QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2021
OR
☐
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission file number 001-35714
_____________________________________________
MPLX LP
(Exact name of registrant as specified in its charter)
_____________________________________________
Delaware
27-0005456
(State or other jurisdiction of incorporation or organization)
(I.R.S. Employer Identification No.)
200 E. Hardin Street,
Findlay,
Ohio
45840
(Address of principal executive offices)
(Zip code)
(419) 421-2414
(Registrant’s telephone number, including area code)
_____________________________________________
Securities Registered pursuant to Section 12(b) of the Act
Title of each class
Trading symbol(s)
Name of each exchange on which registered
Common Units Representing Limited Partnership Interests
MPLX
New York Stock Exchange
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yesx No ¨
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files.) Yesx No ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer
x
Accelerated filer
☐
Non-accelerated filer
☐
Smaller reporting company
☐
Emerging growth company
☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act) Yes ☐ No x
MPLX LP had 1,019,863,638 common units outstanding at October 29, 2021.
Unless the context otherwise requires, references in this report to “MPLX LP,” “MPLX,” “the Partnership,” “we,” “our,” “us,” or like terms refer to MPLX LP and its subsidiaries. Additionally, throughout this Quarterly Report on Form 10-Q, we have used terms in our discussion of the business and operating results that have been defined in our Glossary of Terms.
Notes to Consolidated Financial Statements (Unaudited)
1. Description of the Business and Basis of Presentation
Description of the Business – MPLX LP is a diversified, large-cap master limited partnership formed by Marathon Petroleum Corporation that owns and operates midstream energy infrastructure and logistics assets, and provides fuels distribution services. References in this report to “MPLX LP,” “MPLX,” “the Partnership,” “we,” “ours,” “us,” or like terms refer to MPLX LP and its subsidiaries. References to “MPC” refer collectively to Marathon Petroleum Corporation as our sponsor and its subsidiaries, other than the Partnership. We are engaged in the transportation, storage, marketing and distribution of crude oil, asphalt and refined petroleum products; the gathering, processing and transportation of natural gas; and the gathering, transportation, fractionation, storage and marketing of NGLs. MPLX’s principal executive office is located in Findlay, Ohio.
MPLX’s business consists of two segments based on the nature of services it offers: Logistics and Storage (“L&S”), which relates primarily to crude oil, asphalt and refined petroleum products; and Gathering and Processing (“G&P”), which relates primarily to natural gas and NGLs. See Note 9 for additional information regarding the operations and results of these segments.
Impairments – Through the first nine months of 2021, we continued to see improvements in the environment in which our business operates as COVID-19 impacts continue to subside. The increased availability of vaccinations and easing of COVID-19 restrictions has been followed by an increase in economic activity despite the recent resurgence in COVID-19. We are unable to predict the long-term impacts COVID-19 may have on our financial position and results.
In the second quarter of 2021, we recognized impairment expense of $42 million within our G&P segment related to our continued emphasis on portfolio optimization with the anticipated divestiture of several non-core assets and the closure of other non-core assets.
During the first quarter of 2020, the overall deterioration in the economy and the environment in which MPLX and its customers operate, as well as a sustained decrease in unit price, were considered triggering events at that time resulting in impairments of the carrying value of certain assets. We recognized impairments related to goodwill, certain equity method investments and certain long-lived assets (including intangibles), within our G&P segment. Many of our producer customers refined and updated production forecasts in response to the environment at that time, which impacted their expected future demand for our services, including the future utilization of our assets. Additionally, certain of our contracts have commodity price exposure, including NGL prices, which experienced increased volatility as noted above. The table below provides information related to the impairments recognized during the first quarter of 2020 as well as the corresponding footnote where additional information can be found.
(In millions)
Impairment
Footnote Reference
Goodwill
$
1,814
12
Equity method investments
1,264
4
Intangibles, net
177
12
Property, plant and equipment, net
174
11
Total impairments
$
3,429
Basis of Presentation – The accompanying interim consolidated financial statements are unaudited; however, in the opinion of MPLX’s management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal, recurring nature unless otherwise disclosed. These interim consolidated financial statements, including the notes, have been prepared in accordance with the rules and regulations of the SEC applicable to interim period financial statements and do not include all of the information and disclosures required by GAAP for complete financial statements. Certain amounts in prior years have been reclassified to conform to current year presentation.
These interim consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2020. The results of operations for the three and nine months ended September 30, 2021 are not necessarily indicative of the results to be expected for the full year.
MPLX’s consolidated financial statements include all majority-owned and controlled subsidiaries. For non-wholly owned consolidated subsidiaries, the interests owned by third parties have been recorded as “Noncontrolling interests” on the accompanying Consolidated Balance Sheets. Intercompany investments, accounts and transactions have been eliminated.
MPLX’s investments in which MPLX exercises significant influence but does not control and does not have a controlling financial interest are accounted for using the equity method. MPLX’s investments in VIEs in which MPLX exercises significant influence but does not control and is not the primary beneficiary are also accounted for using the equity method.
2. Accounting Standards
Recently Adopted
We did not adopt any ASUs during the first nine months of 2021 that are expected to have a material impact to our financial statements or financial statement disclosures.
3. Acquisitions and Dispositions
Sale of Javelina Assets and Liabilities
On February 12, 2021, MarkWest Energy Operating Company, L.L.C., (“MarkWest Energy”) a wholly owned subsidiary of MPLX, completed the sale of all of MarkWest Energy’s equity interests in MarkWest Javelina Company L.L.C., MarkWest Javelina Pipeline Company L.L.C., and MarkWest Gas Services L.L.C. (collectively, “Javelina”) pursuant to the terms of an Equity Purchase Agreement entered into with a third party on December 23, 2020. The agreement included adjustments for working capital as well as an earnout provision based on the performance of the assets. No gain or loss was recorded on the sale. The estimated value of the earnout provision was recorded as a contingent asset shown within “Other noncurrent assets” on the Consolidated Balance Sheets as of September 30, 2021. Javelina’s assets and liabilities sold are shown on the Consolidated Balance Sheets as “Assets held for sale” and “Liabilities held for sale” for the year ended December 31, 2020. Prior to the sale, Javelina was reported within the G&P segment.
Wholesale Exchange
On July 31, 2020, MPLX entered into a Redemption Agreement (the “Redemption Agreement”) with Western Refining Southwest, Inc. (now known as Western Refining Southwest LLC) (“WRSW”), a wholly owned subsidiary of MPC, pursuant to which MPLX agreed to transfer to WRSW all of the outstanding membership interests in Western Refining Wholesale, LLC (“WRW”) in exchange for the redemption of MPLX common units held by WRSW. The transaction effected the transfer to MPC of the Western wholesale distribution business that MPLX acquired as a result of its acquisition of Andeavor Logistics LP (“ANDX”). Per the terms of the Redemption Agreement, MPLX redeemed 18,582,088 common units (the “Redeemed Units”) held by WRSW on July 31, 2020. The number of Redeemed Units was calculated by dividing WRW’s aggregate valuation of $340 million by the simple average of the volume weighted average NYSE prices of an MPLX common unit for the ten trading days ending at market close on July 27, 2020. MPLX canceled the Redeemed Units immediately following the Wholesale Exchange. The carrying value of the net assets of WRW transferred to MPC was approximately $90 million as of July 31, 2020, resulting in $250 million being recorded to “Common Unit-holder MPC” within the Consolidated Statements of Equity, netted against the fair value of the Redeemed Units. Included within the $90 million carrying value of the WRW net assets was approximately $65 million of goodwill. These financial statements include the results of WRW through July 31, 2020.
The following table presents MPLX’s equity method investments at the dates indicated:
Ownership as of
Carrying value at
September 30,
September 30,
December 31,
(In millions, except ownership percentages)
2021
2021
2020
L&S
MarEn Bakken Company LLC(1)
25%
$
457
$
465
Illinois Extension Pipeline Company, L.L.C.
35%
253
254
LOOP LLC
41%
268
252
Andeavor Logistics Rio Pipeline LLC(2)
67%
188
194
Minnesota Pipe Line Company, LLC
17%
184
188
Whistler Pipeline LLC(2)
38%
146
185
Explorer Pipeline Company
25%
68
72
W2W Holdings LLC(2)(3)
50%
66
72
Other(2)
115
103
Total L&S
1,745
1,785
G&P
MarkWest Utica EMG, L.L.C.(2)
57%
682
698
Sherwood Midstream LLC(2)
50%
548
557
MarkWest EMG Jefferson Dry Gas Gathering Company, L.L.C.(2)
67%
335
307
MarkWest Torñado GP, L.L.C.(2)
60%
223
188
Rendezvous Gas Services, L.L.C.(2)
78%
151
159
Sherwood Midstream Holdings LLC(2)
51%
138
148
Centrahoma Processing LLC
40%
132
145
Other(2)
47
49
Total G&P
2,256
2,251
Total
$
4,001
$
4,036
(1) The investment in MarEn Bakken Company LLC includes our 9.19 percent indirect interest in a joint venture (“Dakota Access”) that owns and operates the Dakota Access Pipeline and Energy Transfer Crude Oil Pipeline projects, collectively referred to as the Bakken Pipeline system or DAPL.
(2) Investments deemed to be VIEs. Some investments included within “Other” have also been deemed to be VIEs.
(3) Through our ownership interest in W2W Holdings LLC, we have a 15 percent equity interest in Wink to Webster Pipeline LLC.
For those entities that have been deemed to be VIEs, neither MPLX nor any of its subsidiaries have been deemed to be the primary beneficiary due to voting rights on significant matters. While we have the ability to exercise influence through participation in the management committees which make all significant decisions, we have equal influence over each committee as a joint interest partner and all significant decisions require the consent of the other investors without regard to economic interest and as such we have determined that these entities should not be consolidated and apply the equity method of accounting with respect to our investments in each entity.
Sherwood Midstream LLC (“Sherwood Midstream”) has been deemed the primary beneficiary of Sherwood Midstream Holdings LLC (Sherwood Midstream Holdings”) due to its controlling financial interest through its authority to manage the joint venture. As a result, Sherwood Midstream consolidates Sherwood Midstream Holdings. Therefore, MPLX also reports its portion of Sherwood Midstream Holdings’ net assets as a component of its investment in Sherwood Midstream. As of September 30, 2021, MPLX has a 24.55 percent indirect ownership interest in Sherwood Midstream Holdings through Sherwood Midstream.
MPLX’s maximum exposure to loss as a result of its involvement with equity method investments includes its equity investment, any additional capital contribution commitments and any operating expenses incurred by the subsidiary operator in excess of its compensation received for the performance of the operating services. MPLX did not provide any financial support to equity method investments that it was not contractually obligated to provide during the nine months ended September 30, 2021.
During the first quarter of 2020, we recorded an other than temporary impairment for three joint ventures in which we have an interest as discussed in Note 1. Impairment of these investments was $1,264 million, of which $1,251 million was related to MarkWest Utica EMG, L.L.C. and its investment in Ohio Gathering Company, L.L.C. The impairment was recorded through “Income from equity method investments.” The impairments were largely due to a reduction in forecasted volumes gathered and processed by the systems operated by the joint ventures.
Summarized financial information for MPLX’s equity method investments for the nine months ended September 30, 2021 and 2020 is as follows:
Nine Months Ended September 30, 2021
(In millions)
VIEs
Non-VIEs
Total
Revenues and other income
$
565
$
940
$
1,505
Costs and expenses
350
427
777
Income from operations
215
513
728
Net income
172
449
621
Income from equity method investments(1)
$
120
$
108
$
228
(1) Includes impairment expense of $6 million.
Nine Months Ended September 30, 2020
(In millions)
VIEs
Non-VIEs
Total
Revenues and other income
$
132
$
933
$
1,065
Costs and expenses
308
405
713
(Loss)/income from operations
(176)
528
352
Net (loss)/income
(230)
477
247
(Loss)/income from equity method investments(1)
$
(1,138)
$
126
$
(1,012)
(1) Includes impairment expense of $1,264 million.
Summarized balance sheet information for MPLX’s equity method investments as of September 30, 2021 and December 31, 2020 is as follows:
September 30, 2021
(In millions)
VIEs
Non-VIEs
Total
Current assets
$
328
$
444
$
772
Noncurrent assets
7,426
4,907
12,333
Current liabilities
216
254
470
Noncurrent liabilities
$
2,448
$
873
$
3,321
December 31, 2020
(In millions)
VIEs
Non-VIEs
Total
Current assets
$
530
$
318
$
848
Noncurrent assets
6,889
4,997
11,886
Current liabilities
323
187
510
Noncurrent liabilities
$
1,904
$
830
$
2,734
5. Related Party Agreements and Transactions
MPLX engages in transactions with both MPC and certain of its equity method investments as part of its normal business; however, transactions with MPC make up the majority of MPLX’s related party transactions. Transactions with related parties are further described below.
MPLX has various long-term, fee-based commercial agreements with MPC. Under these agreements, MPLX provides transportation, terminal, fuels distribution, marketing, storage, management, operational and other services to MPC. MPC has committed to provide MPLX with minimum quarterly throughput volumes on crude oil and refined products and other fees for
storage capacity; operating and management fees; as well as reimbursements for certain direct and indirect costs. MPC has also committed to provide a fixed fee for 100 percent of available capacity for boats, barges and third-party chartered equipment under the marine transportation service agreement. MPLX also has a keep-whole commodity agreement with MPC under which MPC pays us a processing fee for NGLs related to keep-whole agreements and delivers shrink gas to the producers on our behalf. We pay MPC a marketing fee in exchange for assuming the commodity risk. Additionally, MPLX has obligations to MPC for services provided to MPLX by MPC under omnibus and employee services-type agreements as well as other various agreements.
Related Party Loan
MPLX is party to a loan agreement with MPC Investment LLC (“MPC Investment”) (the “MPC Loan Agreement”). Under the terms of the agreement, MPC Investment extends loans to MPLX on a revolving basis as requested by MPLX and as agreed to by MPC Investment. The borrowing capacity of the MPC Loan Agreement is $1.5 billion aggregate principal amount of all loans outstanding at any one time. The loan agreement is scheduled to expire, and borrowings under the loan agreement are scheduled to mature and become due and payable, on July 31, 2024, provided that MPC Investment may demand payment of all or any portion of the outstanding principal amount of the loan, together with all accrued and unpaid interest and other amounts (if any), at any time prior to maturity. Borrowings under the MPC Loan Agreement bear interest at LIBOR plus 1.25 percent or such lower rate as would be applicable to such loans under the MPLX Credit Agreement as discussed in Note 15. Activity on the MPC Loan Agreement was as follows:
(In millions)
Nine Months Ended September 30, 2021
Year Ended December 31, 2020
Borrowings
$
6,571
$
6,264
Average interest rate of borrowings
1.345
%
2.278
%
Repayments
$
5,201
$
6,858
Outstanding balance at end of period(1)
$
1,370
$
—
(1) Included in “Current liabilities - related parties” on the Consolidated Balance Sheets.
