (“BGE”). Chapter 11.3.4 addresses excess volumes of gasohol (“EV”) created when gasoline and ethanol components are blended together. EV for truck rack throughput at Terminals equipped with Terminal Automation Software (TAS) will be calculated using the equation in Chapter 11.3.4 performed by TAS for any BGE. The TAS will be programmed to calculate EV by multiplying these BGE volumes by the correction factors as calculated using the equation from Chapter 11.3.4.  This process of crediting Terminal Owner with the EV based on the technology Terminal Owner installed and maintains at its Terminals is known as “Ethanol Excess Volume Value Capture.” 

The price will be calculated via the following method: Each Terminal is assigned to the CHICAGO (Midwest-designated as ‘MW’) or US GULF COAST (Southeast-designated as ‘SE’) region based on Schedule 3.1. EV credited to Terminal Owner will be valued using the non-weighted monthly average ARGUS 85 Assessment MID CBOB price for given market based on the location of the Terminal. The Midwest (‘MW’) will be using West Shore and Gulf Coast (‘SE’) will be using Pasadena posted pricing.

Schedule 7.1 – Market Price Formula

Each terminal location will be assigned to the CHICAGO (Midwest designated as ’MW’) or US GULF COAST (Southeast designated as ‘SE’) based on Region column on Schedule 3.1. The Midwest (‘MW’) will be using West Shore and Gulf Coast (‘SE’) will be using Pasadena posted pricing as published by ARGUS.

Ordinary Handling Losses in excess of 0.25% will be valued via pricing gasoline and distillate proration between ARGUS 85 Assessment MID CBOB and ARGUS Ultra-low sulfur diesel Assessment MID, considering CHICAGO/US GULF COAST markets to determine one weighted average price for the given month.

Extraordinary losses will be valued based on individual incident.  The ARGUS price for commodity or commodities involved in the incident will be used, considering CHICAGO/US GULF COAST pricing based on the Terminal location Assignment.  If the incident involves Transmix, valuation should be based on the lower of the Assessment MID ARGUS 85 CBOB or Ultra-low sulfur diesel value less $0.10/gallon, considering CHICAGO/US GULF COAST pricing based on the Terminal location.

VRU Gains will be valued using the non-weighted monthly average ARGUS 85 Assessment MID CBOB price for given market based on the Terminal location.Exhibit

Exhibit 10.103

Fifth Amendment to the Third Amended and Restated Terminal Services Agreement

This Fifth Amendment to the Third Amended and Restated Terminal Services Agreement ("Amendment") is dated December 13, 2019 by and between Marathon Petroleum Company LP, a Delaware limited partnership with an address of 539 South Main Street, Findlay, Ohio 45840 ("MPC"), and MPLX Terminals LLC, a Delaware limited liability company with an address of 200 East Hardin Street, Findlay, Ohio 45840 ("Terminal Owner"). Each of MPC and Terminal Owner shall be referred to herein individually as a "Party" or collectively as the "Parties."

WHEREAS, MPC and Terminal Owner are the Parties to that certain Third Amended and Restated Terminal Services Agreement, dated March 1, 2017, as amended on September 1, 2017, October 31, 2017, March 20, 2018 and July 1, 2019 (as amended, the “Agreement”); and

WHEREAS, MPC and Terminal Owner desire to amend the Agreement to update Schedule 1.1(A), Schedule 3.1 and Schedule 5.1.

NOW, THEREFORE, in consideration of the forgoing and for other goods and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto agree that the foregoing recitals are incorporated herein by reference and as follows:

		
	1.
	Except for the provisions of the Agreement specifically addressed in this Amendment, all other provisions of the Agreement shall remain in full force and effect.

		
	2.
	Capitalized terms used but not defined in this Amendment shall have the meaning ascribed to such terms in the Agreement.

