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 ~~September 30, 2019~~March 31, 2020



☐	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: 1-32225

_____________________________________________________________________________________

HOLLY ENERGY PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

______________________________________________________________________________________



Delaware		20-0833098
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
2828 N. Harwood, Suite 1300
Dallas
Texas		75201
(Address of principal executive offices)		(Zip code)

(214) 871-3555

(Registrant’s telephone number, including area code)

(Former name, former address and former fiscal year, if changed since last report)



Securities registered pursuant to 12(b) of the Securities Exchange Act of 1934:
Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Limited Partner Units	HEP	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. 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 (§232.405 of this chapter) 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, 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 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 by Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

The number of the registrant’s outstanding common units at ~~October 25, 2019,~~May 1, 2020, was 105,440,201.

Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

INDEX

Table of Contentsril 19,

FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q contains certain “forward-looking statements” within the meaning of the federal securities laws. All statements, other than statements of historical fact included in this Form 10-Q, including, but not limited to, ~~those~~statements regarding funding of capital expenditures and distributions, distributable cash flow coverage and leverage targets, and statements under “Results of Operations” and “Liquidity and Capital Resources” in Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part I are forward-looking statements. Forward-looking statements use words such as “anticipate,” “project,” “expect,” “plan,” “goal,” “forecast,” “intend,” “should,” “would,” “could,” “believe,” “may,” and similar expressions and statements regarding our plans and objectives for future operations. These statements are based on our beliefs and assumptions and those of our general partner using currently available information and expectations as of the date hereof, are not guarantees of future performance and involve certain risks and uncertainties. Although we and our general partner believe that such expectations reflected in such forward-looking statements are reasonable, neither we nor our general partner can give assurance that our expectations will prove to be correct. All statements concerning our expectations for future results of operations are based on forecasts for our existing operations and do not include the potential impact of any future acquisitions. Our forward-looking statements are subject to a variety of risks, uncertainties and assumptions. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, our actual results may vary materially from those anticipated, estimated, projected or expected. Certain factors could cause actual results to differ materially from results anticipated in the forward-looking statements. These factors include, but are not limited to:

the extraordinary market environment and effects of the COVID-19 pandemic, including the continuation of a material decline in demand for refined petroleum products in markets we serve;

risks and uncertainties with respect to the actual quantities of petroleum products and crude oil shipped on our pipelines and/or terminalled, stored or throughput in our terminals and refinery processing units;

the economic viability of HollyFrontier Corporation (“HFC”), ~~Delek US Holdings, Inc. (“Delek”)~~our other customers and our joint ventures’ other ~~customers;~~

~~the demand for refined petroleum products in markets we serve;~~customers, including any refusal or inability of our or our joint ventures’ customers or counterparties to perform their obligations under their contracts;

our ability to purchase and integrate future acquired operations;

our ability to complete previously announced or contemplated acquisitions;

the availability and cost of additional debt and equity financing;

the possibility of reductions in production or shutdowns at refineries utilizing our pipelines, terminal facilities and refinery processing ~~units;~~units, whether due to infection in the workforce or in response to reductions in demand;

the effects of current and future government regulations and ~~policies;~~policies, including the effects of current restrictions on various commercial and economic activities in response to the COVID-19 pandemic;

our and our joint venture partners’ ability to complete and maintain operational efficiency in carrying out routine operations and capital construction projects;

the possibility of terrorist or cyber attacks and the consequences of any such attacks;

general economic ~~conditions;~~conditions, including uncertainty regarding the timing, pace and extent of an economic recovery in the United States;

the impact of recent or proposed changes in the tax laws and regulations that affect master limited partnerships; and

other financial, operational and legal risks and uncertainties detailed from time to time in our Securities and Exchange Commission filings.

Cautionary statements identifying important factors that could cause actual results to differ materially from our expectations are set forth in this Form 10-Q, including, without limitation, the forward-looking statements that are referred to above. You should not put any undue reliance on any forward-looking statements. When considering forward-looking statements, you should keep in mind the known material risk factors and other cautionary statements set forth in our Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019, and in this Quarterly Report on Form 10-Q in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and in “Risk Factors.” All forward-looking statements included in this Form 10-Q and all subsequent written or oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by these cautionary statements. The forward-looking statements speak only as of the date made and, other than as required by law, we undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.

Table of Contentsril 19,

PART I. FINANCIAL INFORMATION


Item 1.	Financial Statements

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED BALANCE SHEETS

(In thousands, except unit data)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
	(Unaudited)				(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	7,469	$	3,045
Cash and cash equivalents (Cushing Connect VIEs: $16,675 and $6,842, respectively)					$	19,282	$	13,287
Accounts receivable:
Trade	16,182		12,332		15,638		18,731
Affiliates	35,770		46,786		38,406		49,716
	51,952		59,118		54,044		68,447
Prepaid and other current assets	4,779		4,311		7,548		7,629
Total current assets	64,200		66,474		80,874		89,363

Properties and equipment, net	1,478,950		1,538,655
Properties and equipment, net (Cushing Connect VIEs: $15,087 and $2,916, respectively)					1,465,789		1,467,099
Operating lease right-of-use assets, net	3,454		—		3,587		3,255
Net investment in leases	136,394		16,488		134,108		134,886
Intangible assets, net	104,824		115,329		97,820		101,322
Goodwill	270,336		270,336		270,336		270,336
Equity method investments	82,884		83,840
Equity method investments (Cushing Connect VIEs: $39,054 and $37,084, respectively)					123,580		120,071
Other assets	13,233		11,418		12,190		12,900
Total assets	$	2,154,275	$	2,102,540	$	2,188,284	$	2,199,232

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable:
Trade	$	12,608	$	16,435
Trade (Cushing Connect VIEs: $11,417 and $2,082, respectively)					$	19,549	$	17,818
Affiliates	6,747		14,222		6,393		16,737
	19,355		30,657		25,942		34,555

Accrued interest	5,884		13,302		4,695		13,206
Deferred revenue	9,774		8,697		10,810		10,390
Accrued property taxes	9,266		1,779		5,707		3,799
Current operating lease liabilities	807		—		1,235		1,126
Current finance lease liabilities	5,426		936		3,238		3,224
Other current liabilities	2,926		2,526		3,065		2,305
Total current liabilities	53,438		57,897		54,692		68,605

Long-term debt	1,431,869		1,418,900		1,502,154		1,462,031
Noncurrent operating lease liabilities	2,995		—		2,709		2,482
Noncurrent finance lease liabilities	69,168		867		70,640		70,475
Other long-term liabilities	12,902		14,440		12,450		12,808
Deferred revenue	46,862		48,714		45,078		45,681

Class B unit	48,557		46,161		50,227		49,392

Equity:
Partners’ equity:
Common unitholders (105,440,201 units issued and outstanding at September 30, 2019 and December 31, 2018)	404,584		427,435
Common unitholders (105,440,201 units issued and outstanding at March 31, 2020 and December 31, 2019)					338,159		381,103
Noncontrolling interest	83,900		88,126		112,175		106,655
Total equity	488,484		515,561		450,334		487,758
Total liabilities and equity	$	2,154,275	$	2,102,540	$	2,188,284	$	2,199,232

See accompanying notes.

Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

(In thousands, except per unit data)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Revenues:
Affiliates	$	106,027		$	100,188		$	311,755		$	295,629		$	101,428		$	103,359
Third parties	29,868			25,596			89,388			77,799			26,426			31,138
	135,895			125,784			401,143			373,428			127,854			134,497
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	44,924			35,996			123,045			106,731			34,981			37,519
Depreciation and amortization	24,121			24,367			72,192			74,117			23,978			23,824
General and administrative	2,714			2,498			7,322			8,293			2,702			2,620
	71,759			62,861			202,559			189,141			61,661			63,963
Operating income	64,136			62,923			198,584			184,287			66,193			70,534

Other income (expense):
Equity in earnings of equity method investments	1,334			1,114			5,217			4,127			1,714			2,100
Interest expense	(18,807		)	(18,042		)	(57,059		)	(53,249		)	(17,767		)	(19,022		)
Interest income	2,243			540			3,322			1,581			2,218			528
Gain on sales-type leases	35,166			—			35,166			—
Loss on early extinguishment of debt													(25,915		)	—
Gain (loss) on sale of assets and other	142			38			(57		)	71			506			(310		)
	20,078			(16,350		)	(13,411		)	(47,470		)	(39,244		)	(16,704		)
Income before income taxes	84,214			46,573			185,173			136,817			26,949			53,830
State income tax expense	(30		)	(39		)	(36		)	(149		)	(37		)	(36		)
Net income	84,184			46,534			185,137			136,668			26,912			53,794
Allocation of net income attributable to noncontrolling interests	(1,839		)	(1,531		)	(5,920		)	(5,354		)	(2,051		)	(2,612		)
Net income attributable to the partners	82,345			45,003			179,217			131,314			24,861			51,182
Limited partners’ per unit interest in earnings—basic and diluted	$	0.78		$	0.43		$	1.70		$	1.25		$	0.24		$	0.49
Weighted average limited partners’ units outstanding	105,440			105,440			105,440			104,908			105,440			105,440

See accompanying notes.

Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash flows from operating activities
Net income	$	185,137		$	136,668		$	26,912		$	53,794
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	72,192			74,117			23,978			23,824
Gain on sale of assets	(19		)	(196		)	(417		)	(9		)
Gain on sales-type leases	(35,166		)	—
Loss on early extinguishment of debt							25,915			—
Amortization of deferred charges	2,307			2,278			799			766
Equity-based compensation expense	1,774			2,259			506			406
Equity in earnings of equity method investments, net of distributions	263			—			(1,164		)	(112		)
(Increase) decrease in operating assets:
Accounts receivable—trade	(3,850		)	2,502			3,093			(2,253		)
Accounts receivable—affiliates	11,016			4,392			11,310			10,748
Prepaid and other current assets	1,694			(402		)	126			244
Increase (decrease) in operating liabilities:
Accounts payable—trade	2,622			(1,209		)	(10,344		)	(2,199		)
Accounts payable—affiliates	(7,475		)	(1,311		)	2,921			(7,002		)
Accrued interest	(7,418		)	(7,526		)	(8,511		)	(7,616		)
Deferred revenue	413			5,218			(184		)	(233		)
Accrued property taxes	7,487			2,746			1,908			3,757
Other current liabilities	400			(1,955		)	760			130
Other, net	(3,160		)	(169		)	339			(3,090		)
Net cash provided by operating activities	228,217			217,412			77,947			71,155

Cash flows from investing activities
Additions to properties and equipment	(23,828		)	(34,270		)	(18,942		)	(10,718		)
Business and asset acquisitions	—			(6,841		)
Investment in Cushing Connect							(2,345		)	—
Proceeds from sale of assets	265			210			417			9
Distributions in excess of equity in earnings of equity investments	693			1,368			—			395
Net cash used for investing activities	(22,870		)	(39,533		)	(20,870		)	(10,314		)

Cash flows from financing activities
Borrowings under credit agreement	269,500			256,000			112,000			104,000
Repayments of credit agreement borrowings	(257,000		)	(347,000		)	(67,000		)	(85,000		)
Proceeds from issuance of common units	—			114,887
Redemption of senior notes							(522,500		)	—
Proceeds from issuance of debt							500,000			—
Contributions from general partner							354			—
Contributions from noncontrolling interest							7,304			—
Distributions to HEP unitholders	(204,701		)	(197,300		)	(68,519		)	(67,975		)
Distributions to noncontrolling interest	(7,750		)	(5,500		)	(3,000		)	(3,000		)
Payments on finance leases	(780		)	(929		)	(1,096		)	(252		)
Contributions from general partner	182			614
Purchase of units for incentive grants	(255		)	—
Deferred financing costs							(8,478		)	—
Units withheld for tax withholding obligations	(119		)	(58		)	(147		)	(119		)
Other	—			6
Net cash used by financing activities	(200,923		)	(179,280		)	(51,082		)	(52,346		)

Cash and cash equivalents
Increase for the period	4,424			(1,401		)	5,995			8,495
Beginning of period	3,045			7,776			13,287			3,045
End of period	$	7,469		$	6,375		$	19,282		$	11,540

See accompanying notes.

Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF EQUITY

(Unaudited)

(In thousands)


	Common Units			Noncontrolling Interest			Total Equity			Common Units			Noncontrolling Interest			Total Equity

Balance December 31, 2018	$	427,435		$	88,126		$	515,561
Balance December 31, 2019										$	381,103		$	106,655		$	487,758
Capital contribution-Cushing Connect										—			7,304			7,304
Distributions to HEP unitholders	(67,975		)	—			(67,975		)	(68,519		)	—			(68,519		)
Distributions to noncontrolling interest	—			(3,000		)	(3,000		)	—			(3,000		)	(3,000		)
Amortization of restricted and performance units	661			—			661
Equity-based compensation										506			—			506
Class B unit accretion	(780		)	—			(780		)	(835		)	—			(835		)
Other	814			—			814			208			—			208
Net income	51,962			1,832			53,794			25,696			1,216			26,912
Balance March 31, 2019	412,117			86,958			499,075
Distributions to HEP unitholders	(68,232		)	—			(68,232		)
Distributions to noncontrolling interest	—			(2,250		)	(2,250		)
Amortization of restricted and performance units	585			—			585
Class B unit accretion	(781		)	—			(781		)
Other	(138		)	—			(138		)
Net income	46,471			688			47,159
Balance June 30, 2019	390,022			85,396			475,418
Distributions to HEP unitholders	(68,493		)	—			(68,493		)
Distributions to noncontrolling interest	—			(2,500		)	(2,500		)
Amortization of restricted and performance units	528			—			528
Class B unit accretion	(835		)	—			(835		)
Other	182			—			182
Net income	83,180			1,004			84,184
Balance September 30, 2019	$	404,584		$	83,900		$	488,484
Balance March 31, 2020										338,159			112,175			450,334

~~Table of Contentsril 19,~~


	Common Units			Noncontrolling Interest			Total Equity			Common Units			Noncontrolling Interest			Total Equity

Balance December 31, 2017	$	393,959		$	91,106		$	485,065
Issuance of common units	114,376			—			114,376
Balance December 31, 2018										$	427,435		$	88,126		$	515,561
Distributions to HEP unitholders	(63,496		)	—			(63,496		)	(67,975		)	—			(67,975		)
Distributions to noncontrolling interest	—			(2,000		)	(2,000		)	—			(3,000		)	(3,000		)
Amortization of restricted and performance units	837			—			837
Class B unit accretion	(729		)	—			(729		)
Cumulative transition adjustment for adoption of revenue recognition standard	1,320			—			1,320
Other	240			—			240
Net income	46,897			1,738			48,635
Balance March 31, 2018	493,404			90,844			584,248
Issuance of common units	524			—			524
Distributions to HEP unitholders	(66,579		)	—			(66,579		)
Distributions to noncontrolling interest	—			(1,500		)	(1,500		)
Amortization of restricted and performance units	713			—			713
Equity-based compensation										406			—			406
Class B unit accretion	(730		)	—			(730		)	(780		)	—			(780		)
Other	193			—			193			1,069			—			1,069
Net income	40,872			627			41,499			51,962			1,832			53,794
Balance June 30, 2018	468,397			89,971			558,368
Issuance of common units	(61		)	—			(61		)
Distributions to HEP unitholders	(67,225		)	—			(67,225		)
Distributions to noncontrolling interest	—			(2,000		)	(2,000		)
Amortization of restricted and performance units	709			—			709
Class B unit accretion	(780		)	—			(780		)
Other	122			—			122
Net income	45,784			750			46,534
Balance September 30, 2018	$	446,946		$	88,721		$	535,667
Balance March 31, 2019										412,117			86,958			499,075

See accompanying notes.

Table of Contentsril 19,

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)


Note 1:	Description of Business and Presentation of Financial Statements

Holly Energy Partners, L.P. (“HEP”), together with its consolidated subsidiaries, is a publicly held master limited partnership. As of ~~September 30, 2019,~~March 31, 2020, HollyFrontier Corporation (“HFC”) and its subsidiaries own a 57% limited partner interest and the non-economic general partner interest in HEP. We commenced operations on July 13, 2004, upon the completion of our initial public offering. In these consolidated financial statements, the words “we,” “our,” “ours” and “us” refer to HEP unless the context otherwise indicates.

On October 31, 2017, we closed on an equity restructuring transaction with HEP Logistics Holdings, L.P. (“HEP Logistics”), a wholly-owned subsidiary of HFC and the general partner of HEP, pursuant to which the incentive distribution rights ("IDRs") held by HEP Logistics were canceled, and HEP Logistics' 2% general partner interest in HEP was converted into a non-economic general partner interest in HEP. In consideration, we issued 37,250,000 of our common units to HEP Logistics. In addition, HEP Logistics agreed to waive $2.5 million of limited partner cash distributions for each of twelve consecutive quarters beginning with the first quarter the units issued as consideration were eligible to receive distributions. This waiver of limited partner cash distributions will expire after the cash distribution for the second quarter of 2020, which will be made during the third quarter of 2020. As a result of this transaction, no distributions were made on the general partner interest after October 31, 2017.

On January 25, 2018, we entered into a common unit purchase agreement in which certain purchasers agreed to purchase in a private placement 3,700,000 common units representing limited partner interests, at a price of $29.73 per common unit. The private placement closed on February 6, 2018, and we received proceeds of approximately $110 million, which were used to repay indebtedness under our revolving credit facility.

We own and operate petroleum product and crude oil pipelines, terminal, tankage and loading rack facilities and refinery processing units that support ~~HFC’s~~ refining and marketing operations of HFC and other refineries in the Mid-Continent, Southwest and Northwest regions of the United States and Delek US Holdings, Inc.’s (“Delek”) refinery in Big Spring, Texas. Additionally, we own a 75% interest in UNEV Pipeline, LLC (“UNEV”), a 50% interest in Osage Pipe Line Company, LLC (“Osage”), a 50% interest in Cheyenne Pipeline LLC, and a 50% interest in ~~Cheyenne~~Cushing Connect Pipeline & Terminal LLC.

We operate in two reportable segments, a Pipelines and Terminals segment and a Refinery Processing Unit segment. Disclosures around these segments are discussed in Note 15.

We generate revenues by charging tariffs for transporting petroleum products and crude oil through our pipelines, by charging fees for terminalling and storing refined products and other hydrocarbons, providing other services at our storage tanks and terminals and by charging fees for processing hydrocarbon feedstocks through our refinery processing units. We do not take ownership of products that we transport, terminal, store or process, and therefore, we are not exposed directly to changes in commodity prices.

The consolidated financial statements included herein have been prepared without audit, pursuant to the rules and regulations of the United States Securities and Exchange Commission (the “SEC”). The interim financial statements reflect all adjustments, which, in the opinion of management, are necessary for a fair presentation of our results for the interim periods. Such adjustments are considered to be of a normal recurring nature. Although certain notes and other information required by U.S. generally accepted accounting principles (“GAAP”) have been condensed or omitted, we believe that the disclosures in these consolidated financial statements are adequate to make the information presented not misleading. These consolidated financial statements should be read in conjunction with our Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019. Results of operations for interim periods are not necessarily indicative of the results of operations that will be realized for the year ending December 31, ~~2019.~~2020.

Principles of Consolidation and Common Control Transactions

The consolidated financial statements include our accounts and those of subsidiaries and joint ventures that we control. All significant intercompany transactions and balances have been eliminated.

Most of our acquisitions from HFC occurred while we were a consolidated variable interest entity (“VIE”) of HFC. Therefore, as an entity under common control with HFC, we recorded these acquisitions on our balance sheets at HFC's historical basis instead of our purchase price or fair value.

Accounting Pronouncements Adopted During the Periods Presented

Goodwill Impairment Testing

In January 2017, Accounting Standard Update (“ASU”) 2017-04, “Simplifying the Test for Goodwill Impairment,” was issued amending the testing for goodwill impairment by eliminating Step 2 from the goodwill impairment test. Step 2 measures a goodwill impairment loss by comparing the implied fair value of a reporting unit’s goodwill with the carrying amount of that goodwill. Under this standard, goodwill impairment is measured as the excess of the carrying amount of the reporting unit over the related fair value. We adopted this standard effective in the second quarter of 2019, and the adoption of this standard had no effect on our financial condition, results of operations or cash flows.