Related Party Revenue
Related party sales to MPC consist of crude oil and refined products pipeline and trucking transportation services based on tariff/contracted rates; storage, terminal and fuels distribution services based on contracted rates; and marine transportation services. Related party sales to MPC also includes revenue related to volume deficiency credits.
Certain product sales to MPC net to zero within the consolidated financial statements as the transactions are recorded net due to the terms of the agreements under which such product was sold. For the three and nine months ended September 30, 2021, these sales totaled $203 million and $548 million, respectively. For the three and nine months ended September 30, 2020, these sales totaled $107 million and $332 million, respectively.
MPLX also has operating agreements with MPC under which it receives a fee for operating MPC’s retained pipeline assets and a fixed annual fee for providing oversight and management services required to run the marine business. MPLX also receives management fee revenue for engineering, construction and administrative services for operating certain of its equity method investments. These agreements are classified as “Other income - related parties” on the Consolidated Statements of Income.
Related Party Expenses
MPC charges MPLX for executive management services and certain general and administrative services that MPC provides to MPLX under the terms of our omnibus agreements (“Omnibus charges”). Omnibus charges included in “Rental cost of sales - related parties” primarily relate to services that support MPLX’s rental operations and maintenance of assets available for rent, as well as compensation expenses. Omnibus charges included in “Purchases - related parties” primarily relate to services that support MPLX’s operations and maintenance activities, as well as compensation expenses. Omnibus charges included in “General and administrative expenses” primarily relate to services that support MPLX’s executive management, accounting and human resources activities. MPLX also obtains employee services from MPC under employee services agreements (“ESA charges”). ESA charges for personnel directly involved in or supporting operations and maintenance activities related to rental services are classified as “Rental cost of sales - related parties.” ESA charges for personnel directly involved in or supporting operations and maintenance activities related to other services are classified as “Purchases - related parties.” ESA charges for personnel involved in executive management, accounting and human resources activities are classified as “General and
administrative expenses.” In addition to these agreements, MPLX purchases products from MPC, makes payments to MPC in its capacity as general contractor to MPLX, and has certain lease agreements with MPC.
For the three and nine months ended September 30, 2021, “General and administrative expenses” incurred from MPC totaled $70 million and $190 million, respectively. For the three and nine months ended September 30, 2020, “General and administrative expenses” incurred from MPC totaled $63 million and $195 million, respectively.
Some charges incurred under the omnibus and ESA agreements are related to engineering services and are associated with assets under construction. These charges are added to “Property, plant and equipment, net” on the Consolidated Balance Sheets. For the three and nine months ended September 30, 2021, these charges totaled $13 million and $40 million, respectively. For the three and nine months ended September 30, 2020, these charges totaled $29 million and $80 million, respectively.
MPC has also been advancing certain strategic priorities to lay a foundation for long-term success, including plans to optimize its assets and structurally lower costs in 2021 and beyond. In 2020, MPC approved and executed an involuntary workforce reduction plan, which together with employee reductions resulting from MPC’s indefinite idling of its Martinez, California and Gallup, New Mexico refineries, affected approximately 2,050 employees. All of the employees that conduct MPLX’s business are directly employed by affiliates of MPC, and certain of those employees were affected by MPC’s workforce reductions. During the third quarter of 2020, MPLX reimbursed MPC for $36 million related to severance and employee benefits related expenses that MPC recorded in connection with its workforce reductions. There were no such costs in the first nine months of 2021.
Related Party Assets and Liabilities
Assets and liabilities with related parties appearing on the Consolidated Balance Sheets are detailed in the table below. This table identifies the various components of related party assets and liabilities, including those associated with leases (see Note 18 for additional information) and deferred revenue on minimum volume commitments. If MPC fails to meet its minimum committed volumes, MPC will pay MPLX a deficiency payment based on the terms of the agreement. The deficiency amounts received under these agreements (excluding payments received under agreements classified as sales-type leases) are recorded as “Current liabilities - related parties.” In many cases, MPC may then apply the amount of any such deficiency payments as a credit for volumes in excess of its minimum volume commitment in future periods under the terms of the applicable agreements. MPLX recognizes related party revenues for the deficiency payments when credits are used for volumes in excess of minimum quarterly volume commitments, where it is probable the customer will not use the credit in future periods or upon the expiration of the credits. The use or expiration of the credits is a decrease in “Current liabilities - related parties.” Deficiency payments under agreements that have been classified as sales-type leases are recorded as a reduction against the corresponding lease receivable. In addition, capital projects MPLX undertakes at the request of MPC are reimbursed in cash and recognized as revenue over the remaining term of the applicable agreements or in some cases as a contribution from MPC.
Long-term deferred revenue - Project reimbursements - Other
7
7
Total
$
297
$
283
Other Related Party Transactions
From time to time, MPLX may also sell to or purchase from related parties, assets and inventory at the lesser of average unit cost or net realizable value. Sales to related parties for the nine months ended September 30, 2021 and 2020 were $19 million and $8 million, respectively. Purchases from related parties were immaterial for the nine months ended September 30, 2021 and 2020.
6. Equity
The changes in the number of common units during the nine months ended September 30, 2021 are summarized below:
(In units)
Common
Balance at December 31, 2020
1,038,777,978
Unit-based compensation awards
213,727
Units redeemed in unit repurchase program
(17,563,855)
Balance at September 30, 2021
1,021,427,850
Unit Repurchase Program
On November 2, 2020, MPLX announced the board authorization of a unit repurchase program for the repurchase of up to $1 billion of MPLX’s outstanding common units held by the public. MPLX may utilize various methods to effect the repurchases, which could include open market repurchases, negotiated block transactions, tender offers, accelerated unit repurchases or open market solicitations for units, some of which may be effected through Rule 10b5-1 plans. The timing and
amount of repurchases will depend upon several factors, including market and business conditions, and repurchases may be initiated, suspended or discontinued at any time. The repurchase authorization has no expiration date. During the nine months ended September 30, 2021, we repurchased 17,563,855 common units at an average cost per unit of $26.79 and paid $465 million of cash, with an additional $5 million of cash paid in early October in connection with the settlement of certain late September purchases. As of September 30, 2021, we had $497 million remaining under our repurchase authorization.
Series B Preferred Units
MPLX has outstanding 600,000 units of 6.875 percent Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units representing limited partner interests of MPLX with a price to the public of $1,000 per unit (the “Series B preferred units”). The Series B preferred units are pari passu with the Series A preferred units with respect to distribution rights and rights upon liquidation. Series B preferred unitholders are entitled to receive a fixed distribution of $68.75 per unit, per annum, payable semi-annually in arrears on the 15th day, or the first business day thereafter, of February and August of each year up to and including February 15, 2023. After February 15, 2023, the holders of Series B preferred units are entitled to receive cumulative, quarterly distributions payable in arrears on the 15th day of February, May, August and November of each year, or the first business day thereafter, based on a floating annual rate equal to the three-month LIBOR plus4.652 percent, in each case assuming a distribution is declared by the Board of Directors.
Cash distributions–On November 2, 2021, MPLX declared a cash distribution for the third quarter of 2021, totaling $1,305 million, or $1.28 per common unit, consisting of a base distribution amount of $0.705 per common unit and a special distribution amount of $0.575 per common unit (the “Special Distribution Amount”). This distribution will be paid on November 19, 2021 to common unitholders of record on November 12, 2021. This rate will also be received by Series A preferred unitholders.
Quarterly distributions for 2021 and 2020 are summarized below:
(Per common unit)
2021
2020
March 31,
$
0.6875
$
0.6875
June 30,
0.6875
0.6875
September 30,
$
1.2800
$
0.6875
In accordance with the distribution rights discussed above, MPLX made a cash distribution totaling $21 million to Series B unitholders on August 16, 2021.
The allocation of total quarterly cash distributions to limited and preferred unitholders is as follows for the three and nine months ended September 30, 2021 and 2020. Distributions, although earned, are not accrued until declared. MPLX’s distributions are declared subsequent to quarter end; therefore, the following table represents total cash distributions applicable to the period in which the distributions were earned.
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
2021
2020
Common and preferred unit distributions:
Common unitholders, includes common units of general partner (1)
$
1,305
$
715
$
2,717
$
2,158
Series A preferred unit distributions (1)
38
20
79
61
Series B preferred unit distributions
10
10
31
31
Total cash distributions declared
$
1,353
$
745
$
2,827
$
2,250
(1) 2021 periods include the Special Distribution Amount.
Net income/(loss) per unit applicable to common units is computed by dividing net income/(loss) attributable to MPLX LP less income/(loss) allocated to participating securities by the weighted average number of common units outstanding.
During the three and nine months ended September 30, 2021 and 2020, MPLX had participating securities consisting of common units, certain equity-based compensation awards, Series A preferred units and Series B preferred units and had dilutive potential common units consisting of certain equity-based compensation awards. Potential common units omitted from the diluted earnings per unit calculation for the three and nine months ended September 30, 2021 and 2020 were less than 1 million.
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
2021
2020
Net income/(loss) attributable to MPLX LP
$
802
$
665
$
2,247
$
(1,411)
Less: Distributions declared on Series A preferred units(1)
38
20
79
61
Distributions declared on Series B preferred units
10
10
31
31
Limited partners’ distributions declared on MPLX common units (including common units of general partner)(1)
1,305
715
2,717
2,158
Undistributed net loss attributable to MPLX LP
$
(551)
$
(80)
$
(580)
$
(3,661)
(1) 2021 periods include the Special Distribution Amount. See Note 6 for distribution information.
Three Months Ended September 30, 2021
(In millions, except per unit data)
Limited Partners’ Common Units
Series A Preferred Units
Series B Preferred Units
Total
Basic and diluted net income attributable to MPLX LP per unit
Net income attributable to MPLX LP:
Distributions declared(1)
$
1,305
$
38
$
10
$
1,353
Undistributed net loss attributable to MPLX LP
(551)
—
—
(551)
Net income attributable to MPLX LP(2)
$
754
$
38
$
10
$
802
Weighted average units outstanding:
Basic
1,024
Diluted
1,025
Net income attributable to MPLX LP per limited partner unit:
Basic
$
0.74
Diluted
$
0.74
(1) Includes the Special Distribution Amount.
(2) Allocation of net income attributable to MPLX LP assumes all earnings for the period had been distributed based on the distribution priorities applicable to the period.
Basic and diluted net income attributable to MPLX LP per unit
Net income attributable to MPLX LP:
Distributions declared
$
715
$
20
$
10
$
745
Undistributed net loss attributable to MPLX LP
(80)
—
—
(80)
Net income attributable to MPLX LP(1)
$
635
$
20
$
10
$
665
Weighted average units outstanding:
Basic
1,046
Diluted
1,047
Net income attributable to MPLX LP per limited partner unit:
Basic
$
0.61
Diluted
$
0.61
(1) Allocation of net income attributable to MPLX LP assumes all earnings for the period had been distributed based on the distribution priorities applicable to the period.
Nine Months Ended September 30, 2021
(In millions, except per unit data)
Limited Partners’ Common Units
Series A Preferred Units
Series B Preferred Units
Total
Basic and diluted net income attributable to MPLX LP per unit
Net income attributable to MPLX LP:
Distributions declared(1)
$
2,717
$
79
$
31
$
2,827
Undistributed net loss attributable to MPLX LP
(580)
—
—
(580)
Net income attributable to MPLX LP(2)
$
2,137
$
79
$
31
$
2,247
Weighted average units outstanding:
Basic
1,030
Diluted
1,030
Net income attributable to MPLX LP per limited partner unit:
Basic
$
2.07
Diluted
$
2.07
(1) Includes the Special Distribution Amount.
(2) Allocation of net income attributable to MPLX LP assumes all earnings for the period had been distributed based on the distribution priorities applicable to the period.
Basic and diluted net income attributable to MPLX LP per unit
Net income attributable to MPLX LP:
Distributions declared
$
2,158
$
61
$
31
$
2,250
Undistributed net loss attributable to MPLX LP
(3,661)
—
—
(3,661)
Net (loss)/income attributable to MPLX LP(1)
$
(1,503)
$
61
$
31
$
(1,411)
Weighted average units outstanding:
Basic
1,054
Diluted
1,054
Net income attributable to MPLX LP per limited partner unit:
Basic
$
(1.43)
Diluted
$
(1.43)
(1) Allocation of net income attributable to MPLX LP assumes all earnings for the period had been distributed based on the distribution priorities applicable to the period.
8. Series A Preferred Units
On November 2, 2021, MPLX declared a cash distribution of $1.28 per common unit for the third quarter of 2021. Holders of the Series A preferred units will receive the common unit rate in lieu of the lower $0.528125 base amount. Approximately 29.6 million Series A preferred units remaining outstanding as of September 30, 2021.
The changes in the redeemable preferred balance from December 31, 2020 through September 30, 2021 are summarized below:
(In millions)
Redeemable Series A Preferred Units
Balance at December 31, 2020
$
968
Net income allocated (1)
79
Distributions received by Series A preferred unitholders
(61)
Balance at September 30, 2021
$
986
(1) Includes the Special Distribution Amount.
9. Segment Information
MPLX’s chief operating decision maker is the chief executive officer (“CEO”) of its general partner. The CEO reviews MPLX’s discrete financial information, makes operating decisions, assesses financial performance and allocates resources on a type of service basis. MPLX has two reportable segments: L&S and G&P. Each of these segments is organized and managed based upon the nature of the products and services it offers.
•L&S – transports, stores, distributes and markets crude oil, asphalt, refined petroleum products and water. Also includes an inland marine business, terminals, rail facilities, storage caverns and refining logistics.
•G&P – gathers, processes and transports natural gas; and gathers, transports, fractionates, stores and markets NGLs.
Our CEO evaluates the performance of our segments using Segment Adjusted EBITDA. Amounts included in net income and excluded from Segment Adjusted EBITDA include: (i) depreciation and amortization; (ii) provision/(benefit) for income taxes; (iii) amortization of deferred financing costs; (iv) gain/(loss) on extinguishment of debt; (v) non-cash equity-based compensation; (vi) impairment expense; (vii) net interest and other financial costs; (viii) income/(loss) from equity method investments; (ix) distributions and adjustments related to equity method investments; (x) unrealized derivative gains/(losses); (xi) acquisition costs; (xii) noncontrolling interest; and (xiii) other adjustments as deemed necessary. These items are either: (i) believed to be non-recurring in nature; (ii) not believed to be allocable or controlled by the segment; or (iii) are not tied to the operational performance of the segment.
