Edgar Filing: HOLLY ENERGY PARTNERS LP

Document

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

______________________________________________________________________________________

FORM 10-Q

______________________________________________________________________________________

(Mark One)



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

For the quarterly period ended June 30, 2017



¨	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)

________________________________________________________________

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 ý No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes ý No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.



Large accelerated filer	ý	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 ý

The number of the registrant’s outstanding common units at July 31, 2017, was 64,318,955.

Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

INDEX





	FORWARD-LOOKING STATEMENTS		3

PART I. FINANCIAL INFORMATION			4

	Item 1.	Financial Statements (Unaudited)	4

		Consolidated Balance Sheets	4

		Consolidated Statements of Income	5

		Consolidated Statements of Comprehensive Income	6

		Consolidated Statements of Cash Flows	7

		Consolidated Statement of Equity	8

		Notes to Consolidated Financial Statements	9

	Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	32

	Item 3.	Quantitative and Qualitative Disclosures About Market Risk	46

	Item 4.	Controls and Procedures	46

PART II. OTHER INFORMATION			47

	Item 1.	Legal Proceedings	47

	Item 1A.	Risk Factors	47

	Item 6.	Exhibits	47

		SIGNATURES	48

		Index to Exhibits	49

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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 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:


•	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;


•	the economic viability of HollyFrontier Corporation, Alon USA, Inc. and our other customers;


•	the demand for refined petroleum products in markets we serve;


•	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 pipeline and terminal facilities;


•	the effects of current and future government regulations and policies;


•	our operational efficiency in carrying out routine operations and capital construction projects;


•	the possibility of terrorist attacks and the consequences of any such attacks;


•	general economic conditions; 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. 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, 2016, 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.

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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)



	June 30, 2017			December 31, 2016
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	16,339		$	3,657
Accounts receivable:
Trade	8,131			7,846
Affiliates	36,607			42,562
	44,738			50,408
Prepaid and other current assets	3,122			2,888
Total current assets	64,199			56,953

Properties and equipment, net	1,311,766			1,328,395
Transportation agreements, net	63,381			66,856
Goodwill	256,498			256,498
Equity method investments	163,360			165,609
Other assets	8,687			9,926
Total assets	$	1,867,891		$	1,884,237

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable:
Trade	$	8,632		$	10,518
Affiliates	7,296			16,424
	15,928			26,942

Accrued interest	10,550			18,069
Deferred revenue	13,545			11,102
Accrued property taxes	4,396			5,397
Other current liabilities	3,189			3,225
Total current liabilities	47,608			64,735

Long-term debt	1,236,739			1,243,912
Other long-term liabilities	15,717			16,445
Deferred revenue	46,245			47,035

Class B unit	41,682			40,319

Equity:
Partners’ equity:
Common unitholders (64,318,955 and 62,780,503 units issued and outstanding at June 30, 2017 and December 31, 2016, respectively)	518,178			510,975
General partner interest (2% interest)	(130,871		)	(132,832		)
Accumulated other comprehensive income	63			91
Total partners’ equity	387,370			378,234
Noncontrolling interest	92,530			93,557
Total equity	479,900			471,791
Total liabilities and equity	$	1,867,891		$	1,884,237

See accompanying notes.

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Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF INCOME

(Unaudited)

(In thousands, except per unit data)



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016 ⁽¹⁾			2017			2016 ⁽¹⁾
Revenues:
Affiliates	$	93,152		$	79,179		$	182,177		$	162,025
Third parties	15,991			15,718			32,600			34,882
	109,143			94,897			214,777			196,907
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	34,097			29,212			66,586			57,067
Depreciation and amortization	19,945			15,712			38,722			32,263
General and administrative	2,615			2,863			5,249			5,954
	56,657			47,787			110,557			95,284
Operating income	52,486			47,110			104,220			101,623

Other income (expense):
Equity in earnings of equity method investments	4,053			3,623			5,893			6,388
Interest expense	(13,748		)	(11,276		)	(27,287		)	(21,811		)
Interest income	103			112			205			224
Loss on early extinguishment of debt	—			—			(12,225		)	—
Gain (loss) on sale of assets and other	89			—			162			(8		)
	(9,503		)	(7,541		)	(33,252		)	(15,207		)
Income before income taxes	42,983			39,569			70,968			86,416
State income tax expense	(127		)	(54		)	(233		)	(149		)
Net income	42,856			39,515			70,735			86,267
Allocation of net loss attributable to Predecessor	—			1,960			—			3,110
Allocation of net income attributable to noncontrolling interests	(1,521		)	(2,355		)	(3,837		)	(7,282		)
Net income attributable to the partners	41,335			39,120			66,898			82,095
General partner interest in net income attributable to the partners	(18,328		)	(12,677		)	(35,466		)	(24,779		)
Limited partners’ interest in net income	$	23,007		$	26,443		$	31,432		$	57,316
Limited partners’ per unit interest in earnings—basic and diluted	$	0.36		$	0.45		$	0.49		$	0.96
Weighted average limited partners’ units outstanding	64,086			58,865			63,602			58,761

(1) Retrospectively adjusted as described in Note 1.

See accompanying notes.