		
	3.
	Schedule 1.1(A) of the Agreement is hereby deleted in its entirety and replaced with the attached Schedule 1.1(A). 

		
	4.
	Schedule 3.1 of the Agreement is hereby deleted in its entirety and replaced with the attached Schedule 3.1.

		
	5.
	Schedule 5.1 of the Agreement is hereby deleted in its entirety and replaced with the attached Schedule 5.1.

		
	6.
	The effective date of this Amendment is August 1, 2019.

		
	7.
	This Amendment constitutes the entire agreement among the Parties regarding this subject matter and may be amended or modified only by a written instrument signed by each of the Parties and supersedes any other prior agreements or understandings of the Parties relating to this subject matter and the Parties are not relying on any statement, representation, promise or inducement not expressly set forth herein.

		
	8.
	This Amendment may be executed in one or more counterparts, and in both original form and one or more photocopies, each of which shall be deemed to be an original, but all of which together shall be deemed to constitute one and the same instrument.

IN WITNESS WHEREOF, the Parties hereto have caused this Amendment to be executed by their respective authorized representatives.
	
					
	Marathon Petroleum Company LP
	 
	MPLX Terminals LLC

	By: MPC Investment LLC, its General Partner
	 
	 
	 

	 
	 
	 
	 
	 

	 
	 
	 
	 
	 

	By:
	/s/ P. A. Melton
	 
	By:
	/s/ L. A. Wilkins

	Name:
	P. A. Melton
	 
	Name:
	L. A. Wilkins

	Title:
	Vice President
	 
	Title:
	President

	 
	 
	 
	 
	 

	 
	 
	 
	 
	 

	 
	 
	 
	 
	 

Schedule 1.l(A) - Products

Blend-grade Gasoline
Regular Gasoline
Super-grade Gasoline
Ethanol
Gasoline Additives
No. 1 Distillate
No. 2 Distillate
Biodiesel
Distillate Additives
Distillate Dye
Transmix
Natural Gasoline
Butane
Pentane

Exclusively at Kenova/Catlettsburg Docks:
Asphalt
Heavy Oils
Other Chemicals
Other Feedstocks

Schedule 3.1 - Terminals and Minimum Quarterly Terminal Volume Commitments

	
									