The tables below present information about revenues and other income, Segment Adjusted EBITDA, restructuring expenses, capital expenditures and investments in unconsolidated affiliates as well as total assets for our reportable segments:
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
2021
2020
L&S
Service revenue
$
983
$
989
$
2,928
$
2,924
Rental income
172
249
597
737
Product related revenue
3
9
11
49
Sales-type lease revenue - related parties
132
38
305
114
Income from equity method investments
41
36
112
126
Other income
15
13
46
40
Total segment revenues and other income(1)
1,346
1,334
3,999
3,990
Segment Adjusted EBITDA(2)
904
893
2,747
2,604
Restructuring expenses
—
27
—
27
Capital expenditures
85
118
220
410
Investments in unconsolidated affiliates
9
4
31
132
G&P
Service revenue
519
524
1,520
1,549
Rental income
80
94
263
271
Product related revenue
553
234
1,357
607
Income/(loss) from equity method investments
51
47
116
(1,138)
Other income
10
14
38
41
Total segment revenues and other income(1)
1,213
913
3,294
1,330
Segment Adjusted EBITDA(2)
485
442
1,368
1,252
Restructuring expenses
—
9
—
9
Capital expenditures
69
131
135
375
Investments in unconsolidated affiliates
$
23
$
18
$
85
$
112
(1) Within the total segment revenues and other income amounts presented above, third party revenues for the L&S segment were $138 million and $405 million for the three and nine months ended September 30, 2021, respectively, and $139 million and $443 million for the three and nine months ended September 30, 2020, respectively. Third party revenues for the G&P segment were $1,170 million and $3,147 million for the three and nine months ended September 30, 2021, respectively, and $858 million and $1,181 million for the three and nine months ended September 30, 2020, respectively.
(2) See below for the reconciliation from Segment Adjusted EBITDA to “Net income/(loss).”
The table below provides a reconciliation between “Net income/(loss)” and Segment Adjusted EBITDA.
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
2021
2020
Reconciliation to Net income/(loss):
L&S Segment Adjusted EBITDA
$
904
$
893
$
2,747
$
2,604
G&P Segment Adjusted EBITDA
485
442
1,368
1,252
Total reportable segments
1,389
1,335
4,115
3,856
Depreciation and amortization(1)
(324)
(346)
(971)
(992)
Provision for income taxes
—
(1)
(1)
(1)
Amortization of deferred financing costs
(18)
(15)
(53)
(44)
Non-cash equity-based compensation
(1)
(4)
(6)
(12)
Impairment expense
—
—
(42)
(2,165)
Net interest and other financial costs
(200)
(223)
(618)
(647)
Gain on extinguishment of debt
(2)
14
10
14
Income/(loss) from equity method investments
92
83
228
(1,012)
Distributions/adjustments related to equity method investments
(129)
(130)
(371)
(369)
Unrealized derivative losses(2)
(2)
(10)
(41)
(1)
Restructuring expenses
—
(36)
—
(36)
Other
(3)
(3)
(5)
(5)
Adjusted EBITDA attributable to noncontrolling interests
9
10
29
27
Net income/(loss)
$
811
$
674
$
2,274
$
(1,387)
(1) Depreciation and amortization attributable to L&S was $131 million and $414 million for the three and nine months ended September 30, 2021, respectively, and $164 million and $440 million for the three and nine months ended September 30, 2020, respectively. Depreciation and amortization attributable to G&P was $193 million and $557 million for the three and nine months ended September 30, 2021, respectively, and $182 million and $552 million for the three and nine months ended September 30, 2020, respectively.
(2) MPLX makes a distinction between realized and unrealized gains and losses on derivatives. During the period when a derivative contract is outstanding, changes in the fair value of the derivative are recorded as an unrealized gain or loss. When a derivative contract matures or is settled, the previously recorded unrealized gain or loss is reversed and the realized gain or loss of the contract is recorded.
Property, plant and equipment with associated accumulated depreciation is shown below:
September 30, 2021
December 31, 2020
(In millions)
Gross PP&E
Accumulated Depreciation
Net PP&E
Gross PP&E
Accumulated Depreciation
Net PP&E
L&S
$
12,296
$
3,108
$
9,188
$
12,813
$
2,997
$
9,816
G&P
14,115
3,145
10,970
14,062
2,660
11,402
Total
$
26,411
$
6,253
$
20,158
$
26,875
$
5,657
$
21,218
Long-lived assets used in operations are assessed for impairment whenever changes in facts and circumstances indicate that the carrying value of the assets may not be recoverable based on the expected undiscounted future cash flow of an asset group. For purposes of impairment evaluation, long-lived assets must be grouped at the lowest level for which independent cash flows can be identified, which is at least at the segment level and in some cases for similar assets in the same geographic region where cash flows can be separately identified. If the sum of the undiscounted cash flows is less than the carrying value of an asset group, fair value is calculated, and the carrying value is written down if greater than the calculated fair value.
During the first quarter of 2020, we identified an impairment trigger relating to asset groups within our Western G&P reporting unit as a result of significant impacts to forecasted cash flows for these asset groups resulting from the first quarter of 2020 events and circumstances as discussed in Note 1. The cash flows associated with these assets were significantly impacted by volume declines reflecting decreased forecasted producer customer production as a result of lower commodity prices. After assessing each asset group within the Western G&P reporting unit for impairment, only the East Texas G&P asset group resulted in the fair value of the underlying assets being less than the carrying value. As a result, an impairment of $174 million was recorded to “Impairment expense” on the Consolidated Statements of Income in the first quarter of 2020. See Note 1 for discussion of 2021 impairments.
12. Goodwill and Intangibles
Goodwill
During the first quarter of 2020, we performed an interim impairment analysis of the goodwill recorded based on consideration of a number of first quarter events and circumstances as discussed in Note 1. Our producer customers in our Eastern G&P region reduced production forecasts and drilling activity in response to the global economic downturn. Additionally, a decline in NGL prices impacted our future revenue forecast. As a result of the interim impairment analysis, we recorded an impairment of $1,814 million within the Eastern G&P reporting unit, which was recorded to “Impairment expense” on the Consolidated Statements of Income. The impairment was primarily driven by additional guidance related to the slowing of drilling activity, which reduced production growth forecasts from our producer customers.
Changes in the carrying amount of goodwill were as follows:
During the first quarter of 2020, we also determined that an impairment analysis of intangibles within our Western G&P reporting unit was necessary. See Note 11 for additional information regarding our assessment around the Western G&P reporting unit, and more specifically our East Texas G&P asset group. The fair value of the intangibles in our East Texas G&P asset group was determined based on applying the multi-period excess earnings method, which is an income approach. Key assumptions included management’s best estimates of the expected future cash flows from existing customers, customer attrition rates and the discount rate. After performing our evaluations related to the impairment of intangible assets associated with our East Texas G&P asset group during the first quarter of 2020, we recorded an impairment of $177 million to “Impairment expense” on the Consolidated Statements of Income related to our customer relationships. No additional impairments have been recorded since that time.
13. Fair Value Measurements
Fair Values – Recurring
Fair value measurements and disclosures relate primarily to MPLX’s derivative positions as discussed in Note 14. The following table presents the financial instruments carried at fair value on a recurring basis as of September 30, 2021 and December 31, 2020 by fair value hierarchy level. MPLX has elected to offset the fair value amounts recognized for multiple derivative contracts executed with the same counterparty.
September 30, 2021
December 31, 2020
(In millions)
Assets
Liabilities
Assets
Liabilities
Significant unobservable inputs (Level 3)
Embedded derivatives in commodity contracts
$
—
$
(104)
$
—
$
(63)
Total carrying value on Consolidated Balance Sheets
$
—
$
(104)
$
—
$
(63)
Level 3 instruments include an embedded derivative in commodity contracts. The embedded derivative liability relates to a natural gas purchase commitment embedded in a keep-whole processing agreement. The fair value calculation for these Level 3 instruments used significant unobservable inputs including: (1) NGL prices interpolated and extrapolated due to inactive markets ranging from $0.68 to $1.80 per gallon with a weighted average of $0.88 per gallon and (2) the probability of renewal of 100 percent for the first five-year term and second five-year term of the gas purchase commitment and related keep-whole processing agreement. Increases or decreases in the fractionation spread result in an increase or decrease in the fair value of the embedded derivative liability, respectively. Beyond the embedded derivative discussed above, we had no outstanding commodity derivative contracts as of September 30, 2021 or December 31, 2020.
Changes in Level 3 Fair Value Measurements
The following table is a reconciliation of the net beginning and ending balances recorded for net assets and liabilities classified as Level 3 in the fair value hierarchy.
Three Months Ended September 30, 2021
Three Months Ended September 30, 2020
(In millions)
Commodity Derivative Contracts (net)
Embedded Derivatives in Commodity Contracts (net)
Commodity Derivative Contracts (net)
Embedded Derivatives in Commodity Contracts (net)
Fair value at beginning of period
$
—
$
(102)
$
—
$
(51)
Total losses (realized and unrealized) included in earnings(1)
—
(7)
—
(12)
Settlements
—
5
—
2
Fair value at end of period
—
(104)
—
(61)
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to liabilities still held at end of period
Total losses (realized and unrealized) included in earnings(1)
—
(52)
—
(5)
Settlements
—
11
—
4
Fair value at end of period
—
(104)
—
(61)
The amount of total losses for the period included in earnings attributable to the change in unrealized losses relating to liabilities still held at end of period
$
—
$
(44)
$
—
$
(2)
(1) Gains and losses on derivatives embedded in commodity contracts are recorded in “Purchased product costs” on the Consolidated Statements of Income.
Fair Values – Reported
MPLX’s primary financial instruments are cash and cash equivalents, receivables, receivables from related parties, lease receivables from related parties, accounts payable, payables to related parties and debt. MPLX’s fair value assessment incorporates a variety of considerations, including (1) the duration of the instruments, (2) MPC’s investment-grade credit rating and (3) the historical incurrence of and expected future insignificance of bad debt expense, which includes an evaluation of counterparty credit risk. MPLX believes the carrying values of its current assets and liabilities approximate fair value. The recorded value of the amounts outstanding under the bank revolving credit facility, if any, approximate fair value due to the variable interest rate that approximates current market rates. Derivative instruments are recorded at fair value, based on available market information (see Note 14).
The fair value of MPLX’s debt is estimated based on recent market non-binding indicative quotes. The debt fair values are considered Level 3 measurements. The following table summarizes the fair value and carrying value of our third-party debt, excluding finance leases:
September 30, 2021
December 31, 2020
(In millions)
Fair Value
Carrying Value
Fair Value
Carrying Value
Outstanding debt(1)
$
20,553
$
18,350
$
22,951
$
20,244
(1) Amounts outstanding under the MPC Loan Agreement are not included in the table above, as the carrying value approximates fair value. This balance is reflected in “Current liabilities - related parties” on the Consolidated Balance Sheets.
14. Derivative Financial Instruments
As of September 30, 2021, MPLX had no outstanding commodity contracts beyond the embedded derivative discussed below.
Embedded Derivative - MPLX has a natural gas purchase commitment embedded in a keep-whole processing agreement with a producer customer in the Southern Appalachian region expiring in December 2022. The customer has the unilateral option to extend the agreement for two consecutive five-year terms through December 2032. For accounting purposes, the natural gas purchase commitment and the term extending options have been aggregated into a single compound embedded derivative. The probability of the customer exercising its options is determined based on assumptions about the customer’s potential business strategy decision points that may exist at the time they would elect whether to renew the contract. The changes in fair value of this compound embedded derivative are based on the difference between the contractual and index pricing, the probability of the producer customer exercising its option to extend and the estimated favorability of these contracts compared to current market conditions. The changes in fair value are recorded in earnings through “Purchased product costs” on the Consolidated Statements of Income. For further information regarding the fair value measurement of derivative instruments, see Note 13. As of September 30, 2021 and December 31, 2020, the estimated fair value of this contract was a liability of $104 million and $63 million, respectively.
Certain derivative positions are subject to master netting agreements, therefore, MPLX has elected to offset derivative assets and liabilities that are legally permissible to be offset. As of September 30, 2021 and December 31, 2020, there were no derivative assets or liabilities that were offset on the Consolidated Balance Sheets. The impact of MPLX’s derivative instruments on its Consolidated Balance Sheets is summarized below:
(In millions)
September 30, 2021
December 31, 2020
Derivative contracts not designated as hedging instruments and their balance sheet location
Asset
Liability
Asset
Liability
Commodity contracts(1)
Other current assets / Other current liabilities
$
—
$
(15)
$
—
$
(7)
Other noncurrent assets / Deferred credits and other liabilities
—
(89)
—
(56)
Total
$
—
$
(104)
$
—
$
(63)
(1) Includes the embedded derivative in the commodity contract discussed above.
The impact of MPLX’s derivative contracts not designated as hedging instruments and the location of gains and losses recognized on the Consolidated Statements of Income is summarized below:
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
2021
2020
Purchased product costs
Realized loss
$
(5)
$
(2)
$
(11)
$
(4)
Unrealized loss
(2)
(10)
(41)
(1)
Purchased product costs derivative loss
(7)
(12)
(52)
(5)
Total derivative loss
$
(7)
$
(12)
$
(52)
$
(5)
15. Debt
MPLX’s outstanding borrowings consist of the following:
(In millions)
September 30, 2021
December 31, 2020
MPLX LP:
Bank revolving credit facility
$
—
$
175
Floating rate senior notes
—
1,000
Fixed rate senior notes
18,532
19,240
Consolidated subsidiaries:
MarkWest
23
23
ANDX
45
87
Financing lease obligations
9
11
Total
18,609
20,536
Unamortized debt issuance costs
(105)
(116)
Unamortized discount/premium
(250)
(281)
Amounts due within one year
(1)
(764)
Total long-term debt due after one year
$
18,253
$
19,375
Credit Agreement
MPLX’s amended and restated credit agreement (as amended, the “MPLX Credit Agreement”), provides for borrowings up to $3.5 billion and a term that extends to July 2024. During the nine months ended September 30, 2021, MPLX borrowed $3.0 billion under the MPLX Credit Agreement, at an average interest rate of 1.345 percent,and repaid $3.175 billion. At September 30, 2021, MPLX had no outstanding borrowings and less than $1 million in letters of credit outstanding under the MPLX Credit Agreement, resulting in total availability of $3.5 billion, or 100 percent of the borrowing capacity.
On September 3, 2021 MPLX redeemed, at par value, all of the $1.0 billion aggregate principal amount of floating rate senior notes due September 2022, which resulted in the immediate expense recognition of $2 million of unamortized debt issuance costs. These costs are included on the Consolidated Statements of Income as “Other financial costs.” This redemption was funded primarily by borrowings under the MPC Loan Agreement.
Fixed Rate Senior Notes
MPLX’s senior notes, including those issued by consolidated subsidiaries, consist of various series of senior notes expiring between 2022 and 2058 with interest rates ranging from 1.750 percent to 5.500 percent. Interest on each series of notes is payable semi-annually in arrears on various dates depending on the series of the notes.
On January 15, 2021 MPLX redeemed all of the $750 million outstanding aggregate principal amount of 5.250 percent senior notes due January 15, 2025, including approximately $42 million aggregate principal amount of senior notes issued by ANDX at a price equal to 102.625 percent of the principal amount. The payment of $20 million related to the note premium, offset by the immediate expense recognition of $12 million of unamortized debt premium and issuance costs, resulted in a loss on extinguishment of debt of $8 million that is included on the Consolidated Statements of Income as “Other financial costs.”
16. Revenue
Disaggregation of Revenue
The following tables represent a disaggregation of revenue for each reportable segment for the three and nine months ended September 30, 2021 and 2020:
(1) Non-ASC 606 Revenue includes rental income, sales-type lease revenue, income/(loss) from equity method investments, derivative gains and losses, mark-to-market adjustments, and other income.