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HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

(In thousands)



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016 ⁽¹⁾			2017			2016⁽¹⁾
Net income	$	42,856		$	39,515		$	70,735		$	86,267

Other comprehensive income:
Change in fair value of cash flow hedging instruments	11			(255		)	87			(938		)
Reclassification adjustment to net income on partial settlement of cash flow hedge	(102		)	113			(115		)	343
Other comprehensive income (loss)	(91		)	(142		)	(28		)	(595		)
Comprehensive income before noncontrolling interest	42,765			39,373			70,707			85,672
Allocation of net loss attributable to Predecessor	—			1,960			—			3,110
Allocation of comprehensive income to noncontrolling interests	(1,521		)	(2,355		)	(3,837		)	(7,282		)
Comprehensive income attributable to Holly Energy Partners	$	41,244		$	38,978		$	66,870		$	81,500

(1) Retrospectively adjusted as described in Note 1.

See accompanying notes.

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Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)



	Six Months Ended June 30,
	2017			2016 ⁽¹⁾
Cash flows from operating activities
Net income	$	70,735		$	86,267
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	38,722			32,263
(Gain) loss on sale of assets	(133		)	5
Amortization of deferred charges	1,504			1,376
Amortization of restricted and performance units	1,109			1,193
Earnings distributions greater (less) than income from equity investments	594			(414		)
Loss on early extinguishment of debt	12,225			—
(Increase) decrease in operating assets:
Accounts receivable—trade	(285		)	2,564
Accounts receivable—affiliates	6,033			(10,183		)
Prepaid and other current assets	(234		)	416
Increase (decrease) in operating liabilities:
Accounts payable—trade	104			(637		)
Accounts payable—affiliates	(9,128		)	(2,454		)
Accrued interest	(7,519		)	(91		)
Deferred revenue	1,653			948
Accrued property taxes	(1,001		)	1,409
Other current liabilities	(442		)	(979		)
Other, net	(336		)	(381		)
Net cash provided by operating activities	113,601			111,302

Cash flows from investing activities
Additions to properties and equipment	(20,524		)	(32,667		)
Purchase of Woods Cross refinery processing units	—			(42,718		)
Purchase of interest in Cheyenne Pipeline	—			(42,500		)
Proceeds from sale of assets	635			18
Distributions in excess of equity in earnings of equity investments	1,654			1,496
Net cash used for investing activities	(18,235		)	(116,371		)

Cash flows from financing activities
Borrowings under credit agreement	479,000			239,000
Repayments of credit agreement borrowings	(189,000		)	(165,000		)
Redemption of 6.5% Senior Notes	(309,750		)	—
Proceeds from issuance of common units	52,634			13,690
Distributions to HEP unitholders	(112,195		)	(91,109		)
Distributions to noncontrolling interest	(3,500		)	(2,500		)
Distribution to HFC for Tulsa tank acquisition	—			(39,500		)
Distribution to HFC for Osage acquisition	—			(1,245		)
Distribution to HFC for El Dorado tanks	(103		)	—
Contributions from HFC for acquisitions	—			45,707
Contributions from general partner	995			120
Purchase of units for incentive grants	—			(784		)
Deferred financing costs	—			(3,084		)
Other	(765		)	(357		)
Net cash used by financing activities	(82,684		)	(5,062		)

Cash and cash equivalents
Increase (decrease) for the period	12,682			(10,131		)
Beginning of period	3,657			15,013
End of period	$	16,339		$	4,882

(1) Retrospectively adjusted as described in Note 1.

See accompanying notes.

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Table of Contentsril 19,

HOLLY ENERGY PARTNERS, L.P.

CONSOLIDATED STATEMENT OF EQUITY

(Unaudited)

(In thousands)



	Common Units			General Partner Interest			Accumulated Other Comprehensive Income (Loss)			Noncontrolling Interest			Total Equity

Balance December 31, 2016	$	510,975		$	(132,832	)	$	91		$	93,557		$	471,791
Issuance of common units	52,383			—			—			—			52,383
Contribution from HFC	—			1,072			—			—			1,072
Distribution to HFC for acquisition	—			(103		)	—			—			(103		)
Distributions to HEP unitholders	(77,748		)	(34,447		)	—			—			(112,195		)
Distributions to noncontrolling interest	—			—			—			(3,500		)	(3,500		)
Amortization of restricted and performance units	1,109			—			—			—			1,109
Class B unit accretion	(1,337		)	(27		)	—			—			(1,364		)
Net income	32,796			35,466			—			2,473			70,735
Other comprehensive income	—			—			(28		)	—			(28		)
Balance June 30, 2017	$	518,178		$	(130,871	)	$	63		$	92,530		$	479,900

See accompanying notes.

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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 which is 36% owned (including the 2% general partner interest) by HollyFrontier Corporation (“HFC”) and its subsidiaries as of June 30, 2017. 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.

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 in the Mid-Continent, Southwest and Northwest regions of the United States and Alon USA, Inc.’s (“Alon”) refinery in Big Spring, Texas. Additionally, we own a 75% interest in UNEV Pipeline, LLC (“UNEV”), a 50% interest in Frontier Aspen LLC, a 50% interest in Osage Pipe Line Company, LLC (“Osage”), a 50% interest in Cheyenne Pipeline LLC and a 25% interest in SLC Pipeline 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 13.

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, 2016. 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, 2017.

