Document

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

New York Stock Exchange

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)



☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934



For the quarterly period ended	June 30, 2019



☐	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:	001-36011

Phillips 66 Partners LP

(Exact name of registrant as specified in its charter)



Delaware		38-3899432
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

2331 CityWest Blvd., Houston, Texas 77042

(Address of principal executive offices) (Zip Code)

(855) 283-9237

(Registrant’s telephone number, including area code)

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. Yes ☒ 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 during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ 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	☒	Accelerated file	☐
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 ☒

The registrant had 124,938,423 common units outstanding as of June 30, 2019.

PHILLIPS 66 PARTNERS LP

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	Page
Part I – Financial Information	1

Item 1. Financial Statements	1
Consolidated Statement of Income	1
Consolidated Statement of Comprehensive Income	2
Consolidated Balance Sheet	3
Consolidated Statement of Cash Flows	4
Consolidated Statement of Changes in Equity	5
Notes to Consolidated Financial Statements	7

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	22

Item 3. Quantitative and Qualitative Disclosures About Market Risk	35

Item 4. Controls and Procedures	35

Part II – Other Information	36

Item 1. Legal Proceedings	36

Item 1A. Risk Factors	36

Item 6. Exhibits	37

Signatures	38

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PART I. FINANCIAL INFORMATION

Item 1. FINANCIAL STATEMENTS



Consolidated Statement of Income	Phillips 66 Partners LP



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018
Revenues and Other Income
Operating revenues—related parties	$	256	244	552	493
Operating revenues—third parties	7		10	13	17
Equity in earnings of affiliates	137		100	256	198
Other income	1		—	3	1
Total revenues and other income	401		354	824	709

Costs and Expenses
Operating and maintenance expenses	85		85	224	182
Depreciation	29		29	58	57
General and administrative expenses	17		16	35	32
Taxes other than income taxes	9		9	20	19
Interest and debt expense	27		29	54	59
Total costs and expenses	167		168	391	349
Income before income taxes	234		186	433	360
Income tax expense	1		—	2	2
Net income	233		186	431	358
Less: Preferred unitholders’ interest in net income	9		10	19	19
Less: General partner’s interest in net income	71		55	140	108
Limited partners’ interest in net income	$	153	121	272	231

Net Income Per Limited Partner Unit (dollars)
Common units—basic	$	1.23	0.99	2.19	1.89
Common units—diluted	1.15		0.94	2.07	1.80

Weighted-Average Limited Partner Units Outstanding (thousands)
Common units—basic	124,824		122,189	124,543	121,901
Common units—diluted	138,644		136,008	138,362	135,720
See Notes to Consolidated Financial Statements.

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Consolidated Statement of Comprehensive Income	Phillips 66 Partners LP



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018

Net Income	$	233	186	431	358
Defined benefit plans
Plan sponsored by equity affiliates, net of income taxes	—		—	—	—
Other comprehensive income	—		—	—	—
Comprehensive Income	$	233	186	431	358
See Notes to Consolidated Financial Statements.

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Consolidated Balance Sheet	Phillips 66 Partners LP



	Millions of Dollars
	June 30 2019			December 31 2018
Assets
Cash and cash equivalents	$	130		1
Accounts receivable—related parties	85			90
Accounts receivable—third parties	3			5
Materials and supplies	13			13
Prepaid expenses and other current assets	9			20
Total current assets	240			129
Equity investments	2,912			2,448
Net properties, plants and equipment	3,158			3,052
Goodwill	185			185
Other assets	49			5
Total Assets	$	6,544		5,819

Liabilities
Accounts payable—related parties	$	19		22
Accounts payable—third parties	74			88
Accrued interest	37			36
Deferred revenues	17			60
Short-term debt	150			50
Accrued property and other taxes	18			9
Other current liabilities	2			5
Total current liabilities	317			270
Long-term debt	3,174			2,998
Obligation from equity interest transfer	341			—
Other liabilities	96			42
Total Liabilities	3,928			3,310

Equity
Preferred unitholders (2019 and 2018—13,819,791 units issued and outstanding)	746			746
Common unitholders—public (2019—56,178,286 units issued and outstanding; 2018—55,343,918 units issued and outstanding)	2,555			2,485
Common unitholder—Phillips 66 (2019 and 2018—68,760,137 units issued and outstanding)	626			592
General partner—Phillips 66 (2019 and 2018—2,480,051 units issued and outstanding)	(1,310		)	(1,313	)
Accumulated other comprehensive loss	(1		)	(1	)
Total Equity	2,616			2,509
Total Liabilities and Equity	$	6,544		5,819
See Notes to Consolidated Financial Statements.

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Consolidated Statement of Cash Flows	Phillips 66 Partners LP



	Millions of Dollars
	Six Months Ended June 30
	2019			2018
Cash Flows From Operating Activities
Net income	$	431		358
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	58			57
Undistributed equity earnings	3			(7	)
Other liabilities	12			(38	)
Working capital adjustments
Accounts receivable	6			(3	)
Prepaid expenses and other current assets	12			—
Accounts payable	(3		)	(3	)
Accrued interest	—			2
Deferred revenues	(46		)	30
Other accruals	8			1
Net Cash Provided by Operating Activities	481			397

Cash Flows From Investing Activities
Cash capital expenditures and investments	(759		)	(234	)
Advances/loans—related party	(95		)	—
Collection of advances/loans—related party	95			—
Return of investment from equity affiliates	35			22
Proceeds from sale of equity interest	81			—
Net Cash Used in Investing Activities	(643		)	(212	)

Cash Flows From Financing Activities
Proceeds from equity interest transfer	341			—
Issuance of debt	860			—
Repayment of debt	(585		)	—
Issuance of common units	42			67
Quarterly distributions to preferred unitholders	(19		)	(18	)
Quarterly distributions to common unitholders—public	(93		)	(74	)
Quarterly distributions to common unitholder—Phillips 66	(116		)	(96	)
Quarterly distributions to General Partner—Phillips 66	(136		)	(98	)
Other distributions to Phillips 66	(3		)	—
Net Cash Provided by (Used in) Financing Activities	291			(219	)

Net Change in Cash and Cash Equivalents	129			(34	)
Cash and cash equivalents at beginning of period	1			185
Cash and Cash Equivalents at End of Period	$	130		151
See Notes to Consolidated Financial Statements.

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Consolidated Statement of Changes in Equity	Phillips 66 Partners LP



	Millions of Dollars
	Three Months Ended June 30
	Preferred Unitholders Public			Common Unitholders Public		Common Unitholder Phillips 66		General Partner Phillips 66		Accum. Other Comprehensive Loss		Total

March 31, 2019	$	747		2,523		600		(1,315	)	(1	)	2,554
Issuance of common units	—			10		—		—		—		10
Net income	9			69		84		71		—		233
Quarterly cash distributions to unitholders and General Partner ($0.845 per common unit)	(10		)	(47	)	(58	)	(69	)	—		(184	)
Other contributions from Phillips 66	—			—		—		3		—		3
June 30, 2019	$	746		2,555		626		(1,310	)	(1	)	2,616

March 31, 2018	$	746		2,308		519		(1,338	)	(1	)	2,234
Cumulative effect of accounting change	—			—		1		—		—		1
Issuance of common units	—			58		—		—		—		58
Net income	10			53		68		55		—		186
Quarterly cash distributions to unitholders and General Partner ($0.714 per common unit)	(9		)	(38	)	(50	)	(51	)	—		(148	)
Other contributions from Phillips 66	—			—		—		2		—		2
June 30, 2018	$	747		2,381		538		(1,332	)	(1	)	2,333



	Units
	Three Months Ended June 30
	Preferred Units Public	Common Units Public	Common Units Phillips 66	General Partners Units Phillips 66	Total Units

March 31, 2019	13,819,791	55,965,950	68,760,137	2,480,051	141,025,929
Units issued in public equity offerings	—	212,336	—	—	212,336
June 30, 2019	13,819,791	56,178,286	68,760,137	2,480,051	141,238,265

March 31, 2018	13,819,791	53,000,637	68,760,137	2,480,051	138,060,616
Units issued in public equity offerings	—	1,152,119	—	—	1,152,119
June 30, 2018	13,819,791	54,152,756	68,760,137	2,480,051	139,212,735

See Notes to Consolidated Financial Statements.