Contract Balances
Contract assets typically relate to aid in construction agreements where the revenue recognized and MPLX’s rights to consideration for work completed exceeds the amount billed to the customer. Contract assets are included in “Other current assets” and “Other noncurrent assets” on the Consolidated Balance Sheets.
Contract liabilities, which we refer to as “Deferred revenue” and “Long-term deferred revenue,” typically relate to advance payments for aid in construction agreements and deferred customer credits associated with makeup rights and minimum volume commitments. Related to minimum volume commitments, breakage is estimated and recognized into service revenue in instances where it is probable the customer will not use the credit in future periods. We classify contract liabilities as current or long-term based on the timing of when we expect to recognize revenue.
“Receivables, net” primarily relate to our commodity sales. Portions of the “Receivables, net” balance are attributed to the sale of commodity product controlled by MPLX prior to sale while a significant portion of the balance relates to the sale of commodity product on behalf of our producer customers. The sales and related “Receivable, net” are commingled and excluded from the table below. MPLX remits the net sales price back to our producer customers upon completion of the sale. Each period end, certain amounts within accounts payable relate to our payments to producer customers. Such amounts are not deemed material at period end as a result of when we settle with each producer.
The tables below reflect the changes in our contract balances for the nine-month periods ended September 30, 2021 and 2020:
(In millions)
Balance at December 31, 2020(1)
Additions/ (Deletions)
Revenue Recognized(2)
Balance at September 30, 2021
Contract assets
$
40
$
(21)
$
1
$
20
Long-term contract assets
2
—
—
2
Deferred revenue
37
40
(27)
50
Deferred revenue - related parties
91
59
(77)
73
Long-term deferred revenue
119
11
—
130
Long-term deferred revenue - related parties
48
(12)
—
36
Long-term contract liability
$
6
$
—
$
—
$
6
(In millions)
Balance at December 31, 2019(1)
Additions/ (Deletions)
Revenue Recognized(2)
Balance at September 30, 2020
Contract assets
$
39
$
(9)
$
(1)
$
29
Deferred revenue
23
16
(6)
33
Deferred revenue - related parties
53
77
(60)
70
Long-term deferred revenue
90
25
—
115
Long-term deferred revenue - related parties
$
55
$
(7)
$
—
$
48
(1) Balance represents ASC 606 portion of each respective line item.
(2) No significant revenue was recognized related to past performance obligations in the current periods.
Remaining Performance Obligations
The table below includes estimated revenue expected to be recognized in the future related to performance obligations that are unsatisfied (or partially unsatisfied) at the end of the reporting period.
As of September 30, 2021, the amounts allocated to contract assets and contract liabilities on the Consolidated Balance Sheets are $288 million and are reflected in the amounts below. This will be recognized as revenue as the obligations are satisfied, which is expected to occur over the next 22 years. Further, MPLX does not disclose variable consideration due to volume variability in the table below.
(In millions)
2021
$
476
2022
1,795
2023
1,656
2024
1,524
2025 and thereafter
4,484
Total revenue on remaining performance obligations(1),(2),(3)
$
9,935
(1) All fixed consideration from contracts with customers is included in the amounts presented above. Variable consideration that is constrained or not required to be estimated as it reflects our efforts to perform is excluded.
(2) Arrangements deemed implicit leases and sales-type leases are excluded from this table, see further discussion about leases in Note 18.
(3) Only minimum volume commitments that are deemed fixed are included in the table above. MPLX has various minimum volume commitments in processing arrangements that vary based on the actual Btu content of the gas received. These amounts are deemed variable consideration and are excluded from the table above.
We do not disclose information on the future performance obligations for any contract with an original expected duration of one year or less.
Net cash provided by operating activities included:
Interest paid (net of amounts capitalized)
$
627
$
631
Income taxes paid
2
1
Non-cash investing and financing activities:
Net transfers of property, plant and equipment (to)/from materials and supplies inventories
1
(1)
Fair value of common units redeemed for Wholesale Exchange
$
—
$
340
The Consolidated Statements of Cash Flows exclude changes to the Consolidated Balance Sheets that do not affect cash. The following is the change of additions to property, plant and equipment related to capital accruals:
Nine Months Ended September 30,
(In millions)
2021
2020
Decrease in capital accruals
$
(19)
$
(197)
18. Leases
During the second quarter of 2021 and during the first quarter of 2020, reimbursements for projects and changes to minimum volume commitments at certain L&S locations were agreed to between MPLX and MPC. These reimbursements and minimum volume commitments relate to the storage services agreements between MPLX and MPC at these locations and required the embedded leases within these agreements to be reassessed under ASC 842. As a result of the reassessment, certain leases were reclassified from an operating lease to a sales-type lease. Accordingly, the underlying assets previously shown on the Consolidated Balance Sheets associated with the sales-type leases were derecognized and the net investment in the lease (i.e., the sum of the present value of the future lease payments and the unguaranteed residual value of the assets) was recorded as a lease receivable during the respective periods. See Note 5 for the location of lease receivables and unguaranteed residual assets on the Consolidated Balance Sheets. The difference between the net book value of the underlying assets and the net investment in the lease has been recorded as a “Contribution from MPC” in the Consolidated Statements of Equity given the impacted storage services agreements are related to a common control transaction. During the second quarter of 2021, MPLX derecognized approximately $421 million of property, plant and equipment, recorded a lease receivable of approximately $519 million, recorded an unguaranteed residual asset of approximately $14 million with the difference recorded as a deemed “Contribution from MPC” of $112 million. During the first quarter of 2020, MPLX derecognized approximately $171 million of property, plant and equipment, recorded a lease receivable of approximately $370 million, recorded an unguaranteed residual asset of approximately $10 million with the difference recorded as a deemed “Contribution from MPC” of $209 million.
Lease revenues included on the Consolidated Statements of Income were as follows:
Three Months Ended September 30, 2021
Three Months Ended September 30, 2020
(In millions)
Related Party
Third Party
Related Party
Third Party
Operating leases:
Operating lease revenue(1)
$
139
$
56
$
208
$
70
Sales-type leases:
Profit/(loss) recognized at the commencement date
—
—
—
—
Interest income (Sales-type lease revenue- fixed minimum)
133
—
37
—
Interest income (Revenue from variable lease payments)
Interest income (Sales-type lease revenue- fixed minimum)
305
—
113
—
Interest income (Revenue from variable lease payments)
$
—
$
—
$
1
$
—
(1) These amounts are presented net of executory costs.
See Note 5 for additional information on where related party lease assets are recorded in the Consolidated Balance Sheets. Capital expenditures related to assets subject to sales-type lease arrangements were $33 million for the three and nine months ended September 30, 2021. Third party lease assets are less than $1 million as of September 30, 2021 and are included within the “Receivables, net” and “Other noncurrent assets” captions within the Consolidated Balance Sheets.
The following is a schedule of future payments on the sales-type leases as of September 30, 2021:
(In millions)
Related Party
2021
$
136
2022
543
2023
544
2024
538
2025
525
2026 and thereafter
1,018
Total minimum future rentals
3,304
Less: present value discount
2,371
Lease receivable
$
933
19. Commitments and Contingencies
MPLX is the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. Some of these matters are discussed below. For matters for which MPLX has not recorded a liability, MPLX is unable to estimate a range of possible loss because the issues involved have not been fully developed through pleadings, discovery or court proceedings. However, the ultimate resolution of some of these contingencies could, individually or in the aggregate, be material.
Environmental Matters – MPLX is subject to federal, state and local laws and regulations relating to the environment. These laws generally provide for control of pollutants released into the environment and require responsible parties to undertake remediation of hazardous waste disposal sites. Penalties may be imposed for non-compliance.
At September 30, 2021 and December 31, 2020, accrued liabilities for remediation totaled $22 million and $17 million, respectively. It is not presently possible to estimate the ultimate amount of all remediation costs that might be incurred or the penalties, if any, that may be imposed. At September 30, 2021 and December 31, 2020, there were no balances with MPC for indemnification of environmental costs.
MPLX is involved in environmental enforcement matters arising in the ordinary course of business. While the outcome and impact to MPLX cannot be predicted with certainty, management believes the resolution of these environmental matters will not, individually or collectively, have a material adverse effect on its consolidated results of operations, financial position or cash flows.
MPLX is also a party to a number of other lawsuits and other proceedings arising in the ordinary course of business. While the ultimate outcome and impact to MPLX cannot be predicted with certainty, management believes the resolution of these other lawsuits and proceedings will not, individually or collectively, have a material adverse effect on its consolidated financial position, results of operations or cash flows.
Guarantees – Over the years, MPLX has sold various assets in the normal course of its business. Certain of the related agreements contain performance and general guarantees, including guarantees regarding inaccuracies in representations, warranties, covenants and agreements, and environmental and general indemnifications that require MPLX to perform upon the occurrence of a triggering event or condition. These guarantees and indemnifications are part of the normal course of selling assets. MPLX is typically not able to calculate the maximum potential amount of future payments that could be made under such contractual provisions because of the variability inherent in the guarantees and indemnities. Most often, the nature of the guarantees and indemnities is such that there is no appropriate method for quantifying the exposure because the underlying triggering event has little or no past experience upon which a reasonable prediction of the outcome can be based.
We hold a 9.19 percent indirect interest in a joint venture (“Dakota Access”) that owns and operates the Dakota Access Pipeline and Energy Transfer Crude Oil Pipeline projects, collectively referred to as the Bakken Pipeline system or DAPL. In 2020, the U.S. District Court for the District of Columbia (the “D.D.C.”) ordered the U.S. Army Corps of Engineers (“Army Corps”), which granted permits and an easement for the Bakken Pipeline system, to prepare an environmental impact statement (“EIS”) relating to an easement under Lake Oahe in North Dakota. The D.D.C. later ordered vacatur of the easement during the pendency of the EIS and further ordered a shut down of the pipeline by August 5, 2020. On August 5, 2020, the U.S. Court of Appeals for the District of Columbia (the “Court of Appeals”) stayed the D.D.C.’s injunction that required the pipeline be shutdown and emptied of oil by August 5, 2020. On January 26, 2021, the Court of Appeals upheld the D.D.C.’s order vacating the easement while the Army Corps prepares the EIS. The Court of Appeals reversed the D.D.C.’s order to the extent it directed that the pipeline be shutdown and emptied of oil. In May 2021, the D.D.C. denied a renewed request for an injunction to shut down the pipeline while the EIS is being prepared. In June 2021, the D.D.C. issued an order dismissing without prejudice the tribes’ claims against the Dakota Access Pipeline. The judge noted that the plaintiffs may move to reopen the case in the event of a violation of the court’s prior orders. Dakota Access has petitioned the U.S. Supreme Court for review of the Court of Appeal’s decision upholding the D.D.C.’s order vacating the easement. The pipeline remains operational.
We have entered into a Contingent Equity Contribution Agreement whereby MPLX LP, along with the other joint venture owners in the Bakken Pipeline system, has agreed to make equity contributions to the joint venture upon certain events occurring to allow the entities that own and operate the Bakken Pipeline system to satisfy their senior note payment obligations. The senior notes were issued to repay amounts owed by the pipeline companies to fund the cost of construction of the Bakken Pipeline system. If the pipeline were temporarily shut down, MPLX would have to contribute its 9.19 percent pro rata share of funds required to pay interest accruing on the notes and any portion of the principal that matures while the pipeline is shutdown. MPLX also expects to contribute its 9.19 percent pro rata share of any costs to remediate any deficiencies to reinstate the permit and/or return the pipeline into operation. If the vacatur of the easement permit results in a permanent shutdown of the pipeline, MPLX would have to contribute its 9.19 percent pro rata share of the cost to redeem the bonds (including the 1% redemption premium required pursuant to the indenture governing the notes) and any accrued and unpaid interest. As of September 30, 2021, our maximum potential undiscounted payments under the Contingent Equity Contribution Agreement were approximately $230 million.
Other Legal Proceedings – In early July 2020, Tesoro High Plains Pipeline Company, LLC (“THPP”), a subsidiary of MPLX, received a Notification of Trespass Determination from the Bureau of Indian Affairs (“BIA”) relating to a portion of the Tesoro High Plains Pipeline that crosses the Fort Berthold Reservation in North Dakota. The notification covered the rights of way for 23 tracts of land and demanded the immediate cessation of pipeline operations. The notification also assessed trespass damages of approximately $187 million. THPP appealed this determination, which triggered an automatic stay of the requested pipeline shutdown and payment. On October 29, 2020, the Assistant Secretary - Indian Affairs issued an order vacating the BIA’s trespass order and requiring the Regional Director for the BIA Great Plains Region to issue a new decision on or before December 15 covering all 34 tracts at issue. On December 15, 2020, the Regional Director of the BIA issued a new trespass notice to THPP consistent with the Assistant Secretary - Indian Affairs order vacating the prior trespass order. The new order found that THPP was in trespass and assessed trespass damages of approximately $4 million (including interest), which has been paid. The order also required THPP to immediately cease and desist use of the portion of the pipeline that crosses the property at issue. THPP has complied with the Regional Director’s December 15, 2020 notice. On February 12, 2021, landowners filed suit in the U.S. District Court for the District of North Dakota (the “District of North Dakota”) against THPP, the Department of the Interior, the Assistant Secretary - Indian Affairs, the Interior Board of Indian Appeals and the BIA, requesting, among other things, that decisions by the Assistant Secretary - Indian Affairs and the Interior Board of Indian Appeals be vacated as to the award of damages to plaintiffs. In March 2021, THPP received a copy of an order purporting to vacate all orders related to THPP’s alleged trespass issued by the BIA between July 2, 2020 and January 14, 2021. The order
directs the Regional Director of the BIA to reconsider the issue of THPP’s alleged trespass and issue a new order, if necessary, after all interested parties have had an opportunity to be heard. Subsequently, landowners voluntarily dismissed the suit filed in the District of North Dakota. On April 23, 2021, THPP filed a lawsuit in the District of North Dakota against the United States of America, the U.S. Department of the Interior and the BIA challenging the March order purporting to vacate all previous orders related to THPP’s alleged trespass.
We continue to work towards a settlement of this matter with holders of the property rights at issue.
Contractual Commitments and Contingencies – In the ordinary course of business, MPLX and its affiliates provide guarantees of MPLX’s subsidiaries payment and performance obligations in the G&P segment. Certain natural gas processing and gathering arrangements require MPLX to construct new natural gas processing plants, natural gas gathering pipelines and NGL pipelines and contain certain fees and charges if specified construction milestones are not achieved for reasons other than force majeure. In certain cases, certain producers may have the right to cancel the processing arrangements if there are significant delays that are not due to force majeure. As of September 30, 2021, management does not believe there are any indications that MPLX will not be able to meet the construction milestones, that force majeure does not apply or that such fees and charges will otherwise be triggered.
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
Management’s Discussion and Analysis of Financial Condition and Results of Operations should also be read in conjunction with the unaudited consolidated financial statements and accompanying footnotes included under Item 1. Financial Statements and in conjunction with our Annual Report on Form 10-K for the year ended December 31, 2020.