	Terminal Name
	State
	Region
	Facility Type
	Loading Hours
	Gallons
	RC Assets

	Lanes
	Docks
	Shell Capacity

	Bay City
	MI
	MW
	Pipeline
	24/7
	71,625,000
	3
	 
	437,600

	Bellevue
	OH
	MW
	Pipeline
	24/7
	5,664,000
	1
	 
	-

	Belton
	SC
	SE
	Pipeline
	24/7
	74,949,000
	3
	 
	370,500

	Birmingham
	AL
	SE
	Pipeline
	24/7
	58,131,000
	2
	 
	251,000

	Brecksville
	OH
	MW
	Pipeline
	24/7
	30,912,000
	2
	 
	454,800

	Canton
	OH
	MW
	Refinery
	24/7
	159,134,000
	6
	 
	48,500

	Champaign
	IL
	MW
	Pipeline
	24/7
	96,441,000
	4
	 
	554,500

	Charleston
	WV
	MW
	Barge
	24/7
	36,360,000
	2
	1
	165,700

	Charlotte (East)
	NC
	SE
	Pipeline
	24/7
	110,751,000
	4
	 
	451,800

	Charlotte (West)
	NC
	SE
	Pipeline
	24/7
	41,871,000
	2
	 
	152,700

	Cincinnati
	OH
	MW
	Barge
	24/7
	54,021,000
	2
	1
	438,700

	Columbus (East & West)
	OH
	MW
	Pipeline
	24/7
	197,481,000
	4
	 
	749,700

	Columbus (GA)
	GA
	SE
	Pipeline
	24/7
	22,335,000
	1
	 
	132,600

	Covington
	KY
	MW
	Barge
	24/7
	100,056,000
	4
	1
	342,100

	Detroit
	MI
	MW
	Refinery
	24/7
	260,460,000
	6
	 
	-

	Doraville
	GA
	SE
	Pipeline
	24/7
	52,626,000
	2
	 
	217,100

	Evansville
	IN
	MW
	Barge
	24/7
	37,686,000
	2
	1
	126,000

	Flint
	MI
	MW
	Pipeline
	24/7
	37,401,000
	2
	 
	223,800

	Ft. Lauderdale (Eisenhower)
	FL
	SE
	Marine
	24/7
	112,170,000
	4
	1
	559,900

	Ft. Lauderdale (Spangler)
	FL
	SE
	Marine
	24/7
	107,451,000
	3
	1
	473,800

	Garyville
	LA
	SE
	Refinery
	24/7
	61,788,000
	2
	 
	96,700

	Greensboro (Guilford County)
	NC
	SE
	Pipeline
	24/7
	43,170,000
	 
	 
	414,700

	Hammond
	IN
	MW
	Pipeline
	24/7
	117,831,000
	3
	 
	1,193,800

	Heath
	OH
	MW
	Pipeline
	24/7
	49,524,000
	2
	 
	11,100

	Huntington
	IN
	MW
	Pipeline
	24/7
	35,220,000
	2
	 
	187,000

	Indianapolis
	IN
	MW
	Pipeline
	24/7
	64,806,000
	3
	 
	951,600

	Jackson
	MI
	MW
	Pipeline
	24/7
	21,828,000
	2
	 
	263,700

	Jacksonville
	FL
	SE
	Marine
	24/7
	139,122,000
	5
	1
	1,142,000

	Kenova/Catlettsburg Docks
	WV/KY
	MW
	Marine Docks
	24/7
	712,500,000
	 
	4
	1,421,100

	Knoxville
	TN
	SE
	Pipeline
	24/7
	77,520,000
	4
	 
	332,800

	Lansing
	MI
	MW
	Pipeline
	24/7
	59,682,000
	3
	 
	174,700

	Lexington
	KY
	MW
	Pipeline
	24/7
	79,470,000
	3
	 
	205,300

	Lima
	OH
	MW
	Pipeline
	24/7
	92,961,000
	2
	 
	864,200

	Louisville (Algonquin)
	KY
	MW
	Barge
	24/7
	202,890,000
	6
	1
	1,215,400

	Louisville (Kramers)
	KY
	MW
	Barge
	24/7
	115,401,000
	4
	1
	558,300

	Macon
	GA
	SE
	Pipeline
	24/7
	79,296,000
	3
	 
	309,700

	Marietta
	OH
	MW
	Barge
	24/7
	46,947,000
	3
	2
	170,700

	Midland
	PA
	MW
	Barge
	24/7
	54,573,000
	2
	1
	390,400

	Montgomery
	AL
	SE
	Pipeline
	24/7
	53,745,000
	2
	 
	191,700

	Mt. Prospect
	IL
	MW
	Pipeline
	24/7
	53,487,000
	3
	 
	333,200

	Mt. Vernon
	IN
	MW
	Barge
	24/7
	105,945,000
	1
	1
	630,000

	Muncie
	IN
	MW
	Pipeline
	24/7
	42,747,000
	2
	 
	243,800

	Nashville (Bordeaux)
	TN
	SE
	Pipeline
	24/7
	64,008,000
	3
	1
	233,800

	Nashville (Downtown)
	TN
	SE
	Barge
	24/7
	44,289,000
	2
	1
	250,800

	Nashville (51st)
	TN
	SE
	Pipeline
	24/7
	60,903,000
	3
	 
	331,100

	Niles
	MI
	MW
	Pipeline
	24/7
	74,589,000
	2
	 
	631,100

	North Muskegon
	MI
	MW
	Pipeline
	24/7
	113,175,000
	5
	 
	440,200

	Oregon
	OH
	MW
	Pipeline
	24/7
	53,250,000
	2
	 
	247,800

	Paducah
	KY
	MW
	Barge
	24/7
	30,654,000
	2
	1
	208,300

	Powder Springs
	GA
	SE
	Pipeline
	24/7
	78,300,000
	3
	 
	338,300

	Robinson
	IL
	MW
	Refinery
	24/7
	74,736,000
	4
	 
	7,300

	
									