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	Millions of Dollars
	Six Months Ended June 30
	Preferred Unitholders Public		Common Unitholders Public		Common Unitholder Phillips 66		General Partner Phillips 66		Accum. Other Comprehensive Loss		Total

December 31, 2018	746		2,485		592		(1,313	)	(1	)	2,509
Cumulative effect of accounting change	—		(1	)	—		—		—		(1	)
Issuance of common units	—		42		—		—		—		42
Net income	19		122		150		140		—		431
Quarterly cash distributions to unitholders and General Partner ($1.680 per common unit)	(19	)	(93	)	(116	)	(136	)	—		(364	)
Other distributions to Phillips 66	—		—		—		(1	)	—		(1	)
June 30, 2019	746		2,555		626		(1,310	)	(1	)	2,616

December 31, 2017	746		2,274		487		(1,345	)	(1	)	2,161
Cumulative effect of accounting change	—		13		17		1		—		31
Issuance of common units	—		67		—		—		—		67
Net income	19		101		130		108		—		358
Quarterly cash distributions to unitholders and General Partner ($1.392 per common unit)	(18	)	(74	)	(96	)	(98	)	—		(286	)
Other contributions from Phillips 66	—		—		—		2		—		2
June 30, 2018	747		2,381		538		(1,332	)	(1	)	2,333



	Units
	Six Months Ended June 30
	Preferred Units Public	Common Units Public	Common Units Phillips 66	General Partners Units Phillips 66	Total Units

December 31, 2018	13,819,791	55,343,918	68,760,137	2,480,051	140,403,897
Units issued in public equity offerings	—	834,368	—	—	834,368
June 30, 2019	13,819,791	56,178,286	68,760,137	2,480,051	141,238,265

December 31, 2017	13,819,791	52,811,822	68,760,137	2,480,051	137,871,801
Units issued in public equity offerings	—	1,340,934	—	—	1,340,934
June 30, 2018	13,819,791	54,152,756	68,760,137	2,480,051	139,212,735

See Notes to Consolidated Financial Statements.

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Notes to Consolidated Financial Statements	Phillips 66 Partners LP

Note 1—Description of the Business

Unless otherwise stated or the context otherwise indicates, all references to “Phillips 66 Partners,” “the Partnership,” “us,” “our,” “we,” or similar expressions refer to Phillips 66 Partners LP, including its consolidated subsidiaries. References to Phillips 66 may refer to Phillips 66 and/or its subsidiaries, depending on the context. References to our “General Partner” refer to Phillips 66 Partners GP LLC, and references to Phillips 66 PDI refer to Phillips 66 Project Development Inc., the Phillips 66 subsidiary that holds a limited partner interest in us and wholly owns our General Partner.

We are a growth-oriented master limited partnership formed to own, operate, develop and acquire primarily fee-based midstream assets. Our operations consist of crude oil, refined petroleum products and natural gas liquids (NGL) transportation, terminaling, processing and storage assets. We conduct our operations through both wholly owned and joint venture operations. The majority of our wholly owned assets are associated with, and are integral to the operation of, nine of Phillips 66’s owned or joint venture refineries.

We primarily generate revenue by providing fee-based transportation, terminaling, processing, storage and fractionation services to Phillips 66 and other customers. Our equity affiliates primarily generate revenue from transporting and terminaling crude oil, refined petroleum products and NGL. Since we do not own any of the crude oil, refined petroleum products and NGL we handle and do not engage in the trading of crude oil, refined petroleum products and NGL, we have limited direct exposure to risks associated with fluctuating commodity prices, although these risks indirectly influence our activities and results of operations over the long term.

Note 2—Interim Financial Information

The unaudited interim financial information presented in the financial statements included in this report is prepared in accordance with generally accepted accounting principles in the United States (GAAP) and includes all known accruals and adjustments necessary, in the opinion of management, for a fair presentation of our financial position, results of operations and cash flows for the periods presented. Unless otherwise specified, all such adjustments are of a normal and recurring nature. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these interim financial statements should be read in conjunction with the audited consolidated financial statements and notes included in our 2018 Annual Report on Form 10-K. The results of operations for the three and six months ended June 30, 2019, are not necessarily indicative of the results to be expected for the full year. Certain prior period financial information has been recast to reflect the current year’s presentation.

Note 3—Changes in Accounting Principles

Effective January 1, 2019, we early adopted Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) 2016-13, “Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which amends the impairment model to utilize an expected loss methodology in place of the incurred loss methodology for financial instruments and off-balance sheet credit exposures. The amendment requires entities to consider a broader range of information to estimate expected credit losses, which may result in earlier recognition of losses. The adoption of the ASU did not have a material impact on our consolidated financial statements.

Effective January 1, 2019, we adopted ASU 2016-02, “Leases (Topic 842)” using the modified retrospective transition method. The new standard establishes a right-of-use (ROU) model that requires a lessee to record a ROU asset and corresponding lease liability on the consolidated balance sheet for all operating leases with terms longer than 12 months. Leases will continue to be classified as either finance or operating, with classification affecting the pattern of expense recognition in the consolidated income statement.

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We elected the package of practical expedients that allowed us to carry forward the determination of whether an arrangement contains a lease and lease classification, as well as our accounting for initial direct costs for existing contracts. We recorded a noncash cumulative effect adjustment to our opening consolidated balance sheet as of January 1, 2019, to record an aggregate operating lease ROU asset and a corresponding lease liability of $45 million. See Note 5—Lease Assets and Liabilities, for the new lease disclosures required by this ASU for lessees.

For arrangements where we are the lessor, effective for periods after January 1, 2019, we elected to account for lease and service elements of contracts classified as leases on a combined basis under the provisions of ASU No. 2016-02, except for leases of processing-type assets, which contain non-ratable fees related to turnaround activity. For these types of leases, we continued to separate the lease and service elements based on relative standalone prices and applied the new lease standard to the lease element and the revenue standard to the service element. We recorded a noncash cumulative effect adjustment of $1 million to decrease our opening equity balance as of January 1, 2019. See Note 4—Operating Revenues, for additional impacts of adopting this ASU, including new lease disclosures required for lessors.

Note 4—Operating Revenues

Operating revenues are primarily generated from long-term pipeline transportation, terminaling, storage, processing and fractionation lease and service agreements, mainly with Phillips 66. These agreements typically include escalation clauses to adjust transportation tariffs and terminaling and storage fees to reflect changes in price indices. In addition, most of these agreements contain renewal options, which typically require the mutual consent of both our customers and us.

Total operating revenues disaggregated by asset type were as follows:



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018

Pipelines	$	117	111	226	213
Terminals	39		38	79	77
Storage, processing and other revenues	107		105	260	220
Total operating revenues	$	263	254	565	510

The majority of our agreements with Phillips 66 are considered operating leases under GAAP. For reporting periods prior to our adoption of the new lease accounting standard, ASU No. 2016-02, as of January 1, 2019, the lease and service elements included in these contracts were separated with the lease element recognized in accordance with the existing lease accounting standard and the service element recognized in accordance with the revenue accounting standard. Effective for periods after January 1, 2019, we elected to account for lease and service elements of contracts classified as leases on a combined basis under the provisions of ASU No. 2016-02, except for leases of processing-type assets, which contain non-ratable fees related to turnaround activity. For these types of leases, we continued to separate the lease and service elements based on relative standalone prices and applied the new lease standard to the lease element and the revenue standard to the service element. As a result of our change in accounting policy, our lease and service revenues, lease and service accounts receivable and lease and service deferred revenues reported for the three and six months ended June 30, 2019, are not prepared on the same basis as the amounts reported for the three and six months ended June 30, 2018.

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Total operating revenues disaggregated by lease and service revenues were as follows:



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018

Lease revenues	$	214	143	471	287
Service revenues	49		111	94	223
Total operating revenues	$	263	254	565	510

Accounts Receivable

We bill our customers, mainly Phillips 66, under our lease and service contracts generally on a monthly basis.

Total accounts receivable by revenue type was as follows:



	Millions of Dollars
	June 30 2019		December 31 2018

Lease receivables	$	69	53
Service receivables	19		41
Other receivables	—		1
Total accounts receivables	$	88	95

Deferred Revenues

Our deferred revenues represent payments received from our customers, mainly Phillips 66, in advance of the period in which lease and service contract performance obligations have been fulfilled. The majority of our deferred revenues relate to a tolling agreement and a storage agreement that are classified as leases. The remainder of our deferred revenues relate to lease and service agreements that contain minimum volume commitments with recovery provisions. Our deferred revenues are recorded in the “Deferred revenues” and “Other liabilities” lines on our consolidated balance sheet. Total deferred revenues under our lease and service agreements were as follows:



	Millions of Dollars
	June 30 2019		December 31 2018

Deferred lease revenues	$	42	73
Deferred service revenues	1		6
Total deferred revenues	$	43	79

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Future Minimum Lease Payments from Customers

At June 30, 2019, future minimum payments to be received under our lease agreements with customers were estimated to be:



	Millions of Dollars

Remainder of 2019	$	325
2020	644
2021	639
2022	627
2023	585
Remaining years	1,570
Total future minimum lease payments from customers	$	4,390

Remaining Service Performance Obligations

We typically have long-term service contracts with our customers, of which the original durations range from 5 to 15 years. The weighted-average remaining duration of these contracts is 11 years. These contracts include both fixed and variable transaction price components. At June 30, 2019, future service revenues expected to be recognized for the fixed component of the transaction price of our remaining performance obligations from service contracts with our customers that have an original expected duration of greater than one year were:



	Millions of Dollars

Remainder of 2019	$	72
2020	139
2021	131
2022	130
2023	130
Remaining years	754
Total future service revenues	$	1,356

For the remaining service performance obligations, we applied the exemption for variable prices allocated entirely to a wholly unsatisfied performance obligation or to a wholly unsatisfied promise to transfer distinct services as part of a performance obligation.