Disclosures Regarding Forward-Looking Statements
This Quarterly Report on Form 10-Q, particularly Management’s Discussion and Analysis of Financial Condition and Results of Operations and Quantitative and Qualitative Disclosures about Market Risk, includes forward-looking statements that are subject to risks, contingencies or uncertainties. You can identify forward-looking statements by words such as “anticipate,” “believe,” “commitment,” “could,” “design,” “estimate,” “expect,” “forecast,” “goal,” “guidance,” “imply,” “intend,” “may,” “objective,” “opportunity,” “outlook,” “plan,” “policy,” “position,” “potential,” “predict,” “priority,” “project,” “proposition,” “prospective,” “pursue,” “seek,” “should,” “strategy,” “target,” “will,” “would” or other similar expressions that convey the uncertainty of future events or outcomes.
Forward-looking statements include, among other things, statements regarding:
•future financial and operating results;
•environmental, social and governance (“ESG”) goals and targets, including those related to greenhouse gas emissions, diversity and inclusion and ESG reporting;
•our plans to achieve our ESG goals and targets and to monitor and report progress thereon;
•the success or timing of completion of ongoing or anticipated capital or maintenance projects;
•the timing and amount of future distributions or unit repurchases; and
•the anticipated effects of actions of third parties such as competitors, activist investors, federal, foreign, state or local regulatory authorities, or plaintiffs in litigation.
Our forward-looking statements are not guarantees of future performance and you should not rely unduly on them, as they involve risks, uncertainties and assumptions. Material differences between actual results and any future performance suggested in our forward-looking statements could result from a variety of factors, including the following:
•general economic, political or regulatory developments, including inflation, changes in governmental policies relating to refined petroleum products, crude oil, natural gas or NGLs, or taxation;
•the magnitude, duration and extent of future resurgences of the COVID-19 pandemic and its restrictions, including travel restrictions, business and school closures, increased remote work, stay-at-home orders and other actions taken by individuals, governments and the private sector to stem the spread of the virus;
•the ability of MPC to achieve its strategic objectives and the effects of those strategic decisions on us;
•further impairments;
•negative capital market conditions, including an increase of the current yield on common units;
•the ability to achieve strategic and financial objectives, including with respect to distribution coverage, future distribution levels, proposed projects and completed transactions;
•the success of MPC’s portfolio optimization, including the ability to complete any divestitures on commercially reasonable terms and/or within the expected timeframe, and the effects of any such divestitures on our business, financial condition, results of operations and cash flows;
•the adequacy of capital resources and liquidity, including the availability of sufficient cash flow to pay distributions and access to debt on commercially reasonable terms, and the ability to successfully execute business plans, growth strategies and self-funding models;
•the timing and extent of changes in commodity prices and demand for crude oil, refined products, feedstocks or other hydrocarbon-based products;
•volatility in or degradation of market and industry conditions;
•changes to the expected construction costs and timing of projects and planned investments, and the ability to obtain regulatory and other approvals with respect thereto;
•completion of midstream infrastructure by competitors;
•disruptions due to equipment interruption or failure, including electrical shortages and power grid failures;
•the suspension, reduction or termination of MPC’s obligations under MPLX’s commercial agreements;
•modifications to financial policies, capital budgets, and earnings and distributions;
•the ability to manage disruptions in credit markets or changes to credit ratings;
•compliance with federal and state environmental, economic, health and safety, energy and other policies and regulations or enforcement actions initiated thereunder;
•adverse results in litigation;
•the effect of restructuring or reorganization of business components;
•the potential effects of changes in tariff rates on our business, financial condition, results of operations and cash flows;
•changes in foreign imports and exports of crude oil, refined products, natural gas and NGLs;
•changes in producer customers’ drilling plans or in volumes of throughput of crude oil, natural gas, NGLs, refined products or other hydrocarbon-based products;
•changes in the cost or availability of third-party vessels, pipelines, railcars and other means of transportation for crude oil, natural gas, NGLs, feedstocks and refined products;
•the price, availability and acceptance of alternative fuels and alternative-fuel vehicles and laws mandating such fuels or vehicles;
•actions taken by our competitors, including pricing adjustments and the expansion and retirement of pipeline capacity, processing, fractionation and treating facilities in response to market conditions;
•expectations regarding joint venture arrangements and other acquisitions or divestitures of assets;
•midstream and refining industry overcapacity or under capacity;
•accidents or other unscheduled shutdowns affecting our machinery, pipelines, processing, fractionation and treating facilities or equipment, means of transportation, or those of our suppliers or customers;
•acts of war, terrorism or civil unrest that could impair our ability to gather, process, fractionate or transport crude oil, natural gas, NGLs or refined products; and
•political pressure and influence of environmental groups upon policies and decisions related to the production, gathering, refining, processing, fractionation, transportation and marketing of crude oil or other feedstocks, refined products, natural gas, NGLs or other hydrocarbon-based products.
For additional risk factors affecting our business, see the risk factors described in our Annual Report on Form 10-K for the year ended December 31, 2020. We undertake no obligation to update any forward-looking statement except to the extent required by applicable law.
MPLX OVERVIEW
We are a diversified, large-cap MLP formed by MPC, that owns and operates midstream energy infrastructure and logistics assets, and provides fuels distribution services. The business consists of two segments based on the nature of services it offers: Logistics and Storage (“L&S”), and Gathering and Processing (“G&P”). The L&S segment is engaged in the transportation, storage, distribution and marketing of crude oil, asphalt, refined petroleum products and water. The G&P segment provides
gathering, processing and transportation of natural gas; and the gathering, transportation, fractionation, storage and marketing of NGLs.
SIGNIFICANT FINANCIAL AND OTHER HIGHLIGHTS
Significant financial highlights including revenues and other income, income from operations, net income, adjusted EBITDA attributable to MPLX and DCF attributable to GP and LP unitholders for the three months ended September 30, 2021 and September 30, 2020 are shown in the chart below. See the Non-GAAP Financial Information section below for the definitions of Adjusted EBITDA and DCF and the Results of Operations section for further details regarding changes in these metrics.
Other Highlights
•Announced a third quarter 2021 distribution of $1.28 per common unit, which consists of a base distribution amount of $0.705 per common unit and a special distribution amount of $0.575 per common unit.
•During the third quarter of 2021, we returned $155 million of cash to unitholders through the repurchase of over 5 million common units under our unit repurchase program.
•Generated net cash provided by operating activities of $1,182 million in the third quarter of 2021, which resulted in excess cash flow after distributions to common and preferred unitholders of $310 million.
CURRENT ECONOMIC ENVIRONMENT
During the nine months of 2021, we continued to see improvements in the environment in which our business operates as COVID-19 impacts are beginning to subside. The increased availability of vaccinations and easing of COVID-19 restrictions has been followed by an increase in economic activity despite the recent resurgence in COVID-19. We are unable to predict the long-term impacts COVID-19 may have on our financial position and results.
In the first quarter of 2020, the outbreak of COVID-19 and its development into a pandemic resulted in significant economic disruption globally. Actions taken by various governmental authorities, individuals and companies around the world to prevent the spread of COVID-19 through social distancing restricted travel, many business operations, public gatherings and the overall level of individual movement and in-person interaction across the globe. This significantly reduced global economic activity and resulted in a decline in the demand for products for which we provide midstream services. Macroeconomic conditions and global geopolitical events have also resulted in significant price volatility related to those aforementioned products.
Many uncertainties remain with respect to COVID-19 and we are unable to predict the ultimate economic impacts from COVID-19 and how quickly economies can fully recover to pre-pandemic levels. We believe we have proactively addressed many of the known impacts of COVID-19 to the extent possible and will strive to continue to do so, but there can be no guarantee the measures will be fully effective. MPLX remains focused on executing its strategic priorities of strict capital discipline, lowering the cost structure, and portfolio optimization.
Our management uses a variety of financial and operating metrics to analyze our performance. These metrics are significant factors in assessing our operating results and profitability and include the non-GAAP financial measures of Adjusted EBITDA, DCF, free cash flow (“FCF”) and excess/deficit cash flow. The amount of Adjusted EBITDA and DCF generated is considered by the board of directors of our general partner in approving MPLX’s cash distributions. Management also utilizes Segment Adjusted EBITDA in evaluating the financial performance of our segments. The use of this measure allows investors to understand how management evaluates financial performance to make operating decisions and allocate resources.
We define Adjusted EBITDA as net income adjusted for: (i) depreciation and amortization; (ii) provision/(benefit) for income taxes; (iii) amortization of deferred financing costs; (iv) (gain)/loss on extinguishment of debt; (v) non-cash equity-based compensation; (vi) impairment expense; (vii) net interest and other financial costs; (viii) income/(loss) from equity method investments; (ix) distributions and adjustments related to equity method investments; (x) unrealized derivative gains/(losses); (xi) acquisition costs; (xii) noncontrolling interest; and (xiii) other adjustments as deemed necessary. We also use DCF, which we define as Adjusted EBITDA adjusted for: (i) deferred revenue impacts; (ii) sales-type lease payments, net of income; (iii) net interest and other financial costs; (iv) net maintenance capital expenditures; (v) equity method investment capital expenditures paid out; and (vi) other adjustments as deemed necessary. Segment Adjusted EBITDA represents Adjusted EBITDA attributable to the reportable segments.
We make a distinction between realized and unrealized gains and losses on derivatives. During the period when a derivative contract is outstanding, changes in the fair value of the derivative are recorded as an unrealized gain or loss. When a derivative contract matures or is settled, the previously recorded unrealized gain or loss is reversed and the realized gain or loss of the contract is recorded.
We define FCF as net cash provided by operating activities adjusted for (i) net cash used in investing activities; (ii) cash contributions from MPC; (iii) cash contributions from noncontrolling interests and (iv) cash distributions to noncontrolling interests. We define excess/deficit cash flow as FCF adjusted for distributions to common and preferred unitholders.
We believe that the presentation of Adjusted EBITDA, DCF, FCF and excess/deficit cash flow provides useful information to investors in assessing our financial condition and results of operations. The GAAP measures most directly comparable to Adjusted EBITDA and DCF are net income and net cash provided by operating activities while the GAAP measure most directly comparable to FCF and excess/deficit cash flow is net cash provided by operating activities. These non-GAAP financial measures should not be considered alternatives to GAAP net income or net cash provided by operating activities as they have important limitations as analytical tools because they exclude some but not all items that affect net income and net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. These non-GAAP financial measures should not be considered in isolation or as substitutes for analysis of our results as reported under GAAP. Additionally, because non-GAAP financial measures may be defined differently by other companies in our industry, our definitions may not be comparable to similarly titled measures of other companies, thereby diminishing their utility. For a reconciliation of Adjusted EBITDA and DCF to their most directly comparable measures calculated and presented in accordance with GAAP, see the Results of Operations section. For a reconciliation of FCF and excess/deficit cash flow to their most directly comparable measure calculated and presented in accordance with GAAP, see the Liquidity and Capital resources section.
COMPARABILITY OF OUR FINANCIAL RESULTS
Our acquisitions and dispositions have impacted comparability of our financial results (see Note 3 of the Notes to Consolidated Financial Statements).
RESULTS OF OPERATIONS
The following tables and discussion are a summary of our results of operations for the three and nine months ended September 30, 2021 and 2020, including a reconciliation of Adjusted EBITDA and DCF from “Net income/(loss)” and “Net cash provided by operating activities,” to the most directly comparable GAAP financial measures.
Less: Net income attributable to noncontrolling interests
9
9
—
27
24
3
Net income/(loss) attributable to MPLX LP
802
665
137
2,247
(1,411)
3,658
Adjusted EBITDA attributable to MPLX LP(2)
1,389
1,335
54
4,115
3,856
259
DCF attributable to GP and LP unitholders(2)
$
1,143
$
1,032
$
111
$
3,468
$
3,075
$
393
(1) The nine months ended September 30, 2021 and September 30, 2020 include $6 million and $1,264 million of impairment expense related to equity method investments, respectively.
(2) Non-GAAP measure. See reconciliation below to the most directly comparable GAAP measures.
Reconciliation of Adjusted EBITDA attributable to MPLX LP and DCF attributable to GP and LP unitholders from Net income:
Net income/(loss)
$
811
$
674
$
137
$
2,274
$
(1,387)
$
3,661
Provision for income taxes
—
1
(1)
1
1
—
Amortization of deferred financing costs
18
15
3
53
44
9
Loss/(Gain) on extinguishment of debt
2
(14)
16
(10)
(14)
4
Net interest and other financial costs
200
223
(23)
618
647
(29)
Income/(loss) from operations
1,031
899
132
2,936
(709)
3,645
Depreciation and amortization
324
346
(22)
971
992
(21)
Non-cash equity-based compensation
1
4
(3)
6
12
(6)
Impairment expense
—
—
—
42
2,165
(2,123)
(Income)/loss from equity method investments
(92)
(83)
(9)
(228)
1,012
(1,240)
Distributions/adjustments related to equity method investments
129
130
(1)
371
369
2
Unrealized derivative losses(1)
2
10
(8)
41
1
40
Restructuring expenses
—
36
(36)
—
36
(36)
Other
3
3
—
5
5
—
Adjusted EBITDA
1,398
1,345
53
4,144
3,883
261
Adjusted EBITDA attributable to noncontrolling interests
(9)
(10)
1
(29)
(27)
(2)
Adjusted EBITDA attributable to MPLX LP
1,389
1,335
54
4,115
3,856
259
Deferred revenue impacts
14
29
(15)
76
92
(16)
Sales-type lease payments, net of income (2)
14
—
14
68
—
68
Net interest and other financial costs
(200)
(223)
23
(618)
(647)
29
Maintenance capital expenditures
(35)
(41)
6
(81)
(108)
27
Maintenance capital expenditures reimbursements
14
11
3
31
31
—
Equity method investment capital expenditures paid out
(1)
(5)
4
(4)
(16)
12
Restructuring expenses
—
(36)
36
—
(36)
36
Other
(4)
(3)
(1)
(9)
—
(9)
DCF
1,191
1,067
124
3,578
3,172
406
Preferred unit distributions
(48)
(35)
(13)
(110)
(97)
(13)
DCF attributable to GP and LP unitholders
$
1,143
$
1,032
$
111
$
3,468
$
3,075
$
393
(1) MPLX makes a distinction between realized and unrealized gains and losses on derivatives. During the period when a derivative contract is outstanding, changes in the fair value of the derivative are recorded as an unrealized gain or loss. When a derivative contract matures or is settled, the previously recorded unrealized gain or loss is reversed and the realized gain or loss of the contract is recorded.
(2) The nine months ended September 30, 2021 includes one time impact from Refining Logistics harmonization project of $54 million.