Principles of Consolidation and Common Control Transactions

The consolidated financial statements include our accounts, our Predecessor's (defined below) 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. GAAP requires transfers of a business between entities under common control to be accounted for as though the transfer occurred as of the beginning of the period of transfer, and prior period financial statements and financial information are retrospectively adjusted to include the historical results and assets of the acquisitions from HFC for all periods presented prior to the effective dates of each acquisition. We refer to the historical results of the acquisitions prior to their respective acquisition dates as those of our "Predecessor." Many of these transactions are cash purchases and do not involve the issuance of equity; however, GAAP requires the retrospective adjustment of financial statements. Therefore, in such transactions, the prior year balance sheet includes as equity the amount of cost incurred by HFC to that date. See “Acquisitions” below for further discussion as well as effects of the retrospective adjustments.

Acquisitions

Osage

On February 22, 2016, HFC obtained a 50% membership interest in Osage in a non-monetary exchange for a 20-year terminalling services agreement, whereby a subsidiary of Magellan Midstream Partners (“Magellan”) will provide terminalling services for all HFC products originating in Artesia, New Mexico requiring terminalling in or through El Paso, Texas. Osage is the owner of the Osage Pipeline, a 135-mile pipeline that transports crude oil from Cushing, Oklahoma to HFC’s El Dorado Refinery in Kansas and also connects to the Jayhawk pipeline serving the CHS Inc. refinery in McPherson, Kansas. The Osage Pipeline is the primary pipeline supplying HFC’s El Dorado refinery with crude oil.

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Concurrent with this transaction, we entered into a non-monetary exchange with HFC, whereby we received HFC’s interest in Osage in exchange for our El Paso terminal. Under this exchange, we agreed to build two connections on our south products pipeline system that will permit HFC access to Magellan’s El Paso terminal. Effective upon the closing of this exchange, we became the named operator of the Osage Pipeline and transitioned into that role on September 1, 2016. Since we are a consolidated VIE of HFC, this transaction was recorded as a transfer between entities under common control and reflects HFC’s carrying basis of its 50% membership interest in Osage of $44.5 million offset by our net carrying basis in the El Paso terminal of $12.1 million with the difference recorded as a contribution from HFC. However, since these transactions were concurrent, there was no impact on periods prior to February 22, 2016.

Tulsa Tanks

On March 31, 2016, we acquired crude oil tanks (the “Tulsa Tanks”) located at HFC’s Tulsa refinery from an affiliate of Plains All American Pipeline, L.P. (“Plains”) for cash consideration of $39.5 million. In 2009, HFC sold these tanks to Plains and leased them back, and due to HFC’s continuing interest in the tanks, HFC accounted for the transaction as a financing arrangement. Accordingly, the tanks had remained on HFC’s balance sheet and were being depreciated for accounting purposes.

As we are a consolidated VIE of HFC, this transaction was recorded as a transfer between entities under common control and reflects HFC’s carrying basis in the net assets acquired. We have retrospectively adjusted our financial position and operating results as if these units were owned for all periods while we were under common control of HFC.

Cheyenne Pipeline

On June 3, 2016, we acquired a 50% interest in Cheyenne Pipeline LLC, owner of the Cheyenne Pipeline, in exchange for a contribution of $42.6 million in cash to Cheyenne Pipeline LLC. Cheyenne Pipeline LLC will continue to be operated by an affiliate of Plains, which owns the remaining 50% interest. The 87-mile crude oil pipeline runs from Fort Laramie to Cheyenne, Wyoming and has an 80,000 barrel per day (“bpd”) capacity.

Woods Cross Operating

Effective October 1, 2016, we acquired all the membership interests of Woods Cross Operating LLC (“Woods Cross Operating”), a wholly owned subsidiary of HFC, which owns the newly constructed atmospheric distillation tower, fluid catalytic cracking unit, and polymerization unit located at HFC’s Woods Cross Refinery, for cash consideration of $278 million. The consideration was funded with $103 million in proceeds from the private placement of 3,420,000 common units with the balance funded with borrowings under our credit facility. In connection with this transaction, we entered into 15-year tolling agreements containing minimum quarterly throughput commitments from HFC. As of June 30, 2017, these commitments provide minimum annualized revenues of $57 million.

The Utah Division of Air Quality issued an air quality permit to HollyFrontier Woods Cross Refining LLC (“HFC Woods Cross Refining”) authorizing the expansion units at the Woods Cross Refinery. The appeal proceeding challenging the Utah Department of Environmental Quality’s decision to uphold the air quality permit was taken under advisement by the Utah Supreme Court in June 2017, and the court issued a decision in favor of the state of Utah and HFC. As a result, the purchase agreement remedies we had against HFC in the event of an unfavorable ruling in the appeal proceeding are no longer applicable.

The following tables present lines in our previously reported income statement for the three and six months ended June 30, 2016, that were impacted by Predecessor transactions, and retrospectively adjusts only the acquisition of Woods Cross Operating as the Tulsa Tanks acquisition included Predecessor transactions in the previously reported income statement for the three and six months ended June 30, 2016. However, the presentation of the Tulsa Tanks’ Predecessor transactions have been modified as shown in the table below.