Leases

In February 2016, ASU No. 2016-02, “Leases” (“ASC 842”) was issued requiring leases to be measured and recognized as a lease liability, with a corresponding right-of-use asset on the balance sheet. We adopted this standard effective January 1, 2019, and we elected to adopt using the ~~optional~~modified retrospective transition method, whereby comparative prior period financial information will not be restated and will continue to be reported under the lease accounting standard in effect during those periods. We also elected practical expedients provided by the new standard, including the package of practical expedients ~~whereby we did~~and the short-term lease recognition practical expedient, which allow an entity to not ~~reassess lease classification or initial indirect lease cost under~~recognize on the ~~new standard. In addition, we elected to exclude short-term~~balance sheet leases ~~which at inception have~~with a ~~lease~~ term of 12 months or ~~less, from the amounts recognized on our balance sheet.~~less. Upon adoption of this standard, we recognized $78.4 million of lease liabilities and corresponding right-of-use assets on our consolidated balance sheet. ~~Initial adoption~~Adoption of this standard did not have a material impact on our results of operations or cash flows. See Notes 3 and 4 for additional information on our lease policies.

~~Revenue Recognition~~

In May 2014, an accounting standard update was issued requiring revenue to be recognized when promised goods or services are transferred to customers in an amount that reflects the expected consideration for these goods or services. This standard had an effective date of January 1, 2018, and we accounted for the new guidance using the modified retrospective implementation method, whereby a cumulative effect adjustment was recorded to retained earnings as of the date of initial application. In preparing for adoption, we evaluated the terms, conditions and performance obligations under our existing contracts with customers. Furthermore, we implemented policies to comply with this new standard. See Note 2 for additional information on our revenue recognition policies.

~~Business Combinations~~

In December 2014, an accounting standard update was issued to provide new guidance on the definition of a business in relation to accounting for identifiable intangible assets in business combinations. This standard had an effective date of January 1, 2018 and had no effect on our financial condition, results of operations or cash flows.

~~Financial Assets and Liabilities~~

In January 2016, an accounting standard update was issued requiring changes in the accounting and disclosures for financial instruments. This standard was effective beginning with our 2018 reporting year and had no effect on our financial condition, results of operations or cash flows.

~~Accounting Pronouncements - Not Yet Adopted~~

Credit Losses Measurement

In June 2016, ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” was issued requiring measurement of all expected credit losses for certain types of financial instruments, including trade receivables, held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. ~~This~~We adopted this standard is effective January 1, 2020, and ~~our preliminary review~~adoption of ~~historic and expected credit losses indicates~~ the ~~amount of expected credit losses upon adoption would~~standard did not have a material impact on our financial condition, results of operations or cash flows.


Note 2:	Investment in Joint Venture

On October 2, 2019, HEP Cushing LLC (“HEP Cushing”), a wholly-owned subsidiary of HEP, and Plains Marketing, L.P. (“PMLP”), a wholly-owned subsidiary of Plains All American Pipeline, L.P. (“Plains”), formed a 50/50 joint venture, Cushing Connect Pipeline & Terminal LLC (the ~~“Joint~~“Cushing Connect Joint Venture”), for (i) the development and construction of a new 160,000 barrel per day

common carrier crude oil pipeline (the ~~“Pipeline”~~“Cushing Connect Pipeline”) that will connect the Cushing, Oklahoma crude oil hub to the Tulsa, Oklahoma refining complex owned by a subsidiary of HFC and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the ~~“JV~~“ Cushing Connect JV Terminal”). The Cushing Connect JV Terminal was partially in service in the first quarter of 2020 and is expected to be fully in service during the second quarter of ~~2020, and the~~2020. The Cushing Connect Pipeline is expected to be in service during the first quarter of 2021. Long-term commercial agreements have been entered into to support the Cushing Connect Joint Venture assets.

The Cushing Connect Joint Venture ~~will contract~~contracted with an affiliate of HEP to manage the construction and operation of the Cushing Connect Pipeline and with an affiliate of Plains to manage the operation of the Cushing Connect JV Terminal. The total Cushing Connect Joint Venture investment will be shared proportionately among the partners, and HEP estimates its share of the cost of the Cushing Connect JV Terminal contributed by Plains and Cushing Connect Pipeline construction costs ~~are~~will be approximately $65 million.

The Cushing Connect Joint Venture legal entities are variable interest entities ("VIEs") as defined under GAAP. A VIE is a legal entity if it has any one of the following characteristics: (i) the entity does not have sufficient equity at risk for the entity to finance its activities without additional subordinated financial support; (ii) the at risk equity holders, as a group, lack the characteristics of a controlling financial interest; or (iii) the entity is structured with non-substantive voting rights. The Cushing Connect Joint Venture legal entities do not have sufficient equity at risk to finance their activities without additional financial support. Since HEP is constructing and will operate the Cushing Connect Pipeline, HEP has more ability to direct the activities that most significantly impact the financial performance of the Cushing Connect Joint Venture and Cushing Connect Pipeline legal entities. Therefore, HEP consolidates those legal entities. We do not have the ability to direct the activities that most significantly impact the Cushing Connect JV Terminal legal entity, and therefore, we account for our interest in the Cushing Connect JV Terminal legal entity using the equity method of accounting.


Note 3:	Revenues

Revenues are generally recognized as products are shipped through our pipelines and terminals, feedstocks are processed through our refinery processing units or other services are rendered. The majority of our contracts with customers meet the definition of a lease since (1) performance of the contracts is dependent on specified property, plant, or equipment and (2) it is remote that one or more parties other than the customer will take more than a minor amount of the output associated with the specified property, plant, or equipment. Prior to the adoption of the new lease standard (see Note 1), we bifurcated the consideration received between lease and service revenue. The new lease standard allows the election of a practical expedient whereby a lessor does not have to separate non-lease (service) components from lease components under certain conditions. The majority of our contracts meet these conditions, and we have made this election for those contracts. Under this practical expedient, we treat the combined components as a single performance obligation in accordance with Accounting Standards Codification (“ASC”) 606, which largely codified ASU 2014-09, if the non-lease (service) component is the dominant component. If the lease component is the dominant component, we treat the combined components as a lease in accordance with ASC 842, which largely codified ASU 2016-02.

We adopted the new revenue recognition standard (see Note 1) using the modified retrospective method, whereby the cumulative effect of applying the new standard was recorded as an adjustment to the opening balance of partners’ equity as well as the carrying amounts of assets and liabilities as of January 1, 2018, which had no impact on our cash flows. The following table reflects the cumulative effect of adoption as of January 1, 2018:

Prior to Adoption Increase (Decrease) As Adjusted
(In thousands)
Deferred revenue $ 9,598
$ (1,320 ) $ 8,278
Partners’ equity: Common unitholders $ 393,959
$ 1,320
$ 395,279

Several of our contracts include incentive or reduced tariffs once a certain quarterly volume is met. Revenue from the variable element of these transactions is recognized based on the actual volumes shipped as it relates specifically to rendering the services during the applicable quarter.

The majority of our long-term transportation contracts specify minimum volume requirements, whereby, we bill a customer for a minimum level of shipments in the event a customer ships below their contractual requirements. If there are no future performance obligations, we will recognize these deficiency payments in revenue.

In certain of these throughput agreements, a customer may later utilize such shortfall billings as credit towards future volume shipments in excess of its minimum levels within its respective contractual shortfall make-up period. Such amounts represent an obligation to perform future services, which may be initially deferred and later recognized as revenue based on estimated future shipping levels, including the likelihood of a customer’s ability to utilize such amounts prior to the end of the contractual shortfall make-up period. We recognize the service portion of these deficiency payments in revenue when we do not expect we will be required to satisfy these performance obligations in the future based on the pattern of rights exercised by the customer. During the three ~~and nine~~ months ended ~~September 30, 2019,~~March 31, 2020, we recognized ~~$3.7~~$7.5 million ~~and $10.4 million, respectively,~~ of these deficiency payments in revenue, of which ~~none and $0.6~~$0.7 million ~~respectively,~~ related to deficiency payments billed in prior periods. As of ~~September 30, 2019,~~March 31, 2020, deferred revenue reflected in our consolidated balance sheet related to shortfalls billed was ~~$0.8~~$0.3 million.

A contract liability exists when an entity is obligated to perform future services to a customer for which the entity has received consideration. Since HEP may be required to perform future services for these deficiency payments received, the deferred revenues on our balance sheets were considered contract liabilities. A contract asset exists when an entity has a right to consideration in

exchange for goods or services transferred to a customer. Our consolidated balance sheets included the contract assets and liabilities in the table below:


	September 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
	(In thousands)						(In thousands)
Contract assets	$	5,479		$	1,818		$	5,870		$	5,675
Contract liabilities	$	(810	)	$	(1,821	)	$	(300	)	$	(650	)

The contract assets and liabilities include both lease and service components. We ~~did not recognize any~~recognized $0.7 million of revenue, during the three months ended ~~September 30, 2019,~~March 31, 2020, that was previously included in contract liability as of December 31, ~~2018,~~2019, and we recognized $0.6 million of revenue during the ~~nine~~three months ended ~~September 30,~~March 31, 2019, that was previously included in contract liability as of December 31, 2018. During the three ~~and the nine~~ months ended September 30, 2018, we recognized $37 thousand and $2.6 million, respectively, that was previously included in contract liability as of January 1, 2018. During the three and the nine months ended September 30, 2019,March 31, 2020, we also recognized $0.2 million ~~and $3.7 million, respectively,~~ of revenue included in contract assets at ~~September 30, 2019.~~March 31, 2020.

As of ~~September 30, 2019,~~March 31, 2020, we expect to recognize ~~$2.5~~$2.3 billion in revenue related to our unfulfilled performance obligations under the terms of our long-term throughput agreements and operating leases expiring in ~~2020~~2021 through 2036. These agreements generally provide for changes in the minimum revenue guarantees annually for increases or decreases in the Producer Price Index (“PPI”) or Federal Energy Regulatory Commission (“FERC”) index, with certain contracts having provisions that limit the level of the rate increases or decreases. We expect to recognize revenue for these unfulfilled performance obligations as shown in the table below (amounts shown in table include both service and lease revenues):


Years Ending December 31,	(In millions)		(In millions)
Remainder of 2019	$	96
2020	368
Remainder of 2020			$	277
2021	358		359
2022	331		331
2023	295		295
2024			257
2025			186
Thereafter	1,082		639
Total	$	2,530	$	2,344

Payment terms under our contracts with customers are consistent with industry norms and are typically payable within 10 to 30 days of the date of invoice.

Disaggregated revenues were as follows:


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2019		2018		2020		2019
	(In thousands)								(In thousands)
Pipelines	$	73,163	$	69,735	$	220,526	$	207,443	$	70,472	$	75,100
Terminals, tanks and loading racks	42,454		36,469		119,121		109,036		37,498		37,578
Refinery processing units	20,278		19,580		61,496		56,949		19,884		21,819
	$	135,895	$	125,784	$	401,143	$	373,428	$	127,854	$	134,497

During the three ~~and nine~~ months ended ~~September 30,~~March 31, 2020 and March 31, 2019, lease revenues amounted to ~~$97.5~~$93.2 million and ~~$285.8~~$94.3 million, respectively, and service revenues amounted to ~~$38.4~~$34.7 million and ~~$115.3~~$40.2 million, respectively. Both of these revenues were recorded within affiliates and third parties revenues on our consolidated statement of income.


Note 4:	Leases

We adopted ASC 842 effective January 1, 2019, and elected to adopt using the modified retrospective transition method and practical expedients, both of which are provided as options by the standard and further defined in Note 1.

Lessee Accounting

At inception, we determine if an arrangement is or contains a lease. Right-of-use assets represent our right to use an underlying asset for the lease term, and lease liabilities represent our payment obligation under the leasing arrangement. Right-of-use assets and lease liabilities are recognized at the commencement date based on the present value of lease payments over the lease term. We use our estimated incremental borrowing rate (“IBR”) to determine the present value of lease payments as most of our leases do not contain an implicit rate. Our IBR represents the interest rate which we would pay to borrow, on a collateralized basis, an amount equal to the lease payments over a similar term in a similar economic environment. We use the implicit rate when readily determinable.

As a lessee, we lease land, buildings, pipelines, transportation and other equipment to support our operations. These leases can be categorized into operating and finance leases. Operating leases are recorded in operating lease right-of-use assets and current and noncurrent operating lease liabilities on our consolidated balance sheet. Finance leases are included in properties and equipment, current finance lease liabilities and noncurrent finance lease liabilities on our consolidated balance sheet.

When renewal options are defined in a lease, our lease term includes an option to extend the lease when it is reasonably certain we will exercise that option. Leases with a term of 12 months or less are not recorded on our balance sheet, and lease expense is accounted for on a straight-line basis. In addition, as a lessee, we separate non-lease components that are identifiable and exclude them from the determination of net present value of lease payment obligations.

Our leases have remaining terms of 1 to 2625 years, some of which include options to extend the leases for up to 10 years.

Finance Lease Obligations

We have finance lease obligations related to vehicle leases with initial terms of 33 to 48 months. The total cost of assets under finance leases was ~~$6.7~~$7.4 million and ~~$5.8~~$7.0 million as of ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively, with accumulated depreciation of ~~$4.9~~$3.9 million and ~~$4.3~~$4.5 million as of ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively. We include depreciation of finance leases in depreciation and amortization in our consolidated statements of income.

In addition, we have a finance lease obligation related to a pipeline lease with an initial term of 10 years with one remaining subsequent renewal option for an additional 10 years. ~~The right of use asset associated with this obligation was derecognized as discussed under the lessor accounting disclosures below.~~

Supplemental balance sheet information related to leases was as follows (in thousands, except for lease term and discount rate):


	September 30, 2019			March 31, 2020			December 31, 2019

Operating leases:
Operating lease right-of-use assets, net	$	3,454		$	3,587		3,255

Current operating lease liabilities	807			1,235			1,126
Noncurrent operating lease liabilities	2,995			2,709			2,482
Total operating lease liabilities	$	3,802		$	3,944		3,608

Finance leases:
Properties and equipment	$	6,741		$	7,388		6,968
Accumulated amortization	(4,858		)	(3,934		)	(4,547	)
Properties and equipment, net	$	1,883		$	3,454		2,421

Current finance lease liabilities	$	5,426		$	3,238		3,224
Noncurrent finance lease liabilities	69,168			70,640			70,475
Total finance lease liabilities	$	74,594		$	73,878		73,699

Weighted average remaining lease term (in years)
Operating leases	6.6			6.2			6.5
Finance leases	17.4			16.6			17.0

Weighted average discount rate
Operating leases	5%			4.8%			5.0%
Finance leases	6%			5.6%			6.0%

Supplemental cash flow and other information related to leases were as follows:


			Three Months Ended March 31,
	Nine Months Ended September 30, 2019		2020		2019
	(In thousands)		(In thousands)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows on operating leases	$	5,467	$	282	$	1,795
Operating cash flows on finance leases	$	75	$	1,077	$	27
Financing cash flows on finance leases	$	780	$	1,096	$	252

Maturities of lease liabilities were as follows:


	September 30, 2019						March 31, 2020
	Operating			Finance			Operating			Finance
	(In thousands)						(In thousands)
2019	$	237		$	1,856
2020	897			7,305			$	722		$	5,430
2021	853			6,856			963			7,333
2022	509			6,711			628			7,207
2023	423			6,755			544			7,254
2024 and thereafter	1,534			86,738
2024							494			6,774
2025 and thereafter							1,184			80,313
Total lease payments	4,453			116,221			4,535			114,311
Less: Imputed interest	(651		)	(41,627		)	(591		)	(40,433		)
Total lease obligations	3,802			74,594			3,944			73,878
Less: Current obligations	(807		)	(5,426		)	(1,235		)	(3,238		)
Long-term lease obligations	$	2,995		$	69,168		$	2,709		$	70,640

The components of lease expense were as follows:


	Three Months Ended September 30, 2019		Nine Months Ended September 30, 2019		Three Months Ended March 31, 2020		Three Months Ended March 31, 2019
	(In thousands)				(In thousands)
Operating lease costs	$	1,852	$	5,420	$	273	1,770
Finance lease costs
Amortization of assets	213		711		242		244
Interest on lease liabilities	24		75		1,037		27
Variable lease cost	41		112		49		35
Total net lease cost	$	2,130	$	6,318	$	1,601	2,076

Lessor Accounting

As discussed in Note 2,3, the majority of our contracts with customers meet the definition of a lease. See Note 23 for further discussion of the impact of adoption of this standard on our activities as a lessor.

Customer contracts that contain leases are generally classified as either operating leases, direct finance leases or sales-type leases. We consider inputs such as the lease term, fair value of the underlying asset and residual value of the underlying assets when assessing the classification.

Substantially all of the assets supporting contracts meeting the definition of a lease have long useful lives, and we believe these assets will continue to have value when the current agreements expire due to our risk management strategy for protecting the residual fair value of the underlying assets by performing ongoing maintenance during the lease term. HFC generally has the option to purchase assets located within HFC refinery boundaries, including refinery tankage, truck racks and refinery processing units, at fair market value when the related agreements expire.

One of our throughput agreements with HFC was renewed during the three months ending September 30, 2019. Certain components of this agreement met the criteria of sales-type leases since the underlying assets are not expected to have an alternative use at the end of the lease term to anyone besides HFC. Under sales-type lease accounting, at the commencement date, the lessor recognizes a net investment in the lease and derecognizes the underlying assets with the difference recorded as selling profit or loss arising from the lease. Therefore, we recognized a gain on sales-type leases during the three months ending September 30, 2019 composed of the following:

(In thousands)

Net investment in leases $ 122,800
Properties and equipment, net (15,031 )
Operating lease right-of-use assets, net (72,603 )
Gain on sales-type leases $ 35,166

~~This sales-type lease transaction, including the related gain, was a non-cash transaction.~~

Lease income recognized was as follows:


	Three Months Ended September 30, 2019				Nine Months Ended September 30,
	2019		2018		2019		2018		Three Months Ended March 31, 2020		Three Months Ended March 31, 2019
	(In thousands)								(In thousands)
Operating lease revenues	$	94,459	$	71,297	$	282,747	$	209,850	$	91,388	$	94,295
Direct financing lease interest income	$	539	$	510	$	1,558	$	1,513	$	524	$	509
Gain on sales-type leases	$	35,166	$	—	$	35,166	$	—
Sales-type lease interest income	$	1,675	$	—	$	1,675	$	—	$	1,655	$	—
Lease revenues relating to variable lease payments not included in measurement of the sales-type lease receivable	$	3,075	$	—	$	3,075	$	—	$	1,797	$	—

For our sales-type leases, we included customer obligations related to minimum volume requirements in guaranteed minimum lease payments. Portions of our minimum guaranteed pipeline tariffs for assets subject to sales-type lease accounting are recorded as interest income with the remaining amounts recorded as a reduction in net investment in leases. We recognized any billings for throughput volumes in excess of minimum volume requirements as variable lease payments, and these variable lease payments were recorded in lease revenues.

As discussed in Note 2,3, prior to the adoption of ASC 842, contract consideration was bifurcated between operating lease and service revenues.

Annual minimum undiscounted lease payments under our leases were as follows as of ~~September 30, 2019:~~March 31, 2020:


	Operating		Finance		Sales-type		Operating		Finance		Sales-type
Years Ending December 31,	(In thousands)						(In thousands)
Remainder of 2019	$	81,025	$	526	$	2,375
2020	309,604		2,112		9,501
Remainder of 2020							$	233,353	$	1,586	$	7,126
2021	304,857		2,128		9,501		305,811		2,128		9,501
2022	303,454		2,145		9,501		303,468		2,145		9,501
2023	272,954		2,162		9,501		272,784		2,162		9,501
2024							235,009		2,179		9,501
Thereafter	963,783		42,966		52,255		728,110		40,787		42,754
Total	$	2,235,677	$	52,039	$	92,634	$	2,078,535	$	50,987	$	87,884

Net investments in leases recorded on our balance sheet were composed of the following:


	September 30, 2019				December 31, 2018				March 31, 2020				December 31, 2019
	Sales-type Leases		Direct Financing Leases		Sales-type Leases		Direct Financing Leases		Sales-type Leases		Direct Financing Leases		Sales-type Leases		Direct Financing Leases
	(In thousands)				(In thousands)				(In thousands)				(In thousands)
Lease receivables⁽¹⁾	$	70,426	$	16,522	$	—	$	16,549	$	67,092	$	16,499	$	68,457	$	16,511
Unguaranteed residual assets	51,674		—		—		—		53,577		—		52,933		—
Net investment in leases	$	122,100	$	16,522	$	—	$	16,549	$	120,669	$	16,499	$	121,390	$	16,511


(1)	Current portion of lease receivables included in prepaid and other current assets on the balance sheet.


Note 5:	Fair Value Measurements

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Fair value measurements are derived using inputs (assumptions that market participants would use in pricing an asset or liability) including assumptions about risk. GAAP categorizes inputs used in fair value measurements into three broad levels as follows:

(Level 1) Quoted prices in active markets for identical assets or liabilities.

(Level 2) Observable inputs other than quoted prices included in Level 1, such as quoted prices for similar assets and liabilities in active markets, similar assets and liabilities in markets that are not active or can be corroborated by observable market data.