	Rockford
	IL
	MW
	Pipeline
	24/7
	48,678,000
	3
	 
	326,000

	Romulus
	MI
	MW
	Pipeline
	24/7
	27,309,000
	3
	 
	268,400

	Selma (Buffalo)
	NC
	SE
	Pipeline
	24/7
	123,750,000
	3
	 
	549,000

	Selma (West Oak)
	NC
	SE
	Pipeline
	24/7
	134,537,000
	4
	 
	355,000

	Speedway
	IN
	MW
	Pipeline
	24/7
	124,647,000
	5
	 
	526,300

	Steubenville
	OH
	MW
	Pipeline
	24/7
	16,599,000
	2
	 
	111,400

	Tampa
	FL
	SE
	Marine
	24/7
	334,203,000
	10
	1
	1,231,700

	Viney Branch
	KY
	MW
	Refinery
	24/7
	114,474,000
	6
	 
	57,100

	Youngstown
	OH
	MW
	Pipeline
	24/7
	28,176,000
	2
	 
	131,000

Terminal Complexes:

1.     Brecksville and Canton
2.    Charlotte (West) and Charlotte (East)
3.    Cincinnati and Covington
4.    Evansville and Mt. Vernon
5.    Ft. Lauderdale (Spangler) and Ft. Lauderdale (Eisenhower)
6.    Indianapolis and Speedway
7.    Louisville (Kramers) and Louisville (Algonquin)
8.    Nashville (Bordeaux), Nashville (Downtown) and Nashville (51st)
9.    Selma (Buffalo) and Selma (West Oak)

Schedule 5.1 – Fees 

	
			
	Terminal Name
	Base Throughput Fee*
	Excess Throughput Fee*

	Bay City
	0.01634260
	0.01347734

	Bellevue
	0.01326510
	0.01326510

	Belton
	0.01443243
	0.01273450

	Birmingham
	0.01496303
	0.01284062

	Brecksville
	0.03310969
	0.01326510

	Canton
	0.01326510
	0.01326510

	Champaign
	0.01411407
	0.01326510

	Charleston
	0.02292209
	0.01368958

	Charlotte (East)
	0.01464467
	0.01305286

	Charlotte (West)
	0.01835890
	0.01252225

	Cincinnati
	0.02950158
	0.01368958

	Columbus (East & West)
	0.01241613
	0.01241613

	Columbus (GA)
	0.02727305
	0.01294674

	Covington
	0.01655484
	0.01623648

	Detroit
	0.01326510
	0.01326510

	Doraville
	0.01963235
	0.01294674

	Evansville
	0.02079968
	0.01390182

	Flint
	0.02292209
	0.01337122

	Ft. Lauderdale (Eisenhower)
	0.01782829
	0.01337122

	Ft. Lauderdale (Spangler)
	0.01432631
	0.01432631

	Garyville
	0.01400795
	0.01241613

	Greensboro (Friendship) – Guilford County
	0.01273450
	0.01273450

	 
	 
	 

	 
	 
	 

	 
	 
	 

	 
	 
	 

	 
	 
	 

	
			
	 
	 
	 

	Hammond
	0.01920786
	0.01252225

	Heath
	0.01220389
	0.01220389

	Huntington
	0.01931399
	0.01347734

	Indianapolis
	0.02642408
	0.01347734

	Jackson
	0.03947694
	0.01347734

	Jacksonville
	0.02897098
	0.01390182

	Kenova/Catlettsburg Docks
	0.00689785
	0.00689785

	Knoxville
	0.01305286
	0.01262838

	Lansing
	0.01496303
	0.01347734

	Lexington
	0.01337122
	0.01305286

	Lima
	0.01825278
	0.01220389

	Louisville (Algonquin)
	0.01857114
	0.01273450

	Louisville (Kramers)
	0.01581200
	0.01337122

	Macon
	0.01411407
	0.01241613

	Marietta
	0.02154252
	0.01368958

	Midland
	0.02493839
	0.01199165

	Montgomery
	0.01644872
	0.01284062

	Mt. Prospect
	0.02313433
	0.01326510

	Mt. Vernon
	0.01687321
	0.01167329

	Muncie
	0.01697933
	0.01326510

	Nashville (Bordeaux)
	0.01475079
	0.01284062

	Nashville (Downtown)
	0.02090580
	0.01284062

	Nashville (51st)
	0.01750993
	0.01284062

	Niles
	0.01899562
	0.01315898

	 
	 