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	Three Months Ended June 30, 2016
	Holly Energy Partners, L.P.(Previously reported)		Tulsa Tanks		Woods Cross Operating		Holly Energy Partners, L.P. (Currently reported)
	(In Thousands)
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	$	27,255	$	—	$	1,957	$	29,212
Depreciation and amortization	15,709		—		3		15,712
Allocation of net loss attributable to predecessor	—		—		1,960		1,960



	Six Months Ended June 30, 2016
	Holly Energy Partners, L.P.(Previously reported)		Tulsa Tanks		Woods Cross Operating		Holly Energy Partners, L.P. (Currently reported)
	(In Thousands)
Operating costs and expenses:
Operations (exclusive of depreciation and amortization)	$	54,177	$	—	$	2,890	$	57,067
Depreciation and amortization	32,260		—		3		32,263
Allocation of net loss attributable to predecessor	—		217		2,893		3,110

The following tables present lines in our previously reported cash flows for the six months ended June 30, 2016, that were impacted by Predecessor transactions, and retrospectively adjusts only the acquisition of Woods Cross Operating as the Tulsa Tanks acquisition included Predecessor transactions in the previously reported cash flows for the six months ended June 30, 2016.



	Six Months Ended June 30, 2016
	Holly Energy Partners, L.P.(Previously reported)			Woods Cross Operating			Holly Energy Partners, L.P. (Currently reported)
Cash flows from operating activities	(In Thousands)
Net income	$	89,160		$	(2,893	)	$	86,267
Depreciation and amortization	32,260			$	3		32,263
Net cash provided by operating activities	$	114,192		$	(2,890	)	$	111,302

Cash flows from investing activities
Acquisition of refinery processing units	—			(42,718		)	(42,718		)
Net cash used for investing activities	$	(73,653	)	$	(42,718	)	$	(116,371	)

Cash flows from financing activities
Contributions from HFC for acquisitions	$	99		$	45,608		$	45,707
Net cash provided (used) by financing activities	$	(50,670	)	$	45,608		$	(5,062	)

Accounting Pronouncements Adopted During the Periods Presented

Earnings Per Unit

In April 2015, an accounting standard update was issued requiring changes to the allocation of the earnings or losses of a transferred business for periods before the date of a dropdown of net assets accounted for as a common control transaction entirely to the general partner for purposes of calculating historical earnings per unit. We adopted this standard as of January 1, 2016. In connection with the dropdown of assets from HFC’s Tulsa refinery on March 31, 2016, we reduced net income by $0.2 million for the three and six months ended June 30, 2016, and in connection with the purchase of HFC’s Woods Cross refinery units on

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October 1, 2016, we reduced net income by $2.0 million and $2.9 million, respectively, for the three and six months ended June 30, 2016. This reduction had no impact on the historical earnings per limited partner unit.

Share-Based Compensation

In March 2016, an accounting standard update was issued which simplifies the accounting for employee share-based payment transactions, including the accounting for income taxes, forfeitures and statutory tax withholding requirements, as well as classification in the statement of cash flows. We adopted this standard effective January 1, 2017, with no impact to our financial condition, results of operations and cash flows. As permitted by the standard, we continue to account for forfeitures on an estimated basis.

Accounting Pronouncements Not Yet Adopted

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 has an effective date of January 1, 2018, and we intend to account for the new guidance using the modified retrospective implementation method, whereby a cumulative effect adjustment is recorded to retained earnings as of the date of initial application. Our preparation for adoption of this standard is in progress, and we are currently evaluating terms, conditions and our performance obligations of our existing contracts with customers. We are evaluating the effect of this standard on our revenue recognition policies and whether it will have a material impact on our financial condition or results of operations.

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 has an effective date of January 1, 2018, and we are evaluating its impact.

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 will become effective beginning with our 2018 reporting year. We are evaluating the impact of this standard.

Leases

In February 2016, an accounting standard update was issued requiring leases to be measured and recognized as a lease liability, with a corresponding right-of-use asset on the balance sheet. This standard has an effective date of January 1, 2019, and we are evaluating the impact of this standard.


Note 2:	Financial Instruments

Our financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable, debt and interest rate swaps. 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.

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.

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



		June 30, 2017				December 31, 2016
Financial Instrument	Fair Value Input Level	Carrying Value		Fair Value		Carrying Value		Fair Value
		(In thousands)
Assets:
Interest rate swaps	Level 2	$	63	$	63	$	91	$	91

Liabilities:
6.5% Senior notes	Level 2	$	—	$	—	$	297,519	$	308,250
6% Senior notes	Level 2	393,739		418,000		393,393		415,500
		$	393,739	$	418,000	$	690,912	$	723,750

Level 2 Financial Instruments

Our senior notes and interest rate swaps 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. The fair value of our interest rate swaps is based on the net present value of expected future cash flows related to both variable and fixed-rate legs of the swap agreement. This measurement is computed using the forward London Interbank Offered Rate (“LIBOR”) yield curve, a market-based observable input.

See Note 6 for additional information on these instruments.


Note 3:	Properties and Equipment

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



	June 30, 2017		December 31, 2016
	(In thousands)
Pipelines, terminals and tankage	$	1,249,383	$	1,246,746
Refinery assets	347,285		346,058
Land and right of way	65,337		65,331
Construction in progress	40,914		28,753
Other	27,542		27,133
	1,730,461		1,714,021
Less accumulated depreciation	418,695		385,626
	$	1,311,766	$	1,328,395

We capitalized $0.4 million and $0.3 million in interest attributable to construction projects during the six months ended June 30, 2017 and 2016, respectively.

Depreciation expense was $34.9 million and $28.5 million for the six months ended June 30, 2017 and 2016, respectively, and includes depreciation of assets acquired under capital leases.