(Level 3) Unobservable inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. This includes valuation techniques that involve significant unobservable inputs.

Financial Instruments

Our financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable, and debt. The carrying amounts of cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term maturity of these instruments. Debt consists of outstanding principal under our revolving credit agreement (which approximates fair value as interest rates are reset frequently at current interest rates) and our fixed interest rate senior notes.

The carrying amounts and estimated fair values of our senior notes were as follows:

September 30, 2019

December 31, 2018

March 31, 2020

December 31, 2019

Financial Instrument

Fair Value Input Level

Carrying

Value

Fair Value

Carrying

Value

Fair Value

Fair Value Input Level

Carrying

Value

Fair Value

Carrying

Value

Fair Value

(In thousands)

Liabilities:

6% Senior Notes

Level 2

496,369

523,220

495,900

488,310

Level 2

—

496,531

522,045

5% Senior Notes

Level 2

491,654

416,795

—

Level 2 Financial Instruments

Our senior notes are measured at fair value using Level 2 inputs. The fair value of the senior notes is based on market values provided by a third-party bank, which were derived using market quotes for similar type debt instruments. See Note 89 for additional information.

~~Non-Recurring Fair Value Measurements~~

For gains on sales-type leases recognized during the third quarter of 2019, the estimated fair value of the underlying leased assets at contract inception and the present value of the estimated unguaranteed residual asset at the end of the lease term are used in determining the net investment in leases and related gain on sales-type leases recorded. The asset valuation estimates include Level 3 inputs based on a replacement cost valuation method.


Note 6:	Properties and Equipment

The carrying amounts of our properties and equipment are as follows:


	September 30, 2019			December 31, 2018			March 31, 2020		December 31, 2019
	(In thousands)						(In thousands)
Pipelines, terminals and tankage	$	1,541,971		$	1,571,338		$	1,602,189	$	1,602,231
Refinery assets	347,338			347,338			349,030		348,093
Land and right of way	86,095			86,298			87,076		86,190
Construction in progress	36,901			23,482			26,894		10,930
Other	41,198			41,250			14,501		14,110
	2,053,503			2,069,706			2,079,690		2,061,554
Less accumulated depreciation	(574,553		)	(531,051		)	613,901		594,455
	$	1,478,950		$	1,538,655		$	1,465,789	$	1,467,099

We capitalized ~~$24~~$23.0 thousand and ~~$0.2 million~~$46.0 thousand during the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively, in interest attributable to construction projects.

Depreciation expense was ~~$61.7~~$20.3 million and ~~$62.6~~$20.7 million for the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~, respectively, and includes depreciation of assets acquired under capital leases.


Note 7:	Intangible Assets

Intangible assets include transportation agreements and customer relationships that represent a portion of the total purchase price of certain assets acquired from Delek in 2005, from HFC in 2008 prior to HEP becoming a consolidated VIE of HFC, from Plains in 2017, and from other minor acquisitions in 2018.

The carrying amounts of our intangible assets are as follows:


	Useful Life	September 30, 2019			December 31, 2018			Useful Life	March 31, 2020		December 31, 2019
		(In thousands)							(In thousands)
Delek transportation agreement	30 years	$	59,933		$	59,933		30 years	$	59,933	$	59,933
HFC transportation agreement	10-15 years	75,131			75,131			10-15 years	75,131		75,131
Customer relationships	10 years	69,683			69,683			10 years	69,683		69,683
Other		50			50				50		50
		204,797			204,797				204,797		204,797
Less accumulated amortization		(99,973		)	(89,468		)		106,977		103,475
		$	104,824		$	115,329			$	97,820	$	101,322

Amortization expense was ~~$10.5 million and $11.0~~$3.5 million for both of the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 and ~~2018, respectively.~~2019. We estimate amortization expense to be $14.0 million for each of the next ~~three~~two years, $9.9 million in 2023, and $9.1 million in ~~2024.~~2024 and 2025.

We have additional transportation agreements with HFC resulting from historical transactions consisting of pipeline, terminal and tankage assets contributed to us or acquired from HFC. These transactions occurred while we were a consolidated ~~VIE~~variable interest entity of HFC; therefore, our basis in these agreements is zero and does not reflect a step-up in basis to fair value.


Note 8:	Employees, Retirement and Incentive Plans

Direct support for our operations is provided by Holly Logistic Services, L.L.C. (“HLS”), an HFC subsidiary, which utilizes personnel employed by HFC who are dedicated to performing services for us. Their costs, including salaries, bonuses, payroll taxes, benefits and other direct costs, are charged to us monthly in accordance with an omnibus agreement that we have with HFC (the “Omnibus Agreement”). These employees participate in the retirement and benefit plans of HFC. Our share of retirement and benefit plan costs was ~~$1.8~~$2.2 million and $1.9 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $5.4 million and $5.3 million for the nine months ended September 30, 2019 and 2018,~~ respectively.

Under HLS’s secondment agreement with HFC (the “Secondment Agreement”), certain employees of HFC are seconded to HLS to provide operational and maintenance services for certain of our processing, refining, pipeline and tankage assets, and HLS reimburses HFC for its prorated portion of the wages, benefits, and other costs related to these employees.

We have a Long-Term Incentive Plan for employees and non-employee directors who perform services for us. The Long-Term Incentive Plan consists of 4 components: restricted or phantom units, performance units, unit options and unit appreciation rights. Our accounting policy for the recognition of compensation expense for awards with pro-rata vesting (a significant proportion of our awards) is to expense the costs ratably over the vesting periods.

As of ~~September 30, 2019~~March 31, 2020, we had 2 types of incentive-based awards outstanding, which are described below. The compensation cost charged against income was $0.5 million and $0.7 million for the three months ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~,

~~respectively, and $1.8 million and $2.1 million for the nine months ended September 30, 2019 and 2018,~~ respectively. We currently purchase units in the open market instead of issuing new units for settlement of all unit awards under our Long-Term Incentive Plan. As of ~~September 30, 2019,~~March 31, 2020, 2,500,000 units were authorized to be granted under our Long-Term Incentive Plan, of which ~~1,236,095~~1,116,919 have not yet been granted, assuming no forfeitures of the unvested units and full achievement of goals for the unvested performance units.

Restricted and Phantom Units

Under our Long-Term Incentive Plan, we grant restricted units to non-employee directors and phantom units to selected employees who perform services for us, with most awards vesting over a period of one to ~~three years. We previously granted restricted units to selected employees who perform services for us, which vest over a period of~~ three years. Although full ownership of the units does not transfer to the recipients until the units vest, the recipients have distribution rights on these units from the date of grant, and the recipients of the restricted units have voting rights on the restricted units from the date of grant.

The fair value of each restricted or phantom unit award is measured at the market price as of the date of grant and is amortized on a straight-line basis over the requisite service period for each separately vesting portion of the award.

A summary of restricted and phantom unit activity and changes during the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, is presented below:


Restricted and Phantom Units	Units		Weighted Average Grant-Date Fair Value		Units		Weighted Average Grant-Date Fair Value
Outstanding at January 1, 2019 (nonvested)	138,016		$	31.35
Outstanding at January 1, 2020 (nonvested)					145,205		$	26.22
Vesting and transfer of full ownership to recipients					(4,397	)	30.29
Forfeited	(18,008	)	31.22		(3,267	)	24.44
Outstanding at September 30, 2019 (nonvested)	120,008		$	31.37
Outstanding at March 31, 2020 (nonvested)					137,541		$	26.14

The grant date fair values of phantom units that were vested and transferred to recipients during the three months ended March 31, 2020 were $0.1 million. No restricted or phantom units were vested and transferred to recipients during the ~~nine~~three months ended ~~September 30,~~March 31, 2019. As of ~~September 30, 2019,~~March 31, 2020, there was ~~$0.9~~$1.9 million of total unrecognized compensation expense related to unvested restricted and phantom unit grants, which is expected to be recognized over a weighted-average period of ~~1.1~~1.4 years.

Performance Units

Under our Long-Term Incentive Plan, we grant performance units to selected officers who perform services for us. Performance units granted are payable in common units at the end of a three-year performance period based upon meeting certain criteria over the performance period. Under the terms of our performance unit grants, some awards are subject to the growth in our distributable cash flow per common unit over the performance period while other awards are subject to "financial performance" and "market performance." Financial performance is based on meeting certain earnings before interest, taxes, depreciation and amortization ("EBITDA") targets, while market performance is based on the relative standing of total unitholder return achieved by HEP compared to peer group companies. The number of units ultimately issued under these awards can range from 50% to 150% or 0% to 200%. As of ~~September 30, 2019~~March 31, 2020, estimated unit payouts for outstanding nonvested performance unit awards ranged between 100% and 150% of the target number of performance units granted.

We did not grant any performance units during the ~~nine~~three months ended ~~September 30, 2019.~~March 31, 2020. Although common units are not transferred to the recipients until the performance units vest, the recipients have distribution rights with respect to the ~~common~~target number of performance units subject to the award from the date of ~~grant.~~grant at the same rate as distributions paid on our common units.

A summary of performance unit activity and changes for the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, is presented below:



Performance Units	Units
Outstanding at January 1, ~~2019~~2020 (nonvested)	~~51,748~~53,445
Vesting and transfer of common units to recipients	(~~10,113~~	)
~~Forfeited~~	~~(5,200~~11,634	)
Outstanding at ~~September 30, 2019~~March 31, 2020 (nonvested)	~~36,435~~41,811

The grant date fair value of performance units vested and transferred to recipients during the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019 ~~and 2018~~ was ~~$0.3~~$0.4 million and ~~$0.1~~$0.3 million, respectively. Based on the weighted-average fair value of performance units

outstanding at ~~September 30, 2019,~~March 31, 2020, of $1.2 million, there was ~~$0.3~~$0.5 million of total unrecognized compensation expense related to nonvested performance units, which is expected to be recognized over a weighted-average period of ~~1.3~~1.8 years.

During the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, we ~~paid $0.3 million for the~~did not purchase any of our common units in the open market for the issuance and settlement of unit awards under our Long-Term Incentive Plan.


Note 9:	Debt

Credit Agreement

We have a $1.4 billion senior secured revolving credit facility (the “Credit Agreement”) expiring in July 2022. The Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. The Credit Agreement is also available to fund letters of credit up to a $50 million sub-limit, and it contains an accordion feature giving us the ability to increase the size of the facility by up to $300 million with additional lender commitments.

Our obligations under the Credit Agreement are collateralized by substantially all of our assets, and indebtedness under the Credit Agreement is guaranteed by our material, wholly-owned subsidiaries. The Credit Agreement requires us to maintain compliance with certain financial covenants consisting of total leverage, senior secured leverage, and interest coverage. It also limits or restricts our ability to engage in certain activities. If, at any time prior to the expiration of the Credit Agreement, HEP obtains two investment grade credit ratings, the Credit Agreement will become unsecured and many of the covenants, limitations, and restrictions will be eliminated.

We may prepay all loans at any time without penalty, except for tranche breakage costs. If an event of default exists under the Credit Agreement, the lenders will be able to accelerate the maturity of all loans outstanding and exercise other rights and remedies. We were in compliance with the covenants as of ~~September 30, 2019.~~March 31, 2020.

Senior Notes

~~We have~~As of December 31, 2019, we had $500 million in aggregate principal amount of 6% senior unsecured notes due in 2024 (the ~~“6%~~"6% Senior ~~Notes”~~Notes") outstanding. The 6% Senior Notes were unsecured and imposed certain restrictive covenants, including limitations on our ability to incur additional indebtedness, make investments, sell assets, incur certain liens, pay distributions, enter into transactions with affiliates and enter into mergers.

On February 4, 2020, we closed a private placement of $500 million in aggregate principal amount of 5% senior unsecured notes due in 2028 (the "5% Senior Notes"). On February 5, 2020, we redeemed the existing $500 million 6% Senior Notes at a redemption cost of $522.5 million, at which time we recognized a $25.9 million early extinguishment loss consisting of a $22.5 million debt redemption premium and unamortized financing costs of $3.4 million. We funded the $522.5 million redemption with net proceeds from the issuance of our 5% Senior Notes and borrowings under our Credit Agreement.

time when the 6%5% Senior Notes are rated investment grade by ~~both~~either Moody’s ~~and~~or Standard & Poor’s and no default or event of default exists, we will not be subject to many of the foregoing covenants. Additionally, we have certain redemption rights at varying premiums over face value under the 6%5% Senior Notes.

Indebtedness under the 6%5% Senior Notes is guaranteed by all of our existing wholly-owned subsidiaries (other than Holly Energy Finance Corp. and certain immaterial subsidiaries).

Long-term Debt

The carrying amounts of our long-term debt was as follows:


	September 30, 2019			December 31, 2018			March 31, 2020		December 31, 2019
	(In thousands)						(In thousands)
Credit Agreement
Amount outstanding	$	935,500		$	923,000		1,010,500		$	965,500

6% Senior Notes
Principal	500,000			500,000			—		500,000
Unamortized premium and debt issuance costs	(3,631		)	(4,100		)	—		(3,469		)
	496,369			495,900			—		496,531

5% Senior Notes
Principal							500,000		—
Unamortized premium and debt issuance costs							(8,346	)	—
							491,654		—

Total long-term debt	$	1,431,869		$	1,418,900		1,502,154		$	1,462,031

Interest Expense and Other Debt Information

Interest expense consists of the following components:


	Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2020		2019
	(In thousands)				(In thousands)
Interest on outstanding debt:
Credit Agreement	$	30,959	$	27,233	$	8,601	$	10,372
6% Senior Notes	22,500		22,500		2,833		7,500
5% Senior Notes					4,167		—
Amortization of discount and deferred debt issuance costs	2,307		2,277		799		766
Commitment fees and other	1,317		1,450
Commitment fees					353		403
Interest on finance leases					1,037		27
Total interest incurred	57,083		53,460		17,790		19,068
Less capitalized interest	24		211		23		46
Net interest expense	$	57,059	$	53,249	$	17,767	$	19,022
Cash paid for interest	$	62,195	$	58,697	$	25,168	$	25,918


Note 10:	Related Party Transactions

We serve HFC’s refineries under long-term pipeline, terminal and tankage throughput agreements, and refinery processing unit tolling agreements expiring from 2021 to 2036, and revenues from these agreements accounted for ~~78%~~79% of our total revenues for the three ~~and nine~~ months ended ~~September 30, 2019.~~March 31, 2020. Under these agreements, HFC agrees to transport, store and process throughput volumes of refined product, crude oil and feedstocks on our pipelines, terminals, tankage, loading rack facilities and refinery processing units that result in minimum annual payments to us. These minimum annual payments or revenues are subject to annual rate adjustments on July 1st each year generally based on increases or decreases in PPI or the FERC index. As of ~~September 30, 2019,~~March 31, 2020, these agreements with HFC require minimum annualized payments to us of ~~$349~~$348.2 million.

If HFC fails to meet its minimum volume commitments under the agreements in any quarter, it will be required to pay us the amount of any shortfall in cash by the last day of the month following the end of the quarter. Under certain of these agreements, a shortfall payment may be applied as a credit in the following four quarters after its minimum obligations are met.

Under certain provisions of the Omnibus Agreement, we pay HFC an annual administrative fee (currently $2.6 million) for the provision by HFC or its affiliates of various general and administrative services to us. This fee does not include the salaries of personnel employed by HFC who perform services for us on behalf of HLS or the cost of their employee benefits, which are charged to us separately by HFC. Also, we reimburse HFC and its affiliates for direct expenses they incur on our behalf.

Related party transactions with HFC are as follows:


•	Revenues received from HFC were ~~$106.0~~$101.4 million and ~~$100.2~~$103.4 million for the three months ended ~~September 30, 2019~~March 31, 2020 and ~~2018~~2019, ~~respectively, and $311.8 million and $295.6 million for the nine months ended September 30, 2019 and 2018,~~ respectively.

HFC charged us general and administrative services under the Omnibus Agreement of $0.7 million and $0.6 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $1.9 million for each of the nine months ended September 30, 2019 and 2018.~~respectively.

We reimbursed HFC for costs of employees supporting our operations of ~~$13.7~~$14.1 million and ~~$13.1~~$13.6 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $40.5 million and $38.3 million for the nine months ended September 30, 2019 and 2018,~~ respectively.

HFC reimbursed us ~~$4.6~~$3.1 million and ~~$2.8~~$2.1 million for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ respectively, for expense and capital ~~projects, and $10.4 million and $6.9 million for the nine months ended September 30, 2019 and 2018, respectively.~~projects.

We distributed $37.6 million and ~~$36.9~~$37.3 million in the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively, and $112.4 million and $109.7 million for the nine months ended September 30, 2019 and 2018,~~ respectively, to HFC as regular distributions on its common units.


•	Accounts receivable from HFC were ~~$35.8~~$38.4 million and $~~46.8~~49.7 million at ~~September 30, 2019~~March 31, 2020, and December 31, ~~2018~~2019, respectively.


•	Accounts payable to HFC were ~~$6.7~~$6.4 million and $~~14.2~~16.7 million at ~~September 30, 2019~~March 31, 2020, and December 31, ~~2018~~2019, respectively.


•	Deferred revenue in the consolidated balance sheets at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019, included ~~$0.6~~$0.2 million and ~~$1.7~~$0.5 million, respectively, relating to certain shortfall billings to HFC.

We received direct financing lease payments from HFC for use of our Artesia and Tulsa railyards of $0.5 million for ~~each of~~ the three months ended ~~September 30, 2019~~March 31, 2020 and ~~2018,~~2019.

We received sales-type lease payments of $2.4 million from HFC that were not included in revenues for the three months ended March 31, 2020.

On October 31, 2017, we closed on an equity restructuring transaction with HEP Logistics, a wholly-owned subsidiary of HFC and ~~$1.5~~the general partner of HEP, pursuant to which the incentive distribution rights held by HEP Logistics were canceled, and HEP Logistics' 2% general partner interest in HEP was converted into a non-economic general partner interest in HEP. In consideration, we issued 37,250,000 of our common units to HEP Logistics. In addition, HEP Logistics agreed to waive $2.5 million of limited partner cash distributions for each of twelve consecutive quarters beginning with the ~~nine months ended September 30, 2019 and 2018.~~first quarter the units issued as consideration were eligible to receive distributions. This waiver of limited partner cash distributions will expire after the cash distribution for the second quarter of 2020, which will be made during the third quarter of 2020.


•	~~We recorded a gain on sales-type leases of $35.2 million during the three months ended~~ ~~September 30, 2019, and we received sales-type lease payments of $2.4 million that were not included in revenues for the three and nine months ended September 30, 2019.~~


Note 11:	Partners’ Equity, Income Allocations and Cash Distributions

As of ~~September 30, 2019,~~March 31, 2020, HFC held 59,630,030 of our common units, constituting a 57% limited partner interest in us, and held the non-economic general partner interest.

On January 25, 2018, we entered into a common unit purchase agreement in which certain purchasers agreed to purchase in a private placement 3,700,000 common units representing limited partnership interests, at a price of $29.73 per common unit. The private placement closed on February 6, 2018, and we received proceeds of approximately $110 million, which were used to repay indebtedness under our Credit Agreement.

Continuous Offering Program

We have a continuous offering program under which we may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. ~~For the nine months ended September 30, 2019, HEP did not issue units under this program.~~ As of ~~September 30, 2019,~~March 31, 2020, HEP has issued 2,413,153 units under this program, providing $82.3 million in gross proceeds.

We intend to use our net proceeds for general partnership purposes, which may include funding working capital, repayment of debt, acquisitions and capital expenditures. Amounts repaid under the Credit Agreement may be reborrowed from time to time.

Allocations of Net Income

Net income attributable to HEP is allocated to the partners based on their weighted-average ownership percentage during the period.

Cash Distributions

On ~~October 17, 2019,~~April 23, 2020, we announced our cash distribution for the ~~third~~first quarter of ~~2019~~2020 of ~~$0.6725~~$0.35 per unit. The distribution is payable on all common units and will be paid ~~November 12, 2019,~~May 14, 2020, to all unitholders of record on ~~October 28, 2019.~~May 4, 2020. However, HEP Logistics waived $2.5 million in limited partner cash distributions due to them as discussed in Note 1.

Our regular quarterly cash distribution to the limited partners will be ~~$68.5~~$34.5 million for the three months ended ~~September 30, 2019~~March 31, 2020 and was ~~$67.7~~$68.2 million for the three months ended September 30, 2018. For the nine months ended September 30, 2019, the regular quarterly distribution to the limited partners will be $205.2 million and was $201.3 million for the nine months ended September 30, 2018.March 31, 2019. Our distributions are declared subsequent to quarter end; therefore, these amounts do not reflect distributions paid during the respective period.