Note 5—Lease Assets and Liabilities

We have agreements with Phillips 66 to lease land underlying or associated with certain of our assets that are classified as operating leases. Due to the economic infeasibility of canceling these leases, we consider them non-cancellable. Certain leases include escalation clauses for adjusting rental payments to reflect changes in price indices. There are no significant restrictions imposed on us in our lease agreements with regards to distribution payments, asset dispositions or borrowing ability.

Effective with our implementation of ASU No. 2016-02, we elected to discount lease obligations using our incremental borrowing rate. For all leases, we elected the practical expedient to not separate service and lease costs. Our right-of-way agreements in effect prior to January 1, 2019, were not accounted for as leases as they were not initially determined

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to be leases at their commencement dates. However, modifications to these agreements or new agreements will be assessed and accounted for accordingly under ASU No. 2016-02. For short-term leases, which are leases that, at the commencement date, have a lease term of 12 months or less and do not include an option to purchase the underlying asset that is reasonably certain to be exercised, we elected to not recognize the ROU asset and corresponding lease liability on our consolidated balance sheet.

Operating lease ROU assets are recorded in the “Other assets” line and lease liabilities are recorded in the “Other current liabilities” and “Other liabilities” lines on our consolidated balance sheet. At June 30, 2019, the total operating lease ROU asset was $44 million.

Future minimum lease payments and recorded short- and long-term lease liabilities at June 30, 2019, for operating leases were:



	Millions of Dollars

Remainder of 2019	$	2
2020	3
2021	3
2022	3
2023	3
Remaining years	93
Future minimum lease payments	107
Amount representing interest or discounts	(63		)
Total lease liabilities	44
Short-term lease liabilities	(1		)
Long-term lease liabilities	$	43

Operating lease costs and operating cash outflows for the three and six months ended June 30, 2019, were $1 million.

The weighted-average remaining lease term for our operating leases as of June 30, 2019, was 36 years. The weighted-average discount rate for our operating leases as of June 30, 2019, was 5.9%.

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Note 6—Equity Investments and Loans

Equity Investments

The following table summarizes the carrying value of our equity investments:



			Millions of Dollars
	Percentage Ownership		June 30 2019		December 31 2018

Dakota Access, LLC and Energy Transfer Crude Oil Company, LLC (Bakken Pipeline)	25.00	%	$	590	608
Bayou Bridge Pipeline, LLC (Bayou Bridge)	40.00		296		277
DCP Sand Hills Pipeline, LLC (Sand Hills)	33.34		600		601
DCP Southern Hills Pipeline, LLC (Southern Hills)	33.34		209		206
Explorer Pipeline Company (Explorer)	21.94		107		115
Gray Oak Pipeline, LLC (Gray Oak)	65.00		745		288
Paradigm Pipeline LLC (Paradigm)	50.00		145		145
Phillips 66 Partners Terminal LLC (Phillips 66 Partners Terminal)	70.00		70		71
South Texas Gateway Terminal LLC (South Texas Gateway Terminal)	25.00		36		20
STACK Pipeline LLC (STACK)	50.00		114		117
Total equity investments			$	2,912	2,448

Earnings from our equity investments were as follows:



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018

Bakken Pipeline	$	58	39	109	71
Bayou Bridge	8		3	12	8
Sand Hills	38		31	74	56
Southern Hills	11		9	24	16
Explorer	11		8	14	24
Gray Oak	—		—	—	—
Paradigm	3		2	6	4
Phillips 66 Partners Terminal	6		6	12	15
South Texas Gateway Terminal	—		—	—	—
STACK	2		2	5	4
Total equity in earnings of affiliates	$	137	100	256	198

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Gray Oak

In April 2018, we entered into a Purchase and Sale Agreement with Phillips 66 PDI to acquire its 100% interest in Gray Oak Holdings LLC (Holdings LLC), a limited liability company that, at that time, owned a 100% interest in Gray Oak. Gray Oak is developing and constructing the Gray Oak Pipeline which, upon completion, will provide crude oil transportation from the Permian and Eagle Ford to destinations in Corpus Christi, Texas, and the Sweeny, Texas, area, including the Phillips 66 Sweeny Refinery. The pipeline system is anticipated to be in service by the end of 2019. We accounted for the acquisition of Holdings LLC as an acquisition of assets under common control accounting. Also in April 2018, a co-venturer acquired a 25% interest in Gray Oak, along with sufficient voting rights over key governance provisions such that we no longer could assert control over Gray Oak. As a result, we (through our consolidated subsidiary Holdings LLC) began using the equity method of accounting for our investment in Gray Oak at that time.

In December 2018, a third party exercised its option to acquire a 35% interest in Holdings LLC. Because Holdings LLC’s sole asset was its 75% ownership interest in Gray Oak, which is considered a financial asset, and because certain restrictions were placed on the third party’s ability to transfer or sell its interest in Holdings LLC during the construction of the Gray Oak Pipeline, the legal sale of the 35% interest did not qualify as a sale under GAAP. Rather, the third party’s cash contributions to Holdings LLC in 2019 to fund its share of previously incurred and future construction costs plus a premium to us are reflected as a long-term obligation in the “Obligation from equity interest transfer” line on our consolidated balance sheet and financing cash inflows in the “Proceeds from equity interest transfer” line on our consolidated statement of cash flows. After construction of the Gray Oak Pipeline is fully completed, these restrictions expire, and the sale will be recognized under GAAP. We will continue to control and consolidate Holdings LLC after sale recognition, and therefore the third party’s 35% interest will be recharacterized from a long-term obligation to a noncontrolling interest on our consolidated balance sheet at that time. Also at that time, the premium paid will be recharacterized from a long-term obligation to a gain in our consolidated statement of income. During the six months ended June 30, 2019, the third party contributed an aggregate of $341 million into Holdings LLC, which Holdings LLC used to fund its portion of Gray Oak’s cash calls.

In February 2019, Holdings LLC transferred a 10% interest in Gray Oak to a third party that exercised a purchase option, for proceeds of $81 million. This transfer was accounted for as a sale and resulted in a decrease in Holdings LLC’s ownership interest in Gray Oak from 75% to 65% and the recognition of an immaterial gain. The proceeds received from this sale are reflected as an investing cash inflow in the “Proceeds from sale of equity interest” line on our consolidated statement of cash flows. At June 30, 2019, our effective ownership interest in the Gray Oak Pipeline was 42.25%.

In June 2019, Gray Oak entered into a third-party term loan facility with an initial borrowing capacity of $1,230 million, which was increased in July 2019 to $1,317 million. Borrowings under the facility are due on June 3, 2022. We and our co-venturers provided a guarantee through an equity contribution agreement requiring proportionate equity contributions to Gray Oak up to the total outstanding loan amount. Under the agreement, our maximum potential amount of future obligations is $556 million, plus any accrued interest and associated fees, which would be required if the term loan facility is fully utilized and Gray Oak defaults on its obligations. At June 30, 2019, Gray Oak had borrowings of $551 million outstanding, and our 42.25% proportionate exposure was $233 million. The net proceeds from the term loan were used by Gray Oak for construction of the Gray Oak Pipeline and repayment of amounts borrowed under a related party loan agreement that we and our co-venturers executed in March 2019 and terminated upon the repayment by Gray Oak in June. Our total related party loan to and repayment received from Gray Oak was $95 million during the second quarter of 2019.

Gray Oak is considered a variable interest entity because it does not have sufficient equity at risk to fully fund the construction of all assets required for principal operations. We have determined we are not the primary beneficiary because we and our co-venturers jointly direct the activities of Gray Oak that most significantly impact economic performance. At June 30, 2019, our maximum exposure to loss was $978 million, which represented our guarantee of the third-party term loan facility of $233 million and the aggregate book value of our equity method investment in Gray Oak of $745 million.