Note 4:	Transportation Agreements

Our transportation agreements are intangible assets that represent a portion of the total purchase price of certain assets acquired from Alon in 2005 and from HFC in 2008 prior to HEP becoming a consolidated VIE of HFC. The Alon agreement is being amortized over 30 years ending 2035 (the initial 15-year term of the agreement plus an expected 15-year extension period), and the HFC agreement is being amortized over 15 years ending 2023 (the term of the HFC agreement).

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The carrying amounts of our transportation agreements are as follows:



	June 30, 2017		December 31, 2016
	(In thousands)
Alon transportation agreement	$	59,933	$	59,933
HFC transportation agreement	74,231		74,231
Other	50		50
	134,214		134,214
Less accumulated amortization	70,833		67,358
	$	63,381	$	66,856

Amortization expense was $3.5 million for each of the six months ended June 30, 2017 and 2016.

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 of HFC; therefore, our basis in these agreements is zero and does not reflect a step-up in basis to fair value.


Note 5:	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. These employees participate in the retirement and benefit plans of HFC. Our share of retirement and benefit plan costs was $1.3 million and $1.3 million for the three months ended June 30, 2017 and 2016, respectively, and $3.0 million and $2.9 million for the six months ended June 30, 2017 and 2016.

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 four 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 June 30, 2017, we had two types of incentive-based awards outstanding, which are described below. The compensation cost charged against income was $0.6 million and $0.5 million for the three months ended June 30, 2017 and 2016, respectively, and $0.9 million and $1.2 million for the six months ended June 30, 2017 and 2016. 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 June 30, 2017, 2,500,000 units were authorized to be granted under our Long-Term Incentive Plan, of which 1,409,261 have not yet been granted, assuming no forfeitures of the unvested units and full achievement of goals for the unvested performance units.

Restricted Units

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

The fair value of each restricted 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.

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A summary of restricted unit activity and changes during the six months ended June 30, 2017, is presented below:



Restricted Units	Units		Weighted Average Grant-Date Fair Value
Outstanding at January 1, 2017 (nonvested)	123,988		$	32.96
Granted	20,348		36.01
Forfeited	(17,653	)	29.75
Outstanding at June 30, 2017 (nonvested)	126,683		$	33.90

As of June 30, 2017, there was $1.6 million of total unrecognized compensation expense related to nonvested restricted unit grants, which is expected to be recognized over a weighted-average period of 1.0 year.

Performance Units

Under our Long-Term Incentive Plan, we grant performance units to selected executives who perform services for us. Performance units granted are payable in common units at the end of a three-year performance period based upon the growth in our distributable cash flow per common unit over the performance period. As of June 30, 2017, 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 six months ended June 30, 2017. Performance units granted in 2016 vest over a three-year performance period ending December 31, 2019, and are payable in HEP common units. The number of units actually earned will be based on the growth of our distributable cash flow per common unit over the performance period, and can range from 50% to 150% of the target number of performance units granted. Although common units are not transferred to the recipients until the performance units vest, the recipients have distribution rights with respect to the common units from the date of grant.

A summary of performance unit activity and changes during the six months ended June 30, 2017, is presented below:



Performance Units	Units
Outstanding at January 1, 2017 (nonvested)	49,520
Vesting and transfer of common units to recipients	(2,262	)
Forfeited	(21,228	)
Outstanding at June 30, 2017 (nonvested)	26,030

The grant-date fair value of performance units vested and transferred to recipients during the six months ended June 30, 2017, was $0.1 million. Based on the weighted average fair value of performance units outstanding at June 30, 2017, of $0.9 million, there was $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 1.8 years.


Note 6:	Debt

Credit Agreement

At June 30, 2017, we had a $1.2 billion senior secured revolving credit facility (the “Credit Agreement”) expiring in November 2018. On July 27, 2017, the Credit Agreement was amended, increasing the size of the facility from $1.2 billion to $1.4 billion and extending the expiration to 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.

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We may prepay all loans outstanding 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 June 30, 2017.

Senior Notes

On January 4, 2017, we redeemed the $300 million aggregate principal amount of 6.5% senior notes (the “6.5% Senior Notes”) at a redemption cost of $309.8 million at which time we recognized a $12.2 million early extinguishment loss consisting of a $9.8 million debt redemption premium and unamortized discount and financing costs of $2.4 million. We funded the redemption with borrowings under our Credit Agreement.

On July 19, 2016, we closed a private placement of $400 million in aggregate principal amount of 6% senior unsecured notes due in 2024 (the “6% Senior Notes”). We used the net proceeds to repay indebtedness under our Credit Agreement.

The 6% 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% Senior Notes as of June 30, 2017. At any time when the 6% Senior Notes are rated investment grade by both Moody’s and 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% Senior Notes.

Indebtedness under the 6% Senior Notes is guaranteed by our wholly-owned subsidiaries.

Long-term Debt

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



	June 30, 2017			December 31, 2016
	(In thousands)
Credit Agreement
Amount outstanding	$	843,000		$	553,000

6% Senior Notes
Principal	400,000			400,000
Unamortized debt issuance costs	(6,261		)	(6,607		)
	393,739			393,393
6.5% Senior Notes
Principal	—			300,000
Unamortized discount and debt issuance costs	—			(2,481		)
	—			297,519

Total long-term debt	$	1,236,739		$	1,243,912

Interest Rate Risk Management

We use interest rate swaps (derivative instruments) to manage our exposure to interest rate risk.