	 

	 
	 
	 

	 
	 
	 

	 
	 
	 

	 
	 
	 

	
			
	 
	 
	 

	North Muskegon
	0.01347734
	0.01347734

	Oregon
	0.01708545
	0.01326510

	Paducah
	0.02706080
	0.01326510

	Powder Springs
	0.01549364
	0.01294674

	Robinson
	0.01390182
	0.01294674

	Rockford
	0.02111804
	0.01305286

	Romulus
	0.03703616
	0.01358346

	Selma (Buffalo)
	0.01294674
	0.01294674

	Selma (West Oak)
	0.01294674
	0.01294674

	Speedway
	0.01347734
	0.01347734

	Steubenville
	0.03194236
	0.01315898

	Tampa
	0.01453855
	0.01347734

	Viney Branch
	0.01337122
	0.01337122

	Youngstown
	0.02313433
	0.01284062

*The table above reflects the fees effective as of January 1, 2019, as adjusted per Section 5.3.

Marine Docks
Kenova/Catlettsburg Docks includes Kenova Light Product, and Catlettsburg Crude, Heavy Oil, and
Light Oil Docks

Kenova/Catlettsburg Docks - $2,653,020 per month (reflects monthly fee effective as January 1, 2019, as adjusted per Section 5.3).

Butane/Natural Gasoline/Pentane Blending
		
	A)
	Facilities with Third Party Licensed Blending Technology

From and after July 1, 2019, at facilities at which Energy Transfer Partners LP (“ETP”) licenses blending technology to MPC, Terminal Owner's fee for performing the butane blending service shall be calculated as follows:

Ninety-five percent (95%) of the difference between the Daily Gasoline Value (defined below) and the Daily Butane Value (defined below). Expressed as a formula, the Butane Blending Service Fee is:

Butane Blending Service Fee = (DGV-DBV)* 95%

NOTE: Terminal Owner will reflect an Annual True-Up, as defined in Section 4 of this Schedule 5.1, as a separate line item on any monthly invoices submitted pursuant to this Agreement.

Definitions:

1.   Daily Gasoline Value ("DGV"): Expressed as a formula:

DGV = (GB)*(GPV+TF)

GB: number of Gallons of butane blended on a given day at the terminal site.
GPV: daily gasoline posted value per Gallon.
TF: the transportation fee for moving spot purchased gasoline to the terminal for the gasoline grade in which the butane is blended.

a.  GPV is calculated by location as follows:

	
			
	Location
	Market
	GPV Price Calculation

	Bay City
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Charlotte East
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Jacksonville
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Lansing
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Nashville 51st
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Selma Buffalo
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Selma Oak
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Speedway
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	North Muskegon
	Chicago
	Daily posted Argus 85 CBOB and 91 PREM spot prices

	Tampa
	Gulf Coast
	Daily posted Argus 85 CBOB and 91 PREM spot prices

b.  TF is the avoided MPC cost of transporting one Gallon of gasoline (in the most cost effective method possible) to a terminal blending location, as verified and provided by MPC's Supply Distribution & Planning - Light Products Project Analysis organization.

2.   Daily Butane Value ("DBV"): the daily agreed upon butane purchase price ("BPP") from ETP plus the total daily RIN value (“DRV”), multiplied by the daily total number of butane gallons blended ("GB"). Expressed as a formula:

DBV = (GB)*(BPP+DRV)

Bay City DBV = (GB)*(BPP+1/2DRV)

a. DRV will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually or the most recent requirements and will be adjusted retroactively for any difference between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year. OPIS daily posting for the respective RINs pricing will be used. In order to minimize the daily average RINs Cost, postings for prior years RINs will be used up to the maximum allowable percentage.