As a master limited partnership, we distribute our available cash, which historically has exceeded our net income attributable to HEP because depreciation and amortization expense represents a non-cash charge against income. The result is a decline in our partners’ equity since our regular quarterly distributions have exceeded our quarterly net income attributable to HEP. Additionally, if the asset contributions and acquisitions from HFC had occurred while we were not a consolidated VIE of HFC, our acquisition cost, in excess of HFC’s historical basis in the transferred assets, would have been recorded in our financial statements at the time of acquisition as increases to our properties and equipment and intangible assets instead of decreases to our partners’ equity.


Note 12:	Net Income Per Limited Partner Unit

~~Net~~Basic net income per unit applicable to the limited partners is ~~computed using~~calculated as net income attributable to the ~~two-class method, since we have more than one participating security (common~~partners divided by the weighted average limited partners’ units outstanding. Diluted net income per unit assumes, when dilutive, the issuance of the net incremental units from restricted units, phantom units and ~~restricted units).~~

Toperformance units.To the extent net income attributable to the partners exceeds or is less than cash distributions, this difference is allocated to the partners based on their weighted-average ownership percentage during the period, after consideration of any priority allocations of earnings. Our dilutive securities ~~restricted units,~~ are immaterial for all periods presented.

~~For purposes of applying the two-class method, including the allocation of cash distributions in excess of earnings, net~~

Net income per limited partner unit is computed as follows:

Three Months Ended
September 30, Nine Months Ended
September 30,
2019 2018 2019 2018
(In thousands)
Net income attributable to the partners $ 82,345
$ 45,003
$ 179,217
$ 131,314
Limited partner’s distribution declared on common units (68,494 ) (67,669 ) (205,223 ) (201,310 )
Net income attributable to the partners in excess of (less than) distributions $ 13,851
$ (22,666 ) $ (26,006 ) $ (69,996 )


	Three Months Ended September 30,					Nine Months Ended September 30,						Three Months Ended March 31,
	2019		2018			2019			2018			2020		2019
	(In thousands, except per unit data)											(In thousands, except per unit data)
Net income attributable to the partners:
Distributions declared	$	68,494	$	67,669		205,223			201,310
Net income attributable to the partners in excess of (less than) distributions	13,851		(22,666		)	(26,006		)	(69,996		)
Net income attributable to the partners	$	82,345	$	45,003		$	179,217		$	131,314		$	24,861	$	51,182
Weighted average limited partners' units outstanding	105,440		105,440			105,440			104,908			105,440		105,440
Limited partners' per unit interest in earnings - basic and diluted	$	0.78	$	0.43		$	1.70		$	1.25		$	0.24	$	0.49


Note 13:	Environmental

We expensed ~~$0.3~~$0.2 million for the three ~~and nine~~ months ended ~~September 30, 2019,~~March 31, 2020, for environmental remediation obligations, and we ~~expensed $25 thousand and $0.4 million~~incurred no expenses for the three ~~and nine~~ months ended ~~September 30, 2018, respectively.~~March 31, 2019. The accrued environmental liability, net of expected recoveries from indemnifying parties, reflected in our consolidated balance sheets was ~~$5.8 million and $6.3~~$5.5 million at ~~September 30, 2019~~both March 31, 2020 and December 31, ~~2018, respectively,~~2019, of which ~~$3.8~~$3.3 million and ~~$4.3~~$3.5 million, respectively, were classified as other long-term liabilities. These accruals include remediation and monitoring costs expected to be incurred over an extended period of time.

Under the Omnibus Agreement and certain transportation agreements and purchase agreements with HFC, HFC has agreed to indemnify us, subject to certain monetary and time limitations, for environmental noncompliance and remediation liabilities associated with certain assets transferred to us from HFC and occurring or existing prior to the date of such transfers. Our consolidated balance sheets included additional accrued environmental liabilities of $0.4 million and $0.5 million for HFC indemnified liabilities for ~~both~~the periods ending ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, respectively, and other assets included equal and offsetting balances representing amounts due from HFC related to indemnifications for environmental remediation liabilities.


Note 14:	Contingencies

We are a party to various legal and regulatory proceedings, none of which we believe will have a material adverse impact on our financial condition, results of operations or cash flows.


Note 15:	Segment Information

Although financial information is reviewed by our chief operating decision makers from a variety of perspectives, they view the business in two reportable operating segments: pipelines and terminals, and refinery processing units. These operating segments adhere to the accounting polices used for our consolidated financial statements.

Pipelines and terminals have been aggregated as one reportable segment as both pipeline and terminals (1) have similar economic characteristics, (2) similarly provide logistics services of transportation and storage of petroleum products, (3) similarly support the petroleum refining business, including distribution of its products, (4) have principally the same customers and (5) are subject to similar regulatory requirements.

We evaluate the performance of each segment based on its respective operating income. Certain general and administrative expenses and interest and financing costs are excluded from segment operating income as they are not directly attributable to a specific reportable segment. Identifiable assets are those used by the segment, whereas other assets are principally equity method investments, cash, deposits and other assets that are not associated with a specific reportable reportable segment.


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
	(In thousands)												(In thousands)
Revenues:
Pipelines and terminals - affiliate	$	85,749		$	80,608		$	250,259		$	238,680		$	81,544		$	81,540
Pipelines and terminals - third-party	29,868			25,596			89,388			77,799			26,426			31,138
Refinery processing units - affiliate	20,278			19,580			61,496			56,949			19,884			21,819
Total segment revenues	$	135,895		$	125,784		$	401,143		$	373,428		$	127,854		$	134,497

Segment operating income:
Pipelines and terminals	$	56,944		$	56,531		$	178,112		$	167,748		$	58,903		$	63,232
Refinery processing units	9,906			8,890			27,794			24,832			9,992			9,922
Total segment operating income	66,850			65,421			205,906			192,580			68,895			73,154
Unallocated general and administrative expenses	(2,714		)	(2,498		)	(7,322		)	(8,293		)	(2,702		)	(2,620		)
Interest and financing costs, net	(16,564		)	(17,502		)	(53,737		)	(51,668		)	(15,549		)	(18,494		)
Loss on early extinguishment of debt													(25,915		)	—
Equity in earnings of equity method investments	1,334			1,114			5,217			4,127			1,714			2,100
Gain on sales-type leases	35,166			—			35,166			—
Gain (loss) on sale of assets and other	142			38			(57		)	71			506			(310		)
Income before income taxes	$	84,214		$	46,573		$	185,173		$	136,817		$	26,949		$	53,830

Capital Expenditures:
Pipelines and terminals	$	5,320		$	9,389		$	23,072		$	34,128		$	18,618		$	10,718
Refinery processing units	756			142			756			142			324			—
Total capital expenditures	$	6,076		$	9,531		$	23,828		$	34,270		$	18,942		$	10,718


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
	(In thousands)				(In thousands)
Identifiable assets:
Pipelines and terminals⁽¹⁾	$	1,747,930	$	1,694,101	$	1,732,984	$	1,749,843
Refinery processing units	308,311		312,888		302,654		305,897
Other	98,034		95,551		152,646		143,492
Total identifiable assets	$	2,154,275	$	2,102,540	$	2,188,284	$	2,199,232

(1) Includes goodwill of $270.3 million as of ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.


Note 16:	Supplemental Guarantor/Non-Guarantor Financial Information

Obligations of HEP (“Parent”) under both the 6% and 5% Senior Notes have been jointly and severally guaranteed by each of its direct and indirect 100% owned subsidiaries (“Guarantor Subsidiaries”). These guarantees are full and unconditional, subject to certain customary release provisions. These circumstances include (i) when a Guarantor Subsidiary is sold or sells all or substantially all of its assets, (ii) when a Guarantor Subsidiary is declared “unrestricted” for covenant purposes, (iii) when a Guarantor Subsidiary’s guarantee of other indebtedness is terminated or released and (iv) when the requirements for legal defeasance or covenant defeasance or to discharge the senior notes have been satisfied.

The following financial information presents condensed consolidating balance sheets, statements of comprehensive income, and statements of cash flows of the Parent, the Guarantor Subsidiaries and the Non-Guarantor Subsidiaries. The information has been presented as if the Parent accounted for its ownership in the Guarantor Subsidiaries, and the Guarantor Restricted Subsidiaries accounted for the ownership of the Non-Guarantor Non-Restricted Subsidiaries, using the equity method of accounting.

Condensed Consolidating Balance Sheet


September 30, 2019		Parent		Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
March 31, 2020															Parent		Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
		(In thousands)													(In thousands)
ASSETS
Current assets:
Cash and cash equivalents		$	5,603	$	(1,043	)	$	2,909	$	—		$	7,469		$	1,722	$	(1,152	)	$	18,712	$	—		$	19,282
Accounts receivable		—		46,995			5,218		(261		)	51,952			—		49,018			5,988		(962		)	54,044
Prepaid and other current assets		145		4,335			299					4,779			445		6,483			620					7,548
Total current assets		5,748		50,287			8,426		(261		)	64,200			2,167		54,349			25,320		(962		)	80,874

Properties and equipment, net		—		1,144,873			334,077		—			1,478,950			—		1,123,996			341,793		—			1,465,789
Operating lease right-of-use assets	0	—		3,424			30		—			3,454		0	—		3,379			208		—			3,587
Net investment in leases		—		136,394			—		—			136,394			—		134,108			—		—			134,108
Investment in subsidiaries		1,829,611		251,700			—		(2,081,311		)	—			1,837,112		277,876			—		(2,114,988		)	—
Intangible assets, net		—		104,824			—		—			104,824			—		97,820			—		—			97,820
Goodwill		—		270,336			—		—			270,336			—		270,336			—		—			270,336
Equity method investments		—		82,884			—		—			82,884			—		84,526			39,054		—			123,580
Other assets		7,334		5,899			—		—			13,233			6,110		6,080			—		—			12,190
Total assets		$	1,842,693	$	2,050,621		$	342,533	$	(2,081,572	)	$	2,154,275		$	1,845,389	$	2,052,470		$	406,375	$	(2,115,950	)	$	2,188,284

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable		$	—	$	18,055		$	1,561	$	(261	)	$	19,355		$	—	$	13,363		$	13,541	$	(962	)	$	25,942
Accrued interest		5,884		—			—		—			5,884			4,695		—			—		—			4,695
Deferred revenue		—		8,964			810		—			9,774			—		10,510			300		—			10,810
Accrued property taxes		—		5,131			4,135		—			9,266			—		3,845			1,862		—			5,707
Current operating lease liabilities		—		777			30		—			807			—		1,167			68		—			1,235
Current finance lease liabilities		—		5,426			—		—			5,426			—		3,238			—		—			3,238
Other current liabilities		96		2,830			—		—			2,926			121		2,923			21		—			3,065
Total current liabilities		5,980		41,183			6,536		(261		)	53,438			4,816		35,046			15,792		(962		)	54,692

Long-term debt		1,431,869		—			—		—			1,431,869			1,502,154		—			—		—			1,502,154
Noncurrent operating lease liabilities		—		2,995			—		—			2,995			—		2,709			—		—			2,709
Noncurrent finance lease liabilities		—		69,168			—		—			69,168			—		70,640			—		—			70,640
Other long-term liabilities		260		12,245			397		—			12,902			260		11,658			532		—			12,450
Deferred revenue		—		46,862			—		—			46,862			—		45,078			—		—			45,078
Class B unit		—		48,557			—		—			48,557			—		50,227			—		—			50,227
Equity - partners		404,584		1,829,611			251,700		(2,081,311		)	404,584			338,159		1,837,112			277,876		(2,114,988		)	338,159
Equity - noncontrolling interest		—		—			83,900		—			83,900			—		—			112,175		—			112,175
Total liabilities and equity		$	1,842,693	$	2,050,621		$	342,533	$	(2,081,572	)	$	2,154,275		$	1,845,389	$	2,052,470		$	406,375	$	(2,115,950	)	$	2,188,284

Condensed Consolidating Balance Sheet


December 31, 2018	Parent		Guarantor Restricted Subsidiaries		Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
December 31, 2019												Parent		Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
	(In thousands)											(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	2	$	—	$	3,043	$	—		$	3,045	$	4,790	$	(709	)	$	9,206	$	—		$	13,287
Accounts receivable	—		53,376		5,994		(252		)	59,118		—		60,229			8,549		(331		)	68,447
Prepaid and other current assets	217		3,542		552		—			4,311		282		6,710			637		—			7,629
Total current assets	219		56,918		9,589		(252		)	66,474		5,072		66,230			18,392		(331		)	89,363

Properties and equipment, net	—		1,193,181		345,474		—			1,538,655		—		1,133,534			333,565		—			1,467,099
Operating lease right-of-use assets												—		3,243			12		—			3,255
Net investment in leases	—		16,488		—		—			16,488		—		134,886			—		—			134,886
Investment in subsidiaries	1,850,416		264,378		—		(2,114,794		)	—		1,844,812		275,279			—		(2,120,091		)	—
Intangible assets, net	—		115,329		—		—			115,329		—		101,322			—		—			101,322
Goodwill	—		270,336		—		—			270,336		—		270,336			—		—			270,336
Equity method investments	—		83,840		—		—			83,840		—		82,987			37,084		—			120,071
Other assets	9,291		2,127		—		—			11,418		6,722		6,178			—		—			12,900
Total assets	$	1,859,926	$	2,002,597	$	355,063	$	(2,115,046	)	$	2,102,540	$	1,856,606	$	2,073,995		$	389,053	$	(2,120,422	)	$	2,199,232

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	—	$	30,325	$	584	$	(252	)	$	30,657	$	—	$	29,895		$	4,991	$	(331	)	$	34,555
Accrued interest	13,302		—		—		—			13,302		13,206		—			—		—			13,206
Deferred revenue	—		8,065		632		—			8,697		—		9,740			650		—			10,390
Accrued property taxes	—		744		1,035		—			1,779		—		2,737			1,062		—			3,799
Current operating lease liabilities												—		1,114			12		—			1,126
Current finance lease liabilities	—		936		—		—			936		—		3,224			—		—			3,224
Other current liabilities	29		2,493		4		—			2,526		6		2,293			6		—			2,305
Total current liabilities	13,331		42,563		2,255		(252		)	57,897		13,212		49,003			6,721		(331		)	68,605

Long-term debt	1,418,900		—		—		—			1,418,900		1,462,031		—			—		—			1,462,031
Noncurrent operating lease liabilities												—		2,482			—		—			2,482
Noncurrent finance lease liabilities	—		867		—		—			867		—		70,475			—		—			70,475
Other long-term liabilities	260		13,876		304		—			14,440		260		12,150			398		—			12,808
Deferred revenue	—		48,714		—		—			48,714		—		45,681			—		—			45,681
Class B unit	—		46,161		—		—			46,161		—		49,392			—		—			49,392
Equity - partners	427,435		1,850,416		264,378		(2,114,794		)	427,435		381,103		1,844,812			275,279		(2,120,091		)	381,103
Equity - noncontrolling interest	—		—		88,126		—			88,126		—		—			106,655		—			106,655
Total liabilities and equity	$	1,859,926	$	2,002,597	$	355,063	$	(2,115,046	)	$	2,102,540	$	1,856,606	$	2,073,995		$	389,053	$	(2,120,422	)	$	2,199,232

Condensed Consolidating Statement of Comprehensive Income


Three Months Ended September 30, 2019	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-restricted Subsidiaries			Eliminations			Consolidated
Three Months Ended March 31, 2020																Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)															(In thousands)
Revenues:
Affiliates	$	—		$	99,482		$	6,545		$	—		$	106,027		$	—		$	94,755		$	6,673		$	—		$	101,428
Third parties	—			23,999			5,869			—			29,868			—			19,155			7,271			—			26,426
	—			123,481			12,414			—			135,895			—			113,910			13,944			—			127,854
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			40,866			4,058			—			44,924			—			31,131			3,850			—			34,981
Depreciation and amortization	—			19,757			4,364			—			24,121			—			19,753			4,225			—			23,978
General and administrative	569			2,145			—			—			2,714			1,099			1,603			—			—			2,702
	569			62,768			8,422			—			71,759			1,099			52,487			8,075			—			61,661
Operating income (loss)	(569		)	60,713			3,992			—			64,136			(1,099		)	61,423			5,869			—			66,193

Other income (expense):
Equity in earnings of subsidiaries	101,638			3,013			—			(104,651		)	—			68,535			4,295			—			(72,830		)	—
Equity in earnings of equity method investments	—			1,334			—			—			1,334			—			2,088			(374		)	—			1,714
Interest expense	(18,945		)	138			—			—			(18,807		)	(16,730		)	(1,037		)	—			—			(17,767		)
Interest income	—			2,243			—			—			2,243			—			2,218			—			—			2,218
Gain on sales-type lease	—			35,166			—			—			35,166
Loss on early extinguishment of debt																(25,915		)	—			—			—			(25,915		)
Gain on sale of assets and other	221			(104		)	25			—			142			70			420			16			—			506
	82,914			41,790			25			(104,651		)	20,078			25,960			7,984			(358		)	(72,830		)	(39,244		)
Income before income taxes	82,345			102,503			4,017			(104,651		)	84,214			24,861			69,407			5,511			(72,830		)	26,949
State income tax expense	—			(30		)	—			—			(30		)	—			(37		)	—			—			(37		)
Net income	82,345			102,473			4,017			(104,651		)	84,184			24,861			69,370			5,511			(72,830		)	26,912
Allocation of net income attributable to noncontrolling interests	—			(835		)	(1,004		)	—			(1,839		)	—			(835		)	(1,216		)	—			(2,051		)
Net income attributable to the partners	$	82,345		$	101,638		$	3,013		$	(104,651	)	$	82,345		$	24,861		$	68,535		$	4,295		$	(72,830	)	$	24,861

Condensed Consolidating Statement of Comprehensive Income

Three Months Ended September 30, 2018 Parent
Guarantor
Restricted Subsidiaries
Non-Guarantor Non-Restricted Subsidiaries Eliminations Consolidated
(In thousands)
Revenues:
Affiliates $ —
$ 94,270
$ 5,918
$ —
$ 100,188
Third parties —
21,277
4,319
—
25,596
—
115,547
10,237
—
125,784
Operating costs and expenses:
Operations (exclusive of depreciation and amortization) —
32,906
3,090
—
35,996
Depreciation and amortization —
20,198
4,169
—
24,367
General and administrative 698
1,800
—
—
2,498
698
54,904
7,259
—
62,861
Operating income (loss) (698 ) 60,643
2,978
—
62,923

Other income (expense):
Equity in earnings of subsidiaries 63,731
2,251
—
(65,982 ) —
Equity in earnings of equity method investments —
1,114
—
—
1,114
Interest expense (18,030 ) (12 ) —
—
(18,042 )
Interest income —
540
—
—
540
Gain (loss) on sale of assets and other —
14
24
—
38
45,701
3,907
24
(65,982 ) (16,350 )
Income before income taxes 45,003
64,550
3,002
(65,982 ) 46,573
State income tax expense —
(39 ) —
—
(39 )
Net income 45,003
64,511
3,002
(65,982 ) 46,534
Allocation of net income attributable to noncontrolling interests —
(780 ) (751 ) —
(1,531 )
Net income attributable to the partners $ 45,003
$ 63,731
$ 2,251
$ (65,982 ) $ 45,003

~~Condensed Consolidating Statement of Comprehensive Income~~


Nine Months Ended September 30, 2019	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-restricted Subsidiaries			Eliminations			Consolidated
Three Months Ended March 31, 2019																Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)															(In thousands)
Revenues:
Affiliates	$	—		$	293,096		$	18,659		$	—		$	311,755		$	—		$	97,393		$	5,966		$	—		$	103,359
Third parties	—			69,764			19,624			—			89,388			—			22,065			9,073			—			31,138
	—			362,860			38,283			—			401,143			—			119,458			15,039			—			134,497
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			111,644			11,401			—			123,045			—			34,077			3,442			—			37,519
Depreciation and amortization	—			59,320			12,872			—			72,192						19,536			4,288			—			23,824
General and administrative	2,390			4,932			—			—			7,322			1,076			1,544			—			—			2,620
	2,390			175,896			24,273			—			202,559			1,076			55,157			7,730			—			63,963
Operating income (loss)	(2,390		)	186,964			14,010			—			198,584			(1,076		)	64,301			7,309			—			70,534