Bakken Pipeline

In March 2019, a wholly owned subsidiary of Dakota Access, LLC (Dakota Access) closed on an offering of $2,500 million aggregate principal amount of unsecured senior notes. The net proceeds from the issuance of these notes were used to repay amounts outstanding under existing credit facilities of Dakota Access and Energy Transfer Crude Oil Company, LLC (ETCO). Dakota Access and ETCO have guaranteed repayment of the notes. In addition, we and our

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co-venturers provided a Contingent Equity Contribution Undertaking (CECU) in conjunction with the notes offering. Under the CECU, if Dakota Access receives an unfavorable court ruling related to certain disputed construction permits and Dakota Access determines that an equity contribution trigger event has occurred, the venturers may be severally required to make proportionate equity contributions to Dakota Access and ETCO up to an aggregate maximum of approximately $2,525 million. Our share of the maximum potential equity contributions under the CECU is approximately $631 million.

Note 7—Net Income Per Limited Partner Unit

Net income per limited partner unit applicable to common units is computed by dividing the limited partners’ interest in net income by the weighted-average number of common units outstanding for the period. Because we have more than one class of participating securities, we use the two-class method to calculate the net income per unit applicable to the limited partners. As of June 30, 2019, the classes of participating securities included common units, general partner units and incentive distribution rights (IDRs). For the three and six months ended June 30, 2019 and 2018, our preferred units are potentially dilutive securities and were dilutive to net income per limited partner unit.

Net income earned by the Partnership is allocated between the limited partners and the General Partner (including the General Partner’s IDRs) in accordance with our partnership agreement, after giving effect to priority income allocations to the holders of the preferred units. First, earnings are allocated based on actual cash distributions declared to our unitholders, including those attributable to the General Partner’s IDRs. To the extent net income exceeds or is less than cash distributions, this difference is allocated based on the unitholders’ respective ownership percentages, after consideration of any priority allocations of earnings. For the diluted net income per limited partner unit calculation, the preferred units are assumed to be converted at the beginning of the period into common limited partner units on a one-for-one basis, and the distribution formula for available cash in our partnership agreement is recalculated, using the original available cash amount increased only for the preferred distributions which would not have been paid after conversion.



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018

Net income	$	233	186	431	358
Less:
General partner’s distributions declared (including IDRs)*	70		57	139	108
Limited partners’ distributions declared on preferred units*	9		10	19	19
Limited partners’ distributions declared on common units*	107		91	212	179
Distributions less than net income	$	47	28	61	52

*Distributions declared attributable to the indicated periods.

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	Limited Partners’ Common Units		General Partner (including IDRs)	Limited Partners’ Preferred Units	Total
Three Months Ended June 30, 2019
Net income (millions):
Distributions declared	$	107	70	9	186
Distributions less than net income	46		1	—	47
Net income (basic)	153		71	9	233
Dilutive effect of preferred units*	6
Net income (diluted)	$	159

Weighted-average units outstanding—basic	124,824,010
Dilutive effect of preferred units*	13,819,791
Weighted-average units outstanding—diluted	138,643,801

Net income per limited partner unit—basic (dollars)	$	1.23
Net income per limited partner unit—diluted (dollars)	1.15



Three Months Ended June 30, 2018
Net income (millions):
Distributions declared	$	91	57		10	158
Distributions less than (more than) net income	30		(2	)	—	28
Net income (basic)	121		55		10	186
Dilutive effect of preferred units*	7
Net income (diluted)	$	128

Weighted-average units outstanding—basic	122,188,646
Dilutive effect of preferred units*	13,819,791
Weighted-average units outstanding—diluted	136,008,437

Net income per limited partner unit—basic (dollars)	$	0.99
Net income per limited partner unit—diluted (dollars)	0.94
*The dilutive effect of preferred units assumes the reallocation of net income to the limited and general partners, including a reallocation associated with IDRs, pursuant to the available cash formula in the partnership agreement.

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	Limited Partners’ Common Units		General Partner (including IDRs)	Limited Partners’ Preferred Units	Total
Six Months Ended June 30, 2019
Net income (millions):
Distributions declared	$	212	139	19	370
Distributions less than net income	60		1	—	61
Net income (basic)	272		140	19	431
Dilutive effect of preferred units*	14
Net income (diluted)	$	286

Weighted-average units outstanding—basic	124,542,536
Dilutive effect of preferred units*	13,819,791
Weighted-average units outstanding—diluted	138,362,327

Net income per limited partner unit—basic (dollars)	$	2.19
Net income per limited partner unit—diluted (dollars)	2.07



Six Months Ended June 30, 2018
Net income (millions):
Distributions declared	$	179	108	19	306
Distributions less than net income	52		—	—	52
Net income (basic)	231		108	19	358
Dilutive effect of preferred units*	14
Net income (diluted)	$	245

Weighted-average units outstanding—basic	121,900,683
Dilutive effect of preferred units*	13,819,791
Weighted-average units outstanding—diluted	135,720,474

Net income per limited partner unit—basic (dollars)	$	1.89
Net income per limited partner unit—diluted (dollars)	1.80
*The dilutive effect of preferred units assumes the reallocation of net income to the limited and general partners, including a reallocation associated with IDRs, pursuant to the available cash formula in the partnership agreement.

On July 17, 2019, the Board of Directors of our General Partner declared a quarterly cash distribution of $0.855 per common unit attributable to the second quarter of 2019. This distribution is payable on August 13, 2019, to unitholders of record as of July 31, 2019.

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Note 8—Properties, Plants and Equipment

Our investment in properties, plants and equipment (PP&E), with the associated accumulated depreciation, was:



	Millions of Dollars
	June 30 2019			December 31 2018

Land	$	19		19
Buildings and improvements	92			89
Pipelines and related assets*	1,405			1,398
Terminals and related assets*	717			710
Rail racks and related assets*	137			137
Processing and related assets*	889			842
Caverns and related assets*	585			584
Construction-in-progress	314			216
Gross PP&E	4,158			3,995
Accumulated depreciation	(1,000		)	(943	)
Net PP&E	$	3,158		3,052
*Assets for which we are the lessor.

Note 9—Debt



	Millions of Dollars
	June 30 2019			December 31 2018

2.646% Senior Notes due February 2020	$	300		300
3.605% Senior Notes due February 2025	500			500
3.550% Senior Notes due October 2026	500			500
3.750% Senior Notes due March 2028	500			500
4.680% Senior Notes due February 2045	450			450
4.900% Senior Notes due October 2046	625			625
Term loans due March 2020 at 3.167% at June 30, 2019	400			—
Tax-exempt bonds due April 2020 and April 2021 at 2.105% and 1.885% at June 30, 2019, and December 31, 2018, respectively	75			75
Revolving credit facility due January 2019 at 3.669% at December 31, 2018	—			125
Debt at face value	3,350			3,075
Net unamortized discounts and debt issuance costs	(26		)	(27	)
Total debt	3,324			3,048
Short-term debt	(150		)	(50	)
Long-term debt	$	3,174		2,998

On March 22, 2019, we entered into a senior unsecured term loan facility with a borrowing capacity of $400 million that matures on March 20, 2020. At June 30, 2019, term loans totaling $400 million were outstanding under this facility. Borrowings under this facility bear interest at a floating rate based on either the Eurodollar rate or the reference rate, plus a margin determined by our credit ratings. Proceeds from term loans made under this facility were used for general partnership purposes, including repayment of amounts borrowed under our $750 million revolving credit facility.

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As of June 30, 2019, no amount had been directly drawn under our $750 million revolving credit facility; however, $1 million in letters of credit had been issued that were supported by this facility. As of December 31, 2018, we had an aggregate of $125 million borrowed and outstanding under the credit facility.

At June 30, 2019, $575 million of debt due within a year was classified as long-term debt based on our intent to refinance the obligation on a long-term basis and ability to do so under our revolving credit facility.

The fair value of our fixed-rate and floating-rate debt is estimated based on observable market prices and is classified in level 2 of the fair value hierarchy. The fair value of our fixed-rate debt amounted to $2,962 million and $2,660 million at June 30, 2019, and December 31, 2018, respectively. The fair value of our floating-rate debt approximated carrying value of $475 million and $200 million at June 30, 2019, and December 31, 2018, respectively.

Note 10—Equity

ATM Programs

Our initial $250 million continuous offering of common units, or at-the-market (ATM) program, was completed in June 2018. At that time, we commenced issuing common units under our second $250 million ATM program. For the three and six months ended June 30, 2019, on a settlement date basis, we issued an aggregate of 212,336 and 834,368 common units under our ATM programs, generating net proceeds of $10 million and $42 million, respectively. For the three and six months ended June 30, 2018, we issued an aggregate of 1,152,119 and 1,340,934 common units under our ATM programs, generating net proceeds of $58 million and $67 million, respectively. Since inception in June 2016 through June 30, 2019, we issued an aggregate of 7,085,332 common units under our ATM programs, generating net proceeds of $361 million, after broker commissions of $4 million. The net proceeds from sales under the ATM programs are used for general partnership purposes, which may include debt repayment, acquisitions, capital expenditures and additions to working capital.