As of June 30, 2017, we had two interest rate swaps with identical terms that hedged our exposure to the cash flow risk caused by the effects of LIBOR changes on $150 million of Credit Agreement advances. The swaps effectively converted $150 million of our LIBOR based debt to fixed rate debt having an interest rate of 0.74% plus an applicable margin of 2.25% as of June 30, 2017, which equaled an effective interest rate of 2.99%. Both of these swap contracts matured on July 31, 2017.

We have designated these interest rate swaps as cash flow hedges. Based on our assessment of effectiveness using the change in variable cash flows method, we have determined these interest rate swaps are effective in offsetting the variability in interest payments on $150 million of our variable rate debt resulting from changes in LIBOR. Under hedge accounting, we adjust our cash flow hedges on a quarterly basis to their fair values with the offsetting fair value adjustments to accumulated other comprehensive income (loss). Also on a quarterly basis, we measure hedge effectiveness by comparing the present value of the cumulative change in the expected future interest to be paid or received on the variable leg of our swaps against the expected

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future interest payments on $150 million of our variable rate debt. Any ineffectiveness is recorded directly to interest expense. As of June 30, 2017, we had no ineffectiveness on our cash flow hedges.

At June 30, 2017, we had accumulated other comprehensive income of $0.1 million that related to our current cash flow hedging instruments. Approximately $0.1 million will be transferred from accumulated other comprehensive income into interest expense as interest is paid on the underlying swap agreements during the third quarter of 2017.

Additional information on our interest rate swaps is as follows:



Derivative Instrument	Balance Sheet Location	Fair Value		Location of Offsetting Balance	Offsetting Amount
	(In thousands)
June 30, 2017
Interest rate swaps designated as cash flow hedging instrument:
Variable-to-fixed interest rate swap contracts ($150 million of LIBOR-based debt interest)	Other current assets	$	63	Accumulated other comprehensive income	$	63
		$	63		$	63

December 31, 2016
Interest rate swaps designated as cash flow hedging instrument:
Variable-to-fixed interest rate swap contracts ($150 million of LIBOR-based debt interest)	Other current assets	$	91	Accumulated other comprehensive income	$	91
		$	91		$	91

Interest Expense and Other Debt Information

Interest expense consists of the following components:



	Six Months Ended June 30,
	2017		2016
	(In thousands)
Interest on outstanding debt:
Credit Agreement, net of interest on interest rate swaps	$	13,299	$	10,284
6.5% Senior Notes	162		9,757
6% Senior Notes	12,000		—
Amortization of discount and deferred debt issuance costs	1,536		1,376
Commitment fees and other	720		679
Total interest incurred	27,717		22,096
Less capitalized interest	430		285
Net interest expense	$	27,287	$	21,811
Cash paid for interest	$	33,700	$	20,736

Capital Lease Obligations

Our capital lease obligations relate to vehicle leases with initial terms of 33 to 48 months. The total cost of assets under capital leases was $5.0 million and $4.9 million as of June 30, 2017 and December 31, 2016, respectively, with accumulated depreciation of $2.9 million and $2.4 million as of June 30, 2017 and December 31, 2016, respectively. We include depreciation of capital leases in depreciation and amortization in our consolidated statements of income.


Note 7:	Significant Customers

All revenues are domestic revenues, of which 91% are currently generated from our two largest customers: HFC and Alon.

The following table presents the percentage of total revenues generated by each of these customers:

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	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
HFC	85	%	83	%	85	%	82	%
Alon	6	%	9	%	7	%	8	%


Note 8:	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 2019 to 2036. 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 based on the Producer Price Index (“PPI”) or Federal Energy Regulatory Commission (“FERC”) index. As of June 30, 2017, these agreements with HFC require minimum annualized payments to us of $322 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 an omnibus agreement we have with HFC (the “Omnibus Agreement”), we pay HFC an annual administrative fee (currently $2.5 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 $93.2 million and $79.2 million for the three months ended June 30, 2017 and 2016, respectively, and $182.2 million and $162.0 million for the six months ended June 30, 2017 and 2016, respectively.


•	HFC charged us general and administrative services under the Omnibus Agreement of $0.6 million for each of the three months ended June 30, 2017 and 2016, and $1.2 million for each of the six months ended June 30, 2017 and 2016.


•	We reimbursed HFC for costs of employees supporting our operations of $11.4 million and $9.5 million for the three months ended June 30, 2017 and 2016, respectively, and $22.9 million and $19.4 million for the six months ended June 30, 2017 and 2016, respectively.


•	HFC reimbursed us $1.5 million and $5.0 million for the three months ended June 30, 2017 and 2016, respectively, and $2.8 million and $6.7 million for the six months ended June 30, 2017 and 2016, respectively, for expense and capital projects.


•	We distributed $31.7 million and $25.3 million for the three months ended June 30, 2017 and 2016, respectively, and $61.9 million and $49.8 million for the six months ended June 30, 2017 and 2016, respectively, to HFC as regular distributions on its common units and general partner interest, including general partner incentive distributions.


•	Accounts receivable from HFC were $36.6 million and $42.6 million at June 30, 2017, and December 31, 2016, respectively.