Other income (expense):
Equity in earnings (loss) of subsidiaries	238,368			10,572			—			(248,940		)	—
Equity in earnings of subsidiaries																71,299			5,496			—			(76,795		)	—
Equity in earnings of equity method investments	—			5,217			—			—			5,217			—			2,100			—			—			2,100
Interest expense	(56,982		)	(77		)	—			—			(57,059		)	(19,041		)	19			—			—			(19,022		)
Interest income	—			3,322			—			—			3,322			—			528			—			—			528
Gain on sales-type lease	—			35,166			—			—			35,166
Gain (loss) on sale of assets	221			(364		)	86			—			(57		)
Gain (loss) on sale of assets and other																—			(329		)	19			—			(310		)
	181,607			53,836			86			(248,940		)	(13,411		)	52,258			7,814			19			(76,795		)	(16,704		)
Income (loss) before income taxes	179,217			240,800			14,096			(248,940		)	185,173
Income before income taxes																51,182			72,115			7,328			(76,795		)	53,830
State income tax expense	—			(36		)	—			—			(36		)	—			(36		)	—			—			(36		)
Net income (loss)	179,217			240,764			14,096			(248,940		)	185,137
Net income																51,182			72,079			7,328			(76,795		)	53,794
Allocation of net income attributable to noncontrolling interests	—			(2,396		)	(3,524		)	—			(5,920		)	—			(780		)	(1,832		)	—			(2,612		)
Net income attributable to the partners	$	179,217		$	238,368		$	10,572		$	(248,940	)	$	179,217		$	51,182		$	71,299		$	5,496		$	(76,795	)	$	51,182

~~Condensed Consolidating Statement of Comprehensive Income~~

Nine Months Ended September 30, 2018 Parent
Guarantor
Restricted Subsidiaries
Non-Guarantor Non-Restricted Subsidiaries Eliminations Consolidated
(In thousands)
Revenues:
Affiliates $ —
$ 278,083
$ 17,546
$ —
$ 295,629
Third parties —
60,795
17,004
—
77,799
—
338,878
34,550
—
373,428
Operating costs and expenses:
Operations (exclusive of depreciation and amortization) —
97,064
9,667
—
106,731
Depreciation and amortization —
61,630
12,487
—
74,117
General and administrative 2,739
5,554
—
—
8,293
2,739
164,248
22,154
—
189,141
Operating income (loss) (2,739 ) 174,630
12,396
—
184,287

Other income (expense):
Equity in earnings (loss) of subsidiaries 187,349
9,344
—
(196,693 ) —
Equity in earnings of equity method investments —
4,127
—
—
4,127
Interest expense (53,341 ) 92
—
—
(53,249 )
Interest income —
1,581
—
—
1,581
Gain (loss) on sale of assets and other 45
(37 ) 63
—
71
134,053
15,107
63
(196,693 ) (47,470 )
Income (loss) before income taxes 131,314
189,737
12,459
(196,693 ) 136,817
State income tax expense —
(149 ) —
—
(149 )
Net income (loss) 131,314
189,588
12,459
(196,693 ) 136,668
Allocation of net income attributable to noncontrolling interests —
(2,239 ) (3,115 ) —
(5,354 )
Net income attributable to the partners $ 131,314
$ 187,349
$ 9,344
$ (196,693 ) $ 131,314

Condensed Consolidating Statement of Cash Flows


Nine Months Ended September 30, 2019	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
Three Months Ended March 31, 2020																Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)															(In thousands)
Cash flows from operating activities	$	(62,229	)	$	271,657		$	31,467		$	(12,678	)	$	228,217		$	(24,974	)	$	85,061		$	22,243		$	(4,383	)	$	77,947

Cash flows from investing activities
Additions to properties and equipment	—			(23,227		)	(601		)	—			(23,828		)	—			(5,942		)	(13,000		)	—			(18,942		)
Investment in Cushing Connect																—			(7,304		)	(2,345		)	7,304			(2,345		)
Distributions from UNEV in excess of earnings	—			10,572			—			(10,572		)	—			—			4,617			—			(4,617		)	—
Proceeds from sale of assets	—			265			—			—			265			—			417			—			—			417
Distributions in excess of equity in earnings of equity investments	—			693			—			—			693
	—			(11,697		)	(601		)	(10,572		)	(22,870		)	—			(8,212		)	(15,345		)	2,687			(20,870		)

Cash flows from financing activities
Net borrowings under credit agreement	12,500			—			—			—			12,500			45,000			—			—			—			45,000
Net intercompany financing activities	260,362			(260,362		)	—			—			—			76,196			(76,196		)	—			—			—
Redemption of senior notes																(522,500		)	—			—			—			(522,500		)
Proceeds from issuance of senior notes																500,000			—			—			—			500,000
Contribution from general partner	182			—			—			—			182			354			—			7,304			(7,304		)	354
Contribution from noncontrolling interest																—			—			7,304			—			7,304
Distributions to HEP unitholders	(204,701		)	—			—			—			(204,701		)	(68,519		)	—			—			—			(68,519		)
Distributions to noncontrolling interests	—			—			(31,000		)	23,250			(7,750		)	—			—			(12,000		)	9,000			(3,000		)
Units withheld for tax withholding obligations	(119		)	—			—			—			(119		)	(147		)	—			—			—			(147		)
Purchase units for incentive grants	(255		)	—			—			—			(255		)
Deferred financing costs																(8,478		)	—			—			—			(8,478		)
Payments on finance leases	—			(780		)	—			—			(780		)	—			(1,096		)	—			—			(1,096		)
Other	(139		)	139			—			—			—
	67,830			(261,003		)	(31,000		)	23,250			(200,923		)	21,906			(77,292		)	2,608			1,696			(51,082		)

Cash and cash equivalents
Increase (decrease) for the period	5,601			(1,043		)	(134		)	—			4,424			(3,068		)	(443		)	9,506			—			5,995
Beginning of period	2			—			3,043			—			3,045			4,790			(709		)	9,206			—			13,287
End of period	$	5,603		$	(1,043	)	$	2,909		$	—		$	7,469		$	1,722		$	(1,152	)	$	18,712		$	—		$	19,282

Condensed Consolidating Statement of Cash Flows


Nine Months Ended September 30, 2018	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
Three Months Ended March 31, 2019																Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)															(In thousands)
Cash flows from operating activities	$	(58,326	)	$	259,360		$	25,722		$	(9,344	)	$	217,412		$	(26,584	)	$	91,226		$	12,009		$	(5,496	)	$	71,155

Cash flows from investing activities
Additions to properties and equipment	—			(28,057		)	(6,213		)	—			(34,270		)	—			(10,564		)	(154		)	—			(10,718		)
Business and asset acquisitions	—			(6,803		)	(38		)	—			(6,841		)
Distributions from UNEV in excess of earnings	—			7,156			—			(7,156		)	—			—			3,504			—			(3,504		)	—
Proceeds from sale of assets	—			210			—			—			210			—			9			—			—			9
Distributions in excess of equity in earnings of equity investments	—			1,368			—			—			1,368			—			395			—			—			395
	—			(26,126		)	(6,251		)	(7,156		)	(39,533		)	—			(6,656		)	(154		)	(3,504		)	(10,314		)

Cash flows from financing activities
Net repayments under credit agreement	(91,000		)	—			—			—			(91,000		)	19,000			—			—			—			19,000
Net intercompany financing activities	231,231			(231,231		)	—			—			—			75,678			(75,678		)	—			—			—
Proceeds from issuance of common units	114,839			48			—			—			114,887
Distributions to HEP unitholders	(197,300		)	—			—			—			(197,300		)	(67,975		)	—			—			—			(67,975		)
Distributions to noncontrolling interests	—			—			(22,000		)	16,500			(5,500		)	—			—			(12,000		)	9,000			(3,000		)
Contributions from general partner	614			—			—			—			614
Units withheld for tax withholding obligations	(58		)	—			—			—			(58		)	(119		)	—			—			—			(119		)
Other	—			(923		)	—			—			(923		)
Payments on finance leases																—			(252		)	—			—			(252		)
	58,326			(232,106		)	(22,000		)	16,500			(179,280		)	26,584			(75,930		)	(12,000		)	9,000			(52,346		)

Cash and cash equivalents
Increase (decrease) for the period	—			1,128			(2,529		)	—			(1,401		)	—			8,640			(145		)	—			8,495
Beginning of period	2			511			7,263			—			7,776			2			—			3,043			—			3,045
End of period	$	2		$	1,639		$	4,734		$	—		$	6,375		$	2		$	8,640		$	2,898		$	—		$	11,540

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

This Item 2, including but not limited to the sections under “Results of Operations” and “Liquidity and Capital Resources,” contains forward-looking statements. See “Forward-Looking Statements” at the beginning of Part I of this Quarterly Report on Form 10-Q. In this document, the words “we,” “our,” “ours” and “us” refer to Holly Energy Partners, L.P. (“HEP”) and its consolidated subsidiaries or to HEP or an individual subsidiary and not to any other person.

OVERVIEW

HEP is a Delaware limited partnership. WeThrough our subsidiaries and joint ventures, we own ~~and~~and/or operate petroleum product and crude oil pipelines, terminal, tankage and loading rack facilities and refinery processing units that support the refining and marketing operations of HollyFrontier Corporation (“HFC”) and other refineries in the Mid-Continent, Southwest and Northwest regions of the United States and Delek US Holdings, Inc.’s (“Delek”) refinery in Big Spring, Texas. HEP, through its subsidiaries and joint ventures, owns and/or operates petroleum product and crude pipelines, tankage and terminals in Texas, New Mexico, Washington, Idaho, Oklahoma, Utah, Nevada, Wyoming and Kansas as well as refinery processing units in Utah and Kansas. HFC owned 57% of our outstanding common units and the non-economic general partnership interest, as of ~~September 30, 2019.~~March 31, 2020.

We generate revenues by charging tariffs for transporting petroleum products and crude oil through our pipelines, by charging fees for terminalling and storing refined products and other hydrocarbons, providing other services at our storage tanks and terminals and charging a tolling fee per barrel or thousand standard cubic feet of feedstock throughput in our refinery processing units. We do not take ownership of products that we transport, terminal, store or process, and therefore, we are not directly exposed to changes in commodity prices.

We believe the long-term growth of global refined product demand and U.S. crude production should support high utilization rates for the refineries we serve, which in turn should support volumes in our product pipelines, crude gathering systems and terminals.

~~Acquisitions~~Impact of COVID-19 on Our Business

Our business depends in large part on the demand for the various petroleum products we transport, terminal and store in the markets we serve. The impact of COVID-19 on the global macroeconomy has created unprecedented destruction of demand, as well as lack of forward visibility, for refined products and crude oil transportation, and for the terminalling and storage services that we provide. We expect a recovery of our services as demand for all of these essential products returns in the long run; however, there is little visibility on the timing for, or the extent of, this recovery in the near-term. Currently, the primary determinants of refined product and crude oil demand are the various government orders and guidance restricting and discouraging most forms of travel. For example, HFC, our largest customer, has announced that for the second quarter of 2020 it expects to run between 300,000 and 340,000 barrels per day of crude oil, which is approximately 65% to 75% of HFC refinery capacity, based on expected market demand for transportation fuels. We expect that HFC and other customers will continue to adjust refinery production levels commensurate with market demand.

In response to the COVID-19 pandemic, and with the health and safety of our employees as a top priority, we took several actions, including limiting onsite staff at all of our facilities to essential operational personnel only, implementing a work from home policy for certain employees and restricting travel unless approved by senior leadership. In addition, we took steps to sequester employees critical to the operation of our control room. We will continue to monitor COVID-19 developments and the dynamic environment to properly address these policies going forward.

In light of current circumstances and our expectations for the future, HEP has reduced its quarterly distribution to $0.35 per unit, representative of a new distribution strategy focused on funding all capital expenditures and distributions within cash flow, improving distributable cash flow coverage to 1.3x or greater and reducing leverage to 3.0-3.5x.

On March 27, 2020, the United States government passed the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”), an approximately $2 trillion stimulus package that includes various provisions intended to provide relief to individuals and businesses in the form of tax changes, loans and grants, among others. At this time, we have not sought relief in the form of loans or grants from the CARES Act; however, we have benefited from certain tax deferrals in the CARES Act and may benefit from other tax provisions if we meet the requirements to do so.

The extent to which HEP’s future results are affected by COVID-19 will depend on various factors and consequences beyond our control, such as the duration and scope of the pandemic, additional actions by businesses and governments in response to the

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pandemic and the speed and effectiveness of responses to combat the virus. However, we have long-term customer contracts with minimum volume commitments, which have expiration dates from 2021 to 2036. These minimum volume commitments accounted for approximately 70% of our total revenues in 2019. We are currently not aware of any reasons that would prevent such customers from making the minimum payments required under the contracts or potentially making payments in excess of the minimum payments. In addition to these payments, we also expect to collect payments for services provided to uncommitted shippers. However, we currently expect revenues for the second quarter to be lower than such revenues for the first quarter.

COVID-19, and the volatile regional and global economic conditions stemming from the pandemic, could also exacerbate the risk factors identified in our Annual Report on Form 10-K for the fiscal year ended December 31, 2019 and in this Form 10-Q. COVID-19 may also materially adversely affect our results in a manner that is either not currently known or that we do not currently consider to be a significant risk to our business.

See “Item 1A - Risk Factors” for other potential impacts of COVID-19 on our business.

Investment in Joint Venture

On October 2, 2019, HEP Cushing (“HEP Cushing”), a wholly-owned subsidiary of HEP, and Plains Marketing, L.P. (“PMLP”), a wholly-owned subsidiary of Plains All American Pipeline, L.P. (“Plains”), formed a 50/50 joint venture, Cushing Connect Pipeline & Terminal LLC (the ~~“Joint~~“Cushing Connect Joint Venture”), for (i) the development and construction of a new 160,000 barrel per day common carrier crude oil pipeline (the ~~“Pipeline”~~“Cushing Connect Pipeline”) that will connect the Cushing, Oklahoma crude oil hub to the Tulsa, Oklahoma refining complex owned by a subsidiary of HFC and (ii) the ownership and operation of 1.5 million barrels of crude oil storage in Cushing, Oklahoma (the ~~“JV~~“Cushing Connect JV Terminal”). The Cushing Connect JV Terminal is expected to be in service during the second quarter of 2020, and the Cushing Connect Pipeline is expected to be in service during the first quarter of 2021. Long-term commercial agreements have been entered into to support the Cushing Connect Joint Venture assets.

The Cushing Connect Joint Venture will contract with an affiliate of HEP to manage the construction and operation of the Cushing Connect Pipeline and with an affiliate of Plains to manage the operation of the Cushing Connect JV Terminal. The total Cushing Connect Joint Venture investment will be shared proportionately among the partners, and HEP estimates its share of the cost of the Cushing Connect JV Terminal contributed by Plains and Cushing Connect Pipeline construction costs ~~are~~will be approximately $65 million.

Agreements with HFC ~~and Delek~~

We serve HFC’s refineries under long-term pipeline, terminal, tankage and refinery processing unit throughput agreements expiring from 2021 to 2036. Under these agreements, HFC agrees to transport, store and process throughput volumes of refined product, crude oil and feedstocks on our pipelines, terminal, tankage, and loading rack facilities and refinery processing units that result in minimum annual payments to us. These minimum annual payments or revenues are subject to annual rate adjustments on July 1st each year, based on the Producer Price Index (“PPI”) or Federal Energy Regulatory Commission index. As of ~~September 30, 2019,~~March 31, 2020, these agreements with HFC require minimum annualized payments to us of ~~$349~~$348.2 million.

If HFC fails to meet its minimum volume commitments under the agreements in any quarter, it will be required to pay us the amount of any shortfall in cash by the last day of the month following the end of the quarter. Under certain of the agreements, a shortfall payment may be applied as a credit in the following four quarters after minimum obligations are met.

A significant reduction in revenues under these agreements could have a material adverse effect on our results of operations.

~~Table of Contentsril 19,~~

We have a pipelines and terminals agreement with Delek expiring in 2020 under which Delek has agreed to transport on our pipelines and throughput through our terminals volumes of refined products that result in a minimum level of annual revenue that is also subject to annual tariff rate adjustments. On September 30, 2019, Delek exercised its first renewal option (the “Renewal”) under this agreement for an additional five year period beginning April 1, 2020, but only with respect to specific assets. For the refined product pipelines and refined product terminals that were not subject to the Renewal and which currently account for approximately half of HEP’s annual revenues and distributable cash flows from Delek, the agreement terminates as of March 31, 2020. In light of this development, we will explore other potential options with respect to the pipeline and terminal assets that were not subject to the Renewal.

We also have a capacity lease agreement under which we lease space to Delek on our Orla to El Paso pipeline for the shipment of refined product. The terms for a portion of the capacity under this lease agreement expired in 2018 and were not renewed, and the remaining portions of the capacity expire in 2020 and 2022. As of September 30, 2019, these agreements with Delek require minimum annualized payments to us of $32 million.

Under certain provisions of an omnibus agreement we have with HFC (the “Omnibus Agreement”), we pay HFC an annual administrative fee, currently $2.6 million, for the provision by HFC or its affiliates of various general and administrative services to us. This fee does not include the salaries of personnel employed by HFC who perform services for us on behalf of Holly Logistic Services, L.L.C. (“HLS”), or the cost of their employee benefits, which are separately charged to us by HFC. We also reimburse HFC and its affiliates for direct expenses they incur on our behalf.

Under HLS’s Secondment Agreement with HFC, certain employees of HFC are seconded to HLS to provide operational and maintenance services for certain of our processing, refining, pipeline and tankage assets, and HLS reimburses HFC for its prorated portion of the wages, benefits, and other costs of these employees for our benefit.

We have a long-term strategic relationship with ~~HFC.~~HFC that has historically facilitated our growth. Our ~~current~~future growth ~~plan is~~plans include organic projects around our existing assets and select investments or acquisitions that enhance our service platform while creating accretion for our unitholders. While in the near term, any acquisitions would be subject to ~~continue~~economic conditions discussed in “Overview” above, we also expect over the longer term to ~~pursue purchases of logistic and other assets at HFC’s existing refining locations in New Mexico, Utah, Oklahoma, Kansas and Wyoming. We also expect~~continue to work with HFC on logistic asset acquisitions in conjunction with HFC’s refinery acquisition strategies.

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Furthermore, we plan to continue to pursue third-party logistic asset acquisitions that are accretive to our unitholders and increase the diversity of our revenues.

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RESULTS OF OPERATIONS (Unaudited)

Income, Distributable Cash Flow, Volumes and Balance Sheet Data

The following tables present income, distributable cash flow and volume information for the three ~~and the nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018.~~2019.