Note 11—Contingencies

From time to time, lawsuits involving a variety of claims that arise in the ordinary course of business are filed against us. We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various sites. We regularly assess the need for accounting recognition or disclosure of these contingencies. In the case of all known contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. In the case of income-tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain.

Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include any contingent liabilities recorded for environmental remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and the determination of our liability in proportion to that of other potentially responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes.

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Environmental

We are subject to federal, state and local environmental laws and regulations. We record accruals for contingent environmental liabilities based on management’s best estimates, using all information that is available at the time. We measure estimates and base liabilities on currently available facts, existing technology, and presently enacted laws and regulations, taking into account stakeholder and business considerations. When measuring environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies’ cleanup experience, and data released by the U.S. Environmental Protection Agency or other organizations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable.

In the future, we may be involved in additional environmental assessments, cleanups and proceedings.

Legal Proceedings

Under our amended omnibus agreement, Phillips 66 provides certain services for our benefit, including legal support services, and we pay an operational and administrative support fee for these services. Phillips 66’s legal organization applies its knowledge, experience and professional judgment to the specific characteristics of our cases, employing a litigation management process to manage and monitor the legal proceedings against us. The process facilitates the early evaluation and quantification of potential exposures in individual cases and enables tracking of those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, Phillips 66’s legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existing accruals, or establishment of new accruals, is required. As of June 30, 2019, and December 31, 2018, we did not have any material accrued contingent liabilities associated with litigation matters.

Indemnification and Excluded Liabilities

Under our amended omnibus agreement and pursuant to the terms of various agreements under which we acquired assets from Phillips 66, Phillips 66 will indemnify us, or assume responsibility, for certain environmental liabilities, tax liabilities, litigation and any other liabilities attributable to the ownership or operation of the assets contributed to us and that arose prior to the effective date of each acquisition. These indemnifications and exclusions from liability have, in some cases, time limits and deductibles. When Phillips 66 performs under any of these indemnifications or exclusions from liability, we recognize noncash expenses and associated noncash capital contributions from our General Partner, as these are considered liabilities paid for by a principal unitholder.

Note 12—Cash Flow Information

Capital Expenditures and Investments

Our capital expenditures and investments consisted of:



	Millions of Dollars
	Six Months Ended June 30
	2019			2018

Cash capital expenditures and investments	$	759		234
Change in capital expenditure accruals	(13		)	14
Total capital expenditures and investments	$	746		248

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Note 13—Related Party Transactions

Commercial Agreements

We have entered into long-term, fee-based commercial agreements with Phillips 66 to provide transportation, terminaling, storage, stevedoring, fractionation, processing, and rail terminal services. Under these agreements, Phillips 66 commits to provide us with minimum transportation, throughput or storage volumes, or minimum monthly service fees. If Phillips 66 does not meet its minimum volume commitments, Phillips 66 pays us a deficiency payment based on the calculation described in the agreement.

Amended and Restated Operational Services Agreement

Under our amended and restated operational services agreement, we reimburse Phillips 66 for certain operational services in support of our pipelines, terminaling, processing, and storage facilities. These services include routine and emergency maintenance and repair services, routine operational activities, routine administrative services, construction and related services and such other services as we and Phillips 66 may mutually agree upon from time to time.

Amended Omnibus Agreement

The amended omnibus agreement addresses our payment of an operating and administrative support fee and our obligation to reimburse Phillips 66 for all other direct or allocated costs and expenses incurred by Phillips 66 in providing general and administrative services. Additionally, the omnibus agreement addresses Phillips 66’s indemnification to us and our indemnification to Phillips 66 for certain environmental and other liabilities. Further, it addresses the granting of a license from Phillips 66 to us with respect to the use of certain Phillips 66 trademarks.

Tax Sharing Agreement

Under our tax sharing agreement, we reimburse Phillips 66 for our share of state and local income and other taxes incurred by Phillips 66 due to our results of operations being included in a combined or consolidated tax return filed by Phillips 66. Any reimbursement is limited to the tax that we (and our subsidiaries) would have paid had we not been included in a combined group with Phillips 66. Phillips 66 may use its tax attributes to cause its combined or consolidated group to owe no tax; however, we would nevertheless reimburse Phillips 66 for the tax we would have owed, even though Phillips 66 had no cash expense for that period.

Related Party Transactions

Significant related party transactions included in our total costs and expenses were:



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018

Operating and maintenance expenses	$	50	50	155	115
General and administrative expenses	16		15	33	30
Total	$	66	65	188	145

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We pay Phillips 66 a monthly operational and administrative support fee under the terms of our amended omnibus agreement in the amount of $8 million. The operational and administrative support fee is for the provision of certain services, including: logistical services; asset oversight, such as operational management and supervision; corporate engineering services, including asset integrity and regulatory services; business development services; executive services; financial and administrative services (including treasury and accounting); information technology; legal services; corporate health, safety and environmental services; facility services; human resources services; procurement services; investor relations; tax matters; and public company reporting services. We also reimburse Phillips 66 for all other direct or allocated costs incurred on behalf of us, pursuant to the terms of our amended omnibus agreement. The classification of these charges between operating and maintenance expenses and general and administrative expenses is based on the functional nature of the services performed for our operations. Under our amended and restated operational services agreement, we reimburse Phillips 66 for the provision of certain operational services in support of our operating assets. Additionally, we pay Phillips 66 for insurance services provided to us, and recoveries under these policies are recorded as an offset to our expenses. Operating and maintenance expenses also include volumetric gains and losses associated with volumes transported by Phillips 66.

Other related party balances were included in the following line items on our consolidated balance sheet, all of which were related to commercial agreements with Phillips 66:



	Millions of Dollars
	June 30 2019		December 31 2018

Prepaid expenses and other current assets	$	4	4
Other assets	44		—
Deferred revenues	16		60
Other current liabilities	1		—
Other liabilities	70		18

Equity Affiliate Guarantee

In June 2019, we issued a guarantee for 42.25% of the third-party term loan facility for Gray Oak. See Note 6—Equity Investments and Loans, for additional information.

Note 14—Subsequent Event

On July 24, 2019, we executed a definitive agreement to eliminate all of Phillips 66’s IDRs and its general partner economic interest in exchange for 101 million newly issued common units. Pursuant to the definitive agreement, the IDRs will be eliminated and the general partner economic interest will be converted into a non-economic general partner interest. After the transaction closes, Phillips 66 will own approximately 170 million PSXP common units, representing approximately 75% of our outstanding common units. As a result of the transaction, the General Partner’s negative equity balance of approximately $1.3 billion will transfer to Phillips 66’s limited partner equity account. The transaction is scheduled to close on August 1, 2019.

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Item 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Management’s Discussion and Analysis is the Partnership’s analysis of its financial performance, financial condition, and of significant trends that may affect future performance. It should be read in conjunction with the consolidated financial statements and notes thereto included elsewhere in this report. It contains forward-looking statements including, without limitation, statements relating to the Partnership’s plans, strategies, objectives, expectations and intentions. The words “anticipate,” “estimate,” “believe,” “budget,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “seek,” “should,” “will,” “would,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target” and similar expressions identify forward-looking statements. The Partnership does not undertake to update, revise or correct any of the forward-looking information unless required to do so under the federal securities laws. Readers are cautioned that such forward-looking statements should be read in conjunction with the Partnership’s disclosures under the heading: “CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS.”

BUSINESS ENVIRONMENT AND EXECUTIVE OVERVIEW

Partnership Overview

Our common units trade on the New York Stock Exchange under the symbol PSXP.

How We Evaluate Our Operations

Our management uses a variety of financial and operating metrics to analyze our performance, including: (1) volumes handled; (2) operating and maintenance expenses; (3) net income (loss) before net interest expense, income taxes, depreciation and amortization (EBITDA); (4) adjusted EBITDA; and (5) distributable cash flow.

Volumes Handled

The amount of revenue we generate primarily depends on the volumes of crude oil, refined petroleum products and NGL that we handle in our pipeline, terminal, rail rack, processing, storage and fractionator systems. In addition, our equity affiliates generate revenue from transporting and terminaling crude oil, refined petroleum products and NGL. These volumes are primarily affected by the supply of, and demand for, crude oil, refined petroleum products and NGL in the markets served directly or indirectly by our assets, as well as the operational status of the refineries served by our assets. Phillips 66 has committed to minimum throughput volumes under many of our commercial agreements.

Operating and Maintenance Expenses

Our management seeks to maximize the profitability of our operations by effectively managing operating and maintenance expenses. These expenses primarily consist of labor expenses (including contractor services), utility costs, and repair and maintenance expenses. Operating and maintenance expenses generally remain relatively stable across broad ranges of throughput volumes but can fluctuate from period to period depending on the mix of activities,

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particularly maintenance activities, performed during the period. Although we seek to manage our maintenance expenditures on our facilities to avoid significant variability in our quarterly cash flows, we balance this approach with our high standards of safety and environmental stewardship, such that critical maintenance is regularly performed.