3.   Profit Sharing Payment: For each calendar month, a Profit Sharing Payment (“PSP”) is paid by ETP to MPC for volumes blended at the Bay City terminal.  The PSP is calculated as the volume of gallons blended (“GB”) at Bay City in such month multiplied by fifty percent multiplied by the following value: (A) the volume weighted daily average of the high and low assessments of Argus posted Chicago Cycle 1 gasoline price (85 CBOB) minus (B) the volume weighted daily average of the high and low assessments of the OPIS posted Mt. Belvieu TET normal butane price minus (C) the average supply cost.

Fee calculations pursuant to this Schedule 5.1 for butane blending services completed prior to July 1, 2019 shall not be affected by changes in the foregoing formulas.

4.  Annual True-Up: This cost or revenue is intended to cover changes in the estimated vs actual transportation costs, half of shared maintenance expenses, and estimated vs actual butane purchase costs. The cost or revenue is calculated ETP. MPC will pass ninety-five (95%) of this to Terminal Owner.

		
	B)
	Facilities Without Third Party Blending Technology

From and after September 1, 2018, at facilities at which no third party licensed blending technology is utilized, Terminal Owner’s fee for performing the butane or pentane blending service shall be calculated as follows:

Ninety-five percent (95%) of the difference between the Tank Daily Gasoline Value (defined below) and the Tank Daily Butane Value (defined below). Expressed as a formula, the Tank Butane Blending Service Fee is:

Tank Butane Blending Service Fee = (TDGV-TDBV)* 95%
            

Or

Ninety-five percent (95%) of the difference between the Tank Daily Gasoline Value (defined below) and the Tank Daily Pentane Value (defined below). Expressed as a formula, the Tank Pentane Blending Service Fee is:

Tank Pentane Blending Service Fee = (TDGV-TDPV)* 95%

Definitions:

		
	1.
	Tank Daily Gasoline Value (“TDGV”): Expressed as a formula:

TDGV = (GB)*(GPV+TF)
GB: number of Gallons of butane blended on a given day at the terminal site.
GPV: daily gasoline posted value per gallon.
TF: the avoided transportation fee for moving spot purchased gasoline to the terminal for the gasoline grade in which the butane is blended.

		
	a.
	GPV is calculated by location using the daily posted average Argus 85 CBOB or Argus PREM spot prices for the respective blend and market derived from Schedule 3.1.

		
	2.
	Tank Daily Butane Value (“TDBV”): the daily agreed upon tank butane purchase price (“TBPP”) from supplier, plus the total daily RIN value (“DRV”), multiplied by the daily total number of butane Gallons blended (“GB”). Expressed as a formula:

TDBV = (GB)*(TBPP+DRV+TC)

		
	a.
	TC is the trucking cost of transporting one Gallon of butane (in the most cost effective method possible) to a terminal blending location.

		
	b.
	DRV will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually to the most recent requirements and will be adjusted retroactively for any difference between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year. OPIS daily posting for the respective RINs pricing will be used. In order to minimize the daily average RINs Cost, posting for prior years RINs will be used up to the maximum allowable percentage.

		
	3.
	Tank Daily Pentane Value (“TDPV”): the daily agreed upon tank pentane purchase price (“TPPP”) from supplier, plus the total daily RIN value (“DRV”), multiplied by the daily total number of butane Gallons blended (“GB”).  Expressed as a formula:

 
TDPV = (GB) * (TPPP + DRV + TC)

		
	a.
	TC is the trucking costs of transporting one Gallon of pentane (in the most cost-effective manner) to a terminal blending location.

		
	b.
	 DRV will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually or the most recent requirements and will be adjusted retroactively for any difference 

between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year.  OPIS daily posting for the respective RINs pricing will be used.  In order to minimize the daily average RINs Cost, postings for the prior years RINs will be used up to the maximum allowable percentage.