	Three Months Ended September 30,						Change from			Three Months Ended March 31,						Change from
	2019			2018			2018			2020			2019			2019
	(In thousands, except per unit data)									(In thousands, except per unit data)
Revenues:
Pipelines:
Affiliates—refined product pipelines	$	19,401		$	20,803		$	(1,402	)	$	20,083		$	20,732		$	(649	)
Affiliates—intermediate pipelines	7,490			6,772			718			7,474			7,281			193
Affiliates—crude pipelines	21,675			20,461			1,214			20,393			21,121			(728		)
	48,566			48,036			530			47,950			49,134			(1,184		)
Third parties—refined product pipelines	13,270			11,194			2,076			14,798			15,604			(806		)
Third parties—crude pipelines	11,327			10,505			822			7,724			10,362			(2,638		)
	73,163			69,735			3,428			70,472			75,100			(4,628		)
Terminals, tanks and loading racks:
Affiliates	37,183			32,572			4,611			33,594			32,406			1,188
Third parties	5,271			3,897			1,374			3,904			5,172			(1,268		)
	42,454			36,469			5,985			37,498			37,578			(80		)

Affiliates—refinery processing units	20,278			19,580			698			19,884			21,819			(1,935		)

Total revenues	135,895			125,784			10,111			127,854			134,497			(6,643		)
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	44,924			35,996			8,928			34,981			37,519			(2,538		)
Depreciation and amortization	24,121			24,367			(246		)	23,978			23,824			154
General and administrative	2,714			2,498			216			2,702			2,620			82
	71,759			62,861			8,898			61,661			63,963			(2,302		)
Operating income	64,136			62,923			1,213			66,193			70,534			(4,341		)
Other income (expense):
Equity in earnings of equity method investments	1,334			1,114			220			1,714			2,100			(386		)
Interest expense, including amortization	(18,807		)	(18,042		)	(765		)	(17,767		)	(19,022		)	1,255
Interest income	2,243			540			1,703			2,218			528			1,690
Gain on sales-type leases	35,166			—			35,166
Gain (loss) on sale of assets and other	142			38			104
Loss on early extinguishment of debt										(25,915		)	—			(25,915		)
Gain on sale of assets and other										506			(310		)	816
	20,078			(16,350		)	36,428			(39,244		)	(16,704		)	(22,540		)
Income before income taxes	84,214			46,573			37,641			26,949			53,830			(26,881		)
State income tax benefit (expense)	(30		)	(39		)	9
State income tax expense										(37		)	(36		)	(1		)
Net income	84,184			46,534			37,650			26,912			53,794			(26,882		)
Allocation of net income attributable to noncontrolling interests	(1,839		)	(1,531		)	(308		)	(2,051		)	(2,612		)	561
Net income attributable to the partners	82,345			45,003			37,342			24,861			51,182			(26,321		)
Limited partners’ earnings per unit—basic and diluted	$	0.78		$	0.43		$	0.35		$	0.24		$	0.49		$	(0.25	)
Weighted average limited partners’ units outstanding	105,440			105,440			—			105,440			105,440			—
EBITDA ⁽¹⁾	$	123,060		$	86,911		$	36,149		$	64,425		$	93,536		$	(29,111	)
Adjusted EBITDA ⁽¹⁾	$	90,269		$	86,911		$	3,358		$	91,109		$	93,536		$	(2,427	)
Distributable cash flow ⁽²⁾	$	68,838		$	66,598		$	2,240		$	70,708		$	70,599		$	109

Volumes (bpd)
Pipelines:
Affiliates—refined product pipelines	129,681			120,024			9,657			129,966			130,807			(841		)
Affiliates—intermediate pipelines	153,547			148,347			5,200			142,112			130,830			11,282
Affiliates—crude pipelines	358,867			322,590			36,277			305,031			400,797			(95,766		)
	642,095			590,961			51,134			577,109			662,434			(85,325		)
Third parties—refined product pipelines	67,440			67,112			328			49,637			81,064			(31,427		)
Third parties—crude pipelines	129,222			119,503			9,719			92,203			126,496			(34,293		)
	838,757			777,576			61,181			718,949			869,994			(151,045		)
Terminals and loading racks:
Affiliates	482,291			417,079			65,212			429,730			373,912			55,818
Third parties	59,307			57,990			1,317			45,945			68,765			(22,820		)
	541,598			475,069			66,529			475,675			442,677			32,998

Affiliates—refinery processing units	75,857			65,640			10,217			69,795			65,837			3,958

Total for pipelines and terminal and refinery processing unit assets (bpd)	1,456,212			1,318,285			137,927			1,264,419			1,378,508			(114,089		)

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Nine Months Ended September 30, Change from
2019 2018 2018
(In thousands, except per unit data)
Revenues:
Pipelines:
Affiliates—refined product pipelines $ 60,892
$ 60,841
$ 51
Affiliates—intermediate pipelines 22,068
22,496
(428 )
Affiliates—crude pipelines 63,447
58,737
4,710
146,407
142,074
4,333
Third parties—refined product pipelines 40,652
37,124
3,528
Third parties—crude pipelines 33,467
28,245
5,222
220,526
207,443
13,083
Terminals, tanks and loading racks:
Affiliates 103,852
96,606
7,246
Third parties 15,269
12,430
2,839
119,121
109,036
10,085

Affiliates—refinery processing units 61,496
56,949
4,547

Total revenues 401,143
373,428
27,715
Operating costs and expenses:
Operations (exclusive of depreciation and amortization) 123,045
106,731
16,314
Depreciation and amortization 72,192
74,117
(1,925 )
General and administrative 7,322
8,293
(971 )
202,559
189,141
13,418
Operating income 198,584
184,287
14,297
Other income (expense):
Equity in earnings of equity method investments 5,217
4,127
1,090
Interest expense, including amortization (57,059 ) (53,249 ) (3,810 )
Interest income 3,322
1,581
1,741
Gain on sales-type leases 35,166
—
35,166
Gain (loss) on sale of assets and other (57 ) 71
(128 )
(13,411 ) (47,470 ) 34,059
Income before income taxes 185,173
136,817
48,356
State income tax expense (36 ) (149 ) 113
Net income 185,137
136,668
48,469
Allocation of net income attributable to noncontrolling interests (5,920 ) (5,354 ) (566 )
Net income attributable to the partners 179,217
131,314
47,903
Limited partners’ earnings per unit—basic and diluted $ 1.70
$ 1.25
$ 0.45
Weighted average limited partners’ units outstanding 105,440
104,908
532
EBITDA ⁽¹⁾
$ 305,182
$ 257,248
$ 47,934
Adjusted EBITDA ⁽¹⁾
$ 272,391
$ 257,248
$ 15,143
Distributable cash flow ⁽²⁾
$ 206,923
$ 200,878
$ 6,045

Volumes (bpd)
Pipelines:
Affiliates—refined product pipelines 130,426
125,642
4,784
Affiliates—intermediate pipelines 141,991
142,371
(380 )
Affiliates—crude pipelines 376,518
336,224
40,294
648,935
604,237
44,698
Third parties—refined product pipelines 71,773
70,830
943
Third parties—crude pipelines 132,101
119,344
12,757
852,809
794,411
58,398
Terminals and loading racks:
Affiliates 429,660
418,009
11,651
Third parties 62,437
59,776
2,661
492,097
477,785
14,312

Affiliates—refinery processing units 73,178
67,873
5,305

Total for pipelines and terminal and refinery processing unit assets (bpd) 1,418,084
1,340,069
78,015

~~Table of Contentsril 19,~~

(1)

Earnings before interest, taxes, depreciation and amortization (“EBITDA”) is calculated as net income attributable to the partners plus (i) interest expense, net of interest income, (ii) state income tax expense and (iii) depreciation and amortization. Adjusted EBITDA is calculated as EBITDA ~~minus gain~~plus (i) loss on ~~sales-type leases plus~~early extinguishment of debt and (ii) pipeline tariffs not included in revenues due to impacts from lease accounting for certain pipeline ~~tariffs.~~tariffs minus (iii) pipeline lease payments not included in operating costs and expenses. Portions of our minimum guaranteed pipeline tariffs for assets subject to sales-type lease accounting are recorded as interest income with the remaining amounts recorded as a reduction in net investment in leases. These pipeline tariffs were previously recorded as revenues prior to the ~~adoption~~renewal of ~~ASU No. 2016-02, "Leases".~~the throughput agreement, which triggered sales-type lease accounting. Similarly, certain pipeline lease payments were previously recorded as operating costs and expenses, but the underlying lease was reclassified from an operating lease to a financing lease, and these payments are now recoded as interest expense and reductions in the lease liability. EBITDA and Adjusted EBITDA are not calculations based upon generally accepted accounting principles ("GAAP"). However, the amounts included in the EBITDA and Adjusted EBITDA calculations are derived from amounts included in our consolidated financial statements. EBITDA and Adjusted EBITDA should not be considered as alternatives to net income attributable to Holly Energy Partners or operating income, as indications of our operating performance or as alternatives to operating cash flow as a measure of liquidity. EBITDA and Adjusted EBITDA are not necessarily comparable to similarly titled measures of other companies. EBITDA and Adjusted EBITDA are presented here because they are widely used financial indicators used by investors and analysts to measure performance. EBITDA and Adjusted EBITDA are also used by our management for internal analysis and as a basis for compliance with financial covenants. Set forth below are our calculations of EBITDA and Adjusted EBITDA.


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
	(In thousands)												(In thousands)
Net income attributable to the partners	$	82,345		$	45,003		$	179,217		$	131,314		$	24,861		$	51,182
Add (subtract):
Interest expense	18,807			18,042			57,059			53,249			17,767			19,022
Interest income	(2,243		)	(540		)	(3,322		)	(1,581		)	(2,218		)	(528		)
State income tax expense	30			39			36			149			37			36
Depreciation and amortization	24,121			24,367			72,192			74,117			23,978			23,824
EBITDA	$	123,060		$	86,911		$	305,182		$	257,248		$	64,425		$	93,536
Gain on sales-type leases	(35,166		)	—			(35,166		)	—
Loss on early extinguishment of debt													25,915			—
Pipeline tariffs not included in revenues	2,375			—			2,375			—			2,375			—
Lease payments not included in operating costs													(1,606		)	—
Adjusted EBITDA	$	90,269		$	86,911		$	272,391		$	257,248		$	91,109		$	93,536

(2)

Distributable cash flow is not a calculation based upon GAAP. However, the amounts included in the calculation are derived from amounts presented in our consolidated financial statements, with the general exceptions of maintenance capital expenditures. Distributable cash flow should not be considered in isolation or as an alternative to net income or operating income as an indication of our operating performance or as an alternative to operating cash flow as a measure of liquidity. Distributable cash flow is not necessarily comparable to similarly titled measures of other companies. Distributable cash flow is presented here because it is a widely accepted financial indicator used by investors to compare partnership performance. It is also used by management for internal analysis and for our performance units. We believe that this measure provides investors an enhanced perspective of the operating performance of our assets and the cash our business is generating. Set forth below is our calculation of distributable cash flow.

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	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
	(In thousands)												(In thousands)
Net income attributable to the partners	$	82,345		$	45,003		$	179,217		$	131,314		$	24,861		$	51,182
Add (subtract):
Depreciation and amortization	24,121			24,367			72,192			74,117			23,978			23,824
Amortization of discount and deferred debt issuance costs	771			762			2,307			2,278			799			766
Loss on early extinguishment of debt													25,915			—
Revenue recognized (greater) less than customer billings	504			1,294			(2,827		)	2,994			264			(3,034		)
Maintenance capital expenditures⁽³⁾	(2,118		)	(3,198		)	(3,477		)	(4,504		)	(2,487		)	(735		)
Increase (decrease) in environmental liability	91			(150		)	(464		)	(368		)	1			(278		)
Decrease in reimbursable deferred revenue	(1,964		)	(1,517		)	(5,604		)	(3,937		)	(2,800		)	(1,579		)
Gain on sales-type leases	(35,166		)	—			(35,166		)	—
Other	254			37			745			(1,016		)	177			453
Distributable cash flow	$	68,838		$	66,598		$	206,923		$	200,878		$	70,708		$	70,599


(3)	Maintenance capital expenditures are capital expenditures made to replace partially or fully depreciated assets in order to maintain the existing operating capacity of our assets and to extend their useful lives. Maintenance capital expenditures include expenditures required to maintain equipment reliability, tankage and pipeline integrity, safety and to address environmental regulations.


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
	(In thousands)				(In thousands)
Balance Sheet Data
Cash and cash equivalents	$	7,469	$	3,045	$	19,282	$	13,287
Working capital	$	10,762	$	8,577	$	26,182	$	20,758
Total assets	$	2,154,275	$	2,102,540	$	2,188,284	$	2,199,232
Long-term debt	$	1,431,869	$	1,418,900	$	1,502,154	$	1,462,031
Partners’ equity ⁽⁴⁾	$	404,584	$	427,435	$	338,159	$	381,103

(4)

As a master limited partnership, we distribute our available cash, which historically has exceeded our net income attributable to the partners because depreciation and amortization expense represents a non-cash charge against income. The result is a decline in partners’ equity since our regular quarterly distributions have exceeded our quarterly net income attributable to the partners. Additionally, if the assets contributed and acquired from HFC while we were a consolidated variable interest entity of HFC had been acquired from third parties, our acquisition cost in excess of HFC’s basis in the transferred assets would have been recorded in our financial statements as increases to our properties and equipment and intangible assets at the time of acquisition instead of decreases to partners’ equity.

Results of Operations—Three Months Ended ~~September 30, 2019~~March 31, 2020 Compared with Three Months Ended ~~September 30, 2018~~March 31, 2019

Summary

Net income attributable to the partners for the ~~third~~first quarter was ~~$82.3~~$24.9 million ($~~0.78~~0.24 per basic and diluted limited partner unit) compared to ~~$45.0~~$51.2 million ($~~0.43~~0.49 per basic and diluted limited partner unit) for the ~~third~~first quarter of ~~2018. During~~2019. The decrease in earnings is primarily due to a charge of $25.9 million related to the ~~third quarter~~early redemption of ~~2019, HEP and HFC renewed~~our previously outstanding $500 million aggregate principal amount of 6% senior notes, due in 2024. Excluding the ~~original throughput agreement~~loss on ~~specific HEP assets. Portions~~early extinguishment of the new throughput agreement meet the definition of sales-type leases, which resulted in an accounting gain of $35.2 million upon the initial recognition of the sales-type leases during the third quarter. Excluding this gain,debt, net income attributable to ~~Holly Energy Partners~~the partners for the first quarter ~~was $47.2~~would have been $50.8 million ($~~0.45~~0.48 per basic and diluted limited partner unit), an increase of $2.2 million compared to the same period of 2018. The increase in net income attributable to HEP was mainly due to strong third-party volumes on our UNEV pipeline, higher spot revenues on our crude oil pipeline systems in Wyoming and Utah and stronger terminal and tank volumes at El Dorado and Tulsa. These gains were partially offset by higher operating costs and interest expense.

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Revenues

Revenues for the ~~third~~first quarter were ~~$135.9~~$127.9 million, ~~an increase~~a decrease of ~~$10.1~~$6.6 million compared to the ~~third~~first quarter of ~~2018.~~2019. The ~~increase~~decrease was mainly attributable to ~~higher~~lower pipeline volumes on our UNEV pipeline and our crude pipeline systems in Wyoming and Utah, which contributed to ~~an increase~~a decrease in overall pipeline volumes of 8%17%. ~~Along with higher volumes through~~In addition, revenues on our refinery ~~tankage and terminals, contractual tariff escalators across our assets also led~~processing units were higher in the first quarter of 2019 mainly due to an ~~increase~~adjustment in ~~revenues year over year.~~revenue recognition recorded in that quarter.

Revenues from our refined product pipelines were ~~$32.7~~$34.9 million, ~~an increase~~a decrease of ~~$0.7~~$1.5 million compared to the ~~third~~first quarter of ~~2018, due to higher throughput and contractual tariff escalators.~~2019. Shipments averaged ~~197.1~~179.6 thousand barrels per day (“mbpd”) compared to ~~187.1~~211.9 mbpd for the ~~third~~first quarter of ~~2018.~~2019. The

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volume ~~increase~~decrease was mainly due to ~~higher~~lower volumes on pipelines servicing Delek's Big Spring refinery and our UNEV pipeline. The decrease in revenue was mainly due to the recording of certain pipeline tariffs as interest income as the related throughput contract renewal was determined to be a sales-type lease and lower volumes on our UNEV pipeline ~~and~~partially offset by higher revenues on product pipelines servicing HFC's Navajo refinery.

Revenues from our intermediate pipelines were $7.5 million, an increase of ~~$0.7~~$0.2 million compared to the ~~third~~first quarter of ~~2018,~~2019, due to higher throughput and contractual tariff escalators. Shipments averaged ~~153.5~~142.1 mbpd for the ~~third~~first quarter of 2019 compared to ~~148.3~~130.8 mbpd for the ~~third~~first quarter of ~~2018.~~2019. The increase in volumes was mainly due to higher throughputs on our intermediate pipelines servicing HollyFrontier's Tulsa refinery.

Revenues from our crude pipelines were ~~$33.0~~$28.1 million, ~~an increase~~a decrease of ~~$2.0~~$3.4 million compared to the ~~third~~first quarter of ~~2018,~~2019, and shipments averaged ~~488.1~~397.2 mbpd compared to ~~442.1~~527.3 mbpd for the ~~third~~first quarter of ~~2018.~~2019. The ~~increases~~decreases were mainly attributable to ~~increased~~decreased volumes on our crude pipeline systems in New Mexico and Texas and on our crude pipeline systems in Wyoming and ~~Utah, as well as contractual tariff escalators.~~Utah.

Revenues from terminal, tankage and loading rack fees were ~~$42.5~~$37.5 million, ~~an increase~~a decrease of ~~$6.0~~$0.1 million compared to the ~~third~~first quarter of ~~2018.~~2019. Refined products and crude oil terminalled in the facilities averaged ~~541.6~~475.7 mbpd compared to ~~475.1~~442.7 mbpd for the ~~third~~first quarter of ~~2018.~~2019. The ~~revenue and~~ volume ~~increases were~~increase was mainly due to higher volumes at HFC's Tulsa and El Dorado refineries, our new Orla diesel rack and our Catoosa ~~Las Vegas and Spokane terminals.~~terminal while revenue remained constant mainly due to contractual minimum volume guarantees.

Revenues from refinery processing units were ~~$20.3~~$19.9 million, ~~an increase~~a decrease of ~~$0.7~~$1.9 million compared to the ~~third~~first quarter of ~~2018,~~2019, and throughputs averaged ~~75.9~~69.8 mbpd compared to ~~65.6~~65.8 mbpd for the ~~third~~first quarter of ~~2018. The increase~~2019. Revenues were higher in the first quarter of 2019 primarily due to an adjustment in revenue ~~was mainly due to contractual rate increases.~~recognition recorded in that quarter.

Operations Expense

Operations (exclusive of depreciation and amortization) expense was ~~$44.9~~$35.0 million for the three months ended ~~September 30, 2019, an increase~~March 31, 2020, a decrease of ~~$8.9~~$2.5 million compared to the ~~third~~first quarter of ~~2018.~~2019. The ~~increase~~decrease was mainly due to ~~higher employee compensation expenses,~~lower rental and maintenance costs ~~and property taxes~~ for the three months ended ~~September 30, 2019.~~March 31, 2020.

Depreciation and Amortization

Depreciation and amortization for the three months ended ~~September 30, 2019, decreased~~March 31, 2020 increased by $0.2 million compared to the three months ended ~~September 30, 2018.~~March 31, 2019.

General and Administrative

General and administrative costs for the three months ended ~~September 30, 2019,~~March 31, 2020 increased by ~~$0.2~~$0.1 million compared to the three months ended ~~September 30, 2018,~~March 31, 2019, mainly due to higher legal expenses for the three months ended ~~September 30, 2019.~~March 31, 2020.

Equity in Earnings of Equity Method Investments


	Three Months Ended September 30,				Three Months Ended March 31,
Equity Method Investment	2019		2018		2020			2019
	(in thousands)				(in thousands)
Osage Pipe Line Company, LLC	$	606	$	294	$	1,014		$	505
Cheyenne Pipeline LLC	728		820		1,075			1,595
Cushing Terminal					(375		)	—
Total	$	1,334	$	1,114	$	1,714		$	2,100

Equity in earnings of Osage Pipe Line Company, LLC increased for the three months ended ~~September 30, 2019,~~March 31, 2020, mainly due to ~~higher crude throughput volumes and lower maintenance project expenses.~~an insurance claim settlement related to a prior year environmental cleanup.

Interest Expense

Interest expense for the three months ended ~~September 30, 2019,~~March 31, 2020, totaled ~~$18.8~~$17.8 million, ~~an increase~~a decrease of ~~$0.8~~$1.3 million compared to the three months ended ~~September 30, 2018.~~March 31, 2019. The ~~increase~~decrease was ~~primarily~~mainly due to market interest ~~expense associated~~rate decreases under our senior secured revolving credit facility and refinancing our $500 million 6% Senior Notes with ~~higher average~~$500 million 5% Senior Notes. Our aggregate effective interest rates were 4.5% and 5.3% for the three months ended March 31, 2020 and 2019, respectively.

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balances outstanding under the Credit Agreement (as defined below) and market interest rate increases under that facility. Our aggregate effective interest rates were 5.2% and 5.1% for the three months ended September 30, 2019 and 2018, respectively.

State Income Tax

We recorded a state income tax expense of ~~$30,000~~$37,000 and ~~$39,000~~$36,000 for the three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018, respectively. All tax expense is solely attributable to the Texas margin tax.~~

~~Results of Operations—Nine Months Ended September 30, 2019 Compared with Nine Months Ended September 30, 2018~~

~~Summary~~

Net income attributable to the partners for the nine months ended September 30, 2019, was $179.2 million compared to $131.3 million for the nine months ended September 30, 2018. The increase in earnings was primarily due to the gain on sales-type leases as well as higher crude oil pipeline volumes around the Permian Basin and our crude pipeline systems in Wyoming and Utah, higher revenues on our refinery processing units and contractual tariff escalators. These gains were partially offset by higher operating costs and interest expense.

~~Revenues~~

Revenues for the nine months ended September 30, 2019, were $401.1 million, an increase of $27.7 million compared to the nine months ended September 30, 2018. The increase was mainly attributable to higher crude oil pipeline volumes around the Permian Basin and our crude pipeline systems in Wyoming and Utah, higher revenues on our refinery processing units, and contractual tariff escalators.

~~Revenues from our~~ ~~refined product pipelines~~ were $101.5 million, an increase of $3.6 million compared to the nine months ended September 30, 2018. Shipments averaged 202.2 mbpd compared to 196.5 mbpd for the nine months ended September 30, 2018. The volume and revenue increases were mainly due to higher Delek volumes, higher volumes on pipelines servicing HFC's Woods Cross refinery, which had lower throughput in 2018 due to operational issues, and contractual tariff escalators.