Our operating and maintenance expenses are also affected by volumetric gains/losses resulting from variances in meter readings and other measurement methods, as well as volume fluctuations due to pressure and temperature changes. Under certain commercial agreements with Phillips 66, the value of any crude oil, refined petroleum product and NGL volumetric gains and losses are determined by reference to the monthly average reference price for the applicable commodity. Any gains/losses under these provisions decrease or increase, respectively, our operating and maintenance expenses in the period in which they are realized. These contractual volumetric gain/loss provisions could increase variability in our operating and maintenance expenses.

EBITDA, Adjusted EBITDA and Distributable Cash Flow

We define EBITDA as net income (loss) plus net interest expense, income taxes, depreciation and amortization.

Adjusted EBITDA is EBITDA, further adjusted for:


•	The proportional share of equity affiliates’ net interest expense, income taxes and depreciation and amortization.


•	Transaction costs associated with acquisitions.


•	Certain other noncash items, including expenses indemnified by Phillips 66.

Distributable cash flow is defined as adjusted EBITDA less (i) equity affiliate distributions less than proportional EBITDA, (ii) maintenance capital expenditures, (iii) net interest expense, (iv) income taxes paid and (v) preferred unit distributions; plus adjustments for deferred revenue impacts.

EBITDA, adjusted EBITDA, and distributable cash flow are not presentations made in accordance with generally accepted accounting principles in the United States (GAAP). EBITDA, adjusted EBITDA and distributable cash flow are non-GAAP supplemental financial measures that management believes external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies, may find useful to assess:


•	Our operating performance as compared to other publicly traded partnerships in the midstream energy industry, without regard to historical cost basis or, in the case of EBITDA and adjusted EBITDA, financing methods.


•	The ability of our business to generate sufficient cash to support our decision to make distributions to our unitholders.


•	Our ability to incur and service debt and fund capital expenditures.


•	The viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.

The GAAP performance measure most directly comparable to EBITDA and adjusted EBITDA is net income. The GAAP liquidity measure most directly comparable to EBITDA and distributable 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. They have important limitations as analytical tools because they exclude some items that affect net income and net cash provided by operating activities. Additionally, because EBITDA, adjusted EBITDA, and distributable cash flow may be defined differently by other companies in our industry, our definition of these non-GAAP financial measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.

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Business Environment

Since we do not own any of the crude oil, refined petroleum products and NGL we handle and do not engage in the trading of crude oil, refined petroleum products and NGL, we have limited direct exposure to risks associated with fluctuating commodity prices, although these risks indirectly influence our activities and results of operations over the long term.

Our throughput volumes primarily depend on the volume of crude oil processed and refined petroleum products produced at Phillips 66’s owned or operated refineries with which our assets are integrated. These volumes are primarily dependent on Phillips 66’s refining margins and maintenance schedules. Refining margins depend on the price of crude oil or other feedstocks and the price of refined petroleum products. These prices are affected by numerous factors beyond our or Phillips 66’s control, including the domestic and global supply of and demand for crude oil and refined petroleum products. Throughput volumes of our equity affiliates primarily depend on upstream drilling activities, refinery performance and product supply and demand.

While we believe we have substantially mitigated our indirect exposure to commodity price fluctuations through the minimum volume commitments in our commercial agreements with Phillips 66 during the respective terms of those agreements, our ability to execute our growth strategy will depend, in part, on the availability of attractively priced crude oil in the areas served by our crude oil pipelines and rail racks, demand for refined petroleum products in the markets served by our refined petroleum product pipelines and terminals, and the general demand for midstream services, including NGL transportation and fractionation.

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RESULTS OF OPERATIONS

Unless otherwise indicated, discussion of results for the three and six months ended June 30, 2019, is based on a comparison with the corresponding period of 2018.



	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018
Revenues and Other Income
Operating revenues—related parties	$	256	244	552	493
Operating revenues—third parties	7		10	13	17
Equity in earnings of affiliates	137		100	256	198
Other income	1		—	3	1
Total revenues and other income	401		354	824	709

Costs and Expenses
Operating and maintenance expenses	85		85	224	182
Depreciation	29		29	58	57
General and administrative expenses	17		16	35	32
Taxes other than income taxes	9		9	20	19
Interest and debt expense	27		29	54	59
Total costs and expenses	167		168	391	349
Income before income taxes	234		186	433	360
Income tax expense	1		—	2	2
Net income	233		186	431	358
Less: Preferred unitholders’ interest in net income	9		10	19	19
Less: General partner’s interest in net income	71		55	140	108
Limited partners’ interest in net income	$	153	121	272	231

Net cash provided by operating activities	$	276	226	481	397

Adjusted EBITDA	$	319	276	600	523

Distributable cash flow	$	254	204	480	398

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	Three Months Ended June 30			Six Months Ended June 30
	2019		2018	2019	2018
Wholly Owned Operating Data
Pipelines
Pipeline revenues (millions of dollars)	$	117	111	226	213
Pipeline volumes⁽¹⁾ (thousands of barrels daily)
Crude oil	1,000		1,020	980	984
Refined petroleum products and NGL	995		920	882	859
Total	1,995		1,940	1,862	1,843

Average pipeline revenue per barrel (dollars)	$	0.64	0.63	0.67	0.64

Terminals
Terminal revenues (millions of dollars)	$	39	38	79	77
Terminal throughput (thousands of barrels daily)
Crude oil⁽²⁾	456		471	463	477
Refined petroleum products	809		806	773	763
Total	1,265		1,277	1,236	1,240

Average terminaling revenue per barrel (dollars)	$	0.33	0.33	0.34	0.34

Storage, processing and other revenues (millions of dollars)	$	107	105	260	220
Total operating revenues (millions of dollars)	$	263	254	565	510

Joint Venture Operating Data⁽³⁾
Crude oil, refined petroleum products and NGL (thousands of barrels daily)	772		638	730	621

⁽¹⁾Represents the sum of volumes transported through each separately tariffed pipeline segment.

⁽²⁾Bayway and Ferndale rail rack volumes included in crude oil terminals.

⁽³⁾ Proportional share of total pipeline and terminal volumes of joint ventures consistent with recognized equity in earnings of affiliates.

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The following tables present reconciliations of EBITDA and adjusted EBITDA to net income, and EBITDA and distributable cash flow to net cash provided by operating activities, the most directly comparable GAAP financial measures, for each of the periods indicated.



	Millions of Dollars
	Three Months Ended June 30					Six Months Ended June 30
	2019			2018		2019		2018
Reconciliation to Net Income
Net income	$	233		186		431		358
Plus:
Depreciation	29			29		58		57
Net interest expense	26			29		53		58
Income tax expense	1			—		2		2
EBITDA	289			244		544		475
Plus:
Proportional share of equity affiliates’ net interest, taxes and depreciation and amortization	29			28		55		43
Expenses indemnified or prefunded by Phillips 66	1			1		1		1
Transaction costs associated with acquisitions	—			3		—		4
Adjusted EBITDA	319			276		600		523
Plus:
Deferred revenue impacts*^†	(4		)	(5	)	(4	)	—
Less:
Equity affiliate distributions less than proportional EBITDA	13			18		22		28
Maintenance capital expenditures^†	12			10		21		20
Net interest expense	26			29		53		58
Preferred unit distributions	9			10		19		19
Income taxes paid	1			—		1		—
Distributable cash flow	$	254		204		480		398

*Difference between cash receipts and revenue recognition.

†Excludes Merey Sweeny capital reimbursements and turnaround impacts.

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	Millions of Dollars
	Three Months Ended June 30					Six Months Ended June 30
	2019			2018		2019		2018
Reconciliation to Net Cash Provided by Operating Activities
Net cash provided by operating activities	$	276		226		481		397
Plus:
Net interest expense	26			29		53		58
Income tax expense	1			—		2		2
Changes in working capital	(11		)	(10	)	23		(27	)
Undistributed equity earnings	(1		)	(1	)	(3	)	7
Deferred revenues and other liabilities	1			5		(8	)	43
Other	(3		)	(5	)	(4	)	(5	)
EBITDA	289			244		544		475
Plus:
Proportional share of equity affiliates’ net interest, taxes and depreciation and amortization	29			28		55		43
Expenses indemnified or prefunded by Phillips 66	1			1		1		1
Transaction costs associated with acquisitions	—			3		—		4
Adjusted EBITDA	319			276		600		523
Plus:
Deferred revenue impacts*^†	(4		)	(5	)	(4	)	—
Less:
Equity affiliate distributions less than proportional EBITDA	13			18		22		28
Maintenance capital expenditures^†	12			10		21		20
Net interest expense	26			29		53		58
Preferred unit distributions	9			10		19		19
Income taxes paid	1			—		1		—
Distributable cash flow	$	254		204		480		398

*Difference between cash receipts and revenue recognition.