		
	4.
	In the event MPC requests a butane skid for temporary use at an MPC owned terminal(s), MPC shall pay an MPLX Tank Butane Blending Equipment Service Fee equal to 5% of the blending value. Expressed as a formula:

		
	a.
	MPLX Tank Butane Blending Equipment Service Fee = (TDGV-TDBV)* 5%.

		
	5.
	Annual Adjustment to Revenue: This cost or revenue is intended to cover changes in the estimated vs actual transportation costs. Annually during the month of April, MPC will issue an adjustment of revenue to MPLX. This adjustment will be the result in changes of actual vs previously estimated trucking costs associated with delivery of butane to the terminals for the previous April- March.

		
	C)
	Kenova Blending 

From and after October 31st, 2019, at the Kenova, WV terminal the Terminal Owner’s fee for performing in-line or barge loading blending service shall be calculated as follows: 

Ninety-five percent (95%) of the difference between the Marathon Daily Gasoline Value (defined below) and the Marathon Daily Butane Value (defined below) or the Marathon Daily Pentane Value (defined below).  Expressed as a formula the Inline or Barge Blending Service Fee is: 

Inline or Barge Blending Service Fee = (MDGV – MDBV) * 0.95
Or
Inline or Barge Blending Service Fee = (MDGV – MDPV) * 0.95

Definitions: 
1.Marathon Daily Gasoline Value (“MDGV”): Expressed as a formula: 
MDGV = (GB) * (GPV + KTF) 
GB: Number of Gallons of butane/pentane blended on a given day at the terminal site. 
GPV: daily gasoline posted value per Gallon 
KTF: the additional transportation costs for moving the gasoline barrel produced through butane or pentane blending to the terminal of sale 

a.GPV is calculated by the location using the daily posted averages of either Argus 85 CBOB or Argus Prem spot prices for the respective blend and market derived from Schedule 3.1

2.Marathon Daily Butane Value (“MDBV”): the daily agreed upon Marathon butane purchase price (“MBPP”) from supplier, plus the total daily RIN value (“DRV”), multiplied by the daily total number of butane Gallons blended (“GB”).  Expressed as a formula:
 
MDBV = (GB) * (MBPP + DRV + TC)

a.    TC is the trucking costs of transporting one Gallon of butane (in the most cost-effective manner) to a terminal blending location.
b.    DRV will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually or the most recent requirements and will be adjusted retroactively for any difference between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year.  OPIS daily posting for the respective RINs pricing will be used.  In order to minimize the daily average RINs Cost, postings for the prior year’s RINs will be used up to the maximum allowable percentage. 

3.Marathon Daily Pentane Value (“MDPV”): the daily agreed upon Marathon pentane purchase price (“MPPP”) from supplier, plus the total daily RIN value (“DRV”), multiplied by the daily total number of butane Gallons blended (“GB”).  Expressed as a formula:
 
MDPV = (GB) * (MPPP + DRV + TC)

a.    TC is the trucking costs of transporting one Gallon of pentane (in the most cost-effective manner) to a terminal blending location.
b.    DRV will be determined by using the percentage of each type of RINs specified by the Renewable Fuel Standard Program updated annually or the most recent requirements and will be adjusted retroactively for any difference between the requirements at the time of the calculation and the requirements contained in a final rule establishing Renewable Volume Obligations for the year.  OPIS daily posting for the respective RINs pricing will be used.  In order to minimize the daily average RINs Cost, postings for the prior year’s RINs will be used up to the maximum allowable percentage. 

D) Butane Blending into Natural Gasoline at Facilities Without Third Party Licensed Blending Technology

a.   Butane Blending into Natural Gasoline  Project Service Fee: Prior to MPC requesting Terminal Owner to provide natural gasoline blending services at a Terminal that does not have butane blending into natural gasoline  service capabilities, MPC will pay a one-time fee to Terminal Owner as reimbursement for the project capital costs to be incurred by a Terminal to enable such Terminal to provide butane blending into natural gasoline  services, as well as an additional charge of 15% of such project capital costs. Prior to any Terminal incurring any project capital costs to be able to provide butane blending into natural gasoline 

services for MPC, the Parties will agree upon the Butane Blending into Natural Gasoline Project Services Fee for each Terminal providing such services.

b.   Butane Blending into Natural Gasoline Services Fee: From and after August 20th, 2019 at any Terminal with no third-party licensed blending technology utilized, Terminal Owner’s fee for performing butane blending into natural gasoline services shall be calculated as follows, expressed as a formula:
 
Natural Gas Blending Services Fee = $1.58 * the number of barrels of butane blended into natural gasoline

Ethanol Denaturing

$0.02 per Gallon of undenatured ethanol.