~~Revenues from our~~ ~~intermediate pipelines~~ were $22.1 million, a decrease of $0.4 million compared to the nine months ended September 30, 2018. Shipments averaged 142.0 mbpd compared to 142.4 mbpd for the nine months ended September 30, 2018. The decrease in revenue was primarily attributable to a decrease in deferred revenue realized.

~~Revenues from our~~ ~~crude pipelines~~ were $96.9 million, an increase of $9.9 million compared to the nine months ended September 30, 2018. Shipments averaged 508.6 mbpd compared to 455.6 mbpd for the nine months ended September 30, 2018. The increases were mainly attributable to increased volumes on our crude pipeline systems in New Mexico and Texas and on our crude pipeline systems in Wyoming and Utah as well as contractual tariff escalators.

~~Revenues from~~ ~~terminal, tankage and loading rack~~ fees were $119.1 million, an increase of $10.1 million compared to the nine months ended September 30, 2018. Refined products and crude oil terminalled in the facilities averaged 492.1 mbpd compared to 477.8 mbpd for the nine months ended September 30, 2018. The revenue and volume increases were mainly due to volumes at our new Orla diesel rack and higher volumes at the Spokane and Catoosa terminals, partially offset by lower volumes at HFC's Tulsa refinery as a result of the planned turnaround in the first quarter and flooding in the second quarter.

~~Revenues from~~ ~~refinery processing units~~ were $61.5 million, an increase of $4.5 million compared to the nine months ended September 30, 2018. Throughputs averaged 73.2 mbpd compared to 67.9 mbpd for the nine months ended September 30, 2018. The increase in revenue was mainly due to an adjustment in revenue recognition and contractual rate increases.

~~Operations Expense~~

Operations expense (exclusive of depreciation and amortization) for the nine months ended September 30, 2019, increased by $16.3 million compared to the nine months ended September 30, 2018. The increase was mainly due to higher employee compensation expenses, maintenance costs and property taxes.

~~Depreciation and Amortization~~

Depreciation and amortization for the nine months ended September 30, 2019, decreased by $1.9 million compared to the nine months ended September 30, 2018. The decrease was primarily due to lower amortization of intangible assets and asset retirement obligations.

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~~General and Administrative~~

General and administrative costs for the nine months ended September 30, 2019, decreased $1.0 million compared to the nine months ended September 30, 2018, mainly due to lower employee compensation and consulting costs incurred in the nine months ended September 30, 2019.

~~Equity in Earnings of Equity Method Investments~~

Nine Months Ended September 30,
Equity Method Investments 2019 2018
(in thousands)
Osage Pipe Line Company, LLC $ 1,857
$ 1,895
Cheyenne Pipeline LLC 3,360
2,232
Total $ 5,217
$ 4,127

~~Equity in earnings of Cheyenne Pipeline LLC increased for the nine months ended September 30, 2019, mainly due to higher crude throughput volumes.~~

~~Interest Expense~~

Interest expense for the nine months ended September 30, 2019, totaled $57.1 million, an increase of $3.8 million compared to the nine months ended September 30, 2018. The increase is primarily due to higher average balances outstanding under our Credit Agreement, and market interest rate increases under that facility. Our aggregate effective interest rates were 5.3% and 5.0% for the nine months ended September 30, 2019 and 2018, respectively.

~~State Income Tax~~

~~We recorded state income tax expense of $36,000 and $149,000 for the nine months ended September 30, 2019 and 2018,~~ respectively. All tax expense is solely attributable to the Texas margin tax.

LIQUIDITY AND CAPITAL RESOURCES

Overview

During the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, we received advances totaling ~~$269.5~~$112.0 million and repaid ~~$257.0~~$67.0 million, resulting in a net increase of ~~$12.5~~$45.0 million under the Credit Agreement and an outstanding balance of ~~$935.5~~$1,010.5 million at ~~September 30, 2019.~~March 31, 2020. As of ~~September 30, 2019,~~March 31, 2020, we have no letters of credit outstanding under the Credit Agreement and the available capacity under the Credit Agreement was ~~$464.5~~$389.5 million. Amounts repaid under the Credit Agreement may be reborrowed from time to time.

If any particular lender under the Credit Agreement could not honor its commitment, we believe the unused capacity that would be available from the remaining lenders would be sufficient to meet our borrowing needs. Additionally, we review publicly available information on the lenders in order to monitor their financial stability and assess their ongoing ability to honor their commitments under the Credit Agreement. We do not expect to experience any difficulty in the lenders’ ability to honor their respective commitments, and if it were to become necessary, we believe there would be alternative lenders or options available.

On ~~January 25, 2018,~~February 4, 2020, we ~~entered into a common unit purchase agreement in which certain purchasers agreed to purchase in~~closed a private placement ~~3,700,000 common units representing limited partnership interests,~~of $500 million in aggregate principal amount of 5% senior unsecured notes due in 2028 (the "5% Senior Notes"). On February 5, 2020, we redeemed the existing $500 million 6% Senior Notes at a ~~price~~redemption cost of ~~$29.73 per common unit. The private placement closed on February 6, 2018,~~$522.5 million, at which time we recognized a $25.9 million early extinguishment loss consisting of a $22.5 million debt redemption premium and ~~we received~~unamortized financing costs of $3.4 million. We funded the $522.5 million redemption with proceeds from the issuance of ~~approximately $110 million, which were used to repay indebtedness~~our 5% Senior Notes and borrowings under ~~the~~our Credit Agreement.

We have a continuous offering program under which we may issue and sell common units from time to time, representing limited partner interests, up to an aggregate gross sales amount of $200 million. We did not issue any units under this program during the ~~nine~~three months ended ~~September 30, 2019. We intend to use the net proceeds for general partnership purposes, which may include funding working capital, repayment of debt, acquisitions and capital expenditures.~~March 31, 2020. As of ~~September 30, 2019,~~March 31, 2020, HEP has issued 2,413,153 units under this program, providing $82.3 million in gross proceeds.

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Under our registration statement filed with the Securities and Exchange Commission (“SEC”) using a “shelf” registration process, we currently have the authority to raise up to $2.0 billion by offering securities, through one or more prospectus supplements that would describe, among other things, the specific amounts, prices and terms of any securities offered and how the proceeds would be used. Any proceeds from the sale of securities would be used for general business purposes, which may include, among other things, funding acquisitions of assets or businesses, working capital, capital expenditures, investments in subsidiaries, the retirement of existing debt and/or the repurchase of common units or other securities.

~~In March 2019, we repurchased 8,674 common units in the open market for the issuance and settlement of unit awards under our Long-Term Incentive Plan, for an aggregate purchase price of $0.3 million.~~

We believe our current cash balances, future internally generated funds and funds available under the Credit Agreement will provide sufficient resources to meet our working capital liquidity needs for the foreseeable future.

In ~~August 2019,~~February 2020, we paid a regular cash distribution of $0.6725 on all units in an aggregate amount of $68.5 million after deducting HEP Logistics' waiver of $2.5 million of limited partner cash distributions. As noted above, we have reduced our quarterly distribution to $0.35 per unit commencing with the distribution payable on May 14, 2020.

Cash and cash equivalents increased by ~~$4.4~~$6.0 million during the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020. The cash flows provided by operating activities of ~~$228.2~~$77.9 million were more than the cash flows used for financing activities of ~~$200.9~~$51.1 million and investing activities of ~~$22.9~~$20.9 million. Working capital increased by ~~$2.2~~$5.4 million to ~~$10.8~~$26.2 million at ~~September 30, 2019,~~March 31, 2020, from ~~$8.6~~$20.8 million at December 31, ~~2018.~~2019.

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Cash Flows—Operating Activities

Cash flows from operating activities increased by ~~$10.8~~$6.8 million from ~~$217.4~~$71.2 million for the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, to ~~$228.2~~$77.9 million for the ~~nine~~three months ended ~~September 30, 2019.~~March 31, 2020. The increase was mainly due to ~~increased receipts from customers during the nine months ended September 30, 2019, as compared to the nine months ended September 30, 2018, partially offset by higher~~lower payments for operating and interest ~~expenses.~~expenses during the three months ended March 31, 2020, as compared to the three months ended March 31, 2019.

Cash Flows—Investing Activities

Cash flows used for investing activities were ~~$22.9~~$20.9 million for the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, compared to ~~$39.5~~$10.3 million for the ~~nine~~three months ended ~~September 30, 2018, a decrease~~March 31, 2019, an increase of ~~$16.7~~$10.6 million. During the ~~nine~~three months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ we invested ~~$23.8~~$18.9 million and ~~$34.3~~$10.7 million in additions to properties and equipment, respectively. During the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2020, we ~~had cash payments of $6.8~~invested $2.3 million ~~for acquisitions.~~in our equity method investment in Cushing Connect JV Terminal. We ~~also~~ received ~~$0.7 million and $1.4 million for~~no distributions in excess of equity in earnings ~~of equity investments~~ during the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 and ~~2018, respectively.~~$0.4 million during the three months ended March 31, 2019.

Cash Flows—Financing Activities

Cash flows used for financing activities were ~~$200.9~~$51.1 million for the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, compared to ~~$179.3~~$52.3 million for the ~~nine~~three months ended ~~September 30, 2018, an increase~~March 31, 2019, a decrease of ~~$21.6~~$1.3 million. During the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, we received ~~$269.5~~$112.0 million and repaid ~~$257.0~~$67.0 million in advances under the Credit Agreement. Additionally, we paid ~~$204.7~~$68.5 million in regular quarterly cash distributions to our limited partners and ~~$7.8~~$3.0 million to our noncontrolling interest. We also received net proceeds of $491.5 million for issuance of our 5% Senior Notes and paid $522.5 million to retire our 6% Senior Notes. During the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, we received ~~$256.0~~$104.0 million and repaid ~~$347.0~~$85.0 million in advances under the Credit Agreement. We paid ~~$197.3~~$68.0 million in regular quarterly cash distributions to our limited partners, and distributed ~~$5.5~~$3.0 million to our noncontrolling interest. ~~We also received net proceeds of $114.9 million from the issuance of common units during the nine months ended September 30, 2018.~~

Capital Requirements

Our pipeline and terminalling operations are capital intensive, requiring investments to maintain, expand, upgrade or enhance existing operations and to meet environmental and operational regulations. Our capital requirements have consisted of, and are expected to continue to consist of, maintenance capital expenditures and expansion capital expenditures. “Maintenance capital expenditures” represent capital expenditures to replace partially or fully depreciated assets to maintain the operating capacity of existing assets. Maintenance capital expenditures include expenditures required to maintain equipment reliability, tankage and pipeline integrity, safety and to address environmental regulations. “Expansion capital expenditures” represent capital expenditures to expand the operating capacity of existing or new assets, whether through construction or acquisition. Expansion capital expenditures include expenditures to acquire assets, to grow our business and to expand existing facilities, such as projects that increase throughput capacity on our pipelines and in our terminals. Repair and maintenance expenses associated with existing assets that are minor in nature and do not extend the useful life of existing assets are charged to operating expenses as incurred.

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Each year the board of directors of HLS, our ultimate general partner, approves our annual capital budget, which specifies capital projects that our management is authorized to undertake. Additionally, at times when conditions warrant or as new opportunities arise, additional projects may be approved. The funds allocated for a particular capital project may be expended over a period in excess of a year, depending on the time required to complete the project. Therefore, our planned capital expenditures for a given year consist of expenditures approved for capital projects included in the current year’s capital budget as well as, in certain cases, expenditures approved for capital projects in capital budgets for prior years. WeThe 2020 capital budget as well as our current forecast are ~~forecasting~~comprised of approximately $8 million to ~~spend approximately $7-8~~$12 million for maintenance capital expenditures, $5 million to $7 million for refinery unit turnarounds and ~~approximately $35~~$45 million to $50 million for expansion capital expenditures ~~in 2019.~~and our share of Cushing Connect Joint Venture investments. We expect the majority of the 2020 expansion capital budget to be invested in ~~refined product pipeline expansions, crude system enhancements, new storage tanks and enhanced blending capabilities at~~ our ~~racks.~~share of Cushing Connect Joint Venture investments. In addition to our capital budget, we may spend funds periodically to perform capital upgrades or additions to our assets where a customer reimburses us for such costs. The upgrades or additions would generally benefit the customer over the remaining life of the related service agreements.

We expect that our currently planned sustaining and maintenance capital expenditures, as well as expenditures for acquisitions and capital development projects, will be funded with cash generated by operations, the sale of additional limited partner common units, the issuance of debt securities and advances under our Credit Agreement, or a combination thereof. With volatility and uncertainty at times in the credit and equity markets, there may be limits on our ability to issue new debt or equity financing. Additionally, due to pricing movements in the debt and equity markets, we may not be able to issue new debt and equity securities at acceptable pricing. Without additional capital beyond amounts available under the Credit Agreement, our ability to obtain funds for some of these capital projects may be limited.operations.

Under the terms of the transaction to acquire HFC’s 75% interest in UNEV, we issued to HFC a Class B unit comprising a noncontrolling equity interest in a wholly-owned subsidiary subject to redemption to the extent that HFC is entitled to a 50% interest in our share of annual UNEV earnings before interest, income taxes, depreciation, and amortization above $30 million beginning July 1, 2015, and ending in June 2032, subject to certain limitations. However, to the extent earnings thresholds are not achieved, no redemption payments are required. No redemption payments have been required to date.

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Credit Agreement

Our $1.4 billion Credit Agreement expires in July 2022. The Credit Agreement is available to fund capital expenditures, investments, acquisitions, distribution payments and working capital and for general partnership purposes. The Credit Agreement is also available to fund letters of credit up to a $50 million sub-limit, and it contains an accordion feature giving us the ability to increase the size of the facility by up to $300 million with additional lender commitments.

We may prepay all loans at any time without penalty, except for tranche breakage costs. If an event of default exists under the Credit Agreement, the lenders will be able to accelerate the maturity of all loans outstanding and exercise other rights and remedies. We were in compliance with all covenants as of ~~September 30, 2019.~~March 31, 2020.

Senior Notes

~~We have~~As of December 31, 2019, we had $500 million in aggregate principal amount of 6% Senior Notes due in 2024 (the “ 6% Senior Notes”). ~~We used~~

On February 4, 2020, we closed a private placement of $500 million in aggregate principal amount of 5% senior unsecured notes due in 2028 (the "5% Senior Notes"). On February 5, 2020, we redeemed the ~~net proceeds from our offerings of the~~existing $500 million 6% Senior Notes ~~to repay indebtedness~~at a redemption cost of $522.5 million, at which time we recognized a $25.9 million early extinguishment loss consisting of a $22.5 million debt redemption premium and unamortized financing costs of $3.4 million. We funded the $522.5 million redemption with proceeds from the issuance of our 5% Senior Notes and borrowings under our Credit Agreement.

The 6%5% Senior Notes are unsecured and impose certain restrictive covenants, including limitations on our ability to incur additional indebtedness, make investments, sell assets, incur certain liens, pay distributions, enter into transactions with affiliates, and enter into mergers. We were in compliance with the restrictive covenants for the 6%5% Senior Notes as of ~~September 30, 2019.~~March 31, 2020. At any time when the 6%5% Senior Notes are rated investment grade by ~~both~~either Moody’s ~~and~~or Standard & Poor’s and no default or event of default exists, we will not be subject to many of the foregoing covenants. Additionally, we have certain redemption rights at varying premiums over face value under the 6%5% Senior Notes.

Indebtedness under the 6%5% Senior Notes is guaranteed by all of our existing wholly-owned subsidiaries (other than Holly Energy Finance Corp. and certain immaterial subsidiaries).

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Long-term Debt

The carrying amounts of our long-term debt are as follows:


	September 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
	(In thousands)						(In thousands)
Credit Agreement	$	935,500		$	923,000		1,010,500			$	965,500

6% Senior Notes
Principal	500,000			500,000			—			500,000
Unamortized debt issuance costs	(3,631		)	(4,100		)	—			(3,469		)
	496,369			495,900			—			496,531

5% Senior Notes
Principal							500,000			—
Unamortized debt issuance costs							(8,346		)	—
							491,654			—

Total long-term debt	$	1,431,869		$	1,418,900		$	1,502,154		$	1,462,031

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Contractual Obligations

There were no significant changes to our long-term contractual obligations during this period.

Impact of Inflation

Inflation in the United States has been relatively moderate in recent years and did not have a material impact on our results of operations for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 and ~~2018.~~2019. PPI has increased an average of ~~0.8%~~0.6% annually over the past five calendar years, including increases of 0.8% and 3.1% in 2019 and ~~3.2% in~~ 2018, ~~and 2017,~~ respectively.

The substantial majority of our revenues are generated under long-term contracts that provide for increases or decreases in our rates and minimum revenue guarantees annually for increases or decreases in the PPI. Certain of these contracts have provisions that limit the level of annual PPI percentage rate increases or decreases. A significant and prolonged period of high inflation or a significant and prolonged period of negative inflation could adversely affect our cash flows and results of operations if costs increase at a rate greater than the fees we charge our shippers.

Environmental Matters

Our operation of pipelines, terminals, and associated facilities in connection with the transportation and storage of refined products and crude oil is subject to stringent and complex federal, state, and local laws and regulations governing the discharge of materials into the environment, or otherwise relating to the protection of the environment. As with the industry generally, compliance with existing and anticipated laws and regulations increases our overall cost of business, including our capital costs to construct, maintain, and upgrade equipment and facilities. While these laws and regulations affect our maintenance capital expenditures and net income, we believe that they do not affect our competitive position given that the operations of our competitors are similarly affected. However, these laws and regulations, and the interpretation or enforcement thereof, are subject to frequent change by regulatory authorities, and we are unable to predict the ongoing cost to us of complying with these laws and regulations or the future impact of these laws and regulations on our operations. Violation of environmental laws, regulations, and permits can result in the imposition of significant administrative, civil and criminal penalties, injunctions, and construction bans or delays. A major discharge of hydrocarbons or hazardous substances into the environment could, to the extent the event is not insured, subject us to substantial expense, including both the cost to comply with applicable laws and regulations and claims made by employees, neighboring landowners and other third parties for personal injury and property damage.

We have an environmental agreement with Delek with respect to pre-closing environmental costs and liabilities relating to the pipelines and terminals acquired from Delek in 2005, under which Delek will indemnify us subject to certain monetary and time limitations.

There are environmental remediation projects in progress that relate to certain assets acquired from HFC. Certain of these projects were underway prior to our purchase and represent liabilities retained by HFC. At ~~September 30, 2019,~~March 31, 2020, we had an accrual of ~~$5.8~~$5.5 million that related to environmental clean-up projects for which we have assumed liability or for which the indemnity provided for by HFC has expired or will expire. The remaining projects, including assessment and monitoring activities, are covered under the HFC environmental indemnification discussed above and represent liabilities of HFC.

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CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. The preparation of these financial statements requires us to make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities as of the date of the financial statements. Actual results may differ from these estimates under different assumptions or conditions. Our significant accounting policies are described in “Item 7. Management’s Discussion and Analysis of Financial Condition and Operations—Critical Accounting Policies” in our Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019. Certain critical accounting policies that materially affect the amounts recorded in our consolidated financial statements include revenue recognition, assessing the possible impairment of certain long-lived assets and goodwill, and assessing contingent liabilities for probable losses. ~~With the exception of certain of our revenue recognition policies discussed in Note 3 of Notes to the Consolidated Financial Statements, there~~There have been no changes to these policies in ~~2019.~~2020. We consider these policies to be the most critical to understanding the judgments that are involved and the uncertainties that could impact our results of operations, financial condition and cash flows.

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Accounting Pronouncements Adopted During the Periods Presented

Goodwill Impairment Testing

Leases

In February 2016, ASU No. 2016-02, “Leases” (“ASC 842”) was issued requiring leases to be measured and recognized as a lease liability, with a corresponding right-of-use asset on the balance sheet. We adopted this standard effective January 1, 2019, and we elected to adopt using the modified retrospective transition method, whereby comparative prior period financial information will not be restated and will continue to be reported under the lease accounting standard in effect during those periods. We also elected practical expedients provided by the new standard, including the package of practical expedients and the short-term lease recognition practical expedient, which allows an entity to not recognize on the balance sheet leases with a term of 12 months or less. Upon adoption of this standard, we recognized $78.4 million of lease liabilities and corresponding right-of-use assets on our consolidated balance sheet. Adoption of the standard did not have a material impact on our results of operations or cash flows. See Notes 3 and 4 of Notes to the Consolidated Financial Statements for additional information on our lease policies.

~~Revenue Recognition~~

In May 2014, an accounting standard update was issued requiring revenue to be recognized when promised goods or services are transferred to customers in an amount that reflects the expected consideration for these goods or services. This standard had an effective date of January 1, 2018, and we accounted for the new guidance using the modified retrospective implementation method, whereby a cumulative effect adjustment was recorded to retained earnings as of the date of initial application. In preparing for adoption, we evaluated the terms, conditions and performance obligations under our existing contracts with customers. Furthermore, we implemented policies to comply with this new standard. See Note 3 of Notes to the Consolidated Financial Statements for additional information on our revenue recognition policies.