^†Excludes Merey Sweeny capital reimbursements and turnaround impacts.

Statement of Income Analysis

Operating revenues increased $55 million, or 11%, in the six-month period of 2019. The increase was attributable to recognition of previously deferred revenues associated with fees charged to Phillips 66 related to turnaround activity at Merey Sweeny LLC (Merey Sweeny) in the first quarter of 2019, and higher volumes on wholly owned assets.

Equity in earnings of affiliates increased $37 million, or 37%, and increased $58 million, or 29%, in the second quarter and six-month period of 2019, respectively. The increases in both periods were attributable to higher earnings from Dakota Access, LLC (Dakota Access) and Energy Transfer Crude Oil Company, LLC (ETCO), together referred to as the Bakken Pipeline, DCP Sand Hills Pipeline, LLC (Sand Hills), and Bayou Bridge Pipeline, LLC (Bayou Bridge), primarily due to higher volumes. In addition, the increase in the six-month period of 2019 was partially offset by a decrease in earnings from Explorer Pipeline Company due to a one-time benefit from U.S. tax reform in the first quarter of 2018.

Operating and maintenance expenses increased by $42 million, or 23%, in the six-month period of 2019. The increase was primarily due to turnaround activity at Merey Sweeny.

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CAPITAL RESOURCES AND LIQUIDITY

Significant Sources of Capital

Our sources of liquidity include cash generated from operations, borrowings from related parties and under our revolving credit facility, and issuances of additional debt and equity securities. We believe that cash generated from these sources will be sufficient to meet our short-term working capital requirements, long-term capital expenditure requirements and our quarterly cash distributions.

Operating Activities

We generated $481 million in cash from operations during the first six months of 2019, an improvement over cash from operations of $397 million for the corresponding period of 2018. The improvement was primarily driven by higher distributions from equity affiliates.

ATM Programs

Revolving Credit Facility

As of June 30, 2019, no amount had been directly drawn under our $750 million revolving credit facility; however, $1 million in letters of credit had been issued that were supported by this facility.

Term Loan Facility

Transfers of Equity Interests

In December 2018, a third party exercised an option to acquire a 35% interest in Gray Oak Holdings LLC (Holdings LLC), a consolidated subsidiary. This transfer did not qualify as a sale under GAAP because of certain restrictions placed on the acquirer. The contributions received by Holdings LLC from the third party to cover capital calls from Gray Oak Pipeline, LLC (Gray Oak) are presented as a long-term obligation on our consolidated balance sheet and financing cash inflows on our consolidated statement of cash flows until construction of the Gray Oak Pipeline is completed and the restrictions expire. During the first three months of 2019, the third party contributed an aggregate of $341 million into Holdings LLC, which Holdings LLC used to fund its portion of Gray Oak’s cash calls.

In February 2019, Holdings LLC sold a 10% ownership interest in Gray Oak to a third party that exercised a purchase option, for proceeds of $81 million. The proceeds received from this sale are presented as an investing cash inflow on our consolidated statement of cash flows.

See Note 6—Equity Investments and Loans, in the Notes to Consolidated Financial Statements, for additional information regarding these transactions.

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Shelf Registration

We have a universal shelf registration statement on file with the U.S. Securities and Exchange Commission (SEC) under which we, as a well-known seasoned issuer, have the ability to issue and sell an indeterminate amount of common units representing limited partner interests, preferred units representing limited partner interests, and debt securities.

Off-Balance Sheet Arrangements

In March 2019, a wholly owned subsidiary of Dakota Access closed on an offering of $2,500 million aggregate principal amount of unsecured senior notes. The net proceeds from the issuance of these notes were used to repay amounts outstanding under existing credit facilities of Dakota Access and ETCO. Dakota Access and ETCO have guaranteed repayment of the notes. In addition, we and our co-venturers provided a Contingent Equity Contribution Undertaking (CECU) in conjunction with the notes offering. Under the CECU, if Dakota Access receives an unfavorable court ruling related to certain disputed construction permits and Dakota Access determines that an equity contribution trigger event has occurred, the venturers may be severally required to make proportionate equity contributions to Dakota Access and ETCO up to an aggregate maximum of approximately $2,525 million. Our share of the maximum potential equity contributions under the CECU is approximately $631 million.

Capital Requirements

Capital Expenditures and Investments

Our operations are capital intensive and require investments to expand, upgrade, maintain or enhance existing operations and to meet environmental and operational requirements of our wholly owned and joint venture entities. Our capital requirements consist of maintenance and expansion capital expenditures, as well as contributions to our joint ventures. Expansion capital expenditures are those made to expand and upgrade our systems and facilities and to construct or acquire new systems or facilities to grow our business, including contributions to joint ventures that are using the contributed funds for such purposes. In contrast, 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 to maintain existing system volumes and related cash flows.

Our capital expenditures and investments represent the total spending for our capital requirements. Our adjusted capital spending is a non-GAAP financial measure that demonstrates our net share of capital spending, and reflects an adjustment for the portion of consolidated capital spending funded by certain of our Gray Oak joint venture partners from our sale or transfer of equity interests to them. Additionally, the disaggregation of adjusted capital spending between expansion and maintenance is not a distinction recognized under GAAP. We disaggregate adjusted capital spending because our partnership agreement requires that we treat expansion and maintenance capital differently for certain surplus determinations. Further, we generally fund expansion capital spending with both operating and financing cash flows and fund maintenance capital spending with operating cash flows.

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Our capital expenditures and investments were:



	Millions of Dollars
	Six Months Ended June 30
	2019			2018
Capital expenditures and investments
Capital expenditures and investments	$	746		248
Capital expenditures and investments funded by Gray Oak joint venture partners*	(422		)	—
Adjusted capital spending	$	324		248

Expansion	$	297		226
Maintenance	27			22

*See Note 6—Equity Investments and Loans, in the Notes to Consolidated Financial Statements, for additional information.

Our capital expenditures and investments for the first six months of 2019 were primarily associated with the following activities:


•	Contributions to Gray Oak to progress construction of the pipeline, which will provide crude oil transportation from the Permian Basin and Eagle Ford to Texas Gulf Coast destinations that include Corpus Christi, the Sweeny area, including the Phillips 66 Sweeny Refinery, as well as access to the Houston market.


•	Construction activities related to a new isomerization unit at the Phillips 66 Lake Charles Refinery.


•	Construction activities related to increasing storage capacity at Clemens Caverns.


•	Contributions to Bayou Bridge to complete the pipeline segment from Lake Charles to St. James, Louisiana.


•	Contributions to South Texas Gateway Terminal for construction activities related to the marine export terminal that will connect to the Gray Oak Pipeline in Corpus Christi, Texas.


•	Construction activities related to the Lake Charles products pipeline that connects storage in Lake Charles to its Clifton Ridge Marine Terminal.


•	Construction activities related to a new ethane pipeline from the Clemens Caverns to petrochemical facilities in Gregory, Texas, near Corpus Christi.


•	Spending associated with other return, reliability and maintenance projects.

Cash Distributions

On July 17, 2019, the Board of Directors of our General Partner declared a quarterly cash distribution of $0.855 per common unit which, combined with distributions to our General Partner, and excluding distributions to holders of our preferred units, resulted in a total distribution of $177 million attributable to the second quarter of 2019. This distribution is payable on August 13, 2019, to unitholders of record as of July 31, 2019.

Cash distributions are made to our General Partner in respect of its general partner interest and its ownership of all incentive distribution rights (IDRs), which entitle our General Partner to receive increasing percentages, up to 50%, of quarterly cash distributions in excess of $0.244375 per unit. Accordingly, based on the per-unit distribution declared on July 17, 2019, our General Partner will receive 40% of the second-quarter 2019 cash distribution, excluding preferred unit distributions, in respect of its general partner interest and its ownership of all IDRs.

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The holders of our preferred units are entitled to receive cumulative quarterly distributions equal to $0.678375 per preferred unit. Preferred unitholders will receive $9 million of distributions attributable to the second quarter of 2019. This distribution is payable on August 13, 2019, to preferred unitholders of record as of July 31, 2019.

Incentive Distribution Rights Elimination

Contingencies

Regulatory Matters

Our interstate common carrier crude oil and refined petroleum products pipeline operations are subject to rate regulation by the Federal Energy Regulatory Commission under the Interstate Commerce Act and Energy Policy Act of 1992, and certain of our pipeline systems providing intrastate service are subject to rate regulation by applicable state authorities under their respective laws and regulations. Our pipeline, rail rack and terminal operations are also subject to safety regulations adopted by the Department of Transportation, as well as to state regulations.