Reconciliation of Adjusted EBITDA attributable to MPLX LP and DCF attributable to GP and LP unitholders from Net cash provided by operating activities:
Net cash provided by operating activities
$
3,671
$
3,336
$
335
Changes in working capital items
(184)
(154)
(30)
All other, net
(11)
(6)
(5)
Non-cash equity-based compensation
6
12
(6)
Net loss on disposal of assets
(4)
(1)
(3)
Gain on extinguishment of debt
(10)
(14)
4
Net interest and other financial costs
618
647
(29)
Current income taxes
2
2
—
Unrealized derivative losses(1)
41
1
40
Restructuring expenses
—
36
(36)
Other adjustments to equity method investment distributions
10
19
(9)
Other
5
5
—
Adjusted EBITDA
4,144
3,883
261
Adjusted EBITDA attributable to noncontrolling interests
(29)
(27)
(2)
Adjusted EBITDA attributable to MPLX LP
4,115
3,856
259
Deferred revenue impacts
76
92
(16)
Sales-type lease payments, net of income (2)
68
—
68
Net interest and other financial costs
(618)
(647)
29
Maintenance capital expenditures
(81)
(108)
27
Maintenance capital expenditures reimbursements
31
31
—
Equity method investment capital expenditures paid out
(4)
(16)
12
Restructuring expenses
—
(36)
36
Other
(9)
—
(9)
DCF
3,578
3,172
406
Preferred unit distributions
(110)
(97)
(13)
DCF attributable to GP and LP unitholders
$
3,468
$
3,075
$
393
(1) MPLX makes a distinction between realized and unrealized gains and losses on derivatives. During the period when a derivative contract is outstanding, changes in the fair value of the derivative are recorded as an unrealized gain or loss. When a derivative contract matures or is settled, the previously recorded unrealized gain or loss is reversed and the realized gain or loss of the contract is recorded.
(2) The nine months ended September 30, 2021 includes one time impact from Refining Logistics harmonization project of $54 million.
Three months ended September 30, 2021 compared to three months ended September 30, 2020
Total revenues and other income increased $312 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to higher prices in the G&P segment of approximately $300 million. There were also increased pipeline volumes of $57 million, increased equity method income due to volume increases, and increased revenue from our terminal, storage and refining logistics operations due to increased throughput, storage capacity and annual rate escalations. These increases were partially offset by decreases in marine transportation fees of $27 million, $15 million from the Wholesale Exchange, and decreased pipeline tariff rates and fees of $12 million.
Cost of revenues decreased $25 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the Wholesale Exchange, as well as to lower repairs, maintenance, operating costs and project-related spend as a result of cost reduction initiatives.
Purchased product costs increased $269 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to higher prices of $241 million in the Southwest and Southern Appalachia and other product increases, partially offset by a decrease of $8 million related to unrealized derivative losses in the current year.
Rental cost of sales and rental cost of sales - related parties decreased $8 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to modifications to lease contracts which resulted in costs now being recorded to purchases - related parties, as noted below, as opposed to rental cost of sales - related parties.
Purchases - related parties increased $10 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to modifications to lease contracts which resulted in costs now being recorded to purchases - related parties as opposed to rental cost of sales - related parties, as noted above.
Depreciation and amortization decreased $22 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the write-off of assets under construction related to idled MPC refineries during the third quarter of 2020 and the derecognition of assets reclassified as sales-type leases due to contract modifications. These decreases resulting from the prior year charges were partially offset by accelerated depreciation on assets permanently idled in 2021, as well as by property plant and equipment placed in service after the third quarter of 2020.
Restructuring expenses decreased $36 million in the third quarter of 2021 compared to the same period of 2020. This was due to cost cutting measures taken during 2020 that resulted in restructuring charges.
Nine months ended September 30, 2021 compared to nine months ended September 30, 2020
Total revenues and other income increased $1,973 million in the first nine months of 2021 compared to the same period of 2020. This increase was primarily due to $1,264 million of impairments recorded for three joint ventures in which we have an interest. The impairments were recorded through “Income from equity method investments.” The remaining $709 million increase is primarily due to higher prices in the G&P segment of approximately $717 million and increased pipeline and terminal volumes of $198 million. There were also increases related to higher terminal storage fees, refining logistics fee escalations and higher fees from contracts in the Marcellus and Southern Appalachia regions. These increases were partially offset by decreases of $99 million related to the Wholesale Exchange, $80 million related to marine transportation fees, and $33 million related to lower pipeline tariffs and fees.
Cost of revenues decreased $142 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the Wholesale Exchange as well as lower repairs, maintenance, operating costs and project-related spend as a result of cost reduction initiatives. These decreases were partially offset by higher prices in the Rockies.
Purchased product costs increased $661 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to higher prices of $544 million in the Southwest and Southern Appalachia, an increase of $40 million related to unrealized derivative losses in the current year compared to the prior year, and other product cost increases.
Rental cost of sales and rental cost of sales - related parties decreased $37 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to modifications to lease contracts which resulted in costs now being recorded to purchases - related parties, as noted below, as opposed to rental cost of sales - related parties.
Purchases - related parties increased $49 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to modifications to lease contracts which resulted in costs now being recorded to purchases - related parties as opposed to rental cost of sales - related parties, as noted above. In addition, higher employee related costs also contributed to the increase.
Depreciation and amortization decreased $21 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the write-off of assets under construction related to idled MPC refineries during 2020 and the derecognition of assets reclassified as sales-type leases due to contract modifications. These decreases were partially offset by accelerated depreciation in the current year related to assets permanently idled in 2021, as well as property, plant and equipment placed in service after the third quarter of 2020.
Impairment expense decreased $2,123 million in the first nine months of 2021 compared to the same period of 2020. During the first quarter of 2020 we recorded impairment expense for goodwill, intangible assets and property, plant and equipment of $1,814 million, $177 million and $174 million, respectively. The impairment of goodwill related to our Eastern G&P reporting unit while the intangible asset and property, plant and equipment impairments related to certain assets in our Southwest region. The impairments were primarily driven by the slowing of drilling activity, which reduced production growth forecasts from our producer customers. This decrease was partially offset by an impairment recorded during the second quarter of 2021 related to our continued emphasis on portfolio optimization with the anticipated divestiture of several non-core assets and the closure of other non-core assets.
General and administrative expenses decreased $22 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to decreased employee costs from MPC as a result of cost reduction initiatives.
Restructuring expenses decreased $36 million in the first nine months of 2021 compared to the same period of 2020. This was due to cost cutting measures taken during 2020 that resulted in restructuring charges.
The tables below present information about Segment Adjusted EBITDA for the reported segments for the three and nine months ended September 30, 2021 and 2020.
L&S Segment
Third Quarter L&S Segment Financial Highlights (in millions)
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
Variance
2021
2020
Variance
Service revenue
$
983
$
989
$
(6)
$
2,928
$
2,924
$
4
Rental income
172
249
(77)
597
737
(140)
Product related revenue
3
9
(6)
11
49
(38)
Sales-type lease revenue
132
38
94
305
114
191
Income from equity method investments
41
36
5
112
126
(14)
Other income
15
13
2
46
40
6
Total segment revenues and other income
1,346
1,334
12
3,999
3,990
9
Cost of revenues
164
173
(9)
451
601
(150)
Purchases - related parties
232
219
13
675
629
46
Depreciation and amortization
131
164
(33)
414
440
(26)
General and administrative expenses
48
55
(7)
140
159
(19)
Restructuring expenses
—
27
(27)
—
27
(27)
Other taxes
19
19
—
57
53
4
Segment income from operations
752
677
75
2,262
2,081
181
Depreciation and amortization
131
164
(33)
414
440
(26)
Income from equity method investments
(41)
(36)
(5)
(112)
(126)
14
Distributions/adjustments related to equity method investments
58
55
3
174
169
5
Restructuring expenses
—
27
(27)
—
27
(27)
Non-cash equity-based compensation
1
3
(2)
4
8
(4)
Other
3
3
—
5
5
—
Segment adjusted EBITDA(1)
904
893
11
2,747
2,604
143
Capital expenditures
85
118
(33)
220
410
(190)
Investments in unconsolidated affiliates
$
9
$
4
$
5
$
31
$
132
$
(101)
(1) See the Reconciliation of Adjusted EBITDA attributable to MPLX LP and DCF attributable to GP and LP unitholders from Net income table for the reconciliation to the most directly comparable GAAP measure.
Three months ended September 30, 2021 compared to three months ended September 30, 2020
Service revenue decreased $6 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to a $27 million decrease in marine transportation fees, a decrease of $13 million from the reclassification of lease income between service revenue, rental income and sales-type lease revenue due to modifications to lease contracts, as well as decreases due the Wholesale Exchange, terminal throughputs and lower pipeline tariffs. The decreases were mostly offset by increased pipeline volumes of $57 million.
Rental income decreased $77 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the reclassification of lease income between service revenue, rental income and sales-type lease revenue due to modifications to lease contracts. The net decreases due to reclassifications were offset by increased terminal storage fees.
Product related revenue decreased $6 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the Wholesale Exchange.
Sales-type lease revenue - related parties increased $94 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the reclassification of lease income between service revenue, rental income and sales-type lease revenue due to modifications to lease contracts.
Cost of revenues decreased $9 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the Wholesale Exchange and lower project-related spend as a result of cost reduction initiatives. In addition, modifications to lease contracts resulted in costs now being recorded to purchases - related parties, as noted below, as opposed to rental cost of sales - related parties, which is included in the decrease being explained here.
Purchases - related parties increased $13 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to modifications to lease contracts which resulted in costs now being recorded to purchases - related parties as opposed to rental cost of sales - related parties, which is included in cost of revenues as noted above.
Depreciation and amortization decreased $33 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to the write-off of assets under construction in the third quarter of 2020 related to idled MPC refineries. The decrease in the current quarter also reflects the derecognition of fixed assets due to the modification of certain lease contracts in 2021.
General and administrative expenses decreased $7 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to decreased employee costs from MPC as a result of cost reduction initiatives.
Restructuring expenses decreased $27 million in the third quarter of 2021 compared to the same period of 2020. This was due to cost cutting measures during 2020 that resulted in restructuring charges.
Nine months ended September 30, 2021 compared to nine months ended September 30, 2020
Service revenue increased $4 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to increased revenue from pipeline and terminal throughput of $198 million, partially offset by an $80 million decrease in marine transportation fees, a $56 million decrease due to the Wholesale Exchange, a $33 million decrease from lower pipeline tariffs and other fees, and a decrease of $25 million due to the reclassification of lease income between service revenue, rental income and sales-type lease revenue due to modifications to lease contracts.
Rental income decreased $140 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the reclassification of lease income between service revenue, rental income and sales-type lease revenue due to modifications to lease contracts. The net decreases due to reclassifications were offset by increased terminal storage fees as well as additional refining logistics fees associated with annual fee escalations.
Product related revenue decreased $38 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the Wholesale Exchange.
Sales-type lease revenue - related parties increased $191 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the reclassification of lease income between service revenue, rental income and sales-type lease revenue due to modifications to lease contracts.
Income from equity method investments decreased $14 million in the first nine months of 2021 compared to the same period of 2020 primarily due to lower overall throughput volumes on our equity method investments.
Cost of revenues decreased $150 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the Wholesale Exchange, lower project-related spend and other operating expenses as a result of cost reduction initiatives. In addition, modifications to lease contracts resulted in costs now being recorded to purchases - related parties, as noted below, as opposed to rental cost of sales - related parties, which is included in the decrease being explained here.
Purchases - related parties increased $46 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to modifications to lease contracts which resulted in costs now being recorded to purchases - related parties as opposed to rental cost of sales - related parties, which is included in cost of revenues as noted above. In addition, higher employee related costs also contributed to the increase.
Depreciation and amortization decreased $26 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to the write-off of assets under construction in 2020 related to idled MPC refineries, offset by accelerated depreciation in the current year related to assets at an indefinitely idled MPC refinery, as well as property, plant and equipment placed in service since the third quarter of 2020. The decrease in the 2021 period also reflects the derecognition of fixed assets due to the modification of certain lease contracts in the current year.
General and administrative expenses decreased $19 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to decreased employee costs from MPC as a result of cost reduction initiatives.
Restructuring expenses decreased $27 million in the first nine months of 2021 compared to the same period of 2020. This was due to cost cutting measures during 2020 that resulted in restructuring charges.
Third Quarter G&P Segment Financial Highlights (in millions)
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
Variance
2021
2020
Variance
Service revenue
$
519
$
524
$
(5)
$
1,520
$
1,549
$
(29)
Rental income
80
94
(14)
263
271
(8)
Product related revenue
553
234
319
1,357
607
750
Income/(loss) from equity method investments(1)
51
47
4
116
(1,138)
1,254
Other income
10
14
(4)
38
41
(3)
Total segment revenues and other income
1,213
913
300
3,294
1,330
1,964
Cost of revenues
191
215
(24)
596
625
(29)
Purchased product costs
421
152
269
1,035
374
661
Purchases - related parties
75
78
(3)
227
224
3
Depreciation and amortization
193
182
11
557
552
5
Impairment expense
—
—
—
42
2,165
(2,123)
General and administrative expenses
46
41
5
127
130
(3)
Restructuring expenses
—
9
(9)
—
9
(9)
Other taxes
8
14
(6)
36
41
(5)
Segment income/(loss) from operations
279
222
57
674
(2,790)
3,464
Depreciation and amortization
193
182
11
557
552
5
Impairment expense
—
—
—
42
2,165
(2,123)
(Income)/loss from equity method investments
(51)
(47)
(4)
(116)
1,138
(1,254)
Distributions/adjustments related to equity method investments
71
75
(4)
197
200
(3)
Restructuring expenses
—
9
(9)
—
9
(9)
Unrealized derivative losses(2)
2
10
(8)
41
1
40
Non-cash equity-based compensation
—
1
(1)
2
4
(2)
Adjusted EBITDA attributable to noncontrolling interests
(9)
(10)
1
(29)
(27)
(2)
Segment Adjusted EBITDA(3)
485
442
43
1,368
1,252
116
Capital expenditures
69
131
(62)
135
375
(240)
Investments in unconsolidated affiliates
$
23
$
18
$
5
$
85
$
112
$
(27)
(1) The nine months ended September 30, 2021 and September 30, 2020 include $6 million and $1,264 million of impairment expense, respectively.
(2) MPLX makes a distinction between realized and unrealized gains and losses on derivatives. During the period when a derivative contract is outstanding, changes in the fair value of the derivative are recorded as an unrealized gain or loss. When a derivative contract matures or is settled, the previously recorded unrealized gain or loss is reversed and the realized gain or loss of the contract is recorded.
(3) See the Reconciliation of Adjusted EBITDA attributable to MPLX LP and DCF attributable to GP and LP unitholders from Net income table for the reconciliation to the most directly comparable GAAP measure.
Three months ended September 30, 2021 compared to three months ended September 30, 2020
Service revenue decreased $5 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to lower fees from lower volumes in the Rockies, Marcellus and Southwest of $19 million, which includes the impact related to the Javelina divestiture, partially offset by an increase in fees due to a contract modification in the Marcellus.
Rental income decreased $14 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to a contract modification in the Marcellus resulting in the reclassification of the related income from rental income to service revenue.
Product related revenue increased $319 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to higher prices in all of the regions of approximately $300 million and other product related sales increases. This was partially offset by a decrease in volumes of $21 million, primarily due to the Javelina divestiture in the Southwest.