~~Business Combinations~~

In December 2014, an accounting standard update was issued to provide new guidance on the definition of a business in relation to accounting for identifiable intangible assets in business combinations. This standard had an effective date of January 1, 2018, and had no effect on our financial condition, results of operations or cash flows.

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~~Financial Assets and Liabilities~~

~~Accounting Pronouncements - Not Yet Adopted~~

Credit Losses Measurement

In June 2016, ASU 2016-13, “Measurement of Credit Losses on Financial Instruments,” was issued requiring measurement of all expected credit losses for certain types of financial instruments, including trade receivables, held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. This standard iswas effective January 1, ~~2020, and our preliminary review~~2020. Adoption of ~~historic and expected credit losses indicates~~ the ~~amount of expected credit losses upon adoption would~~standard did not have a material impact on our financial condition, results of operations or cash flows.

RISK MANAGEMENT

The market risk inherent in our debt positions is the potential change arising from increases or decreases in interest rates as discussed below.

At ~~September 30, 2019~~March 31, 2020, we had an outstanding principal balance of $500 million on our 6%5% Senior Notes. A change in interest rates generally would affect the fair value of the 6%5% Senior Notes, but not our earnings or cash flows. At ~~September 30, 2019~~March 31, 2020, the fair value of our 6%5% Senior Notes was ~~$523.2~~$416.8 million. We estimate a hypothetical 10% change in the yield-to-maturity applicable to the 6%5% Senior Notes at ~~September 30, 2019~~March 31, 2020, would result in a change of approximately ~~$11~~$21 million in the fair value of the underlying 6%5% Senior Notes.

For the variable rate Credit Agreement, changes in interest rates would affect cash flows, but not the fair value. At ~~September 30, 2019~~March 31, 2020, borrowings outstanding under the Credit Agreement were ~~$935.5~~$1,010.5 million. A hypothetical 10% change in interest rates applicable to the Credit Agreement would not materially affect our cash flows.

Our operations are subject to normal hazards of operations, including fire, explosion and weather-related perils. We maintain various insurance coverages, including business interruption insurance, subject to certain deductibles. We are not fully insured against certain risks because such risks are not fully insurable, coverage is unavailable, or premium costs, in our judgment, do not justify such expenditures.

We have a risk management oversight committee that is made up of members from our senior management. This committee monitors our risk environment and provides direction for activities to mitigate, to an acceptable level, identified risks that may adversely affect the achievement of our goals.


Item 3.	Quantitative and Qualitative Disclosures About Market Risk

Market risk is the risk of loss arising from adverse changes in market rates and prices. See “Risk Management” under “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for a discussion of market risk exposures that we have with respect to our long-term debt, which disclosure should be read in conjunction with the quantitative and qualitative disclosures about market risk contained in our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2018.~~2019.

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Since we do not own products shipped on our pipelines or terminalled at our terminal facilities, we do not have direct market risks associated with commodity prices.

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Item 4.	Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Our principal executive officer and principal financial officer have evaluated, as required by Rule 13a-15(b) under the Securities Exchange Act of 1934 (the “Exchange Act”), our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this quarterly report on Form 10-Q. Our disclosure controls and procedures are designed to provide reasonable assurance that the information we are required to disclose in the reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective as of ~~September 30, 2019~~March 31, 2020, at a reasonable level of assurance.

(b) Changes in internal control over financial reporting

During the three months ended ~~September 30, 2019,~~March 31, 2020, there have been no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that occurred during our last fiscal quarter 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

In the ordinary course of business, we may become party to legal, regulatory or administrative proceedings or governmental investigations, including environmental and other matters. Damages or penalties may be sought from us in some matters and certain matters may require years to resolve. While the outcome and impact of these proceedings and investigations on us cannot be predicted with certainty, based on advice of counsel and information currently available to us, management believes that the resolution of these proceedings and investigations, through settlement or adverse judgment, will not, either individually or in the aggregate, have a materially adverse effect on our financial condition, results of operations or cash flows.

~~Environmental Matters~~

We are reporting the following proceedings to comply with SEC regulations which require us to disclose proceedings arising under federal, state or local provisions regulating the discharge of materials into the environment or protecting the environment if we reasonably believe that such proceedings may result in monetary sanctions of $100,000 or more. Our respective subsidiaries have or will develop corrective action plans regarding the subject of these proceedings that will be implemented in consultation with the respective federal and state agencies. It is not possible to predict the ultimate outcome of these proceedings, although none are currently expected to have a material effect on our financial condition, results of operations or cash flows.

~~Written Safety Compliance Program~~

Holly Energy Partners - Operating, L.P. (“HEP Operating”) received a Notice of Probable Violation (NOPV) dated June 20, 2018 from the Pipeline and Hazardous Materials Safety Administration (“PHMSA”). The NOPV follows a routine inspection of HEP's facilities and records and is not in response to an incident. In the NOPV, PHMSA alleges certain regulatory violations involving HEP Operating’s written safety compliance program for its pipelines, terminals and tanks. On June 20, 2018, PHMSA proposed a civil penalty and a compliance order that would require HEP Operating to take certain remedial actions. HEP Operating submitted information to PHMSA to demonstrate compliance regarding several of the allegations. PHMSA issued a Final Order dated August 8, 2019 withdrawing a number of the violations and reducing the civil penalty to an amount less than $100,000. HEP has paid the reduced penalty, and PHMSA will close this matter after HEP completes the work required in the Final Order.

~~Other~~

We are a party to various other legal and regulatory proceedings, which we believe, based on the advice of counsel, will not either individually or in the aggregate have a materially adverse impact on our financial condition, results of operations or cash flows.


Item 1A.	Risk Factors

~~Other than the risk factor set forth~~Except as disclosed below, there have been no material changes in our risk factors as previously disclosed in Part 1, “Item 1A. Risk Factors” of our Annual Report on Form 10-K for the fiscal year ended December 31, ~~2018.~~2019. In addition to the other information set forth in this quarterly report, you should consider carefully the factors discussed in our ~~2018~~2019 Form 10-K, which could materially affect our business, financial condition or future results. The risks described below and in our ~~2018~~2019 Form 10-K are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial may also materially and adversely affect our business, financial condition or future results.

~~The following risk~~Our business depends on hydrocarbon supply and demand fundamentals, which can be adversely affected by numerous factors ~~which were previously disclosed in Part 1, “Item 1A Risk Factors,”~~outside of our ~~Annual Report~~control, including the widespread outbreak of an illness, pandemic (like COVID-19) or any other public health crisis.

Our business depends in large part on ~~Form 10-K~~the demand for the ~~fiscal year ended December 31, 2018,~~various petroleum products we transport, terminal and store in the markets we serve. COVID-19’s spread across the globe and government regulations in response thereto have negatively affected worldwide economic and commercial activity, reduced global demand for oil, gas and refined products, and created significant volatility and disruption of financial and commodity markets. Other factors expected to impact crude oil supply include production levels implemented by OPEC members, other large oil producers such as Russia and domestic and Canadian oil producers. This combination of events has contributed to a sharp drop in the demand for crude oil and refined products.

In addition, the volumes of crude oil or refined products we transport, terminal or store will depend on many factors outside of our control, some of which include:

changes in domestic demand for, and the marketability of, refined products, and in turn, for crude oil and its transportation, due to governmental regulations, including travel bans and restrictions, quarantines, shelter in place orders, and shutdowns;

the ability of HFC, our other customers or our joint ventures’ other customers to fulfill their respective contractual obligations or any material reduction in, or loss of, revenue from our customers or our joint ventures’ customers;

increased price volatility, including the prices our customers or our joint ventures’ customers pay for crude oil and other raw materials and receive for their refined and finished lubricant products;

the health of our workforce, including contractors and subcontractors, and their access to our facilities, which could result in a shutdown of our facilities if a significant portion of the workforce at a facility is ~~hereby amended~~impacted or if a significant portion of the workforce in our control room is impacted;

the ability or willingness of our or our joint ventures’ current vendors and ~~restated~~suppliers to provide the equipment or parts for our or our joint ventures’ operations or otherwise fulfill their contractual obligations, potentially causing our delay or failure in ~~its entirety~~construction projects or to deliver crude oil or refined products on a timely basis or at all;

increased potential for the occurrence of operational hazards, including terrorism, cyberattacks or domestic vandalism, as ~~follows:~~well as information system failures or communication network disruptions;

increasing cost and reduced availability of capital for additional liquidity, growth or capital expenditures;

~~RISKS RELATED TO OUR BUSINESS~~delay by government authorities in issuing permits necessary for our business or our capital projects;

Weincreasing costs of operation in relation to the COVID-19 outbreak, which costs may not be ~~able to retain existing customers~~fully recoverable or ~~acquire new customers.~~adequately covered by insurance; and

~~The renewal~~the impact of any economic downturn, recession or ~~replacement~~other disruption of ~~existing contracts with our customers at rates sufficient to maintain attractive revenues~~the U.S. and ~~cash flows depends on a number of factors outside our control, including competition from other pipelines~~global economies and ~~the demand for refined products in the markets that we serve. Our long-term pipeline~~financial and ~~terminal, tankage and refinery processing unit throughput~~commodity markets.

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~~agreements with HFC~~The spread of COVID-19 has caused us to significantly modify our business practices (including limiting employee and Delek expire beginning in 2020 through 2036. On September 30, 2019, Delek exercised its first renewal option (the “Renewal”) under this agreement for an additional five year period beginning April 1, 2020, but only with respectcontractor presence at our work locations and to ~~specific assets. For the refined product pipelines and refined product terminals that were not subject~~sequester employees critical to the ~~Renewal~~operation of our control room), and ~~which currently account for approximately half of HEP’s annual revenues and distributable cash flows from Delek, the agreement terminates~~we may take further actions as ~~of March 31, 2020. In light of this development, we will explore other potential options with respect to the pipeline and terminal assets that were not subject to the Renewal. No assurances can~~may be ~~given~~required by government authorities or that we determine are in the best interests of our employees, contractors, customers, suppliers and communities. There is no certainty that such measures will be ~~able~~sufficient to ~~find new customers or that~~mitigate the ~~tariff rates we achieve on~~risks posed by the ~~assets not contractually renewed by Delek will be similar to the tariff rates we had with Delek.~~

~~TAX RISKS TO COMMON UNITHOLDERS~~

The tax treatment of publicly traded partnerships or an investment in our common units could be subject to potential legislative, judicial or administrative changes or differing interpretations, possibly applied on a retroactive basis.

~~The present federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be modified by administrative, legislative or judicial changes~~virus, and differing interpretations at any time. From time to time, members of Congress propose and consider similar substantive changes to the existing federal income tax laws that would affect publicly traded partnerships, including elimination of partnership tax treatment for publicly traded partnerships. For example, the “Clean Energy for America Act”, which is similar to legislation that was commonly proposed during the Obama Administration, was introduced in the Senate on May 2, 2019. If enacted, this proposal would, among other things, repeal Section 7704(d)(1)(E) of the Code upon which we rely for our treatment as a partnership for federal income tax purposes.

In addition, the Treasury Department has issued, and in the future may issue, regulations interpreting those laws that affect publicly traded partnerships. There can be no assurance that there will not be further changes to U.S. federal income tax laws or the Treasury Department’s interpretation of the qualifying income rules in a manner that could impact our ability to ~~qualify as a partnership~~perform critical functions could be adversely impacted.

As the potential effects of COVID-19 are difficult to predict, the duration of any potential business disruption or the extent to which it may negatively affect our operating results or our liquidity is uncertain. We are monitoring the situation to assess further possible implications to our business and to take actions in an effort to mitigate adverse consequences. Any potential impact will depend on future developments and new information that may emerge regarding the spread, severity and duration of the COVID-19 pandemic and the actions taken by authorities to contain it or treat its impact, all of which are beyond our control. In addition, if the volatility and seasonality in the ~~future, which~~oil and gas industry were to increase, the demand for our services may decline. We are monitoring the situation to assess further possible implications to our business and to take actions in an effort to mitigate adverse consequences. These potential effects, while uncertain, could ~~negatively impact the value~~materially adversely affect our business, financial condition, results of ~~an investment in~~operations and/or cash flows, as well as our ability to pay distributions to our common units. Any modification to the federal income tax laws may be applied retroactively and could make it more difficult or impossible for us to meet the qualifying income requirement to be treated as a partnership for U.S. federal income tax purposes. You are urged to consult with your own tax advisor with respect to the status of regulatory or administrative developments and proposals and their potential effect on your investment in our common units.unitholders.


Item 6.	Exhibits

The Exhibit Index on page 5144 of this Quarterly Report on Form 10-Q lists the exhibits that are filed or furnished, as applicable, as part of this Quarterly Report on Form 10-Q.

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Exhibit Index



Exhibit Number		Description

3.1		Second Amended and Restated Agreement of Limited Partnership of Holly Energy Partners, L.P. (incorporated by reference to Exhibit 3.1 to Registrant’s Current Report on Form 8-K filed on November 1, 2017, File No. 1-32225).
3.2		First Amended and Restated Agreement of Limited Partnership of Holly Energy Partners - Operating Company, L.P. (incorporated by reference to Exhibit 3.2 of Registrant’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2004, File No. 1-32225).
3.3		First Amended and Restated Agreement of Limited Partnership of HEP Logistics Holdings, L.P. (incorporated by reference to Exhibit 3.4 of Registrant’s Quarterly Report on Form 10-Q for its quarterly period ended June 30, 2004, File No. 1-32225).
3.4		First Amended and Restated Limited Liability Company Agreement of Holly Logistic Services, L.L.C. (incorporated by reference to Exhibit 3.5 of Registrant’s Quarterly Report on Form 10-Q for its quarterly period ended June 30, 2004, File No. 1-32225).
3.5		Amendment No. 1 to the First Amended and Restated Limited Liability Company Agreement of Holly Logistic Services, L.L.C., dated April 27, 2011 (incorporated by reference to Exhibit 3.1 of Registrant’s Form 8-K Current Report filed on May 3, 2011, File No. 1-32225).
3.6		First Amended and Restated Limited Liability Company Agreement of HEP Logistics GP, L.L.C. (incorporated by reference to Exhibit 3.6 of Registrant’s Quarterly Report on Form 10-Q for its quarterly period ended June 30, 2004, File No. 1-32225).
10.1*4.1		~~Alon USA, LP Notice of Partial Renewal of Pipelines and Terminals Agreement,~~Indenture, dated February ~~28, 2005,~~4, 2020, by and among ~~Alon USA, LP and~~ Holly Energy Partners, L.P., ~~dated September 30, 2019.~~
~~10.2+~~		~~Form of~~ Holly Energy ~~Partners, L.P. Indemnification Agreement to be entered into with officers~~Finance Corp., each of the Guarantors party thereto and ~~directors of Holly Logistic Services, L.L.C. and its subsidiaries~~ ~~(incorporated by reference to Exhibit 10.2 of Registrant’s Quarterly Report on Form 10-Q for its quarterly period ended June 30, 2019, filed August 1, 2019, File No. 1-32225).~~
~~10.3~~		~~Fifth Amended and Restated Master Throughput Agreement, dated as of July 1, 2019, by and between HollyFrontier Refining & Marketing LLC and Holly Energy Partners - Operating, L.P.~~U.S. Bank National Association (incorporated by reference to Exhibit ~~10.1~~4.1 of Registrant’s Current Report on Form 8-K ~~Current Report~~ filed ~~July 2, 2019,~~February 4, 2020, File No. 1-32225).
~~10.4~~		Fifth Amendment to the Pipelines and Terminals Agreement, dated August 28, 2019, by and between Holly Energy Partners, L.P. and Alon USA, LP. (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K Current Report filed August 30, 2019, File No. 1-32225).
~~10.5~~		Sixth Amended and Restated Master Throughput Agreement, dated as of October 2, 2019, by and between HollyFrontier Refining & Marketing LLC and Holly Energy Partners - Operating, L.P. (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K Current Report filed October 3, 2019, File No. 1-32225).
~~10.6~~		Twentieth Amended and Restated Omnibus Agreement, dated as of October 2, 2019, by and between HollyFrontier Corporation, Holly Energy Partners, L.P. and certain of their respective subsidiaries (incorporated by reference to Exhibit 10.2 of Registrant’s Form 8-K Current Report filed October 3, 2019, File No. 1-32225).
~~10.7*+~~4.2		Form of ~~Performance Unit Agreement.~~
~~10.8*+~~		~~Form of Phantom Unit Agreement (Employee).~~
~~10.9*+~~		~~Form of Notice of Grant of Phantom Units.~~
10.10*		~~Form of Notice of Grant of Restricted Units (Non-Employee Director Award).~~
10.11*		~~Form of Restricted Unit Agreement (Non-Employee Director Award)~~5.000% Senior Notes due 2028 (Included in Exhibit 4.1).
31.1*		Certification of Chief Executive Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*		Certification of Chief Financial Officer under Section 302 of the Sarbanes-Oxley Act of 2002.
32.1**		Certification of Chief Executive Officer under Section 906 of the Sarbanes-Oxley Act of 2002.
32.2**		Certification of Chief Financial Officer under Section 906 of the Sarbanes-Oxley Act of 2002.
~~101~~101++		The following financial information from Holly Energy Partners, L.P.’s Quarterly Report on Form 10-Q for the quarter ended ~~September 30, 2019,~~March 31, 2020 formatted in iXBRL (Inline Extensible Business Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Income, (iii) Consolidated Statements of Comprehensive Income, (iv) Consolidated Statements of Cash Flows, (v) Consolidated Statement of Partners’ Equity, and (vi) Notes to Consolidated Financial Statements. The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.
104		Cover Page Interactive Data File (formatted as inline XBRL and contained in Exhibit 101).

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*	Filed herewith.
**	Furnished herewith.
++	~~Constitutes management contracts or compensatory plans or arrangements.~~Filed electronically herewith.

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HOLLY ENERGY PARTNERS, L.P.

SIGNATURES

Pursuant to the requirements of the Securities and Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	HOLLY ENERGY PARTNERS, L.P.
	(Registrant)

		By: HEP LOGISTICS HOLDINGS, L.P. its General Partner

		By: HOLLY LOGISTIC SERVICES, L.L.C. its General Partner

Date: ~~October 31, 2019~~May 7, 2020		/s/ ~~Richard L. Voliva III~~John Harrison
		~~Richard L. Voliva III~~John Harrison
		~~Executive~~Senior Vice President, ~~and~~ Chief Financial Officer and Treasurer (Principal Financial Officer)

Date: ~~October 31, 2019~~May 7, 2020		/s/ Kenneth P. Norwood
		Kenneth P. Norwood
		Vice President and Controller (Principal Accounting Officer)

- 5145 -



	Prior to Adoption		Increase (Decrease)			As Adjusted
	(In thousands)
Deferred revenue	$	9,598	$	(1,320	)	$	8,278
Partners’ equity: Common unitholders	$	393,959	$	1,320		$	395,279



	(In thousands)

Net investment in leases	$	122,800
Properties and equipment, net	(15,031		)
Operating lease right-of-use assets, net	(72,603		)
Gain on sales-type leases	$	35,166



Three Months Ended September 30, 2018	Parent			Guarantor Restricted Subsidiaries			Non-Guarantor Non-Restricted Subsidiaries			Eliminations			Consolidated
	(In thousands)
Revenues:
Affiliates	$	—		$	94,270		$	5,918		$	—		$	100,188
Third parties	—			21,277			4,319			—			25,596
	—			115,547			10,237			—			125,784
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	—			32,906			3,090			—			35,996
Depreciation and amortization	—			20,198			4,169			—			24,367
General and administrative	698			1,800			—			—			2,498
	698			54,904			7,259			—			62,861
Operating income (loss)	(698		)	60,643			2,978			—			62,923

Other income (expense):
Equity in earnings of subsidiaries	63,731			2,251			—			(65,982		)	—
Equity in earnings of equity method investments	—			1,114			—			—			1,114
Interest expense	(18,030		)	(12		)	—			—			(18,042		)
Interest income	—			540			—			—			540
Gain (loss) on sale of assets and other	—			14			24			—			38
	45,701			3,907			24			(65,982		)	(16,350		)
Income before income taxes	45,003			64,550			3,002			(65,982		)	46,573
State income tax expense	—			(39		)	—			—			(39		)
Net income	45,003			64,511			3,002			(65,982		)	46,534
Allocation of net income attributable to noncontrolling interests	—			(780		)	(751		)	—			(1,531		)
Net income attributable to the partners	$	45,003		$	63,731		$	2,251		$	(65,982	)	$	45,003