Legal and Tax Matters

Under our amended omnibus agreement, Phillips 66 provides certain services for our benefit, including legal and tax support services, and we pay an operational and administrative support fee for these services. Phillips 66’s legal and tax organizations apply their knowledge, experience and professional judgment to the specific characteristics of our cases and uncertain tax positions. Phillips 66’s legal organization employs a litigation management process to manage and monitor the legal proceedings against us. The process facilitates the early evaluation and quantification of potential exposures in individual cases and enables tracking of those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, Phillips 66’s legal organization regularly assesses the adequacy of current accruals and recommends if adjustment of existing accruals, or establishment of new accruals, is required. As of June 30, 2019, and December 31, 2018, we did not have any material accrued contingent liabilities associated with litigation matters.

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Environmental

We are subject to extensive federal, state and local environmental laws and regulations. These requirements, which frequently change, regulate the discharge of materials into the environment or otherwise relate to protection of the environment. Compliance with these laws and regulations may require us to remediate environmental damage from any discharge of petroleum or chemical substances from our facilities or require us to install additional pollution control equipment at or on our facilities. Our failure to comply with these or any other environmental or safety-related regulations could result in the assessment of administrative, civil, or criminal penalties, the imposition of investigatory and remedial liabilities, and the issuance of governmental orders that may subject us to additional operational constraints. Future expenditures may be required to comply with the Federal Clean Air Act and other federal, state and local requirements in respect of our various sites, including our pipelines and storage assets. The impact of legislative and regulatory developments, if enacted or adopted, could result in increased compliance costs and additional operating restrictions on our business, each of which could have an adverse impact on our financial position, results of operations and liquidity.

As with all costs, if these expenditures are not ultimately recovered in the tariffs and other fees we receive for our services, our operating results will be adversely affected. We believe that substantially all similarly situated parties and holders of comparable assets must comply with similar environmental laws and regulations. However, the specific impact on each may vary depending on a number of factors, including, but not limited to, the age and location of its operating facilities.

We accrue for environmental remediation activities when the responsibility to remediate is probable and the amount of associated costs can be reasonably estimated. As environmental remediation matters proceed toward ultimate resolution or as additional remediation obligations arise, charges in excess of those previously accrued may be required. New or expanded environmental requirements, which could increase our environmental costs, may arise in the future. We believe we are in substantial compliance with all legal obligations regarding the environment and have established the environmental accruals that are currently required; however, it is not possible to predict all of the ultimate costs of compliance, including remediation costs that may be incurred and penalties that may be imposed, because not all of the costs are fixed or presently determinable (even under existing legislation) and the costs may be affected by future legislation or regulations.

Indemnification and Excluded Liabilities

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

This report includes forward-looking statements. You can identify our forward-looking statements by the words “anticipate,” “estimate,” “believe,” “budget,” “continue,” “could,” “intend,” “may,” “plan,” “potential,” “predict,” “seek,” “should,” “will,” “would,” “expect,” “objective,” “projection,” “forecast,” “goal,” “guidance,” “outlook,” “effort,” “target” and similar expressions.

We based the forward-looking statements on our current expectations, estimates and projections about us and the industries in which we operate in general. We caution you these statements are not guarantees of future performance as they involve assumptions that, while made in good faith, may prove to be incorrect, and involve risks and uncertainties we cannot predict. In addition, we based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecast in the forward-looking statements. Any differences could result from a variety of factors, including the following:


•	The continued ability of Phillips 66 to satisfy its obligations under our commercial and other agreements.


•	Reductions in the volume of crude oil, refined petroleum products and NGL we transport, fractionate, process, terminal and store.


•	Changes to the tariff rates with respect to volumes that we transport through our regulated assets, which rates are subject to review and possible adjustment by federal and state regulators.


•	Changes in revenue we realize under the loss allowance provisions of our regulated tariffs resulting from changes in underlying commodity prices.


•	Fluctuations in the prices and demand for crude oil, refined petroleum products and NGL.


•	Changes in global economic conditions and the effects of a global economic downturn on the business of Phillips 66 and the business of its suppliers, customers, business partners and credit lenders.


•	Potential liabilities associated with the risks and operational hazards inherent in transporting, fractionating, processing, terminaling and storing crude oil, refined petroleum products and NGL.


•	Curtailment of operations due to severe weather disruption or natural disasters; riots, strikes, lockouts or other industrial disturbances; or failure of information technology systems due to various causes, including unauthorized access or attack.


•	Accidents or other unscheduled shutdowns affecting our pipelines, processing, fractionating, terminaling, and storage facilities or equipment, or those of our suppliers or customers.


•	Our inability to obtain or maintain permits in a timely manner, if at all, including those necessary for capital projects, or the revocation or modification of existing permits.


•	Our inability to comply with government regulations or make capital expenditures required to maintain compliance.


•	The failure to complete construction of announced and future capital projects in a timely manner and any cost overruns associated with such projects.


•	Our ability to successfully execute growth strategies, whether through organic growth or acquisitions.


•	The operation, financing and distribution decisions of our joint ventures.


•	Costs or liabilities associated with federal, state, and local laws and regulations relating to environmental protection and safety, including spills, releases and pipeline integrity.


•	Costs associated with compliance with evolving environmental laws and regulations on climate change.


•	Costs associated with compliance with safety regulations, including pipeline integrity management program testing and related repairs.


•	Changes in the cost or availability of third-party vessels, pipelines, railcars and other means of delivering and transporting crude oil, refined petroleum products and NGL.


•	Direct or indirect effects on our business resulting from actual or threatened terrorist incidents or acts of war.


•	Our ability to comply with the terms of our credit facility, indebtedness and other financing arrangements, which, if accelerated, we may not be able to repay.


•	Our ability to incur additional indebtedness or our ability to obtain financing on terms that we deem acceptable, including the refinancing of our current obligations; higher interest rates and costs of financing would increase our expenses.


•	Changes in tax, environmental and other laws and regulations.


•	The factors generally described in “Item 1A. Risk Factors” in our 2018 Annual Report on Form 10-K filed with the SEC on February 22, 2019.

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Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Our commodity price risk and interest rate risk at June 30, 2019, did not differ materially from that disclosed under Item 7A of our 2018 Annual Report on Form 10-K.

Item 4. CONTROLS AND PROCEDURES

We maintain disclosure controls and procedures designed to ensure that information required to be disclosed in reports we file or submit under the Securities Exchange Act of 1934, as amended (the Act), is recorded, processed, summarized and reported within the time periods specified in U.S. Securities and Exchange Commission rules and forms, and that such information is accumulated and communicated to our General Partner’s management, including its principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure. As of June 30, 2019, our General Partner’s Chairman and Chief Executive Officer and its Vice President and Chief Financial Officer, with the participation of the General Partner’s management, carried out an evaluation, pursuant to Rule 13a-15(b) of the Act, of the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) of the Act). Based upon that evaluation, our General Partner’s Chairman and Chief Executive Officer and its Vice President and Chief Financial Officer concluded that our disclosure controls and procedures were operating effectively as of June 30, 2019.

There have been no changes in our internal control over financial reporting, as defined in Rule 13a-15(f) of the Act, in the quarterly period ended June 30, 2019, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. OTHER INFORMATION

Item 1. LEGAL PROCEEDINGS

Under our amended omnibus agreement, and pursuant to the terms of various agreements under which we acquired assets from Phillips 66, Phillips 66 indemnifies us or assumes responsibility for certain liabilities relating to litigation and environmental matters attributable to the ownership or operation of our assets prior to their contribution to us from Phillips 66. See Note 11—Contingencies, in the Notes to Consolidated Financial Statements, for additional information.

This section identifies reportable legal proceedings attributable to the ownership or operation of our assets, including those involving governmental authorities under federal, state and local laws regulating the discharge of materials into the environment, for this reporting period. There are no new matters to report.

Item 1A. RISK FACTORS

There were no material changes from the risk factors disclosed in Item 1A of our 2018 Annual Report on Form 10-K.

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Item 6. EXHIBITS




Exhibit Number		Exhibit Description

31.1*		Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.

31.2*		Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.

32*		Certifications pursuant to 18 U.S.C. Section 1350.

101.INS*		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.

101.SCH*		XBRL Taxonomy Extension Schema Document.

101.CAL*		XBRL Taxonomy Extension Calculation Linkbase Document.

101.DEF*		XBRL Taxonomy Extension Definition Linkbase Document.

101.LAB*		XBRL Taxonomy Extension Labels Linkbase Document.

101.PRE*		XBRL Taxonomy Extension Presentation Linkbase Document.

* Filed herewith

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SIGNATURES

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.



	PHILLIPS 66 PARTNERS LP

	By: Phillips 66 Partners GP LLC, its general partner

	/s/ Chukwuemeka A. Oyolu
	Chukwuemeka A. Oyolu Vice President and Controller (Chief Accounting and Duly Authorized Officer)

Date: July 26, 2019