•	Accounts payable to HFC were $7.3 million and $16.4 million at June 30, 2017, and December 31, 2016, respectively.

•

Revenues for the six months ended June 30, 2017 and 2016, include $2.7 million and $5.5 million, respectively, of shortfall payments billed to HFC in 2016 and 2015, respectively. Deferred revenue in the consolidated balance sheets at June 30, 2017 and December 31, 2016, includes $5.9 million and $5.6 million, respectively, relating to certain shortfall billings to HFC. It is possible that HFC may not exceed its minimum obligations to receive credit for any of the $5.9 million deferred at June 30, 2017.

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Note 9:	Partners’ Equity

As of June 30, 2017, HFC held 22,380,030 of our common units and the 2% general partner interest, which together constituted a 36% ownership interest in us. Additionally, HFC owned all incentive distribution rights.

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 six months ended June 30, 2017, HEP issued 1,538,452 units under this program, providing $52.4 million in net proceeds. In connection with this program and to maintain the 2% general partner interest, HFC made capital contributions totaling $1.1 million. As of June 30, 2017, HEP has issued 2,241,907 units under this program, providing $77.1 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 our credit facility may be reborrowed from time to time.

Allocations of Net Income

Net income attributable to HEP is allocated between limited partners and the general partner interest in accordance with the provisions of the partnership agreement. HEP net income allocated to the general partner includes incentive distributions that are declared subsequent to quarter end. After incentive distributions and other priority allocations are allocated to the general partner, the remaining net income attributable to HEP is allocated to the partners based on their weighted-average ownership percentage during the period.

The following table presents the allocation of the general partner interest in net income for the periods presented below:



	Three Months Ended June 30,					Six Months Ended June 30,
	2017		2016			2017		2016
	(In thousands)
General partner interest in net income	$	827	$	540		$	1,338	$	1,170
General partner incentive distribution	17,501		12,137			34,128		23,609
Net loss attributable to Predecessor	—		(1,960		)	—		(3,110		)
Total general partner interest in net income	$	18,328	$	10,717		$	35,466	$	21,669

Cash Distributions

Our general partner, HEP Logistics, is entitled to incentive distributions if the amount we distribute with respect to any quarter exceeds specified target levels.

On July 27, 2017, we announced our cash distribution for the second quarter of 2017 of $0.6325 per unit. The distribution is payable on all common and general partner units and will be paid August 14, 2017, to all unitholders of record on August 7, 2017.

The following table presents the allocation of our regular quarterly cash distributions to the general and limited partners for the periods in which they apply. Our distributions are declared subsequent to quarter end; therefore, the amounts presented do not reflect distributions paid during the periods presented below.



	Three Months Ended June 30,				Six Months Ended June 30,
	2017		2016		2017		2016
	(In thousands, except per unit data)
General partner interest in distribution	$	1,188	$	978	$	2,336	$	1,927
General partner incentive distribution	17,501		12,137		34,128		23,609
Total general partner distribution	18,689		13,115		36,464		25,536
Limited partner distribution	40,682		34,575		80,314		68,302
Total regular quarterly cash distribution	$	59,371	$	47,690	$	116,778	$	93,838
Cash distribution per unit applicable to limited partners	$	0.6325	$	0.5850	$	1.2525	$	1.1600

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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 variable interest entity 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 10:	Net Income Per Limited Partner Unit

Net income per unit applicable to the limited partners is computed using the two-class method, because we have more than one class of participating securities. The classes of participating securities as of June 30, 2017, included common units, general partner units and incentive distribution rights (IDRs). 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. The dilutive securities are immaterial for all periods presented.

When our financial statements are retrospectively adjusted after a dropdown transaction, the earnings of the acquired business, prior to the closing of the transaction, are allocated entirely to our general partner and presented as net income (loss) attributable to Predecessors. The earnings per unit of our limited partners prior to the close of the transaction do not change as a result of the dropdown. After the closing of a dropdown transaction, the earnings of the acquired business are allocated in accordance with our partnership agreement as previously described.

For purposes of applying the two-class method including the allocation of cash distributions in excess of earnings, net income per limited partner unit is computed as follows:



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016
	(In thousands)
Net income attributable to the partners	$	41,335		$	39,120		$	66,898		$	82,095
Less: General partner’s distribution declared (including IDRs)	(18,689		)	(13,115		)	(36,464		)	(25,536		)
Limited partner’s distribution declared on common units	(40,682		)	(34,575		)	(80,314		)	(68,302		)
Distributions in excess of net income attributable to the partners	$	(18,036	)	$	(8,570	)	$	(49,880	)	$	(11,743	)

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	General Partner (including IDRs)			Limited Partners’ Common Units			Total
	(In thousands, except per unit data)
Three Months Ended June 30, 2017
Net income attributable to the partners:
Distributions declared	$	18,689		$	40,682		$	59,371
Distributions in excess of net income attributable to the partners	(361		)	(17,675		)	(18,036		)
Net income attributable to the partners	$	18,328		$	23,007		$	41,335
Weighted average limited partners' units outstanding				64,086
Limited partners' per unit interest in earnings - basic and diluted				$	0.36

Three Months Ended June 30, 2016
Net income attributable to the partners:
Distributions declared	$	13,115		$	34,575		$	47,690
Distributions in excess of net income attributable to the partners	(171		)	(8,399		)	(8,570		)
Net income attributable to the partners	$	12,944		$	26,176		$	39,120
Weighted average limited partners' units outstanding				58,865
Limited partners' per unit interest in earnings - basic and diluted				$	0.45