Cost of revenues decreased $24 million in the third quarter of 2021 compared to the same period of 2020. This decrease is attributable to lower repairs, maintenance and operating costs in the Marcellus, Southwest and Rockies as a result of the Javelina divestiture and cost reduction initiatives.
Purchased product costs increased $269 million in the third quarter of 2021 compared to the same period of 2020. This was primarily due to higher prices of $241 million in the Southwest and Southern Appalachia and other product increases, partially offset by a decrease of $8 million related to unrealized derivative losses in the current year.
Depreciation and amortization increased $11 million in the third quarter of 2021 compared to the same period of 2020. The increase was primarily due to property, plant and equipment placed in service after the third quarter of 2020 and accelerated depreciation on idled assets, partially offset by lower depreciation as a result of divestitures.
Restructuring expenses decreased $9 million in the third quarter of 2021 compared to the same period of 2020. This was due to cost cutting measures during 2020 that resulted in restructuring charges.
Nine months ended September 30, 2021 compared to nine months ended September 30, 2020
Service revenue decreased $29 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to lower fees from lower volumes in the Southwest and Rockies of $43 million, which includes impacts related to severe weather and Javelina divestiture in the Southwest, partially offset by an increase in fees due to a contract modification in the Marcellus.
Rental income decreased $8 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to a contract modification in the Marcellus resulting in the reclassification of lease income between rental income to service revenue, partially offset by higher fees related to contracts in the Marcellus and Southern Appalachia.
Product related revenue increased $750 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to higher prices in all of the regions of approximately $717 million and other product related sales increases, partially offset by the impact related to the Javelina divestiture, impacts related to severe weather in the Southwest and a decrease in volumes in the Rockies.
Income from equity method investments increased $1,254 million in the first nine months of 2021 compared to the same period of 2020. This increase was driven by impairments recorded in the first quarter of 2020 of $1,264 million. Impairments were recognized related to our ownership in MarkWest Utica EMG, our indirect ownership in Ohio Gathering Company, L.L.C. through our investment in MarkWest Utica EMG and our ownership in Uintah Basin Field Services, L.L.C. Also contributing to the increase was higher volumes associated with our Sherwood Midstream LLC and Ohio Condensate Company joint ventures. These increases were partially offset by lower volumes at our joint ventures in the Utica and Southwest regions along with an asset impairment recognized within our Three Rivers Gathering LLC joint venture in the current period.
Cost of revenues decreased $29 million in the first nine months of 2021 compared to the same period of 2020.This decrease is attributable to lower repairs, maintenance and operating costs in the Marcellus and Southwest as a result of the Javelina divestiture and cost reduction initiatives, partially offset by higher prices in the Rockies.
Purchased product costs increased $661 million in the first nine months of 2021 compared to the same period of 2020. This was primarily due to higher prices of $544 million in the Southwest and Southern Appalachia, an increase of $40 million related to unrealized derivative losses and other product cost increases.
Depreciation and amortization increased $5 million in the first nine months of 2021 compared to the same period of 2020 primarily due to property, plant and equipment placed in service after the third quarter of 2020 and accelerated depreciation on idled assets, partially offset by the impairment of intangible assets, property, plant and equipment during the first quarter of 2020 and lower depreciation as a result of divestitures.
Impairment expense decreased $2,123 million in the first nine months of 2021 compared to the same period of 2020. During the first quarter of 2020 we recorded impairment expense for goodwill, intangible assets and property, plant and equipment of $1,814 million, $177 million and $174 million, respectively. The impairment of goodwill related to our Eastern G&P reporting unit while the intangible asset and property, plant and equipment impairments relate to certain assets in our Southwest region. The impairments were primarily driven by the slowing of drilling activity, which reduced production growth forecasts from our producer customers. This decrease was partially offset by an impairment recorded during the second quarter of 2021 related to our continued emphasis on portfolio optimization with the anticipated divestiture of several non-core assets and the closure of other non-core assets.
Restructuring expenses decreased $9 million in the first nine months of 2021 compared to the same period of 2020. This was due to cost cutting measures during 2020 that resulted in restructuring charges.
SEASONALITY
The volume of crude oil and refined products transported and stored utilizing our assets is directly affected by the level of supply and demand for crude oil and refined products in the markets served directly or indirectly by our assets. Any effects of seasonality on the L&S segment’s revenues will be mitigated through the use of our fee-based transportation and storage services agreements with MPC that include minimum volume commitments.
In our G&P segment, we experience minimal impacts from seasonal fluctuations which impact the demand for natural gas and NGLs and the related commodity prices caused by various factors including variations in weather patterns from year to year. We are able to manage the seasonality impacts through the execution of our marketing strategy and via our storage capabilities. Overall, our exposure to seasonality fluctuations is declining due to growth in our fee-based business.
(1) Average tariff rates calculated using pipeline transportation revenues divided by pipeline throughput barrels.
(2) Represents total at end of period.
(3) This column represents operating data for entities that have been consolidated into the MPLX financial statements.
(4) This column represents operating data for entities that have been consolidated into the MPLX financial statements as well as operating data for MPLX-operated equity method investments.
(5) Entities within the Marcellus and Utica Operations jointly own the Hopedale fractionation complex. Hopedale throughput is included in the Marcellus and Utica Operations and represent each region’s utilization of the complex.
(6) The Southwest Operations for the nine months ended September 30, 2021 include the Javelina complex, which was sold on February 12, 2021. The processing and fractionated volumes calculated for the number of days MPLX owned these assets during 2021 were 96 MMcf/d and 17 mbpd, respectively.
(7) Includes NGLs fractionated for the Marcellus Operations and Utica Operations.
(8) Purity ethane makes up approximately 199 mbpd and 193 mbpd of total MPLX Operated, fractionated products for the three months ended September 30, 2021 and 2020, respectively, and approximately 196 mbpd and 192 mbpd of total fractionated products for the nine months ended September 30, 2021 and 2020, respectively. Purity ethane makes up approximately 194 mbpd and 188 mbpd of total MPLX LP consolidated, fractionated products for the three months ended September 30, 2021 and 2020, respectively, and approximately 191 mbpd and 186 mbpd of total fractionated products for the nine months ended September 30, 2021 and 2020, respectively.
(9) C2 + NGL pricing based on Mont Belvieu prices assuming an NGL barrel of approximately 35 percent ethane, 35 percent propane, six percent Iso-Butane, 12 percent normal butane and 12 percent natural gasoline.
Our cash and cash equivalents were $39 million at September 30, 2021 and $15 million at December 31, 2020. The change in cash, cash equivalents and restricted cash was due to the factors discussed below. Net cash provided by (used in) operating activities, investing activities and financing activities were as follows:
Nine Months Ended September 30,
(In millions)
2021
2020
Net cash provided by (used in):
Operating activities
$
3,671
$
3,336
Investing activities
(377)
(1,060)
Financing activities
(3,270)
(2,263)
Total
$
24
$
13
Net cash provided by operating activities increased $335 million in the first nine months of 2021 compared to the first nine months of 2020, primarily due to an increase in net income adjusted for non-cash items.
Net cash used in investing activities decreased $683 million in the first nine months of 2021 compared to the first nine months of 2020, primarily due to lower capital spending, which reflects our continued focus on capital discipline, and decreased contributions to equity method investments.
Financing activities were a $3,270 million use of cash in the first nine months of 2021 compared to a $2,263 million use of cash in the first nine months of 2020. The primary reason for the increase in the use of cash was due to the return of capital to unitholders through the unit repurchase program as well as net repayments on long-term debt in the current year compared to net borrowings on long-term debt in the prior year.
Free Cash Flow
The following table provides a reconciliation of FCF and excess/deficit cash flow from net cash provided by operating activities for the three and nine months ended September 30, 2021 and September 30, 2020.
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions)
2021
2020
2021
2020
Net cash provided by operating activities
$
1,182
$
1,222
$
3,671
$
3,336
Adjustments to reconcile net cash provided by operating activities to free cash flow
On September 3, 2021 MPLX redeemed all of the $1.0 billion aggregate principal amount of floating rate senior notes due September 2022 at 100 percent of the principal amount.
On January 15, 2021, MPLX redeemed $750 million outstanding aggregate principal amount of 5.250 percent senior notes due January 2025, at 102.625 percent of the principal amount.
Our outstanding borrowings at September 30, 2021 and December 31, 2020 consist of the following:
(In millions)
September 30, 2021
December 31, 2020
MPLX LP:
Bank revolving credit facility
$
—
$
175
Floating rate senior notes
—
1,000
Fixed rate senior notes
18,532
19,240
Consolidated subsidiaries:
MarkWest
23
23
Andeavor Logistics LP
45
87
Financing lease obligations
9
11
Total
18,609
20,536
Unamortized debt issuance costs
(105)
(116)
Unamortized discount/premium
(250)
(281)
Amounts due within one year
(1)
(764)
Total long-term debt due after one year
$
18,253
$
19,375
Our intention is to maintain an investment-grade credit profile. As of September 30, 2021, the credit ratings on our senior unsecured debt were at or above investment grade level as follows:
Rating Agency
Rating
Moody’s
Baa2 (stable outlook)
Standard & Poor’s
BBB (negative outlook)
Fitch
BBB (stable outlook)
The ratings reflect the respective views of the rating agencies. Although it is our intention to maintain a credit profile that supports an investment grade rating, there is no assurance that these ratings will continue for any given period of time. The ratings may be revised or withdrawn entirely by the rating agencies if, in their respective judgments, circumstances so warrant.
The MPLX Credit Agreement contains certain representations and warranties, affirmative and restrictive covenants and events of default that we consider to be usual and customary for an agreement of this type. The financial covenant requires MPLX to maintain a ratio of Consolidated Total Debt as of the end of each fiscal quarter to Consolidated EBITDA (both as defined in the MPLX Credit Agreement) for the prior four fiscal quarters of no greater than 5.0 to 1.0 (or 5.5 to 1.0 during the six-month period following certain acquisitions). Consolidated EBITDA is subject to adjustments for certain acquisitions completed and capital projects undertaken during the relevant period. Other covenants restrict us and/or certain of our subsidiaries from incurring debt, creating liens on assets and entering into transactions with affiliates. As of September 30, 2021, we were in compliance with the covenants, including the financial covenant with a ratio of Consolidated Total Debt to Consolidated EBITDA of 3.64 to 1.0.
The agreements governing our debt obligations do not contain credit rating triggers that would result in the acceleration of interest, principal or other payments solely in the event that our credit ratings are downgraded. However, any downgrades in the credit ratings of our senior unsecured debt ratings to below investment grade ratings could, among other things, increase the applicable interest rates and other fees payable under the MPLX Credit Agreement and may limit our ability to obtain future financing, including refinancing existing indebtedness.
Our liquidity totaled $3.7 billion at September 30, 2021 consisting of:
September 30, 2021
(In millions)
Total Capacity
Outstanding Borrowings
Available Capacity
Bank revolving credit facility due 2024(1)
$
3,500
$
—
$
3,500
MPC Loan Agreement
1,500
(1,370)
130
Total liquidity
$
5,000
$
(1,370)
3,630
Cash and cash equivalents
39
Total liquidity
$
3,669
(1) Outstanding borrowings include less than $1 million in letters of credit outstanding under this facility.
We expect our ongoing sources of liquidity to include cash generated from operations and borrowings under the MPC Loan Agreement, the MPLX Credit Agreement and access to capital markets. We believe that cash generated from these sources will be sufficient to meet our short-term and long-term funding requirements, including working capital requirements, capital expenditure requirements, contractual obligations, and quarterly cash distributions. We may also, from time to time, repurchase notes or preferred shares in the open market, in privately negotiated transactions or otherwise in such volumes, at market prices and upon such other terms as we deem appropriate. MPC manages our cash and cash equivalents on our behalf directly with third-party institutions as part of the treasury services that it provides to us under our omnibus agreement. From time to time, we may also consider utilizing other sources of liquidity, including the formation of joint ventures or sales of non-strategic assets.
Equity and Preferred Units Overview
Common units
The table below summarizes the changes in the number of units outstanding through September 30, 2021:
(In units)
Balance at December 31, 2020
1,038,777,978
Unit-based compensation awards
213,727
Units redeemed in Unit Repurchase Program
(17,563,855)
Balance at September 30, 2021
1,021,427,850
Distributions
We intend to pay a minimum quarterly distribution to the holders of our common units of $0.2625 per unit, or $1.05 per unit on an annualized basis, to the extent we have sufficient cash from our operations after the establishment of cash reserves and the payment of costs and expenses, including reimbursements of expenses to our general partner. The amount of distributions paid under our policy and the decision to make any distributions is determined by our general partner, taking into consideration the terms of our partnership agreement. Such minimum distribution would equate to $268 million per quarter, or $1,072 million per year, based on the number of common units outstanding at September 30, 2021.
On November 2, 2021, MPLX declared a cash distribution for the third quarter of 2021, totaling $1,305 million, or $1.28 per common unit, consisting of a base distribution amount of $0.705 per common unit and a special distribution amount of $0.575 per common unit (the “Special Distribution Amount”) as supported by our year-to-date cash flow. This distribution will be paid on November 19, 2021 to common unitholders of record on November 12, 2021. Although our partnership agreement requires that we distribute all of our available cash each quarter, we do not otherwise have a legal obligation to distribute any particular amount per common unit. This rate will also be received by Series A preferred unitholders.
Series B preferred unitholders are entitled to receive a fixed distribution of $68.75 per unit, per annum, payable semi-annually in arrears on February 15 and August 15, or the first business day thereafter, up to and including February 15, 2023. After February 15, 2023, the holders of Series B preferred units are entitled to receive cumulative, quarterly distributions payable in arrears on the 15th day of February, May, August and November of each year, or the first business day thereafter, based on a floating annual rate equal to the three-month LIBOR plus 4.652 percent, in each case assuming a distribution is declared by the board of directors. Accordingly, a cash distribution payment totaling $21 million was paid to Series B unitholders on August 16, 2021.
The allocation of total cash distributions is as follows for the three and nine months ended September 30, 2021 and 2020. MPLX’s distributions are declared subsequent to quarter end; therefore, the following table represents total cash distributions applicable to the period in which the distributions were earned.
Three Months Ended September 30,
Nine Months Ended September 30,
(In millions, except per unit data)
2021
2020
2021
2020
Distribution declared:
Limited partner units - public (1)
$
476
$
270
$
998
$
810
Limited partner units - MPC (1)
829
445
1,719
1,348
Total LP distribution declared
1,305
715
2,717
2,158
Series A preferred units (1)
38
20
79
61
Series B preferred units
10
10
31
31
Total distribution declared
1,353
745
2,827
2,250
Quarterly cash distributions declared per limited partner common unit
$
1.2800
$
0.6875
$
2.6550
$
2.0625
(1) Includes the Special Distribution Amount.