Unit Train Ethanol Receipts

Beginning on January 15, 2017 and continuing thereafter for so long as the Master Terminal Services Agreement by and between MPC and ECO Energy Distribution Services, LLC dated October 19, 2015 (the "ECO Agreement") has not terminated, been cancelled or otherwise expired pursuant to its terms or agreement of the parties thereto, each of the following shall apply:

1.     MPC shall pay Terminal Owner $0.0135 per Gallon for Unit Train Ethanol Receipts; provided that the invoice for the month ending March 31 of each year (or upon termination of the ECO Agreement, prorated according to the time of such termination) shall include an additional fee of $0.0135 per Gallon of Unit Train Ethanol Receipts that are less than 111,360,000 Gallons for the 12-month period ending on March 31 of the same year (prorated for the time period between January 15, 2017 through March 31, 2017. The $0.0135 per Gallon fee set forth in this Section shall be adjusted at the time of and in an amount equal to any adjustment to the Throughput Fees (as defined in the ECO Agreement) pursuant to Section 6.l(b) of the ECO Agreement, as may be amended from time to time.

At the end of each Calendar Quarter, Terminal Owner shall credit MPC on the monthly invoice (or upon termination of the ECO Agreement, prorated according to the time of such termination) an amount equal to the sum of (a) the Base Throughput Fee for Selma (Buffalo) set forth in Schedule 5.1 (as adjusted) multiplied by the volume (in Gallons) of ethanol redelivered by truck from the Selma (Buffalo) Terminal to the Selma (West Oak) Terminals during such Calendar Quarter; and (b) the Base Throughput Fee for Selma (Buffalo) set forth in Schedule 5.1 (as adjusted) multiplied by the volume (in Gallons) of ethanol redelivered per MPC's direction from the Selma (Buffalo) Terminal into trucks for ECO during such Calendar Quarter.

Ethanol Excess Volume Value Capture

MPC will pay Terminal Owner fees as calculated herein for EV at Terminals where sales volume is made on a temperature corrected basis.

The value will be calculated via the following method: Multiply the volume by the price per the calculations described in the following two paragraphs.

The volume will be calculated via the following method: The American Petroleum Institute’s Manual of Petroleum Measurement Standards Chapter 11.3.4 “Miscellaneous Hydrocarbon Properties – Denatured Ethanol and Gasoline Blend Densities and Volume Correction Factors” (“Chapter 11.3.4”) provides data-based equations for Blends of Gasoline and Ethanol (“BGE”). Chapter 11.3.4 addresses excess volumes of gasohol (“EV”) created when gasoline and ethanol components are blended together. EV for truck rack throughput at Terminals equipped with Terminal Automation Software (TAS) will be calculated using the equation in Chapter 11.3.4 performed by TAS for any BGE. The TAS will be programmed to calculate EV by multiplying these BGE volumes by the correction factors as calculated using the equation from Chapter 11.3.4.  This process of crediting Terminal Owner with the EV based on the technology Terminal Owner installed and maintains at its Terminals is known as “Ethanol Excess Volume Value Capture.” 

The price will be calculated via the following method: Each Terminal is assigned to the CHICAGO (Midwest-designated as ‘MW’) or US GULF COAST (Southeast-designated as ‘SE’) region based on Schedule 3.1. EV credited to Terminal Owner will be valued using the non-weighted monthly average ARGUS 85 Assessment MID CBOB price for given market based on the location of the Terminal. The Midwest (‘MW’) will be using West Shore and Gulf Coast (‘SE’) will be using Pasadena posted pricing.

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