	General Partner (including IDRs)			Limited Partners’ Common Units			Total
	(In thousands, except per unit data)
Six Months Ended June 30, 2017
Net income attributable to partnership:
Distributions declared	$	36,464		$	80,314		$	116,778
Distributions in excess of net income attributable to partnership	(998		)	(48,882		)	(49,880		)
Net income attributable to partnership	$	35,466		$	31,432		$	66,898
Weighted average limited partners' units outstanding				63,602
Limited partners' per unit interest in earnings - basic and diluted				$	0.49

Six Months Ended June 30, 2016
Net income attributable to partnership:
Distributions declared	$	25,536		$	68,302		$	93,838
Distributions in excess of net income attributable to partnership	(234		)	(11,509		)	(11,743		)
Net income attributable to partnership	$	25,302		$	56,793		$	82,095
Weighted average limited partners' units outstanding				58,761
Limited partners' per unit interest in earnings - basic and diluted				$	0.96

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Note 11:	Environmental

We incurred no expenses for environmental remediation obligations for the three and six months ended June 30, 2017, and $0.2 million of expenses for the three and six months ended June 30, 2016. The accrued environmental liability, net of expected recoveries from indemnifying parties, reflected in our consolidated balance sheets was $6.5 million and $7.1 million at June 30, 2017, and December 31, 2016, respectively, of which $4.9 million and $5.4 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. As of June 30, 2017, and December 31, 2016, our consolidated balance sheets included additional accrued environmental liabilities of $0.8 million and $0.9 million, respectively, for HFC indemnified liabilities, and other assets included equal and offsetting balances representing amounts due from HFC related to indemnifications for environmental remediation liabilities.


Note 12:	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 13:	Operating Segments

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

The pipelines and terminals segment has been aggregated 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 operating 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 operating segment.



	Three Months Ended June 30,						Six Months Ended June 30,
	2017			2016			2017			2016

Revenues:
Pipelines and terminals - affiliate	$	75,613		$	75,004		$	145,258		$	153,343
Pipelines and terminals - third-party	15,991			15,718			32,600			34,882
Refinery processing units - affiliate	17,539			4,175			36,919			8,682
Total segment revenues	$	109,143		$	94,897		$	214,777		$	196,907

Segment operating income:
Pipelines and terminals	$	49,164		$	49,481		$	95,649		$	106,729
Refinery processing units	5,937			492			13,820			848
Total segment operating income	55,101			49,973			109,469			107,577
Unallocated general and administrative expenses	(2,615		)	(2,863		)	(5,249		)	(5,954		)
Interest and financing costs, net	(13,645		)	(11,164		)	(39,307		)	(21,587		)
Equity in earnings of unconsolidated affiliates	4,053			3,623			5,893			6,388
Gain (loss) on sale of assets and other	89			—			162			(8		)
Income before income taxes	$	42,983		$	39,569		$	70,968		$	86,416

Capital Expenditures:
Pipelines and terminals	$	12,157		$	13,770		$	20,286		$	31,644
Refinery processing units	102			19,431			238			43,742
Total capital expenditures	$	12,259		$	33,201		$	20,524		$	75,386

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	June 30, 2017		December 31, 2016
	(in thousands)
Identifiable assets:
Pipelines and terminals	$	1,354,198	$	1,369,756
Refinery processing units	334,796		342,506
Other	178,897		171,975
Total identifiable assets	$	1,867,891	$	1,884,237


Note 14:	Supplemental Guarantor/Non-Guarantor Financial Information

Obligations of HEP (“Parent”) under the 6% 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.

In conjunction with the preparation of our Condensed Consolidating Balance Sheet and Statements of Comprehensive Income included below, we identified and corrected the presentation of noncontrolling interests presented in the eliminations column in prior periods to reflect such balances and activity within the respective guarantor and non-guarantor subsidiaries columns.

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Condensed Consolidating Balance Sheet



June 30, 2017	Parent		Guarantor Restricted Subsidiaries		Non-Guarantor Non-Restricted Subsidiaries		Eliminations			Consolidated
	(In thousands)
ASSETS
Current assets:
Cash and cash equivalents	$	2	$	10,464	$	5,873	$	—		$	16,339
Accounts receivable	—		40,497		4,483		(242		)	44,738
Prepaid and other current assets	92		2,718		312		—			3,122
Total current assets	94		53,679		10,668		(242		)	64,199

Properties and equipment, net	—		947,611		364,155		—			1,311,766
Investment in subsidiaries	790,632		277,591		—		(1,068,223		)	—
Transportation agreements, net	—		63,381		—		—			63,381
Goodwill	—		256,498		—		—			256,498
Equity method investments	—		163,360		—		—			163,360
Other assets	725		7,962		—		—			8,687
Total assets	$	791,451	$	1,770,082	$	374,823	$	(1,068,465	)	$	1,867,891

LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	30	$	15,236	$	904	$	(242	)	$	15,928
Accrued interest	10,000		550		—		—			10,550
Deferred revenue	—		12,641		904		—			13,545
Accrued property taxes	—		1,696		2,700		—			4,396
Other current liabilities	26		3,160		3		—			3,189
Total current liabilities	10,056		33,283		4,511		(242		)	47,608