Capital Expenditures
Our operations are capital intensive, requiring investments to expand, upgrade, enhance or maintain existing operations and to meet environmental and operational regulations. Our capital requirements consist of maintenance capital expenditures and growth capital expenditures. Examples of maintenance capital expenditures are those made to replace partially or fully depreciated assets, to maintain the existing operating capacity of our assets and to extend their useful lives, or other capital expenditures that are incurred in maintaining existing system volumes and related cash flows. In contrast, growth capital expenditures are those incurred for capital improvements that we expect will increase our operating capacity to increase volumes gathered, processed, transported or fractionated, decrease operating expenses within our facilities or increase operating income over the long term. Examples of growth capital expenditures include the acquisition of equipment or the construction costs associated with new well connections, and the development of additional pipeline, processing or storage capacity. In general, growth capital includes costs that are expected to generate additional or new cash flow for MPLX.
MPLX’s initial capital investment plan for 2021 totaled approximately $1.0 billion for capital projects and investments, excluding capitalized interest, and is currently estimated to be approximately $650 million. We continuously evaluate our capital investment plan and make changes as conditions warrant. Growth capital expenditures and investments in affiliates during the nine months ended September 30, 2021 were primarily for gas gathering and processing projects in our Marcellus and Southwest regions and the expansion of our crude gathering systems.
Our capital expenditures are shown in the table below:
Nine Months Ended September 30,
(In millions)
2021
2020
Capital expenditures:
Growth capital expenditures
$
274
$
677
Growth capital reimbursements
—
(2)
Investments in unconsolidated affiliates
116
244
Return of capital
(36)
(112)
Capitalized interest
(11)
(31)
Total growth capital expenditures
343
776
Maintenance capital expenditures
81
108
Maintenance capital reimbursements
(31)
(31)
Capitalized interest
(1)
—
Total maintenance capital expenditures
49
77
Total growth and maintenance capital expenditures
392
853
Investments in unconsolidated affiliates(1)
(116)
(244)
Return of capital(1)
36
112
Growth and maintenance capital reimbursements(2)
31
33
Decrease in capital accruals
19
197
Capitalized interest
12
31
Additions to property, plant and equipment, net(1)
$
374
$
982
(1) Investments in unconsolidated affiliates, return of capital and additions to property, plant and equipment, net are shown as separate lines within investing activities in the Consolidated Statements of Cash Flows.
(2) Growth and maintenance capital reimbursements are included in the “Contributions from MPC” line within financing activities in the Consolidated Statements of Cash Flows.
Contractual Cash Obligations
As of September 30, 2021, our contractual cash obligations included third-party and related party debt, finance and operating lease obligations, purchase obligations for services and to acquire property, plant and equipment, and other liabilities. During the nine months ended September 30, 2021, our third-party long-term debt obligations decreased by $1,925 million, primarily due to the redemption of $750 million outstanding aggregate principal amount of 5.250 percent senior notes due January 2025 discussed above, the redemption of the floating rate senior notes due September 2022, as well as net repayments on the MPLX Credit Agreement.Additionally, borrowings on the MPC Loan Agreement increased to fund the floating rate senior notes redemption. There were no other material changes to our contractual obligations outside the ordinary course of business since December 31, 2020.
Off-Balance Sheet Arrangements
Off-balance sheet arrangements comprise those arrangements that may potentially impact our liquidity, capital resources and results of operations, even though such arrangements are not recorded as liabilities under U.S. GAAP. Our off-balance sheet arrangements are limited to indemnities and guarantees that are described in Note 19. Although these arrangements serve a variety of our business purposes, we are not dependent on them to maintain our liquidity and capital resources, and we are not aware of any circumstances that are reasonably likely to cause the off-balance sheet arrangements to have a material adverse effect on our liquidity and capital resources.
TRANSACTIONS WITH RELATED PARTIES
At September 30, 2021, MPC owned our non-economic general partnership interest and held approximately 63 percent of our outstanding common units.
We provide MPC with crude oil and product pipeline and trucking transportation services based on regulated tariff/contracted rates, as well as storage, terminal, fuels distribution, and inland marine transportation services based on contracted rates. We
also have agreements with MPC under which we receive fees for operating MPC’s retained pipeline assets, providing management services for the marine business, and operating certain of MPC’s equity method investments. MPC provides us with certain services related to information technology, engineering, legal, accounting, treasury, human resources and other administrative services under employee services and omnibus services agreements.
The below table shows the percentage of “Total revenues and other income” as well as “Total costs and expenses” with MPC:
Three Months Ended September 30,
2021
2020
Total revenues and other income (1)
48
%
55
%
Total costs and expenses
26
%
31
%
(1) Excludes revenues attributable to volumes shipped by MPC under joint tariffs with third parties that are treated as third party revenues for accounting purposes.
For further discussion of agreements and activity with MPC and related parties see Item 1. Business in our Annual Report on Form 10-K for the year ended December 31, 2020 and Note 5 of the Notes to Consolidated Financial Statements in this report.
ENVIRONMENTAL MATTERS AND COMPLIANCE COSTS
We have incurred and may continue to incur substantial capital, operating and maintenance, and remediation expenditures as a result of environmental laws and regulations. If these expenditures, as with all costs, are not ultimately reflected in the prices of our products and services, our operating results will be adversely affected. We believe that substantially all of our competitors must comply with similar environmental laws and regulations. However, the specific impact on each competitor may vary depending on a number of factors, including, but not limited to, the age and location of its operating facilities.
As of September 30, 2021, there have been no significant changes to our environmental matters and compliance costs since our Annual Report on Form 10-K for the year ended December 31, 2020.
CRITICAL ACCOUNTING ESTIMATES
As of September 30, 2021, there have been no significant changes to our critical accounting estimates since our Annual Report on Form 10-K for the year ended December 31, 2020.
ACCOUNTING STANDARDS NOT YET ADOPTED
While new financial accounting pronouncements will be effective for our financial statements in the future, there are no standards that have not yet been adopted that are expected to have a material impact on our financial statements. Accounting standards are discussed in Note 2 of the Notes to Consolidated Financial Statements.
Item 3. Quantitative and Qualitative Disclosures about Market Risk
We are exposed to market risks related to the volatility of commodity prices. We employ various strategies, including the potential use of commodity derivative instruments, to economically hedge the risks related to these price fluctuations. We are also exposed to market risks related to changes in interest rates. As of September 30, 2021, we did not have any open financial or commodity derivative instruments to hedge the economic risks related to interest rate fluctuations or the volatility of commodity prices, respectively; however, we continually monitor the market and our exposure and may enter into these arrangements in the future.
Commodity Price Risk
The information about commodity price risk for the three and nine months ended September 30, 2021 does not differ materially from that discussed in Item 7A. Quantitative and Qualitative Disclosures about Market Risk of our Annual Report on Form 10-K for the year ended December 31, 2020.
We have a natural gas purchase commitment embedded in a keep-whole processing agreement with a producer customer in the Southern Appalachian region expiring in December 2022. The customer has the unilateral option to extend the agreement for two consecutive five-year terms through December 2032. For accounting purposes, the natural gas purchase commitment and the term extending options have been aggregated into a single compound embedded derivative. The probability of the customer exercising its options is determined based on assumptions about the customer’s potential business strategy decision points that may exist at the time they would elect whether to renew the contract. The changes in fair value of this compound embedded derivative are based on the difference between the contractual and index pricing and the probability of the producer customer exercising its option to extend. The changes in fair value are recorded in earnings through “Purchased product costs” on the Consolidated Statements of Income. As of September 30, 2021 and December 31, 2020, the estimated fair value of this contract was a liability of $104 million and $63 million, respectively. We evaluate our portfolio of commodity derivative instruments on an ongoing basis and add or revise strategies in anticipation of changes in market conditions and in risk profiles.
Interest Rate Risk and Sensitivity Analysis
Sensitivity analysis of the effect of a hypothetical 100-basis-point change in interest rates on third-party outstanding debt, excluding finance leases, is provided in the following table. Fair value of cash and cash equivalents, receivables, accounts payable and accrued interest approximate carrying value and are relatively insensitive to changes in interest rates due to the short-term maturity of the instruments. Accordingly, these instruments are excluded from the table.
(In millions)
Fair value as of September 30, 2021(1)
Change in Fair Value(2)
Change in Income Before Income Taxes for the Nine Months Ended September 30, 2021(3)
Outstanding debt
Fixed-rate
$
20,553
$
1,881
N/A
Variable-rate(4)
$
—
$
—
$
9
(1) Fair value was based on market prices, where available, or current borrowing rates for financings with similar terms and maturities.
(2) Assumes a 100-basis-point decrease in the weighted average yield-to-maturity at September 30, 2021.
(3) Assumes a 100-basis-point change in interest rates. The change to net income was based on the weighted average balance of all outstanding variable-rate debt for the nine months ended September 30, 2021.
(4) MPLX redeemed the outstanding floating rate senior notes on September 3, 2021 and had no outstanding borrowings on the Revolver as of September 30, 2021.
At September 30, 2021, our portfolio of long-term debt consisted of fixed-rate instruments and also provides for borrowings under our revolving credit facility. The fair value of our fixed-rate debt is relatively sensitive to interest rate fluctuations. Our sensitivity to interest rate declines and corresponding increases in the fair value of our debt portfolio unfavorably affects our results of operations and cash flows only when we elect to repurchase or otherwise retire fixed-rate debt at prices above carrying value. Interest rate fluctuations generally do not impact the fair value of borrowings under our bank revolving credit facility, but may affect our results of operations and cash flows.
Item 4. Controls and Procedures
Disclosure Controls and Procedures
An evaluation of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) was carried out under the supervision and with the participation of management, including the chief executive officer and chief financial officer of our general partner. Based upon that evaluation, the chief executive officer and chief financial officer of our general partner concluded that the design and operation of these disclosure controls and procedures were effective as of September 30, 2021, the end of the period covered by this report.
Changes in Internal Control Over Financial Reporting
During the quarter ended September 30, 2021, there were no changes in our internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
We are the subject of, or a party to, a number of pending or threatened legal actions, contingencies and commitments involving a variety of matters, including laws and regulations relating to the environment. While it is possible that an adverse result in one or more of the lawsuits or proceedings in which we are a defendant could be material to us, based upon current information and our experience as a defendant in other matters, we believe that these lawsuits and proceedings, individually or in the aggregate, will not have a material adverse effect on our consolidated results of operations, financial position or cash flows.
Item 103 of Regulation S-K promulgated by the SEC requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions, unless we reasonably believe that the matter will result in no monetary sanctions, or in monetary sanctions, exclusive of interest and costs, of less than $300,000.
Except as described below, there have been no material changes to the legal matters previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2020, as updated in our subsequent Quarterly Reports on Form 10-Q.
Dakota Access Pipeline
We hold a 9.19 percent indirect interest in a joint venture (“Dakota Access”) that owns and operates the Dakota Access Pipeline and Energy Transfer Crude Oil Pipeline projects, collectively referred to as the Bakken Pipeline system or DAPL. In 2020, the U.S. District Court for the District of Columbia (the “D.D.C.”) ordered the U.S. Army Corps of Engineers (“Army Corps”), which granted permits and an easement for the Bakken Pipeline system, to prepare an environmental impact statement (“EIS”) relating to an easement under Lake Oahe in North Dakota. The D.D.C. later ordered vacatur of the easement during the pendency of the EIS and further ordered a shut down of the pipeline by August 5, 2020. On August 5, 2020, the U.S. Court of Appeals for the District of Columbia (the “Court of Appeals”) stayed the D.D.C.’s injunction that required the pipeline be shutdown and emptied of oil by August 5, 2020. On January 26, 2021, the Court of Appeals upheld the D.D.C.’s order vacating the easement while the Army Corps prepares the EIS. The Court of Appeals reversed the D.D.C.’s order to the extent it directed that the pipeline be shutdown and emptied of oil. In May 2021, the D.D.C. denied a renewed request for an injunction to shut down the pipeline while the EIS is being prepared. In June 2021, the D.D.C. issued an order dismissing without prejudice the tribes’ claims against the Dakota Access Pipeline. The judge noted that the plaintiffs may move to reopen the case in the event of a violation of the court’s prior orders. Dakota Access has petitioned the U.S. Supreme Court for review of the Court of Appeal’s decision upholding the D.D.C.’s order vacating the easement. The pipeline remains operational.
We have entered into a Contingent Equity Contribution Agreement whereby MPLX LP, along with the other joint venture owners in the Bakken Pipeline system, has agreed to make equity contributions to the joint venture upon certain events occurring to allow the entities that own and operate the Bakken Pipeline system to satisfy their senior note payment obligations. The senior notes were issued to repay amounts owed by the pipeline companies to fund the cost of construction of the Bakken Pipeline system. If the pipeline were temporarily shut down, MPLX would have to contribute its 9.19 percent pro rata share of funds required to pay interest accruing on the notes and any portion of the principal that matures while the pipeline is shutdown. MPLX also expects to contribute its 9.19 percent pro rata share of any costs to remediate any deficiencies to reinstate the permit and/or return the pipeline into operation. If the vacatur of the easement permit results in a permanent shutdown of the pipeline, MPLX would have to contribute its 9.19 percent pro rata share of the cost to redeem the bonds (including the 1% redemption premium required pursuant to the indenture governing the notes) and any accrued and unpaid interest. As of September 30, 2021, our maximum potential undiscounted payments under the Contingent Equity Contribution Agreement were approximately $230 million.
Item 1A. Risk Factors
There have been no material changes from the risk factors previously disclosed in our Annual Report on Form 10-K for the year ended December 31, 2020.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
The following table sets forth a summary of our purchases during the quarter ended September 30, 2021, of equity securities that are registered by MPLX pursuant to Section 12 of the Securities Exchange Act of 1934, as amended.
Period
Total Number of Units Purchased
Average Price Paid per Unit(1)
Total Number of Units Purchased as Part of Publicly Announced Plans or Programs
Maximum Dollar
Value of Units that
May Yet Be Purchased
Under the Plans or
Programs(2)
7/01/2021-7/31/2021
1,578,870
$
28.55
1,578,870
$
611,620,731
8/01/2021-8/31/2021
1,990,647
$
28.06
1,990,647
$
555,771,983
9/01/2021-9/30/2021
2,064,340
$
28.62
2,064,340
$
496,699,570
Total
5,633,857
$
28.40
5,633,857
(1)Amounts in this column reflect the weighted average price paid for units purchased under our unit repurchase authorization. The weighted average price includes commissions paid to brokers on shares repurchased under our unit repurchase authorization.
(2)On November 2, 2020, we announced the board authorization of a unit repurchase program for the repurchase of up to $1 billion of MPLX’s common units held by the public. This unit repurchase authorization has no expiration date.
XBRL Instance Document: The instance document does not appear in the interactive data file because its XBRL tags are embedded within the Inline XBRL document.
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
† The exhibits and schedules have been omitted pursuant to Item 601(b)(2) of Regulation S-K and will be provided to the Securities and Exchange Commission upon request
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
MPLX LP
By:
MPLX GP LLC
Its general partner
Date: November 2, 2021
By:
/s/ Kelly D. Wright
Kelly D. Wright
Vice President and Controller of MPLX GP LLC (the general partner of MPLX LP)
